Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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7223/5-1

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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.
    7223/5-1
    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
    Press release
    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
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    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    BARENTS SEA
    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.
    7223/5-1
    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.
    StatoilHydro Petroleum 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.
    1209-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.
    41
    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,
    05.12.2008
    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.
    14.01.2009
    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.
    03.01.2011
    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.
    03.01.2011
    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.
    APPRAISAL
    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.
    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.
    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.
    TRIASSIC
    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.
    SNADD FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE TRIASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    KOBBE FM
    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.
    340.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2549.0
    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).
    2548.6
    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 TRIASSIC
    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.
    KLAPPMYSS FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 32' 6.18'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    23° 20' 7.74'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8052579.21
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    377307.19
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    35
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5960

  • Wellbore history
    General
    Well 7223/5-1 was drilled on the Bjarmeland Platform, south of the Swaen Graben, east of the Loppa High in the Barents Sea. The primary objective was to prove oil or gas in a new segment of Ladinian channel complex in the Obesum prospect. The location was chosen in order to test several plays and seismic amplitude anomalies in the Triassic Snadd and Kobbe Formations, and to avoid shallow gas anomalies.
    Operations and results
    A 9 7/8" pilot hole was drilled to 607 m to check for shallow gas. Some sands were penetrated, but no signs of shallow gas were seen. Well 7223/5-1 was spudded with the semi-submersible installation Polar Pioneer on 4 December 2008 and drilled to TD at 2549 m in the Early Triassic Klappmyss Formation. A leakage on the BOP control system was discovered while drilling the 12 1/4" section. The BOP and riser was pulled and repaired; this took 75 hrs. Otherwise no significant technical problem occurred. The well was drilled with seawater/CaCl2/Polymer mud down to 602 m and with Glydril WBM from 602 m to TD.
    The Snadd Formation was encountered at 585 m and was 1271 m thick. The underlying Kobbe Formation was encountered at 1856 m and was 595 m thick. Hydrocarbons (gas) were observed in Snadd Formation in fluvial sandstones of Ladinian age and in the Kobbe Formation in sandstones of Anisian age. A lower Snadd Formation reservoir penetrated at 1575 m had 60 m gross sandstone with 17 m net gas bearing reservoir, but gas saturation was probably very low. Several sandstone intervals in the Kobbe Formation contained gas but the reservoirs were of very poor quality. Oil shows in the form of fluorescence were recorded at several levels in the Kobbe Formation.
    Two cores were cut in the intervals 1579-1595 m in the Snadd formation and 1933-1946 m in the Kobbe formation. MSCT (Mechanical Sidewall Coring Tool) cores were also sampled during TD logging. In the Snadd Formation water and gas were sampled. A water sample was collected at 1584.6 m with dual packer after pumping of 242 litre of fluid. The sample had high contamination level of 14 %. At 1578.4 m gas samples were collected both with large diameter probe and dual packer. The drawdown with the probe was 40 - 45 bar, while with the dual packer a drawdown of approximately 0.9 Bar was observed. The water sample at 1590.3 m was collected with the single probe. The formation had poor reservoir properties and just a few litres were pumped. The sample contained mainly mud filtrate with a small fraction of formation water. In the Kobbe Formation gas samples were collected 1919.9 m. Due to poor reservoir properties the samples were collected with the dual packer. During the sampling a drawdown of approximately 18 Bar was observed.
    The well was permanently abandoned on 5 December 2008 as a gas discovery.
    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]
    610.00
    2550.00

  • 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
    1579.0
    1593.2
    [m ]
    2
    1933.0
    1945.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    27.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    412.0
    36
    417.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    587.0
    17 1/2
    602.0
    2.76
    LOT
    INTERM.
    9 5/8
    1109.0
    12 1/4
    1110.0
    2.87
    LOT
    OPEN HOLE
    2549.0
    8 1/2
    2549.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI HNGS HRLA
    1106
    2549
    MDT PRESSURE
    1176
    1634
    MDT SAMPLE
    1919
    1919
    MSCT
    1106
    2549
    MWD LWD - ARCVRES6 GVR6 TELESCOP
    1110
    2549
    MWD LWD - ARCVRES9 POWERPULSE
    417
    1110
    MWD LWD - POWERPULSE
    363
    417
    PEX DSI
    577
    1169
    PEX ECS CMR MSIP
    1106
    2549
    VSP
    366
    2544

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.45

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1110
    1.30
    23.0
    Glydril
    1220
    1.30
    18.0
    Glydril
    1929
    1.30
    17.0
    Glydril
    2549
    1.30
    16.0
    Glydril
    2549
    1.30
    16.0
    Glydril
    2549
    1.29
    18.0
    Glydril

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    610.0
    [m]
    DC
    FUGRO
    620.0
    [m]
    DC
    FUGRO
    640.0
    [m]
    DC
    FUGRO
    650.0
    [m]
    DC
    FUGRO
    670.0
    [m]
    DC
    FUGRO
    680.0
    [m]
    DC
    FUGRO
    700.0
    [m]
    DC
    FUGRO
    710.0
    [m]
    DC
    FUGRO
    730.0
    [m]
    DC
    FUGRO
    740.0
    [m]
    DC
    FUGRO
    760.0
    [m]
    DC
    FUGRO
    770.0
    [m]
    DC
    FUGRO
    790.0
    [m]
    DC
    FUGRO
    800.0
    [m]
    DC
    FUGRO
    820.0
    [m]
    DC
    FUGRO
    830.0
    [m]
    DC
    FUGRO
    850.0
    [m]
    DC
    FUGRO
    860.0
    [m]
    DC
    FUGRO
    880.0
    [m]
    DC
    FUGRO
    910.0
    [m]
    DC
    FUGRO
    920.0
    [m]
    DC
    FUGRO
    940.0
    [m]
    DC
    FUGRO
    950.0
    [m]
    DC
    FUGRO
    970.0
    [m]
    DC
    FUGRO
    980.0
    [m]
    DC
    FUGRO
    1000.0
    [m]
    DC
    FUGRO
    1010.0
    [m]
    DC
    FUGRO
    1030.0
    [m]
    DC
    FUGRO
    1040.0
    [m]
    DC
    FUGRO
    1060.0
    [m]
    DC
    FUGRO
    1070.0
    [m]
    DC
    FUGRO
    1090.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1128.0
    [m]
    DC
    FUGRO
    1137.0
    [m]
    DC
    FUGRO
    1152.0
    [m]
    DC
    FUGRO
    1161.0
    [m]
    DC
    FUGRO
    1173.0
    [m]
    DC
    FUGRO
    1206.0
    [m]
    DC
    FUGRO
    1227.0
    [m]
    DC
    FUGRO
    1236.0
    [m]
    DC
    FUGRO
    1251.0
    [m]
    DC
    FUGRO
    1272.0
    [m]
    DC
    FUGRO
    1296.0
    [m]
    DC
    FUGRO
    1311.0
    [m]
    DC
    FUGRO
    1329.0
    [m]
    DC
    FUGRO
    1353.0
    [m]
    DC
    FUGRO
    1374.0
    [m]
    DC
    FUGRO
    1383.0
    [m]
    DC
    FUGRO
    1401.0
    [m]
    DC
    FUGRO
    1419.0
    [m]
    DC
    FUGRO
    1428.0
    [m]
    DC
    FUGRO
    1443.0
    [m]
    DC
    FUGRO
    1458.0
    [m]
    DC
    FUGRO
    1467.0
    [m]
    DC
    FUGRO
    1485.0
    [m]
    DC
    FUGRO
    1503.0
    [m]
    DC
    FUGRO
    1518.0
    [m]
    DC
    FUGRO
    1536.0
    [m]
    DC
    FUGRO
    1579.9
    [m]
    C
    FUGRO
    1587.7
    [m]
    C
    FUGRO
    1588.8
    [m]
    C
    FUGRO
    1592.3
    [m]
    C
    FUGRO
    1602.0
    [m]
    DC
    FUGRO
    1611.0
    [m]
    DC
    FUGRO
    1620.0
    [m]
    DC
    FUGRO
    1629.0
    [m]
    DC
    FUGRO
    1638.0
    [m]
    DC
    FUGRO
    1647.0
    [m]
    DC
    FUGRO
    1656.0
    [m]
    DC
    FUGRO
    1665.0
    [m]
    DC
    FUGRO
    1674.0
    [m]
    DC
    FUGRO
    1683.0
    [m]
    DC
    FUGRO
    1692.0
    [m]
    DC
    FUGRO
    1701.0
    [m]
    DC
    FUGRO
    1710.0
    [m]
    DC
    FUGRO
    1719.0
    [m]
    DC
    FUGRO
    1728.0
    [m]
    DC
    FUGRO
    1737.0
    [m]
    DC
    FUGRO
    1746.0
    [m]
    DC
    FUGRO
    1755.0
    [m]
    DC
    FUGRO
    1764.0
    [m]
    DC
    FUGRO
    1773.0
    [m]
    DC
    FUGRO
    1782.0
    [m]
    DC
    FUGRO
    1791.0
    [m]
    DC
    FUGRO
    1800.0
    [m]
    DC
    FUGRO
    1809.0
    [m]
    DC
    FUGRO
    1818.0
    [m]
    DC
    FUGRO
    1827.0
    [m]
    DC
    FUGRO
    1836.0
    [m]
    DC
    FUGRO
    1848.0
    [m]
    DC
    FUGRO
    1857.0
    [m]
    DC
    FUGRO
    1866.0
    [m]
    DC
    FUGRO
    1875.0
    [m]
    DC
    FUGRO
    1884.0
    [m]
    DC
    FUGRO
    1893.0
    [m]
    DC
    FUGRO
    1902.0
    [m]
    DC
    FUGRO
    1911.0
    [m]
    DC
    FUGRO
    1920.0
    [m]
    DC
    FUGRO
    1933.4
    [m]
    C
    FUGRO
    1936.5
    [m]
    C
    FUGRO
    1940.3
    [m]
    C
    FUGRO
    1942.5
    [m]
    C
    FUGRO
    1945.4
    [m]
    C
    FUGRO
    1953.0
    [m]
    DC
    FUGRO
    1962.0
    [m]
    DC
    FUGRO
    1971.0
    [m]
    DC
    FUGRO
    1980.0
    [m]
    DC
    FUGRO
    1989.0
    [m]
    DC
    FUGRO
    1998.0
    [m]
    DC
    FUGRO
    2007.0
    [m]
    DC
    FUGRO
    2013.0
    [m]
    DC
    FUGRO
    2022.0
    [m]
    DC
    FUGRO
    2031.0
    [m]
    DC
    FUGRO
    2040.0
    [m]
    DC
    FUGRO
    2049.0
    [m]
    DC
    FUGRO
    2058.0
    [m]
    DC
    FUGRO
    2067.0
    [m]
    DC
    FUGRO
    2073.0
    [m]
    DC
    FUGRO
    2082.0
    [m]
    DC
    FUGRO
    2091.0
    [m]
    DC
    FUGRO
    2100.0
    [m]
    DC
    FUGRO
    2112.0
    [m]
    DC
    FUGRO
    2121.0
    [m]
    DC
    FUGRO
    2130.0
    [m]
    DC
    FUGRO
    2142.0
    [m]
    DC
    FUGRO
    2148.0
    [m]
    DC
    FUGRO
    2160.0
    [m]
    DC
    FUGRO
    2166.0
    [m]
    DC
    FUGRO
    2178.0
    [m]
    DC
    FUGRO
    2184.0
    [m]
    DC
    FUGRO
    2196.0
    [m]
    DC
    FUGRO
    2202.0
    [m]
    DC
    FUGRO
    2214.0
    [m]
    DC
    FUGRO
    2220.0
    [m]
    DC
    FUGRO
    2232.0
    [m]
    DC
    FUGRO
    2238.0
    [m]
    DC
    FUGRO
    2250.0
    [m]
    DC
    FUGRO
    2256.0
    [m]
    DC
    FUGRO
    2268.0
    [m]
    DC
    FUGRO
    2274.0
    [m]
    DC
    FUGRO
    2292.0
    [m]
    DC
    FUGRO
    2298.0
    [m]
    DC
    FUGRO
    2310.0
    [m]
    DC
    FUGRO
    2316.0
    [m]
    DC
    FUGRO
    2316.0
    [m]
    DC
    FUGRO
    2328.0
    [m]
    DC
    FUGRO
    2334.0
    [m]
    DC
    FUGRO
    2352.0
    [m]
    DC
    FUGRO
    2364.0
    [m]
    DC
    FUGRO
    2370.0
    [m]
    DC
    FUGRO
    2382.0
    [m]
    DC
    FUGRO
    2388.0
    [m]
    DC
    FUGRO
    2400.0
    [m]
    DC
    FUGRO
    2406.0
    [m]
    DC
    FUGRO
    2418.0
    [m]
    DC
    FUGRO
    2424.0
    [m]
    DC
    FUGRO
    2436.0
    [m]
    DC
    FUGRO
    2442.0
    [m]
    DC
    FUGRO
    2454.0
    [m]
    DC
    FUGRO
    2460.0
    [m]
    DC
    FUGRO
    2472.0
    [m]
    DC
    FUGRO
    2478.0
    [m]
    DC
    FUGRO
    2490.0
    [m]
    DC
    FUGRO
    2496.0
    [m]
    DC
    FUGRO
    2508.0
    [m]
    DC
    FUGRO
    2514.0
    [m]
    DC
    FUGRO
    2526.0
    [m]
    DC
    FUGRO
    2532.0
    [m]
    DC
    FUGRO
    2544.0
    [m]
    DC
    FUGRO
    2550.0
    [m]
    DC
    FUGRO

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1586.75
    [m ]
    1579.10
    [m ]
    1591.25
    [m ]