Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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7220/4-1

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7220/4-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Press release
    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.
    7220/4-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey WG08STR10 : inline 1324 & xline 4288
    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.
    1494-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.
    65
    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,
    22.12.2013
    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.
    25.02.2014
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    25.02.2016
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    25.02.2016
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    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
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    TRIASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    SNADD 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.
    403.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3240.0
    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).
    3239.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    105
    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.
    MIDDLE 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.
    SNADD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 35' 19.67'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 14' 5.97'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8062450.07
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    674650.00
    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.
    7307

  • Wellbore history
    General
    Well 7220/4-1 was drilled to test the Kramsnø prospect in the Johan Castberg area of the Barents Sea. The primary objective was to prove commercial volumes of hydrocarbons in the Stø, Nordmela and Tubåen formations and confirm the GOC and OWC seen on seismics. Secondary objective was to investigate the Snadd Formation and acquire data for exploration of the Triassic play.
    Operations and results
    Wildcat well 7220/4-1 was spudded with the semi-submersible installation West Hercules on 22 December 2013 and drilled to TD at 3240 m in the Triassic Snadd Formation. No significant problem was encountered in the operations. The well was drilled with Seawater and hi-vis pills down to 744 m, with KCl/polymer/glycol mud from 744 m to 2128 m, and with Low sulphate/KCl/polymer/glycol from 2128 m to TD.
    A potential source rock section is proven by sidewall cores and elevated Gamma Ray in the interval 2220 to 2228 m within the Knurr Formation (Late Barremian). This section has TOC from 2.5 to 4.1% and Rock-Eval Hydrogen Index in the range 270 to 370 mg HC/g TOC. The Hekkingen Formation source rock is not present in the well. In the reservoir, the well penetrated sandstone and siltstone of the Jurassic Stø and Nordmela Formations. MDT pressure gradients show a gas column from top Stø Formation at 2267 m and down to a gas/water contact at 2400 m in the Nordmela Formation. The reservoir quality in Stø, Nordmela and Tubåen formations is deteriorated by extensive quartz cementation. There was no oil leg in the well, but weak oil shows are recorded from 2387 m and downwards in the cored section in Nordmela and Tubåen formations. Further weak oil shows (cut fluorescence) are described on cuttings down to 2503 m in the Tubåen Formation.
    Triassic sandstones and claystones were encountered in the Fruholmen and Snadd Formations. Gas was found in two zones in the Snadd Formation: from 3002 m with gas down-to contact at 3047 m and from 3117 with gas down-to contact at 3162 m. The overall reservoir quality in Snadd is poor due to the low net thickness of permeable sandstones.
    Three cores with a total recovery of 185.4 m were taken in the Stø, Nordmela and Tubåen formations. The core-log depth shifts are -1.7 m, -2.8 m and - 3.3 m for cores 1, 2, and 3, respectively. MDT fluid samples were taken at 2334.4 m (gas), 2393.6 m (gas), 2417.5 m (water), and 3009 m (gas),
    The well was permanently abandoned on 25 February 2014 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]
    755.00
    3240.00

  • 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
    2274.0
    2318.2
    [m ]
    2
    2319.0
    2389.7
    [m ]
    3
    2390.0
    2460.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    185.5
    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
    755.0
    [m]
    DC
    ROBERTSO
    790.0
    [m]
    DC
    ROBERT
    825.0
    [m]
    DC
    ROBERT
    860.0
    [m]
    DC
    ROBERT
    895.0
    [m]
    DC
    ROBERT
    930.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    990.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1050.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1110.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1170.0
    [m]
    DC
    ROBERT
    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
    1770.0
    [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
    2140.0
    [m]
    DC
    ROBERT
    2146.0
    [m]
    DC
    ROBERT
    2152.0
    [m]
    DC
    ROBERT
    2158.0
    [m]
    DC
    ROBERT
    2164.0
    [m]
    DC
    ROBERT
    2170.0
    [m]
    DC
    ROBERT
    2176.0
    [m]
    DC
    ROBERT
    2182.0
    [m]
    DC
    ROBERT
    2188.0
    [m]
    DC
    ROBERT
    2194.0
    [m]
    DC
    ROBERT
    2200.0
    [m]
    DC
    ROBERT
    2206.0
    [m]
    DC
    ROBERT
    2212.0
    [m]
    DC
    ROBERT
    2218.0
    [m]
    DC
    ROBERT
    2224.0
    [m]
    DC
    ROBERT
    2230.0
    [m]
    DC
    ROBERT
    2236.0
    [m]
    DC
    ROBERT
    2242.0
    [m]
    DC
    ROBERT
    2248.0
    [m]
    DC
    ROBERT
    2248.0
    [m]
    SWC
    ROBERT
    2254.0
    [m]
    DC
    ROBERT
    2260.0
    [m]
    DC
    ROBERT
    2260.0
    [m]
    SWC
    ROBERT
    2266.0
    [m]
    DC
    ROBERT
    2274.0
    [m]
    DC
    ROBERT
    2274.2
    [m]
    C
    ROBERT
    2275.1
    [m]
    C
    ROBERT
    2282.6
    [m]
    C
    ROBERT
    2291.8
    [m]
    C
    ROBERT
    2297.7
    [m]
    C
    ROBERT
    2302.3
    [m]
    C
    ROBERT
    2304.6
    [m]
    C
    ROBERT
    2308.3
    [m]
    C
    ROBERT
    2314.5
    [m]
    C
    ROBERT
    2319.3
    [m]
    C
    ROBERT
    2325.5
    [m]
    C
    ROBERT
    2331.1
    [m]
    C
    ROBERT
    2335.2
    [m]
    C
    ROBERT
    2338.5
    [m]
    C
    ROBERT
    2343.9
    [m]
    C
    ROBERT
    2348.9
    [m]
    C
    ROBERT
    2353.7
    [m]
    C
    ROBERT
    2358.2
    [m]
    C
    ROBERT
    2363.6
    [m]
    C
    ROBERT
    2369.8
    [m]
    C
    ROBERT
    2374.6
    [m]
    C
    ROBERT
    2379.5
    [m]
    C
    ROBERT
    2383.6
    [m]
    C
    ROBERT
    2388.8
    [m]
    C
    ROBERT
    2392.8
    [m]
    C
    ROBERT
    2398.8
    [m]
    C
    ROBERT
    2400.8
    [m]
    C
    ROBERT
    2405.6
    [m]
    C
    ROBERT
    2407.8
    [m]
    C
    ROBERT
    2410.7
    [m]
    C
    ROBERT
    2413.9
    [m]
    C
    ROBERT
    2417.5
    [m]
    C
    ROBERT
    2421.5
    [m]
    C
    ROBERT
    2426.4
    [m]
    C
    ROBERT
    2434.8
    [m]
    C
    ROBERT
    2439.4
    [m]
    C
    ROBERT
    2443.7
    [m]
    C
    ROBERT
    2448.9
    [m]
    C
    ROBERT
    2453.2
    [m]
    C
    ROBERT
    2457.9
    [m]
    C
    ROBERT
    2460.1
    [m]
    C
    ROBERT
    2464.0
    [m]
    DC
    ROBERT
    2470.0
    [m]
    DC
    ROBERT
    2476.0
    [m]
    DC
    ROBERT
    2482.0
    [m]
    DC
    ROBERT
    2488.0
    [m]
    DC
    ROBERT
    2494.0
    [m]
    DC
    ROBERT
    2500.0
    [m]
    DC
    ROBERT
    2515.0
    [m]
    DC
    ROBERT
    2516.0
    [m]
    DC
    ROBERT
    2533.0
    [m]
    DC
    ROBERT
    2548.0
    [m]
    DC
    ROBERT
    2563.0
    [m]
    DC
    ROBERT
    2566.0
    [m]
    SWC
    ROBERT
    2581.0
    [m]
    DC
    ROBERT
    2596.0
    [m]
    DC
    ROBERT
    2611.0
    [m]
    DC
    ROBERT
    2629.0
    [m]
    DC
    ROBERT
    2644.0
    [m]
    DC
    ROBERT
    2659.0
    [m]
    DC
    ROBERT
    2677.0
    [m]
    DC
    ROBERT
    2692.0
    [m]
    DC
    ROBERT
    2707.0
    [m]
    DC
    ROBERT
    2725.0
    [m]
    DC
    ROBERT
    2740.0
    [m]
    DC
    ROBERT
    2755.0
    [m]
    DC
    ROBERT
    2773.0
    [m]
    DC
    ROBERT
    2788.0
    [m]
    DC
    ROBERT
    2803.0
    [m]
    DC
    ROBERT
    2821.0
    [m]
    DC
    ROBERT
    2836.0
    [m]
    DC
    ROBERT
    2838.0
    [m]
    SWC
    ROBERT
    2851.0
    [m]
    DC
    ROBERT
    2869.0
    [m]
    DC
    ROBERT
    2884.0
    [m]
    DC
    ROBERT
    2899.0
    [m]
    DC
    ROBERT
    2917.0
    [m]
    DC
    ROBERT
    2932.0
    [m]
    DC
    ROBERT
    2934.0
    [m]
    SWC
    ROBERT
    2947.0
    [m]
    DC
    ROBERT
    2965.0
    [m]
    DC
    ROBERT
    2980.0
    [m]
    DC
    ROBERT
    2980.0
    [m]
    SWC
    ROBERT
    2995.0
    [m]
    DC
    ROBERT
    3013.0
    [m]
    DC
    ROBERT
    3028.0
    [m]
    DC
    ROBERT
    3043.0
    [m]
    DC
    ROBERT
    3100.0
    [m]
    SWC
    ROBERT
    3109.0
    [m]
    DC
    ROBERT
    3124.0
    [m]
    DC
    ROBERT
    3139.0
    [m]
    DC
    ROBERT
    3157.0
    [m]
    DC
    ROBERT
    3172.0
    [m]
    DC
    ROBERT
    3185.0
    [m]
    SWC
    ROBERT
    3187.0
    [m]
    DC
    ROBERT
    3205.0
    [m]
    DC
    ROBERT
    3226.0
    [m]
    DC
    ROBERT
    3240.0
    [m]
    DC
    ROBERT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR HRLA PEX ECS HNGS
    2128
    3236
    FMI MSIP GR
    431
    1343
    FMI MSIP GR
    1635
    3263
    MDT GR
    2268
    3204
    MDT GR
    2334
    3204
    MSCT GR
    2160
    3050
    MSCT GR
    2500
    3050
    MSCT GR
    3050
    3258
    MWD-PDX5 RAB6 ARC6 TELE675
    1355
    2274
    MWD-TELE ARCVRES
    434
    1355
    USIT CBL
    0
    0
    VSP
    1270
    3160
    ZAIT HRLA PEX EXCS GR
    734
    1344

  • 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
    484.0
    42
    488.0
    0.00
    SURF.COND.
    20
    734.5
    26
    744.0
    1.18
    FIT
    INTERM.
    13 3/8
    1338.7
    17 1/2
    1355.0
    1.40
    LOT
    LINER
    9 5/8
    2127.0
    12 1/4
    2128.0
    1.33
    LOT
    OPEN HOLE
    3240.0
    8 1/2
    3240.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    488
    1.03
    12.0
    Spud Mud
    744
    1.12
    14.0
    KCl/Polymer/Glycol
    748
    1.12
    14.0
    KCl/Polymer/Glycol
    1220
    1.12
    19.0
    KCl/Polymer/Glycol
    1355
    1.12
    15.0
    KCl/Polymer/Glycol
    1920
    1.23
    17.0
    Low Sulphate/KCl/Polymer/Glycol
    1920
    1.28
    24.0
    Low Sulphate/KCl/Polymer/Glycol
    1972
    1.12
    29.0
    KCl/Polymer/Glycol
    2128
    1.12
    27.0
    KCl/Polymer/Glycol
    2134
    1.22
    19.0
    KCl/Polymer/Glycol
    2165
    1.22
    18.0
    Low Sulphate/KCl/Polymer/Glycol
    2395
    1.22
    20.0
    Low Sulphate/KCl/Polymer/Glycol
    3240
    1.28
    24.0
    Low Sulphate/KCl/Polymer/Glycol
    8000
    1.12
    19.0
    KCl/Polymer/Glycol