Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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6407/1-5 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.
    6407/1-5 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.
    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
    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.
    6407/1-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST0614WIR10 -inline7836 & crossline 2118
    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 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.
    1357-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.
    112
    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,
    31.01.2012
    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.
    21.05.2012
    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.
    21.05.2014
    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.
    21.05.2014
    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/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.
    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.
    GARN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    298.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4177.0
    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).
    4164.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    10.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    145
    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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 59' 20.12'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 0' 17.16'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7208885.51
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    405879.91
    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.
    6774

  • Wellbore history
    General
    Well 6407/1-5 S was drilled to appraise the northern extension of the Maria Field in the Haltenbanken area in the Norwegian Sea. The primary objective was to test the sands in the Middle Jurassic Garn, Ile and Tilje Formations. In case of petroleum in the Garn Formation, a DST was planned to be carried out.
    Operations and results
    Appraisal well 6407/1-5 S was spudded with the semi-submersible installation Borgland Dolphin on 31 January 2012 and drilled to TD at 4177 m (4164 m TVD) in the Early Jurassic Tilje Formation. A 12 1/4" pilot hole was drilled from 398 m to 703 m and shallow gas was indicated. The 20" casing was set above the shallow gas zone, at 563 m. Due to the shallow gas, rough weather, rig repair, and additional coring and wire line runs total rig time became 26 days longer than planned, but otherwise there were no serious problem related to the operations and all objectives were met. It was drilled vertically down to 2300 m, with a 10.6 deg deviation from ca 2300 m to ca 3200 m and then again vertically from 3200 m through the reservoir section and down to TD. The well was drilled water based down to 1199 m and with Omniflow oil based mud from 1199 m to TD.
    The target Garn Formation was encountered at 3811 m (3797.8 m TVD) with a 40 m oil column down to the OWC at 3851 m. The Garn sandstone had a net/gross ratio of 0.99 only using a calcite flag as cut-off. The Ile and Tilje Formations were water bearing. Apart from shows in the hydrocarbon bearing section in the Garn Formation the only oil shows above the oil based mud in the well were in thin sandstone stringers in the lower part of the Melke Formation.
    Three cores were cut from 3785 m in the base of the Melke Formation to 3859 m in the Garn Formation. A fourth core was attempted but was accidentally left in the hole. RCI wire line samples were taken at 3826.5 m (oil), 3841.5 m (oil), 3858 m (water), and 3863.4 m (water).
    The well was permanently abandoned on 21 May 2012 as an oil and gas appraisal well.
    Testing
    One drill stem test was carried out from the interval 3809 m to 3832 m in the Garn Formation. The test produced 101 Sm3 oil and 18512 Sm3 gas /day through a 28/64" choke. The gas contained 6 ppm H2S and 4 % CO2. The GOR was 183 Sm3/Sm3. The bottom hole temperature in the main flow was 135.2 deg 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]
    570.00
    4175.00

  • 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
    3785.0
    3793.1
    [m ]
    2
    3793.1
    3832.6
    [m ]
    3
    3832.6
    3858.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    73.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3809
    3822
    16.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    135
    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
    101
    18512
    0.789
    0.904
    183

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GR GEOWAVES
    2100
    3900
    LWD - DIR GR PWD
    329
    562
    LWD - DIR GR RES PWD
    562
    3908
    LWD - DIR GR SON RES PWD
    398
    703
    LWD - RES BIT DIR GR RES PWD
    2015
    4177
    MARCH JAR TTR GR XMAC 6CAL ORIT
    3766
    4177
    MARCH JAR TTRM DSL CN ZDL FLEX
    3766
    4177
    MRCH JAR GR PCOR
    3857
    3869
    MRCH JAR TTR DSL CN ZDL ORIT XMA
    2015
    3773
    MRCH JAR TTRM 6TC IFX RCI SPKR D
    3826
    3858
    MRCH JAR TTRM GR EI ORIT ECBIL G
    3766
    3975
    MRCH JAR TTRM GR MREX
    3766
    4040
    MRCH JAR TTRM GR RCI IFX 6TC 4L
    3912
    3950
    RCI
    2015
    3215
    TLD APS ECS IS EDTC GR
    3766
    3895
    ZAIT ADT5 HNGS IS EDTC
    3766
    3908

  • 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
    395.0
    36
    0.0
    0.00
    SURF.COND.
    20
    556.0
    26
    556.0
    1.36
    FIT
    LINER
    16
    1163.0
    17 1/2
    1202.0
    1.63
    FIT
    LINER
    13 3/8
    1976.0
    14 3/4
    2019.0
    1.77
    FIT
    LINER
    9 5/8
    3766.0
    12 1/4
    3776.0
    1.60
    FIT
    LINER
    7
    4175.0
    8 1/2
    0.0
    0.00
    OPEN HOLE
    4177.0
    8 1/2
    0.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    395
    1.24
    21.0
    Aqua-Drill
    434
    1.39
    32.0
    Aqua-Drill
    468
    1.53
    19.0
    Aquadrill
    533
    1.24
    18.0
    Aqua-Drill
    1200
    1.24
    14.0
    Aqua-Drill
    1235
    1.34
    20.0
    Aqua-Drill
    1935
    1.53
    25.0
    Aqua-Drill
    3726
    1.69
    36.0
    Carbo-sea OBM
    3832
    1.19
    23.0
    Omniflow DIF
    3840
    1.69
    46.0
    Carbosea
    3840
    1.19
    Brine
    4177
    1.19
    23.0
    Omniflow DIF