Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/9-8

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/9-8
    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.
    SUSPENDED
    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.
    30/9-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8831 - 105 COL 774
    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.
    615-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.
    5
    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,
    29.07.1989
    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.
    02.08.1989
    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.
    02.08.1991
    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.
    20.06.2011
    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.
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    104.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1060.0
    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).
    1060.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.29
    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.
    MIOCENE
    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.
    HORDALAND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 25' 26.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 47' 58.38'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6698797.68
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    488962.17
    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.
    1421

  • Wellbore history
    General
    Well 30/9-8 was drilled on the Oseberg Omega structure, which is located between the Gamma structure to the east and the B structure to the west, and extends northwards into 079 license area. The main target of the well was sandstones in the Middle Jurassic Brent Group. The primary objectives were to prove the extension of the Omega oil column into license 104, find the fluid contacts, and test communication and reservoir relationship with the Omega North and B prospects. The well was planned to drill approximately 50 m into the Dunlin Group at a final depth of approximately 3182 m RKB.
    Operations and results
    Well 30/9-8 was spudded with the semi-submersible installation Polar Pioneer on 29 July 1989 and drilled to TD at 1060 m in presumed Miocene sediments of the Hordaland Group. The well was drilled using seawater and high viscosity pills with returns to the seabed.
    No cores were cut and no wire line fluid samples were taken.
    After setting of the 13 3/8" casing to 1044 m the well was suspended on 2 August while the rig left for work on another contract (TOGI pull-in operation). The well is classified as dry.
    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]
    1070.00
    3200.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1610.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2105.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2135.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2165.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2195.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2255.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2285.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2315.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2345.0
    [m]
    C
    HYDRO
    2360.0
    [m]
    DC
    RRI
    2375.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2659.0
    [m]
    SWC
    HYDRO
    2665.0
    [m]
    SWC
    HYDRO
    2675.0
    [m]
    SWC
    HYDRO
    2701.0
    [m]
    SWC
    HYDRO
    2708.0
    [m]
    SWC
    HYDRO
    2714.0
    [m]
    SWC
    HYDRO
    2720.0
    [m]
    SWC
    HYDRO
    2722.0
    [m]
    SWC
    HYDRO
    2728.0
    [m]
    SWC
    HYDRO
    2745.0
    [m]
    SWC
    HYDRO
    2754.0
    [m]
    SWC
    HYDRO
    2761.0
    [m]
    SWC
    HYDRO
    2764.0
    [m]
    SWC
    HYDRO
    2765.0
    [m]
    SWC
    HYDRO
    2767.0
    [m]
    SWC
    HYDRO
    2769.0
    [m]
    SWC
    HYDRO
    2771.0
    [m]
    SWC
    HYDRO
    2773.0
    [m]
    SWC
    HYDRO
    2775.0
    [m]
    SWC
    HYDRO
    2780.0
    [m]
    SWC
    HYDRO
    2786.0
    [m]
    SWC
    HYDRO
    2795.0
    [m]
    SWC
    HYDRO
    2798.0
    [m]
    SWC
    HYDRO
    2800.0
    [m]
    C
    HYDRO
    2807.4
    [m]
    C
    HYDRO
    2812.6
    [m]
    C
    HYDRO
    2816.6
    [m]
    C
    HYDRO
    2819.7
    [m]
    C
    HYDRO
    2825.8
    [m]
    C
    HYDRO
    2828.0
    [m]
    C
    RRI
    2832.7
    [m]
    C
    HYDRO
    2838.1
    [m]
    C
    HYDRO
    2841.7
    [m]
    C
    HYDRO
    2850.0
    [m]
    C
    HYDRO
    2857.6
    [m]
    C
    HYDRO
    2863.5
    [m]
    C
    HYDRO
    2872.0
    [m]
    C
    HYDRO
    2880.0
    [m]
    C
    HYDRO
    2883.0
    [m]
    C
    HYDRO
    2889.0
    [m]
    C
    HYDRO
    2893.0
    [m]
    C
    HYDRO
    2895.4
    [m]
    C
    HYDRO
    2898.7
    [m]
    C
    HYDRO
    2901.8
    [m]
    C
    HYDRO
    2910.8
    [m]
    C
    HYDRO
    2913.8
    [m]
    C
    HYDRO
    2916.9
    [m]
    C
    HYDRO
    2919.4
    [m]
    C
    HYDRO
    2921.5
    [m]
    C
    HYDRO
    2923.5
    [m]
    C
    HYDRO
    2925.8
    [m]
    C
    HYDRO
    2928.5
    [m]
    C
    HYDRO
    2930.0
    [m]
    C
    HYDRO
    2933.1
    [m]
    C
    HYDRO
    2943.0
    [m]
    SWC
    HYDRO
    2947.0
    [m]
    SWC
    HYDRO
    2960.0
    [m]
    DC
    RRI
    2970.0
    [m]
    SWC
    HYDRO
    2980.0
    [m]
    DC
    RRI
    2990.0
    [m]
    DC
    RRI
    3001.0
    [m]
    SWC
    HYDRO
    3011.0
    [m]
    SWC
    HYDRO
    3025.0
    [m]
    SWC
    HYDRO
    3035.0
    [m]
    SWC
    HYDRO
    3040.0
    [m]
    DC
    RRI
    3050.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3074.0
    [m]
    SWC
    HYDRO
    3080.0
    [m]
    DC
    RRI
    3090.0
    [m]
    DC
    RRI
    3095.0
    [m]
    SWC
    HYDRO
    3100.0
    [m]
    DC
    RRI
    3112.0
    [m]
    SWC
    HYDRO
    3120.0
    [m]
    DC
    RRI
    3130.0
    [m]
    DC
    RRI
    3137.0
    [m]
    SWC
    HYDRO
    3140.0
    [m]
    SWC
    HYDRO
    3146.0
    [m]
    SWC
    HYDRO
    3160.0
    [m]
    DC
    RRI
    3170.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3190.0
    [m]
    DC
    RRI
    3200.0
    [m]
    DC
    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
    DST2A
    2837.00
    2848.00
    19.09.1989 - 00:00
    YES
    DST
    DST2B
    2825.00
    2848.00
    21.09.1989 - 00:00
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    127
    662
    686
    890

  • 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
    3.34
    pdf
    19.13

  • 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
    215.0
    36
    216.0
    0.00
    LOT
    INTERM.
    13 3/8
    1044.0
    17 1/2
    1060.0
    1.67
    LOT
    INTERM.
    9 5/8
    2651.0
    12 1/4
    2669.0
    1.78
    LOT
    LINER
    7
    3198.0
    8 1/2
    3200.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    127
    1.05
    water based
    216
    1.05
    water based
    1060
    1.05
    water based

  • 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
    0.18