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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35/11-1

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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.
    35/11-1
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    35/11-1
    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.
    Mobil Exploration Norway INC
    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.
    417-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.
    76
    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,
    23.05.1984
    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.
    06.08.1984
    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.
    06.08.1986
    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.
    15.06.2005
    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
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    360.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3361.0
    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).
    3360.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    108
    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.
    TRIASSIC
    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.
    HEGRE GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 10' 59.27'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 39' 44.95'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6783527.21
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    535626.01
    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.
    128

  • Wellbore history
    General
    Wildcat well 35/11-1 was drilled on the "A" structure close to the border between Block 35/11 and Block 35/12, and ca 25 km north of the Troll Field. Its primary objective was to assess the hydrocarbon potential in Middle to Upper Jurassic strata on the "A" structure that straddles the border between Block 35/11 and the unlicensed Block 35/12. Sands of Lower Jurassic age were regarded as secondary objectives. Planned TD was into the Triassic.
    Operations and results
    A total of 317 pockmarks were identified in the area from the site survey. The average density was estimated to 20 per square kilometre. The average depth of these was 1-2 m, though some were of greater depth. None of the pockmarks were seen to be active.
    Wildcat well 35/11-1 was spudded with the semi-submersible installation on 23 May 1984 and drilled to TD at 3361 m, approximately 100 meters into in the Triassic Hegre Group. The 36" hole section was drilled through boulder beds causing the bit to build angle. Because of high deviation the well was re-spudded. After drilling the 26" hole, the well flowed several times. Although the well would not stay static, it was decided to run the 20" casing in an attempt to seal off the water flow. This resulted in the 20" casing parting at the wellhead, but was successfully recovered. After reaming some tight spots the 20" casing was set and cement was squeezed to seabed to stop the water flow in annulus. Some tight spots were experienced in the 17 1/2" and 12 1/4" hole sections. Lost circulation occurred at 2439 m, due to this the 9 5/8" casing was run. The well was drilled with gelled seawater spotted with hi-vis pills down to 1015 m and with KCl/polymer mud from 1015 m to TD.
    Top Jurassic was encountered at 2018 m. The 451 meter thick Viking Group was dominated by argillaceous material, but water-wet arenaceous sections with a net reservoir thickness of 78 m were found scattered throughout. Average porosity in the reservoir sections is 20.6 %. Top Brent Group was penetrated at 2469 meters. Interbedded coals, clays and thin sands dominated the Ness Formation. The Etive Formation and large parts of the Dunlin Group were mainly arenaceous. The gross thickness is 502.5 meters. The net reservoir thickness between the top Brent Group and the Statfjord Formation is 255.2 m with an average porosity of 17.2%. The Early Jurassic to Triassic section consisted to a great extent of sandy intervals. The net reservoir section was 209 m meters over a gross interval of 384 m. The average porosity was 13.7%.
    The background gas increased dramatically at 2018 m at Top Viking Group with 8.1 % methane, 0.3 % ethane, and 0.15 % propane, dropping rapidly to normal background levels at 2030 m. No significant shows were recorded on cuttings, sidewall cores or conventional cores in the well. From the logs as all sands had high water saturations, and RFT pressure data from the Jurassic sands showed water gradients. One core was recovered in the Brent Group in the interval from 2552.8 to 2562 m. One RFT run was performed in the Late Jurassic and one in the Middle to Early Jurassic. Formation pressures were recorded from permeable zones, and a sample of the formation fluids were recovered in both runs. The two samples, one taken at 2113 the other at 2535 m, both contained formation water contaminated by a potassium chloride based mud filtrate.
    The well was permanently abandoned on 6 August 1984 as a dry hole.
    Testing
    No drill stem test was performed.
    ml>

  • 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]
    510.00
    3361.00

  • 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
    2552.8
    2562.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    9.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2552-2556m
    Core photo at depth: 2556-2560m
    Core photo at depth: 2560-2562m
    Core photo at depth:  
    Core photo at depth:  
    2552-2556m
    2556-2560m
    2560-2562m

  • 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
    506.5
    36
    510.0
    0.00
    LOT
    SURF.COND.
    20
    1002.5
    26
    1015.0
    1.38
    LOT
    INTERM.
    13 3/8
    2026.0
    17 1/2
    2029.0
    1.80
    LOT
    INTERM.
    9 5/8
    2426.0
    12 1/4
    2439.5
    1.65
    LOT
    OPEN HOLE
    3361.0
    8 1/2
    3361.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    1035
    2027
    CST GR
    2114
    2428
    HRT
    380
    2390
    IDF LSS MAFL GR
    2426
    3361
    ISF LSS GR
    506
    2438
    LDL CAL GR
    1003
    2436
    LDL CNL NGS
    2426
    3361
    NGS
    2027
    2430
    NGS
    2426
    3361
    RFT
    2113
    2276
    RFT
    2426
    3242
    SHDT GR
    2026
    2438
    SHDT HR
    2426
    3361
    TEMPERATURE
    375
    2010
    VSP CHSCKSHOT
    550
    3361

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.55

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.84
    pdf
    2.32

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    13.19

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    800
    1.08
    5.0
    23.0
    WATER BASED
    1050
    1.21
    11.0
    18.0
    WATER BASED
    1260
    1.22
    14.0
    19.0
    WATER BASED
    1500
    1.27
    28.0
    14.0
    WATER BASED
    1820
    1.29
    23.0
    19.0
    WATER BASED
    1885
    1.32
    28.0
    17.0
    WATER BASED
    2060
    1.45
    24.0
    15.0
    WATER BASED
    2230
    1.56
    34.0
    8.0
    WATER BASED
    2310
    1.57
    36.0
    23.0
    WATER BASED
    2360
    1.56
    37.0
    25.0
    WATER BASED
    2460
    1.50
    21.0
    14.0
    WATER BASED
    2510
    1.56
    26.0
    12.0
    WATER BASED
    2685
    1.45
    22.0
    14.0
    WATER BASED
    2770
    1.42
    21.0
    14.0
    WATER BASED
    2880
    1.35
    15.0
    14.0
    WATER BASED
    2990
    1.32
    15.0
    14.0
    WATER BASED
    3100
    1.33
    27.0
    19.0
    WATER BASED