Axial flow compressor

The turbine wheels

Front bearing

AIR COMPRESSOR

1

COMBUSTIONCHAMBER

2

GAS TURBINE

3

EXHAUST

4

Mai

nte

nan

ce F

acto

r

Effect of Fuel

NATURAL GAS

DISTILLATE

CRUDE

RESIDUAL

1

2

3

4

TYPES OF INSPECTION

A- INSPECTION OF UNIT “ Running”

B- INSPECTION OF UNIT “ Shutdown”

C- SPECIAL INSPECTION

A- INSPECTION OF UNIT “ Running”

The registered information can be used to further plan of the unit maintenance

The running inspection is performed during start up and while the unit is operating.

This inspection indicates the general condition of the gas turbine unit and its associated equipment.

B- INSPECTION OF UNIT “ Shutdown”

Standby inspections are performed with the unit in a stand still position

I- “Standby” inspections

II- “Combustion” inspections

III- “Hot gas path” inspections

IV- “Major” inspections

These inspections include:

I- “Standby” inspections

“Standby” inspections regard particularly the gas turbineused for intermittent duties (peak or emergency).

Routine servicing of the battery system,Changing of filters.Checking oil and water levelsCleaning relaysChecking device settings and calibrationsLubrication and other general preventive maintenancePeriodic test runs are also an essential part of good maintenance program.

If the unit is to be down for long period, weekly turn the rotors to 90 degree, And circulate lubricant to re-coat journal bearings

Special inspections such as borescope can be used to further plan periodic maintenance w/o interrupting availability

It is recommended to operate unit at load for one hour bi-monthly.(to dry out the moisture may accumulate inside the turbine components)

The inspection requires the disassembly of the main parts:

II- “Combustion” inspections

Combustion liner

Fuel nozzle

Spark plug and flame detector

III- “Hot gas path” inspections

A complete set of turbine clearances should beTaken before removal of parts

Combustion inspectionsTurbine nozzlesTurbine buckets

To perform this inspection, the upper half of the HP. Turbine and the 1st and 2nd stage must be removed.HP. Turbine buckets will be inspected on site

Hot gas path inspection includes:

As with the combustion inspection, It is recommended that the replacement of: * Combustion liner * Fuel nozzle * Transition piece to be available for installation at the conclusion of visual inspection.

The removed parts can inspected at the turbine service facilities and returned back to warehouse.

It is recommended that the Hot Gas Path inspection to be conducted under the supervision of the GT. Producer representative.

IV- “Major” inspections

Major inspection involves the major flange-to-flange components of the GT. * Casing * Rotors * Bearings * Seals * Bladings * Atomizing air system

To carry out this inspection, all the upper casinghalves and support bearings must be disassembled.

“Boroscope” inspection

C- SPECIAL INSPECTION

“Boroscope” inspection plan

A planned boroscope inspection is usuallycarried out only when necessary to repair orto replace parts.

Turbine preparation for boroscope inspection

Turbine must be standstill and the wheel spaceTemperature not exceed 80 degree centigrade

All the access holes for inspection are normallyclosed through plugs.

STARTS / FIRED HOURS FUEL INSPECTION INTERVALSHOURS

CONINUOUS DUTY

GAS/DISTILLATE 6000 TO 8000< 1/200

4000 TO 5000GAS/DISTILLATE1/50 TO 1/200

CYCLIC DUTY

--1/50 GAS/DISTILLATE3000

OR 250 STARTS

The first inspection to be after 40% of the table intervals

inspection intervals

Combustion inspection

STARTS / FIRED HOURS FUEL INSPECTION INTERVALSHOURS

CONINUOUS DUTYGASDISTILLATE

16000 to 18000

DISTILLATE

1/1000

1/100

1/50

inspection intervalsHot gas inspection

16000 - 1800010000 - 12000

GAS

DISTILLATE

GAS 12000 - 14000

8000 - 10000

CYCLIC DUTY

GAS/DISTILLATE8000

OR 800 STARTS

STARTS / FIRED HOURS FUEL INSPECTION INTERVALSHOURS

CONINUOUS DUTYGASDISTILLATE

32000 to 36000

DISTILLATE

1/1000

1/100

1/50

inspection intervalsMajor inspection

32000 - 3600020000 - 24000

GAS

DISTILLATE

GAS 24000 - 28000

16000 - 200000

CYCLIC DUTY

GAS/DISTILLATE16000

OR 1600 STARTS

FUEL

GAS ORDISTILLATE

SEMI-ANNUALLY OR AT COMPBUSTION INSPECTION WHICHEVER COMES FIRST

BOROSCOPE INSPECTION

INTERVALS

Gas Turbine Washing

1- Off Line Wash

a- Gas Turbine Speed crank speed 20-25% of full speed

b- Liquid used for wash Detergent (wash )+ water (rinse)

2- On Line Wash

a- Gas Turbine Speed Operating speed (under load) 100% b- Liquid used for wash water

3- Solid Wash

a- Gas Turbine Speed Operating speed (under load) 100% b- Material used for wash organic or inorganic substance

c- Always done after Off Line or Solid wash

1- Off Line Wash

a – Preparation

- Sealing air and atomizing air piping shall be disassembled and plugged to prevent water from entering in.

- Auxiliary atomizing air compressor connection shall be disconnected.

- Open the IGV.

- Make sure all drains are opened.

- Close the flame detector valves

- Wheel space temp. shall not exceed 82 c above water temp.0

b -Wash procedure

Cranking speed push button

Wash with Solvent as the quantities shown in table 1 (as a guide)

table 1

PGT5 4-12 1-3MS 3002 4- 20 1-5MS 5001/2 12-40 3-10

l/min gpm

MS 6001 16- 50 4-12MS 7001 EA 20- 60 5 -15MS 9001 EA 30- 80 6 -20

•Apply the detergent for a period from 3-5 minutes, stop the unit• Continue to inject during run down• The detergent soak the deposits for about 20 minutes.• Start cranking speed and wash with water from 5-10 minutes.

Check washing efficiency

The compressor should be washed until drain water is clean.

Wash procedure

2- ON Line Wash

ON Line Washing considered as complement of off- line washing and shall never be alone.The turbine shall be under loadWater shall be more than 10 C at compressor inlet

0

table 2PGT5 4-7 1.5-2 8-12MS 3002 4- 20 1.5-2 8-12MS 5001/2 20-40 5-10 15-30

l/min gpm

MS 6001 16- 50 5-10 15-30MS 7001 EA 40- 80 10 -20 15-30MS 9001 EA 80- 100 20-25 15-30

minutes

3- Solid wash

*When the fouling level is high and washing with liquid is not sufficient to remove deposits.

*A large use of solid washing can result a permanent damage of machine components.

*Washing with solids shall be carried out at steady speed and reduced load. * Nutshells is better than rice.

CHAPTER 7

Miscellaneous

• Gas Turbine Thrust balance

Pd

PS

PS

BALANCEDZONE

BALANCEDZONE

Pd

Pd

Pd

Pd

Pd

Pd

UNBALANCED ZONE

UNBALANCED ZONE

P4 – P0 P4 – P0

BALANCING DRUM

P4

P0

P1 P2 P3

P0P4

P0P4

P1 – P0 P2 – P1

+P3 – P2

+P4 – P3

+ P4 – P0

BALANCING LINE

Balancing Drum

Balancing Room

P1 +– P0 – P1 +P2 +– P2 P3 – P3 P4

4040

BALANCING DRUM

42

2

12 22 32

242

242

12 – 2 22 – 12

+32 –22

+42 – 32

+ 42 – 2

BALANCING LINE

Balancing Drum

Balancing Room

12 +– 2 – 12 +22 +– 2232 – 32 42

P4

P4

P

PPs

Ps

Mechanical seal and bearings arrangementMechanical seal and bearings arrangement

Balancing Pressure

Room

Balancing Pressure

Room

33

• Compressor Surge Phenomenon

34

AXIAL FLOWCOMPRESSORS

CENTRIFUGALCOMPRESSORS

AND

HAPPENS ONLY TO:

HAPPENS ONLY TO:

But Does not Happen toReciprocating Compressors

But Does not Happen toReciprocating Compressors

It is the flow back of gases

from the outlet of the

Last stage of the compressor

towards the suction and

return again to discharge

SURGE PHENOMENSURGE PHENOMEN

IN OUT

SURGE SURGE

• FLOW-RATE IS NOT ENOUGH

• GAS PROPERTY

• FLATENESS OF P.C. AT LOW Q

• COMPRESSOR PERFORMANCE

WhySURGE PHENOMENSURGE PHENOMEN

• FLOW-RATE IS NOT ENOUGH

• GAS PROPERTY

This will happen at starting and shutdown, also at abnormal conditions.

Gas is compressible but liquid is not.

• FLATENESS OF P.C. AT LOW Q

• COMPRESSOR PERFORMANCE

Centrifugal and Axial compressors are pumping gas continuously but reciprocating is not.

Gas pressure has the same energy at horizontal portions of the performance curve

INLET FLOW RATE Q IS ENOUGH

INLET FLOW RATE Q IS ENOUGH

IN OUT

NO SURGE NO SURGE IF IF

OUT

5 to 20 cycles per second

IN

IF INLET FLOW RATE

QIS NOT ENOUGH

COMPRESSOR IS SURGING

COMPRESSOR IS SURGING

42

COMPRESSOR

SURGING

SURGE PHENOMENON

Hp

AB

SUR

GE

LIN

E

Q M³/ hr

10000 6000

SURGE WILL DAMAGE THE

COMPRESSOR THRUST BEARINGS SURGE WILL DAMAGE THE

COMPRESSORTHRUST BEARINGS

THRUST BEARINGS

COMPRESSOR

SURGE WILL DAMAGE THE COMPRESSOR

THRUST BEARINGS SURGE WILL DAMAGE THE COMPRESSOR

THRUST BEARINGS

EFFECT OF SURGE ON CENTRIFGAL COMPRESSOR ROTOR

THRUST BEARINGS

SUR

GE L

INE

A

BHp

B1

5 to20 cycles per second 5 to 20 cycles per second Q M³/ hr- Q

10000 6000

46

SURGE CYCLE

Q M³/ hr- Q

SUR

GE L

INE

A

BHp

B1

10000 6000

47

1 -BY PASS WITH ANTI - SURGE VALVE

P,TFT

UICFY

COMRESSOR

COOLER

ANTI-SURGE VALVE WILL OPEN

IN CASE OF COMPRESSOR SURGING

48

6000 M 3

COMRESSOR

10000 M 3

4000 M 3 4000 M

3

6000 M3

P,TFT

UIC

FY

COOLER

ANTI-SURGE VALVE

FY = TRANSDUCER

UIC = ANTI- SURGE INTEGRATED CONTROLER

1 -BY PASS WITH ANTI - SURGE VALVE

49

BY PASS WITH ANTI - SURGE VALVE

GRAPHICALLY

A

Hp C

Q M³/ hr

B

SURGE CONTROL LINE

RECYCLE TRIP LINE

SURGE LIMIT LINE

50

2 –BLOW OFF VALVE

FY = TRANSDUCER

UIC = ANTI- SURGE INTEGRATED CONTROLLER

BLOW OFF

VALVE

Air

36000 M

P,TFT

UICFY

AIR COMRESSOR

10000 M3

51

2 –BLOW OFF VALVE

A

B

GRAPHICALLY

Q M ³/ hrSUR

GE C

ON

TRO

L LIN

E

Hp

B1

52

IN CASE OF GAS TURBINEAIR COMPRESSOR SURGE BLEED VALVE WILL OPEN

IN CASE OF GAS TURBINEAIR COMPRESSOR SURGE BLEED VALVE WILL OPEN

COMPRESSOR TURBINE

BLEED VALVE

Mokveld Anti-Surge ValveMokveld Anti-Surge Valve

Valve Seat

Spring Loaded during normal operation

Valve Disk moves LHS

to open

Section a-a

websa

a

SurgeSurge is the point of minimum stable flow and maximum head condition for the centrifugal compressor.

The surge region is to the left of the surge line.

Operation in this region is highly undesirable and can be very destructive for the machine since a repeated, almost instantaneous flow reversal takes place.

• Compressor reaches surge point A• Compressor loses its ability to make

pressure• Suddenly Pd drops and thus Pv > Pd

• Plane goes to stall - Compressor surges

Qs, vol

Pd

Machine shutdownno flow, no pressure

• Driver is started• Machine accelerates to nominal

speed• Compressor reaches performance

curve• Note: Flow goes up faster because

pressure is the integral of flow

• Pressure builds• Resistance goes up• Compressor “rides” the curve• Pd = Pv + Rlosses

AABB

• Because Pv > Pd the flow reverses• Compressor operating point goes to point B

C

• Result of flow reversal is that pressure goes down

• Pressure goes down => less negative flow• Operating point goes to point C

D• System pressure is going down• Compressor is again able to overcome Pv

• Compressor “jumps” back to performance curve and goes to point D

• Forward flow is re-established

Pd

Pv

Rlosses

Pd = Compressor discharge pressurePv = Vessel pressureRlosses = Resistance losses over pipe

• Compressor starts to build pressure• Compressor “rides” curve towards surge• Point A is reached• The surge cycle is complete

• From A to B 20 - 50 ms Drop into surge

• From C to D 20 - 120 ms Jump out of surge

• A-B-C-D-A 0.3 - 3 seconds Surge cycle

Developing the Surge Cycle on the Compressor Curve

WrongWrong

Steam Turbine

The two major components of a steam turbine are Nozzles and Blades ( buckets).

Nozzles are stationary; blades rotate. Steam contains energy in the form of pressure and temperature. Nozzles convert this energy into velocity energy. In a nozzle, the pressure drops and the velocity increases .

The high-velocity jets from the nozzles strike the blades and cause them to move. In the moving blades, velocity energy is converted to mechanical work, or power.Blades are located in rows on rotating wheels. Nozzles are arranged on stationary wheels, between the rotating wheels

PRINCIPLE OF OPERATION

TURBINEBLADES

MOVINGFIXED

STATOR BLADES

FIXED

STATOR BLADES

Impulsestage

TURBINEBLADES

MOVINGFIXED

STATOR BLADES

FIXED

STATOR BLADES

Reactionstage

A stage contains one row of nozzles, followed by one row of blades. Turbines may be single-stage or multistage.

Curtis Stage

A Curtis stage is a special kind of wheel that takes a relatively high pressure drop. It is used for single-stage turbines and as the first stage in most older design multistage turbines. Present day turbine design uses a rateau stage since material and blade attachment methods allow higher blade operating stresses

A Curtis stage has one row of nozzles, followed by three rows of buckets. The sequence is as follows:1. Nozzles2. Rotating buckets that develop power3. Fixed buckets that turn the direction of the steam4. A second row of rotating buckets, that develop more power.

All of the pressure drop takes place in the nozzles.

Other Types of StagesIn a multistage turbine, each stage after the first one has one row of nozzles (stationary) andone row of blades (rotating). These stages may be the "Rateau" type or the "reaction" type.

Turbines are divided into two classes,1- Power generation 2- Mechanical drive

Classification of steam turbines

Generate electric power run at constant speed because the frequency of the generated power must be constant. As the turbine runs at constant speed, features can be designed to give a very high efficiency. Tolerances between the moving and stationary parts are very close.

1- Power generation

Are used for driving machinery such as compressors and pumps, where variable speed is usually required. Tolerances are larger, and fewer stages are used.

2- Mechanical drive

Classifications of Mechanical Drive Turbines

A- General Purpose

General Purpose Turbines are used for low power applications. They are covered by API Standard 611 and are mass produced without regard to specific customer requirements. They are limited to steam supply conditions of less than 600 psig and 750°F. They also operate at speeds less than 6000 rpm.

B- Special Purpose.

General purpose turbines are usually single-stage turbines that may exhaust to a condensing system or to the atmosphere. Since they are less reliable than other turbines, their applications are limited to noncritical equipment. They are used as drivers for equipment that has a spare, such as pumps and fans. Such equipment is always has a backup.

For large power loads and covered by API Standard 612.They are manufactured to specific customer orders. These services are usually not spared; therefore, the turbine must be highly reliable. As these turbines are large machines, efficiency is important, and multistage designs are used. The most common applications are Gas compressors and Large pumps.

Double cylinders

Four cylinders

Single cylinder

Three cylinders

II- According to number of cylinders

Used to drive Electric power generator

2- Multistage Turbines

BlowersPumpsSimilar equipment

I - According to number of pressure stages

1- Single stage TurbinesUsed to drive Centrifugal compressors

IV- According to Heat drop process

3 -Back pressure Turbines

4 -Topping TurbinesThe exhaust steam is used as a feed to low pressure Turbines.

Extracting steam from stages to heat up feed water 2 -Condensing Turbine with extracting steam

from stages for industrial process

1 -Condensing Turbine with generators

III - According to principle of steam action

Reaction Turbines

Impulse Turbines

V- According to Steam condition at inlet

        Very high pressure Turbines )Steam P =170 to 225 bara(

       Super critical pressure Turbines ) Steam P > 225 bara (

    Low pressure Turbines )Steam P =1.2 to 2 bara (

        Medium pressure Turbines )Steam P =2 to 40 bara (

        High pressure Turbines )Steam P =40 to 170 bara (

Steam Turbine

Principle of steam turbine action

Three cases study

L = Pu * u ( kg m/ sec)

P u = G/g ( C1t – C2)

If G = 1 kg

P u = 1/g ( C1t – C2)

L = work donePu = force ( kg)u = tangential velocity of blades m/secC1t = theoretical velocity of steam m/sec

C2 = velocity of steam after out m/secw1=Steam relative velocity in m/secw2 =Steam relative velocity out m/sec

P1= 20 kg

a

Steam

uC1tC1t

P2= 40 kg

b

Steam uC2

P3= 34.7 kg

c

=30

=30

Steam

uC1t

C2

Steam Mass Flow kg/sG=

P1= 20 kg

a

SteamuC1t

P2= 40 kg

b

Steam

C1t

u

C2

P3= 34.7 kg

c

=30

=30

Steam

uC1t

C2

Assume C1t = 196.2 m/secCase (a)

Steam strikes a flat perpendicular surface

P1 = 1/9.81 ( 196.2 – 0 ) = 20 Kg

Case (b)Steam strikes a 90 deg bend

neglecting friction loss Then C2 = – C1t

P2 = 1/9.81 ( 196.2 + 196.2 ) = 40 Kg

Case (c)Steam strikes a 30 deg bend ( blade )neglecting friction loss Then C2 = – C1t

P3 = 1/9.81 ( 196.2 + 196.2 ) Cos 30 = 34.7 Kg

Taking into consideration the blade velocity u Relative steam velocity (w) m/sec

w1= C1t cos 30 – u w2 = - w1= -C1t cos30 + uP3= 1/g ( w1- w2 ) = 1/g {(C1t cos30 -u )-(-C1t cos30 +u)}

P3= 2/g ( C1t cos 30 –u )P3= 2/9.81 ( 196.2* 0.866 - 98.1 ) = 14.65 kg

Case c

w1= C1t- u w2 = - w1= -C1t + uP2= 1/g ( w1- w2 ) = 1/g {(C1t-u )-(-C1t+u)}

P2= 2/g {(C1t-u )}P2= 2/9.81 ( 196.2- 98.1 ) = 20 kg

Case b

w1 = C1t – u w2 = C2 = 0If u = 98.1 m / sec

P1= 1/g ( w1- w2 ) = 1/g(C1t - u )P1= 1/9.81 ( 196.2- 98.1 ) = 10 kg

Case a

LEGEND

C 0 = STEAM VELOCITY AT NOZZLE INLET m/sec

= NOZZLE ANGLE OF STEAM VELOCITY C 1

= C2

1t )+ w 22t -w 2

1 - (C 22 / 2g

C1t = THEORITICAL STEAM VELOCITY AT NOZZLE EXIT m/secC2 = STEAM VELOCITY AT MOVING BLADE EXIT m/secw1 = RELATIVE VELOCITY STRIKING MOVING BLADES m/secw2 = RELATIVE VELOCITY LEAVING MOVING BLADES m/secw2t = THEORITICAL RELATIVE VELOCITY LEAVING MOVING BLADES m/sec

= VELOCITY COEFFICIENT = 0.95 TO 0.96

= VELOCITY COEFFICIENT h o = ADIABATIC HEAT DROP OF STEAM kcal/kgh i = USEFUL ADIABATIC HEAT DROP OF STEAM kcal/kgh n = kcal/kgNOZZLE LOSSES = C21t - C21 / 8378 kcal/kg

= EXIT ANGLE OF STEAM VELOCITY C 2

= ENTRY STEAM ANGLE OF RELATIVE VELOCITY w 1

= EXIT STEAM ANGLE OF RELATIVE VELOCITY w 2

A= 1 / 427 = THERMAL EQUIVALENT OF WORK ( kcal/kg )

u= BLLADE ANGLE m/secv = STEAM SPECIFIC VOLUME m 3 /kg

La= WORK DONE BY 1kg OF STEAM (IDEAL IMPULSE ) = C21t - C22 / 2g

C 1 = C 1t = ACTUAL VELOCITY OF STEAM m/sec

EXAMPLE CALCULATION - THEORETICAL STEAM RATE,ACTUAL STEAM RATE, AND OUTLET TEMPERATURE

The method used for predicting turbine conditions uses the Mollier Chart for steam. The following example illustrates the calculation.

Given:Inlet steam pressure 600 psiaInlet steam temperature 700°FOutlet steam pressure 2 psiaTurbine efficiency 75%Brake horsepower required 1000 hp

Calculate:• Theoretical steam rate • Actual steam rate (water rate)• Steam outlet condition + temperature

Solution:Use the Mollier chart for steam(Elliot Bulletin H-37B, inside back cover);

1. Locate the Inlet Steam Temperature and Pressure on the Mollier diagram. Read inlet enthalpy, h1 = 1350 Btu/lb

2. Move vertically downward, along a line of constant entropy, to the outlet pressure of 2 psia. Read the outlet enthalpy, h2 = 923 Btu/lb

3. Calculate the isentropic (ideal) Æh Æhis = h1 - h2 = 1350 – 923 = 427 Btu/lb

4. The conversion factor from heat to work is: 2545 __Btu_hp-hr

5-Therefore, Theoretical Steam Rate, TSR = __ 2545___ Isentropic Æh

2545

427= = 5.96

6. Actual Steam Rate, ASR (Water Rate) ASR = ____TSR_ _____

Turbine Efficiency

_5.96=

0.75

= 7.95 lb/hp/hr

7. Calculate Steam Flow Rate Steam Flow Rate = hp x Actual Steam Rate

= 1000 hp x 7.95 __lb__

hp- hr= 7950 lb

hr8. Outlet Steam Condition: Calculate actual outlet enthalpy

Actual Æh = Æhis x Turbine Efficiency

= 427 Btu/lb x 0.75= 320 Btu/lb

Actual h2 = h1 - Actual Æh = 1350 - 320 = 1030 Btu/lb

Locate the outlet steam condition on the Mollier chart, at h = 1030 Btu/lb and 2 psia

Read Outlet Temperature = 130 °F

NOTE: Since the outlet steam is saturated, and the pressure is known, you can also obtain the temperature from a steam table

STEAM TURBINESCOMMON OPERATING PROBLEMS

Problem Possible Cause

Insufficient Power Developed

• Steam pressure too low.• Backpressure too high.• Supply temperature too low.• Deposits in steam path.

Low Efficiency • Deposits in steam path.• Erosion of nozzles or blades.

Erosion of Blades • Too much moisture in turbine; inlet temperature too low or outlet pressure too low.

Exhaust Too Hot

Vibration • Deposits• Erosion• Broken blades• Damaged bearings• Misalignment of piping

• Low efficiency• Low steam flow rate

Problem Possible Cause

GLOSSARY

Actual Steam Rate (ASR) The actual steam rate required per unit of power. (Pounds per horse power hour.)

{Water Rate}

Backpressure Turbine

Curtis Stage

A steam turbine that does not exhaust into a condenser.The exhaust pressure will typically be 15 psig or higher.

A type of steam turbine stage with one row of nozzles and one or more rows of buckets. The usual sequence of components is: nozzles, rotatingbuckets, stationary turning buckets, rotating buckets.

Governor A device that regulates the speed of a steam turbine. It may be mechanical or electronic.

Hand Valve A valve used to shut off the steam supply to a portion of the inlet nozzles.

Rotating turbine blades in which only velocity decreases; pressure does not decrease.

A steam turbine stage with one row of nozzles and one row of blades.A relatively small pressure drop is taken in therotating blade of a Rateau stage.

Rateau Stage

Reaction Blade Rotating turbine blades in which pressure drop takes place.

Impulse Blades

• Bearings

THRUST BEARINGTHRUST BEARING

ball Bearingsball Bearings

roller Bearingsroller Bearings

Tilting pad BearingsTilting pad Bearings

RADIAL BEARINGRADIAL BEARING

NON-DRIVE END DRIVE END

HANGED BEAMIMPELLER

HANGED BEAMIMPELLER

Thrust Ball Bearings

Thrust Ball Bearings

Non-frictional Bearings

Radial Ball Bearings

Splash ring

MECHANICAL SEAL

BEARING HOUSING

Thrust Load

Radial Load Radial LoadRadial Load

DRIVE END

NON-DRIVE END

IN-BETWEEN TWOBEARINGS IMPELLER

IN-BETWEEN TWOBEARINGS IMPELLER

Thrust Pad Bearings

Mechanical seal and bearings arrangementMechanical seal and bearings arrangement

Equipment

THRUST PAD BEARING

THRUST COLLAR THRUST SHOESTHRUST SHOES

SHAFT

THRUSTCOLLARTHRUSTCOLLAR

BASE RING

LEVEL PLATES

THRUST SHOES

CASING

White material

Tilting pad thrust bearing (carry axial load only)

Radial Tilt-Pad Bearing

Tilting pad radial bearing (carry radial load only)