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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6406/3-10

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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.
    6406/3-10
    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.
    PLUGGED
    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.
    6406/3-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    Wintershall Norge 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.
    1793-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.
    81
    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,
    08.11.2019
    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.
    05.04.2020
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    12.07.2021
    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.
    05.04.2022
    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.
    08.08.2022
    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.
    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.
    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.
    EARLY 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.
    ILE 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.
    MIDDLE 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.
    TILJE FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    GARN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    34.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    312.7
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4600.0
    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).
    4600.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    161
    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° 56' 16.19'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 46' 42.63'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7203549.93
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    395009.97
    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.
    8928

  • Wellbore history
    General
    Well 6406/3-10 was drilled to test the Bergknapp prospect on the Halten Terrace in the Norwegian Sea. The primary objective was to prove oil in the Middle to Early Jurassic Fangst and B t groups. In case of a discovery the well would be tested and cored.
    Operations and results
    Wildcat well 6406/3-10 was spudded with the semi-submersible installation West Mira on 8 November 2019. West Mira completed drilling the top hole to TD in the 16" section at 2287 m and installed the 13 3/8" intermediate casing. However, problems caused by the very rough winter season and inability to essential crew change during the Covid 19 pandemic it was decided to suspend the well on 29 January 2020 and complete the remaining well scope with a different drilling unit. Two months later, the Scarabeo 8 went on contract on 3 March 2020 and drilled the remaining part of the well to TD at 4600 m in the Early Jurassic re Formation. The well was drilled with seawater and hi-vis pills down to 418 m, with KCl/polymer/GEM mud from 418 m to 1197 m and with Innovert NS oil-based mud from 1197 m to final TD. Scarabeo 8 went off contract on 5 April 2020 and the wellbore 6406/3-10 was again suspended for a year until it was re-entered with DeepSea Aberdeen for drill stem testing.
    The well proved hydrocarbons in the Garn, Ile, Tilje and re formations. The Garn Formation had an oil column of at least 60 meters, with the oil-water contact estimated at 4128.7 m based on the log response and the oil and water samples taken in the reservoir. The Ile Formation was penetrated with a 65-meter oil column. The reservoir has a high hydrocarbon saturation at the top of the interval, while the rest of the reservoir is likely in a transition zone. The reservoir was classified as poor and not producible and the hydrocarbon-water contact was not established. The Tilje Formation has an oil column of at least 120 meters. The Tilje reservoir has two oil-saturated intervals separated by a shaly zone, and a water-saturated zone at the base. ODTs in the Upper and Lower Tilje are estimated at 4458 m and 4506 m, respectively. The re Formation contains a lighter oil than Garn, Ile, and Tilje, Geochemical analyses also indicated a more terrigenous source for this oil. No oil-water contact was established. There were no oil shows other than in the hydrocarbon-bearing formations in the Fangst and B t Groups.
    No cores were cut in 6406/3-10, coring was instead planned to do in a side-track. Wireline fluid samples were taken at 4065.2 m (Oil), 4114.7 m (oil and trace water), 4132.2 m (water), 4231.8 m (OBM filtrate), 4447.7 m (oil), 4480 m (oil), 4502.7 m (oil), and 4528 m (water).
    The well was plugged back for side-tracking on 14 July as an oil discovery.
    Testing
    Three DSTs were run in the well during 15 June and 2 July 2021. DST 1 in the Lower Tilje Formation tested the interval 4487.5 - 4492.6 m, DST 2 in the Upper Tilje Formation with tested the interval 4432.0 - 4454.5 m, and DST 3 in the Garn Formation with tested the interval 4057.7 - 4096. 0 m. The main flow results are given here. DST 1 produced 417 Sm3 oil and 125149 Sm3 gas/day through a 36/64 " choke. This gives a GOR of 300 Sm3/Sm3. The bottom hole temperature in the test was 156 C. DST 2 produced 92 Sm3 oil and 24604 Sm3 gas/day through a 26/64 " choke. This gives a GOR of 267 Sm3/Sm3. The bottom hole temperature in the test was 156 C. DST 3 produced 45 Sm3 oil and 22542 Sm3 gas/day through a 24/64 " choke. This gives a GOR of 501 Sm3/Sm3. The bottom hole temperature in the test was 149 C.

  • 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]
    430.00
    4600.00

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    0
    0
    14.0
    2.0
    0
    0
    10.3
    3.0
    0
    0
    9.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    34.800
    156
    2.0
    29.300
    156
    3.0
    18.200
    149
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    417
    125149
    2.0
    92
    24604
    3.0
    45
    22542

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    6CAL DSL RCX SDP
    4064
    4538
    6CAL DSL RCX SSP
    4049
    4600
    DSL CN ZDL FTEX 3DEX HDIL
    4049
    4600
    DSL MRX FLEX 6CAL
    4049
    4600
    LWD - DIR
    345
    418
    LWD - DIR PWD GR RES
    418
    1197
    LWD - DIR PWD GR RES ABG
    1197
    2287
    LWD - DIR PWD GR RES RAB DEN NEU
    4055
    4600
    LWD - DIR PWG GR RES ABG DEN NEU
    2287
    4055
    LWD - SON FTWD ABG FTWD
    4055
    4600
    MC SWC
    4049
    4600
    VSI5
    4049
    4600
    XMAC GXPL ORIT UXPL
    4049
    4600

  • 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
    36
    417.5
    42
    419.0
    0.00
    SURF.COND.
    20
    1191.5
    26
    1198.0
    1.88
    FIT
    INTERM.
    13 3/8
    2281.5
    17 1/2
    2293.0
    1.95
    FIT
    LINER
    9 5/8
    4049.0
    12 1/4
    4058.0
    1.87
    FIT
    OPEN HOLE
    4600.0
    8 1/2
    4600.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    340
    1.26
    19.0
    4.7
    INNOVERT
    360
    1.02
    1.0
    3.8
    Sea Water
    417
    1.39
    11.9
    Water
    1086
    1.39
    15.3
    Water
    1147
    1.38
    12.9
    Water
    1197
    1.50
    11.4
    Oil
    1197
    1.39
    11.0
    Water
    1239
    1.50
    9.5
    Oil
    1786
    1.52
    13.4
    Oil
    2090
    1.55
    14.3
    Oil
    2270
    1.74
    7.6
    Oil
    4055
    1.76
    7.6
    Oil
    4055
    1.25
    5.7
    Oil
    4470
    1.27
    0.4
    Salt Base
    4476
    1.26
    7.6
    Oil
    4476
    1.27
    0.4
    Salt Base
    4534
    1.25
    7.1
    Oil
    4596
    1.26
    20.0
    4.7
    INNOVERT
    4600
    1.25
    6.2
    Oil
    5037
    1.02
    1.0
    3.8
    Sea Water