Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/6-6

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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.
    15/6-6
    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
    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
    Field
    Name of the field the wellbore is related to.
    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.
    15/6-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8010 - 118 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.
    Esso Exploration and Production Norway A/S
    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.
    308-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.
    70
    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,
    01.04.1982
    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.
    09.06.1982
    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.
    09.06.1984
    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.
    19.12.2007
    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.
    GAS/CONDENSATE
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    110.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3760.0
    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).
    3760.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    122
    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 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.
    58° 31' 14.7'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 44' 53.3'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6487517.21
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    427079.83
    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.
    38

  • Wellbore history
    General
    Well 15/6-6 was drilled to appraise the north eastern flank of Alpha structure on the 15/6-3 Sleipner Vest Discovery in the North Sea. The primary target was a gas bearing Jurassic sandstone known as the Hugin Formation. It was drilled to provide needed structural control and to establish a gas/water contact.
    Operations and results
    Appraisal well 15/6-6 was spudded with the semi-submersible installation Glomar Biscay II on 1 April 1982 and drilled to TD at 3760 m in Late Triassic sediments of the Skagerrak Formation. The 36" hole had to be reamed several times due to ledging. This also occurred in the top of the 26" section. Forty-six bbl's (7.3 m3) of fluid were lost to the formation during cementing of the 13 3/8" casing. The mud weight in this section was 1.68 which is lower than the previous Sleipner wells. This and the fluid loss can possibly be related to an unconsolidated sand (Skade Formation) interval from 1185 to 1199 m. Minor hole problems were encountered in the 12 1/4" section. The drill string was temporarily stuck at 1627 m after making a connection. The well was drilled with seawater and gel.
    The well proved sands in the Utsira, Grid, Heimdal, and Sleipner Formations; all water bearing. The gas bearing Hugin Formation was encountered at 3563 m and had a gross thickness of 58 m. The gas/water contact was found at 3607 m, which gives a gross gas interval of 44 m. No oil shows were reported from the target reservoir or other sections in the well.
    Three cores were taken in the Middle Jurassic interval in the 8 1/2" section. Core 1 recovered 18.5 m sandstone from 3591 m to 3609.5 m. Core 2 recovered 16.0 m sandstone from 3609.5 m to 3622 m. Core 3 recovered 18.9 m Sandstone, shale and coal from 3625.5 m to 3644.5 m. No wire line fluid sample was taken.
    The well was permanently abandoned on 9 June 1982 as a gas appraisal well.
    Testing
    The well was tested in the interval 3568 - 3578 m in the Hugin Formation where reservoir data indicated significant accumulations of gas and condensate. The test produced 835000 Sm3 gas and 278 Sm3 condensate /day through a 56/64" choke. The GOR (gas/condensate ratio) was 3003 Sm3/Sm3 and the condensate gravity was 47 dg API. The gas gravity was 0.762 (air = 1), the CO2 content was 5 % and the H2S content was 7.5 ppm.

  • 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]
    210.00
    3760.00

  • 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
    3591.0
    3609.5
    [m ]
    2
    3609.5
    3625.5
    [m ]
    3
    3625.5
    3644.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.4
    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
    500.0
    [m]
    DC
    530.0
    [m]
    DC
    560.0
    [m]
    DC
    590.0
    [m]
    DC
    620.0
    [m]
    DC
    650.0
    [m]
    DC
    690.0
    [m]
    DC
    710.0
    [m]
    DC
    740.0
    [m]
    DC
    770.0
    [m]
    DC
    800.0
    [m]
    DC
    830.0
    [m]
    DC
    860.0
    [m]
    DC
    890.0
    [m]
    DC
    920.0
    [m]
    DC
    950.0
    [m]
    DC
    980.0
    [m]
    DC
    1010.0
    [m]
    DC
    1040.0
    [m]
    DC
    1070.0
    [m]
    DC
    1100.0
    [m]
    DC
    1130.0
    [m]
    DC
    1160.0
    [m]
    DC
    1190.0
    [m]
    DC
    1220.0
    [m]
    DC
    1250.0
    [m]
    DC
    1280.0
    [m]
    DC
    1310.0
    [m]
    DC
    1340.0
    [m]
    DC
    1370.0
    [m]
    DC
    1400.0
    [m]
    DC
    1430.0
    [m]
    DC
    1460.0
    [m]
    DC
    1490.0
    [m]
    DC
    1520.0
    [m]
    DC
    1550.0
    [m]
    DC
    1580.0
    [m]
    DC
    1610.0
    [m]
    DC
    1640.0
    [m]
    DC
    1670.0
    [m]
    DC
    1700.0
    [m]
    DC
    1730.0
    [m]
    DC
    1760.0
    [m]
    DC
    1790.0
    [m]
    DC
    1820.0
    [m]
    DC
    1850.0
    [m]
    DC
    1880.0
    [m]
    DC
    1910.0
    [m]
    DC
    1940.0
    [m]
    DC
    1970.0
    [m]
    DC
    2000.0
    [m]
    DC
    2030.0
    [m]
    DC
    2060.0
    [m]
    DC
    2090.0
    [m]
    DC
    2120.0
    [m]
    DC
    2150.0
    [m]
    DC
    2180.0
    [m]
    DC
    2210.0
    [m]
    DC
    2220.0
    [m]
    DC
    2230.0
    [m]
    DC
    2240.0
    [m]
    DC
    2250.0
    [m]
    DC
    2260.0
    [m]
    DC
    2270.0
    [m]
    DC
    2280.0
    [m]
    DC
    2290.0
    [m]
    DC
    2300.0
    [m]
    DC
    2310.0
    [m]
    DC
    2320.0
    [m]
    DC
    2330.0
    [m]
    DC
    2340.0
    [m]
    DC
    2350.0
    [m]
    DC
    2360.0
    [m]
    DC
    2370.0
    [m]
    DC
    2390.0
    [m]
    DC
    2400.0
    [m]
    DC
    2410.0
    [m]
    DC
    2420.0
    [m]
    DC
    2430.0
    [m]
    DC
    2440.0
    [m]
    DC
    2450.0
    [m]
    DC
    2460.0
    [m]
    DC
    2480.0
    [m]
    DC
    2500.0
    [m]
    DC
    2510.0
    [m]
    DC
    2540.0
    [m]
    DC
    2570.0
    [m]
    DC
    2600.0
    [m]
    DC
    2630.0
    [m]
    DC
    2660.0
    [m]
    DC
    2690.0
    [m]
    DC
    2720.0
    [m]
    DC
    2730.0
    [m]
    DC
    2740.0
    [m]
    DC
    2750.0
    [m]
    DC
    2760.0
    [m]
    DC
    2770.0
    [m]
    DC
    2780.0
    [m]
    DC
    2810.0
    [m]
    DC
    2840.0
    [m]
    DC
    2870.0
    [m]
    DC
    2900.0
    [m]
    DC
    2930.0
    [m]
    DC
    2960.0
    [m]
    DC
    2990.0
    [m]
    DC
    3020.0
    [m]
    DC
    3050.0
    [m]
    DC
    3080.0
    [m]
    DC
    3110.0
    [m]
    DC
    3140.0
    [m]
    DC
    3170.0
    [m]
    DC
    3200.0
    [m]
    DC
    3230.0
    [m]
    DC
    3260.0
    [m]
    DC
    3290.0
    [m]
    DC
    3320.0
    [m]
    DC
    3350.0
    [m]
    DC
    3380.0
    [m]
    DC
    3401.0
    [m]
    SWC
    3403.0
    [m]
    SWC
    3407.0
    [m]
    SWC
    3409.0
    [m]
    DC
    3410.0
    [m]
    SWC
    3427.0
    [m]
    SWC
    3436.5
    [m]
    SWC
    3451.0
    [m]
    DC
    3462.0
    [m]
    SWC
    3481.0
    [m]
    DC
    3482.0
    [m]
    SWC
    3492.0
    [m]
    SWC
    3495.0
    [m]
    SWC
    3499.0
    [m]
    SWC
    3511.0
    [m]
    DC
    3516.0
    [m]
    SWC
    3524.0
    [m]
    SWC
    3541.0
    [m]
    DC
    3543.0
    [m]
    SWC
    3548.0
    [m]
    SWC
    3554.5
    [m]
    SWC
    3556.0
    [m]
    SWC
    3558.0
    [m]
    SWC
    3562.0
    [m]
    SWC
    3571.0
    [m]
    DC
    3601.0
    [m]
    DC
    3631.0
    [m]
    DC
    3648.2
    [m]
    SWC
    3655.0
    [m]
    DC
    3659.2
    [m]
    SWC
    3661.0
    [m]
    DC
    3664.0
    [m]
    DC
    3691.0
    [m]
    DC
    3702.0
    [m]
    SWC
    3721.0
    [m]
    DC
    3740.0
    [m]
    SWC
    3751.0
    [m]
    DC

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.78

  • 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
    34.77

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3568
    3578
    22.2
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    278
    835000
    0.793
    0.762
    3003

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AC CBL
    2446
    3630
    CALIPER
    160
    424
    CDL CNL GR
    2763
    3754
    DIPLOG
    2773
    3749
    DLL MLL
    3500
    3750
    IEL BHC AC GR SP
    190
    3753
    TEMP
    195
    1174
    TEMP
    1500
    2754
    TEMP
    3569
    3716
    VSP
    1800
    3748

  • 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
    196.0
    36
    197.0
    0.00
    LOT
    SURF.COND.
    20
    447.0
    26
    465.0
    1.54
    LOT
    INTERM.
    13 3/8
    1203.0
    17 1/2
    1218.0
    1.67
    LOT
    INTERM.
    9 5/8
    2778.0
    12 1/4
    2794.0
    1.72
    LOT
    LINER
    7
    3686.0
    8 1/2
    3760.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    380
    1.08
    41.0
    waterbased
    720
    1.10
    40.0
    waterbased
    1360
    1.12
    49.0
    waterbased
    2420
    1.16
    51.0
    waterbased
    3290
    1.34
    48.0
    waterbased
    3440
    1.34
    47.0
    waterbased
    3610
    1.36
    42.0
    waterbased
    3660
    1.34
    47.0
    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
    0.23