api mechanical seal plans free sample

Please contact AESSEAL Systems Division for further details. Tel: +44 (0)28 9266 9966 Email: systems@aesseal.com For more information, and a video demonstrating the piping plan in operation, select a plan below

API Plan 53Autilizes a reservoir and circulates a pressurized barrier fluid between the inboard and outboard seals. The typical source of pressurization is plant nitrogen. The reservoir should be set at least 20 psi (1.3 bar) above maximum seal chamber pressure. This is to ensure that leakage across the inboard seal face is barrier fluid which then lubricates the seal faces and passes into the process. For this reason, barrier fluid must be chemically compatible with the process fluid and process dilution not a concern. In order to provide positive circulation through the support system and into the seal, a pumping ring is employed. A reservoir level indicator or level transmitter shows both inboard and outboard seal leakage.

Plan 53A is available as a seal pot assembly. The associated field installation kit for use in connecting the assembly to your system is also available. Assembly contents may include:

See page 35 of the Mechanical Seal Support Systems Application Guide for additional details and ordering information. Contact your authorized Swagelok sales and service center for information on optional components.

In one of the three previous parts this series of articles has dealt with the cost to reheat and/or evaporate flush injection from API Plan 32. It has also addressed industry technology that can be deployed to make seal flush piping plans more energy efficient while at the same time improving the reliability of the sealing device in the rotating equipment. Improvements and savings accrue from the application of best practice alternatives to API Piping Plans 32 and 54. The use of a modified API Plan 53A in the form of a Water Management System was described in Part 3; it eliminates the need to reheat and evaporate diluents. Available benchmark data prove the reliability benefits of this approach.

In the last of this series of articles, Part 4 now addresses the pumps used in condensate services. During many surveys the auditor will note pumps that are leaking hot condensate—a condition very often found in the paper industry. We can make good use of an authoritative source, the U.S. Department of Energy’s Steam Tip #8 by quoting from it in this Mechanical Seal Energy Audit:

Using separator pumps as a case in point, these pumps are taking condensate off the condensate receiver tank after the paper machine rolls. It is not customary for the receiver level controls to be manually overridden. Overrides can occur when the machine is brought on-line and steam must be kept in the rolls to prevent these from flooding. As steam enters the separator pump, the mechanical seal face set cannot seal steam. The lapped faces will become distorted and severe leakage will result.

Condensate pumps traditionally use API Plan 02, API Plan 11, API Plan 21, or API Plan 23. These plans use a single mechanical seal with one of these plan options.

The graphic on the next page shows hypothetically where each plan operates on a vapor-temperature curve for condensate. In order to understand how the traditional plans have been used, assume the condensate pump has a suction pressure of about 30 psig and the condensate is 200 degrees Fahrenheit (93 degrees Celsius). The discharge is 80 psig and there is naturally no change to the discharge temperature. For discussion purposes, the seal generates heat; assume the resulting temperature increase is 25 degrees Fahrenheit (-4 degrees Celsius). What is the pressure in the seal chamber? The seal chamber pressure depends on the pump design. Vanes on the back of the impeller or balancing holes near the eye of the impeller are used in design to control the axial thrust on the pump shaft. These pressure balancing techniques mean the pressure in the seal chamber will be closer to suction pressure. Again, it depends on the pump and seal manufacturers usually recommend consultation with the pump manufacturer to verify this pressure.

Seal chamber pressure and temperature: Pressure is just above the vapor point and the pump is pumping a liquid (water/condensate). The temperature and pressure in the seal chamber are such that the seal chamber contents are still in the liquid state.

API Plan 02. Depending on the actual pressure in the seal chamber, the seal faces generate heat and a pressure drop occurs across the seal face from 40 psig to 0 psig. Therefore, the fluid film between the seal faces could be vaporizing (“flashing”) as temperature increases and pressure drops.

API Plan 11 has been selected for this service. This plan increases the seal chamber pressure to 80 psig, assumes no cooling for seal face generated heat. The safety margin comes from higher pressure.

API Plan 21. A heat exchanger has been added to the discharge bypass line and the pressure is raised while the product is cooled. The safety margin comes from higher pressure and cooling of the condensate.

API Plan 23. The seal chamber is isolated and product is circulated through a heat exchanger. The mechanical seal circulates the liquid with a pumping ring (a “flow inducer”). This plan is more energy efficient than Plan 21 because the cooler only removes the heat generated primarily by the seal. There is also a small amount of heat soak from the process that passes an internal isolation restriction bushing in the seal chamber.

Failure: At any point during the life of the rotating equipment, if the pump sees steam because of operational upsets or the condensate receiver level causes the pump to run dry, the mechanical seal fails and the condensate pump leaks. This is the core issue to address.

The solution recommended is to use a dual seal with a secondary fluid consisting of treated clean condensate. The purpose of the secondary fluid is to cool the seal faces during normal operation and to serve as a lubricating fluid when the pump runs dry or steam is forced through the pump. This deals with the core failure issue of dry running or steam being forced through the pump.

By using a dual seal arrangement to mitigate the dry-running conditions caused by operational upsets affecting the condensate receiver, the user should expect years of leak-free service and energy efficiency benefits outlined in the Department of Energy Steam Tip #8.

Tom Grove is an executive vice president at AESSEAL Inc., one of the world’s leading specialists in the design and manufacture of mechanical seals and support systems. He can be reached at tom.grove@aesseal.com. Heinz P. Bloch, P.E., is one of the world’s most recognized experts in machine reliability and is a Life Fellow of the ASME, in addition to having maintained his registration as a Professional Engineer in both New Jersey and Texas for several straight decades. As a consultant, Mr. Bloch is world-renowned and value-adding. He can be contacted at heinzpbloch@gmail.com.

Mechanical seals are a great cause of concern and failures in many operating plants. This is especially true of systems that are pumping or compressing dirty fluids. Some examples include bottoms pumps, sulfur pumps, or equipment that is handling abrasive or challenging process media. Mechanical seals are often redesigned, replaced and repaired simply because of the challenging conditions these seals face during operation. This has continually led to excessive costs in terms of repair or redesign, not to mention production loss and cost associated on a critical unspared asset.

While seals have to be properly selected and designed for the application during the project’s engineering stages, it is equally critical to select the right and most cost-effective seal plan to help support the seal’s operating environment. The seal flush plan is as equally critical and perhaps more so to help establish a reliable operating mechanical seal. API Standard 682 from the American Petroleum Institute provides various seal plan configurations, their advantages and disadvantages and a good description of each of the plans. To gain an in-depth understanding of the various types of applications and plans available for selection, refer to API 682. In addition, a lot of seal vendors publish handy booklets that contain good, brief and quick references and explanations of the different API seal plans.

This particular article looks at API Plan 53B and how paying careful attention to some aspects of this plan can ensure a proper and reliable running seal in many applications. Of course, the mechanical seal should be correctly and most optimally designed for the particular application at hand.

Figure 1 shows a basic overview of what a 53B seal flush plan looks like. It is a pressurized flush plan that gets used with a dual seal (i.e., two seals) configuration. The accumulator contains a bladder that is pre-charged at a certain calculated bladder pre-charge pressure value through the bladder charge connection shown in Figure 1. Next, the barrier fluid, which can be royal purple or another process compatible based media, is injected into the system at a certain calculated hydraulic charge pressure through the make-up barrier fill or a similar port provided on the piping setup. The idea is that when the seal fails (leaks are more than expected since all seals leak to some extent), then the barrier fluid, being at a higher pressure, will push the leakage back into the process rather than letting the process media leak outside into the ambient. This helps prevent environmental release and avoids wastage of costly process media to the atmosphere. It is quite clear based on this that such plans are best suited for applications that are toxic and hazardous and where negligible leakage is allowed into the atmosphere due to such concerns. Consider reading ample literature available from various sources to gain a deeper understanding of this particular plan.

One of the key advantages of this particular plan is the cost associated with implementing it in a given plant compared to other similar options (i.e., Plan 54 or others). However, it is imperative to realize that the reliability of a 53B plan and the mechanical seal it supports is highly dependent on the plant operator who maintains this and checks on the system on a regular basis. While a number of seal failures can be attributed to incorrect designs or other issues, equally, if not more, causes can be attributed to how a plan 53B is operated and maintained on a running asset.

Here are a few important points that should be considered while working with any plan 53B in a maintenance and operating organization.It is important to vent a 53B through the appropriate vent points provided to ensure there is no vapor entrapment prior to seal start-up. Attention should be paid to horizontal versus vertical heat exchangers provided on the system. Based on experience, it is easier to vent out vertical heat exchanger configurations versus horizontal systems. However, horizontal systems are provided or should be provided with block valves to help ensure proper venting.

In colder climates where a plan 53B is installed outside, the system should be properly heat traced and winterized. This includes the seal flush piping, the accumulator and the exchangers. The accumulator contains a nitrogen bladder with a pre-charge pressure as previously indicated. Fluctuations in the ambient temperature can have a dramatic effect on system pressure and lead to seal failures and loss of seal system reliability.

Operations should confirm and check with engineering that the right calculated values are provided for the pre-charge pressure for the bladder and also the hydraulic system charge pressures. These are quite critical to ensuring system and seal reliability. Any discrepancies in these calculated values can risk reverse pressurization (i.e., seal reversal) and subsequent failure of the sealing system. It is important to note that some plants consider playing around with the pre-charge and hydraulic charge values to buy more time between system failure and low-level alarm of the barrier fluid so the operator has sufficient time to fill and make up the loss of barrier in the system. However, experience has shown the best way to address this issue is to procure accumulators of higher volumes to provide for this as opposed to modifying pressures to buy more volume in the system. The latter seems to have much smaller effects compared to sizing the accumulator correctly in the first place. Also, if consideration is being given to changing pre-charge and hydraulic pressures, this should be in discussions with the original equipment manufacturer (OEM) seal vendor since excess pressures on a given seal can compromise and affect seal leakage rates, thus reducing the time and volume present in the system.

It is equally important that the operator only charge (i.e., make-up fill with hand-pump) the system when the low-level alarm pressure is initiated. Charging the system at every minor occasion when the barrier pressure and level drops is not warranted. This, on the contrary, will lead to a poor seal system and seal reliability as a result of multiple pressure charging in short intervals.

Operations should keep a log of charging frequencies, depending on the low-level alarm. This, along with visual inspections, can provide a good clue to seal failures and acceptable leakage rates. The question most often asked by an operator is: What is considered an acceptable leakage? While engineering, along with the seal OEM, can provide acceptable leakage rates, to get a very good measure of seal reliability, the operator can keep an eye out for the frequency of fill and also, if correctly done, the volume filled during the initial fill cycle.

Since the pump throat bushing controls the stuffing box environment, it would be beneficial to incorporate the throat bushing on the seal cartridge itself to help with maintenance, as opposed to locating it within the pump. This holds true not just for the 53B seal plan, but for others as well.

Having a temperature gauge located on both the inlet and outlet of the seal helps in establishing a temperature gradient between the seal’s in and out flow. A difference of around 20 to 30 degrees C is acceptable; any more delta T changes can point to possible issues with the seal, cooling water, or other variables. This can help the operator make on-site decisions to engage or escalate the issue to engineering in the event of a potential problem.

While there are many individual experiences connected to running a 53B seal flush plan, these important points most certainly can help the operator make an informed decision to help seal reliability and mean time between failures (MTBF) in a running plant. Engineering should perform a detailed root cause analysis on complex seal issues and provide the appropriate solutions sought to address repeated failures. This will help the plant’s bottom line: Cost and Revenue.

Single Seals plans 01, 02, 03, 11, 13, 14, 21, 23, 31, 32, 41 Dual Seals plans 52, 53A, 53B, 53C, 54, 55 Quench Seals plans 62, 65A, 65B, 66A, 66B Gas Seals plans 72, 74, 75, 76 Mechanical Seal Piping Plans

Flowserve recognizes that one of the most effective ways to achieve long,uninterrupted mechanical seal life is to create a healthy environment aroundthe seal faces. Piping plans help keep mechanical seals running cool andclean, promote safe handling of dangerous fluids, and extend the operationalavailability of rotating equipment. This reference book provides a concisesummary of the most essential piping plans used successfully in today’sprocess plants.

Each plan shows all the standard and optional auxiliary components referencedin API Standard 682 and recommended by Flowserve. Consult your localFlowserve sales engineer to identify the right solution that satisfies yourapplication requirements.Page Layout

Seal End View Piping Plan Layout What, Why, and Where• Viewed from drive end • Illustrated schematic • Describes piping plans, • Shows preferred gland of auxiliary components their purpose, and connection orientation typical applications

What pressure source, Pressurized barrier fluid circulation through reservoir. normally open Fluid is circulated by a pumping ring in the dual seal assembly. outlet pressure Why seal transmitter Isolate process fluid. Zero process emissions. Plan 53A

Plan 53A liquid fill, reservoir Where inlet normally closed Used with dual pressurized seals (”double”). High vapor pressure fluids, light hydrocarbons. level indicator Hazardous/toxic fluids. level transmitter Heat transfer fluids. Dirty/abrasive or polymerizing fluids. cooling coils Mixers/agitators and vacuum service. cooling out cooling in Preventative Maintenance - Reference Appendix B Piping loop must self-vent to reservoir locate at highest elevation. drain, Pressurize reservoir at all times, maximum gas charge 10 - 14 bar (150 - 200 psi). normally Barrier fluid must be compatible with process. closed Reservoir level gage indicates both inboard and outboard seal leakage.

Pump Cross-section Mechanical Seal Preventative Maintenance• Simplified centrifugal • Shows typical seal • Provides general tips to pump shown for all plans arrangements improve reliability and for troubleshooting seal end viewPlan 01

WhatInternal seal chamber flush from pump discharge.Operates similar to Plan 11.WhySeal chamber heat removal.Seal chamber venting on horizontal pumps.

Plan 01Reduce risk of freezing/polymerizing fluid in exposed Plan 11 piping.WhereCustom seal chamber, most likely an ANSI/ASME pump.Clean, moderate temperature fluids.Used with single seals, rarely with dual seals.Preventative MaintenanceFlush typically can not be directed over seal faces and seal heat removal is limited.Calculate flush flow rate based on head loss through internal porting. seal end viewPlan 02 flowserve.com

Plan 02Cooling jacket seal chambers in high temperature services.Clean fluids.Top-entry mixers/agitators with dry seals.Heating jacket seal chambers in fluids that solidify at low temperatures.Preventative MaintenanceProcess must have adequate boiling point margin to avoid vaporization.Cooling fluid in seal chamber jacket may be needed at all times in hot services.Horizontal equipment must be self-venting.Often used in combination with steam quench, Plan 62. seal end viewPlan 03

Plan 03WhereLarge bore/open throat seal chambers.Dirty or contaminated fluids.Preventative MaintenanceProper seal chamber design helps prevent solids from collecting at the seal faces. inlet

Plan 11Seal chamber venting on horizontal pumps.Increase seal chamber pressure and fluid vapor margin.WhereGeneral applications with clean fluids.Clean, non-polymerizing fluids.Preventative MaintenanceUse an orifice with a minimum 3 mm (1/8 inch) diameter.Calculate flow rates to size orifice for adequate seal chamber flow.Increase boiling point margin with proper orifice and throat bushing sizing.Flush should be directed over seal faces with piping at 12 O’clock position.Typical failure mode is a clogged orifice - check temperatures at pipe ends. outlet

WhatRecirculation from seal chamber to pump suction through orifice.Standard flush plan on vertical pumps.WhyContinuous seal chamber venting on vertical pumps.Seal chamber heat removal.

Plan 13WhereVertical pumps.Seal chamber pressure is greater than suction pressure.Moderate temperature fluids with moderate solids.Non-polymerizing fluids.Preventative MaintenanceVent piping loop prior to starting vertical pumps.Use an orifice with a minimum 3 mm (1/8 inch) diameter.Calculate flow rates to size orifice for adequate seal chamber flow.Reduce seal chamber pressure with proper orifice and throat bushing sizing.Typical failure mode is a clogged orifice - check temperatures at pipe ends. outlet

WhatSeal flush from pump discharge and recirculation to pump suction with orifices.Combination of Plan 11 and Plan 13.WhyContinuous seal chamber venting on vertical pumps.Seal chamber heat removal.

Plan 14Increase seal chamber pressure and fluid vapor margin.WhereVertical pumps.Clean, non-polymerizing fluids at moderate temperatures.Preventative MaintenanceUse an orifice with a minimum 3 mm (1/8 inch) diameter.Calculate flow rates to size orifice for adequate seal chamber flow.Increase boiling point margin with proper orifice and throat bushing sizing.Flush should be directed over seal faces.Vent piping loop prior to starting vertical pumps.Typical failure mode is a clogged orifice - check temperatures at pipe ends. vents, normally closed inlet

WhatSeal flush from pump discharge through orifice and cooler.Cooler added to Plan 11 flush increases heat removal.WhySeal cooling.Reduce fluid temperature to increase fluid vapor margin.

Plan 21Reduce coking.WhereHigh temperature service, typically less than 177°C (350°F).Hot water over 80°C (180°F).Clean, non-polymerizing fluids.Preventative MaintenanceSeal cooler and piping must have air vents at highest elevation - vent before starting.When using 682 Seal Cooler, pipe with series flow to maximize heat transfer.Use an orifice with a minimum 3 mm (1/8 inch) diameter.Calculate flow rates to size orifice for adequate seal chamber flow.Increase boiling point margin with proper orifice and throat bushing sizing.Regularly monitor cooler inlet and outlet temperatures for signs of clogging or fouling. vent, normally closed

WhatSeal flush from internal pumping device through cooler.Standard flush plan in hot water services.WhyEfficient seal cooling with low cooler duty.Increase fluid vapor margin.

Plan 23Improve water lubricity.WhereHigh temperature service, hot hydrocarbons.Boiler feed water and hot water over 80°C (180°F).Clean, non-polymerizing fluids.Preventative Maintenance - Reference Appendix ASeal cooler and piping must have air vents at highest elevation - vent before starting.When using 682 Seal Cooler, pipe with parallel flow to minimize head loss.Seal chamber requires close clearance throat bushing to isolate process fluid.Tangential seal gland taps should enter at bottom and exit at top.Regularly monitor cooler inlet and outlet temperatures for signs of clogging or fouling.Process fluids with iron should flow through magnetic separator before cooler. inlet

WhatSeal flush from pump discharge through cyclone separator.Centrifuged solids are returned to pump suction.WhySeal chamber heat removal.Solids removal from flush and seal chamber.

Plan 31WhereDirty or contaminated fluids, water with sand or pipe slag.Non-polymerizing fluids.Preventative MaintenanceCyclone separator works best on solids with a specific gravity twice the process fluid.Seal chamber pressure must be nearly equal to suction pressure for proper flows.Piping should not include an orifice and is not expected to vent the seal chamber.Typical failure mode is clogged separator or pipes - check temperatures at pipe ends. inlet

WhatSeal flush from an external clean source.WhySeal chamber heat removal.Process and solids removal from seal chamber.Increase seal chamber pressure and fluid vapor margin.

WhatSeal flush from pump discharge through cyclone separator and cooler.Combination of Plan 21 and Plan 31.WhySeal cooling.Solids removal from flush and seal chamber.

Plan 41WhereHigh temperature service, typically less than 177°C (350°F).Dirty or contaminated fluids, water with sand or pipe slag.Non-polymerizing fluids.Preventative MaintenanceSeal cooler and piping must have air vents at highest elevation - vent before starting.When using 682 Seal Cooler, pipe with series flow to maximize heat transfer.Cyclone separator works best on solids with a specific gravity twice the process fluid.Seal chamber pressure must be nearly equal to suction pressure for proper flows.Typical failure mode is clogged separator or pipes - check temperatures at pipe ends. vent, normally open pressure outlet transmitter orifice seal end view inlet reservoirPlan 52

WhatUnpressurized buffer fluid circulation through reservoir.Fluid is circulated by a pumping ring in the dual seal assembly.WhyOutboard seal acts as a safety backup to the primary seal.Zero to very low process emissions.

Plan 52No process contamination is allowed.WhereUsed with dual unpressurized seals.High vapor pressure fluids, light hydrocarbons.Hazardous/toxic fluids.Heat transfer fluids.Preventative Maintenance - Reference Appendix BPiping loop must self-vent to vapor recovery/flare system near atmospheric pressure.Process vapor pressure is generally greater than reservoir pressure.Buffer fluid must be compatible with process leakage.Primary seal leakage is indicated by increased vent pressure.Reservoir level indicator shows outboard seal leakage. pressure source, normally open

outlet orifice pressure seal transmitter end view reservoirPlan 53A

WhatPressurized barrier fluid circulation through reservoir.Fluid is circulated by a pumping ring in the dual seal assembly.WhyIsolate process fluid.Zero process emissions.

Plan 53AWhereUsed with dual pressurized seals.High vapor pressure fluids, light hydrocarbons.Hazardous/toxic fluids.Heat transfer fluids.Dirty/abrasive or polymerizing fluids.Mixers/agitators and vacuum service.Preventative Maintenance - Reference Appendix BPiping loop must self-vent to reservoir located at highest elevation.Pressurize reservoir at all times, maximum gas charge 10 - 14 bar (150 - 200 psi).Barrier fluid must be compatible with process.Reservoir level indicator shows both inboard and outboard seal leakage. vent, normally closed pressure outlet transmitter seal pressure source, end view finned pipe normally closedPlan 53B

WhatPressurized barrier fluid circulation with bladder accumulator.Fluid is circulated by a pumping ring in the dual seal assembly.WhyIsolate process fluid.Zero process emissions.

Plan 53BHigher pressure than Plan 53A.WhereUsed with dual pressurized seals.High vapor pressure fluids, light hydrocarbons.Hazardous/toxic fluids.Heat transfer fluids.Dirty/abrasive or polymerizing fluids.Preventative Maintenance - Reference Appendix BPiping loop must be fully vented before starting.Accumulator must be pressurized at all times, usually by gas charge.Barrier fluid must be compatible with process.Regularly monitor barrier pressure - manually add barrier fluid when pressure decays. level indicator level transmitter

outlet vent, normally closed differential pressure seal transmitter liquid fill, end view normallyPlan 53C

WhatPressurized barrier fluid circulation with piston accumulator.Fluid is circulated by a pumping ring in the dual seal assembly.WhyIsolate process fluid.Zero process emissions.

Plan 53CHigher pressure than Plan 53A.Dynamic tracking of system pressure.WhereUsed with dual pressurized seals.High vapor pressure fluids, light hydrocarbons.Hazardous/toxic fluids.Heat transfer fluids.Preventative Maintenance - Reference Appendix BPiping loop must be fully vented before starting.Reference line must tolerate process contamination without plugging.Barrier fluid must be compatible with process.Reservoir level indicator indicates both inboard and outboard seal leakage. outlet

Plan 54WhereUsed with pressurized dual seals.High vapor pressure fluids, light hydrocarbons.Hazardous/toxic fluids.Heat transfer fluids.Dirty/abrasive or polymerizing fluids.Mixers/agitators.Preventative MaintenancePiping loop must be fully vented before starting.Circulating system must be pressurized and energized at all times.Barrier fluid must be compatible with process.Circulating system level indicator shows both inboard and outboard seal leakage. outlet seal end viewPlan 55

WhatUnpressurized buffer fluid circulation by external system.WhyOutboard seal acts as a safety backup to the primary seal.Zero to very low process emissions.No process contamination is allowed.

Plan 55Additional heat removal from the inner seal.Seal cannot induce circulation.WhereUsed with unpressurized dual seals.Hazardous/toxic fluids.Fluids that may solidify in contact with atmosphere.Preventative MaintenancePiping loop must be fully vented before starting .Buffer fluid must be compatible with process leakage.Accumulated process leakage should be routed to a recovery system. inlet seal end viewPlan 62

WhatExternal quench on atmospheric side of seal.Quench fluids typically steam, nitrogen, or water.WhyPrevent solids buildup on atmospheric side of seal.Prevent icing.

Plan 62WhereUsed with single seals.Oxidizing fluids or fluids that coke, hot hydrocarbons.Crystallizing fluids or fluids that salt out.Caustic.Cold fluids less than 0°C (32°F).Preventative MaintenanceQuench inlet should be on top of gland with outlet/drain on bottom.Quench pressure should be limited to 0.2 bar (3 psi) or less.Use throttle bushing on atmospheric side of seal to direct quench flow to seal drain.Monitor regularly, checking for closed valves, blocked lines, and steam trap condition. seal level end view block transmitter valve,Plan 65A

Plan 65AMay be used alone or with Plan 62 quench.Used with close clearance throttle bushing.Useful with single seals in remote locations and critical services.

Preventative MaintenanceDrain must be on bottom of gland with downward-sloped piping.Continuously drain to liquid recovery system.Orifice downstream of level switch transmitter 5 mm (1/4 inch) must be oriented vertically.Bypass line from overflow chamber must re-enter below orifice.Piping may require heat tracing when used with solidifying fluids.Monitor regularly, checking for closed valves, blocked lines, and working level transmitter. seal level end view block transmitter overflowPlan 65B

WhatExternal drain with leakage detection on atmospheric side of seal.WhyLeakage collection to detect for process leakage.Safety indicator to detect seal failure.Continuous monitoring of leakage rates to atmosphere.

Plan 65BWhereUse with close clearance throttle bushing.Use with non-flashing, condensing fluids.Useful with seals in remote locations and critical services.

Preventative MaintenanceDrain must be on bottom of gland with downward sloped piping.Empty collection vessel when level transmitter indicates the vessel is full.Bypass line from collection vessel must re-enter below drain valve.Piping may require heat tracing when used with solidifying fluids.Monitor regularly, checking for closed valves, blocked lines, and working level transmitter. pressure PIT seal indicator end view transmitterPlan 66A

WhatLeakage detection on atmospheric side of seal utilizing two throttle bushings in series.WhySafety indicator for primary seal to detect failure.Minimize leakage from seal gland in case of seal failure.

Plan 66AWhereMay be used alone or with Plan 65A or Plan 65B.Used with flashing or non-flashing fluids.Useful with single seals in remote locations and critical services.Used with close clearance throttle bushings.

Preventative MaintenanceDrain must be on bottom of gland with downward sloped piping.Continuously drain to a liquid recovery system.Monitor for high pressure. pressure PIT seal indicator end view transmitterPlan 66B

Plan 66BMay be used alone or with Plan 65A or Plan 65B.Used with close clearance throttle bushing.Used with flashing or non-flashing fluids.Useful when adding atmospheric side leakage detection to an existing seal.Useful with single seals in remote locations and critical services.

Preventative MaintenanceDrain must be on bottom of gland with downward sloped piping.Continuously drain to a liquid recovery system.Monitor for high pressure.Check orifice regularly for build up and plugging. vent flow coalescing inlet seal filter check transmitter end view regulator valvePlan 72

WhatUnpressurized buffer gas control system.Containment seal support typically with nitrogen buffer gas.WhyZero to very low process emissions.Safety backup to primary seal.

Plan 72WhereUsed with dual unpressurized containment seals.High vapor pressure fluids, light hydrocarbons.Hazardous/toxic fluids.Clean, non-polymerizing, non-oxidizing fluids.Used in combination with Plan 75 and/or Plan 76.Preventative MaintenanceClean, reliable, low pressure gas must be supplied to seal at all times.Bottled gas supply is not recommended except as part of emergency backup system.Primary seal leakage is indicated by pressure in the vent line.Vent or drain are usually connected to low pressure vapor recovery/flare system. inlet flow coalescing seal transmitter filter end view check regulator valvePlan 74

Plan 74WhereUsed with dual pressurized gas seals.High vapor pressure fluids, light hydrocarbons.Hazardous/toxic fluids.Services that do not tolerate liquid barrier seals.Clean, non-polymerizing fluids.Moderate temperature fluids.Preventative MaintenanceClean, reliable, pressurized gas must be supplied to seal at all times.Barrier pressure is typically at least 1.75 bar (25 psig) above seal chamber pressure.Flow indicator shows both inboard and outboard seal leakage.Bottled gas supply is not recommended except as part of emergency backup system. pressure test transmitter connection isolation level valve vent, seal end view indicator normally open orifice

Drain - see end view level transmitter reservoir located below seal drain port

WhatDrain from containment seal cavity to liquid collector and vapor recovery.WhyLeakage collection for zero to very low process emissions.Safety indicator for primary seal.

Plan 75WhereMay be used alone or with Plan 72 on containment seals.Fluids that condense at ambient temperature.High vapor pressure fluids, light hydrocarbons.Hazardous/toxic fluids.Clean, non-polymerizing, non-oxidizing fluids.Preventative MaintenanceCollection reservoir must be located below seal drain and downward-sloped piping.Continuously vent collection reservoir to low pressure vapor recovery/flare system.Drain collection reservoir to liquid recovery system as needed.Primary seal leakage is indicated by increased vent pressure.Monitor regularly for liquid level, valve settings, and low vent pressure. vent vent, normally open seal end viewPlan 76

WhatVent from containment seal cavity to vapor recovery.WhyLeakage collection for zero to very low process emissions.Safety indicator for primary seal.

Plan 76WhereMay be used alone or with Plan 72 on containment seals.Fluids that do not condense at ambient temperature.High vapor pressure fluids, light hydrocarbons.Hazardous/toxic fluids.Clean, non-polymerizing, non-oxidizing fluids.Preventative MaintenanceContinuously vent to low pressure vapor recovery/flare system.Vent piping should include a condensate drain.Primary seal leakage is indicated by increased vent pressure.Monitor regularly for valve settings, blocked lines, and low vent pressure. Single Seals - Plan 23 shown What Minimize restrictions in piping systems high point vent Why Optimum flow rate for best piping plan performance WhereAppendix A

low point Horizontal drain Equipment 0.9 m (3 ft.) maxGood Piping Practices Dual Seals - Plan 53A shown Minimize line losses Use large diameter tubing Only upward sloping lines (slope shall be 40 mm/m [0.5 in/ft]) Use long radius bends

low point Horizontal drain Equipment 1.2 m (4 ft.) max Airfin Coolers TM Seal Cooler 682 Seal Cooler ReservoirsAccessories

Forced air or natural Compact design Seal cooler for General duty and convection seal coolers dual coil seal cooler complete API 682 API 682 compliant specifications reservoirs

Plans 21, 23 & 41 Plans 21, 23 & 41 Plans 21, 23 & 41 Plans 53, 53A & 53B flowserve.com

AccessoriesAccumulator Control Panel Standalone dual seal Mobile cart to manually Complete control support system fill liquid reservoirs system for dual gas seals

Plan 53C Plan 54 Plans 52 & 53 Plans 72 & 74 Seal Gard I & II Orifice Magnetic Separator Cyclone SeparatorAccessories

Combination flush Plug and plate Iron particle separator Solid particle separator flow regulator and style flush line for seal flush used in dirty flush stream meter orifices

Plan 32 Plans 11, 13, 14, & 21 Plan 23 Plans 31 & 41 flowserve.com

Plan 62 Plan 62 modified Plans 52, 53 & 54NotesNotesNotesNotesFTA160eng REV 1-15 Printed in USA USA and Canada To find your local Flowserve representative Kalamazoo, Michigan USA and find out more about Flowserve Corporation Telephone: 1 269 381 2650 visit www.flowserve.com Telefax: 1 269 382 8726

Sealing technology by EagleBurgmann is used worldwide in oil and gas industries, refineries, the petrochemical, chemical, and pharmaceutical industries, food processing, energy, water, mining, paper, aerospace, and other industries. Close to 5,800 employees provide their ideas, solutions, and commitment so that customers can rely on our sealing technology.

FLUSH PLANS FOR MECHANICAL SEALS – INTRODUCTIONPumps and seals are being installed into increasingly difficult services. Forsuccessful operation of mechanical seals, the environment and care of the sealsrequire more sophisticated seal chambers and flushing arrangements. This sectionof the Dean Pump Price Book is designed to allow the application and pricing offlush plans suitable to meet the requirements for the mechanical seal.The American Petroleum Institute (API) has defined certain seal flusharrangements known by their plan numbers. Later, the flush plans developed forthe ANSI standard followed suit and placed the digits "73" in front of the API plannumber to achieve some standardization within the process industry. Thus, APIplan 11 becomes and ANSI Plan 7311.Dean Pump has worked with many engineering houses and customers over theyears and has developed a great deal of experience with sealing systems. WhileDean will quote any flush system requirement as requested by a particularcustomer, it has been found that the API/ANSI systems generally meet or exceedmost customer requirements. In addition, Dean Pump developed the Seal GuardEnvironment systems that provide the ultimate mechanical seal flush plan. Forsystems that do not require ANSI/API flush plans, Dean Pump has also includedthe P1200 loop, which is a basic low cost flush plan to satisfy the economyminded customer.The experience of Dean Pump is contained in these price pages. Many of theflush plans are divided into "Toxic/Flammable" and "Non-Toxic/Non-Flammable“services. The information on these plans along with the details described in the"Special Notes" section can be used as a guide in quoting and discussing optionswith customers. The "fine print" in the Special Notes section provides a multitude ofdetails about each flush system. For example, a customer requesting all socketwelded connections can not have every connection welded. Some accommodationmust be made for disconnecting the system. Being aware of the requirements ofthe customer and the manufacturing limitations of the product is extremely helpful.API flush plans are based on the 7 th Edition of API610. Newer versions of the APIspecifications has limited the cooling and flushing options available.Finally, if there are any doubts, questions, or comments, please feel free to call theFactory and the seal vendor.Effective: FEBRUARY 2011 • Replaces: NEWPage 1

SEAL GUARD SYSTEMS – PRODUCT DESCRIPTIONSeal Guard systems are designed to provide a clean liquid for seal flushing thatprovides protection for the mechanical seal in the pump seal chamber. Dean Pumpoffers two basic systems to guard against mechanical seal failure. These systemswill also help to prolong the life of the seal. Both systems are filtration systemsinstalled into the seal flush lines to remove stray abrasive particles which causeseal face wear.Seal Guard A - is designed for filtration only. Particles larger than 10 microns arefiltered from the system using clean-able or replaceable 316SS woven filterelements.Seal Guard B - is designed for high temperature applications and includes a heatexchanger installed ahead of the replaceable filter elements for both filtration andtemperature control.Seal Guard systems are most often used with MIN-FLO Bushings in the pump sealchamber. These bushings restrict the flow from the seal chamber back into thepump during operation and increases the effectiveness of the Seal Guard system.Seal Guards can be used on any pump product line. Their sale is not limited toDean Pump products. Seal Guards are hydrostatically tested but do not meet anyindustrial standard and are not for application to API610 series pumps. Seal Guardapplications must be limited to iron or steel pumps and are not suitable forapplications that require alloy materials.The Seal Guard system is fully described in Bulletin A2000.Effective: FEBRUARY 2011 • Replaces: NEWPage 2

SEAL GUARD SYSTEMS – (See Note #1)Model A Series – Filtration Only (See Note #2)Mounted on Pump BaseplateModel Description List PriceA500T A Series Seal Guard - Filtration - Threaded Connections $4,483A500F A Series Seal Guard - Filtration - Flanged Connections C/FA700T A Series Seal Guard - Filtration - Threaded Connections C/FBD500TB500TModel B Series – Filtration and Cooling (See Notes #2 & #3)Mounted on Separate BaseplateModel Description List PriceBD200T B Series Seal Guard - Cooling & Filtration - $5,248Threaded Connections & Duplex FilterB400T B Series Seal Guard - Cooling & Filtration - $5,248Threaded Connections & Simplex FilterB400F B Series Seal Guard - Cooling & Filtration - C/FFlanged Connections & Simplex FilterB500T B Series Seal Guard - Cooling & Filtration - $6,226Threaded Connections & Simplex FilterBD500T B Series Seal Guard - Cooling & Filtration - $8,240Threaded Connections & Duplex FilterNotes:1. Seal Guard systems are not rated for API application and are suitable for pumps in steel or iron construction only. Do notuse for 316SS or other alloy applications.2. The product description letters and numbers are as follows:First Letter - Seal Guard Series A - Filtration Only; B - Cooling and Filtration. (The letter D following in the second positionindicates a Duplex arrangement.); 3 Digit Number indicates the pressure rating of the Seal Guard system in psi.;Final Letter: T - Threaded Construction; F - Flanged Construction3. The heat exchangers provided for Seal Guard B are furnished with a steel shell and 316SS tube as standard.Effective: FEBRUARY 2011 • Replaces: NEWPage 3

DEAN P1200 ECONOMY FLUSH PLAN FOR PROCESS PUMPSPlan Description:Dean Plan P1200 systems include piping (or tubing) from the pumpdischarge gauge connection to the seal flush connection on the pumpbackhead or seal gland. These plans include all piping and/or tubing.List Prices (Notes 1 & 3)Carbon SteelCarbon SteelFitted 316SS Pipe 316SS PipeSystem Description (Note #2) Tubing Threaded ThreadedRecirculation of Pumpage from Pump Case toP1200 Seal Without Orifice (Similar to API Plan 11 orANSI Plan 7311) VALVE NOT INCLUDED$216 $329 $456 $692Valve Valve for Recirculation Line $205 $762 $205 $762General Notes:1. For all other flush plans, refer to API/ANSI Flush Plans shown elsewhere for your particular requirements.2. The plan with carbon steel tubing uses carbon steel fittings with 316SS tubing.3. Connections on the casing require a price adder for discharge gauge connections and may require an additional price adderif the seal chamber requires back drilling.Effective: FEBRUARY 2011 • Replaces: NEWPage 4

SOME COMMENTS AND RECOMMENDATIONSABOUT API/ANSI FLUSH PLANSThere are two organizations in the United States which have taken the lead in developingacceptable standards for the pump industry. The American Petroleum Institute (API) and AmericanNational Standards Institute (ANSI) have outlined a number of flush plans which encompass themajority of applications. API610 is mainly recognized as a standard which defines the qualityrequirements of a pump and/or system. ANSI-B73.1 is viewed as more of a dimensional and featurestandard. ANSI plans are designated the same as API plans except for the addition of a "73" prefixon the plan number. For example, an API Plan 21 is designated as an ANSI Plan 7321.API and ANSI flush plans are similar and upon initial examination look nearly identical. However,there are definite differences in their construction. Often, API flush plans, which are historicallylocated in refinery environments, are piped and welded. ANSI plans, on the other hand, can utilizetubing. Another notable difference is in the API plan 52/53 and the ANSI plan 7352/7353. APIspecifies Schedule 40 minimum thickness vessels. ANSI allows for the use Schedule 10 vessels. Allof the plans are offered in steel and stainless steel construction. They also have differingconstructions for Toxic/Flammable or Nontoxic/Nonflammable applications.Meeting the customer"s specific requirements is the most important consideration in applying theseplans. Many customers modify their individual requirements from the API and ANSI specifications.Sometimes these are more stringent rules than the API and ANSI specifications. These must takeprecedence over the standard flush plans. There are some limitations as to what the flush plans canor cannot accomplish. The Special Application Notes section on each sheet identifies the particularlimitations of each of the flush plans. For example, a flush loop which requires socket welded jointscan not have all the connections welded some provision must be made to allow for disassembly andrepair.When applying a particular flush plan to a specific job, great care should be taken to insure theneeds of the customer are met. Do not select a plan based solely upon pricing. In general, most APIplans require piping and many require welded joints. Note that these are the most expensive plans.A few API services permit the less expensive plans but, the customer"s requirements takeprecedence. ANSI, on the other hand, is much less specific but still requires close analysis of thecustomer"s specifications and requirements for guidance. However, API plans are often seen onANSI type pumps. Oil companies are very likely to request the more expensive plan and will pay forit. Do not make errors in this area. If there is any doubt, or questions regarding plan selection, sendthe specification/ requirements to the factory for review. The factory will provide any comments,limitations, and pricing that is required.Effective: FEBRUARY 2011 • Replaces: NEWPage 5

API PLAN 11 - FLUSH PLAN FOR PROCESS PUMPS (Note #1)ANSI PLAN 7311 – FLUSH PLAN FOR CHEMICAL PUMPSPlan Description:API Plan 11 (ANSI Plan 7311) systems include piping (ortubing) from the pump discharge gauge connection throughan orifice to the seal flush connection on the pumpbackhead or seal gland. These plans include all piping,tubing, and the orifice. Refer to Note #B for additionalpump drilling.SYSTEMS FOR NON-TOXIC AND NON-FLAMMABLE APPLICATIONSSystem DescriptionDescription Special Notes Max. Press. Max. Temp. List PriceAASteel Threaded Pipe and Fittings with 316SS Tubingand Tube Connectors2, 3, 7, 19 500psi 800º F. $ 413AB Steel Threaded Pipe and Fittings 2, 5, 8 500psi 800º F. $ 627AC316SS Threaded Pipe and Fittings with 316SS Tubing andTube Connectors2, 3, 7, 19 500psi 850º F. $ 483AD All 316SS Threaded Pipe and Fittings 2, 5, 8, 500psi 850º F. $1,496SYSTEMS FOR TOXIC AND/OR FLAMMABLE APPLICATIONSSystem Description Special Notes Max. Press. Max. Temp. List PriceAESocket Welded Steel Pipe and Fittings with 316SS Tubingand Tube Connectors1, 4, 7, 19 500psi 300º F. $ 890AF Socket Welded Steel Pipe and Fittings 1, 6, 8 500psi 800º F. $1,124AGSocket Welded 316SS Pipe and Fittings with 316SS Tubingand Tube Connectors2, 3, 7, 19 500psi 300º F. $ 982AH All Socket Welded 316SS Pipe and Pipe Fittings 2, 5, 8 500psi 850º F. $1,577General Notes:A. ALL PUMPS - The plans are similar to but may not comply with API610, 5 th Ed. Review customer requirements as plansmay not comply with later editions or specific customer requirements.B. ALL PUMPS - Flush plans require one or more pump taps. Add the price of the discharge and suction gauge connections ifrequired. For clamped seat applications, consult factory.Special Application Notes:1. Pipe connections at the pump are threaded and are not backwelded.2. All pipe joints are threaded.3. Pipe nipples, threaded pipe fittings, stainless steel tubing, and compression type stainless steel tube connectors.4. Pipe, pipe nipples, socket weld pipe fittings, backwelded threaded pipe fittings, stainless steel tubing and compression typestainless steel tube connectors with threaded pipe connections that are not backwelded.5. Pipe nipples, threaded pipe fittings, and threaded pipe unions.6. Pipe, pipe nipples, socket weld pipe fittings, backwelded threaded pipe fittings, socket weld pipe unions.Effective: FEBRUARY 2011 • Replaces: NEWPage 7

API PLAN 12 - FLUSH PLAN FOR PROCESS PUMPS (General Note #A)ANSI PLAN 7312 – FLUSH PLAN FOR CHEMICAL PUMPSPlan Description:API Plan 12 (ANSI Plan 7312) systems include piping (ortubing) from the pump discharge gauge connection througha Y-strainer, and orifice to the seal flush connection on thepump backhead or seal gland. These plans include allpiping, tubing, and the orifice. Refer to Note #B foradditional pump drilling.SYSTEMS FOR NON-TOXIC AND NON-FLAMMABLE APPLICATIONSSystem DescriptionDescription Special Notes Max. Press. Max. Temp. List PriceBASteel Threaded Pipe and Fittings with 316SS Tubing andTube Connectors and Y-Strainer2, 3, 7, 9, 19 500psi 800º F. $ 638BB Steel Threaded Pipe and Fittings 2, 5, 8, 9 500psi 800º F. $1,123BC316SS Threaded Pipe and Fittings with 316SS Tubing andTube Connectors and Y-Strainer2, 3, 7, 9, 19 500psi 850º F. $ 939BD All 316SS Threaded Pipe and Fittings and Y-Strainer 2, 5, 8, 9 500psi 850º F. $1,736SYSTEMS FOR TOXIC AND/OR FLAMMABLE APPLICATIONSSystem Description Special Notes Max. Press. Max. Temp. List PriceBESocket Welded Steel Pipe and Fittings with 316SS Tubingand Tube Connectors and Y-Strainer1, 4, 7, 10, 19 500psi 300º F. $1,298BF Socket Welded Steel Pipe and Fittings and Y-Strainer 1, 6, 8, 10 500psi 800º F. $1,602BGSocket Welded 316SS Pipe and Fittings with 316SS Tubingand Tube Connectors and Y-Strainer2, 3, 7, 9, 19 500psi 300º F. $1,270BHAll Socket Welded 316SS Pipe and Pipe Fittings andY-Strainer2, 5, 8, 9 500psi 850º F. $1,817General Notes:A. ALL PUMPS - The plans are similar to but may not comply with API610, 5 th Ed. Review customer requirements as plansmay not comply with later editions or specific customer requirements.B. ALL PUMPS - Flush plans require one or more pump taps. Add the price of the discharge and suction gauge connections ifrequired. For clamped seat applications, consult factory.Special Application Notes:1. Pipe connections at the pump are threaded and are not backwelded.2. All pipe joints are threaded.3. Pipe nipples, threaded pipe fittings, stainless steel tubing, and compression type stainless steel tube connectors.4. Pipe, pipe nipples, socket weld pipe fittings, backwelded threaded pipe fittings, stainless steel tubing and compression type stainless steeltube connectors with threaded pipe connections that are not backwelded.5. Pipe nipples, threaded pipe fittings, and threaded pipe unions.6. Pipe, pipe nipples, socket weld pipe fittings, backwelded threaded pipe fittings, socket weld pipe unions.7. Stainless steel orifice plate in tube connector.8. Stainless steel orifice plate in pipe union.9. Y-strainer has stainless steel screen and 1/4" NPT (plugged) blow-off connection.10. Y-strainer has stainless steel screen and bolted cap without blow-off connection.19. This loop has stainless steel tubing and should not be used where chlorides are present.Effective: FEBRUARY 2011 • Replaces: NEWPage 8

API PLAN 21 - FLUSH PLAN FOR PROCESS PUMPS (General Note #A)ANSI PLAN 7321 – FLUSH PLAN FOR CHEMICAL PUMPSWHEN SPECIFIEDPlan Description:API Plan 21 (ANSI Plan 7321) systems include piping (ortubing) from the pump discharge gauge connection throughthe heat exchanger to the seal flush connection on thepump backhead or seal gland. These plans include allpiping, tubing, heat exchanger, and the orifice. The heatexchanger includes a steel shell and 316SS tubing. Ref.Note #B.SYSTEMS FOR NON-TOXIC AND NON-FLAMMABLE APPLICATIONSMAWP 500psi @System Description Special Notes 300º F 650º F 750º FCACBCCCDSteel Threaded Pipe and Fittings with 316SS Tubing andSteel Threaded Pipe and Fittings and Heat Exchanger316SS Threaded Pipe and Fittings with 316SS Tubing andAll 316SS Threaded Pipe and Fittings and Heat Exchanger2, 3, 7, 11, 13,2, 5, 8, 11, 13,2, 3, 7, 11, 13,2, 5, 8, 11, 13,Heat Exchanger (Steel Sheel & 316SS Tubing)(Steel Sheel & 316SS Tubing)Heat Exchanger (Steel Sheel & 316SS Tubing)(Steel Sheel & 316SS Tubing)19, 212119, 2121$3,301$3,663$5,016$5,229$3,301$3,663.$5,489$5,701$4,864$5,227$6,700$6,913ADD Temperature Indicator 13 C/F C/F C/FSYSTEMS FOR TOXIC AND/OR FLAMMABLE APPLICATIONSSystem Description Special Notes 300º FMAWP 500psi @650º F 750º FCESocket Welded Steel Pipe and Fittings and Heat Exchanger 1, 6, 8, 11, 12,(Steel Sheel & 316SS Tubing) 14, 21$4,286 $4,286 $5,849CFAll 316SS 316SS Pipe and Fittings and Heat Exchanger 2, 5, 8, 11, 13, C/F C/F C/F(Steel Sheel & 316SS Tubing) 21ADD Temperature Indicator with Thermowell 14 C/F C/F C/FGeneral Notes:A. ALL PUMPS - The plans are similar to but may not comply with API610, 5 th Ed. Review customer requirements as plans may not comply withlater editions or specific customer requirements.B. ALL PUMPS - Flush plans require one or more pump taps. Add the price of the discharge and suction gauge connections if required. Forclamped seat applications, consult factory.Special Application Notes:1. Pipe connections at the pump are threaded and are not backwelded.2. All pipe joints are threaded.3. Pipe nipples, threaded pipe fittings, stainless steel tubing, and compression type stainless steel tube connectors.4. Pipe, pipe nipples, socket weld pipe fittings, backwelded threaded pipe fittings, stainless steel tubing and compression type stainless steeltube connectors with threaded pipe connections that are not backwelded.5. Pipe nipples, threaded pipe fittings, and threaded pipe unions.6. Pipe, pipe nipples, socket weld pipe fittings, backwelded threaded pipe fittings, socket weld pipe unions.7. Stainless steel orifice plate in tube connector.8. Stainless steel orifice plate in pipe union.11. Heat exchanger has 1/4" diameter, 18 gauge, stainless steel tubes good for the maximum operating temperature and pressure of the pump.12. Heat exchanger connections are threaded and are not backwelded to allow replacement of the tube coil.13. Dial thermometer is 3" diameter, bi-metal, and screwed into pipe TEE and is furnished only when specified.14. Dial thermometer is 3" diameter, bi-metal, and screwed into a thermometer socket which is welded into pipe TEE and is furnished onlywhen specified.19. This loop has stainless steel tubing and should not be used where chlorides are present.Effective: FEBRUARY 2011 • Replaces: NEWPage 9

API PLAN 22 - FLUSH PLAN FOR PROCESS PUMPS (General Note #A)ANSI PLAN 7322 – FLUSH PLAN FOR CHEMICAL PUMPSWHEN SPECIFIEDPlan Description:API Plan 22 (ANSI Plan 7322) systems include piping (ortubing) from the pump discharge gauge connection througha Y-strainer, through the heat exchanger to the seal flushconnection on the pump backhead or seal gland. Theseplans include all piping, tubing, heat exchanger, and theorifice. The heat exchanger includes a steel shell and316SS tubing. Ref. Note #19.SYSTEMS FOR NON-TOXIC AND NON-FLAMMABLE APPLICATIONSMAWP 500psi @System Description Special Notes 300º F 650º F 750º FDADBDCDDSteel Threaded Pipe and Fittings with 316SS Tubing andSteel Threaded Pipe and Fittings and Heat Exchanger316SS Threaded Pipe and Fittings with 316SS Tubing andAl