Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
21.11.2024 - 01:28
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/9-15

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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.
    30/9-15
    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
    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.
    30/9-15
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8502R- ROW 585 & COLUMN 1481
    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.
    773-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.
    30
    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,
    07.12.1993
    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.
    05.01.1994
    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.
    05.01.1996
    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.
    28.05.2003
    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.
    OIL
    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.
    YES
    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.
    NESS FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    105.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2764.0
    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).
    2763.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.61
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 22' 18.63'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 55' 24.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6692983.26
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    495783.84
    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.
    2223

  • Wellbore history
    General
    Well 30/9-15 is located in the Eastern part of Block 30/9 on the Oseberg Sør Field. The primary objectives of the well were to test the hydrocarbon potential of the Brent Group, Cook, and the Statfjord Formations on the J-north compartment with respect to commercial volumes and future relinquishment decisions. It was not possible to locate a vertical well on the J-north compartment which could test all three reservoir levels in an optimal position. Priority was therefore given to the Brent reservoir, and the well location was chosen in order to prove hydrocarbons in the Brent Group, leaving a minimum of untested hydrocarbon potential in the lower Ness reservoir up dip of the well. Secondary objectives were to penetrate the Cook and Statfjord Formations shallower than the water up to (WUT) top Statfjord in well 30/9-5 (2564 m MSL).
    Operations and results
    Wildcat well 30/9-15 was spudded with the semisubmersible installation "West Vanguard" on 7 December 1993 and was drilled to a& total depth of 2764 m in the Early Jurassic Statfjord Formation. The well was drilled with sea water and hi-vis pills down to top of 12 1/4" section at 936 m, and with ANCO 2000 mud with glycols from 936 to TD. The Brent Group was encountered at 2249 m and was proven to be oil bearing in the lower Ness Formation, with an ODT at 2348.5 m. The ORE (Oseberg/Rannoch/Etive) Formations contained residual oil. The Cook Formation was proven water bearing though moderate to weak shows were recorded from sidewall cores taken over the interval 2465.5 - 2475.5 m. The Statfjord Formation was proven water bearing. Three conventional cores were recovered from the intervals 2240 m to 2250 m (Hardråde, Åsgard, and Ness Formations), 2256m to 2281 m (Ness, ORE, and Drake Formations), and 2283 m to 2306 m (Drake Formation). A wire line MDT sample of acceptable quality was recovered from 2249.9 m in the oil zone in the Ness Formation. The well was plugged back and permanently abandoned as an oil discovery on 5 January 1994.
    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]
    949.45
    2764.00

  • 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
    2240.0
    2249.6
    [m ]
    2
    2256.0
    2280.6
    [m ]
    3
    2283.5
    2305.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    56.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2240-2245m
    Core photo at depth: 2245-2249m
    Core photo at depth: 2256-2261m
    Core photo at depth: 2261-2266m
    Core photo at depth: 2266-2271m
    2240-2245m
    2245-2249m
    2256-2261m
    2261-2266m
    2266-2271m
    Core photo at depth: 2271-2276m
    Core photo at depth: 2276-2280m
    Core photo at depth: 2283-2288m
    Core photo at depth: 2288-2293m
    Core photo at depth: 2293-2298m
    2271-2276m
    2276-2280m
    2283-2288m
    2288-2293m
    2293-2298m
    Core photo at depth: 2298-2303m
    Core photo at depth: 2303-2305m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2298-2303m
    2303-2305m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    949.4
    [m]
    DC
    STRAT
    959.4
    [m]
    DC
    STRAT
    969.4
    [m]
    DC
    STRAT
    979.4
    [m]
    DC
    STRAT
    989.4
    [m]
    DC
    STRAT
    999.4
    [m]
    DC
    STRAT
    1009.4
    [m]
    DC
    STRAT
    1039.4
    [m]
    DC
    STRAT
    1069.4
    [m]
    DC
    STRAT
    1099.4
    [m]
    DC
    STRAT
    1129.4
    [m]
    DC
    STRAT
    1159.4
    [m]
    DC
    STRAT
    1189.4
    [m]
    DC
    STRAT
    1219.4
    [m]
    DC
    STRAT
    1249.4
    [m]
    DC
    STRAT
    1279.4
    [m]
    DC
    STRAT
    1309.4
    [m]
    DC
    STRAT
    1339.4
    [m]
    DC
    STRAT
    1369.4
    [m]
    DC
    STRAT
    1399.4
    [m]
    DC
    STRAT
    1429.4
    [m]
    DC
    STRAT
    1459.4
    [m]
    DC
    STRAT
    1489.4
    [m]
    DC
    STRAT
    1519.4
    [m]
    DC
    STRAT
    1550.0
    [m]
    DC
    STRAT
    1560.0
    [m]
    DC
    STRAT
    1570.0
    [m]
    DC
    STRAT
    1580.0
    [m]
    DC
    STRAT
    1590.0
    [m]
    DC
    STRAT
    1600.0
    [m]
    DC
    STRAT
    1610.0
    [m]
    DC
    STRAT
    1640.0
    [m]
    DC
    STRAT
    1660.0
    [m]
    DC
    STRAT
    1670.0
    [m]
    DC
    STRAT
    1680.0
    [m]
    DC
    STRAT
    1690.0
    [m]
    DC
    STRAT
    1700.0
    [m]
    DC
    STRAT
    1730.0
    [m]
    DC
    STRAT
    1740.0
    [m]
    DC
    STRAT
    1750.0
    [m]
    DC
    STRAT
    1760.0
    [m]
    DC
    STRAT
    1790.0
    [m]
    DC
    STRAT
    1820.0
    [m]
    DC
    STRAT
    1830.0
    [m]
    DC
    STRAT
    1840.0
    [m]
    DC
    STRAT
    1850.0
    [m]
    DC
    STRAT
    1860.0
    [m]
    DC
    STRAT
    1870.0
    [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
    1940.0
    [m]
    DC
    STRAT
    1950.0
    [m]
    DC
    STRAT
    1960.0
    [m]
    DC
    STRAT
    1965.0
    [m]
    DC
    STRAT
    1970.0
    [m]
    DC
    STRAT
    1980.0
    [m]
    DC
    STRAT
    1985.0
    [m]
    DC
    STRAT
    1990.0
    [m]
    DC
    STRAT
    1995.0
    [m]
    DC
    STRAT
    2000.0
    [m]
    DC
    STRAT
    2010.0
    [m]
    DC
    STRAT
    2015.0
    [m]
    DC
    STRAT
    2020.0
    [m]
    DC
    STRAT
    2030.0
    [m]
    DC
    STRAT
    2040.0
    [m]
    DC
    STRAT
    2050.0
    [m]
    DC
    STRAT
    2055.0
    [m]
    DC
    STRAT
    2060.0
    [m]
    DC
    STRAT
    2070.0
    [m]
    DC
    STRAT
    2080.0
    [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
    2155.0
    [m]
    DC
    STRAT
    2160.0
    [m]
    DC
    STRAT
    2170.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2185.0
    [m]
    DC
    STRAT
    2190.0
    [m]
    DC
    STRAT
    2195.0
    [m]
    DC
    STRAT
    2202.0
    [m]
    DC
    STRAT
    2215.0
    [m]
    DC
    STRAT
    2220.0
    [m]
    DC
    STRAT
    2230.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2312.0
    [m]
    DC
    STRAT
    2320.0
    [m]
    DC
    STRAT
    2335.0
    [m]
    DC
    STRAT
    2340.0
    [m]
    DC
    STRAT
    2345.0
    [m]
    DC
    STRAT
    2350.0
    [m]
    DC
    STRAT
    2365.0
    [m]
    DC
    STRAT
    2370.0
    [m]
    DC
    STRAT
    2375.0
    [m]
    DC
    STRAT
    2380.0
    [m]
    DC
    STRAT
    2395.0
    [m]
    DC
    STRAT
    2410.0
    [m]
    DC
    STRAT
    2415.0
    [m]
    DC
    STRAT
    2425.0
    [m]
    DC
    STRAT
    2440.0
    [m]
    DC
    STRAT
    2457.0
    [m]
    DC
    STRAT
    2460.0
    [m]
    DC
    STRAT
    2465.0
    [m]
    DC
    STRAT
    2470.0
    [m]
    DC
    STRAT
    2485.0
    [m]
    DC
    STRAT
    2500.0
    [m]
    DC
    STRAT
    2515.0
    [m]
    DC
    STRAT
    2530.0
    [m]
    DC
    STRAT
    2545.0
    [m]
    DC
    STRAT
    2560.0
    [m]
    DC
    STRAT
    2575.0
    [m]
    DC
    STRAT
    2590.0
    [m]
    DC
    STRAT
    2600.0
    [m]
    DC
    STRAT
    2605.0
    [m]
    DC
    STRAT
    2620.0
    [m]
    DC
    STRAT
    2632.0
    [m]
    DC
    STRAT
    2650.0
    [m]
    DC
    STRAT
    2665.0
    [m]
    DC
    STRAT
    2682.0
    [m]
    DC
    STRAT
    2695.0
    [m]
    DC
    STRAT
    2710.0
    [m]
    DC
    STRAT
    2725.0
    [m]
    DC
    STRAT
    2740.0
    [m]
    DC
    STRAT
    2757.0
    [m]
    DC
    STRAT
    2764.0
    [m]
    DC
    STRAT

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.47

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.46
    pdf
    1.89
    pdf
    1.88
    pdf
    1.94
    pdf
    1.38
    pdf
    1.23

  • 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
    10.08

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    2248
    2688
    DIL SDT/LSS SP GR
    217
    934
    DLL LDL CNL SDL SP AMS GR
    927
    2187
    DLL MSFL LDL CNL NGT AMS
    2201
    2326
    DLL MSFL SDL SP AMS GR
    2201
    2760
    LDL CNL FMS AMS GR
    2201
    2755
    MDT AMS
    2249
    2263
    MDT AMS GR
    2221
    2738
    MWD RGD - YGR RES DIR
    127
    2764
    VSP
    980
    2752

  • 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
    217.0
    36
    218.0
    0.00
    LOT
    INTERM.
    13 5/8
    929.0
    17 1/2
    936.0
    0.00
    LOT
    INTERM.
    9 5/8
    2201.0
    12 1/4
    2215.0
    0.00
    LOT
    OPEN HOLE
    2764.0
    8 1/2
    2764.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    128
    1.03
    WATER BASED
    218
    1.20
    WATER BASED
    245
    1.05
    WATER BASED
    623
    1.03
    WATER BASED
    900
    1.45
    28.0
    WATER BASED
    936
    1.39
    36.0
    WATER BASED
    1143
    1.39
    36.0
    WATER BASED
    1905
    1.45
    34.0
    WATER BASED
    2171
    1.45
    27.0
    WATER BASED
    2215
    1.45
    27.0
    WATER BASED
    2240
    1.20
    19.0
    WATER BASED
    2280
    1.20
    19.0
    WATER BASED
    2283
    1.20
    18.0
    WATER BASED
    2306
    1.20
    15.0
    WATER BASED
    2330
    1.20
    20.0
    WATER BASED
    2448
    1.20
    15.0
    WATER BASED
    2714
    1.20
    20.0
    WATER BASED
    2764
    1.20
    20.0
    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
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