Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
10.05.2024 - 01:33
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6407/7-9 A

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6407/7-9 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).
    WILDCAT
    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.
    NORWEGIAN 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.
    6407/7-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST14204Z15. inline: 5733; xline: 1313
    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.
    Statoil Petroleum 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.
    1639-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.
    26
    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,
    20.09.2016
    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.
    16.10.2016
    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.
    16.10.2018
    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.
    03.12.2018
    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.
    WILDCAT
    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
    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.
    YES
    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.
    TILJE FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    ÅRE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    323.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4960.0
    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).
    4156.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    48.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    155
    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.
    EARLY 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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 18' 59.25'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 9' 24.4'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7133747.71
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    410870.09
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    8050

  • Wellbore history
    Wellbore history
    General
    Well 6407/7-9 A was drilled to test the Njord North Flank 3 prospect about 6 km north of the producing Njord Field in the Norwegian Sea. The primary objective was to prove hydrocarbon potential in the Early-Middle Jurassic Tilje and Ile formations. The secondary objective was to test the hydrocarbon potential in the Åre Formation.
    Operations and results
    Wildcat well 6407/7-9 A was kicked off on 20 September 2016, from 1110.7 m in the 13 3/8" casing in primary well 6407/7-9 S. The sidetrack was drilled with the semi-submersible installation Songa Delta to TD at 4960 m in the Early Jurassic Åre Formation. Operations proceeded without significant problems. The well was drilled with XP07 oil based mud from kick-off to TD.
    Gas with traces of oil-range hydrocarbons was encountered in thin intra-Lange Formation sandstones in the interval 3644 to 3780 m. Top Ile Formation was penetrated at 3992 m (3365.1 m TVD). The Ile Formation had shows in the top from 3998 to 4008 m, but no mobile hydrocarbons were proven.  A 195-metre TVD gas column was encountered in the Tilje Formation, from formation top to formation base, and a 140-metre TVD gas column from top Åre Formation to ca 4888 m (4097 m). The reservoir properties in the reservoirs are poor to moderate. No true oil-water contact was observed, only down-to contacts. Weak oil shows (fluorescence) are described below 4888 m in the Åre Formation as deep as 4977 m.
    No cores were cut. MDT fluid samples were taken in the Ile Formation at 4326.1 m (water), and in the Tilje Formation at 4659.4 m (gas condensate). Isotubes to collect further gas, including in the Lange Formation, proved to contain only air and no formation gas.
    The well was permanently abandoned on 16 October 2016 as a gas discovery.
    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]
    1120.00
    4960.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1120.0
    [m]
    DC
    APT
    1160.0
    [m]
    DC
    APT
    1200.0
    [m]
    DC
    APT
    1240.0
    [m]
    DC
    APT
    1280.0
    [m]
    DC
    APT
    1320.0
    [m]
    DC
    APT
    1360.0
    [m]
    DC
    APT
    1400.0
    [m]
    DC
    APT
    1440.0
    [m]
    DC
    APT
    1480.0
    [m]
    DC
    APT
    1520.0
    [m]
    DC
    APT
    1560.0
    [m]
    DC
    APT
    1600.0
    [m]
    DC
    APT
    1640.0
    [m]
    DC
    APT
    1680.0
    [m]
    DC
    APT
    1720.0
    [m]
    DC
    APT
    1760.0
    [m]
    DC
    APT
    1800.0
    [m]
    DC
    APT
    1840.0
    [m]
    DC
    APT
    1880.0
    [m]
    DC
    APT
    1920.0
    [m]
    DC
    APT
    1960.0
    [m]
    DC
    APT
    2000.0
    [m]
    DC
    APT
    2040.0
    [m]
    DC
    APT
    2080.0
    [m]
    DC
    APT
    2120.0
    [m]
    DC
    APT
    2160.0
    [m]
    DC
    APT
    2200.0
    [m]
    DC
    APT
    2240.0
    [m]
    DC
    APT
    2280.0
    [m]
    DC
    APT
    2320.0
    [m]
    DC
    APT
    2360.0
    [m]
    DC
    APT
    2400.0
    [m]
    DC
    APT
    2440.0
    [m]
    DC
    APT
    2480.0
    [m]
    DC
    APT
    2520.0
    [m]
    DC
    APT
    2560.0
    [m]
    DC
    APT
    2600.0
    [m]
    DC
    APT
    2640.0
    [m]
    DC
    APT
    2680.0
    [m]
    DC
    APT
    2720.0
    [m]
    DC
    APT
    2760.0
    [m]
    DC
    APT
    2800.0
    [m]
    DC
    APT
    2840.0
    [m]
    DC
    APT
    2880.0
    [m]
    DC
    APT
    2920.0
    [m]
    DC
    APT
    2960.0
    [m]
    DC
    APT
    3000.0
    [m]
    DC
    APT
    3040.0
    [m]
    DC
    APT
    3080.0
    [m]
    DC
    APT
    3120.0
    [m]
    DC
    APT
    3160.0
    [m]
    DC
    APT
    3200.0
    [m]
    DC
    APT
    3240.0
    [m]
    DC
    APT
    3280.0
    [m]
    DC
    APT
    3850.0
    [m]
    DC
    APT
    3870.0
    [m]
    DC
    APT
    3890.0
    [m]
    DC
    APT
    3900.0
    [m]
    DC
    APT
    3910.0
    [m]
    DC
    APT
    3920.0
    [m]
    DC
    APT
    3930.0
    [m]
    DC
    APT
    3940.0
    [m]
    DC
    APT
    3950.0
    [m]
    DC
    APT
    3960.0
    [m]
    DC
    APT
    3970.0
    [m]
    DC
    APT
    3980.0
    [m]
    DC
    APT
    3990.0
    [m]
    DC
    APT
    4000.0
    [m]
    DC
    APT
    4009.0
    [m]
    DC
    APT
    4018.0
    [m]
    DC
    APT
    4027.0
    [m]
    DC
    APT
    4036.0
    [m]
    DC
    APT
    4045.0
    [m]
    DC
    APT
    4054.0
    [m]
    DC
    APT
    4063.0
    [m]
    DC
    APT
    4072.0
    [m]
    DC
    APT
    4081.0
    [m]
    DC
    APT
    4090.0
    [m]
    DC
    APT
    4099.0
    [m]
    DC
    APT
    4108.0
    [m]
    DC
    APT
    4117.0
    [m]
    DC
    APT
    4126.0
    [m]
    DC
    APT
    4135.0
    [m]
    DC
    APT
    4144.0
    [m]
    DC
    APT
    4153.0
    [m]
    DC
    APT
    4162.0
    [m]
    DC
    APT
    4171.0
    [m]
    DC
    APT
    4180.0
    [m]
    DC
    APT
    4189.0
    [m]
    DC
    APT
    4198.0
    [m]
    DC
    APT
    4207.0
    [m]
    DC
    APT
    4216.0
    [m]
    DC
    APT
    4225.0
    [m]
    DC
    APT
    4234.0
    [m]
    DC
    APT
    4242.0
    [m]
    DC
    APT
    4252.0
    [m]
    DC
    APT
    4261.0
    [m]
    DC
    APT
    4270.0
    [m]
    DC
    APT
    4279.0
    [m]
    DC
    APT
    4288.0
    [m]
    DC
    APT
    4297.0
    [m]
    DC
    APT
    4306.0
    [m]
    DC
    APT
    4315.0
    [m]
    DC
    APT
    4324.0
    [m]
    DC
    APT
    4333.0
    [m]
    DC
    APT
    4342.0
    [m]
    DC
    APT
    4351.0
    [m]
    DC
    APT
    4360.0
    [m]
    DC
    APT
    4369.0
    [m]
    DC
    APT
    4378.0
    [m]
    DC
    APT
    4387.0
    [m]
    DC
    APT
    4396.0
    [m]
    DC
    APT
    4405.0
    [m]
    DC
    APT
    4414.0
    [m]
    DC
    APT
    4423.0
    [m]
    DC
    APT
    4432.0
    [m]
    DC
    APT
    4441.0
    [m]
    DC
    APT
    4450.0
    [m]
    DC
    APT
    4459.0
    [m]
    DC
    APT
    4468.0
    [m]
    DC
    APT
    4477.0
    [m]
    DC
    APT
    4486.0
    [m]
    DC
    APT
    4496.0
    [m]
    DC
    APT
    4504.0
    [m]
    DC
    APT
    4513.0
    [m]
    DC
    APT
    4522.0
    [m]
    DC
    APT
    4531.0
    [m]
    DC
    APT
    4540.0
    [m]
    DC
    APT
    4549.0
    [m]
    DC
    APT
    4558.0
    [m]
    DC
    APT
    4567.0
    [m]
    DC
    APT
    4571.4
    [m]
    SWC
    APT
    4576.0
    [m]
    DC
    APT
    4585.0
    [m]
    DC
    APT
    4594.0
    [m]
    DC
    APT
    4603.0
    [m]
    DC
    APT
    4612.0
    [m]
    DC
    APT
    4621.0
    [m]
    DC
    APT
    4630.0
    [m]
    DC
    APT
    4639.0
    [m]
    DC
    APT
    4644.2
    [m]
    SWC
    APT
    4648.0
    [m]
    DC
    APT
    4657.0
    [m]
    DC
    APT
    4666.0
    [m]
    DC
    APT
    4675.0
    [m]
    DC
    APT
    4684.0
    [m]
    DC
    APT
    4693.0
    [m]
    DC
    APT
    4702.0
    [m]
    DC
    APT
    4711.0
    [m]
    DC
    APT
    4720.0
    [m]
    DC
    APT
    4729.0
    [m]
    DC
    APT
    4738.0
    [m]
    DC
    APT
    4747.0
    [m]
    DC
    APT
    4756.0
    [m]
    DC
    APT
    4765.0
    [m]
    DC
    APT
    4774.0
    [m]
    DC
    APT
    4783.0
    [m]
    DC
    APT
    4792.0
    [m]
    DC
    APT
    4801.0
    [m]
    DC
    APT
    4810.0
    [m]
    DC
    APT
    4819.0
    [m]
    DC
    APT
    4828.0
    [m]
    DC
    APT
    4837.0
    [m]
    DC
    APT
    4846.0
    [m]
    DC
    APT
    4855.0
    [m]
    DC
    APT
    4864.0
    [m]
    DC
    APT
    4873.0
    [m]
    DC
    APT
    4882.0
    [m]
    DC
    APT
    4891.0
    [m]
    DC
    APT
    4900.0
    [m]
    DC
    APT
    4909.0
    [m]
    DC
    APT
    4918.0
    [m]
    DC
    APT
    4927.0
    [m]
    DC
    APT
    4936.0
    [m]
    DC
    APT
    4945.0
    [m]
    DC
    APT
    4954.0
    [m]
    DC
    APT
    4960.0
    [m]
    DC
    APT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT SON SCAN PEX APT
    3518
    4960
    MDT XLD
    4219
    4912
    MDT XLD SATURN
    4215
    4873
    MSCT GR
    3763
    4847
    MWD - ARC8 TELE 825
    3526
    4960
    PEX150 AIT XPT
    3518
    4960
    XL ROCK GR
    4319
    4912

  • 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
    402.0
    36
    403.0
    0.00
    1089.0
    1089.0
    1.62
    FIT
    SURF.COND.
    13 3/8
    1110.7
    17 1/2
    0.0
    0.00
    LINER
    9 5/8
    3518.2
    12 1/4
    3526.0
    1.83
    FIT
    OPEN HOLE
    4960.0
    8 1/2
    4960.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1133
    1.57
    26.0
    XP-07
    3235
    1.58
    10.0
    XP-07
    3379
    1.57
    26.0
    XP-07
    3379
    1.64
    39.0
    XP-07
    3526
    1.58
    11.0
    XP-07
    3538
    1.64
    40.0
    XP-07
    3644
    1.61
    23.0
    XP-07
    4548
    1.62
    30.0
    XP-07
    4780
    1.64
    32.0
    XP-07
    4960
    1.64
    34.0
    XP-07