Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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2/8-3

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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.
    2/8-3
    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
    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.
    2/8-3
    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.
    72-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.
    80
    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,
    16.06.1972
    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.
    03.09.1972
    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.
    03.09.1974
    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.
    26.10.2009
    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
    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 SHOWS
    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.
    34.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    69.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4115.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    132
    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.
    HAUGESUND FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 18' 31'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 26' 54.1'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6240656.75
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    527741.32
    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.
    117

  • Wellbore history
    General
    Well 2/8-3 is located in the Feda Graben, ca 2 km north-east of the Valhall Field in the southern North Sea. The primary objective was to test the Jurassic hydrocarbon potential. The secondary objective was the chalk of the Shetland Group.
    The well is reference well for the Haugesund and Farsund Formations.
    Operations and results
    Wildcat well 2/8-3 was spudded with the jack-up installation Zapata Explorer on 16 June 1972 and drilled to TD at 4115 m in Late Jurassic shales of the Haugesund Formation. The well took 48 days to complete and was drilled with unical/lignosulphonate/caustic based mud.
    Reservoir quality rock was absent throughout the well. The first signs of oil were seen in Palaeocene tight siltstones with poor porosities. These were described as bright gold yellow fluorescence with a bright white streaming cut. Gas levels in the Shetland Group were low and no shows were seen in this group. A DST was run over part of this section but yielded only drilling mud. From 3267.3 m, within the Early Cretaceous, gas levels rose significantly and were associated with fair to poor shows in the Marls. The fluorescence was described as gold in colour with a slow pale yellow cut. From 3444 m, gas and shows increased and were contained in slightly argillaceous, hard limestone. Oil staining was seen and the fluorescence described as dark yellow gold with a pale yellow to very light brown cut. Mandal Formation shale was the first Jurassic age rocks seen. Gas levels were very high through these shales and the shows were described as bituminous with no direct fluorescence and a pale yellow cut. Between 3578 - 3600 m a gross sandstone unit was indicated by the gamma ray log. In roughly the same interval (3593.6 and 3605.8 m) abundant free oil appeared in the mud and abundant bright yellow gold fluorescence and a bright yellow straw cut were observed. This interval tested low rates of oil and gas. Dolomite stringers around 3858.8 and 3907.5 m gave good gas and oil shows with a dull yellow fluorescence and a pale yellow streaming cut.
    No conventional cores were cut in this well. Four wire line core slices were cut in the Tor and Hod Formations, each 3 foot long at core points: 2999.2, 2967.8, 2956.6, and 2785 m. All had 100 % recovery. Sidewall cores were not taken. No wire line fluid samples were taken.
    The well was permanently abandoned on 3 September 1972 as a well with oil and gas shows.
    Testing
    Three DST tests were performed, two in the Jurassic and one in the Tor Formation. Small amounts of Oil and gas were recovered from the Jurassic Tests. Only mud was recovered from the Cretaceous Tor Test.
    DST 1 from 3570.7 - 3587.5 m in the Mandal Formation recovered 3.8 Sm3 of oil and 278 Sm3 gas. The formation shut in Pressure was 4443 psi and the Formation flowing pressure was 3632 psi after 332 minutes.
    DST 2 3600 - 3571 m, flowed 32 Sm3 oil and 2019 Sm3 gas with a Final Shut in Pressure of 4037 psi and a final flowing pressure of 3537 psi after 980 minutes. 80 barrels of acid were used to stimulate the well test.
    DST 3 2871-2882 m, flowed only mud despite acidising. The final shut in pressure was 5477 psi and the final flowing pressure was 4455 psi after 491 minutes.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    405.38
    4114.80

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    9100.0
    [ft]
    DC
    OD
    9160.0
    [ft]
    DC
    OD
    9220.0
    [ft]
    DC
    OD
    9280.0
    [ft]
    DC
    OD
    9340.0
    [ft]
    DC
    OD
    9400.0
    [ft]
    DC
    OD
    9460.0
    [ft]
    DC
    OD
    9520.0
    [ft]
    DC
    OD
    9580.0
    [ft]
    DC
    OD
    9640.0
    [ft]
    DC
    OD
    9700.0
    [ft]
    DC
    OD
    9760.0
    [ft]
    DC
    OD
    9820.0
    [ft]
    DC
    OD
    9880.0
    [ft]
    DC
    OD
    9940.0
    [ft]
    DC
    OD
    10000.0
    [ft]
    DC
    OD
    10060.0
    [ft]
    DC
    OD
    10120.0
    [ft]
    DC
    OD
    10180.0
    [ft]
    DC
    OD
    10240.0
    [ft]
    DC
    OD
    10300.0
    [ft]
    DC
    OD
    10360.0
    [ft]
    DC
    OD
    10420.0
    [ft]
    DC
    OD
    10480.0
    [ft]
    DC
    OD
    10540.0
    [ft]
    DC
    OD
    10600.0
    [ft]
    DC
    OD

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.90
    pdf
    0.51

  • 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
    3.28
    pdf
    67.92

  • Documents – Norwegian Offshore Directorate papers

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3571
    3589
    0.0
    2.0
    3600
    3571
    0.0
    3.0
    2871
    2882
    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
    30.000
    25.000
    2.0
    28.000
    24.000
    3.0
    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
    4
    278
    2.0
    32
    2019
    3.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    4ARM HRD
    6039
    10602
    4ARM HRD
    10570
    12142
    4ARM HRD
    12138
    13500
    BHC GR
    6039
    1059
    BHC GR
    10570
    12132
    BHC GR
    12138
    13490
    CBL
    2500
    12140
    CN FDC GR
    8500
    10602
    CN FDC GR
    10570
    12140
    CN FDC GR
    12138
    13500
    DLL
    8500
    10591
    DLL MSFL
    12138
    13490
    DLL MSFL SP
    10570
    12125
    VELOCITY
    6039
    13490
    VSP
    1100
    11700

  • 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
    144.0
    36
    144.0
    0.00
    LOT
    SURF.COND.
    20
    382.0
    26
    396.0
    0.00
    LOT
    INTERM.
    13 3/8
    1841.0
    17 1/2
    1849.0
    0.00
    LOT
    INTERM.
    9 5/8
    3223.0
    12 1/4
    3230.0
    0.00
    LOT
    LINER
    7
    3700.0
    8 1/2
    3700.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1848
    1.62
    waterbased
    2082
    1.64
    waterbased
    2481
    1.63
    waterbased
    3009
    1.67
    waterbased
    3229
    1.68
    waterbased
    3544
    1.92
    waterbased
    3700
    1.99
    waterbased
    4115
    2.01
    waterbased