Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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24.11.2024 - 01:27
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24/9-4

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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.
    24/9-4
    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
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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.
    24/9-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    FI89 X-1017 / FI89 Y-1804
    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.
    675-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.
    62
    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,
    17.04.1991
    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.
    17.06.1991
    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.
    17.06.1993
    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.
    OIL SHOWS
    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.
    24.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    119.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2208.0
    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).
    2206.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    44
    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° 23' 21.95'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 47' 20.29'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6584194.97
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    431209.79
    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.
    1714

  • Wellbore history
    General
    Well 24/9-4 is located 1 km East of the border to British sector, on the northern outskirts of the 24/9-3 Discovery. The main objective of the well was to test the Early Eocene Frigg Formation forming a stratigraphic play in the western part of the block, where the reservoir was interpreted to result from a submarine fan deposition. The primary risk of the prospect was the presence of the reservoir. The prognosed gross thickness of the reservoir sequence was 230 metres with a net/gross ratio of 0.50 at the well location. No secondary targets were identified.
    Operations and results
    Well 24/9-4 was spudded with the semi-submersible installation Byford Dolphin on 17 April 1991 and drilled to TD at 2208 m in the Late Paleocene Lista Formation. Here, a wiper trip was performed. When back reaming the string stuck at 1864 m. It was not possible to circulate since the hole had packed off. Several fishing attempts were made, but all were unsuccessful, leaving an MWD tool and a CDR tool in the hole. The hole was then cemented to 1733 m. The sidetrack vas kicked off from 1753 m to an angle of four degrees before pulling out at 1842 m. A conventional packed hole assembly vas then run to try to drill to section TD. Drilling continued to 2021m where a viper trip vas performed to ream tight hole sections. Drilling resumed without incident to 2164 m where bottoms up vas circulated before tripping out. The string became differentially stuck whilst pulling out of the hole. After spotting a pill and jarring for several hours a back-off charge vas run leaving a 30 m fish in the hole, which included an MWD tool. Several unsuccessful fishing runs were attempted before running a VSP and E-logs. The well vas then plugged and abandoned at 2164 m.
    Well 24/9-4 penetrated the top of the Frigg Formation sands at 1766 m, which was 51 metres deeper than prognosed. It consisted of very fine to fine grained well-sorted very argillaceous sandstone stringers commonly less than one metre thick. One major massive sand was seen from 1864.5 to 1906 m. The majority of the Frigg interval was grey claystone with occasional pyrite and glauconite grains. Thin limestone stringers were also seen.
    The first shows observed in the well occurred at 1759 m with traces of an orange direct fluorescence with a fast white cut fluorescence and a white residue fluorescence. Gas levels increased sharply at 1766 m to 0.36% C1, 0.017% C2 with traces of C3 and C4, with an average reading of 0.123 % C1, 0.025% C2 and traces of C3 and C4 down to 1815 m. Below this depth levels fell to 0.07-0.10% C1, with traces of C2 and C3. Shows were good in the sandstone stringers encountered from 1766 to 1815 m with oil staining, direct and cut fluorescence. Below 1815 m, the shows diminished until below 1840 m, where only traces of cut fluorescence could be detected. The main sand interval between 1864.5 and 1906.0 m was water bearing. Only traces of light brown and occasional black residual oil were encountered in this interval.
    Three cores were cut in the Lower Eocene section at the top of the Frigg Formation sands. A total of 22.0 metres were cored between 1773.0 and 1795.0 m, with a total recovery of 11.75 metres (53.4 %). The cores consist mainly of claystone and only three very thin sand stringers were present. Black oil was bleeding from these stringers. RFT points were taken throughout the four reservoir sections. The overall quality of the data is poor due to the type of reservoir (unconsolidated sandstone), the hole conditions (caliper log indicates values from 6.5 to 14 inches) and large drilling fluid invasion in the reservoir sections. Four attempts were made to collect representative reservoir fluid samples. On each run, a 2 3/4 and a one-gallon RFT chamber were used. The 23/4 chambers were full of mud/mud filtrate. Some oil shows were found but could not be used for laboratory analysis. Wire line logs in run no 4, the MWD/LWD logs in runs no 8 and 9, CST's, and RFT's were taken in the sidetrack. The conventional cores and all other logs were acquired in the first hole. Based on the analysis of the ditch cuttings, conventional cores and logs it was decided not to test the well. The well was plugged and abandoned as a dry well with oil shows on 18 June 1991.
    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]
    770.00
    2161.00

  • 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
    1773.0
    1778.9
    [m ]
    2
    1782.0
    1787.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    11.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1773-1776m
    Core photo at depth: 1776-1778m
    Core photo at depth: 1782-1785m
    Core photo at depth: 1785-1787m
    Core photo at depth: 1787-1791m
    1773-1776m
    1776-1778m
    1782-1785m
    1785-1787m
    1787-1791m

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.51

  • 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
    27.29

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCL
    1300
    1518
    CST GR
    1760
    1850
    DIL BHC CAL GR
    1585
    1792
    DIL BHC CAL GR
    1585
    1857
    DIL BHC LDL GR
    1179
    1617
    DIL LSS GR AMS
    1179
    1443
    DIL LSS LDL GR
    750
    1168
    DIL SLS CAL GR
    1585
    1752
    DLL MSFL GR CAL
    1585
    1855
    LDL CNC GR CAL
    1585
    1857
    MWD LWD - CDR
    1650
    2208
    MWD LWD - GR RES
    143
    610
    MWD LWD - GR RES
    1753
    2161
    RFT HP GR
    1766
    1818
    RFT HP GR
    1766
    1818
    RFT HP GR
    1766
    1818
    VSP
    230
    1820

  • 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
    205.5
    36
    211.0
    0.00
    LOT
    INTERM.
    20
    750.0
    26
    756.0
    1.21
    LOT
    INTERM.
    13 3/8
    1179.0
    17 1/2
    1180.0
    1.53
    LOT
    INTERM.
    9 5/8
    1585.0
    12 1/4
    1654.0
    1.68
    LOT
    OPEN HOLE
    2208.0
    8 1/2
    2208.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    170
    1.03
    130.0
    WATER BASED
    210
    1.20
    31.0
    WATER BASED
    650
    1.20
    31.0
    WATER BASED
    756
    1.03
    140.0
    WATER BASED
    1585
    1.41
    70.0
    WATER BASED
    1654
    1.35
    75.0
    WATER BASED
    1688
    1.13
    55.0
    WATER BASED
    1903
    1.41
    63.0
    WATER BASED
    1979
    1.41
    56.0
    WATER BASED
    2208
    1.25
    53.0
    WATER BASED

  • 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
    0.20