Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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15/5-7 A

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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 A
    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-inline1800 & crossline 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.
    1202-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.
    35
    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,
    09.09.2008
    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.
    13.10.2008
    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.
    13.10.2010
    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.
    13.10.2010
    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.
    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.
    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).
    4199.0
    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).
    4117.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    34
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    35
    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° 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.
    5946

  • Wellbore history
    General
    Well 15/5-7 A is a sidetrack from well 15/5-7 on the Dagny Discovery in the southern Viking Graben area of the North Sea. Well 15/5-7 proved an oil-filled Hugin Formation, a 98 m oil column. The primary objective of the sidetrack 15/5-7 A was to obtain data from the water zone, down-flanks on the structure.
    Operations and results
    Appraisal well 15/5-7 A was drilled with the semi-submersible installation Transocean Winner. The sidetrack commenced on 8 September at 3145 m and drilled to 4130 m in the Sleipner Formation. The wire line logging tools stuck in the first run at 3515 m and only very incomplete logs were obtained from this bore hole. Fishing failed, the fish was pushed down to 3715 m, and the borehole was plugged back for a second sidetrack. The second, named technically as sidetrack 15/5-7 AT2, was kicked off from 3337 m in well 15/5-7 on 24 September 2008 and drilled to TD at 4199 m in the Middle Jurassic Sleipner Formation. TD logging was obtained. The sidetrack well was drilled with an oil based mud.
    Based on pressure gradients recorded in 15/5-7 and the sidetrack, the OWC was estimated at 3923 m TVD RKB. No oil shows were recorded in the well.
    No cores were cut in the well. MDT pressures were recorded in the water bearing Hugin Formation. MDT water samples were taken at 3998.2 m in the technical sidetrack.
    The well was permanently abandoned on 13 October 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]
    3170.00
    4130.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3680.0
    [m]
    DC
    ICHRON
    3690.0
    [m]
    DC
    ICHRON
    3700.0
    [m]
    DC
    ICHRON
    3710.0
    [m]
    DC
    ICHRON
    3720.0
    [m]
    DC
    ICHRON
    3730.0
    [m]
    DC
    ICHRON
    3740.0
    [m]
    DC
    ICHRON
    3750.0
    [m]
    DC
    ICHRON
    3760.0
    [m]
    DC
    ICHRON
    3770.0
    [m]
    DC
    ICHRON
    3780.0
    [m]
    DC
    ICHRON
    3790.0
    [m]
    DC
    ICHRON
    3800.0
    [m]
    DC
    ICHRON
    3810.0
    [m]
    DC
    ICHRON
    3812.0
    [m]
    DC
    ICHRON
    3820.0
    [m]
    DC
    ICHRON
    3827.0
    [m]
    DC
    ICHRON
    3830.0
    [m]
    DC
    ICHRON
    3840.0
    [m]
    DC
    ICHRON
    3842.0
    [m]
    DC
    ICHRON
    3850.0
    [m]
    DC
    ICHRON
    3857.0
    [m]
    DC
    ICHRON
    3860.0
    [m]
    DC
    ICHRON
    3870.0
    [m]
    DC
    ICHRON
    3872.0
    [m]
    DC
    ICHRON
    3880.0
    [m]
    DC
    ICHRON
    3887.0
    [m]
    DC
    ICHRON
    3890.0
    [m]
    DC
    ICHRON
    3900.0
    [m]
    DC
    ICHRON
    3902.0
    [m]
    DC
    ICHRON
    3910.0
    [m]
    DC
    ICHRON
    3917.0
    [m]
    DC
    ICHRON
    3920.0
    [m]
    DC
    ICHRON
    3929.0
    [m]
    DC
    ICHRON
    3933.0
    [m]
    DC
    ICHRON
    3938.0
    [m]
    DC
    ICHRON
    3947.0
    [m]
    DC
    ICHRON
    3956.0
    [m]
    DC
    ICHRON
    3962.0
    [m]
    DC
    ICHRON
    3965.0
    [m]
    DC
    ICHRON
    3968.0
    [m]
    DC
    ICHRON
    3971.0
    [m]
    DC
    ICHRON
    3974.0
    [m]
    DC
    ICHRON
    3977.0
    [m]
    DC
    ICHRON
    3980.0
    [m]
    DC
    ICHRON
    3983.0
    [m]
    DC
    ICHRON
    3986.0
    [m]
    DC
    ICHRON
    3989.0
    [m]
    DC
    ICHRON
    3992.0
    [m]
    DC
    ICHRON
    3995.0
    [m]
    DC
    ICHRON
    3998.0
    [m]
    DC
    ICHRON
    4001.0
    [m]
    DC
    ICHRON
    4004.0
    [m]
    DC
    ICHRON
    4007.0
    [m]
    DC
    ICHRON
    4010.0
    [m]
    DC
    ICHRON
    4013.0
    [m]
    DC
    ICHRON
    4016.0
    [m]
    DC
    ICHRON
    4019.0
    [m]
    DC
    ICHRON
    4022.0
    [m]
    DC
    ICHRON
    4025.0
    [m]
    DC
    ICHRON
    4028.0
    [m]
    DC
    ICHRON
    4031.0
    [m]
    DC
    ICHRON
    4034.0
    [m]
    DC
    ICHRON
    4037.0
    [m]
    DC
    ICHRON
    4040.0
    [m]
    DC
    ICHRON
    4043.0
    [m]
    DC
    ICHRON
    4046.0
    [m]
    DC
    ICHRON
    4049.0
    [m]
    DC
    ICHRON
    4052.0
    [m]
    DC
    ICHRON
    4055.0
    [m]
    DC
    ICHRON
    4055.0
    [m]
    DC
    ICHRON
    4058.0
    [m]
    DC
    ICHRON
    4061.0
    [m]
    DC
    ICHRON
    4064.0
    [m]
    DC
    ICHRON
    4067.0
    [m]
    DC
    ICHRON
    4070.0
    [m]
    DC
    ICHRON
    4073.0
    [m]
    DC
    ICHRON
    4076.0
    [m]
    DC
    ICHRON
    4079.0
    [m]
    DC
    ICHRON
    4082.0
    [m]
    DC
    ICHRON
    4085.0
    [m]
    DC
    ICHRON
    4088.0
    [m]
    DC
    ICHRON
    4091.0
    [m]
    DC
    ICHRON
    4094.0
    [m]
    DC
    ICHRON
    4097.0
    [m]
    DC
    ICHRON
    4100.0
    [m]
    DC
    ICHRON
    4103.0
    [m]
    DC
    ICHRON
    4106.0
    [m]
    DC
    ICHRON
    4109.0
    [m]
    DC
    ICHRON
    4112.0
    [m]
    DC
    ICHRON
    4115.0
    [m]
    DC
    ICHRON
    4118.0
    [m]
    DC
    ICHRON
    4121.0
    [m]
    DC
    ICHRON
    4124.0
    [m]
    DC
    ICHRON
    4127.0
    [m]
    DC
    ICHRON
    4130.0
    [m]
    DC
    ICHRON
    4133.0
    [m]
    DC
    ICHRON
    4139.0
    [m]
    DC
    ICHRON
    4142.0
    [m]
    DC
    ICHRON
    4145.0
    [m]
    DC
    ICHRON
    4148.0
    [m]
    DC
    ICHRON
    4151.0
    [m]
    DC
    ICHRON
    4154.0
    [m]
    DC
    ICHRON
    4163.0
    [m]
    DC
    ICHRON
    4169.0
    [m]
    DC
    ICHRON
    4175.0
    [m]
    DC
    ICHRON
    4181.0
    [m]
    DC
    ICHRON
    4187.0
    [m]
    DC
    ICHRON
    4193.0
    [m]
    DC
    ICHRON

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT
    3969
    4088
    MDT
    3989
    4085
    MSIP GR PPC1
    3634
    4132
    MWD - ECO TELE
    3361
    4199
    MWD - TELE
    3337
    3361
    VSP SS
    3695
    4153
    VSP ZO
    2116
    4100
    XPT PT
    3998
    4149

  • 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
    INTERM.
    13 3/8
    2657.0
    17 1/2
    2669.0
    1.65
    LOT
    OPEN HOLE
    4130.0
    8 1/2
    4130.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    4130
    1.40
    Oil based

  • 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