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

30/9-11

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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.
    30/9-11
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    30/9-11
    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.
    652-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.
    24
    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,
    27.10.1990
    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.
    19.11.1990
    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.
    19.11.1992
    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.
    06.01.2014
    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.
    WILDCAT
    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.
    DRY
    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.
    25.0
    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).
    2570.0
    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).
    2568.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    98
    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° 19' 27.89'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 55' 44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6687700.50
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    496072.29
    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.
    1673

  • Wellbore history
    General
    Well 30/9-11was drilled on the eastern segment of the J-structure on the Oseberg Sør field in the North Sea. Neighbouring wells 30/9-9 on the J-West and 30/9-5 S on the J-Central proved oil and gas, respectively. The primary objective of well 30/9-11 was to prove reservoir sands and oil within the Brent Group of the J-East segment and define oil/water contacts for the Tarbert/Ness and Oseberg-Rannoch-Etive reservoirs. The well was planned to be drilled 50 m into the Dunlin Formation to a total depth of approximately 2540 m.
    Operations and results
    Wildcat well 30/9-11 was spudded with the semi-submersible installation Vildkat on 27 October 1990 and drilled to TD at 2570 m in the Early Jurassic Drake Formation. No significant problem was encountered in the operations. The well was drilled with spud mud down to 922 m and with KCl/polymer mud from 922 m to TD.
    Top Viking Group, Heather Formation was encountered at 2291 m. Top Brent Group, Tarbert Formation was encountered at 2384 m. The Brent Group was entirely water bearing. Poor, patchy shows on thin sandstone lamina in the Heather Formation were the only indications of hydrocarbons in the well.
    Four cores were cut with good recovery. Core 1 was cut from 2382 m to 2403 m in the Tarbert and Ness formations, cores 2 and 3 were cut from 2450 to 2464.5 m in the Ness Formation, and core 4 was cut from 2484 m to 2511 m in the Ness and Rannoch formations. RFT water samples were taken at 2493 m in the Ness Formation.
    The well was plugged back for sidetracking on 19 November 1990. It is classified as a dry well.
    Testing
    No drill stem test was performed.

  • 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]
    930.00
    2570.00

  • 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
    2382.0
    2402.0
    [m ]
    2
    2450.0
    2454.0
    [m ]
    3
    2455.0
    2464.0
    [m ]
    4
    2484.0
    2511.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    60.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2382-2387m
    Core photo at depth: 2387-2392m
    Core photo at depth: 2392-2397m
    Core photo at depth: 2397-2402m
    Core photo at depth: 2450-2454m
    2382-2387m
    2387-2392m
    2392-2397m
    2397-2402m
    2450-2454m
    Core photo at depth: 2455-2460m
    Core photo at depth: 2460-2465m
    Core photo at depth: 2484-2489m
    Core photo at depth: 2489-2494m
    Core photo at depth: 2494-2499m
    2455-2460m
    2460-2465m
    2484-2489m
    2489-2494m
    2494-2499m
    Core photo at depth: 2499-2504m
    Core photo at depth: 2504-2509m
    Core photo at depth: 2509-2511m
    Core photo at depth:  
    Core photo at depth:  
    2499-2504m
    2504-2509m
    2509-2511m

  • 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
    243.0
    36
    245.0
    0.00
    LOT
    INTERM.
    13 3/8
    906.0
    17 1/2
    922.0
    1.56
    LOT
    INTERM.
    9 5/8
    2242.0
    12 1/4
    2260.0
    1.58
    LOT
    OPEN HOLE
    2570.0
    8 1/2
    2570.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    1000
    2242
    CST GR
    2244
    2530
    DIL LSS SP GR AMS
    905
    2247
    DIL LSS SP GR AMS
    2242
    2565
    FMS4 NGT AMS
    2243
    2562
    LDL CNL GR
    905
    2247
    LDL CNL GR
    2242
    2565
    MWD - GR RES DIR
    0
    0
    RFTB GR
    2275
    2504
    VSP
    1000
    2560

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.96

  • 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
    2.13
    pdf
    29.77

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    245
    1.05
    WATER BASED
    31.10.1990
    758
    1.05
    WATER BASED
    01.11.1990
    922
    1.05
    WATER BASED
    02.11.1990
    922
    1.20
    22.0
    8.0
    WATER BASED
    05.11.1990
    1041
    1.42
    14.0
    7.0
    WATER BASED
    19.11.1990
    1164
    1.20
    23.0
    10.0
    WATER BASED
    05.11.1990
    1417
    1.30
    16.0
    8.0
    WATER BASED
    05.11.1990
    1918
    1.40
    18.0
    9.0
    WATER BASED
    06.11.1990
    2140
    1.24
    15.0
    6.0
    WATER BASED
    19.11.1990
    2224
    1.40
    18.0
    9.0
    WATER BASED
    08.11.1990
    2260
    1.40
    21.0
    9.0
    WATER BASED
    08.11.1990
    2260
    1.40
    19.0
    8.0
    WATER BASED
    09.11.1990
    2260
    1.40
    19.0
    8.0
    WATER BASED
    13.11.1990
    2351
    1.40
    13.0
    6.0
    WATER BASED
    13.11.1990
    2403
    1.22
    14.0
    7.0
    WATER BASED
    13.11.1990
    2455
    1.60
    16.0
    6.0
    WATER BASED
    13.11.1990
    2465
    1.60
    16.0
    7.0
    WATER BASED
    14.11.1990
    2511
    1.22
    15.0
    7.0
    WATER BASED
    16.11.1990
    2570
    1.23
    15.0
    7.0
    WATER BASED
    16.11.1990
    2570
    1.23
    15.0
    6.0
    WATER BASED
    19.11.1990

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    930.0
    [m]
    DC
    STRAT
    950.0
    [m]
    DC
    STRAT
    960.0
    [m]
    DC
    STRAT
    980.0
    [m]
    DC
    STRAT
    990.0
    [m]
    DC
    STRAT
    1010.0
    [m]
    DC
    STRAT
    1020.0
    [m]
    DC
    STRAT
    1040.0
    [m]
    DC
    STRAT
    1050.0
    [m]
    DC
    STRAT
    1080.0
    [m]
    DC
    STRAT
    1100.0
    [m]
    DC
    STRAT
    1110.0
    [m]
    DC
    STRAT
    1130.0
    [m]
    DC
    STRAT
    1140.0
    [m]
    DC
    STRAT
    1160.0
    [m]
    DC
    STRAT
    1170.0
    [m]
    DC
    STRAT
    1190.0
    [m]
    DC
    STRAT
    1200.0
    [m]
    DC
    STRAT
    1230.0
    [m]
    DC
    STRAT
    1250.0
    [m]
    DC
    STRAT
    1260.0
    [m]
    DC
    STRAT
    1280.0
    [m]
    DC
    STRAT
    1290.0
    [m]
    DC
    STRAT
    1310.0
    [m]
    DC
    STRAT
    1320.0
    [m]
    DC
    STRAT
    1340.0
    [m]
    DC
    STRAT
    1350.0
    [m]
    DC
    STRAT
    1380.0
    [m]
    DC
    STRAT
    1400.0
    [m]
    DC
    STRAT
    1410.0
    [m]
    DC
    STRAT
    1430.0
    [m]
    DC
    STRAT
    1440.0
    [m]
    DC
    STRAT
    1460.0
    [m]
    DC
    STRAT
    1490.0
    [m]
    DC
    STRAT
    1510.0
    [m]
    DC
    STRAT
    1540.0
    [m]
    DC
    STRAT
    1550.0
    [m]
    DC
    STRAT
    1570.0
    [m]
    DC
    STRAT
    1580.0
    [m]
    DC
    STRAT
    1600.0
    [m]
    DC
    STRAT
    1610.0
    [m]
    DC
    STRAT
    1630.0
    [m]
    DC
    STRAT
    1640.0
    [m]
    DC
    STRAT
    1660.0
    [m]
    DC
    STRAT
    1690.0
    [m]
    DC
    STRAT
    1700.0
    [m]
    DC
    STRAT
    1720.0
    [m]
    DC
    STRAT
    1730.0
    [m]
    DC
    STRAT
    1740.0
    [m]
    DC
    STRAT
    1760.0
    [m]
    DC
    STRAT
    1770.0
    [m]
    DC
    STRAT
    1790.0
    [m]
    DC
    STRAT
    1800.0
    [m]
    DC
    STRAT
    1830.0
    [m]
    DC
    STRAT
    1850.0
    [m]
    DC
    STRAT
    1860.0
    [m]
    DC
    STRAT
    1880.0
    [m]
    DC
    STRAT
    1890.0
    [m]
    DC
    STRAT
    1900.0
    [m]
    DC
    STRAT
    1910.0
    [m]
    DC
    STRAT
    1920.0
    [m]
    DC
    STRAT
    1930.0
    [m]
    DC
    STRAT
    1950.0
    [m]
    DC
    STRAT
    1960.0
    [m]
    DC
    STRAT
    1970.0
    [m]
    DC
    STRAT
    1980.0
    [m]
    DC
    STRAT
    1990.0
    [m]
    DC
    STRAT
    2000.0
    [m]
    DC
    STRAT
    2010.0
    [m]
    DC
    STRAT
    2020.0
    [m]
    DC
    STRAT
    2040.0
    [m]
    DC
    STRAT
    2055.0
    [m]
    DC
    STRAT
    2065.0
    [m]
    DC
    STRAT
    2086.0
    [m]
    DC
    STRAT
    2090.0
    [m]
    DC
    STRAT
    2100.0
    [m]
    DC
    STRAT
    2110.0
    [m]
    DC
    STRAT
    2120.0
    [m]
    DC
    STRAT
    2130.0
    [m]
    DC
    STRAT
    2140.0
    [m]
    DC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2160.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2200.0
    [m]
    DC
    STRAT
    2220.0
    [m]
    DC
    STRAT
    2230.0
    [m]
    DC
    HYDRO
    2240.0
    [m]
    DC
    STRAT
    2254.0
    [m]
    SWC
    HYDRO
    2260.0
    [m]
    DC
    HYDRO
    2277.0
    [m]
    SWC
    HYDRO
    2282.0
    [m]
    DC
    HYDRO
    2290.0
    [m]
    SWC
    HYDRO
    2297.6
    [m]
    SWC
    HYDRO
    2300.0
    [m]
    DC
    HYDRO
    2308.8
    [m]
    SWC
    HYDRO
    2316.6
    [m]
    SWC
    HYDRO
    2326.1
    [m]
    SWC
    HYDRO
    2334.0
    [m]
    SWC
    HYDRO
    2339.8
    [m]
    SWC
    HYDRO
    2346.0
    [m]
    SWC
    HYDRO
    2351.0
    [m]
    SWC
    HYDRO
    2358.0
    [m]
    SWC
    HYDRO
    2360.4
    [m]
    SWC
    HYDRO
    2365.5
    [m]
    SWC
    HYDRO
    2368.5
    [m]
    SWC
    HYDRO
    2370.8
    [m]
    SWC
    HYDRO
    2371.4
    [m]
    SWC
    HYDRO
    2378.1
    [m]
    SWC
    HYDRO
    2380.4
    [m]
    SWC
    HYDRO
    2382.0
    [m]
    DC
    HYDRO
    2382.1
    [m]
    C
    HYDRO
    2384.9
    [m]
    C
    HYDRO
    2387.2
    [m]
    C
    HYDRO
    2388.4
    [m]
    C
    HYDRO
    2390.0
    [m]
    C
    HYDRO
    2392.9
    [m]
    C
    HYDRO
    2397.5
    [m]
    C
    HYDRO
    2401.8
    [m]
    C
    HYDRO
    2416.0
    [m]
    SWC
    HYDRO
    2428.3
    [m]
    SWC
    HYDRO
    2450.7
    [m]
    C
    HYDRO
    2452.7
    [m]
    C
    HYDRO
    2457.9
    [m]
    C
    HYDRO
    2459.0
    [m]
    C
    HYDRO
    2461.5
    [m]
    C
    HYDRO
    2464.2
    [m]
    C
    HYDRO
    2468.5
    [m]
    SWC
    HYDRO
    2476.9
    [m]
    SWC
    HYDRO
    2480.0
    [m]
    DC
    HYDRO
    2499.1
    [m]
    C
    HYDRO
    2501.7
    [m]
    C
    HYDRO
    2504.6
    [m]
    C
    HYDRO
    2505.1
    [m]
    C
    HYDRO
    2506.0
    [m]
    C
    HYDRO
    2507.8
    [m]
    C
    HYDRO
    2509.0
    [m]
    C
    HYDRO
    2510.3
    [m]
    C
    HYDRO
    2512.5
    [m]
    SWC
    HYDRO
    2515.3
    [m]
    SWC
    HYDRO
    2520.0
    [m]
    SWC
    HYDRO
    2530.0
    [m]
    DC
    STRAT
    2540.0
    [m]
    DC
    STRAT
    2557.0
    [m]
    DC
    STRAT
    2567.0
    [m]
    DC
    STRAT
    2570.0
    [m]
    DC
    HYDRO
    2694.5
    [m]
    C
    HYDRO