Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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09.05.2024 - 01:35
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24/9-1

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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.
    24/9-1
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    24/9-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE CN 24-25 R SP.130
    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.
    Conoco Norway Inc.
    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.
    152-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.
    126
    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,
    29.02.1976
    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.
    03.07.1976
    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.
    03.07.1978
    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.
    01.12.2004
    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.
    DRY
    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
    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.
    118.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4907.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    127
    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 JURASSIC
    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.
    HEATHER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 16' 9.48'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 47' 31.18'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6570815.42
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    431138.99
    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.
    344

  • Wellbore history
    General
    Wildcat well 24/9-1 is located in the Vana Sub-basin in the Southern Viking Graben, about 11 km east of the border to British sector. The well was drilled to test a large, dip-closed structure located in the centre of the Viking Graben. The target was Late Jurassic sandstones. Two sandstone intervals were expected in the well, with a possible gross thickness of about 250-300 m. The prognosis was based on a correlation with the UK wells 16/7-1, 16/8-1 and the Norwegian well 15/3-1 which are situated in a similar position as 24/9-1 relative to the eastern boundary fault of the Viking Graben.
    The well is Reference Well for the Svarte, Tryggvason, Kyrre, and Jorsalfare Formations.
    Operations and results
    Well 24/9-1 was spudded with the semi-submersible installation Ross Rig on 29 February 1976 and drilled to TD at 4907 m in the Late Jurassic Heather Formation. Below the 20" casing at 758.3 m the Formations drilled contained abundant sand and was drilled extremely fast. This created problems as the solids removal system on the rig was incapable of removing the sand as fast as it was drilled. In addition the polymer mud system chosen did not provide sufficient fluid loss control in the porous formation and large amounts of fluids were lost to the formation. From ca 2440 m to TD at 2752 m in the 17 1/2" hole low penetration rates was a problem. Of 126 rig days 20 % was counted as lost time, but the total time spent on the well was still less than the originally estimated 139 days. Problems related to tight/sloughing hole and down hole tool failure accounted for roughly half of the lost time. The well was drilled with seawater down to 256 m, with lime / lignosulphonate from 256 m to 3983 m, with Dextrid / Lignosulphonate from 3983 m to 4613 m, and with lime / lignosulphonate from 4613 m to TD.
    Tertiary sandstones were encountered in the Grid Formation (1131 m to 1420 m), The Heimdal Formation (2202 m to 2497 m), and the Ty Formation (2545 m to 2659 m). The well encountered Jurassic shales at 4330 m with a high increase in background gas and additional ethane to pentane gases. The Draupne Formation proved to be 470 m thick, while The Heather Formation was encountered at 4800 m and continued down to TD. Only thin Jurassic sandstones (Intra Heather Formation Sandstones) were penetrated.
    Both cuttings and sidewall cores revealed that Late Jurassic sandstones had low visible porosities. Evaluation of petrophysical logs substantiate this observation. The net thickness sandstone was approximately 18.5 m, none of the individual beds were, however, thicker than 4 m, scattered throughout a gross of about 490 m. Average porosity was 13 % and average Sw is 40%.
    No oil shows were found while drilling and only two of the sidewall cores at 2582 and 4832 m showed trace of cut fluorescence. Gas shows and log analysis suggested that the Jurassic sands are gas bearing. Down to a depth of about 4325 m only minor amounts of methane background gas were encountered. Below this depth down to TD, variable but largely high amounts of gas lighter than hexane were recorded. Shows of gas were continuous and the highest amounts are associated with some of the thin sand-stringers. Shale gas was also present. The Draupne Formation represent a significant source rock with TOC typically in the range 4 % to 6 % and Hydrogen Index typically in the range 130 to 160 mg HC/g rock. Maturity is advanced with Vitrinite reflectance %Ro from 0.9 to 1.3, which imply that most of the hydrocarbon potential already has been realised and expelled. The Heather Formation shales are also source rocks, but slightly leaner (TOC = 3% to 5%). One core was cut in the interval 4441.9 m to 4460.2 m in the Draupne Formation. Fluid sampling was attempted on wire line at 4815 m and at 4816.5 m, but failed due to tight Formation.
    The well was considered a valid test of the Late Jurassic sands, which were demonstrated to be thin with no commercial hydrocarbons. The well was plugged and abandoned on 3 July 1976 with gas shows in Late Jurassic sandstones.
    Testing
    No drill stem test was performed

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    256.00
    4907.00

  • 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
    4441.9
    4460.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    18.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.76

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.37
    pdf
    2.03
    pdf
    3.64

  • 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
    24.84
    pdf
    3.64

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    256
    763
    BHC GR
    3650
    3999
    BHC GR CAL
    3981
    4170
    BHC GR CAL
    3981
    4453
    BHC GR CAL
    3981
    4612
    CBL
    1240
    3983
    CNL FDC GR CAL
    760
    2749
    DLL SP
    4300
    4901
    FDC CNL GR CAL
    4300
    4905
    FDC GR CAL
    3680
    3999
    HDT
    4300
    4900
    ISF BHC GR SP
    760
    2750
    ISF BHC GR SP
    2670
    3715
    ISF BHC GR SP
    4430
    4904
    ISF GR CAL
    3650
    4000
    ISF GR SP
    3981
    4614
    ML MLL
    4300
    4905
    VBL
    3750
    3980

  • 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
    256.0
    36
    257.0
    0.00
    LOT
    INTERM.
    20
    758.0
    26
    760.0
    0.00
    LOT
    INTERM.
    13 3/8
    2736.0
    17 1/2
    2739.0
    0.00
    LOT
    INTERM.
    9 5/8
    3986.0
    12 1/4
    3986.0
    0.00
    LOT
    OPEN HOLE
    4907.0
    8 1/2
    4907.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    256
    1.01
    water mud
    765
    1.10
    65.0
    water based
    1770
    1.25
    65.0
    water based
    2193
    1.25
    59.0
    water based
    2322
    1.31
    54.0
    water based
    2665
    1.31
    52.0
    water based
    2872
    1.26
    50.0
    water based
    3998
    1.66
    45.0
    water based
    4039
    1.79
    55.0
    water based