Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.07.2024 - 01:26
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15/6-5

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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.
    15/6-5
    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.
    15/6-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    line 175 Shot point 310
    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.
    185-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,
    10.10.1977
    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.
    29.11.1977
    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.
    29.11.1979
    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.
    28.03.2014
    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.
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    108.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3824.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    109
    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.
    NO GROUP DEFINED
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 30' 29.87'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 45' 50.74'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6486113.57
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    427983.66
    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.
    320
  • Wellbore history

    General
    Well 15/6-5 was drilled in the north-eastern part of the Sleipner Field (Sleipner West). The objective was to confirm structural and stratigraphic interpretations as well as define the hydrocarbon content and contacts and the reservoir properties in this part of the Field.
    The well is reference well for the Hugin Formation.
    Operations and results
    Appraisal well 15/6-5 was spudded with the semi-submersible installation Drillmaster on 10 October 1977 and drilled to TD at 3824 m in Triassic sediments. No significant problems were encountered during the drilling of the well. Initial drilling from the sea floor to 166.5 m was with fresh water and lignosulphonate. Below this depth and down to 1197.5 m a seawater gel with carboxymethyl-cellulose (CMC) mud system was used. Below 1197.5 m the above mud with lignosulphonate was used.
    The Hugin Formation (Upper Dogger Sandstone) was encountered at 3627 meters. This was six meters below the lowest gas seen in the main Sleipner reservoir to that date, 3597 m MSL in 15/9-1. The Hugin Formation is 53 meters thick in the well and essentially 100% sandstone. Electric log analysis and RFT pressure data show the section to be water bearing, although the presence of residual hydrocarbons down to 3655 m was indicated by bleeding gas and excellent liquid hydrocarbon shows in the cores. No hydrocarbon indications were present below 3655 m. The Sleipner Formation (Lower Dogger) came in at 3580 m with several massive coals beds. The well established that the potential lower limit of hydrocarbons in the main Sleipner reservoir was 3627 m (3603 m MSL).
    Four conventional cores were cut from 3629 m to 3683 m in the Middle Jurassic sandstones (Dogger). Five FIT wire line fluid samples were taken between 3632.6 m and 3655.5 m. They all contained mud filtrate.
    The well was permanently abandoned on 29 November 1977 as a dry well with shows.
    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]
    374.00
    3825.00
  • 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
    3629.0
    3647.5
    [m ]
    2
    3647.5
    3655.7
    [m ]
    3
    3656.4
    3674.0
    [m ]
    4
    3674.1
    3682.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    52.5
    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
    2999.0
    [m]
    C
    3029.0
    [m]
    C
    3059.0
    [m]
    C
    3089.0
    [m]
    C
    3119.0
    [m]
    C
    3149.0
    [m]
    DC
    3179.0
    [m]
    DC
    3209.0
    [m]
    DC
    3239.0
    [m]
    DC
    3269.0
    [m]
    DC
    3301.7
    [m]
    SWC
    3303.7
    [m]
    SWC
    3307.5
    [m]
    SWC
    3333.3
    [m]
    SWC
    3338.0
    [m]
    DC
    3356.0
    [m]
    C
    3362.0
    [m]
    C
    3368.0
    [m]
    C
    3380.0
    [m]
    C
    3401.0
    [m]
    DC
    3419.0
    [m]
    DC
    3428.0
    [m]
    DC
    3440.0
    [m]
    C
    3461.0
    [m]
    C
    3473.0
    [m]
    C
    3491.0
    [m]
    C
    3500.0
    [m]
    DC
    3503.0
    [m]
    DC
    3509.0
    [m]
    DC
    3527.0
    [m]
    DC
    3542.0
    [m]
    DC
    3548.0
    [m]
    DC
    3560.0
    [m]
    DC
    3569.0
    [m]
    DC
    3578.0
    [m]
    DC
    3590.0
    [m]
    C
    3601.3
    [m]
    SWC
    3602.2
    [m]
    SWC
    3603.1
    [m]
    SWC
    3612.1
    [m]
    SWC
    3614.0
    [m]
    C
    3620.5
    [m]
    SWC
    3629.2
    [m]
    C
    3631.6
    [m]
    C
    3632.9
    [m]
    C
    3635.3
    [m]
    C
    3638.6
    [m]
    C
    3642.1
    [m]
    C
    3645.0
    [m]
    C
    3647.4
    [m]
    C
    3648.1
    [m]
    C
    3649.0
    [m]
    C
    3652.5
    [m]
    C
    3654.4
    [m]
    C
    3657.8
    [m]
    C
    3660.0
    [m]
    C
    3662.0
    [m]
    C
    3666.2
    [m]
    C
    3668.5
    [m]
    C
    3672.0
    [m]
    C
    3672.7
    [m]
    C
    3676.2
    [m]
    C
    3677.0
    [m]
    C
    3678.8
    [m]
    C
    RRI
    3679.6
    [m]
    C
    3679.6
    [m]
    C
    3681.4
    [m]
    C
    3706.9
    [m]
    SWC
    3707.9
    [m]
    SWC
    3710.3
    [m]
    SWC
    3746.1
    [m]
    SWC
    3747.1
    [m]
    SWC
    3748.5
    [m]
    SWC
    3769.0
    [m]
    SWC
    3770.0
    [m]
    SWC
    3782.0
    [m]
    SWC
    3783.0
    [m]
    SWC
    3805.0
    [m]
    SWC
    3806.0
    [m]
    SWC
    3823.0
    [m]
    C
  • Lithostratigraphy

  • 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
    2.47
    pdf
    10.63
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    372
    1165
    CBL
    505
    1143
    CDM
    2839
    3823
    FDC CNL
    2839
    3719
    IES
    3250
    3824
    ISF SON
    167
    3822
    MUD
    370
    3824
    TEMP
    1800
    2738
    VELOCITY
    166
    3822
  • 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
    167.0
    36
    167.0
    0.00
    SURF.COND.
    20
    374.0
    26
    385.0
    0.00
    INTERM.
    13 3/8
    1198.0
    17 1/2
    1210.0
    0.00
    INTERM.
    9 5/8
    2840.0
    12 1/4
    2853.0
    0.00
    OPEN HOLE
    3824.0
    8 1/2
    3824.0
    0.00
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    351
    1.10
    waterbased
    1082
    1.10
    waterbased
    1210
    1.09
    waterbased
    2007
    1.13
    waterbased
    2580
    1.21
    waterbased
    3274
    1.25
    waterbased
    3420
    1.32
    waterbased
    3629
    1.37
    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
    0.21