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

30/9-9

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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.
    30/9-9
    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.
    30/9-9
    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.
    621-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.
    42
    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,
    26.09.1989
    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.
    06.11.1989
    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.
    06.11.1991
    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.
    12.01.2015
    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
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    TARBERT FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    NESS FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    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).
    2809.0
    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).
    2809.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    115
    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° 19' 51.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 52' 29.47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6688423.02
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    493089.05
    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.
    1442

  • Wellbore history
    General
    Well 30/9-9 was drilled on the J-South structure in the Oseberg Sør Field complex in the North Sea. The first well on J-South, well 30/9-5 S some 3.5 km to the north, encountered a highly eroded Brent Group with gas shows in the Brent, a gas bearing Cook Formation and a water bearing Statfjord Group. The primary objective of well 30/9-9 was to prove oil in the Brent Group and the Cook Formation, and define the oil-water contact.
    Operations and results
    Wildcat well 30/9-9 was spudded with the semi-submersible installation Polar Pioneer on 26 September 1989 and drilled to TD at 2809 m in the Early Jurassic Eiriksson Formation. No significant problem was encountered in the operations. The well was drilled with seawater and hi-vis pills down to 919 m and with KCl/polymer mud from 919 m to TD.
    The Tarbert Formation and the uppermost part of the Ness Formation were found oil bearing down to 2319 m. The net pay was estimated to be 13.5 m and average water saturation calculated to 30.1%. Average porosity was 20.8%. The Ness Formation (2307 - 2412 m) was found oil bearing from 2391.5 to 2412.5 m. No oil water contact was proved, leaving oil down to base reservoir. The net pay was estimated to be 15.5 m and average water saturation calculated to 24.3%. Average porosity was 24.9%. RFT results showed no pressure communication between the hydrocarbon bearing intervals in the Tarbert and Ness Formations.
    The Etive-Rannoch Formations and the Oseberg Formation were not present in the well, most likely due to faulting. The lower Jurassic Cook Formation and the Statfjord Group were found water bearing. Oil shows were described on claystones and sandstones from 2115 to 2175 m, throughout the Våle Formation. Shows were described on limestones in the interval 2250 to top Brent Group. These shows increased in strength downwards towards the oil-bearing reservoir. No shows are described below the deepest oil in the Ness Formation.
    Seven cores were cut in the Middle Jurassic Brent Group in four intervals: 2291 - 2317 m, 2322 - 2327 m, 2347 - 2357 m and 2393 - 2427.5 m. RFT fluid samples were taken at 2295.5 m (gas, light oil and water) and at 2346 m (water)
    The well was suspended on 6 November 1989. It was plugged and permanently abandoned on 16 August 2003. It is classified as an oil discovery.
    Testing
    Two DST tests were performed in the well.
    DST l tested the interval 2394.4 - 2409.4 m (Ness Formation). It flowed on average 946 Sm3 oil and 158000 Sm3 gas /day on a 19.05 mm choke. The GOR was 166 Sm3/Sm3, the oil gravity was 0.82 g/cm3 and the gas gravity 0.743 (air=l). The bottom hole temperature was 100°.4 C measured at 2349.34 m. The well produced 1.5% CO2 and 1.3 ppm H2S.
    DST 2 tested the interval 2294.6 - 2310.6 (Tarbert Formation and uppermost part of Ness Formation). It flowed on average 966 Sm3/day oil and 158000 Sm3 gas on a 19.05mm choke. The GOR was 164 Sm3/Sm3, the oil gravity was 0.82 g/cc and the gas gravity 0.745 (air=l). The bottom hole temperature was 99.8°C measured at 2240.5 m. The well produced 1.6% C02 and 1.5 ppm H2S.

  • 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]
    930.00
    2809.00

  • 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
    2291.0
    2304.7
    [m ]
    2
    2306.0
    2312.4
    [m ]
    3
    2313.0
    2316.0
    [m ]
    4
    2322.0
    2326.7
    [m ]
    5
    2347.0
    2357.0
    [m ]
    6
    2393.0
    2410.3
    [m ]
    7
    2411.0
    2426.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    70.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2291-2296m
    Core photo at depth: 2296-2301m
    Core photo at depth: 2301-2307m
    Core photo at depth: 2307-2312m
    Core photo at depth: 2312-2315m
    2291-2296m
    2296-2301m
    2301-2307m
    2307-2312m
    2312-2315m
    Core photo at depth: 2322-2326m
    Core photo at depth: 2347-2352m
    Core photo at depth: 2352-2356m
    Core photo at depth: 2393-2398m
    Core photo at depth: 2398-2403m
    2322-2326m
    2347-2352m
    2352-2356m
    2393-2398m
    2398-2403m
    Core photo at depth: 2403-2408m
    Core photo at depth: 2408-2413m
    Core photo at depth: 2413-2418m
    Core photo at depth: 2418-2423m
    Core photo at depth: 2423-2426m
    2403-2408m
    2408-2413m
    2413-2418m
    2418-2423m
    2423-2426m

  • 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
    TEST1
    2394.40
    2409.40
    OIL
    26.10.1989 - 00:00
    YES
    DST
    2294.60
    2310.60
    31.10.1989 - 00:00
    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
    211.0
    36
    213.0
    0.00
    LOT
    INTERM.
    13 3/8
    905.0
    17 1/2
    919.0
    1.41
    LOT
    INTERM.
    9 5/8
    2180.0
    12 1/4
    2193.0
    1.75
    LOT
    LINER
    7
    2523.0
    8 1/2
    2809.0
    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
    2394
    2409
    19.5
    2.0
    2295
    2311
    19.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    100
    2.0
    100
    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
    946
    158000
    0.822
    0.743
    166
    2.0
    966
    158000
    0.820
    0.745
    164

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AMS
    1946
    2776
    CBL VDL
    1772
    2445
    CBL VDL
    2163
    2442
    CST
    2187
    2800
    CST
    2236
    2800
    DLL MSFL GR
    2180
    2437
    FMS
    2180
    2807
    LDL CNL
    904
    2788
    MWD
    124
    2193
    NGL
    2180
    2788
    RFT
    2257
    2784
    RFT
    2295
    2303
    SGR DIL LSS
    904
    2806
    VSP
    1000
    2800

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.13
    pdf
    1.40
    pdf
    3.53

  • 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
    4.32
    pdf
    12.45

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    169
    1.05
    WATER BASED
    27.09.1989
    211
    1.05
    WATER BASED
    28.09.1989
    213
    1.05
    WATER BASED
    29.09.1989
    919
    1.15
    14.0
    8.0
    WATER BASED
    03.10.1989
    919
    1.05
    WATER BASED
    04.10.1989
    946
    1.15
    13.0
    7.0
    WATER BASED
    05.10.1989
    1382
    1.25
    14.0
    11.0
    WATER BASED
    06.10.1989
    1773
    1.36
    20.0
    11.0
    WATER BASED
    09.10.1989
    2074
    1.38
    24.0
    15.0
    WATER BASED
    09.10.1989
    2140
    1.15
    15.0
    7.0
    WATER BASED
    06.11.1989
    2193
    1.38
    21.0
    10.0
    WATER BASED
    09.10.1989
    2193
    1.38
    21.0
    10.0
    WATER BASED
    10.10.1989
    2193
    1.38
    21.0
    10.0
    WATER BASED
    11.10.1989
    2242
    1.13
    15.0
    11.0
    WATER BASED
    12.10.1989
    2306
    1.14
    18.0
    13.0
    WATER BASED
    13.10.1989
    2317
    1.13
    17.0
    10.0
    WATER BASED
    16.10.1989
    2327
    1.14
    18.0
    10.0
    WATER BASED
    16.10.1989
    2357
    1.14
    18.0
    10.0
    WATER BASED
    16.10.1989
    2388
    1.15
    14.0
    8.0
    WATER BASED
    01.11.1989
    2388
    1.15
    14.0
    8.0
    WATER BASED
    02.11.1989
    2388
    1.15
    14.0
    8.0
    WATER BASED
    03.11.1989
    2388
    1.15
    14.0
    8.0
    WATER BASED
    06.11.1989
    2411
    1.14
    20.0
    10.0
    WATER BASED
    18.10.1989
    2461
    1.14
    18.0
    11.0
    WATER BASED
    18.10.1989
    2469
    1.14
    12.0
    4.0
    WATER BASED
    25.10.1989
    2469
    1.14
    14.0
    8.0
    WATER BASED
    27.10.1989
    2469
    1.14
    14.0
    8.0
    WATER BASED
    27.10.1989
    2536
    1.14
    19.0
    8.0
    WATER BASED
    24.10.1989
    2555
    1.14
    23.0
    9.0
    WATER BASED
    19.10.1989
    2809
    1.14
    18.0
    7.0
    WATER BASED
    23.10.1989
    2809
    1.14
    17.0
    7.0
    WATER BASED
    23.10.1989
    2809
    1.14
    17.0
    7.0
    WATER BASED
    23.10.1989
    2809
    1.14
    18.0
    7.0
    WATER BASED
    23.10.1989
    2809
    1.14
    17.0
    7.0
    WATER BASED
    23.10.1989
    2809
    1.14
    17.0
    7.0
    WATER BASED
    23.10.1989

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1750.0
    [m]
    DC
    STRAT
    1770.0
    [m]
    DC
    STRAT
    1780.0
    [m]
    C
    HYDRO
    1800.0
    [m]
    DC
    STRAT
    1810.0
    [m]
    DC
    STRAT
    1830.0
    [m]
    DC
    STRAT
    1840.0
    [m]
    DC
    STRAT
    1860.0
    [m]
    DC
    STRAT
    1870.0
    [m]
    DC
    STRAT
    1890.0
    [m]
    DC
    STRAT
    1900.0
    [m]
    DC
    STRAT
    1920.0
    [m]
    DC
    STRAT
    1930.0
    [m]
    DC
    STRAT
    1950.0
    [m]
    DC
    STRAT
    1960.0
    [m]
    DC
    STRAT
    1980.0
    [m]
    DC
    STRAT
    1990.0
    [m]
    DC
    STRAT
    2010.0
    [m]
    DC
    STRAT
    2020.0
    [m]
    DC
    STRAT
    2040.0
    [m]
    DC
    STRAT
    2050.0
    [m]
    DC
    STRAT
    2070.0
    [m]
    DC
    STRAT
    2080.0
    [m]
    DC
    STRAT
    2100.0
    [m]
    DC
    STRAT
    2110.0
    [m]
    SWC
    HYDRO
    2130.0
    [m]
    SWC
    HYDRO
    2140.0
    [m]
    DC
    STRAT
    2160.0
    [m]
    C
    HYDRO
    2196.5
    [m]
    DC
    STRAT
    2196.5
    [m]
    SWC
    HYDRO
    2206.5
    [m]
    SWC
    HYDRO
    2210.0
    [m]
    SWC
    HYDRO
    2218.0
    [m]
    SWC
    HYDRO
    2219.5
    [m]
    SWC
    HYDRO
    2223.0
    [m]
    SWC
    HYDRO
    2236.0
    [m]
    SWC
    HYDRO
    2271.5
    [m]
    SWC
    HYDRO
    2273.0
    [m]
    SWC
    HYDRO
    2276.0
    [m]
    SWC
    HYDRO
    2280.0
    [m]
    SWC
    HYDRO
    2288.0
    [m]
    SWC
    HYDRO
    2291.1
    [m]
    C
    HYDRO
    2292.5
    [m]
    SWC
    HYDRO
    2293.0
    [m]
    SWC
    HYDRO
    2293.7
    [m]
    C
    HYDRO
    2299.0
    [m]
    C
    HYDRO
    2301.4
    [m]
    C
    HYDRO
    2304.2
    [m]
    C
    HYDRO
    2305.0
    [m]
    DC
    STRAT
    2308.6
    [m]
    C
    HYDRO
    2311.0
    [m]
    C
    STRAT
    2312.3
    [m]
    C
    HYDRO
    2315.1
    [m]
    C
    HYDRO
    2318.5
    [m]
    SWC
    HYDRO
    2321.0
    [m]
    SWC
    HYDRO
    2325.6
    [m]
    C
    HYDRO
    2338.0
    [m]
    SWC
    HYDRO
    2340.0
    [m]
    SWC
    HYDRO
    2344.0
    [m]
    SWC
    HYDRO
    2347.0
    [m]
    C
    HYDRO
    2352.5
    [m]
    C
    HYDRO
    2355.0
    [m]
    DC
    STRAT
    2355.8
    [m]
    C
    HYDRO
    2369.0
    [m]
    SWC
    STRAT
    2369.0
    [m]
    SWC
    HYDRO
    2372.0
    [m]
    SWC
    HYDRO
    2374.0
    [m]
    SWC
    HYDRO
    2382.0
    [m]
    DC
    STRAT
    2393.0
    [m]
    C
    HYDRO
    2405.1
    [m]
    C
    HYDRO
    2407.8
    [m]
    C
    HYDRO
    2409.0
    [m]
    C
    HYDRO
    2411.4
    [m]
    C
    HYDRO
    2415.2
    [m]
    C
    HYDRO
    2435.0
    [m]
    DC
    STRAT
    2445.0
    [m]
    DC
    STRAT
    2455.0
    [m]
    DC
    STRAT
    2465.0
    [m]
    DC
    STRAT
    2475.0
    [m]
    DC
    STRAT
    2485.0
    [m]
    DC
    STRAT
    2495.0
    [m]
    DC
    STRAT
    2505.0
    [m]
    DC
    STRAT
    2515.0
    [m]
    DC
    STRAT
    2525.0
    [m]
    DC
    STRAT
    2535.0
    [m]
    DC
    STRAT
    2545.0
    [m]
    DC
    STRAT
    2553.5
    [m]
    SWC
    HYDRO
    2554.0
    [m]
    SWC
    HYDRO
    2565.0
    [m]
    DC
    STRAT
    2575.0
    [m]
    DC
    STRAT
    2585.0
    [m]
    DC
    STRAT
    2595.0
    [m]
    DC
    STRAT
    2605.0
    [m]
    DC
    STRAT
    2615.0
    [m]
    DC
    STRAT
    2625.0
    [m]
    DC
    STRAT
    2637.0
    [m]
    SWC
    HYDRO
    2650.0
    [m]
    SWC
    HYDRO
    2665.0
    [m]
    DC
    STRAT
    2675.0
    [m]
    DC
    STRAT
    2685.0
    [m]
    DC
    STRAT
    2695.0
    [m]
    DC
    STRAT
    2707.0
    [m]
    SWC
    HYDRO
    2727.0
    [m]
    SWC
    HYDRO
    2734.0
    [m]
    SWC
    HYDRO
    2752.5
    [m]
    SWC
    HYDRO
    2756.0
    [m]
    SWC
    HYDRO
    2761.5
    [m]
    SWC
    HYDRO
    2771.5
    [m]
    SWC
    HYDRO
    2778.0
    [m]
    SWC
    HYDRO
    2780.0
    [m]
    SWC
    HYDRO
    2790.0
    [m]
    SWC
    HYDRO
    2809.0
    [m]
    DC
    STRAT