Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.04.2024 - 01:34
Time of last synchronization with Norwegian Offshore Directorate's internal systems

9/11-1

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    9/11-1
    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.
    9/11-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    57-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.
    48
    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,
    03.07.1971
    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.
    19.08.1971
    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.
    19.08.1973
    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.
    25.04.2005
    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.
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    65.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2196.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    68
    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.
    TRIASSIC
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 0' 41.4'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 31' 40.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6319845.51
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    592790.86
    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.
    194

  • Wellbore history
    General
    Well 9/11-1 is situated in the Åsta Graben in the Danish-Norwegian Basin in the North Sea. The purpose of the well was to test the hydrocarbon and reservoir potential of Triassic to basal Tertiary sediments over a north-south elongated salt dome. The Jurassic - Triassic sandstones were the primary objective, with the Late Cretaceous - Danian carbonates and Palaeocene sandstones as secondary objectives.
    The well is Type Well for the Late Paleocene Fiskebank Formation
    Operations and results
    Wildcat well 9/11-1 was spudded with the semi-submersible installation Transworld 61 on 3 July 1971 and drilled to TD at 2196 m in the Late Triassic Skagerrak Formation. The 26" section was first drilled with a 17 1/2" bit to 412 m using gel/seawater mud. The hole was then under-reamed to 26" to 411 m. The 26" bit was run in hole but could not get past 119 m. When reaming was attempted, circulation was lost at 127 m. The hole was then re-drilled to 412 m with a 17 1/2" bit and opened to 26" with no problems. The 20" casing was run and cemented at 378 m. Eleven days were used on this interval and 700 bbl mud lost to seabed. The remaining well was drilled without significant problems. The well was drilled with seawater and hi-vis pills to 127 m, with seawater and gel from 127 m to 412 m, and with seawater / lignosulphonate (Spersene) and 1 -6 % diesel from 412 m to TD.
    The well drilled a thick Tertiary-Quaternary section (approx. 1600 m), composed mainly of Oligocene-Miocene brown-grey clays and Pliocene-Pleistocene grey sandy clays. The Eocene (Lower part) is represented by green clays overlying varicoloured Paleocene clays without sands. There was a thin chalk, all of Late Cretaceous age (Tor Formation). No Danian was present. The Early Cretaceous was represented by a condensed sequence ranging from Valanginian to Aptian/Albian. From 1766 m to 1993 m there was a series of transitional Early Cretaceous to Late Jurassic beds, the main part of which was presumably deposited during the Late Kimmeridgian. Darker clays with Kimmeridgian faunas were drilled from 1966 m to 2040 m, followed by black shales and sands with coal of Middle Jurassic age from 2040 m to 2082 m. The basal section was represented by red shales, siltstones, and sandstones (Gassum and Skagerrak Formations). All targets proved to be water bearing. Occasional spots of dark brown tarry oil were encountered in the Middle Jurassic sandstones in the recovered part of core 2 and in a sidewall core at 2078 m. A very weak fluorescence was observed locally from the sandstone in core 2 but there was no cut. No fluorescence or cut was seen in the sidewall cores. Organic geochemical analyses proved an immature well all through. Top oil window maturity is suggested at ca 2500 m, below TD. Source rocks are restricted to Late Jurassic shales (best in Tau and Egersund Formations), an in coals and shales of the Bryne Formation.
    Two conventional cores were cut. Core 1 was cut from 1981.2 m to 1990.3 m and core 2 from 2042.8 m to 2061.1 m. Two FIT fluid samples were taken at 2077 m and 1632 m. Both recovered salt water.
    The well was permanently abandoned on 19 August as a dry hole.
    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]
    143.26
    2194.56

  • 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
    6500.0
    6530.0
    [ft ]
    2
    6702.0
    6762.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    27.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3450.0
    [m]
    DC
    RRI
    3500.0
    [m]
    DC
    RRI
    3530.0
    [m]
    DC
    RRI
    3570.0
    [m]
    DC
    RRI
    3610.0
    [m]
    DC
    RRI
    3650.0
    [m]
    DC
    RRI
    3690.0
    [m]
    DC
    RRI
    3730.0
    [m]
    DC
    RRI
    3770.0
    [m]
    DC
    RRI
    3810.0
    [m]
    DC
    RRI
    4380.0
    [ft]
    DC
    OD
    4410.0
    [ft]
    DC
    OD
    4430.0
    [ft]
    DC
    OD
    4470.0
    [ft]
    DC
    OD
    4500.0
    [ft]
    DC
    OD
    4530.0
    [ft]
    DC
    OD
    4560.0
    [ft]
    DC
    OD
    4580.0
    [ft]
    DC
    OD
    4620.0
    [ft]
    DC
    OD
    4650.0
    [ft]
    DC
    OD
    4680.0
    [ft]
    DC
    OD
    4710.0
    [ft]
    DC
    OD
    4750.0
    [ft]
    DC
    OD
    4770.0
    [ft]
    DC
    OD
    4810.0
    [ft]
    DC
    OD
    4840.0
    [ft]
    DC
    OD
    4870.0
    [ft]
    DC
    OD
    4910.0
    [ft]
    DC
    OD
    4930.0
    [ft]
    DC
    OD
    4970.0
    [ft]
    DC
    OD
    4990.0
    [ft]
    DC
    OD
    5020.0
    [ft]
    DC
    OD
    5050.0
    [ft]
    DC
    OD
    5050.0
    [ft]
    DC
    OD
    5080.0
    [ft]
    DC
    OD
    5110.0
    [ft]
    DC
    OD
    5140.0
    [ft]
    DC
    OD
    5170.0
    [ft]
    DC
    OD
    5200.0
    [ft]
    DC
    OD
    5230.0
    [ft]
    DC
    OD
    5260.0
    [ft]
    DC
    OD
    5290.0
    [ft]
    DC
    OD
    5320.0
    [ft]
    DC
    OD
    5340.0
    [ft]
    DC
    OD
    5370.0
    [ft]
    DC
    OD
    5400.0
    [ft]
    DC
    OD
    5430.0
    [ft]
    DC
    OD
    5460.0
    [ft]
    DC
    OD
    5490.0
    [ft]
    DC
    OD
    5520.0
    [ft]
    DC
    OD
    5550.0
    [ft]
    DC
    OD
    5580.0
    [ft]
    DC
    OD
    5760.0
    [ft]
    DC
    STRATLAB
    5780.0
    [ft]
    DC
    STRATL
    5800.0
    [ft]
    DC
    STRATL
    5820.0
    [ft]
    DC
    STRATL
    5840.0
    [ft]
    DC
    STRATL
    5860.0
    [ft]
    DC
    STRATL
    5880.0
    [ft]
    DC
    STRATL
    5900.0
    [ft]
    DC
    STRATL
    5920.0
    [ft]
    DC
    STRATL
    5940.0
    [ft]
    DC
    STRATL
    5960.0
    [ft]
    DC
    STRATL
    5980.0
    [ft]
    DC
    STRATL
    6000.0
    [ft]
    DC
    STRATL
    6020.0
    [ft]
    DC
    STRATL
    6040.0
    [ft]
    DC
    STRATL
    6060.0
    [ft]
    DC
    STRATL
    6080.0
    [ft]
    DC
    STRATL
    6100.0
    [ft]
    DC
    STRATL
    6120.0
    [ft]
    DC
    STRATL
    6140.0
    [ft]
    DC
    STRATL
    6160.0
    [ft]
    DC
    STRATL
    6180.0
    [ft]
    DC
    STRATL
    6200.0
    [ft]
    DC
    STRATL
    6220.0
    [ft]
    DC
    STRATL
    6240.0
    [ft]
    DC
    STRATL
    6280.0
    [ft]
    DC
    STRATL
    6300.0
    [ft]
    DC
    STRATL
    6320.0
    [ft]
    DC
    STRATL
    6340.0
    [ft]
    DC
    STRATL
    6360.0
    [ft]
    DC
    STRATL
    6380.0
    [ft]
    DC
    STRATL
    6390.0
    [ft]
    DC
    GEUS
    6400.0
    [ft]
    DC
    STRATLAB
    6420.0
    [ft]
    DC
    STRATL
    6440.0
    [ft]
    DC
    STRATL
    6460.0
    [ft]
    DC
    STRATL
    6480.0
    [ft]
    DC
    GEUS
    6480.0
    [ft]
    DC
    STRATL
    6500.0
    [ft]
    DC
    STRATL
    6500.0
    [ft]
    DC
    GEUS
    6506.0
    [ft]
    DC
    GEUS
    6509.0
    [ft]
    DC
    GEUS
    6512.0
    [ft]
    DC
    GEUS
    6515.0
    [ft]
    DC
    GEUS
    6518.0
    [ft]
    DC
    GEUS
    6519.0
    [ft]
    DC
    OD
    6521.0
    [ft]
    DC
    GEUS
    6527.0
    [ft]
    DC
    GEUS
    6530.0
    [ft]
    DC
    GEUS
    6540.0
    [ft]
    DC
    STRATLAB
    6560.0
    [ft]
    DC
    STRATL
    6580.0
    [ft]
    DC
    STRATL
    6600.0
    [ft]
    DC
    STRATL
    6600.0
    [ft]
    DC
    OD
    6620.0
    [ft]
    DC
    STRATLAB
    6650.0
    [ft]
    DC
    STRATL
    6660.0
    [ft]
    DC
    STRATL
    6680.0
    [ft]
    DC
    STRATL
    6700.0
    [ft]
    DC
    STRATL
    6702.0
    [ft]
    DC
    STRATL
    6702.0
    [ft]
    DC
    GEUS
    6704.0
    [ft]
    DC
    GEUS
    6705.0
    [ft]
    DC
    OD
    6707.0
    [ft]
    DC
    GEUS
    6708.0
    [ft]
    DC
    STRATLAB
    6710.0
    [ft]
    DC
    GEUS
    6710.0
    [ft]
    DC
    GEUS
    6712.0
    [ft]
    DC
    GEUS
    6770.0
    [ft]
    DC
    STRATLAB
    6780.0
    [ft]
    DC
    STRATL
    6800.0
    [ft]
    DC
    STRATL
    6810.0
    [ft]
    DC
    STRATL
    6830.0
    [ft]
    DC
    OD
    6840.0
    [ft]
    DC
    STRATLAB
    6860.0
    [ft]
    DC
    STRATL
    6890.0
    [ft]
    DC
    STRATL
    6920.0
    [ft]
    DC
    STRATL
    6940.0
    [ft]
    DC
    STRATL
    6950.0
    [ft]
    DC
    STRATL
    6980.0
    [ft]
    DC
    STRATL
    7000.0
    [ft]
    DC
    STRATL
    7020.0
    [ft]
    DC
    STRATL
    7050.0
    [ft]
    DC
    STRATL
    7080.0
    [ft]
    DC
    STRATL
    7100.0
    [ft]
    DC
    STRATL
    7120.0
    [ft]
    DC
    STRATL
    7140.0
    [ft]
    DC
    STRATL
    7180.0
    [ft]
    DC
    STRATL
    7200.0
    [ft]
    DC
    STRATL

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.28

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.93
    pdf
    0.96

  • 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
    6.77
    pdf
    2.31
    pdf
    0.71

  • Documents – Norwegian Offshore Directorate papers
    Documents – Norwegian Offshore Directorate papers
    Document name
    Document format
    Document size [MB]
    pdf
    33.18
    pdf
    0.60
    pdf
    0.47

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    394
    2194
    FDC
    745
    2196
    GR
    91
    394
    HDT
    1589
    2196
    IES
    394
    2196
    PROX MI
    745
    2196
    SNP
    745
    1605

  • 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
    127.0
    36
    127.0
    0.00
    LOT
    INTERM.
    20
    394.0
    26
    411.0
    0.00
    LOT
    INTERM.
    13 3/8
    745.0
    17 1/2
    771.0
    0.00
    LOT
    INTERM.
    9 5/8
    1589.0
    12 1/4
    1605.0
    0.00
    LOT
    OPEN HOLE
    2196.0
    8 1/2
    2196.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    127
    1.33
    50.0
    waterbased
    411
    1.19
    44.0
    waterbased
    1051
    1.43
    48.0
    waterbased
    1584
    1.61
    50.0
    waterbased
    1752
    1.50
    50.0
    waterbased
    2194
    1.49
    52.0
    waterbased

  • 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