Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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24/9-7 B

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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.
    24/9-7 B
    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.
    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.
    NORTH 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.
    24/9-7
    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.
    1076-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.
    4
    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,
    30.03.2004
    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.
    02.04.2004
    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.
    02.04.2006
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    02.04.2004
    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.
    23.05.2006
    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.
    NO
    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.
    EOCENE
    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.
    NO FORMAL NAME
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    125.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2230.0
    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).
    2120.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    29.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    75
    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.
    LISTA FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 28' 42.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 57' 44.49'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6593946.86
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    441212.92
    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.
    4926

  • Wellbore history
    General
    Well 24/9-7 was drilled on the Hamsun prospect located immediately to the west and south west of the Gekko structure in PL203 (Figure 1). The prospect was a "horse-shoe" shape around the Grieg structure, drilled by wells 24/9-5 and 24/9-6 in 1993 and 1994. The Hamsun prospect was defined by the recognition and interpretation of a series of distinct seismic anomalies and mapped as a sandstone injection complex, sourced from early Eocene Hermod Formation sands. These anomalies were interpreted to represent oil-filled, highly porous sandstone dykes and sills. Several well bores were proposed to test the prospect. The prime vertical well was planned to intersect the thickest part of the injection complex to test bright amplitude, low acoustic impedance seismic reflectors interpreted to represent major sandstone dyke complexes. A sidetrack well bore was planned depending on the results of the first well.
    Operations and results
    A total of four wells were drilled from the surface location for 24/9-7 (the planned vertical well, an unplanned down-dip sidetrack 24/9-7 A, the planned up-dip sidetrack 24/9-7 B and a further unplanned lateral sidetrack 24/9-7 C). Taken as a whole, the four well bores took a total of 43.11 days to drill. All were drilled from the semi-submersible installation Deepsea Delta. No significant problems were encountered in the operations. Well 24/9-7 was drilled with seawater down to 953 m. From this depth to TD 24/9-7 and all sidetracks were drilled with Versavert oil based mud.
    The prime vertical well bore 24/9-7 was spudded on 2 March 2004 and drilled to TD at 2280 m in the Late Paleocene Heimdal Formation. The well was plugged back for sidetracking on 24 March 2004. Well 24/9-7 A was kicked off at 1500 m and drilled to TD at 2277 m (2216.9 m TVD) in Heimdal Formation sandstone. The well was plugged back for a second sidetrack on 28 March 2004. Well bore 24/9-7-B was sidetracked from 1060 m and drilled to TD at 2230 m (2120.1 m TVD) in Lista Formation claystone. This well bore was plugged back for the final sidetrack on 2 April 2004. Sidetrack 24/9-7 C was kicked off at 1000 m and drilled to TD at 2363 m (2078.5 m TVD) in Sele Formation claystone.
    Well 24/9-7 encountered hydrocarbons in two injected sandstone dyke complexes ("upper" and "lower"), together with numerous thin injectites distributed throughout the formations in proximity to the main dyke features. Thin injectite sands were first noted at 1822.6 m TVD, ca 54 m TVD shallower than the main injection feature. The upper, gas-bearing complex was penetrated at 1876.9 m TVD and the lower oil-bearing complex was penetrated at 1961.8 m TVD. Average porosities in the pay zones were estimated to 31.7% in the upper complex and 31.3% in the lower complex. The gas-oil and oil-water contacts were not seen directly on logs or core, but were interpreted at 1920 m TVD and 2024.8 m TVD respectively, based on formation pressure gradients.
    Based on these results, sidetrack 24/9-7 A was permitted to evaluate the upper dyke complex down-dip in the oil leg with the intention of encountering an OWC in the lower complex. This sidetrack encountered the upper and lower complexes, approximately 126 m to the north of the original well, at 1927.6 m TVD and 2032.4 m TVD respectively. Gas-bearing pay was encountered distributed in thin breccia injectite intervals above the upper complex, which was oil-bearing throughout with ca 31.6 m vertical oil pay with average porosity of 32.2%. The lower complex was entirely water bearing as it was penetrated below the previously noted OWC. Wire line log interpretation and formation pressure analysis confirmed the oil column data and results recorded in 24/9-7 and the well was plugged back for the programmed up-dip sidetrack.
    Well 24/9-7B was drilled to the planned target location up-dip of the main dyke feature but at 1794 m TVD encountered only thin, sporadic, gas-bearing injectites in the fringe complex.
    Well 24/9-7C was drilled with LWD tools to a tight target 728 m northeast of the initial vertical well. The well encountered oil-bearing injected sandstone with a clearly defined OWC at 2024.3 m TVD. Confirmation of the OWC was obtained through formation pressure analysis and a total of 29 m vertical oil pay was recognized with an average porosity of 33.5%.
    Four conventional cores were cut from 1830 m to 1916 m in 24/9-7 and one core from 1922.5 m to 1978 m in 24/9-7 B. Four suites of logs were run in 24/9-7 with RCI fluid sampling at different depths within the reservoir. Single Phase samples were taken as follows: oil from 1965 m and 1966.5 m in the lower dyke; 2 gas from 1887 m and 1893.5 min the upper dyke. PVT samples were taken as follows: oil samples were taken at 1965 m and 1966.5 m; gas was sampled at 1906.5 m, 1887 m, and 1893.5 m. The samples analysed showed a gas gravity of 0.679 sg while the oil samples analysed showed a density of 858.3kg/m3, viscosity of 0.75cp and a gas/oil ratio (GOR) 104.5 m3/m3. Three suites of logs were acquired in 24/9-7A, again with fluid sampling in the reservoir section. Here, PVT samples were taken as follows: oil from 1996 m and water from 2095 m. A single suite of logs was acquired in each of 24/9-7 B and 24/9-7 C.
    Rig operations were completed and the wells temporarily suspended on 11 April 2004. The well bores were classified as gas oil appraisal wells.
    Testing
    No drill stem test was performed in the well bores.

  • 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]
    1080.00
    2230.00

  • 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
    1922.5
    1978.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    55.7
    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
    OPEN HOLE
    2230.0
    8 1/2
    2230.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GR HDIL ZDL CNL XMAC
    940
    2227
    LWD - ARC6 GR
    1918
    2219
    LWD - RAB6 ARC6 GR
    1055
    1918

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    153
    460
    722
    722
    1151
    1293
    1327
    1342
    2053
    2053
    2170
    2213

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1147
    1.31
    26.0
    VERSAVERT OBM
    1350
    1.30
    26.0
    VERSAVERT OBM
    1866
    1.30
    24.0
    VERSAVERT OBM
    1978
    1.30
    23.0
    VERSAVERT OBM
    2230
    1.30
    24.0
    VERSAVERT OBM