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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33/9-17

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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.
    33/9-17
    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
    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.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    33/9-17
    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.
    Mobil Exploration Norway INC
    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.
    786-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.
    33
    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,
    02.04.1994
    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.
    04.05.1994
    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.
    04.05.1996
    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.
    18.05.2004
    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.
    OIL 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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    228.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3233.0
    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).
    3230.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    120
    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.
    NESS FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 27' 18.58'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 50' 45.79'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6814193.73
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    438481.99
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    2114

  • Wellbore history
    General
    Well 33/9-17 is located immediately north of the Statfjord field, northwest of the Statfjord Nord field with the Murchison field to the west.
    The primary objective of the well was to evaluate the hydrocarbon potential of intra-Draupne sandstone informally named the Munin sandstone unit. It was designed to find commercial hydrocarbons in a structural/stratigraphic play above 3080 meters sub-sea, the interpreted oil/water contact. The secondary objective was to evaluate the Middle Jurassic sandstones of the Brent Group.
    Operations and results
    Well 33/9-17 was spudded on 2 April 1994 with the semi-submersible rig Treasure Saga and reached a total driller's depth of 3233 m RKB in the Middle Jurassic Brent Group. The well was drilled with seawater and swept with high viscosity mud down to the 12 1/4" section, while KCl/polymer/Glycol mud was used when drilling the 12 1/4" section and to TD.
    The Munin sandstone unit (3050 - 3131m) was mostly water bearing with localized hydrocarbon shows. Average water saturation within the reservoir is 89.2%. The unit consisted of 47.3 meters of net reservoir out of a gross interval of 81 meters (N/G = 58.4%). The net reservoir was of excellent quality. Average Munin porosity was 22.6% and permeability was generally over l Darcy. The Brent Group (3187 -3233m) has 22.9 meters of good quality reservoir rock from a gross sandstone thickness of 37 meters, but is water bearing. Average porosity for the reservoir rock is 19.7%.
    None of the analysed potential source rocks of this well are within the oil window and only limited early generation of hydrocarbons has taken place. The Viking Group claystones do, however, seem to have generated some hydrocarbons. These hydrocarbon products appear to be fairly sulphur-rich.
    The best source rocks found in well 33/9-17 are represented by the claystones in the upper and lower sections of the Draupne Formation and in the Munin sandstone unit. These are very rich source rocks and are oil prone. The lower section of the Draupne Formation appears to contain an almost lacustrine assemblage of kerogen.
    The Brent Group contains TOC-rich claystones, but they appear to be more gas prone although they could have some oil potential. The Tertiary and Cretaceous sections have at best a fair potential for gas generation although the base of the Cromer Knoll Group grades to the Draupne Formation and could be said to have some potential for oil generation.
    Three cores were cut through the Mime Formation of the Cromer Knoll Group and the Draupne Formation of the Viking Group. The last core penetrated some 13 m of the Munin sandstone unit. The Munin sandstone cores had good porosity. An RFT sample taken at 3087 m (logger’s depth) in the Munin sandstone unit contained water. RFT formation pressures were obtained in Draupne (Munin sandstone unit), Tarbert Formation and Ness Formation. Traces of oil shows were observed in sandy laminations within claystones of the Draupne Group immediately overlying the Munin sandstones. In the Middle Jurassic Brent Group, no oil shows were observed in sandstones of the Tarbert and Ness Formations and no cores were cut here.
    Well 33/9-17 discovered only traces of hydrocarbons within the Munin sandstone unit. These hydrocarbons were not detected during drilling (MWD) but are evident within the whole core (core depths 3045m and 3055m, measured depths 3050.5mand 3060.5m). Petrophysical analysis confirmed the existence of low oil saturations within the Munin sandstone unit.
    The well was plugged and abandoned as a dry hole with oil shows in the Munin sandstone unit on 4 May 1994.
    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]
    590.00
    3232.00

  • 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
    3029.0
    3034.5
    [m ]
    2
    3034.5
    3041.7
    [m ]
    3
    3042.5
    3059.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    29.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3029-3034m
    Core photo at depth: 3034-3035m
    Core photo at depth: 3035-3039m
    Core photo at depth: 3039-3041m
    Core photo at depth: 3042-3047m
    3029-3034m
    3034-3035m
    3035-3039m
    3039-3041m
    3042-3047m
    Core photo at depth: 3047-3052m
    Core photo at depth: 3052-3057m
    Core photo at depth: 3057-3059m
    Core photo at depth:  
    Core photo at depth:  
    3047-3052m
    3052-3057m
    3057-3059m

  • 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
    304.0
    36
    305.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    572.0
    17 1/2
    578.0
    0.00
    LOT
    INTERM.
    9 5/8
    1782.0
    12 1/4
    1792.0
    0.00
    LOT
    OPEN HOLE
    3233.0
    8 1/2
    3233.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AS - CBL VDL
    1120
    1784
    CST GR
    1826
    3213
    DIL SDL LDL CNL AMS GR
    572
    1795
    FMS LDL CNL NGS TCCB AMS
    1784
    3240
    MWD - RGD
    255
    3233
    PI DLL MSFL AS GR
    1784
    3240
    RFT HP GR TCCB AMS
    3052
    3217
    VSP GR
    520
    3230

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.59

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.56

  • 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
    286.83

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    257
    1.00
    WATER BASED
    04.05.1994
    270
    1.50
    WATER BASED
    02.05.1994
    270
    1.00
    WATER BASED
    03.05.1994
    270
    1.00
    WATER BASED
    04.05.1994
    303
    1.00
    WATER BASED
    05.04.1994
    303
    1.00
    WATER BASED
    05.04.1994
    422
    1.00
    WATER BASED
    05.04.1994
    578
    1.00
    WATER BASED
    08.04.1994
    578
    1.00
    WATER BASED
    08.04.1994
    578
    1.00
    WATER BASED
    08.04.1994
    929
    1.26
    14.0
    12.0
    WATER BASED
    11.04.1994
    1277
    1.40
    14.0
    12.0
    WATER BASED
    11.04.1994
    1645
    1.57
    30.0
    9.2
    WATER BASED
    02.05.1994
    1777
    1.47
    20.0
    25.0
    WATER BASED
    11.04.1994
    1790
    1.47
    20.0
    25.0
    WATER BASED
    12.04.1994
    1790
    1.60
    19.0
    19.0
    WATER BASED
    13.04.1994
    1871
    1.60
    19.0
    19.0
    WATER BASED
    18.04.1994
    2105
    1.60
    19.0
    19.0
    WATER BASED
    18.04.1994
    2105
    1.60
    26.0
    10.4
    WATER BASED
    18.04.1994
    2129
    1.56
    26.0
    10.4
    WATER BASED
    18.04.1994
    2236
    1.56
    32.0
    11.3
    WATER BASED
    18.04.1994
    2428
    1.56
    32.0
    11.3
    WATER BASED
    18.04.1994
    2527
    1.56
    32.0
    11.3
    WATER BASED
    19.04.1994
    2711
    1.56
    32.0
    11.3
    WATER BASED
    20.04.1994
    2814
    1.56
    32.0
    11.3
    WATER BASED
    21.04.1994
    2970
    1.56
    32.0
    11.3
    WATER BASED
    22.04.1994
    3029
    1.56
    32.0
    11.3
    WATER BASED
    25.04.1994
    3036
    1.56
    32.0
    11.3
    WATER BASED
    25.04.1994
    3060
    1.56
    32.0
    11.3
    WATER BASED
    25.04.1994
    3177
    1.56
    32.0
    11.3
    WATER BASED
    28.04.1994
    3233
    1.56
    32.0
    11.3
    WATER BASED
    28.04.1994
    3233
    1.56
    32.0
    11.3
    WATER BASED
    28.04.1994
    3233
    1.56
    32.0
    11.3
    WATER BASED
    29.04.1994

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    590.0
    [m]
    DC
    610.0
    [m]
    DC
    630.0
    [m]
    DC
    650.0
    [m]
    DC
    670.0
    [m]
    DC
    690.0
    [m]
    DC
    710.0
    [m]
    DC
    730.0
    [m]
    DC
    750.0
    [m]
    DC
    770.0
    [m]
    DC
    790.0
    [m]
    DC
    810.0
    [m]
    DC
    830.0
    [m]
    DC
    850.0
    [m]
    DC
    870.0
    [m]
    DC
    890.0
    [m]
    DC
    910.0
    [m]
    DC
    930.0
    [m]
    DC
    950.0
    [m]
    DC
    970.0
    [m]
    DC
    990.0
    [m]
    DC
    1010.0
    [m]
    DC
    1020.0
    [m]
    DC
    1030.0
    [m]
    DC
    1040.0
    [m]
    DC
    1050.0
    [m]
    DC
    1060.0
    [m]
    DC
    1070.0
    [m]
    DC
    1080.0
    [m]
    DC
    1090.0
    [m]
    DC
    1100.0
    [m]
    DC
    1110.0
    [m]
    DC
    1120.0
    [m]
    DC
    1130.0
    [m]
    DC
    1150.0
    [m]
    DC
    1170.0
    [m]
    DC
    1190.0
    [m]
    DC
    1210.0
    [m]
    DC
    1230.0
    [m]
    DC
    1250.0
    [m]
    DC
    1270.0
    [m]
    DC
    1290.0
    [m]
    DC
    1310.0
    [m]
    DC
    1330.0
    [m]
    DC
    1350.0
    [m]
    DC
    1370.0
    [m]
    DC
    1390.0
    [m]
    DC
    1410.0
    [m]
    DC
    1430.0
    [m]
    DC
    1450.0
    [m]
    DC
    1470.0
    [m]
    DC
    1490.0
    [m]
    DC
    1510.0
    [m]
    DC
    1530.0
    [m]
    DC
    1550.0
    [m]
    DC
    1570.0
    [m]
    DC
    1590.0
    [m]
    DC
    1590.0
    [m]
    DC
    1600.0
    [m]
    DC
    1610.0
    [m]
    DC
    1620.0
    [m]
    DC
    1630.0
    [m]
    DC
    1640.0
    [m]
    DC
    1650.0
    [m]
    DC
    1660.0
    [m]
    DC
    1670.0
    [m]
    DC
    1680.0
    [m]
    DC
    1690.0
    [m]
    DC
    1710.0
    [m]
    DC
    1730.0
    [m]
    DC
    1750.0
    [m]
    DC
    1770.0
    [m]
    DC
    1790.0
    [m]
    DC
    1810.0
    [m]
    DC
    1826.0
    [m]
    SWC
    1840.0
    [m]
    DC
    1852.5
    [m]
    SWC
    1866.0
    [m]
    SWC
    1880.0
    [m]
    DC
    1890.0
    [m]
    DC
    1900.0
    [m]
    DC
    1904.5
    [m]
    SWC
    1910.0
    [m]
    DC
    1920.0
    [m]
    DC
    1930.0
    [m]
    DC
    1940.0
    [m]
    DC
    1960.0
    [m]
    DC
    1985.0
    [m]
    SWC
    2000.0
    [m]
    DC
    2020.0
    [m]
    DC
    2040.0
    [m]
    DC
    2060.0
    [m]
    DC
    2083.0
    [m]
    SWC
    2090.0
    [m]
    DC
    2100.0
    [m]
    DC
    2110.0
    [m]
    DC
    2120.0
    [m]
    DC
    2140.0
    [m]
    DC
    2160.0
    [m]
    DC
    2180.0
    [m]
    DC
    2200.0
    [m]
    DC
    2220.0
    [m]
    DC
    2240.0
    [m]
    DC
    2260.0
    [m]
    DC
    2280.0
    [m]
    DC
    2300.0
    [m]
    DC
    2320.0
    [m]
    DC
    2340.0
    [m]
    DC
    2360.0
    [m]
    DC
    2380.0
    [m]
    DC
    2400.0
    [m]
    DC
    2420.0
    [m]
    DC
    2440.0
    [m]
    DC
    2460.0
    [m]
    DC
    2480.0
    [m]
    DC
    2500.0
    [m]
    DC
    2520.0
    [m]
    DC
    2540.0
    [m]
    DC
    2546.0
    [m]
    SWC
    2560.0
    [m]
    DC
    2580.0
    [m]
    DC
    2580.0
    [m]
    DC
    2600.0
    [m]
    DC
    2620.0
    [m]
    DC
    2640.0
    [m]
    DC
    2660.0
    [m]
    DC
    2680.0
    [m]
    DC
    2700.0
    [m]
    DC
    2720.0
    [m]
    DC
    2740.0
    [m]
    DC
    2760.0
    [m]
    DC
    2780.0
    [m]
    DC
    2800.0
    [m]
    DC
    2818.0
    [m]
    DC
    2836.0
    [m]
    DC
    2854.0
    [m]
    DC
    2872.0
    [m]
    DC
    2890.0
    [m]
    DC
    2908.0
    [m]
    DC
    2926.0
    [m]
    DC
    2944.0
    [m]
    DC
    2962.0
    [m]
    DC
    2971.5
    [m]
    SWC
    2980.0
    [m]
    DC
    2989.0
    [m]
    DC
    2995.0
    [m]
    DC
    2998.0
    [m]
    DC
    3002.5
    [m]
    SWC
    3005.0
    [m]
    SWC
    3010.0
    [m]
    DC
    3013.0
    [m]
    DC
    3016.0
    [m]
    DC
    3022.0
    [m]
    DC
    3022.0
    [m]
    SWC
    3025.0
    [m]
    DC
    3026.0
    [m]
    SWC
    3027.5
    [m]
    SWC
    3030.0
    [m]
    C
    3034.0
    [m]
    C
    3035.0
    [m]
    C
    3037.0
    [m]
    C
    3039.0
    [m]
    C
    3041.0
    [m]
    C
    3043.8
    [m]
    C
    3045.8
    [m]
    C
    3048.0
    [m]
    SWC
    3053.8
    [m]
    C
    3057.8
    [m]
    C
    3059.0
    [m]
    C
    3061.0
    [m]
    DC
    3064.0
    [m]
    DC
    3070.0
    [m]
    DC
    3076.0
    [m]
    SWC
    3082.0
    [m]
    DC
    3090.0
    [m]
    SWC
    3094.0
    [m]
    DC
    3097.0
    [m]
    DC
    3101.0
    [m]
    SWC
    3109.0
    [m]
    DC
    3115.0
    [m]
    DC
    3121.0
    [m]
    DC
    3127.0
    [m]
    DC
    3130.0
    [m]
    DC
    3135.0
    [m]
    SWC
    3142.0
    [m]
    DC
    3148.0
    [m]
    DC
    3151.0
    [m]
    DC
    3154.0
    [m]
    DC
    3157.0
    [m]
    DC
    3160.0
    [m]
    DC
    3166.0
    [m]
    DC
    3172.0
    [m]
    DC
    3178.0
    [m]
    DC
    3181.0
    [m]
    DC
    3184.0
    [m]
    DC
    3187.0
    [m]
    DC
    3190.0
    [m]
    DC
    3193.0
    [m]
    DC
    3199.0
    [m]
    DC
    3202.0
    [m]
    DC
    3208.0
    [m]
    DC
    3213.5
    [m]
    SWC
    3220.0
    [m]
    DC
    3226.0
    [m]
    DC
    3229.0
    [m]
    DC
    3233.0
    [m]
    DC