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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34/8-9 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.
    34/8-9 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
    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
    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.
    34/8-9
    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.
    Norsk Hydro Produksjon 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.
    746-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.
    65
    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,
    25.10.1992
    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.
    28.12.1992
    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.
    28.12.1994
    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.
    21.12.2012
    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
    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.
    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.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    301.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3530.0
    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).
    3382.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    37.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    118
    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.
    LATE TRIASSIC
    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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 18' 50.53'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 23' 17.89'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6798082.19
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    467241.65
    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.
    2029

  • Wellbore history
    General
    Well 34/8-9 S is located on the A-structure on the Visund Field. This is a NNE-SSW oriented elongated fault block with the Pre-Cretaceous strata dipping towards WNW. The A-Central fault divides the A-structure into the A-North and A-South compartments. Well 34/8-9 S was drilled on the southern part of the A-South compartment. The primary objective was to establish the inferred OWC at 3100m TVD and confirm the pressure regime in the Statfjord and Amundsen Formations. The secondary objective was to determine the hydrocarbon potential of the Cook Formation in the structure. The well was designed deviated in order that both objectives could be fully evaluated. Furthermore the spud location of the well was chosen so that an optimal, up-dip, sidetrack could be drilled in order to appraise the Lunde A-south gas condensate discovery.
    Operations and results
    Appraisal well 34/8-9 S was spudded with the semi-submersible installation West Delta on 25 October 1992. The first 36" top hole was abandoned because after casing was set due to drill string lost in hole. The rig was moved 28 m from first spud location and re-spudded. The rig downtime for this well amounted to 30% of the total rig time. Most of this was drilling equipment repairs and fishing for equipment, but no single event had any serious consequence for the personnel or the well objectives. The well was drilled to TD at 3530 m in the Late Triassic Lunde Formation. The well was drilled with seawater and hi-vis pills down to 1698 m and with HF-plus KCl/polymer mud from 1698 m to TD.
    The Viking Group, Draupne Formation was encountered at 2903. 5 m (2873.5 m TVD). Weak source rock shows were recorded in these shales. The Brent Group was encountered from 2922.5 m to 2983.5 m (2889.5 m TVD to 2940 m TVD). From a gross Brent Group thickness of 61m a net sand thickness of 47 m was identified, with average porosity of 20.8 %. Wire line logs confirmed ca 11 m oil column with an OWC at 2931 m (2900.6 m TVD). RFT pressure tests suggested a free water level around 2933 m (2902.6 m). The Formation pressure in the Brent Group revealed two separate water regimes, approximately 2.1 and 2.8 bar lower than the established common Brent water gradient on the Visund Field. The pressure data showed two separate water regimes also in the Statfjord Formation, ca 1.3 and 2.0 bar lower than the common water gradient interpreted from wells 34/8-1 and 34/8-5.
    The Cook, Statfjord and Lunde formations were all water wet. The Cook Formation had no shows, the Statfjord Formation had weak shows on the cores from 3170.5 m to 3196 m and the Lunde Formation had weak shows in the upper part from 3417 to 3426 m.
    Six conventional cores were cut in the well. One core was cut in the Nordland Group (Utsira Formation), two cores were taken in the Brent Group, and one core was taken over the Amundsen/Statfjord Formation boundary. Further two cores were taken in the Statfjord Formation. Two RFT fluid samples were taken at 2926.3 m (11 l oil, 0.84 Sm3 gas, and 2.6 l water/filtrate), and 3156 m (water/filtrate).
    The well was permanently abandoned on 28 December 1992 as an oil appraisal well.
    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]
    1370.00
    3530.00

  • 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
    1109.0
    1113.3
    [m ]
    2
    2936.0
    2947.5
    [m ]
    3
    2948.5
    2954.0
    [m ]
    5
    3170.5
    3176.0
    [m ]
    6
    3178.0
    3192.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    41.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1109-1113m
    Core photo at depth: 1113-1113m
    Core photo at depth: 2936-2940m
    Core photo at depth: 2940-2944m
    Core photo at depth: 2944-2947m
    1109-1113m
    1113-1113m
    2936-2940m
    2940-2944m
    2944-2947m
    Core photo at depth: 2948-2952m
    Core photo at depth: 2952-2954m
    Core photo at depth: 3170-3174m
    Core photo at depth: 3174-3176m
    Core photo at depth: 3178-3182m
    2948-2952m
    2952-2954m
    3170-3174m
    3174-3176m
    3178-3182m
    Core photo at depth: 3182-3186m
    Core photo at depth: 3186-3190m
    Core photo at depth: 3190-3192m
    Core photo at depth:  
    Core photo at depth:  
    3182-3186m
    3186-3190m
    3190-3192m

  • 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
    414.0
    36
    415.0
    0.00
    LOT
    INTERM.
    13 3/8
    1344.0
    17 1/2
    1359.0
    1.55
    LOT
    INTERM.
    9 5/8
    2451.0
    12 1/4
    2467.0
    1.80
    LOT
    OPEN HOLE
    3530.0
    8 1/2
    3530.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL GR
    2070
    2449
    ACL GR SP
    2449
    3523
    COREGUN GR
    2895
    3149
    DIFL ACL GR SP CHT
    330
    2466
    DLL MLL GR
    1862
    3509
    FMT GR
    2921
    3290
    FMT GR
    2922
    3192
    FMT GR
    2926
    2926
    FMT GR
    2926
    2973
    FMT GR
    2931
    3486
    HEXDIP GR
    2449
    3506
    VSP
    480
    3520
    ZDL CN GR
    330
    1271
    ZDL CN GR
    2449
    3531

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.02
    pdf
    6.59

  • 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
    2.20
    pdf
    17.82

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1109
    1.20
    WATER BASED
    1350
    1.20
    WATER BASED
    1360
    1.05
    18.0
    WATER BASED
    1698
    1.30
    17.0
    WATER BASED
    1703
    1.30
    18.0
    WATER BASED
    1940
    1.37
    19.0
    WATER BASED
    2102
    1.41
    23.0
    WATER BASED
    2467
    1.43
    21.0
    WATER BASED
    2470
    1.51
    15.0
    WATER BASED
    2531
    1.51
    22.0
    WATER BASED
    2559
    1.51
    21.0
    WATER BASED
    2665
    1.51
    22.0
    WATER BASED
    2707
    1.51
    23.0
    WATER BASED
    2749
    1.51
    24.0
    WATER BASED
    2869
    1.60
    28.0
    WATER BASED
    2899
    1.62
    27.0
    WATER BASED
    2924
    1.64
    29.0
    WATER BASED
    3015
    1.64
    34.0
    WATER BASED
    3135
    1.64
    30.0
    WATER BASED
    3162
    1.64
    32.0
    WATER BASED
    3171
    1.65
    32.0
    WATER BASED
    3190
    1.64
    31.0
    WATER BASED
    3243
    1.64
    26.0
    WATER BASED
    3285
    1.64
    36.0
    WATER BASED
    3332
    1.64
    40.0
    WATER BASED
    3417
    1.64
    37.0
    WATER BASED
    3435
    1.64
    34.0
    WATER BASED
    3530
    1.67
    42.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1370.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2485.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2515.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2545.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2575.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2605.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2635.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2665.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2695.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2725.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2755.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2785.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    2845.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2875.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2910.0
    [m]
    DC
    RRI
    2911.0
    [m]
    SWC
    HYDRO
    2914.0
    [m]
    SWC
    HYDRO
    2920.0
    [m]
    SWC
    HYDRO
    2925.0
    [m]
    DC
    HYDRO
    2930.0
    [m]
    DC
    HYDRO
    2935.0
    [m]
    DC
    HYDRO
    2936.0
    [m]
    C
    HYDRO
    2940.0
    [m]
    C
    HYDRO
    2941.0
    [m]
    C
    HYDRO
    2943.0
    [m]
    C
    HYDRO
    2945.0
    [m]
    DC
    HYDRO
    2951.0
    [m]
    C
    HYDRO
    2952.0
    [m]
    C
    HYDRO
    2953.0
    [m]
    C
    HYDRO
    2961.0
    [m]
    SWC
    HYDRO
    2975.0
    [m]
    SWC
    HYDRO
    2982.0
    [m]
    SWC
    HYDRO
    2988.0
    [m]
    SWC
    HYDRO
    2992.0
    [m]
    SWC
    HYDRO
    2997.0
    [m]
    SWC
    HYDRO
    3004.0
    [m]
    SWC
    HYDRO
    3006.0
    [m]
    SWC
    HYDRO
    3008.0
    [m]
    SWC
    HYDRO
    3012.0
    [m]
    SWC
    HYDRO
    3016.0
    [m]
    SWC
    HYDRO
    3019.0
    [m]
    SWC
    HYDRO
    3025.0
    [m]
    SWC
    HYDRO
    3030.0
    [m]
    SWC
    HYDRO
    3037.0
    [m]
    SWC
    HYDRO
    3051.0
    [m]
    SWC
    HYDRO
    3062.0
    [m]
    SWC
    HYDRO
    3071.0
    [m]
    SWC
    HYDRO
    3083.0
    [m]
    SWC
    HYDRO
    3089.0
    [m]
    SWC
    HYDRO
    3090.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3114.0
    [m]
    SWC
    HYDRO
    3120.0
    [m]
    SWC
    HYDRO
    3132.0
    [m]
    SWC
    HYDRO
    3149.0
    [m]
    SWC
    HYDRO
    3170.0
    [m]
    C
    HYDRO
    3173.0
    [m]
    C
    HYDRO
    3174.0
    [m]
    C
    HYDRO
    3180.0
    [m]
    C
    HYDRO
    3181.0
    [m]
    C
    HYDRO
    3183.0
    [m]
    C
    HYDRO
    3185.0
    [m]
    C
    HYDRO
    3187.0
    [m]
    C
    HYDRO
    3190.0
    [m]
    C
    HYDRO
    3202.0
    [m]
    DC
    RRI
    3217.0
    [m]
    DC
    RRI
    3232.0
    [m]
    DC
    RRI
    3250.0
    [m]
    DC
    RRI
    3265.0
    [m]
    DC
    RRI
    3280.0
    [m]
    DC
    RRI
    3295.0
    [m]
    DC
    RRI
    3310.0
    [m]
    DC
    RRI
    3327.0
    [m]
    DC
    RRI
    3340.0
    [m]
    DC
    RRI
    3352.0
    [m]
    DC
    RRI
    3390.0
    [m]
    DC
    RRI
    3405.0
    [m]
    DC
    RRI
    3420.0
    [m]
    DC
    RRI
    3435.0
    [m]
    DC
    RRI
    3485.0
    [m]
    DC
    RRI
    3512.0
    [m]
    DC
    RRI