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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34/7-3

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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.
    34/7-3
    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.
    34/7-3
    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.
    436-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.
    111
    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,
    14.09.1984
    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.
    02.01.1985
    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.
    02.01.1987
    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.
    01.04.2012
    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.
    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.
    STATFJORD GP
    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.
    LATE TRIASSIC
    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.
    LUNDE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    303.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3414.0
    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).
    3413.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    113
    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° 25' 54.08'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 7' 43.89'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6811345.10
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    453522.97
    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.
    442

  • Wellbore history
    General
    Well 34/7-3 was drilled on the Snorre E structure in the northern part of block 34/7. The purpose was to further appraise the reservoir potential of the Statfjord Formation and upper Lunde Formation in the E-structure extension of the Snorre Discovery and to test the oil/water contact found in wells 34/4-4 and 34/7-1.
    Operations and results
    Well 34/7-3 was spudded with the semi-submersible installation Vildcat Explorer on 14 September 1984 and drilled to TD at 3414 m in the Late Triassic Lunde Formation. Drilling proceeded without significant problems. The well was drilled with spud mud down to 454 m, with gel mud from 454 m to 1165 m, with KCl/Polymer mud from 1165 m to 2769 m, and with ligno/lignosulphonate mud from 2769 m to TD.
    The well consisted mainly of claystones in the Tertiary and Cretaceous sections, with the exception of sand development in the Utsira Formation (Miocene), and an Early Oligocene sand development (1288 - 1323 m). The rest of the well, the Jurassic and Triassic sections, was mainly composed of alternating claystone/sandstone sequences. Top Statfjord was encountered at 2414 m.The Statfjord and Lunde Formations were oil filled down to a common OWC at 2610 m based on pressure gradients. Strong shows on cores continued down to 2622 m, below this depth the shows became weak and spotted. Apart from this oil shows, of variable quality, started in silty claystones at 2180 m in the Late Cretaceous and continued down to 2755 m in the Lunde Formation.
    A total of 19 cores were taken in the interval 2396 - 2643 m in the Jurassic (Dunlin- and Statfjord Formations) and the Triassic sequence (Upper Lunde Formation). The core recovery was 91.5%. Core depth for core 17 was 0.5 m deeper than logger's depth and core depth for core 19 was 2.0 m shallower than logger's depth. Otherwise core depths were found equal to logger's depth. In addition to conventional cores 240 sidewall cores were recovered in this well. RFT fluid samples were taken at 2418 m (oil), 2475 m (oil/water/mud), and 2605 (water and mud filtrate with small amount of oil)
    The well was permanently abandoned on 2 January 1985 as an oil appraisal well.
    Testing
    Three drill stem tests were carried out.
    DST 1 tested the interval 2601.0 to 2607.5 m in the upper Lunde Formation. It produced 293 Sm3 oil/day through an 8 mm choke. The separator GOR was 28.5 Sm3/Sm3, the oil density was 0.840 g/cm3, and the gas gravity was . The down hole temperature measured in the test was 94.4 deg C.
    DST 2 tested the interval 2505.0 to 2513 m in the Statfjord Formation. It produced 666 Sm3 oil/day through an 11 mm choke. The separator GOR was 26 Sm3/Sm3, the oil density was 0.836 g/cm3, and the gas gravity was . The down hole temperature measured in the test was 91.4 deg C
    DST 3 tested the interval 2440.9 to 2449 m in the Statfjord Formation. It produced 1390 Sm3 oil/day through a 12.7 mm choke. The separator GOR was 32 Sm3/Sm3, the oil density was 0.838 g/cm3, and the gas gravity was . The down hole temperature measured in the test was 89.4 deg C.
    All tests produced clean oil with no water or sand. The initial oil formation volume factor ranged from 1.23 m3 /Sm3 to 1.35 m3 /Sm3 in DST1 to DST3 test intervals respectively.

  • 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]
    460.00
    3379.00

  • 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
    2396.0
    2414.0
    [m ]
    2
    2414.0
    2414.5
    [m ]
    3
    2414.5
    2425.5
    [m ]
    4
    2425.5
    2434.1
    [m ]
    5
    2439.0
    2449.8
    [m ]
    6
    2450.0
    2458.8
    [m ]
    7
    2459.5
    2467.8
    [m ]
    8
    2469.0
    2470.7
    [m ]
    9
    2471.0
    2481.5
    [m ]
    10
    2481.5
    2486.8
    [m ]
    11
    2487.5
    2505.5
    [m ]
    13
    2506.5
    2515.5
    [m ]
    14
    2515.5
    2518.0
    [m ]
    15
    2519.0
    2527.0
    [m ]
    16
    2527.5
    2528.4
    [m ]
    17
    2549.5
    2553.0
    [m ]
    18
    2606.0
    2623.0
    [m ]
    19
    2625.0
    2643.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    160.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    DST1
    2601.00
    2607.50
    05.12.1984 - 06:07
    YES
    DST
    DST3B
    2440.90
    2449.40
    OIL
    25.12.1984 - 22:10
    YES

  • 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
    451.0
    36
    454.0
    0.00
    LOT
    SURF.COND.
    20
    1153.0
    26
    1168.0
    1.62
    LOT
    INTERM.
    13 3/8
    1922.0
    17 1/2
    1940.0
    1.70
    LOT
    INTERM.
    9 5/8
    2753.0
    12 1/4
    2786.0
    1.96
    LOT
    OPEN HOLE
    3414.0
    8 1/2
    3414.0
    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
    2601
    2607
    8.0
    2.0
    2505
    2513
    11.0
    3.0
    2441
    2449
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    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
    300
    8400
    0.840
    28
    2.0
    680
    17680
    0.836
    26
    3.0
    1370
    43872
    0.838
    32

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    0
    0
    BGL CAL GR
    1153
    1924
    BGL GR
    451
    1158
    CDR CAL GR
    1152
    1826
    CDR CAL GR
    1153
    1924
    CNL EPL PCT NGT
    1921
    2761
    CNL GR
    2752
    3412
    CST
    0
    0
    DLL MSFL GR
    2335
    2764
    GR
    322
    451
    ISF LSS GR
    451
    1162
    ISF LSS GR
    1153
    1923
    ISF LSS MSFL GR
    2752
    3411
    ISF MSFL BHC GR
    1921
    2543
    LDL
    1921
    2767
    LDL GR
    451
    1163
    LDL GR
    1153
    1924
    LDL NGL
    2752
    3412
    RFT HP GR
    1921
    2543
    RFT HP GR
    1921
    2768
    RFT HP GR
    2752
    3413
    SHDT GR
    1921
    2768
    SHDT GR
    2752
    3413
    VSP
    451
    3412

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.43
    pdf
    1.73
    pdf
    0.71
    pdf
    0.19
    pdf
    2.90

  • 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
    17.12

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    354
    1.03
    WATER BASED
    16.09.1984
    652
    1.07
    WATER BASED
    16.09.1984
    1021
    1.13
    46.0
    31.0
    WATER BASED
    17.09.1984
    1165
    1.19
    45.0
    30.0
    WATER BASED
    25.09.1984
    1165
    1.14
    48.0
    31.0
    WATER BASED
    20.09.1984
    1165
    1.19
    45.0
    30.0
    WATER BASED
    25.09.1984
    1165
    1.24
    52.0
    34.0
    WATER BASED
    25.09.1984
    1165
    1.26
    53.0
    35.0
    WATER BASED
    25.09.1984
    1165
    1.13
    48.0
    32.0
    WATER BASED
    20.09.1984
    1165
    1.14
    48.0
    31.0
    WATER BASED
    20.09.1984
    1165
    1.24
    52.0
    34.0
    WATER BASED
    25.09.1984
    1165
    1.26
    53.0
    35.0
    WATER BASED
    25.09.1984
    1165
    1.26
    50.0
    28.0
    WATER BASED
    25.09.1984
    1165
    1.26
    50.0
    28.0
    WATER BASED
    25.09.1984
    1168
    1.26
    48.0
    22.0
    WATER BASED
    25.09.1984
    1168
    1.13
    44.0
    10.0
    WATER BASED
    01.10.1984
    1168
    1.13
    44.0
    10.0
    WATER BASED
    01.10.1984
    1430
    1.13
    44.0
    10.0
    WATER BASED
    01.10.1984
    1575
    1.28
    50.0
    20.0
    WATER BASED
    01.10.1984
    1860
    1.37
    50.0
    20.0
    WATER BASED
    03.10.1984
    1940
    1.46
    55.0
    19.0
    WATER BASED
    03.10.1984
    1940
    1.50
    59.0
    20.0
    WATER BASED
    04.10.1984
    1940
    1.50
    54.0
    18.0
    WATER BASED
    07.10.1984
    1940
    1.50
    58.0
    20.0
    WATER BASED
    07.10.1984
    1940
    1.50
    59.0
    20.0
    WATER BASED
    04.10.1984
    1940
    1.50
    54.0
    18.0
    WATER BASED
    07.10.1984
    1940
    1.50
    58.0
    20.0
    WATER BASED
    07.10.1984
    1945
    1.50
    55.0
    18.0
    WATER BASED
    07.10.1984
    2214
    1.67
    17.0
    18.0
    WATER BASED
    11.10.1984
    2309
    1.68
    21.0
    18.0
    WATER BASED
    14.10.1984
    2376
    1.73
    24.0
    15.0
    WATER BASED
    14.10.1984
    2396
    1.73
    24.0
    15.0
    WATER BASED
    14.10.1984
    2428
    1.70
    23.0
    14.0
    WATER BASED
    31.10.1984
    2428
    1.70
    24.0
    14.0
    WATER BASED
    01.11.1984
    2428
    1.70
    24.0
    14.0
    WATER BASED
    01.11.1984
    2611
    1.70
    24.0
    16.0
    WATER BASED
    02.11.1984
    2699
    1.70
    52.0
    16.0
    WATER BASED
    03.12.1984
    2699
    1.70
    52.0
    16.0
    WATER BASED
    03.12.1984
    2699
    1.61
    70.0
    20.0
    WATER BASED
    03.12.1984
    2786
    1.63
    20.0
    14.0
    WATER BASED
    15.11.1984
    2846
    1.61
    20.0
    14.0
    WATER BASED
    19.11.1984
    2934
    1.61
    70.0
    20.0
    WATER BASED
    03.12.1984
    3034
    1.61
    19.0
    14.0
    WATER BASED
    19.11.1984
    3197
    1.61
    19.0
    14.0
    WATER BASED
    21.11.1984
    3318
    1.61
    63.0
    12.0
    WATER BASED
    21.11.1984
    3372
    1.61
    63.0
    12.0
    WATER BASED
    23.11.1984
    3414
    1.61
    67.0
    12.0
    WATER BASED
    26.11.1984
    3414
    1.61
    69.0
    12.0
    WATER BASED
    26.11.1984
    3414
    1.61
    70.0
    10.0
    WATER BASED
    27.11.1984
    3414
    1.61
    70.0
    10.0
    WATER BASED
    29.11.1984
    3414
    1.61
    65.0
    12.0
    WATER BASED
    26.11.1984
    3414
    1.61
    69.0
    10.0
    WATER BASED
    27.11.1984
    3414
    1.61
    67.0
    12.0
    WATER BASED
    26.11.1984
    3414
    1.61
    69.0
    12.0
    WATER BASED
    26.11.1984
    3414
    1.61
    69.0
    10.0
    WATER BASED
    27.11.1984
    3414
    1.61
    70.0
    10.0
    WATER BASED
    29.11.1984
    3414
    1.61
    70.0
    10.0
    WATER BASED
    27.11.1984

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1095.0
    [m]
    SWC
    RRI
    1125.0
    [m]
    SWC
    RRI
    1135.0
    [m]
    SWC
    RRI
    1155.0
    [m]
    SWC
    RRI
    1170.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1195.0
    [m]
    SWC
    RRI
    1220.0
    [m]
    DC
    RRI
    1235.0
    [m]
    SWC
    RRI
    1240.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1275.0
    [m]
    SWC
    RRI
    1290.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1395.0
    [m]
    SWC
    RRI
    1415.0
    [m]
    SWC
    RRI
    1425.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1455.0
    [m]
    SWC
    RRI
    1470.0
    [m]
    DC
    RRI
    1485.0
    [m]
    DC
    RRI
    1495.0
    [m]
    SWC
    RRI
    1515.0
    [m]
    DC
    RRI
    1535.0
    [m]
    SWC
    RRI
    1545.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1605.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1800.0
    [m]
    SWC
    RRI
    1828.0
    [m]
    SWC
    RRI
    1850.0
    [m]
    SWC
    RRI
    1860.0
    [m]
    DC
    RRI
    1875.0
    [m]
    SWC
    RRI
    1890.0
    [m]
    DC
    RRI
    1900.0
    [m]
    SWC
    RRI
    2240.0
    [m]
    SWC
    RRI
    2260.0
    [m]
    DC
    RRI
    2330.0
    [m]
    SWC
    RRI
    2355.1
    [m]
    SWC
    RRI
    2362.0
    [m]
    DC
    RRI
    2364.0
    [m]
    SWC
    RRI
    2380.0
    [m]
    SWC
    RRI
    2388.0
    [m]
    SWC
    RRI
    2396.0
    [m]
    C
    RRI
    2414.7
    [m]
    C
    RRI
    2429.2
    [m]
    C
    RRI
    2449.8
    [m]
    SWC
    RRI
    2452.3
    [m]
    C
    RRI
    2454.9
    [m]
    C
    RRI
    2656.0
    [m]
    DC
    RRI
    2671.0
    [m]
    DC
    RRI
    2683.0
    [m]
    DC
    RRI
    2884.0
    [m]
    DC
    RRI