Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/6-10

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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
    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.
    348-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.
    60
    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,
    04.10.1982
    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.
    02.12.1982
    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.
    02.12.1984
    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).
    2656.0
    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).
    2656.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    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.
    92

  • Wellbore history
    General
    Well 30/6-10 was drilled to appraise the hydrocarbon potential in the Alfa structure on the Oseberg Field in the North Sea. The main objective was to define the gas/oil contact and to obtain cores from this zone.
    Operations and results
    Appraisal well 30/6-10 was spudded with the semi-submersible installation Treasure Scout on 4 October 1982 and drilled to TD at 2656 m in the Early Jurassic Drake Formation. Some problems were encountered while running both 20" and 13 3/8" casing. The drill string got stuck at 1992 m and leakages in the BOP stack after installing the 13 3/8" casing also occurred. The well was drilled with seawater and hi-vis pills down to 970 m and with KCl/polymer mud from 970 m to TD. At 1992 m 15 m3 diesel and 15.9 m3 Imco spot was pumped to free the pipe.
    First oil show in the well was recorded at 1980 m in limestone stringers at top Balder Formation level. Poor oil shows were recorded in the intervals 2030 to 2100 m and 2215 m to 2253 m. Good oil shows were recorded on cuttings from marls and limestones in the Shetland Group from 2253 m to 2380 m, then again poor shows were recorded down to top of the Brent Group at 2457 m. The well encountered oil and gas in Middle Jurassic Brent sandstones. The Brent Group was found hydrocarbon bearing over the entire 118 m interval. Net pay was 37.3 m with 23.3 % average porosity and 23.9% average water saturation. The gas/oil contact was found from RFT pressure gradients to be at 2520 m in the Ness Formation, but no oil/water contact was encountered.
    A total of eleven conventional cores were cut from the top of the Ness Formation and down into the Dunlin Group shales. Driller depths through the cored section are 0.0 to 2.5m deeper than logger's depth. The estimated gas/oil contact is captured in core number 6. Segregated RFT samples were taken at 2546.1 m (gas, oil and filtrate), 2555.5 m (gas, oil and filtrate), and 2467.5 m (gas and filtrate).
    The well was plugged back on 2 December 1982 for sidetracking to well 30/6-10 A.
    Testing
    No drill stem test was performed, instead testing was to be done in the 30/6-10 A sidetrack.

  • 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]
    220.00
    2655.00

  • 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
    2461.0
    2475.0
    [m ]
    2
    2475.0
    2488.1
    [m ]
    3
    2493.0
    2502.0
    [m ]
    4
    2503.0
    2509.5
    [m ]
    5
    2510.0
    2517.2
    [m ]
    6
    2517.2
    2528.4
    [m ]
    7
    2530.0
    2548.0
    [m ]
    8
    2548.0
    2551.0
    [m ]
    9
    2553.0
    2554.4
    [m ]
    10
    2554.5
    2572.5
    [m ]
    11
    2572.5
    2590.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    119.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2461-2465m
    Core photo at depth: 2465-2469m
    Core photo at depth: 2469-2473m
    Core photo at depth: 2473-2475m
    Core photo at depth: 2475-2479m
    2461-2465m
    2465-2469m
    2469-2473m
    2473-2475m
    2475-2479m
    Core photo at depth: 2479-2483m
    Core photo at depth: 2483-2487m
    Core photo at depth: 2487-2488m
    Core photo at depth: 2493-2497m
    Core photo at depth: 2497-2501m
    2479-2483m
    2483-2487m
    2487-2488m
    2493-2497m
    2497-2501m
    Core photo at depth: 2501-2502m
    Core photo at depth: 2503-2507m
    Core photo at depth: 2507-2509m
    Core photo at depth: 2510-2514m
    Core photo at depth: 2514-2517m
    2501-2502m
    2503-2507m
    2507-2509m
    2510-2514m
    2514-2517m
    Core photo at depth: 2517-2521m
    Core photo at depth: 2521-2525m
    Core photo at depth: 2525-2528m
    Core photo at depth: 2530-2534m
    Core photo at depth: 2534-2538m
    2517-2521m
    2521-2525m
    2525-2528m
    2530-2534m
    2534-2538m
    Core photo at depth: 2538-2542m
    Core photo at depth: 2542-2546m
    Core photo at depth: 2546-2548m
    Core photo at depth: 2548-2551m
    Core photo at depth: 2553-2554m
    2538-2542m
    2542-2546m
    2546-2548m
    2548-2551m
    2553-2554m
    Core photo at depth: 2554-2558m
    Core photo at depth: 2558-2562m
    Core photo at depth: 2562-2566m
    Core photo at depth: 2566-2570m
    Core photo at depth: 2570-2572m
    2554-2558m
    2558-2562m
    2562-2566m
    2566-2570m
    2570-2572m
    Core photo at depth: 2572-2576m
    Core photo at depth: 2576-2580m
    Core photo at depth: 2580-2584m
    Core photo at depth: 2584-2588m
    Core photo at depth: 2588-2590m
    2572-2576m
    2576-2580m
    2580-2584m
    2584-2588m
    2588-2590m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2385.5
    [m]
    SWC
    RRI
    2396.0
    [m]
    SWC
    RRI
    2398.0
    [m]
    SWC
    RRI
    2402.0
    [m]
    SWC
    RRI
    2406.0
    [m]
    SWC
    RRI
    2410.0
    [m]
    SWC
    RRI
    2413.0
    [m]
    SWC
    RRI
    2415.5
    [m]
    SWC
    RRI
    2417.0
    [m]
    SWC
    RRI
    2419.0
    [m]
    SWC
    RRI
    2420.0
    [m]
    SWC
    RRI
    2434.0
    [m]
    SWC
    RRI
    2445.0
    [m]
    SWC
    RRI
    2454.0
    [m]
    SWC
    RRI
    2465.0
    [m]
    C
    RRI
    2469.9
    [m]
    C
    RRI
    2472.5
    [m]
    C
    RRI
    2473.0
    [m]
    C
    RRI
    2477.3
    [m]
    C
    RRI
    2479.5
    [m]
    C
    RRI
    2480.2
    [m]
    C
    RRI
    2485.3
    [m]
    C
    RRI
    2486.8
    [m]
    C
    RRI
    2606.0
    [m]
    SWC
    RRI
    2627.0
    [m]
    SWC
    RRI
    2638.0
    [m]
    SWC
    RRI
    2647.0
    [m]
    SWC
    RRI
    2655.0
    [m]
    SWC
    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
    RFT2
    2467.50
    0.00
    YES

  • Lithostratigraphy

  • 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
    2.29
    pdf
    21.49

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    1200
    2134
    CST
    1227
    2420
    CST
    2412
    2653
    DLL MSFL
    2370
    2650
    HDT
    1932
    2650
    ISF LSS
    132
    2652
    LDT CNL
    950
    2652
    NGT
    2138
    2652
    RFT
    2458
    2574
    RFT
    2467
    2467
    RFT
    2521
    2522
    VELOCITY
    310
    2654

  • 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
    2138.0
    17 1/2
    2432.0
    1.79
    LOT
    OPEN HOLE
    2656.0
    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
    300
    1.10
    40.0
    waterbased
    1000
    1.20
    40.0
    waterbased
    1520
    1.30
    45.0
    waterbased
    2020
    1.35
    54.0
    waterbased
    2630
    1.36
    53.0
    waterbased

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.22