Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
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2/11-3 A

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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.
    2/11-3 A
    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
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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
    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.
    2/11-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    Amoco Norway Oil Company
    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.
    192-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.
    101
    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,
    03.12.1977
    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.
    13.03.1978
    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.
    13.03.1980
    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.
    22.03.2013
    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
    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.
    PALEOCENE
    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.
    EKOFISK FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    LATE CRETACEOUS
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    TOR FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    LATE CRETACEOUS
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    HOD FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    36.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    72.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3400.0
    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).
    2857.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    53.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    110
    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.
    HOD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 10' 53.74'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 27' 51.78'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6226525.75
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    528827.92
    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.
    287
  • Wellbore history

    General
    The Hod complex was proved to consist of two individual structures by well 2/11-3, which was drilled about 2.5 km due east of 2/11-2. Seismically, the Hod structural complex is difficult to map due to shallow gas in the Tertiary, mainly over the western part of the structure, which complicates the time to depth conversion. As it turned out, the chalk in 2/11-2 was drilled close to the limit of structural closure of the East Structure and was therefore dry with shows only. Well 2/11-3 A was a sidetrack from well 2/11-3 to test Late Cretaceous chalk in a graben feature indicated by seismic in the crestal regional of the East Hod structure. A graben, if present, would have possibilities for preservation of younger Maastrichtian rock which in general is of high reservoir quality with high porosity and often very high oil saturation.
    Operations and results
    Well 2/11-3A was sidetracked from just below the 13 3/8-inch casing shoe on 3 December 197 7 and drilled to TD at a total measured depth of 3400 m (2857 m TVD) in the Late Cretaceous Hod Formation. The pipe stuck at TD prior to logging and deviation survey. After working on the stuck pipe the string was disconnected at 3189 m and the well was kicked-off on the low side in order to complete logging and testing of the pay-zone discovered before the pipe got stuck. This technical sidetrack was drilled to 3333 m (2812 m TVD).
    Top Chalk was encountered in the sidetrack at 3189.5 meters (2713 meters TVD). The uppermost 5 m belonged to the Ekofisk Formation. Then followed 58.5 m of Tor Formation, 13 m of tight Middle Hod Formation, and 70 m of Lower Hod. The Chalk was found oil bearing from top Chalk to TD in the sidetrack, with exception of 8 m in Middle Hod. Shows on cuttings were recorded in the primary well bore down to 3370 m. No oil shows were reported from above top Chalk.
    Seven cores were cut in the top Chalk section in the primary un-logged well bore in the interval from 3192.4 m to 3250.3 m. Recovery varied from 18 % to 100 %. No wire line fluid samples were taken.
    The well was permanently abandoned on 13 March 1978 as an oil appraisal well.
    Testing
    Two Drill Stem Tests were conducted in the well.
    DST 1 tested the interval 3268 to 3280 m. After hydraulic fracturing the test flowed on average 88 Sm3 oil and 12700 Sm3 gas /day through a 24/64" choke. The average GOR was 133 Sm3/Sm3, the oil gravity was 29.1 deg API, and the gas gravity was 0.8 (air=1). Maximum temperature recorded down hole was 102 deg C. A final flow on a 32/64" choke gave sluggish flow but did not increase rates much.
    DST 2 tested the interval 3230 to 3236 m. After acid stimulation the test flowed on average 915 Sm3 oil and 104500 Sm3 gas /day through a 32/64" choke. The average GOR was 114 Sm3/Sm3, the oil gravity was 33.9 deg API and the gas gravity was 0.69 (air = 1). Maximum temperature recorded down hole was 107 deg C.
  • 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]
    1298.46
    3162.50
  • 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
    3192.0
    3198.3
    [m ]
    2
    3201.5
    3206.3
    [m ]
    3
    3206.3
    3209.9
    [m ]
    4
    3226.0
    3230.1
    [m ]
    5
    3231.9
    3235.7
    [m ]
    6
    3235.9
    3239.1
    [m ]
    7
    3240.9
    3251.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    36.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3192-3194m
    Core photo at depth: 3194-3197m
    Core photo at depth: 3197-3198m
    Core photo at depth: 3201-3204m
    Core photo at depth: 3204-3206m
    3192-3194m
    3194-3197m
    3197-3198m
    3201-3204m
    3204-3206m
    Core photo at depth: 3206-3209m
    Core photo at depth: 3209-3209m
    Core photo at depth: 3226-3228m
    Core photo at depth: 3228-3230m
    Core photo at depth: 3231-3234m
    3206-3209m
    3209-3209m
    3226-3228m
    3228-3230m
    3231-3234m
    Core photo at depth: 3234-3235m
    Core photo at depth: 3235-3238m
    Core photo at depth: 3238-3239m
    Core photo at depth: 3240-3243m
    Core photo at depth: 3243-3245m
    3234-3235m
    3235-3238m
    3238-3239m
    3240-3243m
    3243-3245m
    Core photo at depth: 3245-3248m
    Core photo at depth: 3248-3250m
    Core photo at depth: 3250-3252m
    Core photo at depth:  
    Core photo at depth:  
    3245-3248m
    3248-3250m
    3250-3252m
  • 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
    1.75
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3268
    3280
    9.5
    2.0
    3230
    3236
    9.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    88
    12743
    0.880
    0.800
    2.0
    519
    63429
    0.840
    0.690
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL TT
    849
    3114
    CBL VDL TT GR
    2996
    3298
    CBL VDL TT GR
    3000
    3287
    CNL FDC GR CAL
    3121
    3335
    CONT-DIP
    3126
    3327
    DLL MSFL GR SP CAL
    3127
    3334
    ISF SON SP GR
    1280
    2055
    TEMP
    150
    2838
    TEMP
    3100
    3272
  • 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
    INTERM.
    9 5/8
    3129.0
    12 1/4
    3130.0
    1.88
    LOT
    OPEN HOLE
    3400.0
    8 1/2
    3400.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2446
    1.79
    waterbased
    3288
    1.74
    waterbased