Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.06.2024 - 01:33
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/9-18

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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.
    30/9-18
    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
    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.
    30/9-18
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 9111- RAD 1313 & KOLONNE 1021
    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.
    809-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.
    29
    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,
    14.03.1995
    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.
    11.04.1995
    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.
    11.04.1997
    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.
    19.12.2007
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    106.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2994.0
    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).
    2994.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    115
    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° 17' 38.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 49' 22.59'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6684333.06
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    490211.40
    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.
    2552
  • Wellbore history

    General
    Well 30/9-18 is located on the Bjørgvin Arch south of the Oseberg Sør Field and North of the 30/9-16 K Oseberg Sør Discovery. This is in the Northern North Sea. The well was drilled to clarify the Oseberg Sør development strategy. The primary objective was to establish the extent of the high-permeability Tarbert reservoir found in well 30/9-16. Secondary objectives were to test the lower Brent Group, the Cook Formation, and the Statfjord Formation.
    Operations and results
    Well 30/9-18 was spudded with the semi-submersible installation Treasure Saga on 14 March 1995 and drilled to TD at 2994 m in the Late Jurassic Drake Formation. The 24" hole was drilled from 193 m MD to 557 m MD. Shallow gas was predicted at 590 m MD. The 18 5/8" casing was set at 547 m MD. As the cement was displaced bubbles from the hole was observed indicating shallow gas. Displaced out the entire cement volume and filled the annulus with 1.3 sg mud. Mixed and pumped gas block cement around. The well was drilled with spud mud down to 557 m and with KCl/polymer mud from 557 m to TD.
    Formation tops in the Tertiary and Jurassic sections came in slightly higher than prognosed. However, they were within the prognosed uncertainty range. The well penetrated the Brent Group reservoir zones and they were water bearing. Very weak oil shows were reported in the interval 2640 to 2780 m in the Heather/Tarbert intervals during drilling. Intra Heather Sandstone and Tarbert Formation combined contained 127 m gross sand (67.5 m net). The Ness Formation was 195 m thick with 54.5 m net sand. The Cook and Statfjord Formations were not drilled. RFT formation pressures gave three distinct and separate water gradients, one covering the Intra Heather sandstone/Tarbert Formation and two separate gradients covering the Ness Fm. The three water gradients indicated that there was possibly no pressure communication between the three zones. No cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 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]
    560.00
    2990.00
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1400.0
    [m]
    DC
    STRAT
    1420.0
    [m]
    DC
    STRAT
    1440.0
    [m]
    DC
    STRAT
    1460.0
    [m]
    DC
    STRAT
    1480.0
    [m]
    DC
    STRAT
    1500.0
    [m]
    DC
    STRAT
    1520.0
    [m]
    DC
    STRAT
    1540.0
    [m]
    DC
    STRAT
    1560.0
    [m]
    DC
    STRAT
    1580.0
    [m]
    DC
    STRAT
    1600.0
    [m]
    DC
    STRAT
    1620.0
    [m]
    DC
    STRAT
    1630.0
    [m]
    DC
    STRAT
    1640.0
    [m]
    DC
    STRAT
    1660.0
    [m]
    DC
    STRAT
    1670.0
    [m]
    DC
    STRAT
    1680.0
    [m]
    DC
    STRAT
    1700.0
    [m]
    DC
    STRAT
    1720.0
    [m]
    DC
    STRAT
    1740.0
    [m]
    DC
    STRAT
    1760.0
    [m]
    DC
    STRAT
    1780.0
    [m]
    DC
    STRAT
    1790.0
    [m]
    DC
    STRAT
    1800.0
    [m]
    DC
    STRAT
    1820.0
    [m]
    DC
    STRAT
    1840.0
    [m]
    DC
    STRAT
    1860.0
    [m]
    DC
    STRAT
    1880.0
    [m]
    DC
    STRAT
    1900.0
    [m]
    DC
    STRAT
    1920.0
    [m]
    DC
    STRAT
    1940.0
    [m]
    DC
    STRAT
    1950.0
    [m]
    DC
    STRAT
    1960.0
    [m]
    DC
    STRAT
    1980.0
    [m]
    DC
    STRAT
    2000.0
    [m]
    DC
    STRAT
    2010.0
    [m]
    DC
    STRAT
    2020.0
    [m]
    DC
    STRAT
    2035.0
    [m]
    DC
    STRAT
    2055.0
    [m]
    DC
    STRAT
    2070.0
    [m]
    DC
    STRAT
    2080.0
    [m]
    DC
    STRAT
    2090.0
    [m]
    DC
    STRAT
    2110.0
    [m]
    DC
    STRAT
    2130.0
    [m]
    DC
    STRAT
    2135.0
    [m]
    DC
    STRAT
    2140.0
    [m]
    DC
    STRAT
    2145.0
    [m]
    DC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2170.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2190.0
    [m]
    DC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2230.0
    [m]
    DC
    STRAT
    2250.0
    [m]
    DC
    STRAT
    2270.0
    [m]
    DC
    STRAT
    2290.0
    [m]
    DC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2320.0
    [m]
    DC
    STRAT
    2330.0
    [m]
    DC
    STRAT
    2340.0
    [m]
    DC
    STRAT
    2350.0
    [m]
    DC
    STRAT
    2360.0
    [m]
    DC
    STRAT
    2370.0
    [m]
    DC
    STRAT
    2390.0
    [m]
    DC
    STRAT
    2410.0
    [m]
    DC
    STRAT
    2430.0
    [m]
    DC
    STRAT
    2450.0
    [m]
    DC
    STRAT
    2470.0
    [m]
    DC
    STRAT
    2490.0
    [m]
    DC
    STRAT
    2500.0
    [m]
    DC
    STRAT
    2510.0
    [m]
    DC
    STRAT
    2520.0
    [m]
    DC
    STRAT
    2530.0
    [m]
    DC
    STRAT
    2540.0
    [m]
    DC
    STRAT
    2545.0
    [m]
    DC
    STRAT
    2550.0
    [m]
    DC
    STRAT
    2559.0
    [m]
    DC
    STRAT
    2570.0
    [m]
    SWC
    STRAT
    2580.0
    [m]
    SWC
    STRAT
    2585.0
    [m]
    SWC
    STRAT
    2590.0
    [m]
    DC
    STRAT
    2596.0
    [m]
    SWC
    STRAT
    2602.0
    [m]
    DC
    STRAT
    2602.0
    [m]
    SWC
    STRAT
    2607.0
    [m]
    SWC
    STRAT
    2610.0
    [m]
    DC
    STRAT
    2614.0
    [m]
    SWC
    STRAT
    2620.0
    [m]
    SWC
    STRAT
    2620.0
    [m]
    DC
    STRAT
    2626.0
    [m]
    SWC
    STRAT
    2634.0
    [m]
    SWC
    STRAT
    2641.0
    [m]
    SWC
    STRAT
    2645.0
    [m]
    SWC
    STRAT
    2650.0
    [m]
    SWC
    STRAT
    2650.0
    [m]
    DC
    STRAT
    2653.0
    [m]
    SWC
    STRAT
    2660.0
    [m]
    DC
    STRAT
    2664.0
    [m]
    SWC
    STRAT
    2670.0
    [m]
    DC
    STRAT
    2675.0
    [m]
    DC
    STRAT
    2677.0
    [m]
    DC
    STRAT
    2681.0
    [m]
    SWC
    STRAT
    2685.0
    [m]
    DC
    STRAT
    2686.0
    [m]
    SWC
    STRAT
    2690.0
    [m]
    DC
    STRAT
    2700.0
    [m]
    DC
    STRAT
    2710.0
    [m]
    DC
    STRAT
    2720.0
    [m]
    DC
    STRAT
    2730.0
    [m]
    DC
    STRAT
    2740.0
    [m]
    DC
    STRAT
    2751.0
    [m]
    SWC
    STRAT
    2759.0
    [m]
    SWC
    STRAT
    2763.0
    [m]
    SWC
    STRAT
    2774.0
    [m]
    SWC
    STRAT
    2796.0
    [m]
    SWC
    STRAT
    2815.0
    [m]
    SWC
    STRAT
    2828.0
    [m]
    SWC
    STRAT
    2841.0
    [m]
    SWC
    STRAT
    2876.0
    [m]
    SWC
    STRAT
    2899.0
    [m]
    SWC
    STRAT
    2920.0
    [m]
    SWC
    STRAT
    2925.0
    [m]
    SWC
    STRAT
    2933.0
    [m]
    SWC
    STRAT
    2945.0
    [m]
    SWC
    STRAT
    2949.0
    [m]
    SWC
    STRAT
    2950.0
    [m]
    SWC
    STRAT
    2954.0
    [m]
    SWC
    STRAT
    2959.0
    [m]
    SWC
    STRAT
    2965.0
    [m]
    SWC
    STRAT
    2970.0
    [m]
    DC
    STRAT
    2980.0
    [m]
    DC
    STRAT
    2990.0
    [m]
    DC
    STRAT
  • 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
    4.23
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT DLL LSS LDL MSFL GR AMS SP
    525
    2550
    CST GR
    2570
    2965
    DLL LSS MSFL GR SP AMS
    2558
    2990
    LDL CNL FMS GR AMS
    2558
    2981
    MWD RGD - GR RES DIR
    132
    2556
    RFT HP GR AMS
    2624
    2873
    VSP
    290
    2990
  • 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
    193.0
    36
    193.0
    0.00
    LOT
    SURF.COND.
    18 5/8
    547.0
    24
    557.0
    0.00
    LOT
    INTERM.
    9 5/8
    1538.0
    12 1/4
    1550.0
    0.00
    LOT
    LINER
    7
    2557.0
    8 1/2
    2559.0
    0.00
    LOT
    OPEN HOLE
    2994.0
    6
    2994.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    194
    1.05
    WATER BASED
    16.03.1995
    350
    1.15
    19.0
    11.0
    WATER BASED
    18.04.1995
    557
    1.05
    WATER BASED
    17.03.1995
    557
    1.05
    WATER BASED
    20.03.1995
    557
    1.05
    WATER BASED
    20.03.1995
    557
    1.20
    WATER BASED
    20.03.1995
    773
    1.20
    22.0
    10.0
    WATER BASED
    21.03.1995
    1342
    1.20
    17.0
    10.5
    WATER BASED
    23.03.1995
    1550
    1.25
    19.0
    11.0
    WATER BASED
    24.03.1995
    1550
    1.25
    22.0
    14.0
    WATER BASED
    28.03.1995
    1550
    1.25
    22.0
    13.0
    WATER BASED
    23.03.1995
    2070
    1.43
    26.0
    13.5
    WATER BASED
    28.03.1995
    2122
    1.43
    30.0
    14.0
    WATER BASED
    28.03.1995
    2350
    1.15
    18.0
    10.5
    WATER BASED
    18.04.1995
    2420
    1.43
    28.0
    15.0
    WATER BASED
    29.03.1995
    2420
    1.43
    27.0
    13.5
    WATER BASED
    28.03.1995
    2459
    1.43
    27.0
    12.5
    WATER BASED
    30.03.1995
    2559
    1.43
    29.0
    13.0
    WATER BASED
    31.03.1995
    2559
    1.43
    29.0
    13.0
    WATER BASED
    03.04.1995
    2564
    1.15
    9.0
    8.5
    WATER BASED
    03.04.1995
    2651
    1.15
    149.0
    9.0
    WATER BASED
    03.04.1995
    2723
    1.15
    14.0
    8.5
    WATER BASED
    04.04.1995
    2858
    1.15
    18.0
    11.0
    WATER BASED
    05.04.1995
    2947
    1.15
    18.0
    11.5
    WATER BASED
    07.04.1995
    2994
    1.15
    18.0
    11.0
    WATER BASED
    07.04.1995
    2994
    1.15
    18.0
    11.0
    WATER BASED
    18.04.1995
  • 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
    0.23