Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

24/9-5

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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.
    24/9-5
    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
    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.
    24/9-5
    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.
    778-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.
    51
    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.
    26.01.1994
    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.
    26.01.1996
    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.
    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.
    WILDCAT
    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.
    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.
    122.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2860.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    88
    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.
    LATE CRETACEOUS
    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.
    JORSALFARE 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' 6.52'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 55' 10.82'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6594725.25
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    438806.71
    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.
    2244

  • Wellbore history
    General
    Wildcat well 24/9-5 was drilled in a location SW of the Heimdal field, ca 5 km from the UK border. It was programmed to test two primary sandstone prospects in the Late Paleocene. The lower objective was the Hermod Formation and the upper objective was sandstones within the Balder Formation. The Hermod Formation prospect was a mapped isochron thick with a small area of structural closure at Top Sele Formation. The Balder Formation prospect was mapped as an isochron thick with an associated seismic amplitude anomaly and was primarily regarded as a stratigraphic trap.
    Operations and results
    Wildcat well 24/9-5 was spudded with the semi-submersible installation West Delta on 7 December 1993 and drilled to TD at 2860 m in the Late Cretaceous Jorsalfare Formation. No significant problem was reported from the operations. The well was drilled with seawater down to 581 m, with KCl/PAC/PHPA from 581 m to 1941 m, and with KCl/PAC/PHPA/glycol from 1941 m to TD.
    The Balder Formation was encountered at 1964 m. A gross oil bearing Intra Balder Formation sandstone interval of 7.1 m was encountered at 2011 m. Net sandstone was 6.3 m of which 5.9 m was in a single massive unit. Petrophysical analysis gave porosities of 35 - 40% in the massive sandstone unit with an average SW of 22.2%. Base of the reservoir was encountered at 2018 m, which was found to be an oil-down-to water contact. Samples from the FMT tool indicated the reservoir fluid to consist of 32-34 deg API oil with a GOR of 91 Sm3/Sm3. Pressure gradient analysis gave a free water level at 2031.5 m (2028.0 m TVD). Geochemical analysis of the oil sample indicated minor biodegradation had taken place. The Sele Formation was encountered at 2031 m with 47 m net sandstone in two Hermod Formation sequences. The upper sequence was encountered at 2049 m and the lower at 2098 m. These sandstones proved to be water bearing with no shows. A thin sandstone at 2045.5 - 2047 m, just above the upper Hermod interval, gave the highest known water below the Balder Formation pay interval. An additional zone of interest was encountered in the interval 1775-1790 m where a number of siltstone/argillaceous sandstone stringers were identified. Minor gas shows were observed and rare traces of sandstone gave poor (residual?) oil shows. Log analysis showed the presence of hydrocarbons in thin argillaceous stringers particularly over the interval 1785-1787.5 m where neutron density logs (acquired through casing) indicated the presence of gas (Average SW = 40%).
    Four conventional cores were cut. Three were cut in the Late Palaeocene Balder Formation with 7 m Intra Balder Formation sandstone. The fourth was cut in the Hermod Formation Sandstone within the Sele Formation. Three FMT samples were taken in the well, one at 2013.5 m (oil) and two at 2017.5 m (mud filtrate)
    Although the hydrocarbon-bearing interval in the Balder Formation was as prognosis it was recognised that the well was not in an optimum location and it was decided to drill an immediate appraisal well. Well 24/9-5 was therefore not tested.
    The well was permanently abandoned on 26 January 1994 as an oil discovery.
    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]
    590.00
    2860.00

  • 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
    2000.0
    2001.8
    [m ]
    2
    2002.5
    2019.9
    [m ]
    3
    2020.3
    2033.1
    [m ]
    4
    2048.3
    2052.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    36.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2000-2002m
    Core photo at depth: 2002-2007m
    Core photo at depth: 2007-2012m
    Core photo at depth: 2012-2017m
    Core photo at depth: 2017-2020m
    2000-2002m
    2002-2007m
    2007-2012m
    2012-2017m
    2017-2020m
    Core photo at depth: 2020-2025m
    Core photo at depth: 2025-2030m
    Core photo at depth: 2030-2033m
    Core photo at depth: 2048-2052m
    Core photo at depth:  
    2020-2025m
    2025-2030m
    2030-2033m
    2048-2052m

  • 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
    235.0
    36
    240.0
    0.00
    LOT
    SURF.COND.
    20
    576.0
    26
    581.0
    0.00
    LOT
    INTERM.
    13 3/8
    1346.0
    17 1/2
    1377.0
    0.00
    LOT
    INTERM.
    9 5/8
    1935.0
    12 1/2
    1941.0
    0.00
    LOT
    OPEN HOLE
    2860.0
    8 1/2
    2860.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL
    129
    574
    ACBL
    450
    1344
    BRIDGEPLUG BST CCL
    1700
    1806
    CBL VDL GR
    1010
    1932
    CDL CN GR CAL
    1750
    2858
    DIFL ACL SP GR CAL
    129
    1362
    DIFL ACL SP GR CAL
    1344
    1881
    DIFL ACL SP GR CAL
    1932
    2859
    DLL MLL SL CAL SP
    1930
    2350
    FMT VPC GR
    2011
    2320
    FMT VPC GR
    2012
    2012
    FMT VPC GR
    2012
    2111
    FMT VPC GR
    2017
    2017
    HDIP GR
    1932
    2350
    MWD LWD - GR DPR
    159
    2834
    SWC PFC
    1950
    2657
    VSP
    500
    2850

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.36

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.88

  • 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
    17.34

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    240
    1.20
    15.0
    WATER BASED
    580
    1.25
    100.0
    WATER BASED
    1124
    1.17
    18.0
    WATER BASED
    1377
    1.25
    23.0
    WATER BASED
    1377
    1.22
    20.0
    WATER BASED
    2203
    1.25
    23.0
    DUMMY
    2860
    1.25
    21.0
    DUMMY