Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.12.2024 - 01:26
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6607/12-1

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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.
    6607/12-1
    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
    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.
    NORWEGIAN SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6607/12-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE B-20-83 SP.940
    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.
    Elf Petroleum Norge 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.
    521-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.
    75
    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,
    19.07.1986
    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.
    01.10.1986
    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.
    01.10.1988
    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.
    17.09.2007
    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
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    21.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    369.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3521.0
    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).
    3516.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    124
    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 CRETACEOUS
    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.
    SHETLAND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    66° 12' 54.15'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 44' 26.72'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7344635.95
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    443329.05
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    925

  • Wellbore history
    General
    Well 6607/12-1 is located in the western part of the Dønna Terrace in the Norwegian Sea off shore Mid Norway. It was designed to test a structure in the north-western part of the block. The main structuration was seen at top Brygge Formation and top Tare Formation. A secondary structure was mapped at an intra Cretaceous marker. The top of the Shetland Group showed an anomalous graben-like development without structural closure. The well was located close to or at the highest structural point of all closed levels. The main objectives of the well were to test for hydrocarbons at all closed levels of the main structure, to test the contents of the anomalous graben feature seen at top Shetland Group level, and to test the upper part of the Cretaceous section west of the Nordland Ridge for potential source rocks. The prognosed depth was 3500 m.
    Operations and results
    Wildcat well 6607/12-1was spudded with the semi-submersible installation Henry Goodrich on 19 July 1986 and drilled to TD at 3521 m in the Late Cretaceous Shetland Group. Down to 1440 m drilling proceeded without significant problems. At this depth there was experienced a loss of mud to the formation, but the well was stabilised. The well was drilled with bentonite mud down to 765 m, with polymer mud from 765 m to 1526 m, and with Lignosulphonate mud from 1526 m to TD.
    Only thin levels of water bearing sandstones were encountered. The main target (Brygge Formation) came in at 1398 m, 43 meter shallower than prognosis with claystones and a few stringers of limestone and sand. The Cretaceous section came in at 1725 m. The main lithology here was multicoloured claystone with stringers of white, hard limestone. A fault zone, rich in dolomite and calcite alternating with limestone were penetrated at 2666 to 2672 m. Total gas of 38% were recorded from this interval, otherwise no other major shows were recorded during drilling or coring. Minor shows, however, were recorded between 2935 - 2940 m in bituminous claystones and argillaceous dolomites of the Shetland Group. Source rock geochemical analyses did not reveal any prolific kerogen at this depth however. The best source rock in the well was found in the interval 1630 to 1725 m in the Tang Formation, which had TOC in the range 1.2 - 4.5 % and Hydrogen Index in the range 50 - 150 mg HC/g TOC. This can be classified as fair source rock potential with potential for gas and possibly oil.
    One core was cut in the interval 1409 - 1426 m in the Brygge Formation. The recovery was 56% with claystones, limestone, tuff and thin sand stringers. No RFT sampling was performed. Corrected wire line BHT temperatures at TD indicate a formation temperature of 124 deg. C at TD.
    The well was permanently abandoned on 1 October 1986 as a dry well.
    Testing
    No drill stem test was performed.

  • 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]
    470.00
    3460.00

  • 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
    1409.0
    1417.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    8.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1409-1412m
    Core photo at depth: 1412-1415m
    Core photo at depth: 1415-1417m
    Core photo at depth:  
    Core photo at depth:  
    1409-1412m
    1412-1415m
    1415-1417m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1345.0
    [m]
    DC
    OD
    1355.0
    [m]
    DC
    RRI
    1363.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1385.0
    [m]
    DC
    OD
    1400.0
    [m]
    DC
    RRI
    1405.0
    [m]
    DC
    OD
    1410.0
    [m]
    DC
    OD
    1415.0
    [m]
    DC
    RRI
    1435.0
    [m]
    DC
    OD
    1440.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    OD
    1480.0
    [m]
    DC
    RRI
    1495.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    OD
    1520.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    OD
    1540.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    OD
    1560.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    OD
    1620.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    OD
    1700.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    OD
    1720.0
    [m]
    DC
    SAGA
    1725.0
    [m]
    DC
    RRI
    1725.0
    [m]
    DC
    SAGA
    1730.0
    [m]
    DC
    OD
    1730.0
    [m]
    DC
    SAGA
    1740.0
    [m]
    DC
    SAGA
    1740.0
    [m]
    DC
    OD
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    OD
    1810.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    OD
    1830.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    SAGA
    1850.0
    [m]
    DC
    OD
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    SAGA
    1890.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    SAGA
    1900.0
    [m]
    DC
    OD
    1910.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    SAGA
    1930.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    SAGA
    1950.0
    [m]
    DC
    OD
    1960.0
    [m]
    DC
    SAGA
    1990.0
    [m]
    DC
    SAGA
    2000.0
    [m]
    DC
    OD
    2020.0
    [m]
    DC
    SAGA
    2040.0
    [m]
    DC
    SAGA
    2050.0
    [m]
    DC
    OD
    2060.0
    [m]
    DC
    SAGA
    2085.0
    [m]
    DC
    SAGA
    2100.0
    [m]
    DC
    SAGA
    2100.0
    [m]
    DC
    OD
    2120.0
    [m]
    DC
    SAGA
    2145.0
    [m]
    DC
    SAGA
    2150.0
    [m]
    DC
    OD
    2165.0
    [m]
    DC
    SAGA
    2185.0
    [m]
    DC
    SAGA
    2195.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    OD
    2205.0
    [m]
    DC
    SAGA
    2240.0
    [m]
    DC
    SAGA
    2250.0
    [m]
    DC
    OD
    2260.0
    [m]
    DC
    SAGA
    2275.0
    [m]
    DC
    SAGA
    2295.0
    [m]
    DC
    SAGA
    2300.0
    [m]
    DC
    OD
    2330.0
    [m]
    DC
    SAGA
    2350.0
    [m]
    DC
    OD
    2370.0
    [m]
    DC
    SAGA
    2410.0
    [m]
    DC
    SAGA
    2410.0
    [m]
    DC
    OD
    2445.0
    [m]
    DC
    SAGA
    2450.0
    [m]
    DC
    OD
    2480.0
    [m]
    DC
    SAGA
    2500.0
    [m]
    DC
    OD
    2520.0
    [m]
    DC
    SAGA
    2550.0
    [m]
    DC
    OD
    2580.0
    [m]
    DC
    SAGA
    2600.0
    [m]
    DC
    OD
    2620.0
    [m]
    DC
    SAGA
    2635.0
    [m]
    DC
    SAGA
    2650.0
    [m]
    DC
    SAGA
    2650.0
    [m]
    DC
    OD
    2655.0
    [m]
    DC
    SAGA
    2665.0
    [m]
    DC
    SAGA
    2670.0
    [m]
    DC
    OD
    2675.0
    [m]
    DC
    SAGA
    2675.0
    [m]
    DC
    OD
    2690.0
    [m]
    DC
    SAGA
    2695.0
    [m]
    DC
    OD
    2705.0
    [m]
    DC
    OD
    2720.0
    [m]
    DC
    SAGA
    2725.0
    [m]
    DC
    OD
    2740.0
    [m]
    DC
    SAGA
    2760.0
    [m]
    DC
    SAGA
    2775.0
    [m]
    DC
    OD
    2800.0
    [m]
    DC
    SAGA
    2825.0
    [m]
    DC
    OD
    2840.0
    [m]
    DC
    SAGA
    2859.0
    [m]
    DC
    SAGA
    2875.0
    [m]
    DC
    OD
    2900.0
    [m]
    DC
    SAGA
    2925.0
    [m]
    DC
    OD
    2940.0
    [m]
    DC
    OD
    2960.0
    [m]
    DC
    SAGA
    2980.0
    [m]
    DC
    SAGA
    3000.0
    [m]
    DC
    OD
    3020.0
    [m]
    DC
    SAGA
    3050.0
    [m]
    DC
    OD
    3080.0
    [m]
    DC
    SAGA
    3100.0
    [m]
    DC
    OD
    3120.0
    [m]
    DC
    SAGA
    3150.0
    [m]
    DC
    OD
    3180.0
    [m]
    DC
    SAGA
    3200.0
    [m]
    DC
    OD
    3235.0
    [m]
    DC
    OD
    3250.0
    [m]
    DC
    OD
    3300.0
    [m]
    DC
    OD
    3350.0
    [m]
    DC
    OD
    3380.0
    [m]
    DC
    SAGA
    3400.0
    [m]
    DC
    OD
    3420.0
    [m]
    DC
    SAGA
    3440.0
    [m]
    DC
    SAGA
    3450.0
    [m]
    DC
    OD
    3470.0
    [m]
    DC
    SAGA
    3480.0
    [m]
    DC
    SAGA
    3490.0
    [m]
    DC
    SAGA
    3500.0
    [m]
    DC
    OD
    3510.0
    [m]
    DC
    SAGA
    3521.0
    [m]
    DC
    OD

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    390
    1299
    1398
    1398
    1484
    1484
    1578
    1725

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGL
    750
    1325
    BHC
    1330
    2709
    BHC
    2692
    3521
    CBL VDL
    390
    1330
    CBL VDL
    1331
    2694
    CNL
    1330
    2709
    CNL
    2692
    3522
    DIL
    464
    765
    DIL GR
    750
    1325
    DIL GR
    1331
    1523
    GR
    385
    765
    HRT
    1000
    1900
    ISF GR
    1330
    2709
    ISF GR
    2692
    3521
    LDL
    1330
    2709
    LDL
    2692
    3522
    LDL GR
    464
    765
    LDL GR
    750
    1325
    LDL GR
    1331
    1527
    LSS
    464
    765
    LSS
    750
    1325
    LSS
    1331
    1523
    MWD - GR RES DIR
    484
    3521
    NGL
    1330
    2699
    NGL
    2692
    3522
    SHDT GR
    1330
    2660
    SHDT GR
    2692
    3523
    VELOCITY
    1775
    3521
    VSP
    35
    900

  • 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
    463.0
    36
    765.0
    0.00
    LOT
    SURF.COND.
    20
    750.0
    26
    1015.0
    1.33
    LOT
    INTERM.
    13 3/8
    1331.0
    17 1/2
    1353.0
    1.68
    LOT
    INTERM.
    9 5/8
    2694.0
    12 1/4
    2709.0
    1.82
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    420
    1.06
    WATER BASED
    22.07.1986
    765
    1.16
    30.0
    11.7
    WATER BASED
    27.07.1986
    1015
    1.11
    28.0
    5.8
    WATER BASED
    05.08.1986
    1285
    1.16
    32.0
    14.7
    WATER BASED
    05.08.1986
    1345
    1.17
    40.0
    14.7
    WATER BASED
    05.08.1986
    1353
    1.18
    32.0
    8.8
    WATER BASED
    08.08.1986
    1409
    1.18
    32.0
    7.8
    WATER BASED
    10.08.1986
    1445
    1.30
    36.0
    6.8
    WATER BASED
    10.08.1986
    1526
    1.58
    53.0
    11.7
    WATER BASED
    15.08.1986
    1526
    1.45
    30.0
    2.9
    WATER BASED
    12.08.1986
    1526
    1.50
    38.0
    5.8
    WATER BASED
    12.08.1986
    1526
    1.58
    48.0
    12.7
    WATER BASED
    12.08.1986
    1613
    1.59
    55.0
    11.7
    WATER BASED
    18.08.1986
    1676
    1.62
    66.0
    13.7
    WATER BASED
    17.08.1986
    1748
    1.64
    62.0
    12.7
    WATER BASED
    18.08.1986
    2014
    1.64
    61.0
    11.7
    WATER BASED
    21.08.1986
    2178
    1.64
    59.0
    12.7
    WATER BASED
    21.08.1986
    2217
    1.64
    58.0
    12.7
    WATER BASED
    25.08.1986
    2298
    1.64
    59.0
    10.7
    WATER BASED
    25.08.1986
    2402
    1.64
    51.0
    9.8
    WATER BASED
    25.08.1986
    2412
    1.64
    50.0
    9.8
    WATER BASED
    25.08.1986
    2436
    1.65
    66.0
    13.7
    WATER BASED
    27.08.1986
    2540
    1.64
    54.0
    8.8
    WATER BASED
    28.08.1986
    2569
    1.64
    54.0
    10.7
    WATER BASED
    29.08.1986
    2681
    1.63
    61.0
    12.7
    WATER BASED
    01.09.1986
    2707
    1.64
    60.0
    11.7
    WATER BASED
    01.09.1986
    2733
    1.39
    58.0
    13.7
    WATER BASED
    08.09.1986
    2815
    1.39
    52.0
    12.7
    WATER BASED
    08.09.1986
    2859
    1.40
    48.0
    11.7
    WATER BASED
    08.09.1986
    2942
    1.40
    46.0
    8.8
    WATER BASED
    09.09.1986
    3000
    1.41
    46.0
    7.8
    WATER BASED
    10.09.1986
    3033
    1.42
    40.0
    8.8
    WATER BASED
    10.09.1986
    3113
    1.45
    40.0
    8.8
    WATER BASED
    11.09.1986
    3159
    1.47
    44.0
    7.8
    WATER BASED
    14.09.1986
    3181
    1.47
    40.0
    7.8
    WATER BASED
    14.09.1986
    3209
    1.47
    46.0
    7.8
    WATER BASED
    14.09.1986
    3238
    1.47
    48.0
    8.8
    WATER BASED
    16.09.1986
    3251
    1.47
    39.0
    8.8
    WATER BASED
    22.09.1986
    3260
    1.47
    50.0
    9.8
    WATER BASED
    17.09.1986
    3316
    1.47
    50.0
    10.7
    WATER BASED
    17.09.1986
    3372
    1.47
    46.0
    9.8
    WATER BASED
    19.09.1986
    3437
    1.47
    43.0
    8.8
    WATER BASED
    22.09.1986
    3508
    1.47
    39.0
    8.8
    WATER BASED
    22.09.1986