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

24/9-9 S

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.
    24/9-9 S
    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
    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.
    24/9-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    MN DG 043 & 032A
    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.
    Marathon Petroleum Norge 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.
    1277-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.
    26
    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,
    12.09.2009
    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.
    07.10.2009
    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.
    07.10.2011
    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.
    07.10.2011
    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.
    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.
    PALEOCENE
    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.
    HERMOD FM
    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.
    120.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2402.0
    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).
    2226.7
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    37.6
    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.
    PALEOCENE
    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.
    HEIMDAL FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 19' 40.49'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 50' 17.27'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6577295.29
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    433882.57
    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.
    6222

  • Wellbore history
    General
    Well 24/9-9 S is located in the Vana Sub-basin ca 6 km east of the UK border in the North Sea. The primary objective of the well was to establish the presence of hydrocarbons within the Hermod Formation of the Marihøne A prospect. Given success, an optional sidetrack (24/9-9 A) would be drilled to test the A2 segment of the same Hermod Formation. The surface location was placed so as to enable both segments to be tested from the same wellhead location. Further unplanned sidetracks would be contingent on results of the first wells.
    Operations and results
    Wildcat well 24/9-9 S was spudded with the semi-submersible installation Songa Dee on 12 September 2009 and drilled to TD at 2402 m in the Paleocoene Heimdal Formation. No significant technical problem occurred in the operations. The well was drilled with seawater and hi-vis sweeps down to 144 m, with Glydril mud from 144 m to 1033m, and with Versatec oil based mud from 1033 m to TD.
    The target Hermod Formation was encountered at 2202 m (2041.8 m TVD MSL) and proved to be oil bearing. Logging showed a 29.1 m TVD oil leg with OWC at 2238.5m (2070.9m TVD MSL). Average porosity of the oil bearing zone was 27% with an average Sw of 25%. The gross thickness of the reservoir was 52.5 m TVD. The Heimdal Formation sands were water bearing. The only true oil shows recorded were on the cores taken in the reservoir. These extended through the oil-bearing zone and down to the end of the cored interval at 2261 m. The oil based mud used produced a background weak dull yellow direct fluorescence and faint cut fluorescence, which effectively masked any mineral oil show. Additionally the solvent properties of the mud, combined with the structure destroying effect of the PDC bits and the flushing effect due to the overbalanced mud weight may have removed virtually all trace of shows from disaggregated sand grains and minimised or removed shows from sandstone aggregates.
    Two cores were cut 2207 to 2261 m in the Hermod Formation. A wire line programme was run comprising 4 runs: 1A Quad combo, 1B MDT, 1C VSP and 1D MDT. The first MDT run proved Oil and Water gradients in addition to sampling the Oil zone at 2221 m. The second MDT run provided additional oil samples from the same oil horizon. Maximum temperature recorded in the first run was 103 deg C, corresponding to a rather high temperature gradient: 47.6 deg C/km with 4 deg C at sea floor. This was the only BHT reported from the well.
    The well was plugged back for sidetracking on 7 October 2009 as an oil 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]
    1050.00
    2400.00

  • 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
    2207.0
    2233.8
    [m ]
    2
    2234.0
    2260.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1050.0
    [m]
    DC
    CGG
    1110.0
    [m]
    DC
    CGG
    1140.0
    [m]
    DC
    CGG
    1170.0
    [m]
    DC
    CGG
    1200.0
    [m]
    DC
    CGG
    1290.0
    [m]
    DC
    CGG
    1320.0
    [m]
    DC
    CGG
    1350.0
    [m]
    DC
    CGG
    1410.0
    [m]
    DC
    CGG
    1440.0
    [m]
    DC
    CGG
    1500.0
    [m]
    DC
    CGG
    1530.0
    [m]
    DC
    CGG
    1590.0
    [m]
    DC
    CGG
    1620.0
    [m]
    DC
    CGG
    1650.0
    [m]
    DC
    CGG
    1680.0
    [m]
    DC
    CGG
    1710.0
    [m]
    DC
    CGG
    1740.0
    [m]
    DC
    CGG
    1770.0
    [m]
    DC
    CGG
    1830.0
    [m]
    DC
    CGG
    1880.0
    [m]
    DC
    CGG
    1920.0
    [m]
    DC
    CGG
    1950.0
    [m]
    DC
    CGG
    2000.0
    [m]
    DC
    CGG
    2040.0
    [m]
    DC
    CGG
    2070.0
    [m]
    DC
    CGG
    2100.0
    [m]
    DC
    CGG
    2110.0
    [m]
    DC
    CGG
    2120.0
    [m]
    DC
    CGG
    2130.0
    [m]
    DC
    CGG
    2140.0
    [m]
    DC
    CGG
    2150.0
    [m]
    DC
    CGG
    2170.0
    [m]
    DC
    CGG
    2180.0
    [m]
    DC
    CGG
    2190.0
    [m]
    DC
    CGG
    2200.0
    [m]
    DC
    CGG
    2207.2
    [m]
    C
    CGG
    2208.0
    [m]
    C
    CGG
    2211.2
    [m]
    C
    CGG
    2214.4
    [m]
    C
    CGG
    2216.7
    [m]
    C
    CGG
    2217.7
    [m]
    C
    CGG
    2224.1
    [m]
    C
    CGG
    2225.5
    [m]
    C
    CGG
    2228.9
    [m]
    C
    CGG
    2236.6
    [m]
    C
    CGG
    2239.2
    [m]
    C
    CGG
    2244.7
    [m]
    C
    CGG
    2245.8
    [m]
    C
    CGG
    2250.6
    [m]
    C
    CGG
    2251.7
    [m]
    C
    CGG
    2256.6
    [m]
    C
    CGG
    2259.8
    [m]
    C
    CGG
    2270.0
    [m]
    DC
    CGG
    2280.0
    [m]
    DC
    CGG
    2290.0
    [m]
    DC
    CGG
    2300.0
    [m]
    DC
    CGG
    2310.0
    [m]
    DC
    CGG
    2330.0
    [m]
    DC
    CGG
    2340.0
    [m]
    DC
    CGG
    2350.0
    [m]
    DC
    CGG
    2360.0
    [m]
    DC
    CGG
    2370.0
    [m]
    DC
    CGG
    2390.0
    [m]
    DC
    CGG

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT GPIT PPC DSI
    144
    2390
    MDT GR
    253
    2267
    MDT GR
    2221
    2221
    MWD - GR RES POE DEN PWD DI
    2204
    2390
    MWD - GR RES POR DEN PWD DI RES
    1033
    2204
    MWD - GR RES PWD DI
    185
    1020

  • 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
    192.0
    36
    194.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1022.0
    17 1/2
    1033.0
    0.00
    LOT
    OPEN HOLE
    2402.0
    12 1/4
    2402.0
    1.55
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    920
    1.40
    38.0
    wvjobreportmudchk.com
    1335
    1.35
    35.0
    wvjobreportmudchk.com
    2385
    1.39
    31.0
    Added lime and paravis to active
    2402
    1.39
    32.0
    wvjobreportmudchk.com
    2402
    1.39
    33.0
    wvjobreportmudchk.com
    2402
    1.39
    33.0
    wvjobreportmudchk.com
    2402
    1.39
    31.0
    wvjobreportmudchk.com
    2402
    1.39
    33.0
    wvjobreportmudchk.com
    2402
    1.39
    33.0
    Backloaded 117m3 OBM, 78m3 WBM

  • 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
    0.22