Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/5-7

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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.
    15/5-7
    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
    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.
    15/5-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D Survey ST06M02.inline 1800& xline 660
    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.
    StatoilHydro ASA
    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.
    1187-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.
    66
    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,
    04.07.2008
    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.
    07.09.2008
    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.
    07.09.2010
    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.
    07.09.2010
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    119.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4037.0
    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).
    4031.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7
    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.
    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° 33' 22.2'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 39' 19.3'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6491564.70
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    421754.96
    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.
    5842

  • Wellbore history
    General
    Well 15/5-7 was drilled on the Dagny Discovery in the southern Viking Graben area of the North Sea. The primary objective of the well was to prove an oil leg beneath the proven gas in the Dagny structure and establish hydrocarbon contacts. Further objectives were the hydrocarbon characteristics in the Hugin and Sleipner Formations and to test the permeability and productivity of the reservoir. The second objective was to collect a water sample in the Hugin Formation.
    Operations and results
    Appraisal well 15/5-7 was spudded with the semi-submersible installation Transocean Winner on 5 July 2008 and drilled to TD at 4037m in the Triassic Skagerrak Formation. No shallow gas was observed by the ROV at the wellhead or by the MWD while drilling the 36" hole or the 17 1/2" hole. Operational problems included repairs of leakage in the BOP in the 17 1/2" section (close to 5 days NPT), directional deviation in the 8 1/2" section and loss of MDT tool in hole at final logging. The lost MDT was pushed to bottom before plugging back. The well was drilled with spud mud down to 1048 m and with KCl/polymer/Glycol (Glydril) mud from 1048 m to TD.
    The well penetrated rocks of Quaternary, Tertiary, Cretaceous and Jurassic age. The well penetrated the Hugin Formation reservoir at 3821 m (3815.3 m TVD), 59.7 m TVD shallower than prognosed. The well proved oil down to base of the Hugin Formation and it was decided to sidetrack the well for data acquisition in the water zone, including formation water sampling. Based on pressure gradients recorded in 15/5-7 and in the later sidetrack 15/5-7 A, the OWC was estimated at 3923 m TVD RKB. The sandstones of the Hugin Formations had good oil shows, otherwise no oil shows were recorded in the well.
    Three cores were cut. The first core was cut in Hugin Formation, the second core covered the transition zones between the Hugin and Sleipner Formations and the third core was cut in the Sleipner Formation. MDT pressures were recorded in the oil bearing Hugin Formation and into the Sleipner Formation. MDT oil samples were taken at 3828.8 m, 3830.5 m (sampled during mini DST from 3830 - 3831 m), and at 3883 m (sampled during mini DST from 3882.2 - 3883.2 m).
    The open hole was plugged back to 3036 m and prepared for sidetracking (15/5-7 A). The bore hole was abandoned on 7 September 2008 as an oil appraisal.
    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]
    1045.00
    4037.00

  • 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
    3826.0
    3880.5
    [m ]
    2
    3880.5
    3927.4
    [m ]
    3
    3927.4
    3940.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    114.0
    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
    1105.0
    [m]
    DC
    ICHRON
    1125.0
    [m]
    DC
    ICHRON
    1145.0
    [m]
    DC
    ICHRON
    1175.0
    [m]
    DC
    ICHRON
    1195.0
    [m]
    DC
    ICHRON
    1215.0
    [m]
    DC
    ICHRON
    1245.0
    [m]
    DC
    ICHRON
    1265.0
    [m]
    DC
    ICHRON
    1285.0
    [m]
    DC
    ICHRON
    1305.0
    [m]
    DC
    ICHRON
    1325.0
    [m]
    DC
    ICHRON
    1345.0
    [m]
    DC
    ICHRON
    1365.0
    [m]
    DC
    ICHRON
    1385.0
    [m]
    DC
    ICHRON
    1405.0
    [m]
    DC
    ICHRON
    1425.0
    [m]
    DC
    ICHRON
    1445.0
    [m]
    DC
    ICHRON
    1465.0
    [m]
    DC
    ICHRON
    1485.0
    [m]
    DC
    ICHRON
    1505.0
    [m]
    DC
    ICHRON
    1525.0
    [m]
    DC
    ICHRON
    1545.0
    [m]
    DC
    ICHRON
    1565.0
    [m]
    DC
    ICHRON
    1585.0
    [m]
    DC
    ICHRON
    1605.0
    [m]
    DC
    ICHRON
    1625.0
    [m]
    DC
    ICHRON
    1645.0
    [m]
    DC
    ICHRON
    1665.0
    [m]
    DC
    ICHRON
    1685.0
    [m]
    DC
    ICHRON
    1705.0
    [m]
    DC
    ICHRON
    1725.0
    [m]
    DC
    ICHRON
    1745.0
    [m]
    DC
    ICHRON
    1765.0
    [m]
    DC
    ICHRON
    1785.0
    [m]
    DC
    ICHRON
    1805.0
    [m]
    DC
    ICHRON
    1825.0
    [m]
    DC
    ICHRON
    1845.0
    [m]
    DC
    ICHRON
    1865.0
    [m]
    DC
    ICHRON
    1885.0
    [m]
    DC
    ICHRON
    1905.0
    [m]
    DC
    ICHRON
    1925.0
    [m]
    DC
    ICHRON
    1945.0
    [m]
    DC
    ICHRON
    1965.0
    [m]
    DC
    ICHRON
    1985.0
    [m]
    DC
    ICHRON
    2005.0
    [m]
    DC
    ICHRON
    2025.0
    [m]
    DC
    ICHRON
    2045.0
    [m]
    DC
    ICHRON
    2065.0
    [m]
    DC
    ICHRON
    2085.0
    [m]
    DC
    ICHRON
    2595.0
    [m]
    DC
    ICHRON
    2605.0
    [m]
    DC
    ICHRON
    2615.0
    [m]
    DC
    ICHRON
    2625.0
    [m]
    DC
    ICHRON
    2635.0
    [m]
    DC
    ICHRON
    2645.0
    [m]
    DC
    ICHRON
    2655.0
    [m]
    DC
    ICHRON
    2669.0
    [m]
    DC
    ICHRON
    3666.0
    [m]
    DC
    ICHRON
    3672.0
    [m]
    DC
    ICHRON
    3681.0
    [m]
    DC
    ICHRON
    3687.0
    [m]
    DC
    ICHRON
    3693.0
    [m]
    DC
    ICHRON
    3699.0
    [m]
    DC
    ICHRON
    3705.0
    [m]
    DC
    ICHRON
    3711.0
    [m]
    DC
    ICHRON
    3720.0
    [m]
    DC
    ICHRON
    3729.0
    [m]
    DC
    ICHRON
    3735.0
    [m]
    DC
    ICHRON
    3741.0
    [m]
    DC
    ICHRON
    3747.0
    [m]
    DC
    ICHRON
    3753.0
    [m]
    DC
    ICHRON
    3756.0
    [m]
    DC
    ICHRON
    3762.0
    [m]
    DC
    ICHRON
    3768.0
    [m]
    DC
    ICHRON
    3774.0
    [m]
    DC
    ICHRON
    3780.0
    [m]
    DC
    ICHRON
    3786.0
    [m]
    DC
    ICHRON
    3792.0
    [m]
    DC
    ICHRON
    3798.0
    [m]
    DC
    ICHRON
    3804.0
    [m]
    DC
    ICHRON
    3810.0
    [m]
    DC
    ICHRON
    3816.0
    [m]
    DC
    ICHRON
    3835.6
    [m]
    CORE
    ICHRON
    3843.3
    [m]
    CORE
    ICHRON
    3844.5
    [m]
    CORE
    ICHRON
    3845.2
    [m]
    CORE
    ICHRON
    3867.3
    [m]
    CORE
    ICHRON
    3870.2
    [m]
    CORE
    ICHRON
    3873.4
    [m]
    CORE
    ICHRON
    3881.4
    [m]
    CORE
    ICHRON
    3882.9
    [m]
    CORE
    ICHRON
    3891.3
    [m]
    CORE
    ICHRON
    3894.9
    [m]
    CORE
    ICHRON
    3895.5
    [m]
    CORE
    ICHRON
    3900.0
    [m]
    CORE
    ICHRON
    3904.2
    [m]
    CORE
    ICHRON
    3907.2
    [m]
    CORE
    ICHRON
    3910.1
    [m]
    CORE
    ICHRON
    3914.7
    [m]
    CORE
    ICHRON
    3917.0
    [m]
    CORE
    ICHRON
    3917.5
    [m]
    CORE
    ICHRON
    3918.9
    [m]
    CORE
    ICHRON
    3919.2
    [m]
    CORE
    ICHRON
    3925.4
    [m]
    CORE
    ICHRON
    3926.2
    [m]
    CORE
    ICHRON
    3927.5
    [m]
    CORE
    ICHRON
    3929.5
    [m]
    CORE
    ICHRON
    3933.2
    [m]
    CORE
    ICHRON
    3937.7
    [m]
    CORE
    ICHRON
    3938.8
    [m]
    CORE
    ICHRON
    3939.0
    [m]
    CORE
    ICHRON

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    0.00
    0.00
    OIL
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DP SAMPLE
    3828
    3883
    DSI FMI
    2250
    4000
    MDT
    3825
    4000
    MDT
    3830
    3830
    MDT MINIDST
    3830
    3830
    MDT MINIDST
    3882
    3882
    MWD - ARCVRES9 PP
    1045
    4037
    MWD - ARCVRES9-TELE
    192
    1045
    PEX HRLA
    2600
    4025
    VSP
    690
    4010

  • 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
    194.0
    36
    198.0
    0.00
    LOT
    SURF.COND.
    20
    1039.0
    26
    1048.0
    1.92
    LOT
    INTERM.
    13 3/8
    2657.0
    17 1/2
    2669.0
    1.65
    LOT
    OPEN HOLE
    4037.0
    8 1/2
    4063.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    198
    1.03
    spud mud
    1048
    1.06
    spud mud
    2669
    1.35
    KCL/poly
    4037
    1.49
    KCL/poly

  • 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