1. The turbine wheels
Axial flow compressor
Front bearing

2. EXHAUST 4
COMBUSTION
CHAMBER 2
AIR COMPRESSOR 1
GAS TURBINE 3

3. Maintenance Factor Effect of Fuel 4 3 2 1 RESIDUAL CRUDE DISTILLATE
NATURAL GAS
Effect of Fuel

6. TYPES OF INSPECTION A- INSPECTION OF UNIT “ Running”
B- INSPECTION OF UNIT “ Shutdown”
C- SPECIAL INSPECTION

7. A- INSPECTION OF UNIT “ Running”
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.
The registered information can be used to further plan of the unit maintenance

8. I- “Standby” inspections
B- INSPECTION OF UNIT “ Shutdown”
Standby inspections are performed with the unit in a stand still position
These inspections include:
I- “Standby” inspections
II- “Combustion” inspections
III- “Hot gas path” inspections
IV- “Major” inspections

9. I- “Standby” inspections
“Standby” inspections regard particularly the gas turbine
used for intermittent duties (peak or emergency).
Routine servicing of the battery system,
Changing of filters.
Checking oil and water levels
Cleaning relays
Checking device settings and calibrations
Lubrication and other general preventive maintenance
Periodic test runs are also an essential part of good maintenance program.

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

11. II- “Combustion” inspections
The inspection requires the disassembly of the main parts:
Fuel nozzle
Spark plug and flame detector
Combustion liner

12. III- “Hot gas path” inspections
Hot gas path inspection includes:
Combustion inspections
Turbine nozzles
Turbine 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
A complete set of turbine clearances should be
Taken before removal of parts

13. 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.

14. 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 casing
halves and support bearings must be disassembled.

15. C- SPECIAL INSPECTION
“Boroscope” inspection
“Boroscope” inspection plan
A planned boroscope inspection is usually
carried out only when necessary to repair or
to replace parts.

17. Turbine preparation for boroscope inspection
Turbine must be standstill and the wheel space
Temperature not exceed 80 degree centigrade
All the access holes for inspection are normally
closed through plugs.

18. inspection intervals Combustion inspection
STARTS / FIRED HOURS
FUEL
INSPECTION INTERVALS
HOURS
CONINUOUS DUTY
GAS/DISTILLATE
6000 TO 8000
< 1/200
4000 TO 5000
GAS/DISTILLATE
1/50 TO 1/200
CYCLIC DUTY
--1/50
GAS/DISTILLATE
3000
OR 250 STARTS
The first inspection to be after 40% of the table intervals

19. inspection intervals Hot gas inspection 1/1000 1/100 1/50
STARTS / FIRED HOURS
FUEL
INSPECTION INTERVALS
HOURS
CONINUOUS DUTY
GAS
DISTILLATE
16000 to 18000
1/1000
GAS
1/100
DISTILLATE
GAS
1/50
DISTILLATE
CYCLIC DUTY
GAS/DISTILLATE
8000
OR 800 STARTS

20. inspection intervals Major inspection 1/1000 1/100 1/50 16000
STARTS / FIRED HOURS
FUEL
INSPECTION INTERVALS
HOURS
CONINUOUS DUTY
GAS
DISTILLATE
32000 to 36000
1/1000
GAS
1/100
DISTILLATE
GAS
1/50
DISTILLATE
CYCLIC DUTY
GAS/DISTILLATE
16000
OR 1600 STARTS

21. BOROSCOPE INSPECTION
INTERVALS
FUEL
SEMI-ANNUALLY OR AT COMPBUSTION INSPECTION WHICHEVER COMES FIRST
GAS OR
DISTILLATE

22. Gas Turbine Washing 1- Off Line Wash 2- On Line Wash 3- Solid Wash
a- Gas Turbine Speed crank speed % 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
c- Always done after Off Line or Solid wash
3- Solid Wash
a- Gas Turbine Speed Operating speed (under load) 100%
b- Material used for wash organic or inorganic substance

23. 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.

24. b -Wash procedure
Wash with Solvent as the quantities shown in table 1 (as a guide)
table 1
PGT MS
MS 5001/
l/min
gpm MS
MS EA
MS EA
Cranking speed push button
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.

25. 2- ON Line Wash Wash procedure
ON Line Washing considered as complement of off- line washing and shall never be alone.
The turbine shall be under load
Water shall be more than 10 C at compressor inlet
table 2
PGT MS
MS 5001/
l/min
gpm MS
MS EA
MS EA
minutes

26. 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.

27. CHAPTER 7
Miscellaneous

28. Gas Turbine Thrust
balance

29. Pd Pd
BALANCED
ZONE Pd PS
UNBALANCED
ZONE Pd

30. BALANCING DRUM P4 – P0 + + + + – P0 – P1 + + – P2 – P3 P4 – P0 P4 – P0
Balancing Room
BALANCING LINE P4 P0 P1 P2 P3
Balancing Drum
P4 – P0
P1 – P0
P2 – P1 +
P3 – P2 +
P4 – P3 + P1 +
– P0
– P1 + P2 +
– P2 P3
– P3 P4
P4 – P0
P4 – P0

31. BALANCING DRUM 42 – 2 40 40 + + + + – 2 – 12 + + – 22 – 32 42 2 12 22
Balancing Room
BALANCING LINE 42 2 12 22 32
Balancing Drum
42 – 2
12 – 2
22 – 12 +
32– 22 +
42 – 32 + 12 +
– 2
– 12 + 22 +
– 22 32
– 32 42 40 40

32. P4 Mechanical seal and bearings arrangement P Ps Ps Balancing Pressure
Room P4 P Ps Ps

33. Compressor
Surge Phenomenon 33 33

34. But Does not Happen to Reciprocating Compressors
HAPPENS
ONLY TO :
CENTRIFUGAL
COMPRESSORS
AND
AXIAL FLOW
COMPRESSORS
But Does not Happen to
Reciprocating
Compressors 34

35. It is the flow back of gases from the outlet of the
SURGE PHENOMEN
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

36. SURGE IN
OUT

37. Why SURGE PHENOMEN GAS PROPERTY FLOW-RATE IS NOT ENOUGH
COMPRESSOR PERFORMANCE
FLATENESS OF P.C. AT LOW Q

38. FLOW-RATE IS NOT ENOUGH GAS PROPERTY This will happen at
starting and shutdown,
also at abnormal conditions.
GAS PROPERTY
Gas is compressible but liquid is not.

39. FLATENESS OF P.C. AT LOW Q COMPRESSOR PERFORMANCE
Centrifugal and Axial compressors are pumping gas continuously but reciprocating is not.
FLATENESS OF P.C. AT LOW Q
Gas pressure has the same energy at
horizontal portions of the performance curve

40. NO SURGE IF
INLET FLOW RATE Q IS ENOUGH IN
OUT

41. 5 to 20 cycles per second IF INLET FLOW RATE Q IS NOT ENOUGH OUT
COMPRESSOR
IS SURGING
OUT IN
5 to cycles per second

42. Q M³/ hr Hp A SURGE PHENOMENON B 10000 6000 COMPRESSOR SURGING
SURGE LINE Hp
Q M³/ hr
10000
6000 42 42

43. SURGE WILL DAMAGE THE COMPRESSOR THRUST BEARINGS43

44. CENTRIFGAL COMPRESSOR ROTOR
EFFECT OF SURGE ON
CENTRIFGAL COMPRESSOR ROTOR
THRUST BEARINGS
SURGE WILL DAMAGE THE COMPRESSOR THRUST BEARINGS

45. Hp B1 A B
SURGE LINE
Q M³/ hr
- Q
10000
6000
5 to cycles per second

46. SURGE CYCLE Hp B1 A B
SURGE LINE
6000
10000
- Q
Q M³/ hr 46 46

47. 1- BY PASS WITH ANTI - SURGE VALVE
IN CASE OF
COMPRESSOR SURGING
P,T FT
UIC FY
COMRESSOR
COOLER
ANTI-SURGE
VALVE WILL OPEN 47 47

48. 1- BY PASS WITH ANTI - SURGE VALVE
COMRESSOR M 3
4000 M 3
6000 M
P,T FT
UIC FY
COOLER
ANTI-SURGE
VALVE
6000 M 3
4000 M 3
UIC = ANTI- SURGE INTEGRATED CONTROLER 48
FY = TRANSDUCER 48

49. Q M³/ hr GRAPHICALLY Hp BY PASS WITH ANTI - SURGE VALVE B A C
SURGE CONTROL LINE
RECYCLE TRIP LINE
SURGE LIMIT LINE
Q M³/ hr 49 49

50. 2 –BLOW OFF VALVE Air UIC = ANTI- SURGE INTEGRATED CONTROLLER
AIR COMRESSOR M 3 3
6000 M
BLOW
OFF
VALVE
Air FT
P,T FY
UIC
FY = TRANSDUCER
UIC = ANTI- SURGE INTEGRATED CONTROLLER 50 50

51. 2 – BLOW OFF VALVE GRAPHICALLY Hp Q M ³/ hr B A B1 SURGE CONTROL LINE51 51

52. IN CASE OF GAS TURBINE AIR COMPRESSOR SURGE BLEED VALVE WILL OPEN52 52

53. Mokveld Anti-Surge Valve
Spring Loaded during
normal operation
Valve Seat
Valve Disk
moves LHS
to open

54. a
webs a
Section a-a

55. Surge
Surge 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.

56. Wrong Developing the Surge Cycle on the Compressor Curve Pd Qs, vol Pd
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
From A to B ms Drop into surge
From C to D ms Jump out of surge
A-B-C-D-A seconds Surge cycle Pv
Compressor starts to build pressure
Compressor “rides” curve towards surge
Point A is reached
The surge cycle is complete
Rlosses Pd
Pd = Compressor discharge pressure
Pv = Vessel pressure
Rlosses = Resistance losses over pipe BB AA
Driver is started
Machine accelerates to nominal speed
Compressor reaches performance curve
Note: Flow goes up faster because pressure is the integral of flow
Because Pv > Pd the flow reverses
Compressor operating point goes to point B
Pressure builds
Resistance goes up
Compressor “rides” the curve
Pd = Pv + Rlosses
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 D
Result of flow reversal is that pressure goes down
Pressure goes down => less negative flow
Operating point goes to point C C
Machine shutdown
no flow, no pressure
Qs, vol

57. Steam Turbine

58. PRINCIPLE OF OPERATION
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

59. Impulse stage FIXED FIXED STATOR STATOR BLADES BLADES MOVING TURBINE

60. Reaction stage FIXED FIXED STATOR STATOR BLADES BLADES MOVING TURBINE

61. 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

62. A Curtis stage has one row of nozzles, followed by three rows of buckets. The sequence is as follows:
1. Nozzles
2. Rotating buckets that develop power
3. Fixed buckets that turn the direction of the steam
4. A second row of rotating buckets, that develop more power.
All of the pressure drop takes place in the nozzles.
Other Types of Stages
In a multistage turbine, each stage after the first one has
one row of nozzles (stationary) and
one row of blades (rotating).
These stages may be the "Rateau" type or the "reaction" type.

63. Classification of steam turbines
Turbines are divided into two classes,
1- Power generation
2- Mechanical drive
1- Power generation
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.

64. 2- Mechanical drive
Are used for driving machinery such as compressors and pumps, where variable speed is usually required.
Tolerances are larger, and fewer stages are used.
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.

65. 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.
B- Special Purpose.
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.

66. According to number of pressure stages
Used to drive Electric power generator 2-
Multistage Turbines
Blowers
Pumps
Similar equipment I -
According to number of pressure stages 1-
Single stage Turbines
Used to drive Centrifugal compressors
Double cylinders
Four cylinders
Single cylinder
Three cylinders
II-
According to number of cylinders

67. III - According to principle of steam action
Reaction Turbines
Impulse Turbines
IV- According to Heat drop process
1- Condensing Turbine with generators
Extracting steam from stages to heat up feed water
2- Condensing Turbine with extracting steam
from stages for industrial process
3- Back pressure Turbines
4- Topping Turbines
The exhaust steam is used as a feed to low pressure Turbines .

68. V- According to Steam condition at inlet
       
Very high pressure Turbines (
Steam P =
170 to
225
bara )
Super critical pressure Turbines
Steam P >
   
Low pressure Turbines 1 . 2
Medium pressure Turbines 40
High pressure Turbines

69. Principle of steam turbine action

70. Three cases study L = Pu * u ( kg m/ sec) P u = G/g ( C1t – C2)
Steam Mass Flow kg/s G =
L = Pu * u ( kg m/ sec)
P u = G/g ( C1t – C2)
If G = 1 kg
P u = 1/g ( C1t – C2)
L = work done
Pu = force ( kg)
u = tangential velocity of blades m/sec
C1t = theoretical velocity of steam m/sec
C2 = velocity of steam after out m/sec
w1=Steam relative velocity in m/sec
w2 =Steam relative velocity out m/sec
Three cases study
P3= 34.7 kg c
= 30
Steam u
C1t C2
C1t
P2= 40 kg b
Steam u C2
P1= 20 kg a
Steam u
C1t

71. a u
C1t
Steam
P1= 20 kg

72. b
C1t u C2
Steam
P2= 40 kg

73. c
= 30
Steam u
C1t C2
P3= 34.7 kg

74. Assume C1t = 196.2 m/sec Case (a) Case (b) Case (c)
Steam strikes a flat perpendicular surface
P1 = /9.81 ( – 0 ) = Kg
Case (b)
Steam strikes a 90 deg bend
neglecting friction loss Then C2 = – C1t
P2 = 1/9.81 ( ) = Kg
Case (c)
Steam strikes a 30 deg bend ( blade )
neglecting friction loss Then C2 = – C1t
P3 = 1/9.81 ( ) Cos = Kg

75. w1= C1t cos 30 – u w2 = - w1= -C1t cos30 + u Case c
Taking into consideration the blade velocity u Relative steam velocity (w) m/sec
w1 = C1t – u w2 = C2 = 0
If u = 98.1 m / sec
P1= 1/g ( w1- w2 ) = 1/g(C1t - u )
P1= 1/9.81 ( ) = 10 kg
Case a
w1= C1t- u w2 = - w1= -C1t + u
P2= 1/g ( w1- w2 ) = 1/g {(C1t-u )-(-C1t+u)}
P2= 2/g {(C1t-u )}
P2= 2/9.81 ( ) = 20 kg
Case b
w1= C1t cos 30 – u w2 = - w1= -C1t cos30 + u
P3= 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* ) = kg
Case c

76. LEGEND C = m/sec C = m/sec C = m/sec C = m/sec w = m/sec w = m/sec w ==
STEAM VELOCITY AT NOZZLE INLET
m/sec C 1 = 1t
ACTUAL VELOCITY OF STEAM
m/sec C 1t =
THEORITICAL STEAM VELOCITY AT NOZZLE EXIT
m/sec C 2 =
STEAM VELOCITY AT MOVING BLADE EXIT
m/sec w 1 =
RELATIVE VELOCITY STRIKING MOVING BLADES
m/sec w 2 =
RELATIVE VELOCITY LEAVING MOVING BLADES
m/sec w 2t =
THEORITICAL RELATIVE VELOCITY LEAVING MOVING BLADES
m/sec = f
VELOCITY COEFFICIENT = 0.95 TO 0.96
y =
VELOCITY COEFFICIENT h o =
ADIABATIC HEAT DROP OF STEAM
kcal/kg h i =
USEFUL ADIABATIC HEAT DROP OF STEAM
kcal/kg h n =
kcal/kg
NOZZLE LOSSES = C21t - C21 / kcal/kg a 1 =
NOZZLE ANGLE OF STEAM VELOCITY C a 2 =
EXIT ANGLE OF STEAM VELOCITY C b 1 =
ENTRY STEAM ANGLE OF RELATIVE VELOCITY w b 2 =
EXIT STEAM ANGLE OF RELATIVE VELOCITY w
A =
1 / = THERMAL EQUIVALENT OF WORK ( kcal/kg )
u =
BLLADE ANGLE
m/sec
v =
STEAM SPECIFIC VOLUME m 3
/kg
La =
WORK DONE BY 1kg OF STEAM (IDEAL IMPULSE ) = C21t - C22 / 2g
= C 2 1t
+(w 2t -w 1
) - C
/ 2g

77. The following example illustrates the calculation.
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 psia
Inlet steam temperature °F
Outlet steam pressure psia
Turbine efficiency %
Brake horsepower required hp
Calculate:
• Theoretical steam rate • Actual steam rate (water rate)
• Steam outlet condition + temperature

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

79. = 7.95 lb/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

80. = 7950 lb 7. Calculate Steam Flow Rate Steam Flow Rate
= hp x Actual Steam Rate
= 1000 hp x 7.95 __lb__
hp- hr
= lb hr
8. 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 =
= 1030 Btu/lb

81. 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

82. COMMON OPERATING PROBLEMS
STEAM TURBINES
COMMON OPERATING PROBLEMS
Problem Possible Cause
Insufficient Power
Developed
• Steam pressure too low.
• Backpressure too high.
• Supply temperature too low.
• Deposits in steam path.
• Deposits in steam path.
• Erosion of nozzles or blades.
Low Efficiency

83. Problem Possible Cause
Erosion of Blades
• Too much moisture in turbine;
inlet temperature too low or
outlet pressure too low.
Exhaust Too Hot
• Low efficiency
• Low steam flow rate
Vibration
• Deposits
• Erosion
• Broken blades
• Damaged bearings
• Misalignment of piping

84. GLOSSARY Actual Steam Rate (ASR)
The actual steam rate required per unit of power.
(Pounds per horse power hour.)
{Water Rate}
Backpressure Turbine
A steam turbine that does not exhaust into a condenser.
The exhaust pressure will typically be 15 psig or higher.
Curtis Stage
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, rotating
buckets, 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.

85. Impulse Blades
Rotating turbine blades in which only velocity decreases; pressure does not decrease.
Rateau Stage
A steam turbine stage with one row of nozzles
and one row of blades.
A relatively small pressure drop is taken in the
rotating blade of a Rateau stage.
Reaction Blade
Rotating turbine blades in which pressure
drop takes place.

86. Bearings

87. RADIAL BEARING
THRUST BEARING
ball Bearings
roller Bearings
Tilting pad Bearings

88. Thrust Ball Bearings
DRIVE END
NON-DRIVE END
HANGED BEAM
IMPELLER

89. Non-frictional Bearings
Radial Ball Bearings
Thrust Ball Bearings
Splash ring

90. MECHANICAL SEAL
BEARING HOUSING

91. Thrust Load
Radial Load

92. Thrust Pad Bearings DRIVE END NON-DRIVE END IN-BETWEEN TWO
BEARINGS IMPELLER

93. Mechanical seal and bearings arrangement
Equipment

94. THRUST PAD BEARING
THRUST SHOES
THRUST COLLAR

95. THRUST
SHOES
LEVEL
PLATES
BASE
RING
CASING
SHAFT
THRUSTCOLLAR

96. White
material
Tilting pad thrust bearing (carry axial load only)

97. Radial Tilt-Pad Bearing

98. Tilting pad radial bearing (carry radial load only)