Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

24/9-6

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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.
    24/9-6
    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
    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
    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.
    24/9-6
    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.
    Fina Production Licenses 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.
    782-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.
    35
    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,
    01.02.1994
    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.
    07.03.1994
    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.
    07.03.1996
    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.
    15.02.2006
    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.
    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.
    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.
    INTRA BALDER FM SS
    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.
    123.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2255.0
    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).
    2255.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    60
    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° 29' 1.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 57' 27.14'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6594535.74
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    440949.06
    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.
    2288

  • Wellbore history
    General
    Well 24/9-6 was drilled to appraise the 24/9-5 discovery and is located 2.2 km to the east of the 24/9-5 well location. Well 24/9-5 encountered a thin, 5.9 m net Balder Sandstone reservoir. It was considered not to be optimally placed for the Balder Formation objective and no production tests were made. Instead well 24/9-6 was drilled as an immediate appraisal in an optimum location. Mapping indicated that sandstone presence within the Balder Formation could be identified by gross Balder Formation thickening and by an associated seismic amplitude anomaly, believed to be a direct hydrocarbon indicator. Well 24/9-6 was located close to the centre of the Balder Formation interval thickening in a position where the seismic amplitude anomaly was best developed
    Operations and results
    Appraisal well 24/9-6 was spudded with the semi-submersible installation West Delta on 1 February 1994 and drilled to TD at 2255 m in the Paleocene Heimdal Formation. No significant technical problems were reported from the operations. The well was drilled with seawater down to 1279 m, with KCl/polymer/glycol from 1279 m to 1957 m, and with KCl/polymer mud from 1957 m to TD.
    The Balder Formation was encountered at 1917 m with two massive Intra Balder Formation sandstone sequences with a total net thickness of 49.5 m (prognosis 25 m). The first Intra Balder Formation sandstone was encountered at 2010.5 m, the second at 2034 m. A thin (0.5 m) oil-bearing sandstone was encountered at 2004.0 m just above the upper massive sandstone. The upper massive sandstone was hydrocarbon bearing all through down to the base at 2022 m, without any OWC seen. The lower massive sandstone proved to be water bearing. Thin sandstones in the interval 2029.0-2033.0 m had good shows on core. The highest known water was observed at 2034.0 m.
    Analysis of a PVT sample from 2012.0 m showed the oil gravity to be 32 deg API with a gas/oil ratio (GOR) of 105 Sm3/Sm3. PVT pressure data indicated the fluid system to be saturated or near saturation at reservoir conditions. However no indications of the presence of a gas cap were seen. Three conventional cores were cut from 2015 m to 2046 m in the Balder Formation. Core recovered in core no. 1 (2015 m to 2024 m) is believed to be from the bottom of the cored interval. The inner liner of core no. 3 sheared and it is believed that up to 0.9 m may have been lost at 2035.5 m. One FMT fluid sample was taken at 2012 m. It contained 32 deg API oil.
    The accumulation was concluded to be of sub-commercial size and the well was plugged and abandoned without production testing. The well was permanently abandoned on 7 March 1994 as an oil appraisal.
    Testing
    No drill stem test was performed in the well.

  • 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]
    1287.00
    2283.00

  • 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
    2022.1
    2024.0
    [m ]
    2
    2024.0
    2032.2
    [m ]
    3
    2032.5
    2045.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    22.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2022-2024m
    Core photo at depth: 2024-2029m
    Core photo at depth: 2029-2032m
    Core photo at depth: 2032-2037m
    Core photo at depth: 2037-2042m
    2022-2024m
    2024-2029m
    2029-2032m
    2032-2037m
    2037-2042m
    Core photo at depth: 2042-2045m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2042-2045m

  • 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
    249.0
    36
    254.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1279.0
    17 1/2
    1286.0
    0.00
    LOT
    INTERM.
    9 5/8
    1957.0
    12 1/4
    1963.0
    0.00
    LOT
    OPEN HOLE
    2255.0
    8 1/2
    2255.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BP BST CCL
    1878
    1878
    CBIL CGR TTRM
    1955
    2253
    DAC DGR TTRM
    130
    1278
    DAC DGR TTRM
    1278
    4000
    DLL MLL GR CHT
    1955
    2253
    DPIL SP DAC DGR XDL CAL TTRM
    1278
    1946
    DPIL SP MAC DGR TTRM
    2955
    2253
    HEXDIP GR CHT
    1955
    2253
    MAC DGR TTRM
    0
    0
    MWD - GR DPR
    158
    2254
    SWC
    2004
    2241
    VPC FMT GR
    2004
    2119
    VSP
    0
    0
    ZDL CN DSL TTRM
    1955
    2253

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.20

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.78

  • 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
    14.58

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    190
    1.06
    WATER BASED
    04.02.1994
    254
    1.06
    WATER BASED
    07.02.1994
    254
    1.06
    WATER BASED
    07.02.1994
    254
    1.06
    WATER BASED
    07.02.1994
    254
    1.06
    WATER BASED
    08.02.1994
    254
    1.06
    WATER BASED
    09.02.1994
    254
    1.01
    WATER BASED
    10.02.1994
    390
    1.06
    WATER BASED
    02.02.1994
    614
    1.06
    WATER BASED
    03.02.1994
    741
    1.01
    WATER BASED
    11.02.1994
    1206
    1.03
    24.0
    19.0
    WATER BASED
    14.02.1994
    1286
    1.13
    39.0
    18.0
    WATER BASED
    16.02.1994
    1286
    1.25
    20.0
    10.0
    WATER BASED
    14.02.1994
    1286
    1.13
    39.0
    18.0
    WATER BASED
    15.02.1994
    1286
    1.40
    34.0
    11.0
    WATER BASED
    17.02.1994
    1286
    1.41
    34.0
    11.0
    WATER BASED
    18.02.1994
    1355
    1.40
    53.0
    12.0
    21.02.1994
    1711
    1.50
    57.0
    13.0
    DUMMY
    21.02.1994
    1948
    1.50
    34.0
    14.0
    DUMMY
    21.02.1994
    1963
    1.50
    45.0
    12.0
    DUMMY
    22.02.1994
    1963
    1.55
    39.0
    24.0
    DUMMY
    23.02.1994
    1963
    1.40
    27.0
    11.0
    DUMMY
    24.02.1994
    1963
    1.15
    17.0
    7.0
    DUMMY
    25.02.1994
    2015
    1.16
    19.0
    10.0
    28.02.1994
    2033
    1.16
    18.0
    12.0
    DUMMY
    28.02.1994
    2087
    1.16
    20.0
    13.0
    DUMMY
    01.03.1994
    2255
    1.17
    22.0
    15.0
    DUMMY
    01.03.1994
    2255
    1.17
    22.0
    13.0
    DUMMY
    02.03.1994
    2255
    1.18
    22.0
    15.0
    DUMMY
    03.03.1994
    2255
    1.18
    21.0
    15.0
    DUMMY
    04.03.1994