Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
10.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/3-11

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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.
    15/3-11
    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
    Press release
    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.
    15/3-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST09M10-FULL-OFFSET-DISPSCAN-FORMATION. inline 2456 Xline 3069
    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.
    Equinor Energy 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.
    1705-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.
    51
    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,
    14.06.2018
    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.
    09.08.2018
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    09.08.2018
    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.
    09.08.2020
    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.
    09.08.2020
    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.
    APPRAISAL
    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.
    NO
    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.
    MIDDLE JURASSIC
    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.
    HUGIN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    108.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4014.0
    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).
    4014.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    132
    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.
    MIDDLE 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.
    SLEIPNER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 49' 8.09'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 52' 2.41'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6520591.41
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    434583.21
    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.
    8489

  • Wellbore history
    General
    Well 15/3-11 is the replacement well for 15/3-10, which was junked for technical reasons. It was drilled to appraise the 15/3-4 Sigrun discovery on the Gudrun Terrace in the North Sea. The target formation was located to the west and down dip of the original discovery well 15/3-4. The main objective was to prove more resources than already proven in the Middle Jurassic Hugin Formation in the 15/3-4 discovery well.
    Operations and results
    Appraisal well 15/3-11 was spudded with the semi-submersible installation Deepsea Bergen on 14 June 2018 and drilled to TD at 4014 m in the Middle Jurassic Sleipner Formation. Operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 1000 m, with KCl/polymer/GEM mud from 1000 m to 2350 m, with Enviromul oil-based mud from 2350 m to 3660 m, and with BaraECD oil-based mud from 3660 m to TD.
    The target Hugin formation was penetrated from 3856 to 3959 m. The reservoir consisted of interbedded sandstones and claystone with a few thin coal layers. It was oil filled in the upper sands, whereas the deeper sands were water-bearing. The fluids are the same volatile oils as were encountered in 15/3-4. Like the previously drilled wells, 15/3-4 and 15/3-5, did the 15/3-11 well encounter oil-down-to (ODT) situations. Pressure data show a complex reservoir with two different oil gradients and three different water gradients. In the well site cuttings descriptions shows are described in the Draupne Formation from 3744 to 3798 m (direct and cut fluorescence but no visible oil stain). In the core description oil shows are described in the Hugin reservoir sandstones down to 3930 (typically direct and cut fluorescence with visible stain), and with weaker shows in a few samples around a coal layer at 3959 m. No other zones with shows are reported.
    Two cores were cut in succession from3868 to 3975 m with 99.3% and 94% recovery, respectively. MDT fluid samples were taken at 3857.7 m (oil), 3888.46 m (oil) and 3927.5 m (water). The oil samples proved undersaturated volatile oil with small variations in GOR.
    The well was permanently abandoned on 9 August 2018 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]
    2330.00
    4014.00

  • 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
    3868.0
    3934.6
    [m ]
    2
    3935.0
    3968.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    99.5
    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
    2330.0
    [m]
    DC
    PETROSTR
    2340.0
    [m]
    DC
    PETROS
    2350.0
    [m]
    DC
    PETROS
    2360.0
    [m]
    DC
    PETROS
    2370.0
    [m]
    DC
    PETROS
    2380.0
    [m]
    DC
    PETROS
    2390.0
    [m]
    DC
    PETROS
    2400.0
    [m]
    DC
    PETROS
    2410.0
    [m]
    DC
    PETROS
    2420.0
    [m]
    DC
    PETROS
    2430.0
    [m]
    DC
    PETROS
    2440.0
    [m]
    DC
    PETROS
    2450.0
    [m]
    DC
    PETROS
    2460.0
    [m]
    DC
    PETROS
    2470.0
    [m]
    DC
    PETROS
    2480.0
    [m]
    DC
    PETROS
    2490.0
    [m]
    DC
    PETROS
    2500.0
    [m]
    DC
    PETROS
    2510.0
    [m]
    DC
    PETROS
    2520.0
    [m]
    DC
    PETROS
    2530.0
    [m]
    DC
    PETROS
    2540.0
    [m]
    DC
    PETROS
    2550.0
    [m]
    DC
    PETROS
    2560.0
    [m]
    DC
    PETROS
    2570.0
    [m]
    DC
    PETROS
    2580.0
    [m]
    DC
    PETROS
    2590.0
    [m]
    DC
    PETROS
    2600.0
    [m]
    DC
    PETROS
    2610.0
    [m]
    DC
    PETROS
    2620.0
    [m]
    DC
    PETROS
    2630.0
    [m]
    DC
    PETROS
    2640.0
    [m]
    DC
    PETROS
    2650.0
    [m]
    DC
    PETROS
    2660.0
    [m]
    DC
    PETROS
    2670.0
    [m]
    DC
    PETROS
    2680.0
    [m]
    DC
    PETROS
    2690.0
    [m]
    DC
    PETROS
    2700.0
    [m]
    DC
    PETROS
    2710.0
    [m]
    DC
    PETROS
    2720.0
    [m]
    DC
    PETROS
    2730.0
    [m]
    DC
    PETROS
    2740.0
    [m]
    DC
    PETROS
    2750.0
    [m]
    DC
    PETROS
    2760.0
    [m]
    DC
    PETROS
    2770.0
    [m]
    DC
    PETROS
    2780.0
    [m]
    DC
    PETROS
    2790.0
    [m]
    DC
    PETROS
    2800.0
    [m]
    DC
    PETROS
    3690.0
    [m]
    DC
    PETROS
    3699.0
    [m]
    DC
    PETROS
    3708.0
    [m]
    DC
    PETROS
    3717.0
    [m]
    DC
    PETROS
    3726.0
    [m]
    DC
    PETROS
    3735.0
    [m]
    DC
    PETROS
    3744.0
    [m]
    DC
    PETROS
    3753.0
    [m]
    DC
    PETROS
    3762.0
    [m]
    DC
    PETROS
    3771.0
    [m]
    DC
    PETROS
    3780.0
    [m]
    DC
    PETROS
    3783.0
    [m]
    DC
    PETROS
    3786.0
    [m]
    DC
    PETROS
    3789.0
    [m]
    DC
    PETROS
    3792.0
    [m]
    DC
    PETROS
    3795.0
    [m]
    DC
    PETROS
    3798.0
    [m]
    DC
    PETROS
    3801.0
    [m]
    DC
    PETROS
    3804.0
    [m]
    DC
    PETROS
    3807.0
    [m]
    DC
    PETROS
    3810.0
    [m]
    DC
    PETROS
    3813.0
    [m]
    DC
    PETROS
    3816.0
    [m]
    DC
    PETROS
    3819.0
    [m]
    DC
    PETROS
    3822.0
    [m]
    DC
    PETROS
    3825.0
    [m]
    DC
    PETROS
    3834.0
    [m]
    DC
    PETROS
    3843.0
    [m]
    DC
    PETROS
    3852.0
    [m]
    DC
    PETROS
    3855.0
    [m]
    DC
    PETROS
    3858.0
    [m]
    DC
    PETROS
    3861.0
    [m]
    DC
    PETROS
    3864.0
    [m]
    DC
    PETROS
    3867.0
    [m]
    DC
    PETROS
    3868.5
    [m]
    C
    PETROS
    3870.0
    [m]
    DC
    PETROS
    3870.2
    [m]
    C
    PETROS
    3872.3
    [m]
    C
    PETROS
    3875.9
    [m]
    C
    PETROS
    3877.0
    [m]
    C
    PETROS
    3879.9
    [m]
    C
    PETROS
    3881.8
    [m]
    C
    PETROS
    3882.5
    [m]
    C
    PETROS
    3886.2
    [m]
    C
    PETROS
    3889.6
    [m]
    C
    PETROS
    3893.5
    [m]
    C
    PETROS
    3896.6
    [m]
    C
    PETROS
    3899.3
    [m]
    C
    PETROS
    3901.5
    [m]
    C
    PETROS
    3904.1
    [m]
    C
    PETROS
    3909.3
    [m]
    C
    PETROS
    3912.7
    [m]
    C
    PETROS
    3915.7
    [m]
    C
    PETROS
    3918.7
    [m]
    C
    PETROS
    3920.6
    [m]
    C
    PETROS
    3922.6
    [m]
    C
    PETROS
    3925.7
    [m]
    C
    PETROS
    3930.9
    [m]
    C
    PETROS
    3931.5
    [m]
    C
    PETROS
    3934.6
    [m]
    C
    PETROS
    3936.7
    [m]
    C
    PETROS
    3939.7
    [m]
    C
    PETROS
    3943.9
    [m]
    C
    PETROS
    3946.6
    [m]
    C
    PETROS
    3949.6
    [m]
    C
    PETROS
    3952.5
    [m]
    C
    PETROS
    3954.4
    [m]
    C
    PETROS
    3956.6
    [m]
    C
    PETROS
    3957.5
    [m]
    C
    PETROS
    3960.9
    [m]
    C
    PETROS
    3962.2
    [m]
    C
    PETROS
    3964.6
    [m]
    C
    PETROS
    3967.2
    [m]
    C
    PETROS
    3969.0
    [m]
    DC
    PETROS
    3978.0
    [m]
    DC
    PETROS
    3987.0
    [m]
    DC
    PETROS
    3996.0
    [m]
    DC
    PETROS
    4005.0
    [m]
    DC
    PETROS
    4014.0
    [m]
    DC
    PETROS

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX XPT SON IC SCA NGI
    2770
    4014
    MWD LWD - GR RES DIR
    182
    4014

  • 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
    182.0
    36
    182.0
    0.00
    SURF.COND.
    20
    955.0
    26
    962.0
    1.50
    LOT
    INTERM.
    14
    2320.0
    17 1/2
    2328.0
    1.66
    FIT
    INTERM.
    9 7/8
    3663.0
    12 1/4
    3666.0
    2.00
    FIT
    OPEN HOLE
    4014.0
    8 1/2
    4014.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    558
    1.38
    14.0
    KCl/Polymer/GEM
    962
    1.36
    9.0
    KCl/Polymer/GEM
    962
    1.30
    11.0
    KCl/Polymer/GEM
    1155
    1.35
    14.0
    KCl/Polymer/GEM
    1835
    1.36
    18.0
    KCl/Polymer/GEM
    2124
    1.37
    18.0
    KCl/Polymer/GEM
    2328
    1.25
    25.0
    Enviromul
    2328
    1.37
    20.0
    KCl/Polymer/GEM
    2653
    1.26
    28.0
    Enviromul
    2779
    1.25
    26.0
    Enviromul
    3075
    1.26
    23.0
    Enviromul
    3114
    1.38
    17.0
    KCl/Polymer/GEM
    3114
    1.75
    34.0
    BaraECD
    3164
    1.26
    25.0
    Enviromul
    3380
    1.30
    25.0
    Enviromul
    3426
    1.33
    25.0
    Enviromul
    3467
    1.37
    26.0
    Enviromul
    3688
    1.75
    31.0
    BaraECD
    3970
    1.78
    36.0
    BaraECD
    4014
    1.75
    36.0
    BaraECD