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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2/7-26 S

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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.
    2/7-26 S
    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.
    RE-CLASS TO DEV
    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.
    2/7-26
    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.
    Phillips Petroleum Company Norway
    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.
    674-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.
    178
    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,
    20.03.1991
    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.
    13.09.1991
    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.
    13.09.1993
    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.
    26.05.2009
    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
    Reclassified to wellbore
    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.
    DEVONIAN
    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.
    NO GROUP DEFINED
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    70.8
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4848.0
    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).
    4697.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    24
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    167
    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.
    DEVONIAN
    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.
    NO GROUP DEFINED
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 19' 59.59'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 14' 53.55'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6243333.20
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    515347.49
    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.
    1756

  • Wellbore history
    General
    Well 2/7 26 S is located on the Embla Field in the Central Graben of the North Sea. It was designed to test the pre-Jurassic sandstones, which had shown commercial quantities of hydrocarbons in the 2/7-20, 2/7-21 S, and 2/7-23 S wells. The objective of the well was to confirm the presence of hydrocarbon bearing sandstones in the western fault block of the structure and to establish the productivity of this reservoir section through a program of well testing and coring. Well location and TD was chosen so that both the upper and lower sandstone members of the pre-Jurassic sequence would be penetrated. The target location was 300 m to the south of the 2/7-9 well at Base Cretaceous level. The reservoir section was expected to be highly fractured and over-pressured. Shallow gas was expected since gas had been encountered in all wells drilled from the template location over the 2/7-20 well.
    Operations and results
    Appraisal well 2/7 26 S was spudded with the semi-submersible installation West Delta on 20 March 1991 and drilled to TD at 4848 in Devonian rocks. The well was drilled deviated from a template located over the 2/7-20 well to penetrate the target reservoir section in the western fault block of the Embla structure. Minor shallow gas was detected in sandy zones with an increase in background gas from 4 to 64 units. Apart from some failures when logging and some stuck pipe experiences, drilling proceeded without significant problems. The well was drilled with seawater and hi-vis sweeps down to 575 m, with KCl/PAC mud from 575 m to 4125.5 m, and with Enviromul oil based mud from 4125.5 m to TD.
    The 9 5/8" casing was set in claystones of the Lower Cretaceous, Rødby Formation. The remaining Lower Cretaceous section including Sola, Tuxen and Åsgård Formations was penetrated, followed by a Late Jurassic sequence consisting of 3 m Mandal Formation and 82 m Farsund Formation. The top of the reservoir sands were encountered at 4386 m (4226 m TVD), 58 m higher than prognosed. As in the other Embla wells the reservoir was undefined, Pre-Jurassic  stratigraphy. Both the upper and the lower sandstone units were present in the well as predicted. The reservoir was oil bearing. No definite OWC was defined, however RFT pressure data, logs and DST results indicated oil-filled porous sandstones from top reservoir and down to at least 4606 m (4465 m TVD).
    The cuttings in the intervals between 1520 - 1680 m and 1730 - 1830 m (Base Nordland Group / upper Hordaland Group) showed 30-100% pale to bright yellow fluorescence accompanied by oil in the mud. The cut was blooming to streaming yellow, and the odour was good to strong. Good to excellent oil shows were seen in the interval 3111.4 m to 3973 m with 35% fluorescence in marls/limestones from 3111.4 m and rapidly increasing to 70% by 3018.1 m. Shows up to 80%, with bright yellow fluorescence and yellow fast streaming cut, were seen from 3124.2 to 3230.9 m. Shows were also seen at 3550.9 m, 5% -10% with dull yellow fluorescence and hazy crushed cut. From 3627.1 to 3834.4 m shows of 20% to 80% with a dull fluorescence were seen. The cut was pale blue yellow and slightly streaming. Shows further down in the well, including the pre-Jurassic reservoir section were weak and most likely caused by the oil-based mud.
    A total of 18 cores were cut in the well. The first was cut at 3200.4 - 3214.3 m in the Tor Formation. The second core was cut through the Mandal Formation and into the upper part of the Farsund Formation. A total of 16 cores were cut in the reservoir interval including a core in the rhyolittic rocks at TD. A total of 90 sidewall cores were attempted and 28 sidewall cores were recovered. No wire line fluid samples were taken.
    The well was suspended on 13 September 1991 as an oil appraisal well and reclassified to development well 2/7-D-26
    Testing
    Two DST tests were performed in this well.
    DST 1 was conducted over the interval 4605.5 - 4696.9 m (4465.0 - 4552.2 m TVD). It flowed in the range of 48 Sm3 (300 STB) /day, with signs of unstable flow, at pressures less than 1000 psi.
    DST 2 was conducted over a gross interval from 4309.8 - 4538.4 (4184 - 4401 m TVD).The well was tested on a 16/64" choke with flowing rates of 223 Sm3 oil and 61447 Sm3 gas/day. The GOR was 275 Sm3/Sm3, the oil density was 0.81 g/cm3 (43 deg API), and the gas gravity (air = 1) was 0.81 with 6% CO2 and 20 ppm H2S. A stable down-hole temperature of 160 deg C was measured in the test.

  • 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]
    579.00
    4547.60

  • 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
    10500.0
    10545.5
    [ft ]
    2
    14103.0
    14153.9
    [ft ]
    3
    14417.0
    14453.1
    [ft ]
    4
    14457.0
    14480.8
    [ft ]
    5
    14481.0
    14545.8
    [ft ]
    6
    14558.0
    14581.6
    [ft ]
    7
    14586.0
    14592.1
    [ft ]
    8
    14598.0
    14635.6
    [ft ]
    9
    14636.0
    14658.0
    [ft ]
    10
    14660.0
    14693.6
    [ft ]
    11
    14696.0
    14743.8
    [ft ]
    12
    14746.0
    14807.2
    [ft ]
    13
    14807.0
    14848.0
    [ft ]
    14
    14854.0
    14903.6
    [ft ]
    15
    14903.0
    14935.6
    [ft ]
    16
    15312.0
    15403.6
    [ft ]
    17
    15404.0
    15495.1
    [ft ]
    18
    15844.0
    15907.7
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    250.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 5480-5487ft
    Core photo at depth: 10500-10510ft
    Core photo at depth: 10510-10522ft
    Core photo at depth: 10522-10534ft
    Core photo at depth: 10534-10545ft
    5480-5487ft
    10500-10510ft
    10510-10522ft
    10522-10534ft
    10534-10545ft
    Core photo at depth: 14103-14118ft
    Core photo at depth: 14118-14133ft
    Core photo at depth: 14133-14148ft
    Core photo at depth: 14148-14153ft
    Core photo at depth: 14417-14432ft
    14103-14118ft
    14118-14133ft
    14133-14148ft
    14148-14153ft
    14417-14432ft
    Core photo at depth: 14432-14447ft
    Core photo at depth: 14447-14453ft
    Core photo at depth: 14457-14472ft
    Core photo at depth: 14472-14480ft
    Core photo at depth: 14481-14496ft
    14432-14447ft
    14447-14453ft
    14457-14472ft
    14472-14480ft
    14481-14496ft
    Core photo at depth: 14496-14511ft
    Core photo at depth: 14511-14526ft
    Core photo at depth: 14526-14541ft
    Core photo at depth: 14541-14545ft
    Core photo at depth: 14558-14573ft
    14496-14511ft
    14511-14526ft
    14526-14541ft
    14541-14545ft
    14558-14573ft
    Core photo at depth: 14573-14581ft
    Core photo at depth: 14586-14592ft
    Core photo at depth: 14598-14613ft
    Core photo at depth: 14613-14628ft
    Core photo at depth: 14628-14635ft
    14573-14581ft
    14586-14592ft
    14598-14613ft
    14613-14628ft
    14628-14635ft
    Core photo at depth: 14636-14651ft
    Core photo at depth: 14651-14658ft
    Core photo at depth: 14660-14675ft
    Core photo at depth: 14675-14690ft
    Core photo at depth: 14790-14693ft
    14636-14651ft
    14651-14658ft
    14660-14675ft
    14675-14690ft
    14790-14693ft
    Core photo at depth: 14696-14711ft
    Core photo at depth: 14711-14726ft
    Core photo at depth: 14726-14741ft
    Core photo at depth: 14741-14743ft
    Core photo at depth: 14746-14761ft
    14696-14711ft
    14711-14726ft
    14726-14741ft
    14741-14743ft
    14746-14761ft
    Core photo at depth: 14761-14776ft
    Core photo at depth: 14776-14791ft
    Core photo at depth: 14791-14806ft
    Core photo at depth: 14806-14807ft
    Core photo at depth: 14807-14822ft
    14761-14776ft
    14776-14791ft
    14791-14806ft
    14806-14807ft
    14807-14822ft
    Core photo at depth: 14822-14837ft
    Core photo at depth: 14854-14869ft
    Core photo at depth: 14869-14884ft
    Core photo at depth: 14884-14899ft
    Core photo at depth: 14899-14903ft
    14822-14837ft
    14854-14869ft
    14869-14884ft
    14884-14899ft
    14899-14903ft
    Core photo at depth: 14903-14918ft
    Core photo at depth: 14918-14933ft
    Core photo at depth: 14933-14935ft
    Core photo at depth: 15312-15327ft
    Core photo at depth: 15327-15342ft
    14903-14918ft
    14918-14933ft
    14933-14935ft
    15312-15327ft
    15327-15342ft
    Core photo at depth: 15342-15357ft
    Core photo at depth: 15357-15372ft
    Core photo at depth: 15372-15387ft
    Core photo at depth: 15387-15402ft
    Core photo at depth: 15402-15403ft
    15342-15357ft
    15357-15372ft
    15372-15387ft
    15387-15402ft
    15402-15403ft
    Core photo at depth: 15404-15419ft
    Core photo at depth: 15419-15434ft
    Core photo at depth: 15434-15449ft
    Core photo at depth: 15449-15464ft
    Core photo at depth: 15464-15479ft
    15404-15419ft
    15419-15434ft
    15434-15449ft
    15449-15464ft
    15464-15479ft
    Core photo at depth: 15479-15494ft
    Core photo at depth: 15494-15495ft
    Core photo at depth: 15844-15859ft
    Core photo at depth: 15859-15874ft
    Core photo at depth: 15874-15889ft
    15479-15494ft
    15494-15495ft
    15844-15859ft
    15859-15874ft
    15874-15889ft
    Core photo at depth: 15889-15904ft
    Core photo at depth: 15904-15907ft
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    15889-15904ft
    15904-15907ft

  • 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
    DST 1
    4605.50
    4696.90
    24.08.1991 - 00:00
    YES
    DST
    DST 2
    4309.80
    4538.40
    03.09.1991 - 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
    158.0
    36
    160.0
    0.00
    LOT
    INTERM.
    20
    571.0
    26
    573.0
    0.00
    LOT
    INTERM.
    13 3/8
    2130.0
    17 1/2
    2133.0
    1.91
    LOT
    INTERM.
    9 5/8
    4117.0
    12 1/4
    4120.0
    2.16
    LOT
    INTERM.
    6 5/8
    4847.0
    8 1/8
    4848.0
    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
    4606
    4697
    6.3
    2.0
    4310
    4538
    6.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    133
    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
    53
    10123
    0.819
    191
    2.0
    223
    61447
    0.819
    0.810
    279

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    4145
    4829
    CST GR
    4147
    4777
    DLL MSFL BHC GR AMS
    2133
    4104
    FMS GR
    3112
    4083
    LDL CNL GR AMS
    3088
    4070
    LDL CNL NGL AMS
    4256
    4859
    MWD - GR RES DIR
    274
    4394
    OBDT GR
    4120
    4857
    PIL ASL GR AMS
    3977
    4856
    RFT GR
    3134
    3530
    RFT GR
    4174
    4715
    VELOCITY
    2255
    4800

  • Lithostratigraphy

  • 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
    2.75
    pdf
    38.80

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    118
    1.05
    WATER BASED
    160
    1.05
    WATER BASED
    180
    1.05
    WATER BASED
    294
    1.05
    WATER BASED
    576
    1.20
    WATER BASED
    694
    1.32
    35.0
    OIL BASED
    1178
    1.32
    38.0
    OIL BASED
    1628
    1.56
    42.0
    OIL BASED
    1991
    1.70
    32.0
    OIL BASED
    2143
    1.70
    26.0
    OIL BASED
    2146
    1.70
    38.0
    OIL BASED
    2288
    1.70
    18.0
    OIL BASED
    2473
    1.70
    18.0
    OIL BASED
    2630
    1.70
    20.0
    OIL BASED
    2724
    1.70
    19.0
    OIL BASED
    2874
    1.73
    21.0
    OIL BASED
    2983
    1.73
    22.0
    OIL BASED
    2987
    1.73
    22.0
    OIL BASED
    2998
    1.73
    23.0
    OIL BASED
    3047
    1.73
    21.0
    OIL BASED
    3125
    1.73
    22.0
    OIL BASED
    3138
    1.73
    22.0
    OIL BASED
    3200
    1.73
    21.0
    OIL BASED
    3219
    1.73
    26.0
    OIL BASED
    3341
    1.73
    21.0
    OIL BASED
    3385
    1.73
    20.0
    OIL BASED
    3487
    1.73
    24.0
    OIL BASED
    3498
    1.73
    24.0
    OIL BASED
    3532
    1.73
    22.0
    OIL BASED
    3625
    1.73
    26.0
    OIL BASED
    3678
    1.73
    26.0
    OIL BASED
    3749
    1.73
    27.0
    OIL BASED
    3772
    1.73
    26.0
    OIL BASED
    3778
    1.73
    26.0
    OIL BASED
    3783
    1.75
    26.0
    OIL BASED
    3987
    1.75
    24.0
    OIL BASED
    3999
    1.75
    24.0
    OIL BASED
    4062
    1.75
    26.0
    OIL BASED
    4073
    1.75
    23.0
    OIL BASED
    4113
    1.93
    35.0
    WATER BASED
    4116
    1.75
    22.0
    OIL BASED
    4126
    1.76
    26.0
    OIL BASED
    4146
    2.00
    52.0
    WATER BASED
    4208
    2.02
    53.0
    WATER BASED
    4256
    2.02
    49.0
    WATER BASED
    4279
    2.04
    46.0
    OIL BASED
    4299
    2.02
    44.0
    WATER BASED
    4314
    2.02
    44.0
    WATER BASED
    4315
    2.04
    45.0
    WATER BASED
    4331
    2.04
    45.0
    WATER BASED
    4362
    2.06
    49.0
    WATER BASED
    4394
    2.06
    50.0
    WATER BASED
    4394
    2.06
    49.0
    WATER BASED
    4407
    2.04
    55.0
    WATER BASED
    4414
    2.06
    49.0
    WATER BASED
    4436
    2.06
    50.0
    WATER BASED
    4450
    2.06
    50.0
    WATER BASED
    4468
    2.06
    49.0
    WATER BASED
    4479
    2.06
    49.0
    WATER BASED
    4523
    2.06
    54.0
    WATER BASED
    4542
    2.04
    48.0
    WATER BASED
    4553
    2.04
    53.0
    WATER BASED
    4554
    2.04
    52.0
    WATER BASED
    4602
    2.04
    46.0
    WATER BASED
    4657
    2.04
    43.0
    OIL BASED
    4723
    2.04
    46.0
    WATER BASED
    4849
    2.04
    42.0
    WATER BASED
    4849
    2.04
    42.0
    OIL BASED