Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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2/2-5

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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.
    2/2-5
    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.
    NORTH 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.
    2/2-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG - 8752 - 315 SP 310
    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.
    Saga Petroleum ASA
    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.
    705-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.
    105
    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,
    07.11.1991
    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.
    19.02.1992
    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.
    19.02.1994
    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.
    17.12.2003
    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.
    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.
    LATE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    63.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4082.0
    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).
    4081.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    160
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 50' 5.8'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 27' 22.9'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6299246.57
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    527846.84
    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.
    1846

  • Wellbore history
    General
    The main objective of the exploration well 2/2-5 was to test the hydrocarbon potential of the Upper Jurassic Ula Formation situated in the Epsilon structure. The structure is a salt induced anticline situated on a rotated, down thrown fault block in the Ula-Gyda Fault zone. The Oligocene Vade Formation was the secondary target.  A seismic anomaly indicated a potential gas accumulation in this zone.
    Operations and results
    Well 2/2-5 was spudded by the semi submersible rig Treasure Saga on November 7 1991 and completed February 20 1992 in Permian Zechstein Group. The well was drilled with spud mud down to 918 m, with KCl mud from 918 m to 3484 m, and with HITEMP Polymer mud from 3484 m to TD.
    The well penetrated mainly claystone with minor sandstone in Nordland, Hordaland, and Rogaland Group. The Vade Formation (within Hordaland Group) proved to be water bearing.  After drilling throughout a typical sequence of the Shetland and Cromer Knoll groups, the top of the Tyne Group was encountered at 3418 m. The Ula Formation, which was reached at 3538 m, consisted of an interbedded sequence of sandstone, siltstone, and shale.
    A 5-meter thick oil bearing zone within the Ula Formation was encountered at 3671 m. An attempt made to obtain an oil sample using RFT failed as the fluid chambers contained mud filtrate only. Geochemical analyses of oil from the DST revealed an unusual chemical and isotopic composition unlike any oil in the area. Sediments interpreted to be Triassic age were penetrated at 3989 m and may represent either a fault gouge above salt or the up thrown fault block. The well was permanently abandoned as an oil discovery on 19 February 1992.
    Testing
    One DST test was performed over the interval 3671.25 m to 3675.5 m. The well flowed oil at maximum rate 600 Sm3 / day. The oil had a density of 0.86 g/cm3 and the GOR was 44.

  • 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]
    920.00
    4080.00

  • 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
    3592.0
    3609.0
    [m ]
    2
    3678.0
    3706.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    45.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3592-3597m
    Core photo at depth: 3597-3602m
    Core photo at depth: 3602-3607m
    Core photo at depth: 3607-3609m
    Core photo at depth: 3678-3683m
    3592-3597m
    3597-3602m
    3602-3607m
    3607-3609m
    3678-3683m
    Core photo at depth: 3683-3688m
    Core photo at depth: 3688-3693m
    Core photo at depth: 3693-3698m
    Core photo at depth: 3698-3703m
    Core photo at depth: 3703-3706m
    3683-3688m
    3688-3693m
    3693-3698m
    3698-3703m
    3703-3706m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1620.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
    3320.0
    [m]
    DC
    RRI
    3380.0
    [m]
    DC
    RRI
    3400.0
    [m]
    DC
    RRI
    3421.0
    [m]
    DC
    RRI
    3429.0
    [m]
    DC
    RRI
    3441.0
    [m]
    DC
    RRI
    3450.0
    [m]
    DC
    RRI
    3459.0
    [m]
    DC
    RRI
    3468.0
    [m]
    DC
    RRI
    3480.0
    [m]
    DC
    RRI
    3489.0
    [m]
    DC
    RRI
    3501.0
    [m]
    DC
    RRI
    3510.0
    [m]
    DC
    RRI
    3510.0
    [m]
    DC
    UOSHE
    3519.0
    [m]
    DC
    RRI
    3531.0
    [m]
    DC
    RRI
    3531.0
    [m]
    DC
    UOSHE
    3540.0
    [m]
    DC
    UOSHE
    3540.0
    [m]
    DC
    RRI
    3549.0
    [m]
    DC
    RRI
    3560.0
    [m]
    DC
    RRI
    3570.0
    [m]
    DC
    RRI
    3580.0
    [m]
    DC
    RRI
    3582.0
    [m]
    DC
    UOSHE
    3588.0
    [m]
    DC
    UOSHE
    3592.1
    [m]
    C
    UOSHE
    3592.2
    [m]
    C
    RRI
    3593.7
    [m]
    C
    RRI
    3594.1
    [m]
    C
    UOSHE
    3595.5
    [m]
    C
    UOSHE
    3599.7
    [m]
    C
    UOSHE
    3601.0
    [m]
    C
    UOSHE
    3602.2
    [m]
    C
    UOSHE
    3604.0
    [m]
    C
    UOSHE
    3607.0
    [m]
    C
    UOSHE
    3608.0
    [m]
    C
    UOSHE
    3608.6
    [m]
    C
    RRI
    3609.0
    [m]
    C
    UOSHE
    3612.0
    [m]
    DC
    UOSHE
    3620.0
    [m]
    DC
    RRI
    3624.0
    [m]
    DC
    UOSHE
    3630.0
    [m]
    DC
    RRI
    3640.0
    [m]
    DC
    RRI
    3645.0
    [m]
    DC
    UOSHE
    3650.0
    [m]
    DC
    RRI
    3660.0
    [m]
    DC
    RRI
    3663.0
    [m]
    DC
    UOSHE
    3670.0
    [m]
    DC
    RRI
    3678.2
    [m]
    C
    RRI
    3678.2
    [m]
    C
    UOSHE
    3680.0
    [m]
    DC
    RRI
    3683.4
    [m]
    C
    UOSHE
    3689.2
    [m]
    C
    UOSHE
    3690.0
    [m]
    DC
    RRI
    3695.3
    [m]
    C
    UOSHE
    3703.0
    [m]
    C
    UOSHE
    3705.0
    [m]
    C
    RRI
    3705.8
    [m]
    C
    RRI
    3711.0
    [m]
    DC
    UOSHE
    3720.0
    [m]
    DC
    RRI
    3726.0
    [m]
    DC
    UOSHE
    3729.0
    [m]
    DC
    RRI
    3741.0
    [m]
    DC
    RRI
    3744.0
    [m]
    DC
    UOSHE
    3750.0
    [m]
    DC
    RRI
    3756.0
    [m]
    DC
    UOSHE
    3759.0
    [m]
    DC
    RRI
    3760.0
    [m]
    DC
    RRI
    3771.0
    [m]
    DC
    RRI
    3780.0
    [m]
    DC
    RRI
    3789.0
    [m]
    DC
    RRI
    3789.0
    [m]
    DC
    UOSHE
    3801.0
    [m]
    DC
    RRI
    3807.0
    [m]
    DC
    UOSHE
    3810.0
    [m]
    DC
    UOSHE
    3810.0
    [m]
    DC
    RRI
    3819.0
    [m]
    DC
    RRI
    3819.0
    [m]
    DC
    UOSHE
    3822.0
    [m]
    DC
    UOSHE
    3831.0
    [m]
    DC
    RRI
    3840.0
    [m]
    DC
    RRI
    3849.0
    [m]
    DC
    RRI
    3849.0
    [m]
    DC
    UOSHE
    3861.0
    [m]
    DC
    RRI
    3867.0
    [m]
    DC
    UOSHE
    3870.0
    [m]
    DC
    RRI
    3879.0
    [m]
    DC
    RRI
    3891.0
    [m]
    DC
    RRI
    3894.0
    [m]
    DC
    UOSHE
    3900.0
    [m]
    DC
    RRI
    3903.0
    [m]
    DC
    UOSHE
    3909.0
    [m]
    DC
    RRI
    3921.0
    [m]
    DC
    RRI
    3924.0
    [m]
    DC
    UOSHE
    3942.0
    [m]
    DC
    RRI
    3945.0
    [m]
    DC
    UOSHE
    3960.0
    [m]
    DC
    RRI
    3969.0
    [m]
    DC
    RRI
    3972.0
    [m]
    DC
    UOSHE
    3981.0
    [m]
    DC
    RRI
    3987.0
    [m]
    DC
    UOSHE
    3990.0
    [m]
    DC
    RRI
    4002.0
    [m]
    DC
    RRI
    4011.0
    [m]
    DC
    RRI
    4020.0
    [m]
    DC
    RRI
    4032.0
    [m]
    DC
    RRI
    4041.0
    [m]
    DC
    RRI
    4050.0
    [m]
    DC
    RRI
    4059.0
    [m]
    DC
    UOSHE
    4062.0
    [m]
    DC
    RRI
    4071.0
    [m]
    DC
    RRI
    4077.0
    [m]
    DC
    UOSHE
    4080.0
    [m]
    DC
    RRI

  • 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
    TEST-1
    3670.00
    2666.00
    OIL
    12.02.1992 - 19:30
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.61

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.97
    pdf
    1.99

  • 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
    19.59

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3666
    3670
    7.9
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    141
    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
    600
    44

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    2227
    3365
    DIL MSFL LSS LDL CNL TLC
    3352
    3627
    DLL LSS LDL CST
    903
    2365
    DLL LSS LDL VDL CST
    2363
    3353
    MWD - GR RES DIR
    188
    190
    MWD DPR - GR RES DIR
    190
    918
    MWD DPR - GR RES DIR
    3365
    4082
    MWD MNP MDL DPR
    3555
    4087
    MWD RGD - GR RES DIR
    918
    3365
    RFT TLC
    3610
    3679
    SHDT
    3352
    3627
    VSP
    2360
    3349
    VSP TLC
    3522
    3722

  • 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
    188.0
    36
    190.0
    0.00
    LOT
    INTERM.
    20
    903.0
    26
    905.0
    1.70
    LOT
    INTERM.
    13 3/8
    2362.0
    17 1/2
    2364.0
    1.75
    LOT
    INTERM.
    9 5/8
    3349.0
    12 1/4
    3350.0
    2.02
    LOT
    LINER
    7
    4082.0
    8 1/2
    4082.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    162
    1.05
    WATER BASED
    190
    1.10
    WATER BASED
    502
    1.10
    WATER BASED
    918
    1.20
    WATER BASED
    1029
    1.20
    27.0
    WATER BASED
    1333
    1.39
    31.0
    WATER BASED
    1680
    1.39
    36.0
    WATER BASED
    1937
    1.41
    41.0
    WATER BASED
    2044
    1.45
    40.0
    WATER BASED
    2377
    1.45
    41.0
    WATER BASED
    2523
    1.45
    33.0
    WATER BASED
    2704
    1.45
    37.0
    WATER BASED
    2790
    1.48
    43.0
    WATER BASED
    2906
    1.48
    39.0
    WATER BASED
    3034
    1.48
    32.0
    WATER BASED
    3140
    1.48
    31.0
    WATER BASED
    3148
    1.48
    28.0
    WATER BASED
    3283
    1.50
    35.0
    WATER BASED
    3334
    1.52
    37.0
    WATER BASED
    3349
    1.51
    20.0
    WATER BASED
    3365
    1.52
    34.0
    WATER BASED
    3381
    1.52
    27.0
    WATER BASED
    3418
    1.50
    25.0
    WATER BASED
    3475
    1.50
    17.0
    WATER BASED
    3484
    1.50
    16.0
    WATER BASED
    3660
    1.54
    18.0
    WATER BASED
    3666
    1.54
    20.0
    WATER BASED
    3865
    1.51
    20.0
    WATER BASED
    3951
    1.51
    19.0
    WATER BASED
    3972
    1.51
    22.0
    WATER BASED
    3981
    1.51
    20.0
    WATER BASED
    3985
    1.51
    19.0
    WATER BASED
    4059
    1.51
    18.0
    WATER BASED
    4082
    1.51
    20.0
    WATER BASED