Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
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2/11-8

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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.
    2/11-8
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/11-8
    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.
    673-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.
    100
    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,
    03.04.1991
    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.
    11.07.1991
    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.
    11.07.1993
    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.
    18.05.2004
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4584.0
    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).
    4580.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    11
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    148
    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.
    DEVONIAN
    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.
    NO GROUP DEFINED
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 8' 8.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 20' 46.64'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6221376.90
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    521522.54
    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.
    1715

  • Wellbore history
    General
    Well 2/11-8 was designed to drill on the western part of block 2/11, approximately 2.3 km north of the Norwegian-Danish sector line. The well was located in the western part of the Ål Basin, separated from the Grensen Nose to the west by a series of faults. The primary target was sandstone of Late Jurassic age. Pre-Late Jurassic sandstones, probably Permian, were considered the secondary target. The main objectives for well 2/11-8 were to prove hydrocarbons in the target Formations; to define the reservoir level and reservoir quality adjacent to the Grensen Nose; and to collect geological information important for further reservoir evaluation and geological modelling in the area. Seismic amplitude anomalies were present at 347 m, 435 m, and 597 m. Shallow gas could not be excluded at these levels so an 8 1/2" pilot hole was planned to be drilled. The total depth of the well was planned to be at 4616 m, in igneous rocks of Permian age.
    Operations and results
    Wildcat well 2/11-8 was spudded with the semi-submersible installation Polar Pioneer on April 3 1991 and drilled to a total depth of 4584 m in clastic rocks of Carboniferous to possible Devonian age. The well was drilled with spud mud down to 1018 m, with ANCOQUAT cation polymer mud from 1018 m to 2515 m, with KCl mud from 2515 m to 3717 m, and with HPHT mud from 3717 m to TD.
    The only Late Jurassic (Ryazanian to Volgian) sediments encountered in the well were 3 m of carbonaceous claystone, representing the Mandal Formation of the Tyne Group. The thin Jurassic section rested unconformably on Carboniferous sediments. Poor shows were observed in the Jurassic claystones as well as in carbonaceous claystones between 4265 m to 4335 m in the Carboniferous. A single 10 m core was cut at TD for stratigraphic purposes. The core recovered claystones with minor sandstone interbeds and stringers of limestone and was dated to possible Devonian. No fluid samples were taken. The well was permanently abandoned as a dry hole on 11 July 1991.
    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]
    1020.00
    4582.00

  • 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
    4574.0
    4583.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    9.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4574-4579m
    Core photo at depth: 4579-4584m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4574-4579m
    4579-4584m

  • 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
    174.0
    36
    174.0
    0.00
    LOT
    INTERM.
    18 5/8
    1000.0
    24
    1015.0
    2.06
    LOT
    INTERM.
    13 3/8
    2500.0
    17 1/2
    2515.0
    1.98
    LOT
    INTERM.
    9 5/8
    4147.0
    12 1/4
    4164.0
    2.17
    LOT
    OPEN HOLE
    4584.0
    8 1/8
    4584.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    4155
    4572
    CST GR
    4155
    4572
    DIL LSS GR SP AMS
    4150
    4581
    DIL LSS LDL GR SP AMS
    999
    2518
    FMS4 AMS
    4150
    4583
    LDL CNL GR CAL AMS
    4150
    4581
    LSS GR
    2497
    4140
    MWD - GR RES DIR
    88
    4298
    MWD - LWD CDR GR DIR
    175
    650
    RFT GR
    4320
    4568
    VDL GR
    1972
    2483
    VDL GR
    3698
    4127
    VSP
    1945
    3845
    VSP
    3675
    4580

  • 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
    0.70

  • 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
    17.20

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    140
    1.05
    WATER BASED
    174
    1.20
    WATER BASED
    216
    1.20
    WATER BASED
    750
    1.60
    19.0
    WATER BASED
    755
    1.08
    WATER BASED
    1015
    1.20
    WATER BASED
    1018
    1.60
    27.0
    WATER BASED
    1376
    1.60
    25.0
    WATER BASED
    1984
    1.60
    39.0
    WATER BASED
    2235
    1.70
    17.0
    WATER BASED
    2259
    1.60
    35.0
    WATER BASED
    2515
    1.60
    27.0
    WATER BASED
    2737
    1.52
    24.0
    WATER BASED
    2958
    1.52
    26.0
    WATER BASED
    3009
    1.52
    23.0
    WATER BASED
    3068
    1.52
    20.0
    WATER BASED
    3080
    1.52
    24.0
    WATER BASED
    3140
    1.51
    24.0
    WATER BASED
    3230
    1.45
    23.0
    WATER BASED
    3245
    1.45
    22.0
    WATER BASED
    3313
    1.45
    22.0
    WATER BASED
    3320
    1.45
    24.0
    WATER BASED
    3484
    1.45
    24.0
    WATER BASED
    3633
    1.45
    21.0
    WATER BASED
    3650
    1.45
    18.0
    WATER BASED
    3687
    1.45
    19.0
    WATER BASED
    3717
    1.50
    19.0
    WATER BASED
    3723
    1.60
    20.0
    WATER BASED
    3748
    1.60
    17.0
    WATER BASED
    3766
    1.60
    20.0
    WATER BASED
    3767
    1.62
    20.0
    WATER BASED
    3819
    1.61
    20.0
    WATER BASED
    3850
    1.60
    20.0
    WATER BASED
    3852
    1.61
    18.0
    WATER BASED
    3884
    1.60
    18.0
    WATER BASED
    3886
    1.60
    19.0
    WATER BASED
    3908
    1.60
    17.0
    WATER BASED
    3972
    1.60
    16.0
    WATER BASED
    3985
    1.60
    16.0
    WATER BASED
    4037
    1.60
    16.0
    WATER BASED
    4085
    1.70
    16.0
    WATER BASED
    4088
    1.60
    16.0
    WATER BASED
    4163
    1.70
    18.0
    WATER BASED
    4170
    1.70
    17.0
    WATER BASED
    4187
    1.70
    19.0
    WATER BASED
    4251
    1.70
    15.0
    WATER BASED
    4276
    1.71
    18.0
    WATER BASED
    4305
    1.70
    17.0
    WATER BASED
    4353
    1.70
    17.0
    WATER BASED
    4353
    1.70
    17.0
    WATER BASED
    4441
    1.80
    18.0
    WATER BASED
    4584
    1.89
    17.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1710.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2990.0
    [m]
    DC
    RRI
    3020.0
    [m]
    DC
    RRI
    3135.0
    [m]
    DC
    RRI
    3770.0
    [m]
    DC
    RRI
    3845.0
    [m]
    DC
    RRI
    3860.0
    [m]
    DC
    RRI
    3875.0
    [m]
    DC
    RRI
    3890.0
    [m]
    DC
    RRI
    3905.0
    [m]
    DC
    RRI
    3920.0
    [m]
    DC
    RRI
    3935.0
    [m]
    DC
    RRI
    3950.0
    [m]
    DC
    RRI
    3965.0
    [m]
    DC
    RRI
    3980.0
    [m]
    DC
    RRI
    4000.0
    [m]
    DC
    RRI
    4010.0
    [m]
    DC
    RRI
    4020.0
    [m]
    DC
    RRI
    4040.0
    [m]
    DC
    RRI
    4055.0
    [m]
    DC
    RRI
    4070.0
    [m]
    DC
    RRI
    4085.0
    [m]
    DC
    RRI
    4100.0
    [m]
    DC
    RRI
    4115.0
    [m]
    DC
    RRI
    4130.0
    [m]
    DC
    RRI
    4165.0
    [m]
    SWC
    RRI
    4180.0
    [m]
    SWC
    RRI
    4230.0
    [m]
    SWC
    RRI
    4255.0
    [m]
    SWC
    RRI
    4263.0
    [m]
    SWC
    RRI
    4264.0
    [m]
    SWC
    RRI
    4266.0
    [m]
    SWC
    RRI
    4267.0
    [m]
    SWC
    RRI
    4270.0
    [m]
    SWC
    RRI
    4278.0
    [m]
    SWC
    RRI
    4280.0
    [m]
    SWC
    RRI
    4290.0
    [m]
    SWC
    RRI
    4295.0
    [m]
    SWC
    RRI
    4300.0
    [m]
    SWC
    RRI
    4305.0
    [m]
    SWC
    RRI
    4310.0
    [m]
    SWC
    RRI
    4313.0
    [m]
    SWC
    RRI
    4318.0
    [m]
    SWC
    RRI
    4320.0
    [m]
    SWC
    RRI
    4327.0
    [m]
    DC
    RRI
    4330.0
    [m]
    SWC
    RRI
    4335.0
    [m]
    SWC
    RRI
    4352.0
    [m]
    DC
    RRI
    4355.0
    [m]
    SWC
    RRI
    4372.0
    [m]
    SWC
    RRI
    4390.0
    [m]
    DC
    RRI
    4405.0
    [m]
    SWC
    RRI
    4412.0
    [m]
    DC
    RRI
    4427.0
    [m]
    DC
    RRI
    4430.0
    [m]
    SWC
    RRI
    4438.0
    [m]
    SWC
    RRI
    4445.0
    [m]
    SWC
    RRI
    4450.0
    [m]
    DC
    RRI
    4457.0
    [m]
    SWC
    RRI
    4480.0
    [m]
    DC
    RRI
    4489.0
    [m]
    SWC
    RRI
    4500.0
    [m]
    SWC
    RRI
    4510.0
    [m]
    DC
    RRI
    4515.0
    [m]
    SWC
    RRI
    4521.0
    [m]
    SWC
    RRI
    4532.0
    [m]
    SWC
    RRI
    4540.0
    [m]
    DC
    RRI
    4540.0
    [m]
    SWC
    RRI
    4552.0
    [m]
    SWC
    RRI
    4562.0
    [m]
    DC
    RRI
    4562.0
    [m]
    SWC
    RRI
    4572.0
    [m]
    DC
    RRI
    4574.1
    [m]
    C
    RRI
    4583.9
    [m]
    C
    RRI