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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24/9-3

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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.
    24/9-3
    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
    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.
    24/9-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    C9/19 - 529 SP.345
    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.
    275-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.
    78
    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,
    28.01.1981
    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.
    15.04.1981
    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.
    15.04.1983
    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.
    29.06.2004
    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
    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.
    FRIGG FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    120.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3051.0
    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).
    3051.0
    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.
    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° 22' 25.38'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 46' 27.28'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6582460.55
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    430341.20
    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.
    346

  • Wellbore history
    General
    Exploration well 24/9-3 was drilled by Conoco for the Conoco/Statoil/Norsk Hydro/Hudbay PL 039 partnership. The well lies in the west-central part of block 24/9, close to the Norway/UK median line. The location was chosen to test an apparent sand build-up, observable on seismic lines, in the Lower Tertiary part of the section. The sand build-up was thought to correspond to the Lower Eocene Frigg Sand Formation, which forms the reservoir in the Frigg Field.
    Operations and results
    Well 24/9-3 was spudded with the semi-submersible installation SEDCO 704 on 28 January 1981 and drilled to TD at 3051 m in the Late Cretaceous Jorsalfare Formation. The duration of the well was 81 days, 20 of which were spent testing. A 36" hole was drilled to 207.6 m / 681 ft and 30" casing set to same depth. A 17 1/2" pilot hole was drilled to 518.2 m, logged, and then opened to 26". 20" x-56 casing was set at 503.2 m. A 17 1/2" hole was drilled to 1600.2 m, logged, and 13 3/8" N-80 casing was set at 1587.1 m. A 12 1/4" hole was drilled and cored to 2049.8 m, logged, and 9 5/8" N-80 casing was set then drilled to TD and logged. The well was drilled with spud mud to 518 m, with Dextrid/gel from 518 m to 853 m, with gel/lime from 853 m to 1067 m, with seawater/gel/Dextrid from 1067 m to 1600 m, and with seawater/lime/Dextrid mud from 1600 m to TD.
    The Lower Eocene sands (Frigg Formation) were encountered 141 m high to prognosis at 1739 m. This shows that the sands correspond to a higher and less distinct build-up on the seismic. The build-up originally mapped corresponded to the Paleocene Tuff level and contained shales and water-wet Paleocene Sands. A gross interval of 92 m of Early Eocene Sands was penetrated. The uppermost 70 m, from 1739 m, were hydrocarbon bearing down to an OWC at 1809 m, while the lowermost 22 m (1809-1831m) were water bearing. Patchy oil shows were observed down to 1870 m, no shows were recorded below this depth. Core analysis carried out by Geco indicated residual oil saturations of 13.4 % - 32.4 % and that the sands, where present, were of excellent reservoir quality with porosities of up to 39% and permeabilities in the 2-4 Darcy range.
    A single RFT result and the results of DST3 in the upper part of the Frigg Formation reservoir (1739.5 m û1747 m) combine to indicate the possibility that a gas zone existed in the interval 1739 m (Top Sand) - 1765m. There is, however, no indication of gas on the logs and the poor results from DST3 suggested that the zone tested was essentially tight.
    Bubble point measurements carried out at well site and subsequently confirmed in the laboratory by Flopetrol showed that the crude in the proven oil zone is under saturated. It therefore follows that the gas zone, if present, represents a separate accumulation and is not in pressure contact with the oil zone.
    Five cores were cut in the interval 1777.9 m to 1797.7 m in the Early Eocene sands. The core depths were generally ca 5 m deep to logger's depth. Geochemical samples were taken at 30 m intervals from 13 3/8" casing to TD.
    The well was permanently abandoned as an oil discovery on 15 April 1981.
    Testing
    After logging at TD the well was plugged back to 1995.5 m and three zones were tested using prepacked screens and a coiled tubing nitrogen unit for artificial lift. Three drill-stem tests were carried out on the hydrocarbon interval. Tests 1 (1797 m to 1805 m) and 2 (1765.4 m to 1773 m) in the lower part of the reservoir produced 21.5 - 23¦ API oil at rates 39 Sm3 oil/day and 86 Sm3 oil/day, respectively. Test 3 in the uppermost part of the reservoir gave only a small trickle of gas.

  • 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]
    210.00
    2959.00

  • 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
    1777.9
    1780.8
    [m ]
    2
    1783.4
    1787.0
    [m ]
    3
    1788.0
    1788.6
    [m ]
    4
    1788.9
    1794.6
    [m ]
    5
    1794.6
    1797.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    15.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1777-1780m
    Core photo at depth: 1780-1780m
    Core photo at depth: 1783-1785m
    Core photo at depth: 1786-1787m
    Core photo at depth: 1787-1788m
    1777-1780m
    1780-1780m
    1783-1785m
    1786-1787m
    1787-1788m
    Core photo at depth: 1788-1794m
    Core photo at depth: 1788-1794m
    Core photo at depth: 1788-1794m
    Core photo at depth: 1794-1797m
    Core photo at depth:  
    1788-1794m
    1788-1794m
    1788-1794m
    1794-1797m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1590.0
    [m]
    DC
    PSER
    1611.0
    [m]
    SWC
    PSER
    1625.0
    [m]
    SWC
    PSER
    1633.0
    [m]
    DC
    PSER
    1655.5
    [m]
    SWC
    PSER
    1663.0
    [m]
    DC
    PSER
    1686.0
    [m]
    SWC
    PSER
    1693.0
    [m]
    DC
    PSER
    1719.0
    [m]
    SWC
    PSER
    1723.0
    [m]
    DC
    PSER
    1739.0
    [m]
    SWC
    PSER
    1750.0
    [m]
    DC
    PSER
    1766.5
    [m]
    SWC
    PSER
    1778.0
    [m]
    SWC
    PSER
    1779.7
    [m]
    C
    PSER
    1783.0
    [m]
    DC
    PSER
    1784.3
    [m]
    C
    PSER
    1797.0
    [m]
    C
    PSER
    1810.0
    [m]
    SWC
    PSER
    1844.0
    [m]
    SWC
    PSER
    1855.0
    [m]
    DC
    PSER
    1867.5
    [m]
    SWC
    PSER
    1873.0
    [m]
    DC
    PSER
    1894.0
    [m]
    SWC
    PSER
    1903.0
    [m]
    DC
    PSER
    1921.0
    [m]
    SWC
    PSER
    1933.0
    [m]
    DC
    PSER
    1948.0
    [m]
    DC
    PSER
    1963.0
    [m]
    DC
    PSER
    1978.0
    [m]
    DC
    PSER
    1993.0
    [m]
    DC
    PSER
    1995.0
    [m]
    SWC
    PSER
    2008.0
    [m]
    DC
    PSER
    2018.0
    [m]
    SWC
    PSER
    2023.0
    [m]
    DC
    PSER
    2038.0
    [m]
    DC
    PSER
    2053.0
    [m]
    DC
    PSER
    2068.0
    [m]
    SWC
    PSER
    2077.0
    [m]
    DC
    PSER
    2098.0
    [m]
    DC
    PSER
    2113.0
    [m]
    DC
    PSER
    2118.0
    [m]
    DC
    PSER
    2128.0
    [m]
    DC
    PSER
    2144.0
    [m]
    SWC
    PSER
    2158.0
    [m]
    DC
    PSER
    2176.0
    [m]
    DC
    PSER
    2188.0
    [m]
    DC
    PSER
    2203.0
    [m]
    DC
    PSER
    2233.0
    [m]
    DC
    PSER
    2248.0
    [m]
    DC
    PSER
    2263.0
    [m]
    DC
    PSER
    2278.0
    [m]
    DC
    PSER
    2293.0
    [m]
    DC
    PSER
    2308.0
    [m]
    DC
    PSER
    2325.0
    [m]
    SWC
    PSER
    2329.0
    [m]
    DC
    PSER
    2338.0
    [m]
    DC
    PSER
    2353.0
    [m]
    DC
    PSER
    2368.0
    [m]
    DC
    PSER
    2386.0
    [m]
    DC
    PSER
    2398.0
    [m]
    DC
    PSER
    2413.0
    [m]
    DC
    PSER
    2436.0
    [m]
    SWC
    PSER
    2443.0
    [m]
    DC
    PSER
    2458.0
    [m]
    DC
    PSER
    2473.0
    [m]
    DC
    PSER
    2491.0
    [m]
    DC
    PSER
    2503.0
    [m]
    DC
    PSER
    2518.0
    [m]
    DC
    PSER
    2533.0
    [m]
    DC
    PSER
    2544.0
    [m]
    DC
    PSER
    2563.0
    [m]
    DC
    PSER
    2578.0
    [m]
    DC
    PSER
    2595.0
    [m]
    SWC
    PSER
    2608.0
    [m]
    DC
    PSER
    2627.0
    [m]
    SWC
    PSER
    2638.0
    [m]
    DC
    PSER
    2653.0
    [m]
    DC
    PSER
    2668.0
    [m]
    DC
    PSER
    2683.0
    [m]
    DC
    PSER
    2698.0
    [m]
    DC
    PSER
    2716.0
    [m]
    DC
    PSER
    2737.0
    [m]
    DC
    PSER
    2749.0
    [m]
    SWC
    PSER
    2761.0
    [m]
    DC
    PSER
    2773.0
    [m]
    DC
    PSER
    2788.0
    [m]
    DC
    PSER
    2803.0
    [m]
    DC
    PSER
    2825.0
    [m]
    SWC
    PSER
    2830.0
    [m]
    DC
    PSER

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    1
    1796.00
    1805.00
    OIL
    21.03.1981 - 00:00
    YES
    DST
    1764.40
    1782.20
    01.04.1981 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.42

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.56

  • 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
    54.09

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1805
    1796
    0.0
    2.0
    1782
    1775
    50.8
    3.0
    1747
    1739
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    39
    1000
    0.916
    0.650
    26
    2.0
    86
    2400
    0.925
    0.630
    28
    3.0
    1000
    0.562

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CNL CCL GR
    970
    2036
    CST
    1611
    1995
    CST
    2048
    3020
    DDBHC GR
    1719
    1925
    DLL MSFL GR SP
    1584
    2033
    FDC CNL GR CAL
    1583
    3042
    HDT CAL
    1584
    3035
    ISF DDBHC GR SP
    514
    2037
    ISF DDBHC GR SP
    1916
    3041
    RFT
    1754
    1802
    VSP
    348
    3030

  • 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
    207.6
    36
    207.6
    0.00
    LOT
    SURF.COND.
    20
    503.2
    26
    518.2
    1.38
    LOT
    INTERM.
    13 3/8
    1587.1
    17 1/2
    1600.2
    1.64
    LOT
    INTERM.
    9 5/8
    3051.0
    12 1/4
    3051.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    450
    1.14
    200.0
    spud mud
    860
    1.04
    50.0
    water based
    1290
    1.11
    64.0
    water based
    1490
    1.11
    87.0
    water based
    1770
    1.23
    48.0
    water based
    1910
    1.32
    55.0
    water based
    2240
    1.31
    50.0
    water based
    2550
    1.25
    55.0
    water based
    2720
    1.25
    62.0
    water based
    2930
    1.20
    57.0
    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
    0.22