Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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16/4-2

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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.
    16/4-2
    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
    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.
    16/4-2
    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.
    Norsk Hydro Produksjon 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.
    639-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.
    31
    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,
    29.06.1990
    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.
    29.07.1990
    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.
    29.07.1992
    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.
    27.02.2004
    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
    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.
    93.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3117.0
    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).
    3117.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    115
    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.
    INTRA DRAUPNE FM SS
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 35' 47.17'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 48.03'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6495672.61
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    443619.47
    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.
    1560

  • Wellbore history
    General
    Well 16/4-2 was the second well on the block and last commitment well for license 087. The well is located in a central position on the structure, close to the western border of the block. The main target was sands of Middle Eocene age supposed to be present within a mounded seismic sequence that constitutes the eastern part of the Alpha prospect in the Sleipner Field. The primary objective of the well was to prove oil in the Eocene sandstones. Secondary objectives were to confirm the seismic interpretation and the geological model for the Eocene sand; to test a possible small closure at top Heimdal Formation level; to obtain additional information on migration paths in the area; to confirm the seismic interpretation of the basal Cretaceous/ Late Jurassic sequence; and to test the hydrocarbon potential of possible Late Jurassic sand accumulations. Shallow gas could be expected at 537 m. This corresponds to the level of the blowout in well 16/4-1. A possible shallow gas content could occur in a thin sand layer at 685 m, which was correlated from well 16/4-1.
    Operations and results
    Wildcat well 16/4-2 was spudded with the semi-submersible installation Vildkat Explorer 29 June 1990 and drilled to 3117 m in Intra Draupne Formation sandstones. No shallow gas was encountered in the well; the gas zones were drilled with riser and mud weight 1.22 rd to control the gas. The well was drilled with seawater and hi-vis pills down to 1710 m and with KCl Polymer mud from 1710 m to TD. Drilling went without any significant problems apart from the 13 3/8" casing getting stuck at 1450 m. To resolve this problem diesel EZ pills were used in the well bore. This affected gas readings throughout the well below 1710 m and gave some spuriously high readings. The 13 3/8" casing shoe was finally set at 1683 m, and the casing cemented. The Eocene Grid formation sandstone came in at 1913 m, approximately 88 m deeper than prognosed. No hydrocarbons were recorded. The Heimdal formation sandstone came in at 2415 m, approximately 110 m deeper than prognosed. No hydrocarbons were recorded. Late Jurassic sands (Intra Draupne Formation) were also developed, but no hydrocarbons were recorded. The only hydrocarbons observed were some weak shows in claystones of the Draupne Formation. One core was cut in the interval from 1920 to 1927 m in the Grid Formation with 88.6 % recovery. A total of 60 sidewall cores were attempted in one run from 1750 to 3113 m, whereof 50 were recovered. No fluid samples were taken. The well was permanently plugged and abandoned 29 July 1990 as a dry well.
    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]
    490.00
    3117.00

  • 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
    1920.0
    1926.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    6.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1920-1924m
    Core photo at depth: 1924-1926m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    1920-1924m
    1924-1926m

  • 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
    205.0
    36
    206.0
    0.00
    LOT
    INTERM.
    18 5/8
    479.0
    24
    485.0
    1.86
    LOT
    INTERM.
    13 3/8
    1683.0
    17 1/2
    1710.0
    1.90
    LOT
    OPEN HOLE
    3117.0
    12 1/4
    3117.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    963
    1680
    CST GR
    1715
    3113
    DIL LSS LDL CNL NGT SP AMS
    1685
    3112
    DIL LSS LDL SP GR AMS
    478
    1708
    MWD - GR RES DIR
    118
    3117
    RFT GR
    1920
    3111
    SHDT GR
    1685
    3114
    VSP
    1000
    3110

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.51

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.48

  • 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
    1.74
    pdf
    11.13

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    160
    1.00
    1.0
    1.0
    WATER BASED
    30.07.1990
    191
    1.20
    WATER BASED
    02.07.1990
    206
    1.20
    WATER BASED
    02.07.1990
    485
    1.20
    WATER BASED
    02.07.1990
    485
    1.20
    WATER BASED
    03.07.1990
    485
    1.20
    WATER BASED
    04.07.1990
    514
    1.24
    13.0
    6.0
    WATER BASED
    05.07.1990
    914
    1.22
    11.0
    10.0
    WATER BASED
    09.07.1990
    1286
    1.21
    15.0
    12.0
    WATER BASED
    09.07.1990
    1446
    1.20
    15.0
    9.0
    WATER BASED
    09.07.1990
    1557
    1.30
    WATER BASED
    26.07.1990
    1557
    1.30
    WATER BASED
    27.07.1990
    1583
    1.23
    17.0
    10.0
    WATER BASED
    09.07.1990
    1710
    1.25
    19.0
    9.0
    WATER BASED
    10.07.1990
    1710
    1.33
    18.0
    10.0
    WATER BASED
    11.07.1990
    1710
    1.31
    14.0
    6.0
    WATER BASED
    12.07.1990
    1710
    1.18
    5.0
    5.0
    WATER BASED
    13.07.1990
    1710
    1.18
    6.0
    5.0
    WATER BASED
    16.07.1990
    1800
    1.31
    WATER BASED
    25.07.1990
    1927
    1.27
    17.0
    8.0
    WATER BASED
    16.07.1990
    2234
    1.27
    15.0
    10.0
    WATER BASED
    17.07.1990
    2445
    1.28
    18.0
    9.0
    WATER BASED
    18.07.1990
    2600
    1.28
    17.0
    8.0
    WATER BASED
    19.07.1990
    2826
    1.31
    14.0
    8.0
    WATER BASED
    20.07.1990
    3015
    1.30
    16.0
    8.0
    WATER BASED
    23.07.1990
    3073
    1.31
    20.0
    10.0
    WATER BASED
    23.07.1990
    3117
    1.31
    16.0
    10.0
    WATER BASED
    23.07.1990
    3117
    1.31
    16.0
    10.0
    WATER BASED
    24.07.1990

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1200.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1715.0
    [m]
    SWC
    HYDRO
    1735.0
    [m]
    SWC
    HYDRO
    1750.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1814.0
    [m]
    SWC
    HYDRO
    1820.0
    [m]
    DC
    RRI
    1850.0
    [m]
    SWC
    HYDRO
    1860.0
    [m]
    SWC
    HYDRO
    1870.0
    [m]
    SWC
    HYDRO
    1880.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    SWC
    HYDRO
    1920.1
    [m]
    C
    HYDRO
    1922.5
    [m]
    C
    HYDRO
    1924.7
    [m]
    C
    HYDRO
    1925.7
    [m]
    C
    HYDRO
    1926.2
    [m]
    C
    HYDRO
    1930.0
    [m]
    SWC
    HYDRO
    1962.0
    [m]
    DC
    RRI
    1975.0
    [m]
    DC
    RRI
    1988.0
    [m]
    SWC
    HYDRO
    2005.0
    [m]
    SWC
    HYDRO
    2070.0
    [m]
    SWC
    HYDRO
    2100.0
    [m]
    SWC
    HYDRO
    2122.0
    [m]
    DC
    RRI
    2152.0
    [m]
    DC
    RRI
    2210.0
    [m]
    SWC
    HYDRO
    2230.0
    [m]
    DC
    RRI
    2275.0
    [m]
    SWC
    HYDRO
    2295.0
    [m]
    SWC
    HYDRO
    2320.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2403.0
    [m]
    SWC
    HYDRO
    2412.0
    [m]
    SWC
    HYDRO
    2455.0
    [m]
    SWC
    HYDRO
    2531.0
    [m]
    SWC
    HYDRO
    2562.0
    [m]
    SWC
    HYDRO
    2580.0
    [m]
    SWC
    HYDRO
    2584.0
    [m]
    SWC
    HYDRO
    2603.0
    [m]
    SWC
    HYDRO
    2633.0
    [m]
    SWC
    HYDRO
    2804.0
    [m]
    SWC
    HYDRO
    2851.0
    [m]
    SWC
    HYDRO
    2880.0
    [m]
    SWC
    HYDRO
    2891.0
    [m]
    SWC
    HYDRO
    2930.0
    [m]
    SWC
    HYDRO
    2965.0
    [m]
    SWC
    HYDRO
    2975.0
    [m]
    SWC
    HYDRO
    2990.0
    [m]
    SWC
    HYDRO
    3030.0
    [m]
    SWC
    HYDRO
    3050.0
    [m]
    SWC
    HYDRO
    3060.0
    [m]
    SWC
    HYDRO
    3068.0
    [m]
    SWC
    HYDRO
    3080.0
    [m]
    SWC
    HYDRO
    3100.0
    [m]
    SWC
    HYDRO
    3110.0
    [m]
    DC
    RRI
    3112.0
    [m]
    SWC
    HYDRO
    3113.0
    [m]
    SWC
    HYDRO
    3117.0
    [m]
    DC
    RRI