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

30/6-22

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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.
    30/6-22
    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.
    SUSPENDED
    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.
    30/6-22
    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.
    578-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.
    54
    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,
    21.05.1988
    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.
    13.07.1988
    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.
    13.07.1990
    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.
    29.03.2014
    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.
    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.
    179.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3336.0
    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).
    3330.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    10.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    123
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 43' 57.26'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 58' 53.12'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6733159.80
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    498986.72
    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.
    1225

  • Wellbore history
    General
    Well 30/6-22 was drilled on the 30/6-19 Beta Saddle Discovery between the Veslefrikk field and the 30/6-5 Oseberg East (Beta South) discovery. The discovery well 30/6-19 found oil in the Brent Group. The objectives of well 30/6-22 were to narrow the range in the oil/water contact levels in the Tarbert/Ness and the Etive/Rannoch/Oseberg Formations and to get information about lateral variation in reservoir quality.
    Operations and results
    Appraisal well 30/6 22 was spudded 21 May 1988 by Polar Frontier Drilling semi submersible rig Polar Pioneer and drilled to TD at 3336 m in the Late Jurassic Statfjord Group. Drilling went without problems, but the prospect was intersected 50 m away from where it was decided, in north-eastern direction. The well was drilled with spud mud down to 963 m and with KCl/polymer mud from 963 m to TD.
    Top Brent Group, Tarbert Formation was penetrated at 2874 m. Moveable oil was confirmed by logs, RFT pressure gradients and tests in sandstones in the Ness and Etive formations from 2908 m (2880 m TVD MSL). The OWC was not clearly defined, but indicated from RFT pressure gradients to be at 2935 m (2907 m TVD MSL). The Oseberg Formation was water bearing. The Cook Formation had good oil shows but it was tight and impossible to test. No shows were recorded in the Statfjord Formation.
    Six cores were cut in the well: The Brent Group was cored in five cores in the interval 2854 - 3009.9 m and one core was cut in the Cook Formation in the interval 3122.5 - 3150.4 m. RFT-tests indicated oil from 2910 m (Ness Formation) and mud filtrate from 2934 m (Etive Formation).
    The well was suspended on 13 July as an oil appraisal.
    Testing
    Two DST tests were performed.
    DST 1 tested the interval 2917.2 - 2936.2 m in the Etive Formation. It produced 294 Sm3 oil and 19430 Sm3 gas /day through a 32/64" choke. The GOR was 67 Sm3/Sm3, the oil density was 0.892 g/cm3, and the gas gravity was 0.76 (air = 1) with no measurable H2S and 4 % CO2. The maximum flowing bottom hole temperature measured at sensor point 2852.8 m was 122.9 deg C.
    DST 2 tested the interval 2908.8 - 2912.3 m in the Ness Formation. It produced 480 Sm3 oil and 31680 Sm3 gas /day through a 32/64" choke. The GOR was 66 Sm3/Sm3, the oil density was 0.823 g/cm3, and the gas gravity was 0.765 (air = 1) with no measurable H2S and 4 % CO2. The maximum flowing bottom hole temperature measured at sensor point 2854.2 m was 123.7 deg C.

  • 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]
    970.00
    3335.00

  • 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
    2854.0
    2881.6
    [m ]
    2
    2881.6
    2905.5
    [m ]
    3
    2906.0
    2921.5
    [m ]
    4
    2921.6
    2958.4
    [m ]
    5
    2958.5
    3009.9
    [m ]
    6
    3122.5
    3150.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    182.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2854-2859m
    Core photo at depth: 2859-2864m
    Core photo at depth: 2864-2869m
    Core photo at depth: 2869-2874m
    Core photo at depth: 2874-2879m
    2854-2859m
    2859-2864m
    2864-2869m
    2869-2874m
    2874-2879m
    Core photo at depth: 2879-2881m
    Core photo at depth: 2881-2886m
    Core photo at depth: 2886-2891m
    Core photo at depth: 2891-2896m
    Core photo at depth: 2896-2901m
    2879-2881m
    2881-2886m
    2886-2891m
    2891-2896m
    2896-2901m
    Core photo at depth: 2901-2905m
    Core photo at depth: 2906-2911m
    Core photo at depth: 2911-2916m
    Core photo at depth: 2916-2921m
    Core photo at depth: 2921-2921m
    2901-2905m
    2906-2911m
    2911-2916m
    2916-2921m
    2921-2921m
    Core photo at depth: 2921-2926m
    Core photo at depth: 2926-2931m
    Core photo at depth: 2931-2936m
    Core photo at depth: 2936-2941m
    Core photo at depth: 2941-2946m
    2921-2926m
    2926-2931m
    2931-2936m
    2936-2941m
    2941-2946m
    Core photo at depth: 2946-2951m
    Core photo at depth: 2951-2956m
    Core photo at depth: 2956-2958m
    Core photo at depth: 2958-2963m
    Core photo at depth: 2963-2968m
    2946-2951m
    2951-2956m
    2956-2958m
    2958-2963m
    2963-2968m
    Core photo at depth: 2968-2973m
    Core photo at depth: 2973-2978m
    Core photo at depth: 2978-2983m
    Core photo at depth: 2983-2988m
    Core photo at depth: 2988-2993m
    2968-2973m
    2973-2978m
    2978-2983m
    2983-2988m
    2988-2993m
    Core photo at depth: 2993-2998m
    Core photo at depth: 2998-3003m
    Core photo at depth: 3003-3008m
    Core photo at depth: 3008-3009m
    Core photo at depth: 3122-2127m
    2993-2998m
    2998-3003m
    3003-3008m
    3008-3009m
    3122-2127m
    Core photo at depth: 3127-3132m
    Core photo at depth: 3132-3237m
    Core photo at depth: 3137-3142m
    Core photo at depth: 3142-3147m
    Core photo at depth: 3147-3150m
    3127-3132m
    3132-3237m
    3137-3142m
    3142-3147m
    3147-3150m

  • 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
    2917.00
    2936.00
    OIL
    08.07.1988 - 00:00
    YES
    DST
    DST2
    2908.75
    2912.25
    OIL
    07.07.1988 - 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
    292.0
    36
    292.0
    0.00
    LOT
    INTERM.
    13 3/8
    948.0
    17 1/2
    963.0
    1.74
    LOT
    INTERM.
    9 5/8
    2781.0
    12 1/4
    2798.0
    1.69
    LOT
    LINER
    7
    3333.0
    8 1/2
    3336.0
    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
    2917
    2036
    12.7
    2.0
    2909
    2912
    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
    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
    294
    19430
    0.829
    0.780
    68
    2.0
    480
    31680
    0.823
    0.765
    66

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    2600
    2340
    DIL LSS GR SP
    190
    2797
    DIS SDT NGS GR
    3337
    3780
    LDL CNL DLL MSFL GR AMS
    2780
    3334
    MWD
    202
    800
    RFT
    2881
    3309
    RFT
    2902
    2934
    RFT
    2930
    2949
    SHDT
    2780
    3338
    VSP
    1000
    3240

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.32
    pdf
    0.16
    pdf
    1.58

  • 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
    18.34

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    292
    1.05
    9.0
    5.0
    WATER BASED
    24.05.1988
    292
    1.05
    9.0
    5.0
    WATER BASED
    24.05.1988
    517
    1.03
    WATER BASED
    23.04.1987
    530
    1.03
    WATER BASED
    27.04.1987
    575
    1.03
    WATER BASED
    29.04.1987
    662
    1.05
    9.0
    5.0
    WATER BASED
    26.05.1988
    677
    1.03
    WATER BASED
    27.04.1987
    963
    1.05
    9.0
    5.0
    WATER BASED
    26.05.1988
    963
    1.05
    9.0
    5.0
    WATER BASED
    27.05.1988
    975
    1.03
    WATER BASED
    30.04.1987
    975
    1.03
    WATER BASED
    04.05.1987
    975
    1.03
    WATER BASED
    27.04.1987
    975
    1.03
    WATER BASED
    05.05.1987
    975
    1.20
    17.0
    21.0
    WATER BASED
    06.05.1987
    1162
    1.21
    16.0
    21.0
    WATER BASED
    06.05.1987
    1310
    1.40
    24.0
    12.0
    WATER BASED
    30.05.1988
    1438
    1.40
    24.0
    22.0
    WATER BASED
    06.05.1987
    1598
    1.40
    23.0
    20.0
    WATER BASED
    06.05.1987
    1601
    1.40
    24.0
    22.0
    WATER BASED
    11.05.1987
    1603
    1.40
    22.0
    18.0
    WATER BASED
    07.05.1987
    1679
    1.28
    7.0
    12.0
    WATER BASED
    12.05.1987
    1786
    1.27
    14.0
    15.0
    WATER BASED
    12.05.1987
    1804
    1.27
    29.0
    18.0
    WATER BASED
    12.05.1987
    1936
    1.43
    27.0
    9.0
    WATER BASED
    30.05.1988
    2007
    1.27
    13.0
    17.0
    WATER BASED
    14.05.1987
    2152
    1.29
    23.0
    16.0
    WATER BASED
    14.05.1987
    2180
    1.43
    28.0
    9.0
    WATER BASED
    30.05.1988
    2205
    1.27
    15.0
    15.0
    WATER BASED
    14.05.1987
    2295
    1.27
    21.0
    17.0
    WATER BASED
    18.05.1987
    2392
    1.27
    16.0
    12.0
    WATER BASED
    18.05.1987
    2411
    1.27
    16.0
    12.0
    WATER BASED
    18.05.1987
    2429
    1.43
    29.0
    9.0
    WATER BASED
    31.05.1988
    2532
    1.45
    28.0
    9.0
    WATER BASED
    02.06.1988
    2551
    1.27
    15.0
    14.0
    WATER BASED
    18.05.1987
    2560
    1.25
    18.0
    8.0
    WATER BASED
    12.07.1988
    2638
    1.45
    26.0
    9.0
    WATER BASED
    02.06.1988
    2758
    1.45
    27.0
    10.0
    WATER BASED
    03.06.1988
    2798
    1.45
    20.0
    10.0
    WATER BASED
    07.06.1988
    2798
    1.45
    21.0
    10.0
    WATER BASED
    07.06.1988
    2798
    1.45
    21.0
    10.0
    WATER BASED
    07.06.1988
    2854
    1.25
    14.0
    5.0
    WATER BASED
    09.06.1988
    2888
    1.25
    15.0
    5.0
    WATER BASED
    10.06.1988
    2916
    1.25
    17.0
    6.0
    WATER BASED
    07.07.1988
    2916
    1.25
    17.0
    6.0
    WATER BASED
    08.07.1988
    2916
    1.25
    17.0
    6.0
    WATER BASED
    12.07.1988
    2916
    1.25
    17.0
    6.0
    WATER BASED
    06.07.1988
    2916
    1.25
    18.0
    8.0
    WATER BASED
    12.07.1988
    2922
    1.25
    14.0
    5.0
    WATER BASED
    13.06.1988
    2954
    1.25
    16.0
    6.0
    WATER BASED
    01.07.1988
    2954
    1.25
    16.0
    6.0
    WATER BASED
    04.07.1988
    2954
    1.25
    15.0
    6.0
    WATER BASED
    05.07.1988
    2954
    1.25
    16.0
    6.0
    WATER BASED
    29.06.1988
    2980
    1.25
    21.0
    7.0
    WATER BASED
    13.06.1988
    3010
    1.25
    20.0
    7.0
    WATER BASED
    13.06.1988
    3030
    1.25
    16.0
    5.0
    WATER BASED
    27.06.1988
    3030
    1.25
    15.0
    5.0
    WATER BASED
    27.06.1988
    3030
    1.25
    16.0
    5.0
    WATER BASED
    28.06.1988
    3089
    1.25
    19.0
    7.0
    WATER BASED
    13.06.1988
    3150
    1.25
    19.0
    6.0
    WATER BASED
    15.06.1988
    3235
    1.25
    17.0
    7.0
    WATER BASED
    15.06.1988
    3254
    1.25
    15.0
    5.0
    WATER BASED
    22.06.1988
    3269
    1.25
    15.0
    5.0
    WATER BASED
    23.06.1988
    3269
    1.25
    16.0
    5.0
    WATER BASED
    27.06.1988
    3333
    1.25
    16.0
    6.0
    WATER BASED
    21.06.1988
    3336
    1.25
    21.0
    7.0
    WATER BASED
    17.06.1988
    3336
    1.25
    16.0
    6.0
    WATER BASED
    20.06.1988
    3336
    1.25
    16.0
    5.0
    WATER BASED
    20.06.1988
    3336
    1.25
    19.0
    6.0
    WATER BASED
    20.06.1988

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2000.0
    [m]
    DC
    STRAT
    2010.0
    [m]
    DC
    STRAT
    2030.0
    [m]
    DC
    STRAT
    2040.0
    [m]
    DC
    STRAT
    2060.0
    [m]
    DC
    STRAT
    2090.0
    [m]
    DC
    STRAT
    2100.0
    [m]
    DC
    STRAT
    2120.0
    [m]
    DC
    STRAT
    2130.0
    [m]
    DC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2160.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2220.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2250.0
    [m]
    DC
    STRAT
    2270.0
    [m]
    DC
    STRAT
    2280.0
    [m]
    DC
    STRAT
    2300.0
    [m]
    DC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2330.0
    [m]
    DC
    STRAT
    2340.0
    [m]
    DC
    STRAT
    2360.0
    [m]
    DC
    STRAT
    2370.0
    [m]
    DC
    STRAT
    2390.0
    [m]
    DC
    STRAT
    2400.0
    [m]
    DC
    STRAT
    2420.0
    [m]
    DC
    STRAT
    2430.0
    [m]
    DC
    STRAT
    2450.0
    [m]
    DC
    STRAT
    2460.0
    [m]
    DC
    STRAT
    2480.0
    [m]
    DC
    STRAT
    2485.0
    [m]
    DC
    PETROSTR
    2490.0
    [m]
    DC
    STRAT
    2495.0
    [m]
    DC
    PETROSTR
    2500.0
    [m]
    DC
    STRAT
    2505.0
    [m]
    DC
    PETROSTR
    2510.0
    [m]
    DC
    STRAT
    2520.0
    [m]
    DC
    STRAT
    2525.0
    [m]
    DC
    PETROSTR
    2530.0
    [m]
    DC
    STRAT
    2535.0
    [m]
    DC
    PETROSTR
    2540.0
    [m]
    DC
    STRAT
    2545.0
    [m]
    DC
    PETROSTR
    2550.0
    [m]
    DC
    STRAT
    2555.0
    [m]
    DC
    PETROSTR
    2570.0
    [m]
    DC
    STRAT
    2575.0
    [m]
    DC
    PETROSTR
    2585.0
    [m]
    DC
    PETROS
    2590.0
    [m]
    DC
    STRAT
    2595.0
    [m]
    DC
    PETROSTR
    2600.0
    [m]
    DC
    STRAT
    2605.0
    [m]
    DC
    PETROSTR
    2610.0
    [m]
    DC
    STRAT
    2615.0
    [m]
    DC
    PETROSTR
    2625.0
    [m]
    DC
    PETROS
    2630.0
    [m]
    DC
    STRAT
    2635.0
    [m]
    DC
    PETROSTR
    2640.0
    [m]
    DC
    STRAT
    2645.0
    [m]
    DC
    PETROS
    2655.0
    [m]
    DC
    PETROS
    2660.0
    [m]
    DC
    STRAT
    2665.0
    [m]
    DC
    PETROSTR
    2670.0
    [m]
    DC
    STRAT
    2675.0
    [m]
    DC
    PETROSTR
    2690.0
    [m]
    DC
    STRAT
    2695.0
    [m]
    DC
    PETROSTR
    2700.0
    [m]
    DC
    STRAT
    2715.0
    [m]
    DC
    PETROSTR
    2720.0
    [m]
    DC
    STRAT
    2730.0
    [m]
    DC
    STRAT
    2735.0
    [m]
    DC
    PETROSTR
    2745.0
    [m]
    DC
    PETROS
    2750.0
    [m]
    DC
    STRAT
    2755.0
    [m]
    DC
    PETROSTR
    2760.0
    [m]
    DC
    STRAT
    2765.0
    [m]
    DC
    PETROSTR
    2780.0
    [m]
    DC
    STRAT
    2785.0
    [m]
    DC
    PETROSTR
    2790.0
    [m]
    DC
    STRAT
    2790.0
    [m]
    DC
    PETROSTR
    2810.0
    [m]
    DC
    STRAT
    2820.0
    [m]
    DC
    STRAT
    2840.0
    [m]
    DC
    STRAT
    2850.0
    [m]
    DC
    STRAT
    2854.0
    [m]
    C
    STRAT
    2860.0
    [m]
    C
    STRAT
    2865.0
    [m]
    C
    STRAT
    2870.0
    [m]
    C
    STRAT
    2874.0
    [m]
    C
    STRAT
    2880.0
    [m]
    C
    STRAT
    2883.0
    [m]
    C
    STRAT
    2889.0
    [m]
    C
    STRAT
    2899.0
    [m]
    C
    STRAT
    2902.0
    [m]
    C
    STRAT
    2906.0
    [m]
    C
    STRAT
    2913.0
    [m]
    C
    STRAT
    2920.0
    [m]
    C
    STRAT
    2923.0
    [m]
    C
    STRAT
    2930.0
    [m]
    C
    STRAT
    2935.0
    [m]
    C
    STRAT
    2940.0
    [m]
    C
    STRAT
    2947.0
    [m]
    C
    STRAT
    2950.0
    [m]
    C
    STRAT
    2954.0
    [m]
    C
    STRAT
    2957.0
    [m]
    C
    STRAT
    2965.0
    [m]
    C
    STRAT
    2972.0
    [m]
    C
    STRAT
    2976.0
    [m]
    C
    STRAT
    2982.0
    [m]
    C
    STRAT
    2984.0
    [m]
    C
    STRAT
    2990.0
    [m]
    C
    STRAT
    2995.0
    [m]
    C
    STRAT
    3000.0
    [m]
    C
    STRAT
    3004.0
    [m]
    C
    STRAT
    3009.0
    [m]
    C
    STRAT
    3020.0
    [m]
    DC
    STRAT
    3030.0
    [m]
    DC
    STRAT
    3040.0
    [m]
    DC
    STRAT
    3050.0
    [m]
    DC
    STRAT
    3060.0
    [m]
    DC
    STRAT
    3070.0
    [m]
    DC
    STRAT
    3080.0
    [m]
    DC
    STRAT
    3090.0
    [m]
    DC
    STRAT
    3100.0
    [m]
    DC
    STRAT
    3110.0
    [m]
    DC
    STRAT
    3123.0
    [m]
    C
    STRAT
    3127.0
    [m]
    C
    STRAT
    3134.0
    [m]
    C
    STRAT
    3137.0
    [m]
    C
    STRAT
    3144.0
    [m]
    C
    STRAT
    3149.0
    [m]
    C
    STRAT
    3160.0
    [m]
    DC
    STRAT
    3170.0
    [m]
    DC
    STRAT
    3180.0
    [m]
    DC
    STRAT
    3190.0
    [m]
    DC
    STRAT
    3200.0
    [m]
    DC
    STRAT
    3212.0
    [m]
    DC
    STRAT
    3220.0
    [m]
    DC
    STRAT
    3230.0
    [m]
    DC
    STRAT
    3240.0
    [m]
    DC
    STRAT
    3250.0
    [m]
    DC
    STRAT
    3260.0
    [m]
    DC
    STRAT
    3270.0
    [m]
    DC
    STRAT
    3280.0
    [m]
    DC
    STRAT
    3290.0
    [m]
    DC
    STRAT
    3300.0
    [m]
    DC
    STRAT
    3310.0
    [m]
    DC
    STRAT
    3320.0
    [m]
    DC
    STRAT
    3335.0
    [m]
    DC
    STRAT