Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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26.11.2024 - 01:27
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17/11-1

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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.
    17/11-1
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    17/11-1
    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.
    A/S Norske Shell
    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.
    13-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.
    38
    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,
    24.05.1968
    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.
    30.06.1968
    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.
    30.06.1970
    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
    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.
    27.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    75.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3269.0
    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).
    3269.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.25
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    83
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 12' 36'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 20' 34.9'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6452288.88
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    520158.20
    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.
    906

  • Wellbore history
    General
    Well 17/11-1 was drilled close to the western edge of the Sele High in the North Sea. The original objective to test the Tertiary and Mesozoic sequences, was extended to penetrate the Zechstein salt and investigate the underlying formations. This latter could not be reached due to drilling difficulties in the salt.
    Operations and results
    Wildcat well 17/11-1 was spudded with the jack-up installation Orion on 24 May 1968 and drilled to TD at 3269 m in the Late Permian Zechstein Group. When logging at 1173 m the logging tool got stuck in the "gumbo" section and an inflow of 2 - 5 bbl/hr of salt water occurred. Several of the tools failed to reach the bottom, among these the gamma-ray/sonic logging tool. Therefore a laterolog is included on the final composite log in the interval 1017-1158 m. The pipe stuck when drilling in potassium and magnesium salt (carnallite). Efforts to free the pipe by jarring and spotting Pipelax were unsuccessful. After working the stuck pipe for 19 hours the drill string parted, leaving a bit and junk sub in the hole. An unsuccessful attempt was made to jar the fish free. It was then decided that further efforts to drill to the base of the salt could not be justified. The well was drilled with seawater down to 166 m, a Spersene/XP-20 mud system from 166 m to 2539 m, converting to a salt-saturated mud from 2539 m through salt to TD.
    Shetland Group chalk (Ekofisk Formation) came in at 1020 m. Top Cretaceous is set at 1040 m where Tor and Hod chalks extend down to 1447 m. Porosities in the chalks were estimated between 15 % to 25%. At 1447 m 63 m of Ran Sandstone Units were penetrated. The remaining Early Cretaceous consisted of mudstones. The Boknfjord Group was encountered at 2083 m, with shales extending down to 2211 m. These shales rest directly on Triassic sediments. The Skagerrak Formation from 2211 m to 2315 m consisted of claystone with sand and siltsone stringers. The sandstone stringers were generally less than 2 m thick with 20 - 30 % estimated porosity. The Smith Bank Formation is set at 2315 m to 2517 m. From 2517 m to 2538 m anhydrite was present. Below 2538 m massive salt is shown on the logs with occasional beds of anhydrite and claystone. Between 3205 m and 3269 low density beds indicate carnallite interbedded with the normal halite. There were no hydrocarbon indications in the well.
    Conventional cores were not cut. A total of 41 sidewall cores were taken from 427 m to 3226 m. No fluid samples were taken.
    The well was permanently abandoned on 30 June 1968 as 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]
    170.69
    3267.46

  • 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
    166.0
    36
    170.0
    0.00
    LOT
    SURF.COND.
    20
    413.0
    26
    419.0
    0.00
    LOT
    INTERM.
    13 3/8
    1170.0
    17 1/2
    1177.0
    0.00
    LOT
    OPEN HOLE
    3270.0
    12 1/4
    3270.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CAL
    165
    415
    CBL
    1068
    1158
    CDM
    1155
    3244
    FDC
    415
    3244
    IES
    166
    2196
    LL
    415
    3246
    MLL-C
    415
    3244
    SGR
    165
    2194
    SGR-C
    2165
    3244
    SNP
    415
    3244
    SRS
    121
    3244
    TS
    0
    442

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.49

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.28

  • 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
    8.44
    pdf
    1.50

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    152
    1.01
    seawater
    419
    1.04
    90.0
    waterbased
    1173
    1.17
    36.0
    waterbased
    2195
    1.24
    42.0
    waterbased
    2540
    1.24
    58.0
    waterbased
    2681
    1.34
    65.0
    waterbased
    3269
    1.37
    53.0
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    5500.0
    [ft]
    DC
    RRI
    5540.0
    [ft]
    DC
    RRI
    5580.0
    [ft]
    DC
    RRI
    5620.0
    [ft]
    DC
    RRI
    5660.0
    [ft]
    DC
    RRI
    5700.0
    [ft]
    DC
    RRI
    5740.0
    [ft]
    DC
    RRI
    5780.0
    [ft]
    DC
    RRI
    5820.0
    [ft]
    DC
    RRI
    5860.0
    [ft]
    DC
    RRI
    5900.0
    [ft]
    DC
    RRI
    5940.0
    [ft]
    DC
    RRI
    5980.0
    [ft]
    DC
    RRI
    6000.0
    [ft]
    DC
    6020.0
    [ft]
    DC
    RRI
    6060.0
    [ft]
    DC
    RRI
    6100.0
    [ft]
    DC
    RRI
    6100.0
    [ft]
    DC
    6140.0
    [ft]
    DC
    RRI
    6180.0
    [ft]
    DC
    RRI
    6200.0
    [ft]
    DC
    6230.0
    [ft]
    DC
    RRI
    6260.0
    [ft]
    DC
    RRI
    6290.0
    [ft]
    DC
    6305.0
    [ft]
    DC
    RRI
    6335.0
    [ft]
    DC
    RRI
    6380.0
    [ft]
    DC
    RRI
    6395.0
    [ft]
    DC
    6410.0
    [ft]
    DC
    RRI
    6470.0
    [ft]
    DC
    RRI
    6500.0
    [ft]
    DC
    RRI
    6500.0
    [ft]
    DC
    6540.0
    [ft]
    DC
    RRI
    6590.0
    [ft]
    DC
    RRI
    6600.0
    [ft]
    DC
    6620.0
    [ft]
    DC
    RRI
    6660.0
    [ft]
    DC
    RRI
    6690.0
    [ft]
    DC
    6700.0
    [ft]
    DC
    RRI
    6740.0
    [ft]
    DC
    RRI
    6780.0
    [ft]
    DC
    RRI
    6800.0
    [ft]
    DC
    6820.0
    [ft]
    DC
    RRI
    6840.0
    [ft]
    DC
    RRI
    6880.0
    [ft]
    DC
    RRI
    6900.0
    [ft]
    DC
    6920.0
    [ft]
    DC
    RRI
    6960.0
    [ft]
    DC
    RRI
    7000.0
    [ft]
    DC
    RRI
    7000.0
    [ft]
    DC
    7040.0
    [ft]
    DC
    RRI
    7080.0
    [ft]
    DC
    RRI
    7100.0
    [ft]
    DC
    7120.0
    [ft]
    DC
    RRI
    7140.0
    [ft]
    DC
    RRI
    7180.0
    [ft]
    DC
    RRI
    7200.0
    [ft]
    DC
    7220.0
    [ft]
    DC
    RRI
    7260.0
    [ft]
    DC
    RRI
    7300.0
    [ft]
    DC
    7400.0
    [ft]
    DC
    7500.0
    [ft]
    DC
    7600.0
    [ft]
    DC
    7700.0
    [ft]
    DC