Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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6406/2-4 S

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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.
    6406/2-4 S
    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.
    SUSPENDED
    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
    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.
    6406/2-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    HWM 94- INLINE 1500 & CROSSLINE 2063
    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.
    Saga Petroleum 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.
    876-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.
    76
    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,
    18.01.1997
    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.
    05.04.1997
    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.
    05.04.1999
    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.
    11.04.2003
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    273.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4546.0
    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).
    4457.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    17.7
    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.
    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.
    MELKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 47' 58.34'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 32' 29.26'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7188560.78
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    383212.30
    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.
    3012

  • Wellbore history
    General
    Appraisal well 6406/2-4 S was drilled on the southern part of the Lavrans structure in the eastern part of block 6406/2, south of the Smørbukk Field and west of the Trestakk Field on Haltenbanken. The Lavrans structure is a rotated fault block west of the Trestakk Fault on the Halten Terrace. The purpose of the well was to appraise the southward extension of hydrocarbons in the Garn, Ile and Tofte Formations in the Lavrans structure, and to test separate closures in the Tilje and Åre formations. In addition, the well was planned to test the productivity improvement achievable by hydraulic stimulation. The well should also penetrate two sandy zones of Turonian (Lysing Formation) and Cenomanian/Albian age (Intra Lange sandstone).
    Operations and results
    The deviated appraisal well 6406/2-4 S was spudded 18 January1997 with the semi-submersible installation "Deepsea Bergen". It was drilled to 4546 m (4457 m TVD) in the Melke Formation. Mainly because of the weather conditions (41 days of WOW and weather-related problems) drilling of 6406/2-4 S was significantly delayed. Due to environmental restrictions in the area the well had to be suspended on April 5 1997 before the well targets had been reached. Well 6406/2-4 S R was re-entered 12 November at depth 4534 m (4446 m TVD), below the 9 5/8" casing shoe in the initial well, and drilled to final TD at 5080 m (4969 m TVD) in Early Jurassic Åre Formation sediments. The well bores were drilled with KCl mud / spud mud down to 1110 m, with KCl mud and "ANCO 208" glycol from 1110 m to 2260 m, and with oil based "ANCOVERT" mud from 2260 m to final TD.
    Down to Base Cretaceous Unconformity the stratigraphy was as expected, the prognosis matched the experienced stratigraphy well. Below ECU, 154 meters of Upper Jurassic shales were penetrated before the drilling had to be stopped. Prognosed thickness of the Upper Jurassic shales was 44 m TVD. High total gas was observed when drilling through the Cretaceous sandy intervals, the Lysing and Lange Formations, but shows were not described in the cuttings.
    Well 6406/2-4 S R proved gas/condensate bearing sandstones in the Garn, Tofte and Tilje formations in hydrocarbon-down-to situations. The well penetrated a large fault within the Garn Formation, so that the Ile Formation along with parts of the Garn, most of the Not, the entire Upper Ror and the upper part of the Tofte Formation were faulted out. This fault came on depth as prognosed, but it had considerably larger throw than expected. In addition to this large fault, two smaller faults were penetrated in the Tilje Formation. The quality of the reservoir formations was somewhat lower than expected due to the tectonic influence. In the Tofte Formation, the proximity to the fault has reduced reservoir quality due to fractures and higher degree of cementation. In the Tilje Formation, the best-developed reservoir zones were either fractured or faulted out. The Garn Formation was intensively brecciated and fractured. Disregarding the faults, thickness of the formations approximates those of the neighbouring wells on Lavrans. The Åre Formation gave some gas readings during drilling but was regarded to be without hydrocarbons. No cores were cut and no wire line samples taken in well bore 6406/2-4 S. In the re-entry a total of ten conventional cores with a total length of 325.1 m were drilled, of which 322.8 m (99.3 %) were recovered. The cores were cut in the Middle Jurassic.
    A total of seven fluid samples were acquired in 6406/2-4 S R. Two hydrocarbon samples were taken in the Tofte Formation at 4701 m, four hydrocarbon samples were taken in the Tilje Formation at 4945.2 m and 4881.0 m, and one water sample was acquired in the Tilje Formation at 4835 m. The mud contamination from base oil in the MDT hydrocarbon samples were analysed to be from 25 to 71 % by weight. Well 6406/2-4 S R was permanently abandoned on 15 February 1999 as a gas and condensate appraisal well.
    Testing
    The Tilje (4874 m - 4904 m) and Tofte (4684 m - 4704 m) formations were production tested. Test 1 in the Tilje Formation produced 237000 m3 gas/day and 93 m3 condensate/day through a 9.53 mm choke. Test 2 in the Tofte Formation produced 42855 m3 gas/day and 18.1 m3 condensate/day through a 7.94 mm choke. The flow capacity of the test was severely influenced by fractures.

  • 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
    4545.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1130.0
    [m]
    DC
    STRAT
    1150.0
    [m]
    DC
    STRAT
    1170.0
    [m]
    DC
    STRAT
    1190.0
    [m]
    DC
    STRAT
    1210.0
    [m]
    DC
    STRAT
    1230.0
    [m]
    DC
    STRAT
    1250.0
    [m]
    DC
    STRAT
    1270.0
    [m]
    DC
    STRAT
    1290.0
    [m]
    DC
    STRAT
    1310.0
    [m]
    DC
    STRAT
    1330.0
    [m]
    DC
    STRAT
    1350.0
    [m]
    DC
    STRAT
    1370.0
    [m]
    DC
    STRAT
    1390.0
    [m]
    DC
    STRAT
    1410.0
    [m]
    DC
    STRAT
    1430.0
    [m]
    DC
    STRAT
    1450.0
    [m]
    DC
    STRAT
    1470.0
    [m]
    DC
    STRAT
    1510.0
    [m]
    DC
    STRAT
    1530.0
    [m]
    DC
    STRAT
    1570.0
    [m]
    DC
    STRAT
    1590.0
    [m]
    DC
    STRAT
    1610.0
    [m]
    DC
    STRAT
    1630.0
    [m]
    DC
    STRAT
    1650.0
    [m]
    DC
    STRAT
    1670.0
    [m]
    DC
    STRAT
    1690.0
    [m]
    DC
    STRAT
    1710.0
    [m]
    DC
    STRAT
    1730.0
    [m]
    DC
    STRAT
    1750.0
    [m]
    DC
    STRAT
    1770.0
    [m]
    DC
    STRAT
    1790.0
    [m]
    DC
    STRAT
    1810.0
    [m]
    DC
    STRAT
    1830.0
    [m]
    DC
    STRAT
    1850.0
    [m]
    DC
    STRAT
    1870.0
    [m]
    DC
    STRAT
    1890.0
    [m]
    DC
    STRAT
    1910.0
    [m]
    DC
    STRAT
    1930.0
    [m]
    DC
    STRAT
    1970.0
    [m]
    DC
    STRAT
    2030.0
    [m]
    DC
    STRAT
    2050.0
    [m]
    DC
    STRAT
    2090.0
    [m]
    DC
    STRAT
    2110.0
    [m]
    DC
    STRAT
    2130.0
    [m]
    DC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2170.0
    [m]
    DC
    STRAT
    2190.0
    [m]
    DC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2230.0
    [m]
    DC
    STRAT
    2250.0
    [m]
    DC
    STRAT
    2270.0
    [m]
    DC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2370.0
    [m]
    DC
    STRAT
    2410.0
    [m]
    DC
    STRAT
    2430.0
    [m]
    DC
    STRAT
    2450.0
    [m]
    DC
    STRAT
    2470.0
    [m]
    DC
    STRAT
    2490.0
    [m]
    DC
    STRAT
    2510.0
    [m]
    DC
    STRAT
    2530.0
    [m]
    DC
    STRAT
    2550.0
    [m]
    DC
    STRAT
    2585.0
    [m]
    DC
    STRAT
    2625.0
    [m]
    DC
    STRAT
    2655.0
    [m]
    DC
    STRAT
    2675.0
    [m]
    DC
    STRAT
    2695.0
    [m]
    DC
    STRAT
    2705.0
    [m]
    DC
    STRAT
    2735.0
    [m]
    DC
    STRAT
    2755.0
    [m]
    DC
    STRAT
    2785.0
    [m]
    DC
    STRAT
    2810.0
    [m]
    DC
    STRAT
    2830.0
    [m]
    DC
    STRAT
    2850.0
    [m]
    DC
    STRAT
    2870.0
    [m]
    DC
    STRAT
    2890.0
    [m]
    DC
    STRAT
    2910.0
    [m]
    DC
    STRAT
    2930.0
    [m]
    DC
    STRAT
    2950.0
    [m]
    DC
    STRAT
    2970.0
    [m]
    DC
    STRAT
    2990.0
    [m]
    DC
    STRAT
    3010.0
    [m]
    DC
    STRAT
    3030.0
    [m]
    DC
    STRAT
    3050.0
    [m]
    DC
    STRAT
    3070.0
    [m]
    DC
    STRAT
    3090.0
    [m]
    DC
    STRAT
    3110.0
    [m]
    DC
    STRAT
    3130.0
    [m]
    DC
    STRAT
    3150.0
    [m]
    DC
    STRAT
    3170.0
    [m]
    DC
    STRAT
    3190.0
    [m]
    DC
    STRAT
    3210.0
    [m]
    DC
    STRAT
    3230.0
    [m]
    DC
    STRAT
    3250.0
    [m]
    DC
    STRAT
    3270.0
    [m]
    DC
    STRAT
    3290.0
    [m]
    DC
    STRAT
    3310.0
    [m]
    DC
    STRAT
    3330.0
    [m]
    DC
    STRAT
    3350.0
    [m]
    DC
    STRAT
    3370.0
    [m]
    DC
    STRAT
    3390.0
    [m]
    DC
    STRAT
    3410.0
    [m]
    DC
    STRAT
    3430.0
    [m]
    DC
    STRAT
    3450.0
    [m]
    DC
    STRAT
    3470.0
    [m]
    DC
    STRAT
    3490.0
    [m]
    DC
    STRAT
    3510.0
    [m]
    DC
    STRAT
    3520.0
    [m]
    DC
    STRAT
    3540.0
    [m]
    DC
    STRAT
    3560.0
    [m]
    DC
    STRAT
    3580.0
    [m]
    DC
    STRAT
    3600.0
    [m]
    DC
    STRAT
    3620.0
    [m]
    DC
    STRAT
    3640.0
    [m]
    DC
    STRAT
    3660.0
    [m]
    DC
    STRAT
    3680.0
    [m]
    DC
    STRAT
    3700.0
    [m]
    DC
    STRAT
    3720.0
    [m]
    DC
    STRAT
    3740.0
    [m]
    DC
    STRAT
    3760.0
    [m]
    DC
    STRAT
    3780.0
    [m]
    DC
    STRAT
    3800.0
    [m]
    DC
    STRAT
    3810.0
    [m]
    DC
    STRAT
    3830.0
    [m]
    DC
    STRAT
    3850.0
    [m]
    DC
    STRAT
    3870.0
    [m]
    DC
    STRAT
    3890.0
    [m]
    DC
    STRAT
    3910.0
    [m]
    DC
    STRAT
    3930.0
    [m]
    DC
    STRAT
    3940.0
    [m]
    DC
    STRAT
    3970.0
    [m]
    DC
    STRAT
    3990.0
    [m]
    DC
    STRAT
    4010.0
    [m]
    DC
    STRAT
    4030.0
    [m]
    DC
    STRAT
    4050.0
    [m]
    DC
    STRAT
    4070.0
    [m]
    DC
    STRAT
    4090.0
    [m]
    DC
    STRAT
    4110.0
    [m]
    DC
    STRAT
    4130.0
    [m]
    DC
    STRAT
    4150.0
    [m]
    DC
    STRAT
    4170.0
    [m]
    DC
    STRAT
    4190.0
    [m]
    DC
    STRAT
    4210.0
    [m]
    DC
    STRAT
    4230.0
    [m]
    DC
    STRAT
    4250.0
    [m]
    DC
    STRAT
    4270.0
    [m]
    DC
    STRAT
    4300.0
    [m]
    DC
    STRAT
    4310.0
    [m]
    DC
    STRAT
    4350.0
    [m]
    DC
    STRAT
    4370.0
    [m]
    DC
    STRAT
    4380.0
    [m]
    DC
    STRAT
    4390.0
    [m]
    DC
    STRAT
    4400.0
    [m]
    DC
    STRAT
    4410.0
    [m]
    DC
    STRAT
    4420.0
    [m]
    DC
    STRAT
    4430.0
    [m]
    DC
    STRAT
    4440.0
    [m]
    DC
    STRAT
    4450.0
    [m]
    DC
    STRAT
    4470.0
    [m]
    DC
    STRAT
    4480.0
    [m]
    DC
    STRAT
    4490.0
    [m]
    DC
    STRAT
    4500.0
    [m]
    DC
    STRAT
    4505.0
    [m]
    DC
    STRAT
    4510.0
    [m]
    DC
    STRAT
    4520.0
    [m]
    DC
    STRAT
    4530.0
    [m]
    DC
    STRAT
    4540.0
    [m]
    DC
    STRAT
    4543.0
    [m]
    DC
    STRAT
    4546.0
    [m]
    DC
    STRAT

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.99
    pdf
    1.78
    pdf
    1.12

  • 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
    36.76

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSI GR GPIT AMS
    1677
    2295
    DSI GR GPIT AMS
    4040
    4485
    MWD - DIR
    296
    374
    MWD - GR RES DIR
    374
    4546
    VSP
    4040
    4485

  • 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
    370.0
    36
    370.0
    0.00
    LOT
    SURF.COND.
    18 5/8
    1103.0
    26
    1103.0
    1.63
    LOT
    INTERM.
    13 3/8
    2252.0
    17 1/2
    2252.0
    1.79
    LOT
    INTERM.
    9 5/8
    4546.0
    12 1/4
    4546.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    0
    0.00
    OIL BASED
    4620
    1.35
    26.0
    OIL BASED
    4629
    1.35
    26.0
    OIL BASED
    4663
    1.37
    27.0
    OIL BASED
    4672
    1.43
    34.0
    OIL BASED
    4680
    1.43
    36.0
    OIL BASED
    4684
    1.25
    BRINE
    4688
    1.43
    39.0
    OIL BASED
    4719
    1.43
    40.0
    OIL BASED
    4722
    1.43
    39.0
    OIL BASED
    4803
    1.43
    40.0
    OIL BASED
    4898
    1.30
    BRINE
    4935
    1.43
    42.0
    OIL BASED
    4970
    1.43
    40.0
    OIL BASED
    5080
    1.43
    43.0
    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
    0.24