Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.10.2024 - 01:27
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7220/11-1

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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.
    7220/11-1
    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
    Press release
    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
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    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    BARENTS SEA
    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.
    7220/11-1
    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.
    Lundin Norway 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.
    1527-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.
    74
    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,
    05.08.2014
    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.
    17.10.2014
    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.
    17.10.2016
    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.
    19.10.2016
    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.
    TRIASSIC
    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.
    UNDEFINED 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.
    CARBONIFEROUS
    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.
    FALK FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    30.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    388.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2251.0
    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).
    2251.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    83
    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 CARBONIFEROUS
    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.
    UGLE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 3' 26.82'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 32' 45.67'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8004336.37
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    690463.21
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    33
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    7503

  • Wellbore history
    General
    Well 7220/11-1 was drilled on the Alta prospect on the southern part of the Loppa High in the Barents Sea. The primary objective was to test sandstones of the Triassic Kobbe Formation and Permian to Carboniferous carbonates of the Ørn Formation. The secondary objective was to test carbonates and sandstones of the Carboniferous Falk Formation.
    Operations and results
    Wildcat well 7220/11-1 was spudded with the semi-submersible installation Island Innovator on 5th August 2014 and drilled to TD at 2251 m in the Late Carboniferous Ugle Formation. No significant problem was encountered in the operations. The well was drilled with seawater down to 588.4 m and with Aqua-Drill mud from 588.4 m to TD.
    Numerous shows, of variable quality, was described in thin sandstones in the upper part of the Triassic Snadd Formation (624 m, 727 - 737 m, 822 m, 845 - 9924 m, 1246 m, 1280 m, 1298 m, and 1329 - 1349 m). The well did not encounter reservoir quality in the primary Alta Kobbe Formation target. A 26 m thick Triassic conglomerate unit was encountered at 1897 m. This unit rests directly on carbonates of the Carboniferous Falk Formation. The Ørn Formation was not present in the well. The Triassic conglomerates and the Falk carbonates were found to be hydrocarbon bearing with a total column height of 57 m (11 m gas column over a 46 m oil leg). The gas/oil contact is interpreted to be at 1908.1 m. Organic geochemical analyses of the oil show an abundance of tricyclic terpanes combined with a light carbon isotopic composition, typical of the Barents region Triassic source rocks. The oil/water contact is interpreted to be at 1954 m. Below the Falk Formation the Ugle Formation had 122 m gross sandstones. These sandstones were described as clear translucent, occasionally yellowish-orange  quartz  (common  moderate  brown  coating)  with  moderate  brown  to  reddish  brown argillaceous matrix. The grain size is mostly fine to medium, but up to coarse.
    The reservoir section was cored in four cores from 1904 m to 1977.5 m with 99 to 100% recovery.  MDT fluid samples were taken at 1900.7 m (condensate), 1912.0 m (oil), 1919.5 m (oil), 1939.7 m (oil), 1986.8 m (water), and 1999.5 m (water).
    The well was permanently abandoned on 17 October 2014 as an oil and gas discovery.
    Testing
    The well was perforated in two separate intervals in the Falk Formation (1934.8-1945.0 m) and the Triassic Conglomerates (1912.9-1921.4 m). While flowing from the lower perforations alone before acid stimulation, well productivity was low. After acid stimulation of the lower zone and perforation of the upper zone, a good productivity was achieved. The final flow rate was 520 Sm3/day oil and 48 600 Sm3/day gas through a 36/64 inch fixed choke; the GOR was 94 Sm3/Sm3, and the downhole temperature was 72.7 °C at 1935 m.

  • 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]
    600.00
    2250.00

  • 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
    1904.0
    1928.0
    [m ]
    2
    1928.0
    1954.2
    [m ]
    3
    1954.3
    1964.0
    [m ]
    4
    1964.0
    1977.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    73.4
    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
    1A
    1946.50
    1937.00
    OIL
    02.10.2014 - 00:00
    YES
    DST
    1B
    1921.00
    1913.00
    OIL
    05.10.2014 - 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
    486.0
    36
    489.5
    0.00
    SURF.COND.
    20
    588.4
    26
    594.0
    1.34
    FIT
    PILOT HOLE
    594.0
    9 7/8
    594.0
    0.00
    INTERM.
    13 3/8
    1196.0
    17 1/2
    1202.0
    1.50
    FIT
    INTERM.
    9 5/8
    1764.1
    12 1/4
    1770.5
    1.50
    FIT
    LINER
    7
    2049.8
    8 1/2
    2251.0
    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
    1935
    1945
    14.3
    2.0
    1913
    1921
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    42
    2.0
    46
    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
    518
    49000
    95
    2.0
    530
    48000
    90

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CCL GR SBT VDL
    1337
    1754
    GR GEOW
    753
    2238
    MRCH JAR GR PCOR
    1777
    2219
    MRCH JAR TTRM DSL CN ZDL ORIT XM
    1752
    2214
    MRCH JAR TTRM DSL FLEX MREX
    1869
    2011
    MRCH JAR TTRM DSL FLEX MREX
    1890
    2108
    MRCH JAR TTRM DSL STAR ORIT UXPL
    1196
    1753
    MRCH JAR TTRM DSL STAR ORIT UXPL
    1762
    2239
    MRCH JAR TTRM RLVP RCX GR
    1328
    1340
    MWD - ATK MXT OTK SDTK CCN ORD Z
    1082
    1770
    MWD - MXT OTK SDTK ZTK BCPM NBG
    537
    1202
    MWD - OTK BCPM
    418
    489
    MWD - OTK SDTK BCPM
    462
    592
    MWD - OTK SDTK CCN ORD BCPM II
    1694
    2249
    SC PO SAT PQ IFA MS PC ADT GR
    1880
    2210

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    465
    1.40
    16.0
    Water Based
    472
    1.03
    2.0
    Water Based
    472
    1.20
    11.0
    Water Based
    490
    1.03
    120.0
    Water Based
    539
    1.20
    11.0
    Water Based
    594
    1.40
    7.0
    Water Based
    594
    1.20
    20.0
    Water Based
    594
    1.03
    20.0
    Water Based
    598
    1.19
    15.0
    Water Based
    869
    1.21
    17.0
    Water Based
    1202
    1.20
    19.0
    Water Based
    1692
    1.20
    16.0
    Water Based
    1774
    1.14
    21.0
    Water Based
    1928
    1.16
    18.0
    Water Based
    2051
    1.14
    1.0
    Brine
    2051
    1.16
    11.0
    Water Based

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    610.0
    [m]
    DC
    ROBERTSO
    640.0
    [m]
    DC
    ROBERT
    660.0
    [m]
    DC
    ROBERT
    680.0
    [m]
    DC
    ROBERT
    700.0
    [m]
    DC
    ROBERT
    720.0
    [m]
    DC
    ROBERT
    740.0
    [m]
    DC
    ROBERT
    760.0
    [m]
    DC
    ROBERT
    780.0
    [m]
    DC
    ROBERT
    800.0
    [m]
    DC
    ROBERT
    820.0
    [m]
    DC
    ROBERT
    830.0
    [m]
    DC
    ROBERT
    840.0
    [m]
    DC
    ROBERT
    850.0
    [m]
    DC
    ROBERT
    860.0
    [m]
    DC
    ROBERT
    870.0
    [m]
    DC
    ROBERT
    900.0
    [m]
    DC
    ROBERT
    920.0
    [m]
    DC
    ROBERT
    940.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    980.0
    [m]
    DC
    ROBERT
    1000.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1040.0
    [m]
    DC
    ROBERT
    1060.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1100.0
    [m]
    DC
    ROBERT
    1120.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1160.0
    [m]
    DC
    ROBERT
    1180.0
    [m]
    DC
    ROBERT
    1202.0
    [m]
    DC
    ROBERT
    1220.0
    [m]
    DC
    ROBERT
    1240.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1280.0
    [m]
    DC
    ROBERT
    1300.0
    [m]
    DC
    ROBERT
    1320.0
    [m]
    DC
    ROBERT
    1340.0
    [m]
    DC
    ROBERT
    1360.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1400.0
    [m]
    DC
    ROBERT
    1420.0
    [m]
    DC
    ROBERT
    1440.0
    [m]
    DC
    ROBERT
    1460.0
    [m]
    DC
    ROBERT
    1480.0
    [m]
    DC
    ROBERT
    1500.0
    [m]
    DC
    ROBERT
    1520.0
    [m]
    DC
    ROBERT
    1540.0
    [m]
    DC
    ROBERT
    1560.0
    [m]
    DC
    ROBERT
    1580.0
    [m]
    DC
    ROBERT
    1600.0
    [m]
    DC
    ROBERT
    1620.0
    [m]
    DC
    ROBERT
    1640.0
    [m]
    DC
    ROBERT
    1660.0
    [m]
    DC
    ROBERT
    1680.0
    [m]
    DC
    ROBERT
    1700.0
    [m]
    DC
    ROBERT
    1720.0
    [m]
    DC
    ROBERT
    1740.0
    [m]
    DC
    ROBERT
    1760.0
    [m]
    DC
    ROBERT
    1782.0
    [m]
    DC
    ROBERT
    1800.0
    [m]
    DC
    ROBERT
    1818.0
    [m]
    DC
    ROBERT
    1836.0
    [m]
    DC
    ROBERT
    1851.1
    [m]
    SWC
    ROBERT
    1854.0
    [m]
    DC
    ROBERT
    1859.9
    [m]
    SWC
    ROBERT
    1863.0
    [m]
    DC
    ROBERT
    1863.2
    [m]
    SWC
    ROBERT
    1872.0
    [m]
    DC
    ROBERT
    1873.0
    [m]
    SWC
    ROBERT
    1881.0
    [m]
    DC
    ROBERT
    1890.0
    [m]
    DC
    ROBERT
    1895.6
    [m]
    SWC
    ROBERT
    1896.5
    [m]
    SWC
    ROBERT
    1899.0
    [m]
    DC
    ROBERT
    1902.0
    [m]
    DC
    ROBERT
    1904.2
    [m]
    C
    ROBERT
    1905.5
    [m]
    C
    ROBERT
    1906.6
    [m]
    C
    ROBERT
    1908.8
    [m]
    C
    ROBERT
    1909.6
    [m]
    C
    ROBERT
    1910.3
    [m]
    C
    ROBERT
    1911.3
    [m]
    C
    ROBERT
    1912.7
    [m]
    C
    ROBERT
    1913.6
    [m]
    C
    ROBERT
    1914.5
    [m]
    C
    ROBERT
    1915.4
    [m]
    C
    ROBERT
    1916.0
    [m]
    C
    ROBERT
    1917.9
    [m]
    C
    ROBERT
    1918.5
    [m]
    C
    ROBERT
    1919.2
    [m]
    C
    ROBERT
    1919.4
    [m]
    C
    APT
    1919.9
    [m]
    C
    APT
    1920.5
    [m]
    C
    APT
    1921.3
    [m]
    C
    ROBERT
    1922.2
    [m]
    C
    ROBERT
    1922.7
    [m]
    C
    APT
    1923.3
    [m]
    C
    ROBERT
    1924.2
    [m]
    C
    ROBERT
    1924.7
    [m]
    C
    APT
    1925.3
    [m]
    C
    ROBERT
    1925.7
    [m]
    C
    ROBERT
    1926.5
    [m]
    C
    ROBERT
    1927.5
    [m]
    C
    ROBERT
    1928.8
    [m]
    C
    ROBERT
    1929.1
    [m]
    C
    ROBERT
    1930.3
    [m]
    C
    ROBERT
    1931.2
    [m]
    C
    ROBERT
    1931.5
    [m]
    C
    ROBERT
    1935.4
    [m]
    C
    ROBERT
    1939.6
    [m]
    C
    ROBERT
    1940.2
    [m]
    C
    ROBERT
    1949.3
    [m]
    C
    ROBERT
    1951.3
    [m]
    C
    ROBERT
    1956.5
    [m]
    C
    ROBERT
    1957.1
    [m]
    C
    ROBERT
    1964.5
    [m]
    C
    ROBERT
    1968.4
    [m]
    C
    ROBERT
    1971.6
    [m]
    C
    ROBERT
    1975.2
    [m]
    C
    ROBERT
    1976.6
    [m]
    C
    ROBERT
    1980.0
    [m]
    DC
    ROBERT
    1998.0
    [m]
    DC
    ROBERT
    2016.0
    [m]
    DC
    ROBERT
    2022.0
    [m]
    DC
    ROBERT
    2031.0
    [m]
    DC
    ROBERT
    2058.0
    [m]
    DC
    ROBERT
    2073.0
    [m]
    DC
    ROBERT
    2091.0
    [m]
    DC
    ROBERT
    2112.0
    [m]
    DC
    ROBERT

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1906.30
    [m ]
    1907.60
    [m ]
    1915.82
    [m ]
    1918.28
    [m ]
    1923.01
    [m ]
    1924.25
    [m ]
    1930.80
    [m ]
    1935.72
    [m ]
    1936.60
    [m ]
    1941.75
    [m ]
    1946.55
    [m ]
    1949.27
    [m ]
    1950.77
    [m ]
    1951.35
    [m ]
    1953.55
    [m ]
    1954.57
    [m ]
    1959.10
    [m ]
    1960.20
    [m ]
    1963.83
    [m ]
    1965.20
    [m ]
    1971.72
    [m ]
    1973.35
    [m ]
    1974.18
    [m ]
    1976.89
    [m ]
    1977.35
    [m ]
    1988.00
    [m ]
    1902.00
    [m ]
    1977.00
    [m ]
    1983.00
    [m ]
    1989.00
    [m ]
    1995.00
    [m ]
    1998.00
    [m ]
    2001.00
    [m ]
    2004.00
    [m ]
    2007.00
    [m ]
    2013.00
    [m ]
    2016.00
    [m ]
    2019.00
    [m ]
    2022.00
    [m ]
    2025.00
    [m ]
    2031.00
    [m ]
    2034.00
    [m ]
    2037.00
    [m ]
    2043.00
    [m ]
    2049.00
    [m ]
    2055.00
    [m ]
    2061.00
    [m ]
    2067.00
    [m ]
    2073.00
    [m ]
    2076.00
    [m ]
    2079.00
    [m ]
    2085.00
    [m ]
    2091.00
    [m ]
    2097.00
    [m ]
    2100.00
    [m ]
    2103.00
    [m ]
    2106.00
    [m ]
    2109.00
    [m ]
    2112.00
    [m ]
    2118.00
    [m ]