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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6406/2-7

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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.
    6406/2-7
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    6406/2-7
    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.
    965-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.
    96
    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,
    22.09.1999
    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.
    26.12.1999
    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.
    26.12.2001
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    01.10.2014
    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.
    18.12.2002
    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
    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/CONDENSATE
    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.
    GARN 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.
    ILE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    293.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4981.0
    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).
    4977.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    177
    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° 50' 22.89'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 20' 31.18'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7193415.64
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    373929.11
    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.
    3878

  • Wellbore history
    General
    Well 6406/2-7 was the fourth wildcat drilled in the PL 199 license. The well was drilled on the eastern part of the Erlend structure in the western part of block 6406/2, southwest of the Kristin Field and northwest of the 6406/2-6 Ragnfrid discovery on Haltenbanken. The Erlend structure is an easterly dipping segmented horst. Well 6406/2-7 was drilled high on the Erlend structure's southeastern high. The main objective of well 6406/2-7 was to test the hydrocarbon potential of the Erlend structure within the Early to Middle Jurassic Fangst and Båt Group sandstones. Late Cretaceous Lysing and Lange sandstones were secondary targets for the well.
    Operations and results
    Wildcat well 6406/2-7 was spudded with the semi-submersible installation "Transocean Arctic" on 22 September 1999 and drilled to TD at 4981 m (4977 m TVD) in the Early Jurassic Tilje Formation. Shallow gas was not encountered in this well. Drilling went without major problems, but leakage in the 7" liner lap led to 8 days NPT. The well was drilled with water based bentonite mud down to 1406 m, with water based KCl mud from 1406 m to 2719 m, and with oil base mud from 2719 m to TD. Pore pressures of the Jurassic units were very high, reaching a gradient of 1.99 g/cc BMW in the upper part of the Garn Formation, and the overpressures in lower Tofte and lower Ile Formations were the highest measured in the area to date. The main result of well 6406/2-7 was the Erlend discovery of gas/condensate in the Garn and Ile Formations as proven by a DST in Garn and further MDT fluid samples in both formations. Increasing amounts of gas were measured in MDT samples upwards in Tofte Formation. In addition there were good indications of hydrocarbons in Lower Lange sandstones, but no hydrocarbon fluid samples were obtained from these units due to poor reservoir quality. The Tilje Formation appeared to be water bearing in the well position. Three conventional cores covering an 81,5 m section were cut in Not, Ile and Tofte Formations, with 97.4 % recovery. MDT samples were collected from the Garn (4558.5 m), Ile (4614.4 m and 4637.6 m), and Tofte (4712 m, 4721,7 m and 4738 m) Formations. The samples from the Garn, Upper Ile and Upper Tofte Formations contained free hydrocarbons. The deepest sample from 4738.0 m in Tofte was from a water column, whereas the other two sampled depths were in a transition zone. The samples collected from the lower Ile and Tofte Formations contained water. The well was suspended for possible later side-tracking as a gas and condensate discovery on 26 December 1999.
    Testing
    The well was production tested from perforation interval 4558-4573 m in the Garn Formation. At the end of the flow period rates were measured to 496000 Sm3/D gas and 678 Sm3/D condensate (12.7 mm choke). The Gas to Oil Ratio at separator conditions 40 bar and 40 deg C was 746 Sm3/Sm3.

  • 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]
    1410.00
    4980.00

  • 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
    4573.0
    4599.3
    [m ]
    2
    4625.0
    4656.9
    [m ]
    3
    4709.0
    4730.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    79.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4573-4578m
    Core photo at depth: 4578-4583m
    Core photo at depth: 4583-4588m
    Core photo at depth: 4588-4593m
    Core photo at depth: 4593-4598m
    4573-4578m
    4578-4583m
    4583-4588m
    4588-4593m
    4593-4598m
    Core photo at depth: 4598-4628m
    Core photo at depth: 4628-4633m
    Core photo at depth: 4633-4638m
    Core photo at depth: 4638-4643m
    Core photo at depth: 4643-4648m
    4598-4628m
    4628-4633m
    4633-4638m
    4638-4643m
    4643-4648m
    Core photo at depth: 4648-4653m
    Core photo at depth: 4653-4710m
    Core photo at depth: 4710-4715m
    Core photo at depth: 4715-4720m
    Core photo at depth: 4720-4725m
    4648-4653m
    4653-4710m
    4710-4715m
    4715-4720m
    4720-4725m
    Core photo at depth: 4725-4730m
    Core photo at depth: 4730-4730m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4725-4730m
    4730-4730m

  • 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
    379.0
    36
    379.0
    0.00
    LOT
    SURF.COND.
    18 5/8
    1399.0
    24
    1406.0
    1.80
    LOT
    INTERM.
    13 3/8
    2707.0
    17 1/2
    2719.0
    1.96
    LOT
    INTERM.
    9 5/8
    4458.0
    12 1/4
    4464.0
    2.18
    LOT
    LINER
    7
    4981.0
    8 1/2
    4981.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4558
    4573
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    50.000
    78.000
    164
    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
    678
    496000
    0.806
    731

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AITB IPLT
    2710
    4463
    AITB IPLT DSI AMS
    4465
    4807
    HALS PEX DSI
    1401
    2713
    LDT AMS GR
    4465
    4579
    MDT AMS GR
    4559
    4559
    MDT AMS GR
    4560
    4742
    MDT GR
    2710
    4390
    MDT GR
    4560
    4712
    MDT GR
    4742
    4928
    MLWD - CDR ISONIC
    2710
    4579
    MLWD - CDR ISONIC ADN
    4465
    4712
    MSCT GR
    2895
    4429
    MSCT GR
    4500
    4928
    MSCT GR
    4500
    4802
    MWD - MPR
    317
    2713
    VSP
    0
    0

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.85

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.74
    pdf
    1.85
    pdf
    1.96
    pdf
    1.95
    pdf
    1.32
    pdf
    0.77
    pdf
    1.52

  • 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
    6.32
    .pdf
    48.14

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    512
    1.03
    WATER BASED
    1406
    1.05
    WATER BASED
    1406
    1.39
    22.0
    KCL MUD
    1463
    1.39
    19.0
    KCL MUD
    2562
    1.68
    35.0
    KCL MUD
    2719
    1.68
    50.0
    OIL BASED
    3648
    1.72
    44.0
    OIL BASED
    4040
    1.72
    43.0
    OIL BASED
    4200
    1.86
    52.0
    OIL BASED
    4315
    1.86
    48.0
    OIL BASED
    4401
    1.86
    48.0
    OIL BASED
    4417
    1.87
    46.0
    OIL BASED
    4463
    1.87
    46.0
    OIL BASED
    4464
    1.88
    47.0
    OIL BASED
    4469
    2.04
    50.0
    OIL BASED
    4555
    2.04
    50.0
    OIL BASED
    4573
    2.04
    50.0
    OIL BASED
    4594
    2.06
    51.0
    OIL BASED
    4600
    2.06
    53.0
    OIL BASED
    4625
    2.06
    54.0
    OIL BASED
    4729
    2.06
    55.0
    OIL BASED
    4930
    1.35
    BRINE
    4930
    2.06
    14.0
    OIL BASED
    4981
    2.06
    56.0
    OIL BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1420.0
    [m]
    DC
    STRAT
    1440.0
    [m]
    DC
    STRAT
    1460.0
    [m]
    DC
    STRAT
    1480.0
    [m]
    DC
    STRAT
    1500.0
    [m]
    DC
    STRAT
    1540.0
    [m]
    DC
    STRAT
    1560.0
    [m]
    DC
    STRAT
    1580.0
    [m]
    DC
    STRAT
    1600.0
    [m]
    DC
    STRAT
    1620.0
    [m]
    DC
    STRAT
    1640.0
    [m]
    DC
    STRAT
    1660.0
    [m]
    DC
    STRAT
    1680.0
    [m]
    DC
    STRAT
    1700.0
    [m]
    DC
    STRAT
    1720.0
    [m]
    DC
    STRAT
    1740.0
    [m]
    DC
    STRAT
    1760.0
    [m]
    DC
    STRAT
    1780.0
    [m]
    DC
    STRAT
    1800.0
    [m]
    DC
    STRAT
    1840.0
    [m]
    DC
    STRAT
    1860.0
    [m]
    DC
    STRAT
    1900.0
    [m]
    DC
    STRAT
    1920.0
    [m]
    DC
    STRAT
    1940.0
    [m]
    DC
    STRAT
    1960.0
    [m]
    DC
    STRAT
    1980.0
    [m]
    DC
    STRAT
    2000.0
    [m]
    DC
    STRAT
    2020.0
    [m]
    DC
    STRAT
    2040.0
    [m]
    DC
    STRAT
    2060.0
    [m]
    DC
    STRAT
    2080.0
    [m]
    DC
    STRAT
    2100.0
    [m]
    DC
    STRAT
    2120.0
    [m]
    DC
    STRAT
    2140.0
    [m]
    DC
    STRAT
    2160.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2200.0
    [m]
    DC
    STRAT
    2220.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2260.0
    [m]
    DC
    STRAT
    2280.0
    [m]
    DC
    STRAT
    2300.0
    [m]
    DC
    STRAT
    2320.0
    [m]
    DC
    STRAT
    2340.0
    [m]
    DC
    STRAT
    2360.0
    [m]
    DC
    STRAT
    2380.0
    [m]
    DC
    STRAT
    2400.0
    [m]
    DC
    STRAT
    2420.0
    [m]
    DC
    STRAT
    2440.0
    [m]
    DC
    STRAT
    2460.0
    [m]
    DC
    STRAT
    2480.0
    [m]
    DC
    STRAT
    2500.0
    [m]
    DC
    STRAT
    2520.0
    [m]
    DC
    STRAT
    2540.0
    [m]
    DC
    STRAT
    2560.0
    [m]
    DC
    STRAT
    2580.0
    [m]
    DC
    STRAT
    2620.0
    [m]
    DC
    STRAT
    2640.0
    [m]
    DC
    STRAT
    2660.0
    [m]
    DC
    STRAT
    2680.0
    [m]
    DC
    STRAT
    2700.0
    [m]
    DC
    STRAT
    2720.0
    [m]
    DC
    STRAT
    2740.0
    [m]
    DC
    STRAT
    2760.0
    [m]
    DC
    STRAT
    2780.0
    [m]
    DC
    STRAT
    2800.0
    [m]
    DC
    STRAT
    2820.0
    [m]
    DC
    STRAT
    2840.0
    [m]
    DC
    STRAT
    2860.0
    [m]
    DC
    STRAT
    2880.0
    [m]
    DC
    STRAT
    2895.0
    [m]
    SWC
    STRAT
    2920.0
    [m]
    DC
    STRAT
    2940.0
    [m]
    DC
    STRAT
    2960.0
    [m]
    DC
    STRAT
    2980.0
    [m]
    DC
    STRAT
    3000.0
    [m]
    DC
    STRAT
    3020.0
    [m]
    DC
    STRAT
    3040.0
    [m]
    DC
    STRAT
    3060.0
    [m]
    DC
    STRAT
    3080.0
    [m]
    DC
    STRAT
    3100.0
    [m]
    DC
    STRAT
    3120.0
    [m]
    DC
    STRAT
    3140.0
    [m]
    DC
    STRAT
    3160.0
    [m]
    DC
    STRAT
    3180.0
    [m]
    DC
    STRAT
    3200.0
    [m]
    DC
    STRAT
    3220.0
    [m]
    DC
    STRAT
    3240.0
    [m]
    DC
    STRAT
    3260.0
    [m]
    DC
    STRAT
    3280.0
    [m]
    DC
    STRAT
    3300.0
    [m]
    DC
    STRAT
    3320.0
    [m]
    DC
    STRAT
    3340.0
    [m]
    DC
    STRAT
    3360.0
    [m]
    DC
    STRAT
    3380.0
    [m]
    DC
    STRAT
    3400.0
    [m]
    DC
    STRAT
    3420.0
    [m]
    DC
    STRAT
    3440.0
    [m]
    DC
    STRAT
    3460.0
    [m]
    DC
    STRAT
    3480.0
    [m]
    DC
    STRAT
    3500.0
    [m]
    DC
    STRAT
    3508.0
    [m]
    SWC
    STRAT
    3520.0
    [m]
    DC
    STRAT
    3522.0
    [m]
    SWC
    STRAT
    3532.0
    [m]
    SWC
    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
    3742.0
    [m]
    SWC
    STRAT
    3780.0
    [m]
    DC
    STRAT
    3782.5
    [m]
    SWC
    STRAT
    3800.0
    [m]
    DC
    STRAT
    3820.0
    [m]
    DC
    STRAT
    3840.0
    [m]
    DC
    STRAT
    3860.0
    [m]
    DC
    STRAT
    3880.0
    [m]
    DC
    STRAT
    3900.0
    [m]
    DC
    STRAT
    3920.0
    [m]
    DC
    STRAT
    3940.0
    [m]
    DC
    STRAT
    3955.0
    [m]
    DC
    STRAT
    3980.0
    [m]
    DC
    STRAT
    4000.0
    [m]
    DC
    STRAT
    4020.0
    [m]
    DC
    STRAT
    4040.0
    [m]
    DC
    STRAT
    4055.0
    [m]
    DC
    STRAT
    4080.0
    [m]
    DC
    STRAT
    4100.0
    [m]
    DC
    STRAT
    4120.0
    [m]
    DC
    STRAT
    4140.0
    [m]
    DC
    STRAT
    4160.0
    [m]
    DC
    STRAT
    4180.0
    [m]
    DC
    STRAT
    4200.0
    [m]
    DC
    STRAT
    4220.0
    [m]
    DC
    STRAT
    4240.0
    [m]
    DC
    STRAT
    4260.0
    [m]
    DC
    STRAT
    4280.0
    [m]
    DC
    STRAT
    4300.0
    [m]
    DC
    STRAT
    4320.0
    [m]
    DC
    STRAT
    4340.0
    [m]
    DC
    STRAT
    4360.0
    [m]
    DC
    STRAT
    4380.0
    [m]
    DC
    STRAT
    4389.5
    [m]
    SWC
    STRAT
    4390.5
    [m]
    SWC
    STRAT
    4400.0
    [m]
    DC
    STRAT
    4420.0
    [m]
    DC
    STRAT
    4440.0
    [m]
    DC
    STRAT
    4460.0
    [m]
    DC
    STRAT
    4480.0
    [m]
    DC
    STRAT
    4500.0
    [m]
    DC
    STRAT
    4500.0
    [m]
    SWC
    STRAT
    4520.0
    [m]
    DC
    STRAT
    4530.0
    [m]
    DC
    STRAT
    4540.0
    [m]
    DC
    STRAT
    4555.0
    [m]
    DC
    STRAT
    4560.0
    [m]
    DC
    STRAT
    4576.5
    [m]
    C
    STRAT
    4577.1
    [m]
    C
    STRAT
    4578.0
    [m]
    C
    STRAT
    4583.0
    [m]
    C
    STRAT
    4588.0
    [m]
    C
    STRAT
    4590.0
    [m]
    C
    STRAT
    4592.0
    [m]
    C
    STRAT
    4594.4
    [m]
    C
    STRAT
    4595.0
    [m]
    DC
    STRAT
    4598.0
    [m]
    C
    STRAT
    4602.0
    [m]
    DC
    STRAT
    4625.0
    [m]
    DC
    STRAT
    4632.3
    [m]
    C
    STRAT
    4640.5
    [m]
    C
    STRAT
    4645.0
    [m]
    C
    STRAT
    4650.0
    [m]
    C
    STRAT
    4654.7
    [m]
    C
    STRAT
    4668.0
    [m]
    DC
    STRAT
    4695.0
    [m]
    DC
    STRAT
    4704.0
    [m]
    DC
    STRAT
    4705.0
    [m]
    SWC
    STRAT
    4709.9
    [m]
    C
    STRAT
    4712.5
    [m]
    C
    STRAT
    4714.0
    [m]
    SWC
    STRAT
    4716.6
    [m]
    C
    STRAT
    4737.0
    [m]
    DC
    STRAT
    4746.0
    [m]
    DC
    STRAT
    4773.0
    [m]
    DC
    STRAT
    4800.0
    [m]
    DC
    STRAT
    4818.0
    [m]
    DC
    STRAT
    4839.0
    [m]
    DC
    STRAT
    4852.0
    [m]
    SWC
    STRAT
    4866.0
    [m]
    DC
    STRAT
    4884.0
    [m]
    DC
    STRAT
    4902.0
    [m]
    DC
    STRAT
    4925.5
    [m]
    SWC
    STRAT
    4927.5
    [m]
    SWC
    STRAT
    4929.0
    [m]
    DC
    STRAT
    4932.0
    [m]
    DC
    STRAT
    4938.0
    [m]
    DC
    STRAT
    4947.0
    [m]
    DC
    STRAT
    4956.0
    [m]
    DC
    STRAT
    4974.0
    [m]
    DC
    STRAT
    4980.0
    [m]
    DC
    STRAT