Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.07.2024 - 01:26
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30/6-10 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.
    30/6-10 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
    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.
    30/6-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    913 133 SP 615
    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.
    360-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.
    92
    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,
    02.12.1982
    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.
    03.03.1983
    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.
    03.03.1985
    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.
    29.03.2014
    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/GAS
    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.
    109.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2665.0
    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).
    2577.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    39
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    104
    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.
    EARLY 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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 36' 29.53'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 46' 24.74'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6719328.26
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    487600.49
    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.
    56
  • Wellbore history

    General
    Well 30/6-10 A is a sidetrack to appraisal well 30/6-10 on the Alfa structure on the Oseberg Field in the North Sea. The primary well found oil and gas all through the Brent Group with a gas/oil contact at 2520 m, but no oil water contact. The main objective was to further define the gas/oil contact and to perform drill stem tests over the reservoir. The well was planned to penetrate the Brent reservoir approximately 300 m west of the original hole.
    Operations and results
    Appraisal well 30/6-10 A was sidetracked on 2 December 1982 through a milled window in the 13 3/8" casing at 1788 to 1803 m in the primary well bore. The sidetrack was drilled with the semi-submersible installation Treasure Scout to 2665 m (2577 m TVD) in the Early Jurassic Drake Formation. At 2657 m bad weather came up and caused some problems and down time. The pipe got stuck at TD but was worked free after 32.5 hrs using pipe lax, Imco spot and diesel. Otherwise the sidetrack was drilled with KCl/polymer mud from kick-off to TD.
    First oil shows were seen in cuttings from limestone stringers in the Balder Formation at 2015 m. Oil shows on limestone cuttings continued down through the Shetland Group to top Heather Formation at 2448 m. The Brent Group interval from 2480 - 2608.5 m (2429 - 2531 m TVD) was found hydrocarbon bearing over the entire interval with the free gas/oil contact based on RFT pressure gradients at 2594 m (2520 m TVD) in the Ness Formation. No oil/water contact was found. The net pay in the Brent Group was calculated to be 58 m with average porosity of 24.4% and average water saturation of 27%. The net/gross ratio in 30/6-10 A is higher than in 30/6-10 due to a better sand development in the Ness Formation.
    A total of 10 cores were cut from 2467 m in the lower part of the Heather Formation, through the Ness Formation and into the oil zone of the Etive Formation at 2606.5 m. When coring the last core the inner barrel parted in two and part of the core was washed away by the mud. Only 21.6% of this core was recovered, and relating this part to any specific depth proved to be impossible. The part recovered was sandstone with good oil shows. Segregated RFT samples were taken at 2605.5 m (gas, oil and solids), 2596 m (gas, oil and solids), and 2592 m (gas and condensate with traces of oil) .
    The well was permanently abandoned on 3 March 1982 as a gas and oil appraisal well.
    Testing
    Four production tests were performed, three in the gas zone and one in the oil zone.
    DST1 from 2600 to 2602 m (2524.75 m to 2526.25 m TVD) at the base of the Etive Formation tested 563 Sm3/day of oil and 78820 Sm3 gas through a 32/64" choke. Oil gravity was 35.7 deg API and gas gravity was 0.685 (air=l). GOR was 140 Sm3/Sm3. Down hole temperature was 100.7 deg C at gauge depth 2513.5 m TVD.
    DST2 from 2587 to 2590 m (2514 to 2516.5 m TVD) in the middle of the Etive Formation tested 181 Sm3 /day of condensate and 546190 Sm3 /day of gas through a 40/64" choke. Condensate gravity was 58.7 deg API and gas gravity was 0.660 (air = 1). GOR was 3030 Sm3/Sm3. Down hole temperature was 102.2 deg C at gauge depth 2513.7 m TVD.
    DST3 from 2546 to 2555 m (2481 - 2489 m TVD) in the lower Ness Formation tested 170 Sm3 /day) of condensate and 551850 Sm3/day of gas through a 40/64" choke. Condensate gravity was 60.2 deg API and gas gravity was 0.655 (air=1). GOR was 3246 Sm3/Sm3. Down hole temperature was 101 deg C at gauge depth 2471 m TVD.
    DST4 from 2480.5 to 2486.5 m (2430 - 2435 m TVD) in the Upper Ness Formation tested 254 Sm3/day of condensate and 798500 Sm3 /day of gas through a 64/6 4" choke. Condensate gravity was 60.2 API and gas gravity 0.665. GOR was 3143 Sm3/Sm3.
  • 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]
    1800.00
    2665.00
  • 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
    2467.0
    2475.7
    [m ]
    2
    2477.5
    2495.6
    [m ]
    3
    2496.0
    2512.8
    [m ]
    4
    2515.0
    2519.7
    [m ]
    5
    2520.0
    2535.9
    [m ]
    6
    2537.0
    2546.0
    [m ]
    7
    2546.0
    2561.2
    [m ]
    8
    2563.7
    2573.2
    [m ]
    9
    2574.5
    2587.9
    [m ]
    10
    2602.6
    2606.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    115.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2467-2471m
    Core photo at depth: 2471-2475m
    Core photo at depth: 2475-2476m
    Core photo at depth: 2477-2481m
    Core photo at depth: 2481-2485m
    2467-2471m
    2471-2475m
    2475-2476m
    2477-2481m
    2481-2485m
    Core photo at depth: 2485-2489m
    Core photo at depth: 2489-2493m
    Core photo at depth: 2493-2495m
    Core photo at depth: 2496-2500m
    Core photo at depth: 2500-2504m
    2485-2489m
    2489-2493m
    2493-2495m
    2496-2500m
    2500-2504m
    Core photo at depth: 2504-2508m
    Core photo at depth: 2508-2512m
    Core photo at depth: 2512-2513m
    Core photo at depth: 2525-2519m
    Core photo at depth: 2519-2519m
    2504-2508m
    2508-2512m
    2512-2513m
    2525-2519m
    2519-2519m
    Core photo at depth: 2520-2524m
    Core photo at depth: 2524-2528m
    Core photo at depth: 2528-2532m
    Core photo at depth: 2532-2535m
    Core photo at depth: 2537-2541m
    2520-2524m
    2524-2528m
    2528-2532m
    2532-2535m
    2537-2541m
    Core photo at depth: 2541-2545m
    Core photo at depth: 2545-2548m
    Core photo at depth: 2546-2550m
    Core photo at depth: 2550-2554m
    Core photo at depth: 2554-2558m
    2541-2545m
    2545-2548m
    2546-2550m
    2550-2554m
    2554-2558m
    Core photo at depth: 2558-2561m
    Core photo at depth: 2563-2567m
    Core photo at depth: 2567-2571m
    Core photo at depth: 2571-2573m
    Core photo at depth: 2574-2578m
    2558-2561m
    2563-2567m
    2567-2571m
    2571-2573m
    2574-2578m
    Core photo at depth: 2578-2582m
    Core photo at depth: 2582-2586m
    Core photo at depth: 2586-2587m
    Core photo at depth: 2602-2606m
    Core photo at depth:  
    2578-2582m
    2582-2586m
    2586-2587m
    2602-2606m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2469.5
    [m]
    C
    RRI
    2472.4
    [m]
    C
    RRI
    2490.3
    [m]
    C
    RRI
    2496.6
    [m]
    C
    RRI
    2512.8
    [m]
    C
    RRI
    2528.4
    [m]
    C
    RRI
    2541.8
    [m]
    C
    RRI
    2557.7
    [m]
    C
    RRI
    2565.5
    [m]
    C
    RRI
    2582.3
    [m]
    C
    RRI
  • 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
    2600.00
    2602.00
    07.02.1983 - 00:00
    YES
    DST
    DST3
    2446.00
    2555.00
    18.02.1983 - 00:00
    YES
    DST
    DST4
    2480.00
    2487.00
    22.02.1983 - 00:00
    YES
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.44
    pdf
    0.61
    pdf
    11.79
    pdf
    0.52
  • 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
    1.12
    pdf
    21.49
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2600
    2602
    12.7
    2.0
    2587
    2590
    15.8
    3.0
    2446
    2555
    15.8
    4.0
    2480
    2487
    25.4
    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
    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
    563
    79000
    0.850
    0.685
    140
    2.0
    181
    546000
    0.740
    0.660
    3017
    3.0
    170
    552000
    0.740
    0.660
    3246
    4.0
    254
    799000
    0.740
    0.664
    3143
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MSFL
    2340
    2648
    FDC CNL
    1768
    2650
    HDT
    1786
    2654
    ISF SON
    1786
    2654
    NGT
    2330
    2640
    RFT
    2481
    2607
    RFT
    2592
    2592
    RFT
    2605
    2605
  • 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
    219.0
    36
    220.0
    0.00
    LOT
    SURF.COND.
    20
    949.0
    26
    970.0
    1.56
    LOT
    INTERM.
    13 3/8
    1788.0
    17 1/2
    1803.0
    1.59
    LOT
    INTERM.
    13 3/8
    2138.0
    17 1/2
    2432.0
    1.79
    LOT
    INTERM.
    9 5/8
    2652.0
    12 1/4
    2656.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2020
    1.35
    54.0
    waterbased
    2630
    1.36
    53.0
    waterbased
    2650
    1.32
    55.0
    waterbased