Flushing plans

Flow Solutions Division

Mechanical Seal Piping Plans

Single Seals plans 01, 02, 11, 13, 14, 21, 23, 31, 32, 41

Dual Seals plans 52, 53A, 53B, 53C, 54

Quench Seals plan 62

Gas Seals plans 72, 74, 75, 76

Flowserve’s Flow Solutions Division recognizes one of the most effective ways toachieve long, uninterrupted mechanical seal life is to create a healthyenvironment around the seal faces. Piping plans help keep mechanical sealsrunning cool and clean, promote safe handling of dangerous fluids, and extendthe operational availability of rotating equipment. This reference book is intendedto provide a concise summary of the most essential piping plans usedsuccessfully in today’s process plants.

Each plan shows all the standard and optional auxiliary components referencedin API Standard 682 2nd edition although not all components are needed in allapplications. Consult your local Flowserve Flow Solutions Sales Engineer toidentify the right solution that satisfies your application requirements.

Mechanical Seal Piping Plans

printed in USA © 2003 Flowserve Corporation

For each piping plan identified in API Standard 682 2nd edition and recommended byFlowserve, each page set of this book shows:

Seal End View Piping Plan Layout What, Why, and Where

Pump Cross-section Mechanical Seal

outlet

inlet

pressure source,normally open

pressure gage

pressure switch

level switch (high)

level switch (low)

cooling in

cooling coils

drain,normally closed

level gage

cooling out

reservoir

liquid fill,normally closed


What• Pressurized barrier fluid circulation through reservoir.• Fluid is circulated by a pumping ring in the dual seal assembly.

Why• Isolate process fluid.• Zero process emissions.

Where• Used with dual pressurized seals (Arrangement 3 or “double”).• High vapor pressure fluids, light hydrocarbons.• Hazardous/toxic fluids.• Heat transfer fluids.• Dirty/abrasive or polymerizing fluids.• Mixers/agitators and vacuum service.

Presventative Maintenance - Reference Appendix A• Piping loop must self-vent to reservoir locate at highest elevation.• Reservoir must be pressurized at all times - typically gas charge up to 200 psi (14bar).• Barrier fluid must be compatible with process.• Reservoir level gage indicates both inboard and outboard seal leakage.

Pla

n 5

3A

Pla

n 5

3A

sealend view

Preventative Maintenance

• Viewed from drive end• Shows preferred gland

connection orientation

• Illustrated schematicof auxiliary components

• Describes piping plans,their purpose, andtypical applications

• Simplified centrifugalpump shown for allplans

• Shows typical sealarrangements

• Provides general tips toimprove reliability and fortroubleshooting

Pla

n 0

1

sealend view

internal porting


Pla

n 0

1

WhatInternal seal chamber flush from pump discharge.Operates similar to Plan 11.

WhySeal chamber heat removal.Seal chamber venting on horizontal pumps.Reduce 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.

Pla

n 0

2

sealend view

open throat seal chamber shown


Pla

n 0

2

WhatDead-ended seal chamber with no flush.

WhySimplicity - no environmental controls.

WhereLarge bore/open throat seal chambers in moderate temperature services.Cooling jacket seal chambers in high temperature services.Clean fluids.Top-entry mixers/agitators with dry seals.

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.Often used in combination with steam quench, Plan 62.

Pla

n 1

1

sealend view

inlet

orifice


Pla

n 1

1

WhatSeal flush from pump discharge through orifice.Default single seal flush plan.

WhySeal chamber heat removal.Seal 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 0.125" (3 mm) 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.

Pla

n 1

3

sealend view

outlet

orifice


Pla

n 1

3

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.

WhereVertical 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 0.125" (3 mm) 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.

Pla

n 1

4

sealend view

orifices

outlet

inlet


Pla

n 1

4

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.Increase seal chamber pressure and fluid vapor margin.

WhereVertical pumps.Clean, non-polymerizing fluids at moderate temperatures.

Preventative MaintenanceUse an orifice with a minimum 0.125" (3 mm) 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.

Pla

n 2

1

sealend view

drain,normallyclosed

inlet

vents,normally closed

cooling in

cooler

cooling out

orifice

cooling coils


Pla

n 2

1

WhatSeal flush from pump discharge through orifice and cooler.Cooler in Plan 11 flush increases heat removal.

WhySeal cooling.Reduce fluid temperature to increase fluid vapor margin.Reduce coking.

WhereHigh temperature service, typically less than 350° F (177° C).Hot water over 180° F (80° C).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 1/8" (3 mm) 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 device inlet and outlet temperatures for signs of clogging or fouling.

Pla

n 2

3

sealend view

outlet

inlet


vent,normally closed

cooling in

cooler

cooling out

cooling coils


Pla

n 2

3

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.Improve water lubricity.

WhereHigh temperature service, hot hydrocarbons.Boiler feed water and hot water over 180° F (80° C).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 plugging or fouling.Process fluids with iron should flow through magnetic separator before cooler.

Pla

n 3

1

sealend view

inlet

cyclone separator


Pla

n 3

1

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.

WhereDirty 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.

Pla

n 3

2

sealend view

inlet

flowmeter

isolationvalvepressure

gage

checkvalve

from cleansource,normally

openstrainer


Pla

n 3

2

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.

WhereDirty or contaminated fluids, paper pulp.High temperature service.Polymerizing and/or oxidizing fluids.

Preventative MaintenanceUse throat bushing sized to hold pressure or maintain flow velocity.To restrict dirty process fluid, regulate injection flow rate.To increase fluid vapor margin, regulate injection pressure.Injection fluid must be compatible with process fluid.Regularly monitor control system for closed valves or signs of plugging.

Pla

n 4

1

sealend view

inlet


vents,normally closed

cooling in

cooler

cooling out

cooling coils

cycloneseparator


Pla

n 4

1

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.

WhereHigh temperature service, typically less than 350° F (177° C).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.

sealend view

Pla

n 5

2

outlet

inlet


vent,normally open

cooling in

pressure gage

cooling outcooling coils

reservoir

pressure switch

level gagelevel switch (high)

level switch (low)


orifice


Pla

n 5

2

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.No process contamination is allowed.

WhereUsed with dual unpressurized seals (“tandem”).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 gage indicates outboard seal leakage.

Pla

n 5

3A

sealend view

outlet

inlet

pressure source,normally open

pressure gage

pressure switch

level switch (high)

level switch (low)

cooling coils

cooling in


cooling out

reservoir


level gage


Pla

n 5

3A

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

WhyIsolate process fluid.Zero process emissions.

WhereUsed with dual pressurized seals (“double”).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 150 - 200 psi (10 - 14 bar).Barrier fluid must be compatible with process.Reservoir level gage indicates both inboard and outboard seal leakage.

Pla

n 5

3B

sealend view

outlet

inlet

pressure source,normally closed

pressuregage

pressure switch




bladderaccumulator

finnedpipe


Pla

n 5

3B

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.Higher pressure than Plan 53A.

WhereUsed with dual pressurized seals (“double”).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.

Pla

n 5

3C

outlet

inlet

sealend view


pressure gage

pressure switch

level switch (low)

cooling in


cooling out


level gage

cooling coils


Pla

n 5

3C

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.Higher pressure than Plan 53A.Dynamic tracking of system pressure.

WhereUsed with dual pressurized seals (“double”).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 gage indicates both inboard and outboard seal leakage.

Pla

n 5

4

sealend view

outlet

inlet

from / to external

circulating system


Pla

n 5

4

WhatPressurized barrier fluid circulation by external system.

WhyIsolate process fluid.Zero process emissions.Seal cannot induce circulation.

WhereUsed with dual pressurized seals (“double”).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 gage indicates both inboard and outboard seal leakage.

Pla

n 6

2

sealend view

inlet

drainpressure

gagesteam trap

(steam quench)

quench,normally

open

drain,normally

open


Pla

n 6

2

WhatExternal quench on atmospheric side of seal.Quench fluids typically steam, nitrogen, or water.

WhyPrevent solids buildup on atmospheric side of seal.Prevent icing.

WhereUsed with single seals.Oxidizing fluids or fluids that coke, hot hydrocarbons.Crystallizing fluids or fluids that salt out.Caustic.Cold fluids less than 32° F (0° C).

Preventative MaintenanceQuench inlet should be on top of gland with outlet/drain on bottom.Quench pressure should be limited to 3 psi (0.2 bar) 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.

Pla

n 7

2

sealend view

vent

drain

inlet

1

32

C

DA

B

E

FH

G

1 - drain2 - vent3 - gas inlet, normally open4 - filter drain, normally closed

4A - filterB - regulatorC - orificeD - flow meterE - flow switchF - pressure switchG - pressure gageH - check valve


Pla

n 7

2

WhatUnpressurized buffer gas control system.Containment seal support typically with nitrogen buffer gas.

WhyZero to very low process emissions.Safety backup to primary seal.

WhereUsed with dual unpressurized containment seals (“tandem”).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.

Pla

n 7

4

sealend view

drain

inlet

1

3

2

C

D

A B

EFG

1 - upset drain, normally closed2 - gas inlet, normally open3 - filter drain, normally closed

A - filterB - regulatorC - flow meterD - flow switchE - pressure switchF - pressure gageG - check valve


Pla

n 7

4

WhatPressurized barrier gas control system.Gas seal support typically with nitrogen barrier gas.

WhyIsolate process fluid.Zero process emissions.

WhereUsed with dual pressurized gas seals (“double”).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 25 psig (1.75 bar) above seal chamber pressure.Flow meter indicates both inboard and outboard seal leakage.Bottled gas supply is not recommended except as part of emergency backup system.

sealend view

Pla

n 7

5 drain

pressure switch

pressure gage

vent,normally

open

orifice

level switch (high)


reservoir locatedbelow seal drain port

isloationvalve

levelgage


Pla

n 7

5

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.

WhereMay 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.

Pla

n 7

6

sealend view

vent

drain

vent,normally

open

pressure gage

pressure switch



orifice


Pla

n 7

6

WhatVent from containment seal cavity to vapor recovery.

WhyLeakage collection for zero to very low process emissions.Safety indicator for primary seal.

WhereMay 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.

sealside view

sealend view

3 ft. (0.9 m) max

1.5 - 2 ft.(0.45 - 0.6 m)

Minimize line lossesLarge diameter tubingUpward sloping linesLong radius bends

high point vent

low point drain

VerticalEquipment

HorizontalEquipment

Ap

pen

dix

AGood Piping Practices Single Seals - Plan 23 shown

�

�

�

�

sealside view

sealend view

Ap

pen

dix

B

Dual Seals - Plan 53A shown

4 ft. (1.2 m) max

low point drain

VerticalEquipment

HorizontalEquipment

1.5 - 2 ft.(0.45 - 0.6 m)

Acc

esso

ries

Airfin CoolersTM

Forced air or naturalconvection seal coolers.

Reservoirs

General duty andAPI 682 compliantreservoirs.

Seal Cooler

Compact designdual coil sealcooler

Plans 21, 23 & 41 Plans 21, 23 & 41 Plans 21, 23 & 41

API 682Seal Cooler

Seal cooler forcomplete API 682specifications.

Plans 53, 53A & 53B


Acc

esso

ries

Circulator

Standalone dual sealsupport system.

Gas BarrierControl Panel

Complete controlsystem for dual gasseals.

Refill Cart

Mobile cart tomanually fill liquidreservoirs.

Plan 54 Plans 52 & 53 Plans 72 & 74

PistonAccumulator

Hydraulically chargedreservoir for dualseals.

Plan 53C

Acc

esso

ries

Orifice

Plug and platestyle flush lineorifices.

Magnetic Separator

Iron particle separatorfor seal flush.

Plans 11, 13, 14, & 21 Plans 31 & 41

Cyclone Separator

Solid particle separatorused in dirty flushstream.

Plan 23

Seal Gard I & II

Combination flushflow regulator andmeter.

Plan 32


Acc

esso

ries

Gestra®Steam Trap

Family of reliablesteam traps forquench flows.

Bearing Gard II& BGM

Bearing frameprotection devices.

SLD

Quench lubricationdevice withsynthetic grease.

Plan 62 Plan 62 modified

DuraClear

Synthetic lubricantsfrom barrier fluid tobearing oil.

Plans 52, 53 & 54

No

tes

No

tes

No

tes

No

tes

For your nearest Flow Solutions Division Serviceand Sales location, look on the “Contact Us” page of

The information and specifications presented in these piping plans are believed to be accurate, but are supplied for information purposes only and should not be considered certified or as aguarantee of satisfactory results by reliance thereon. Nothing contained herein is to be construed as a warranty or guarantee, express or implied, with respect to the product. Although FlowserveCorporation can provide general application guidelines, it cannot provide specific information for all possible applications. The purchaser/user must therefore assume the ultimate responsibility forthe proper selection, installation, operation and maintenance of Flowserve products. Because Flowserve Corporation is continually improving and upgrading its product design, the specifications,dimensions and information contained herein are subject to change without notice.

Flowserve Corporation Flow Solutions DivisionPrimary Worldwide Flow Solutions Division Locations Licensees, authorized agents, and affiliated companies located worldwide

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Netherlands

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www.Flowserve.com

REV 12/03FTA160


Engineering

Flushing plans