Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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11.11.2024 - 01:26
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2/5-2

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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.
    2/5-2
    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
    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.
    2/5-2
    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.
    51-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.
    96
    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,
    15.01.1971
    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.
    20.04.1971
    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.
    20.04.1973
    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.
    02.04.2007
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    35.0
    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).
    3597.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    120
    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.
    TOR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 38' 41.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 22' 20.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6278059.65
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    522837.92
    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.
    188

  • Wellbore history
    General
    Well 2/5-2 was drilled as an appraisal well on the 2/5-1 Tor Discovery in the southern Norwegian North Sea. The objective was to evaluate the eastern part of the structure.
    Operations and results
    Appraisal well 2/5-2 was spudded with the jack-up installation M ærsk Explorer on 15 January 1971 and drilled to TD at 3597 m in the Late Cretaceous Tor Formation. The well was drilled water based, but with diesel addition below 1830 m.
    The well encountered top Paleocene (Balder Formation at 2978 m, top Danian chalk (Ekofisk Formation) at 3118 m, and top Late Cretaceous chalk (Tor Formation) at 3360 m. Commercial quantities of hydrocarbons were encountered in the Ekofisk Formation where a total of approximately 57 m net pay out of a gross section of 244 m was found. This was a significant reduction from the 89 m net pay in the 2/5-1 discovery well. Furthermore, the water saturation in Ekofisk was higher in 2/5-2 compared to 2/5-1 (41% and 22%, respectively).
    Five conventional cores were cut in the intervals 3120 - 3188 m and 3235 - 3311 m in the Ekofisk Formation. No wire line fluid samples were taken.
    The well was permanently abandoned on 20 April 1971 as a an oil appraisal.
    Testing
    Six drill stem tests were carried out: DST 1 in Late Cretaceous chalk (Tor Formation), DST 2 in the Late Cretaceous/ Danian boundary, and DST 3 - 6 in Danian chalk (Ekofisk Formation). The following results are after acidization:
    DST 1 in the interval 3511 to 3513 m flowed minor quantities of slightly oil-cut mud.
    DST 2 at 3350 - 3361 m flowed 165 Sm3, 34 m3 water, and 39077 Sm3 gas /day on 64/64" + 32/64" choke. The oil gravity was 39 deg API and the GOR was 237 Sm3/Sm3.
    DST 3 at 3299 - 3314 m flowed 629 Sm3 oil and 159900 Sm3 gas /day on a 23/64" choke. The oil gravity was 40.5 deg API and the GOR was 254 Sm3/Sm3. Maximum bottom hole temperature recorded in the test was 134 deg C.
    DST 4 at 3165 - 3183 m flowed initially 362 Sm3 and 6400 Sm3 gas /day, declining to 4.6 Sm3 oil and 1010 Sm3 gas /day.
    DST 5 at 3162 - 3179 m produced a total accumulated of 15 Sm3 oil and 36 Sm3 water in a 7.5 hours test.
    DST 6 at 3150 - 3188 m produced sluggishly a total accumulated of 2.4 Sm3 oil and 3.5 Sm3 water in 8 hours test.

  • 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]
    137.16
    3596.64

  • 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
    10235.0
    10244.0
    [ft ]
    2
    10295.0
    10338.0
    [ft ]
    3
    10413.0
    10458.0
    [ft ]
    4
    10614.0
    10669.0
    [ft ]
    5
    10841.0
    10865.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 10235-10253ft
    Core photo at depth: 10253-10271ft
    Core photo at depth: 10271-10289ft
    Core photo at depth: 10289-10307ft
    Core photo at depth: 10307-10321ft
    10235-10253ft
    10253-10271ft
    10271-10289ft
    10289-10307ft
    10307-10321ft
    Core photo at depth: 10321-10415ft
    Core photo at depth: 10415-10423ft
    Core photo at depth: 10415-10432ft
    Core photo at depth: 10249-10458ft
    Core photo at depth: 10432-10449ft
    10321-10415ft
    10415-10423ft
    10415-10432ft
    10249-10458ft
    10432-10449ft
    Core photo at depth: 10614-10630ft
    Core photo at depth: 10630-10647ft
    Core photo at depth: 10647-10664ft
    Core photo at depth: 10664-10850ft
    Core photo at depth: 10850-10865ft
    10614-10630ft
    10630-10647ft
    10647-10664ft
    10664-10850ft
    10850-10865ft

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    101
    1712
    2978
    2978
    2996
    3005
    3102
    3118
    3118
    3360

  • 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
    16.39
    pdf
    2.06
    pdf
    1.43

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3511
    3514
    0.0
    2.0
    3350
    3361
    0.0
    3.0
    3300
    3315
    0.0
    4.0
    3166
    3183
    0.0
    5.0
    3166
    3183
    0.0
    6.0
    3150
    3188
    0.0
    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
    3.0
    4.0
    5.0
    6.0
    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
    2.0
    165
    39643
    3.0
    377
    96276
    4.0
    362
    5.0
    6.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AMPL
    3104
    3596
    BHC GR
    400
    3596
    CBL
    1372
    3571
    CCL
    3021
    3226
    DLL
    3104
    3422
    FDC GR
    1589
    3426
    GR
    67
    400
    GRN
    3110
    3570
    HDT
    1589
    3426
    IES
    400
    3599
    ML MLL-C
    3104
    3426
    PROX ML
    3104
    3426
    SNP GR
    3104
    3599
    VELOCITY
    400
    3598

  • 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
    134.0
    36
    137.0
    0.00
    LOT
    INTERM.
    20
    400.0
    26
    400.0
    0.00
    LOT
    INTERM.
    13 3/8
    1598.0
    17 1/2
    1600.0
    0.00
    LOT
    INTERM.
    9 5/8
    3104.0
    12 1/4
    3109.0
    0.00
    LOT
    PROD.
    7
    3595.0
    8 1/2
    3598.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    137
    1.07
    70.0
    seawater
    365
    1.14
    40.0
    seawater
    1706
    1.49
    43.0
    lignosul
    3322
    1.61
    45.0
    lignosul

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    10862.00
    [ft ]