Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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7219/8-2

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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.
    7219/8-2
    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
    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.
    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.
    7219/8-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey WG0901:inline 641 & xline 4671
    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.
    Statoil Petroleum 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.
    1464-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.
    77
    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,
    16.07.2013
    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.
    30.09.2013
    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.
    30.09.2015
    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.
    30.09.2015
    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.
    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.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    STØ FM
    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.
    MIDDLE JURASSIC
    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.
    NORDMELA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    344.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3425.0
    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).
    3413.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    122
    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 TRIASSIC
    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.
    FRUHOLMEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 19' 17.55'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    19° 35' 21.28'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8030952.00
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    655422.85
    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.
    7225

  • Wellbore history
    General
    Well 7219/8-2 was drilled on the Iskrystall prospect in the Bjørnøyrenna Fault Complex southeast of the Johan Castberg Field in the Barents Sea. The primary objective was to prove hydrocarbons in the Stø, Nordmela and Tubåen formations and to prove the hydrocarbon-water contact observed in the seismic data.
    Operations and results
    Wildcat well 7219/8-2 was spudded with the semi-submersible installation West Hercules on 16 July 2013 and drilled to TD at 3425 m (3413 m TVD) in the Late Triassic Fruholmen Formation. No shallow gas was observed neither in the pilot hole nor main hole. From new data received while drilling it seemed possible to drill into a faulted zone in top of the reservoir. This lead to a decision of deviating the well through the Kolmule formation, so that the reservoir would be encountered outside the faulted zone. The well path was then built to 6.85 degrees through the Kolmule Formation. The well was drilled with seawater and hi-vis sweeps down to 1167 m, with KCl/Polymer/Glycol mud from 1167 m to 2681 m, and with Low Sulphate/KCl/Polymer/Glycol mud from 2681 m to TD down to TD.
    In the overburden, the well penetrated Tertiary and Cretaceous claystones and limestone stringers as well as Jurassic claystones. In the reservoir, the well penetrated sandstone, siltstone and claystones of Jurassic and Late Triassic age. The target reservoir, top Stø Formation, was penetrated at 2898 m. A 132 m gas column was proven in the Stø and Nordmela formations. No oil zone was encountered. The gas-water contact (GWC) was not seen in the well, but there was a gas down-to (GDT) in the lower shaly part of Nordmela Formation at 3106 m (3098 m TVD). Based on the gas and water gradients GWC was estimated to be at 3135 m (3127 m TVD). The reservoir quality was poorer than predicted due to extensive quartz cementation. There were no oil shows in the well and only condensate-like liquid hydrocarbons were observed by organic geochemical analyses of rock and fluid samples from the reservoir section. A thin gas sand was penetrated below the GWC at 3342 m in the Fruholmen Formation.
    Five cores were cut in the well. A shale core was taken in the Kolmule Formation from 2231 to 2239 m and four cores were cut in the target reservoir from 2903 to 3049.5 m. The overall core recovery was close to 100%.  MDT fluid samples were taken in the Stø Formation at 2951.2 m (gas), in the Nordmela Formation at 3101.0 m (gas), in the Tubåen Formation at 3225.0 m (water), and in the Fruholmen Formation at 3342.5 m (gas).
    The well was permanently abandoned on 30 September 2013 as a gas discovery.
    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]
    1170.00
    3425.00

  • 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
    2
    2903.5
    2939.1
    [m ]
    3
    2939.2
    2996.4
    [m ]
    4
    2997.0
    3042.2
    [m ]
    5
    3042.2
    3050.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    146.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1170.0
    [m]
    DC
    ROBERTSO
    1200.0
    [m]
    DC
    ROBERT
    1230.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1290.0
    [m]
    DC
    ROBERT
    1320.0
    [m]
    DC
    ROBERT
    1350.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1410.0
    [m]
    DC
    ROBERT
    1440.0
    [m]
    DC
    ROBERT
    1470.0
    [m]
    DC
    ROBERT
    1500.0
    [m]
    DC
    ROBERT
    1530.0
    [m]
    DC
    ROBERT
    1560.0
    [m]
    DC
    ROBERT
    1590.0
    [m]
    DC
    ROBERT
    1620.0
    [m]
    DC
    ROBERT
    1650.0
    [m]
    DC
    ROBERT
    1680.0
    [m]
    DC
    ROBERT
    1710.0
    [m]
    DC
    ROBERT
    1740.0
    [m]
    DC
    ROBERT
    1760.0
    [m]
    DC
    ROBERT
    1800.0
    [m]
    DC
    ROBERT
    1830.0
    [m]
    DC
    ROBERT
    1860.0
    [m]
    DC
    ROBERT
    1890.0
    [m]
    DC
    ROBERT
    1920.0
    [m]
    DC
    ROBERT
    1950.0
    [m]
    DC
    ROBERT
    1980.0
    [m]
    DC
    ROBERT
    2010.0
    [m]
    DC
    ROBERT
    2040.0
    [m]
    DC
    ROBERT
    2070.0
    [m]
    DC
    ROBERT
    2100.0
    [m]
    DC
    ROBERT
    2130.0
    [m]
    DC
    ROBERT
    2160.0
    [m]
    DC
    ROBERT
    2190.0
    [m]
    DC
    ROBERT
    2220.0
    [m]
    DC
    ROBERT
    2250.0
    [m]
    DC
    ROBERT
    2280.0
    [m]
    DC
    ROBERT
    2310.0
    [m]
    DC
    ROBERT
    2340.0
    [m]
    DC
    ROBERT
    2370.0
    [m]
    DC
    ROBERT
    2400.0
    [m]
    DC
    ROBERT
    2430.0
    [m]
    DC
    ROBERT
    2460.0
    [m]
    DC
    ROBERT
    2490.0
    [m]
    DC
    ROBERT
    2520.0
    [m]
    DC
    ROBERT
    2540.0
    [m]
    DC
    ROBERT
    2580.0
    [m]
    DC
    ROBERT
    2610.0
    [m]
    DC
    ROBERT
    2640.0
    [m]
    DC
    ROBERT
    2670.0
    [m]
    DC
    ROBERT
    2693.0
    [m]
    DC
    ROBERT
    2699.0
    [m]
    DC
    ROBERT
    2705.0
    [m]
    DC
    ROBERT
    2711.0
    [m]
    DC
    ROBERT
    2717.0
    [m]
    DC
    ROBERT
    2723.0
    [m]
    DC
    ROBERT
    2729.0
    [m]
    DC
    ROBERT
    2735.0
    [m]
    DC
    ROBERT
    2741.0
    [m]
    DC
    ROBERT
    2747.0
    [m]
    DC
    ROBERT
    2753.0
    [m]
    DC
    ROBERT
    2759.0
    [m]
    DC
    ROBERT
    2765.0
    [m]
    DC
    ROBERT
    2771.0
    [m]
    DC
    ROBERT
    2777.0
    [m]
    DC
    ROBERT
    2783.0
    [m]
    DC
    ROBERT
    2789.0
    [m]
    DC
    ROBERT
    2792.0
    [m]
    DC
    ROBERT
    2795.0
    [m]
    DC
    ROBERT
    2801.0
    [m]
    DC
    ROBERT
    2807.0
    [m]
    DC
    ROBERT
    2813.0
    [m]
    DC
    ROBERT
    2819.0
    [m]
    DC
    ROBERT
    2825.0
    [m]
    DC
    ROBERT
    2831.0
    [m]
    DC
    ROBERT
    2837.0
    [m]
    DC
    ROBERT
    2843.0
    [m]
    DC
    ROBERT
    2852.0
    [m]
    DC
    ROBERT
    2855.0
    [m]
    DC
    ROBERT
    2861.0
    [m]
    DC
    ROBERT
    2867.0
    [m]
    DC
    ROBERT
    2873.0
    [m]
    DC
    ROBERT
    2879.0
    [m]
    DC
    ROBERT
    2885.0
    [m]
    DC
    ROBERT
    2891.0
    [m]
    DC
    ROBERT
    2897.0
    [m]
    DC
    ROBERT
    2903.9
    [m]
    C
    ROBERT
    2910.2
    [m]
    C
    ROBERT
    2915.2
    [m]
    C
    ROBERT
    2920.8
    [m]
    C
    ROBERT
    2926.7
    [m]
    C
    ROBERT
    2929.6
    [m]
    C
    ROBERT
    2932.9
    [m]
    C
    ROBERT
    2935.5
    [m]
    C
    ROBERT
    2941.0
    [m]
    C
    ROBERT
    2947.9
    [m]
    C
    ROBERT
    2954.2
    [m]
    C
    ROBERT
    2961.9
    [m]
    C
    ROBERT
    2967.9
    [m]
    C
    ROBERT
    2972.6
    [m]
    C
    ROBERT
    2977.4
    [m]
    C
    ROBERT
    2982.9
    [m]
    C
    ROBERT
    2985.6
    [m]
    C
    ROBERT
    2988.6
    [m]
    C
    ROBERT
    2993.9
    [m]
    C
    ROBERT
    2997.4
    [m]
    C
    ROBERT
    3002.7
    [m]
    C
    ROBERT
    3005.7
    [m]
    C
    ROBERT
    3009.6
    [m]
    C
    ROBERT
    3015.2
    [m]
    C
    ROBERT
    3022.0
    [m]
    C
    ROBERT
    3027.7
    [m]
    C
    ROBERT
    3034.8
    [m]
    C
    ROBERT
    3037.0
    [m]
    C
    ROBERT
    3042.7
    [m]
    C
    ROBERT
    3047.9
    [m]
    C
    ROBERT
    3050.6
    [m]
    C
    ROBERT
    3053.0
    [m]
    C
    ROBERT
    3059.0
    [m]
    DC
    ROBERT
    3065.0
    [m]
    DC
    ROBERT
    3071.0
    [m]
    DC
    ROBERT
    3077.0
    [m]
    DC
    ROBERT
    3083.0
    [m]
    DC
    ROBERT
    3089.0
    [m]
    DC
    ROBERT
    3095.0
    [m]
    DC
    ROBERT
    3101.0
    [m]
    DC
    ROBERT
    3107.0
    [m]
    DC
    ROBERT
    3113.0
    [m]
    DC
    ROBERT
    3119.0
    [m]
    DC
    ROBERT
    3125.0
    [m]
    DC
    ROBERT
    3131.0
    [m]
    DC
    ROBERT
    3137.0
    [m]
    DC
    ROBERT
    3143.0
    [m]
    DC
    ROBERT
    3149.0
    [m]
    DC
    ROBERT
    3155.0
    [m]
    DC
    ROBERT
    3161.0
    [m]
    DC
    ROBERT
    3167.0
    [m]
    DC
    ROBERT
    3173.0
    [m]
    DC
    ROBERT
    3179.0
    [m]
    DC
    ROBERT
    3185.0
    [m]
    DC
    ROBERT
    3191.0
    [m]
    DC
    ROBERT
    3197.0
    [m]
    DC
    ROBERT
    3203.0
    [m]
    DC
    ROBERT
    3209.0
    [m]
    DC
    ROBERT
    3215.0
    [m]
    DC
    ROBERT
    3221.0
    [m]
    DC
    ROBERT
    3227.0
    [m]
    DC
    ROBERT
    3233.0
    [m]
    DC
    ROBERT
    3239.0
    [m]
    DC
    ROBERT
    3245.0
    [m]
    DC
    ROBERT
    3251.0
    [m]
    DC
    ROBERT
    3260.0
    [m]
    DC
    ROBERT
    3269.0
    [m]
    DC
    ROBERT
    3278.0
    [m]
    DC
    ROBERT
    3287.0
    [m]
    DC
    ROBERT
    3296.0
    [m]
    DC
    ROBERT
    3304.0
    [m]
    DC
    ROBERT
    3305.0
    [m]
    DC
    ROBERT
    3314.0
    [m]
    DC
    ROBERT
    3323.0
    [m]
    DC
    ROBERT
    3332.0
    [m]
    DC
    ROBERT
    3341.0
    [m]
    DC
    ROBERT
    3350.0
    [m]
    DC
    ROBERT
    3359.0
    [m]
    DC
    ROBERT
    3368.0
    [m]
    DC
    ROBERT
    3377.0
    [m]
    DC
    ROBERT
    3386.0
    [m]
    DC
    ROBERT
    3395.0
    [m]
    DC
    ROBERT
    3413.0
    [m]
    DC
    ROBERT
    3425.0
    [m]
    DC
    ROBERT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR ECS HNGS
    2679
    3408
    FMI MSIP GR
    1950
    3412
    HRLA PEX GR
    2677
    3414
    MDT GR
    2901
    3343
    MSCT GR
    2792
    3382
    MWD - ARCVRES TELE
    1167
    3425
    MWD - PDX5 ARCVRES TELE
    2616
    2681
    ZOVSP GR
    1708
    3400

  • 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
    36
    426.0
    42
    429.0
    0.00
    SURF.COND.
    20
    1158.0
    26
    1167.0
    1.23
    FIT
    PILOT HOLE
    1160.0
    9 7/8
    1160.0
    0.00
    INTERM.
    13 3/8
    2200.0
    17 1/2
    2206.0
    1.59
    LOT
    INTERM.
    9 5/8
    2679.0
    12 1/4
    2681.0
    1.63
    LOT
    OPEN HOLE
    3425.0
    8 1/2
    3425.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1116
    1.13
    17.0
    KCl/Polymer/Glycol
    2020
    1.13
    19.0
    KCl/Polymer/Glycol
    2212
    1.14
    20.0
    KCl/Polymer/Glycol
    2332
    1.16
    22.0
    KCl/Polymer/Glycol
    2610
    1.22
    24.0
    Low Sulphate/KCl/Polymer/Glycol
    2681
    1.17
    23.0
    KCl/Polymer/Glycol
    2681
    1.20
    30.0
    Low Sulphate/KCl/Polymer/Glycol
    2681
    1.16
    26.0
    KCl/Polymer/Glycol
    2681
    1.16
    25.0
    KCl/Polymer/Glycol
    2684
    1.17
    21.0
    KCl/Polymer/Glycol
    2726
    1.20
    26.0
    Low Sulphate/KCl/Polymer/Glycol
    2990
    1.22
    31.0
    Low Sulphate/KCl/Polymer/Glycol
    3425
    1.22
    32.0
    Low Sulphate/KCl/Polymer/Glycol