Sealing Piping Plan(API&ANSI)

8/20/2019 Sealing Piping Plan(API&ANSI)

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Flow Solutions

Mechanical Seal Piping Pla

Single Seals plans 01, 02, 11, 13, 14, 21, 23, 31, 32, 4

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

Quench Seals plan 62

Gas Seals plans 72, 74, 75, 76


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Flowserve’s Flow Solutions Division recognizes one of the most effective ways to

achieve 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 extend

the operational availability of rotating equipment. This reference book is intendedto provide a concise summary of the most essential piping plans used

successfully 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 all

applications. Consult your local Flowserve Flow Solutions Sales Engineer toidentify the right solution that satisfies your application requirements.

M echanical Seal Piping Plans

printed in USA © 2003 Flowserve Corporation


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For each piping plan identified in API Standard 682 2nd edition and recommended

Flowserve, each page set of this book shows:

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

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

Flow Solutions Division

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.

P l a n

5 3 A

P l a n

5 3 A

sealend view

Preventative Maintenance

• Viewed from drive end

• Shows preferred glandconnection orientation

• Illustrated schematic

of auxiliary components

• Describes piping pla

their purpose, andtypical applications

• Simplified centrifugalpump shown for all

plans

• Shows typical sealarrangements

• Provides general tips toimprove reliability and fo

troubleshooting


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Pla

n

01

sealend view

internal porting


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Flow Solutions Divisio

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 limitedCalculate flush flow rate based on head loss through internal porting.


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Pla

n

02

sealend view

open throat seal chamber shown


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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.


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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.


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Pla

n

13

sealend view

outlet

orifice


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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.


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Pla

n

14

sealend view

orifices

outlet

inlet


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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.


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Pla

n

21

sealend view

drain,normallyclosed

inlet

vents,normally closed

cooling in

cooler

cooling out

orifice

cooling coils


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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 startinWhen 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 foulin


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Pla

n

23

sealend view

outlet

inlet


vent,

normally closed

cooling in

cooler

cooling out

cooling coils


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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 startinWhen 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 foulinProcess fluids with iron should flow through magnetic separator before cooler.


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Pla

n

31

sealend view

inlet

cyclone separator


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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 fluiSeal 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 end


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Pla

n

32

sealend view

inlet

flow

meter

isolationvalvepressure

gage

checkvalve

from cleansource,

normallyopen

strainer

Fl S l ti Di i i


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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.


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Pla

n

41

sealend view

inlet


vents,

normally closed

cooling in

cooler

cooling out

cooling coils

cycloneseparator



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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 startinWhen 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 fluiSeal chamber pressure must be nearly equal to suction pressure for proper flows.Typical failure mode is clogged separator or pipes - check temperatures at pipe end


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sealend view

Pla

n

52

outlet

inlet

drain,normally

closed

vent,normally open

cooling in

pressure gage

cooling out

cooling coils

reservoir

pressure switch

level gage

level switch (high)

level switch (low)

liquid fill,

normally closed

orifice



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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 pressureProcess 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.


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Pla

n

53A

seal

end view

outlet

inlet

pressure source,

normally open

pressure gage

pressure switch

level switch (high)

level switch (low)

cooling coils

cooling in

drain,normally

closed

cooling out

reservoir

liquid fill,

normally closedlevel gage



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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.


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Pla

n

53B

seal

end view

outlet

inlet

pressure source,normally closed

pressuregage

pressure switch

drain,normally

closed


vent,normally closed

bladderaccumulator

finnedpipe



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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 deca


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Pla

n

53C

outlet

inlet

seal

end view

vent,

normally closed

pressure gagepressure switch

level switch (low)

cooling in

drain,normally

closed

cooling out


level gage

cooling coils



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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.


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Pla

n

54

sealend view

outlet

inlet

from / to external

circulating system



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WhatPressurized barrier fluid circulation by external system.

Why

Isolate 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.


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Plan

62

sealend view

inlet

drain

pressuregage

steam trap(steam quench)

quench,

normallyopen

drain,normally

open



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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 conditi


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Plan

72

seal

end view

vent

drain

inlet

1

32

C

D

A B

E

FH

G

1 - drain2 - vent3 - gas inlet, normally open

4 - filter drain, normally closed

4A - filterB - regulatorC - orifice

D - flow meterE - flow switchF - pressure switch

G - pressure gageH - check valve



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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 systePrimary seal leakage is indicated by pressure in the vent line.

Vent or drain are usually connected to low pressure vapor recovery/flare system.


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Plan

74

sealend view

drain

inlet

1

3

2

C

D

A B

EF

G

1 - upset drain, normally closed

2 - gas inlet, normally open3 - filter drain, normally closed

A - filter

B - regulatorC - flow meterD - flow switch

E - pressure switch

F - pressure gageG - check valve



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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 pressurFlow meter indicates both inboard and outboard seal leakage.Bottled gas supply is not recommended except as part of emergency backup syste


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sealend view

Plan

75 drain

pressure switch

pressure gage

vent,normally

open

orifice

level switch (high)

drain,

normallyclosed

reservoir locatedbelow seal drain port

isloation

valve

levelgage



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WhatDrain from containment seal cavity to liquid collector and vapor recovery.

Why

Leakage 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.


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Plan

76

sealend view

vent

drain

vent,normally

open

pressure gage

pressure switch

drain,normally

closed


orifice



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WhatVent from containment seal cavity to vapor recovery.

Why

Leakage 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.

Good Piping Practices Single Seals - Plan 23 shown


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seal

side view

seal

end view

3 ft. (0.9 m) max

1.5 - 2 ft.(0.45 - 0.6 m)

Minimize line losses

Large diameter tubing

Upward sloping lines

Long radius bends

high point vent

low point drain

Vertical

Equipment

HorizontalEquipment

Ap

pendixA

Good Piping Practices Single Seals Plan 23 shown

Dual Seals - Plan 53A shown


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sealside view

sealend view

ua Sea s a 53 s o

4 ft. (1.2 m) max

low point drain

Vertical

Equipment

HorizontalEquipment

1.5 - 2 ft.(0.45 - 0.6 m)


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Ac

cessorie

s Airfin CoolersTM

Forced air or naturalconvection seal coolers.

Reservoirs

General duty andAPI 682 compliant

reservoirs.

Seal Cooler

Compact designdual coil seal

cooler

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

API 682

Seal Cooler

Seal cooler forcomplete API 682

specifications.

Plans 53, 53A & 53B

Flow Solution


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Circulator

Standalone dual sealsupport system.

Gas Ba

Control

Complete csystem for

seals.

Refill Cart

Mobile cart tomanually fill liquid

reservoirs.

Plan 54 Plans 52 & 53 Plans 72

Piston

Accumulator

Hydraulically chargedreservoir for dual

seals.

Plan 53C


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Ac

cessories

Orifice

Plug and platestyle flush line

orifices.

Magnetic Separator

Iron particle separatorfor seal flush.

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

Cyclone Separato

Solid particle separatoused in dirty flush

stream.

Plan 23

Seal Gard I & II

Combination flushflow regulator and

meter.

Plan 32

Flow Solution


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Gestra®

Steam Trap

Family of reliablesteam traps for

quench flows.

Bearing & BG

Bearing framprotection d

SLD

Quench lubricationdevice with

synthetic grease.

Plan 62 Plan 62 modified

DuraClear

Synthetic lubricantsfrom barrier fluid to

bearing oil.

Plans 52, 53 & 54


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No

tes


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No

tes


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Flow Solutions Division


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For your nearest Flow Solutions Division Service

and 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

guarantee 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 Flowserv

Corporation can provide general application guidelines, it cannot provide specific information for all possible applications. The purchaser/user must therefore assume the ultimate responsibility f

the proper selection, installation, operation and maintenance of Flowserve products. Because Flowserve Corporation is continually improving and upgrading its product design, the specification

dimensions and inform ation contained herein are subject to change without noti ce.

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

GermanyBrazilMexico

Kalamazoo, MIPhone 269-381-2650Fax 269-382-8726

United States

RoosendaalPhone 31-165-581400Fax 31-165-552622

Netherlands

DortmundPhone 49-231-6964-0Fax 49-231-6964-248

Edmonton, AlbertaPhone 780-464-1188Fax 780-464-1801

Canada

Sao PauloPhone 55-11-4231-6300Fax 55-11-4231-6326

TlaxcalaPhone 52-2-461-6791Fax 52-2-461-6847

Phone 65-6-8465100Fax 65-6-747-1963

OsakaPhone 81-72-885-5571Fax 81-72-885-5575

Singapore Japan

Buenos AiresPhone 54-11-4709-6800Fax 54-11-4709-6800ext 123

Argentina AustraliaMarayong NSWPhone 61-2-8822-710Fax 61-2-9679-7511

Scarborough, OntarioPhone 416-292-2877Fax 416-292-5190

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