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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34/8-8 R

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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.
    34/8-8 R
    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.
    34/8-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH-9001-3d:ROW 925 & COL.585
    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.
    730-L2
    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.
    22
    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,
    16.02.1993
    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.
    09.03.1993
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    09.03.1993
    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.
    09.03.1995
    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.
    10.01.2012
    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.
    YES
    Reentry activity
    Reason for reentry of the wellbore. Only relevant for exploration wellbores. Example of legal values: DRILLING, DRILLING/PLUGGING, LOGGING, PLUGGING, TESTING, TESTING/PLUGGING.
    TESTING/PLUGGING
    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.
    MIDDLE JURASSIC
    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.
    BRENT GP
    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.
    340.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3624.0
    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).
    3622.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    130
    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 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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 22' 46.19'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 28' 43.81'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6805332.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    472148.13
    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.
    2080

  • Wellbore history
    General
    Well 34/8-8 R is a re-entry of appraisal well 34/8-8 on the N-1 segment of the 34/8-1 Visund discovery on Tampen Spur in the Northern North Sea. The primary objective of well 34/8-8R was to determine the pressure regime and pressure gradient in the hydrocarbon bearing sands in Tarbert, Ness and Etive formations. The secondary objective was to determine the fluid system/composition and the possible presence of a gas oil contact in the Tarbert/Ness formations. The third objective was to investigate the mobility of oil and water down to the interpreted free water level (FWL)
    Operations and results
    Well 34/8-8 was re-entered on 16 February 1993 with the semi-submersible installation Polar Pioneer.
    The well was drill stem tested. No significant problems occurred in the operations.
    No cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 9 March 1993 as an oil appraisal.
    Testing
    Two drill stem tests were performed. In both tests production logging (PLT) was performed during the main flow.
    DST 1 tested the interval 2960.2 to 2973.2 m in the Ness/Etive formations. The test sequence consisted of an initial and a cleanup flow/build-up period with down hole shut-in. The main flow with PLT was interrupted by poor weather conditions and the well was immediately killed. Only a limited amount of the surface sampling program was therefore accomplished. No down hole samples were collected. The test produced 775 Sm3 oil, 10600 Sm3 gas and 161 m3 water/day through a 12.7 mm choke in the cleanup flow. GOR was 137 Sm3/Sm3. The oil density was 0.852 g/cm3 and the gas gravity was 0.665 (air = 1) with 1.6% CO2 and 0.25 ppm H2S. Flowing BHP was 423.3 bar and flowing BHT was 112.3 deg C. The PLT results showed an effective OWC at 2971.5.
    DST 2 tested the interval 2921 to 2950 in the Tarbert/Ness formations. The test sequence consisted of an initial and a cleanup flow/build-up period with down hole shut-in. After the cleanup build-up bottom hole sampling was accomplished with the well flowing on a low rate. Three out of five samples were good. The well was production logged (PLT) during the dual rate main flow period. The test produced 956 - 772 Sm3 oil, 147100 Sm3 gas and 0 m3 water/day through a 19.05 mm choke in the main flow. GOR was 164 - 191 Sm3/Sm3. The oil rate was steadily decreasing while the gas rate was relatively constant. Consequently, the GOR steadily increased during this period. The oil density was 0.844 g/cm3 and the gas gravity was 0.660 (air = 1) with 1.4% CO2 and 1.5 ppm H2S. Flowing BHP was 234.6 bar and flowing BHT was 112.4 deg C. No gas/oil contact was reported from the test.
    After the main build-up with surface shut-in, a minifracture test was performed.

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    TEST1
    2973.20
    2960.20
    21.02.1993 - 12:45
    YES
    DST
    TEST2
    2950.00
    2921.00
    26.02.1993 - 13:25
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2960
    2973
    12.7
    2.0
    2921
    2950
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    20.000
    42.000
    112
    2.0
    8.000
    23.000
    112
    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
    775
    106300
    0.852
    0.665
    137
    2.0
    956
    147100
    0.844
    0.660
    164

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHS PLT
    2915
    2955
    CBL VDL GR CCL
    2600
    3106
    CCL
    2921
    2950
    CCL
    2986
    3108
    GR CCL
    2773
    2828
    GR CCL
    2800
    2870
    GR CCL
    2800
    2870
    LDL CNL GR
    2764
    3282
    PLT
    2915
    2955
    PLT
    2955
    2985

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1000
    1.47
    12.0
    9.0
    WATER BASED
    08.03.1993
    1000
    1.47
    12.0
    9.0
    WATER BASED
    10.03.1993
    1000
    1.47
    12.0
    9.0
    WATER BASED
    09.03.1993
    2727
    1.47
    12.0
    10.0
    WATER BASED
    08.03.1993
    2877
    1.63
    15.0
    14.0
    WATER BASED
    01.03.1993
    2877
    1.63
    15.0
    14.0
    WATER BASED
    01.03.1993
    2877
    1.63
    15.0
    14.0
    WATER BASED
    01.03.1993
    2877
    1.63
    15.0
    14.0
    WATER BASED
    02.03.1993
    2877
    1.63
    15.0
    14.0
    WATER BASED
    03.03.1993
    2894
    1.63
    15.0
    15.0
    WATER BASED
    08.03.1993
    2909
    1.63
    20.0
    15.0
    WATER BASED
    23.02.1993
    2909
    1.63
    15.0
    15.0
    WATER BASED
    23.02.1993
    2909
    1.63
    17.0
    15.0
    WATER BASED
    23.02.1993
    2909
    1.63
    14.0
    14.0
    WATER BASED
    24.02.1993
    2957
    1.63
    15.0
    15.0
    WATER BASED
    24.02.1993
    2957
    1.63
    15.0
    14.0
    WATER BASED
    26.02.1993
    2957
    1.63
    14.0
    14.0
    WATER BASED
    04.03.1993
    2957
    1.63
    14.0
    13.0
    WATER BASED
    08.03.1993
    2957
    1.63
    14.0
    13.0
    WATER BASED
    08.03.1993
    2957
    1.63
    15.0
    14.0
    WATER BASED
    26.02.1993
    3111
    1.63
    19.0
    19.5
    WATER BASED
    18.02.1993
    3111
    1.63
    20.0
    15.0
    WATER BASED
    18.02.1993
    3111
    1.63
    19.0
    17.0
    WATER BASED
    19.02.1993