Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/9-16

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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.
    30/9-16
    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
    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.
    30/9-16
    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.
    789-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.
    56
    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,
    14.06.1994
    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.
    08.08.1994
    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.
    08.08.1996
    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.
    13.01.2015
    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/GAS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    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.
    LATE 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.
    INTRA HEATHER FM SS
    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.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    101.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3550.0
    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).
    3549.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    131
    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.
    EIRIKSSON FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 15' 10.35'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 45' 0.84'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6679756.73
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    486174.38
    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.
    2361

  • Wellbore history
    General
    Well 30/9-16 was drilled on the Bjørgvin Arch south of the Oseberg Fault block in the North Sea. The primary objective was to prove hydrocarbon accumulations in the Tarbert Formation and the “NORE” (lower Brent Group) reservoir. Secondary objective was to test the hydrocarbon potential in the Cook Formation and Statfjord Group reservoirs within closure.
    Operations and results
    Wildcat well 30/9-16 was spudded with the semi-submersible installation West Vanguard on 14 June 1994 and drilled to TD at 3550 m in the Early Jurassic Eiriksson Formation. No significant problem was encountered in the operations. The well was drilled with spud mud down to 165 m, with ANCO 2000 mud from 165 m to 2668 m, and with KCl/polymer mud from 2668 m to TD.
    Intra Heather Formation sandstone came in at 2685 m and proved to be gas bearing with GOC at 2706 m, based on geochemical data. Based on RFT pressure gradients the GOC is at 2711 m. The Tarbert Formation came in at 2718 m and was 101 m thick, 11 m thicker than prognosed. It was oil-bearing with an OWC at 2764 m. There is a 10 bars pressure difference in the oil zone, between 30/9-13 S and 30/9-16. The 30/9-9 Lower Ness oil gradient is 14 bars higher than the 30/9-16 oil gradient. The water gradient is only 1.5 bars higher than 30/9-13 S and three bars lower than 30/9-9. No hydrocarbons or shows were reported below OWC in the Brent Group, but weak shows, with gas shows at the top and oil shows below, were reported from the Statfjord Group at 3455 – 3475 m. Further, down to TD, these shows disappeared or became localised.
    Four cores were cut. The three first were cut from 2694 m in the Heather Formation sandstone to 2796.4 m in the Tarbert Formation. Core 4 was cut from 3459 m to 3486.2 m in the upper part of the Statfjord Group. An RFT fluid sample was taken at 2727 m in the Tarbert Formation. It contained oil and water.
    The well was permanently abandoned on 8 August 1994 as an oil and gas discovery.
    Testing
    Two drill stem tests were performed.
    DST 1 tested the interval 2722 - 2753 m in the Tarbert Formation. It produced 264000 Sm3 gas and 1600 Sm3 oil/day through a 72/64” choke. The GOR was 165 Sm3/Sm3, the oil density was 0.836 g/cc density, and the gas gravity was 0.733 (air = 1) with 2.1 % CO2 and 1.5 ppm H2S. The flowing bottom hole temperature was 106.6 °C.
    DST2 tested the interval 2685.1 - 2694.1 min the Intra-Heather Formation sandstone.
    It produced 722000 Sm3 gas and 238 Sm3 oil/day through a 64/64” choke. The GOR was 3030 Sm3/Sm3, the condensate density was 0.836 g/cc density, and the gas gravity was 0.733 (air = 1) with 2.1 % CO2 and 1.5 ppm H2S. The flowing bottom hole temperature was 106.6 °C.
    No water was produced in the tests.

  • 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]
    1590.00
    3550.00

  • 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
    2694.0
    2722.4
    [m ]
    2
    2722.5
    2759.7
    [m ]
    3
    2759.7
    2796.4
    [m ]
    4
    3459.0
    3486.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    129.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2694-2699m
    Core photo at depth: 2699-2704m
    Core photo at depth: 2704-2709m
    Core photo at depth: 2709-2714m
    Core photo at depth: 2714-2719m
    2694-2699m
    2699-2704m
    2704-2709m
    2709-2714m
    2714-2719m
    Core photo at depth: 2719-2722m
    Core photo at depth: 2722-2727m
    Core photo at depth: 2727-2732m
    Core photo at depth: 2732-2737m
    Core photo at depth: 2737-2742m
    2719-2722m
    2722-2727m
    2727-2732m
    2732-2737m
    2737-2742m
    Core photo at depth: 2742-2747m
    Core photo at depth: 2747-2752m
    Core photo at depth: 2752-2757m
    Core photo at depth: 2757-2759m
    Core photo at depth: 2759-2764m
    2742-2747m
    2747-2752m
    2752-2757m
    2757-2759m
    2759-2764m
    Core photo at depth: 2764-2769m
    Core photo at depth: 2769-2774m
    Core photo at depth: 2774-2779m
    Core photo at depth: 2779-2784m
    Core photo at depth: 2784-2789m
    2764-2769m
    2769-2774m
    2774-2779m
    2779-2784m
    2784-2789m
    Core photo at depth: 2789-2794m
    Core photo at depth: 2794-2796m
    Core photo at depth: 3459-3464m
    Core photo at depth: 3464-3469m
    Core photo at depth: 3469-3474m
    2789-2794m
    2794-2796m
    3459-3464m
    3464-3469m
    3469-3474m
    Core photo at depth: 3474-3479m
    Core photo at depth: 3479-3484m
    Core photo at depth: 3484-3486m
    Core photo at depth:  
    Core photo at depth:  
    3474-3479m
    3479-3484m
    3484-3486m

  • 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
    2753.00
    2722.00
    OIL
    23.04.1994 - 06:45
    YES
    DST
    DST2
    2694.10
    2685.10
    OIL
    02.08.1994 - 12:00
    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
    207.0
    36
    208.0
    0.00
    SURF.COND.
    13 3/8
    1578.0
    17 1/2
    1588.0
    1.70
    LOT
    INTERM.
    9 5/8
    2658.0
    12 1/2
    2668.0
    1.60
    FIT
    LINER
    7
    2958.0
    8 1/2
    3550.0
    0.00

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2722
    2753
    28.6
    2.0
    2685
    2694
    25.4
    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
    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
    1604
    264000
    0.836
    165
    2.0
    283
    722000
    0.750
    3030

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    2970
    3550
    DLL LSS GP GR CAL AMS
    123
    3353
    FMI GR AMS
    2658
    3352
    LDL CNL
    1578
    3532
    NGT
    2658
    3301
    NGT
    2658
    3523
    RFT
    2688
    2990
    RFT
    2688
    2790
    RFT
    3185
    3519
    VSP
    460
    3540

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.37
    pdf
    0.47

  • 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
    14.67
    pdf
    19.85

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    123
    1.05
    WATER BASED
    14.06.1994
    208
    1.05
    WATER BASED
    15.06.1994
    488
    1.05
    WATER BASED
    17.06.1994
    1155
    1.05
    WATER BASED
    17.06.1994
    1588
    1.05
    WATER BASED
    20.06.1994
    1588
    1.05
    WATER BASED
    20.06.1994
    1905
    1.43
    30.0
    13.0
    WATER BASED
    24.06.1994
    2271
    1.43
    29.0
    17.0
    WATER BASED
    24.06.1994
    2379
    1.43
    29.0
    16.5
    WATER BASED
    28.06.1994
    2522
    1.43
    28.0
    15.5
    WATER BASED
    28.06.1994
    2668
    1.43
    26.0
    15.0
    WATER BASED
    28.06.1994
    2668
    1.43
    27.0
    14.5
    WATER BASED
    28.06.1994
    2668
    1.43
    27.0
    14.5
    WATER BASED
    30.06.1994
    2668
    1.45
    24.0
    16.0
    WATER BASED
    01.07.1994
    2675
    1.13
    12.0
    9.5
    WATER BASED
    08.08.1994
    2694
    1.12
    20.0
    12.5
    WATER BASED
    07.07.1994
    2760
    1.14
    16.0
    10.0
    WATER BASED
    07.07.1994
    2872
    1.14
    15.0
    11.5
    WATER BASED
    07.07.1994
    2872
    1.14
    15.0
    11.5
    WATER BASED
    07.07.1994
    2958
    1.43
    14.0
    10.0
    WATER BASED
    09.08.1994
    2958
    1.14
    15.0
    10.5
    WATER BASED
    22.07.1994
    2958
    1.13
    20.0
    12.0
    WATER BASED
    26.07.1994
    2958
    1.14
    15.0
    11.5
    WATER BASED
    01.08.1994
    2958
    1.13
    12.0
    9.5
    WATER BASED
    08.08.1994
    2958
    1.43
    15.0
    8.5
    WATER BASED
    09.08.1994
    2958
    1.13
    20.0
    12.0
    WATER BASED
    26.07.1994
    2958
    1.13
    20.0
    12.0
    WATER BASED
    27.07.1994
    2958
    1.13
    20.0
    12.0
    WATER BASED
    28.07.1994
    2958
    1.13
    18.0
    13.0
    WATER BASED
    29.07.1994
    2958
    1.13
    15.0
    12.5
    WATER BASED
    01.08.1994
    2958
    1.13
    13.0
    11.0
    WATER BASED
    02.08.1994
    2958
    1.13
    13.0
    11.5
    WATER BASED
    03.08.1994
    2958
    1.13
    21.0
    16.5
    WATER BASED
    15.07.1994
    2958
    1.13
    14.0
    13.5
    WATER BASED
    18.07.1994
    2958
    1.13
    14.0
    13.5
    WATER BASED
    18.07.1994
    2958
    1.13
    14.0
    14.0
    WATER BASED
    18.07.1994
    2958
    1.13
    13.0
    13.5
    WATER BASED
    19.07.1994
    2958
    1.13
    13.0
    13.5
    WATER BASED
    20.07.1994
    2958
    1.14
    15.0
    10.5
    WATER BASED
    21.07.1994
    2958
    1.13
    11.0
    11.0
    WATER BASED
    25.07.1994
    2959
    1.13
    20.0
    12.0
    WATER BASED
    26.07.1994
    3040
    1.12
    19.0
    11.0
    WATER BASED
    07.07.1994
    3040
    1.12
    19.0
    11.0
    WATER BASED
    07.07.1994
    3265
    1.30
    23.0
    21.0
    WATER BASED
    11.07.1994
    3265
    1.23
    213.0
    17.0
    WATER BASED
    12.07.1994
    3445
    1.30
    22.0
    16.5
    WATER BASED
    07.07.1994
    3486
    1.30
    24.0
    21.0
    WATER BASED
    11.07.1994
    3550
    1.30
    24.0
    21.0
    WATER BASED
    11.07.1994
    3550
    1.23
    20.0
    11.0
    WATER BASED
    13.07.1994
    3550
    1.30
    24.0
    21.0
    WATER BASED
    11.07.1994

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1590.0
    [m]
    DC
    SPT
    1610.0
    [m]
    DC
    SPT
    1630.0
    [m]
    DC
    SPT
    1660.0
    [m]
    DC
    SPT
    1680.0
    [m]
    DC
    SPT
    1700.0
    [m]
    DC
    SPT
    1720.0
    [m]
    DC
    SPT
    1750.0
    [m]
    DC
    SPT
    1780.0
    [m]
    DC
    SPT
    1800.0
    [m]
    DC
    SPT
    1820.0
    [m]
    DC
    SPT
    1840.0
    [m]
    DC
    SPT
    1860.0
    [m]
    DC
    SPT
    1880.0
    [m]
    DC
    SPT
    1900.0
    [m]
    DC
    SPT
    1930.0
    [m]
    DC
    SPT
    1950.0
    [m]
    DC
    SPT
    1970.0
    [m]
    DC
    SPT
    1990.0
    [m]
    DC
    SPT
    2010.0
    [m]
    DC
    SPT
    2030.0
    [m]
    DC
    SPT
    2050.0
    [m]
    DC
    SPT
    2070.0
    [m]
    DC
    SPT
    2090.0
    [m]
    DC
    SPT
    2110.0
    [m]
    DC
    SPT
    2130.0
    [m]
    DC
    SPT
    2140.0
    [m]
    DC
    SPT
    2150.0
    [m]
    DC
    SPT
    2170.0
    [m]
    DC
    SPT
    2190.0
    [m]
    DC
    SPT
    2205.0
    [m]
    DC
    SPT
    2225.0
    [m]
    DC
    SPT
    2245.0
    [m]
    DC
    SPT
    2265.0
    [m]
    DC
    SPT
    2285.0
    [m]
    DC
    SPT
    2305.0
    [m]
    DC
    SPT
    2325.0
    [m]
    DC
    SPT
    2345.0
    [m]
    DC
    SPT
    2365.0
    [m]
    DC
    SPT
    2385.0
    [m]
    DC
    SPT
    2395.0
    [m]
    DC
    SPT
    2405.0
    [m]
    DC
    SPT
    2425.0
    [m]
    DC
    SPT
    2445.0
    [m]
    DC
    SPT
    2465.0
    [m]
    DC
    SPT
    2485.0
    [m]
    DC
    SPT
    2505.0
    [m]
    DC
    SPT
    2525.0
    [m]
    DC
    SPT
    2545.0
    [m]
    DC
    SPT
    2565.0
    [m]
    DC
    SPT
    2585.0
    [m]
    DC
    SPT
    2605.0
    [m]
    DC
    SPT
    2625.0
    [m]
    DC
    SPT
    2645.0
    [m]
    DC
    SPT
    2655.0
    [m]
    DC
    SPT
    2667.0
    [m]
    DC
    SPT
    2670.0
    [m]
    SWC
    SPT
    2672.5
    [m]
    SWC
    SPT
    2679.0
    [m]
    SWC
    SPT
    2682.0
    [m]
    SWC
    SPT
    2684.0
    [m]
    SWC
    SPT
    2695.7
    [m]
    C
    SPT
    2707.8
    [m]
    C
    SPT
    2720.8
    [m]
    DC
    SPT
    2739.0
    [m]
    C
    SPT
    2796.5
    [m]
    C
    SPT
    2798.0
    [m]
    SWC
    SPT
    2807.0
    [m]
    SWC
    SPT
    2813.0
    [m]
    SWC
    SPT
    2817.0
    [m]
    DC
    SPT
    2825.0
    [m]
    DC
    SPT
    2830.0
    [m]
    SWC
    SPT
    2839.0
    [m]
    SWC
    SPT
    2850.0
    [m]
    DC
    SPT
    2855.5
    [m]
    SWC
    SPT
    2862.0
    [m]
    DC
    SPT
    2870.0
    [m]
    DC
    SPT
    2880.0
    [m]
    SWC
    SPT
    2910.0
    [m]
    DC
    SPT
    2917.0
    [m]
    DC
    SPT
    2925.0
    [m]
    DC
    SPT
    2940.0
    [m]
    SWC
    SPT
    2955.0
    [m]
    SWC
    SPT
    2965.0
    [m]
    DC
    SPT
    2976.0
    [m]
    SWC
    SPT
    2992.0
    [m]
    SWC
    SPT
    2998.0
    [m]
    SWC
    SPT
    3010.0
    [m]
    DC
    SPT
    3016.0
    [m]
    SWC
    SPT
    3020.0
    [m]
    DC
    SPT
    3033.0
    [m]
    SWC
    SPT
    3040.0
    [m]
    DC
    SPT
    3050.0
    [m]
    DC
    SPT
    3056.0
    [m]
    SWC
    SPT
    3070.0
    [m]
    SWC
    SPT
    3080.0
    [m]
    DC
    SPT
    3080.0
    [m]
    SWC
    SPT
    3100.0
    [m]
    DC
    SPT
    3110.0
    [m]
    SWC
    SPT
    3120.0
    [m]
    DC
    SPT
    3130.0
    [m]
    SWC
    SPT
    3140.0
    [m]
    DC
    SPT
    3150.0
    [m]
    SWC
    SPT
    3160.0
    [m]
    DC
    SPT
    3170.0
    [m]
    SWC
    SPT
    3185.0
    [m]
    SWC
    SPT
    3190.0
    [m]
    DC
    SPT
    3203.0
    [m]
    SWC
    SPT
    3210.0
    [m]
    DC
    SPT
    3220.0
    [m]
    SWC
    SPT
    3230.0
    [m]
    DC
    SPT
    3240.0
    [m]
    SWC
    SPT
    3250.0
    [m]
    DC
    SPT
    3260.0
    [m]
    DC
    SPT
    3265.0
    [m]
    SWC
    SPT
    3280.0
    [m]
    SWC
    SPT
    3295.0
    [m]
    SWC
    SPT
    3305.0
    [m]
    DC
    SPT
    3315.0
    [m]
    SWC
    SPT
    3325.0
    [m]
    DC
    SPT
    3335.0
    [m]
    SWC
    SPT
    3345.0
    [m]
    DC
    SPT
    3355.0
    [m]
    SWC
    SPT
    3360.0
    [m]
    DC
    SPT
    3370.0
    [m]
    DC
    SPT
    3383.0
    [m]
    SWC
    SPT
    3400.0
    [m]
    DC
    SPT
    3412.0
    [m]
    DC
    SPT
    3420.0
    [m]
    DC
    SPT
    3430.0
    [m]
    DC
    SPT
    3440.0
    [m]
    DC
    SPT
    3450.0
    [m]
    DC
    SPT
    3459.0
    [m]
    C
    SPT
    3465.0
    [m]
    DC
    SPT
    3475.0
    [m]
    DC
    SPT
    3475.0
    [m]
    C
    SPT
    3481.0
    [m]
    C
    SPT
    3490.0
    [m]
    DC
    SPT
    3500.0
    [m]
    DC
    SPT
    3510.0
    [m]
    DC
    SPT
    3521.0
    [m]
    SWC
    SPT
    3533.0
    [m]
    SWC
    SPT
    3540.0
    [m]
    DC
    SPT
    3550.0
    [m]
    DC
    SPT