Turbine Operation Manual

7/29/2019 Turbine Operation Manual

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Table of Content

Part I Turbine Mainframe Operation .................................................................................. 4

Chapter I Overview and Specifications of Unit Equipment.................................................4

1. Overview of Steam Turbine and Auxiliaries....................................................................4

2. Main Design Specifications of the Unit ..........................................................................8

2.1 Main Design Specifications of the Steam Turbine................................................. 8

2.2 Index of Steam and Water Quality ......................................................................13

3. Main auxiliaries and system specifications..................................................................14

3.1 Feed water pump set..........................................................................................14

3.2 High and low-pressure bypass ........................................................................... 22

3.3 Condenser..........................................................................................................26

3.4 Condensate pump ............................................................................................27

3.5 Oil purifier ......................................................................................................... 29

3.6 Performance of water-ring vacuum pump unit....................................................31

Chapter II Protection, Control and Test of the Unit .......................................................... 32

1. General Rules of Interlock Protection Test...................................................................32

1.1 Purpose and Division of Interlock Protection ...................................................... 32

1.2 Test Method of Interlock Protection ....................................................................32

1.3 Verification for Interlock Protection Test Results.................................................32

2. Interlock Protection of Mainframe ................................................................................ 32

2.1 Main Thermal Protection of Steam Turbine ........................................................ 323. Thermal Interlock Protection of Auxiliaries...................................................................43

4. Unit Control and Manual Devices ................................................................................ 65

4.1 Sequence Control System (SCS) .......................................................................65

4.2 Analogue Control System (MCS)........................................................................66

4.3 Turbine Digital Electro-hydraulic Control System (DEH).....................................75

5. Main Test of the Unit....................................................................................................84

5.1 Static Test of the Control System........................................................................84

5.2 Manual Trip Test .................................................................................................84

5.3 Trip Protection Test of Turbine Emergency Trip System (ETS)........................... 85

5.4 Turbine Main Trip Solenoid Valve Test................................................................86

5.5 Power-load Unbalance Relay (PLU) Loop Test ..................................................87

5.6 Eccentric Ring Oil Spray Test of Emergency Governor ...................................... 87

5.7 Emergency Governor Minimum Oil Spray Action Speed Test .............................88

5.8 Turbine Mechanical Over-speed Test .................................................................89

5.9 Electric Over-speed Test of Steam Turbine ........................................................ 91

5.10 Valves Activity Test ...........................................................................................93

5.11 MSV and CV Leak Test.....................................................................................93


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5.12 Mainframe Low Lube Oil Pressure Interlock Protection Test ............................93

5.13 Vacuum Leakage Test ......................................................................................94

5.14 Extraction Check Valve Activity Test ................................................................. 94

5.15 Load Rejection Test ..........................................................................................94

Chapter III Start-up and Outage of the Unit and Operating Maintenance Thereof ...........97

1 Start-up of the Unit........................................................................................................97

1.1 Start-up Specifications and Requirements..........................................................97

1.2 Start-up Prohibition Conditions of the Unit..........................................................98

1.3 Start-up State Classification of the Unit ............................................................ 100

1.4 Inspection before the Steam Turbine Start-up ..................................................100

1.5 Operation of Auxiliaries and Systems before the Unit Start-up .........................101

1.6 Unit Start-up Parameters and Mode Selection Principal...................................103

1.7 Cold Start-up of the Unit ................................................................................... 104

1.8 Warm and Hot Start-up of Unit.......................................................................... 115

1.9 Extreme Hot Start-up of Unit........................................................................... 1177

2. Normal Operation and Maintenance of Unit............................................................. 1188

2.1 Routine Maintenance and Requirements ....................................................... 1188

2.2 Operational Parameters of Unit ...................................................................... 1199

2.3 Adjustment and Maintenance for Normal Operational Parameters of Unit .....1222

3. Normal Shutdown of Unit...........................................................................................125

3.1 Preparations before Shutdown ......................................................................... 1253.2 Shutdown with Variable Parameter...................................................................125

3.3 Operations after Generator Disconnection ....................................................... 127

3.4 Cautions for Unit Shutdown............................................................................1288

3.5 Regular work for steam turbine ........................................................................130

Chapter Accident Management of Unit..................................................................1333

1. General Principles ................................................................................................... 1333

2. Manual on the Handling of Unit Accidents...............................................................1344

2.1 Emergency Outage Conditions of Unit ........................................................... 1344

2.2 Fault Shutdown Conditions of Unit .................................................................1388

2.3 Comprehensive Accident Management of Unit............................................... 1400

3. Abnormal Operation and Accident Management of Steam Turbine......................... 1466

3.1 Condenser Vacuum Drop ............................................................................... 1466

3.2 Steam Turbine Water Attack ........................................................................... 1488

3.3 Abnormal Vibration of Steam Turbine ............................................................. 1500

3.4 Increased Axial Displacement ........................................................................1522

3.5 Damaged or Broken Blade ............................................................................. 1532

3.6 Lubricating Oil System Failure........................................................................ 1533


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3.7 EH Oil System Failure .................................................................................... 1577

3.8 Feed Pump Failure.........................................................................................1588

3.9 Deaerator Failure ...........................................................................................1622

3.10 Heater Failure...............................................................................................1644

3.11 Generator Sealing Oil System Failure .......................................................... 1655

3.12 Generator Hydrogen Cooling System Failure...............................................1677

3.13 Generator Stator Cooling Water System Failure.............................................168

Part II Auxiliary System Operation ............................................................................... 1722

Chapter General Rules on Start-up (in operation) and Shutdown (out of service) of Auxiliaries

and systems ................................................................................................................1722

1. General Operating Rules of Auxiliaries.................................................................... 1722

2 General Outage Rules of Auxiliaries......................................................................... 1744

Chapter II Auxiliaries and Systems .............................................................................. 1765

1. Lubricating Oil System.............................................................................................1765

2. EH Oil System .........................................................................................................1799

3. Unit Bypass System.................................................................................................1833

4. Gland Sealing System ............................................................................................. 1855

5. Vacuum System.........................................................................................................190

6. Circulating Water System ........................................................................................1933

7 Open Circulating Cooling Water System .................................................................. 1955

8. Condensate System .................................................................................................. 1979. Regeneration and extraction Steam System..............................................................200

10. Feed pump System ............................................................................................... 2111

11. Auxiliary Steam System .........................................................................................2199

12. Generator Sealing Oil System ............................................................................... 2222

13. Generator Hydrogen Cooling System.................................................................... 2244

14. Generator stator water cooling system ..................................................................229

Appendix ...................................................................................................................... 232


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Part I Turbine Mainframe Operation

Chapter I Overview and Specifications of Unit Equipment

1. Overview of Steam Turbine and AuxiliariesThe N600-16.7/538/538/-3 steam turbine used in this project is a subcritical, single reheat,

condensing, tandem, three-cylinder four-exhaust, impulse steam turbine produced and

designed by Dongfang Steam Turbine Works. The main and reheat steam of it is configured to

unit system in form of two-one-two. Its high pressure (HP) cylinder contains one

single-governing stage and eight-pressure stage; the intermediate pressure (IP) cylinder has

five-pressure stage; the high and intermediate pressure (HIP) flow passages are designed to

two-layer countercurrent with a common casing; and the low pressure (LP) is two-layer

double-flow LP cylinder with 2*2*7 pressure stages. Through four pieces of admission pipe

that are vertically and symmetrically arranged at the middle of the HIP outer casing, the main

steam enters into the steam turbine, and then to the boiler reheater after experiencing HP

9-stage work. Similarly, the reheat steam enters into the IP part of the steam turbine in the

same way as the main steam, and then enters into two LP two-pass cylinders separately

through a piece of reducing connector after IP five-stage work; at last it is exhausted into a

double-back pressure condenser through the bi-directionally arranged exhaust pipe of the two

cylinders after the 7-stage work.The steam turbine is equipped with two HP main stop valves that are used for contacting the

sealing surface well so as to prevent steam leak at the status of wide open. There are steam

strainers inside the valves for purpose of preventing foreign substances from flowing into the

flow passage. The unit is provided with four main steam control valves for regulating steam

volume entering the steam turbine. They are equipped with a balance chamber for preventing

from vibrating and arranged into a shared valve casing in the form of straight line. The valve

casing is independent of the steam turbine proper. The IP main steam valves and control

valves are union valves with a common valve seat, wherein the former two are sleeve valves

and the later four are spherical valves. Both of them are able to move independently during

the total stroke, and opened, closed by hydraulic pressure and spring separately. The unit is

also provided with two IP union valves each of which has a steam strainer for preventing

foreign substances from entering the flow passage. Under normal condition, the IP main stop

valves and control valves are widely open. The main stop valves, control valves and union

valves are equipped with on-off testers solely used after overhaul and the remote test can be

performed in operation of them on the condition that the load is not subject to large fluctuation.

The structure of HIP cylinder with common casing and double-shell is used. It consists of four

parts, including an integrated HIP outer casing divided into upper and low half casings from


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the split, a HP inner casing divided into upper and lower half casings, an IP inner casing

divided into upper and lower half casings and an IP outer casing. Two LP cylinders are

symmetrical double split flow structure with the function of middle steam admission and

divided into upper and lower parts from the split. The LP cylinders are designed to three-layer

with the first layer served as inner casing for accommodating the elements of the flow

passage, the second one as a heat insulating layer and the third one as an outer casing for

exhausting steam and supporting the elements in the inner casing. The LP cylinder is

connected with the condenser by a stainless steel elastic expansion joint.

The shaft system of the unit is composed of a steam turbine HP rotor and IP rotor, LP rotor A

and B and a generator rotor. Each of them is connected by a solid coupling. The steam

turbine rotors without center holes are totally integral rotor.

The steam turbine is supported by six pieces of bearing blocks; the HIP rotors are supported

by two titling-pad bearings with #1 and #2 numbers of bearing block; two LP rotors are

supported by two elliptical bearing with #3, #4, #5 and #6 numbers of bearing block, horizontal

split and spherical types, and automatic alignment and manual functions. A thrust bearing with

the capability of withstanding much high axial thrust load, whereas resulting in little loss on

any loads is structured to bevel dual thrust disc and located in a middle bearing housing

beside the #2 bearing block.

The expansion dead points of the HIP cylinder locates near the center line of the #2 bearing

block, the LP cylinder A and B, respectively. A transverse pin at the dead point restricts the

axial displacement of the cylinder, and longitudinal pins in front and back of the front bearinghousing and the longitudinal center line of the two low pressure cylinders guide the cylinders

to expand freely along the axial direction and restrict the deviation laterally.

An automatic-meshing turning gear of the steam turbine consisting of a motor and gear train

is equipped between the steam turbine and the generator. Its revolution is 1.5r/min and it is

able to automatically operate and trip.

To avoid water and steam from returning back the steam turbine, the drainage and exhaust

steam systems of the steam turbine are designed to able to exhaust condensate in all of

devices, pipelines and valves and steam in the HIP cylinder and HIP gland sealing system

discharged at the time of unit trip. Their pneumatic drain valves are able to be automatically

and widely opened at the time of lacking compressed air resource. To prevent steam from

arriving at the intermediate and low pressure parts to do work through the steam sealing gland

located between the high and intermediate pressure parts at the time of load rejection, an

emergency discharge valve is set at the place of the steam sealing gland. In case that the IP

control valve is closed, it automatically opens and reliefs most of leaked steam into the

condenser. In order to avoid overheat at the HP steam exhaust part resulting from windage

loss in case that the unit is started by the IP cylinder or high and low pressure bypass on low

load, a vent valve (VV) is equipped on the exhaust pipeline of the HP cylinder to connect with


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the condenser. There are no drain points on the high and intermediate pressure cylinders, and

so water can be drained solely through the drain point on an extraction steam pipe. Water of

the LP cylinder is drained to a condenser hot well level and water of the HP main steam pipes

and valves is drained to a drain flash tank of the condenser. The unit is provided with two sets

of rectangular drain flash tank located at lateral outer walls of the HP condenser and the LP

condenser, respectively, and a spray de-superheating device that is used for spraying water

while the unit is in operation.

The regenerative system of the steam turbine has 8-stage non-regulatory extraction for three

sets of HP heater, one deaerator and four sets of LP heater, respectively. Water of the HP and

LP heaters reflows to the deaerator and the condenser, respectively by means of cascaded

drain. Drain water can flow into the condenser directly in case of accident or low load. Steam

source of the steam turbine for feed water pump is from four-stage extraction under normal

conditions; in case of startup of the unit and low load, it is automatically switched to reheat

steam. Its exhaust steam is discharged into a main condenser. Besides, for regenerative

extraction steam and steam of the steam turbine of the feed water pump, four-stage extraction

of the steam turbine is able to provide auxiliary steam for others. To meet the demand of

connecting the steam exhaust pipe and the drain pipe, the #7 and #8 LP heaters are designed

to compound heaters with a common shell and horizontally configured at throat part of the

condenser with part of which out of the shell.

The condensate system employs an IP condensate polishing system each of which is

provided with a vertical condensate pump with 2*100% volume and one of which is served asstandby. Condensate after boosting pressure enters into the deaerator through a polishing

unit, a gland heater and four LP heaters.

The gland sealing system of the steam turbine is a self-sealing system, i.e. in normal

operation of the unit, steam leakage from the shaft-end steam gland of the HIP cylinder, and

the steam leakage from HIP main stop valve and valve stems of the control valves after being

sprayed and de-superheated is provided for the LP shaft-end steam gland. The redundant

steam flows to the LP heater or condenser through an overflow station. During startup or

operation of unit on low load, the auxiliary steam station is used for providing steam for the

steam gland. The unit is provided with one set of gland heater with 100% volume and two sets

of gland extraction fan with 100% volume. The gland cooler and the steam turbine of the feed

water pump shares the gland steam. During startup and operation of the unit with low load,

gland steam is fresh or auxiliary steam and pressure of the gland main pipe is maintained by a

gland steam supply valve and an overflow valve. During operation of the unit with 25%-60% of

load, its gland steam is provided by the gland cooler; while the load is over 60%, the unit is

self-sealed and the gland steam supply valve is closed. The set value of the gland pressure is

maintained by the overflow valve and the redundant steam is discharged into #8 A LP heater

through the overflow valve. The redundant steam is discharged into the condenser through a


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conversion valve in case of #8 A LP heater failures.

The emergency governing system is the actuating mechanism of the HP fire-resistant oil DEH,

which works on instruction reception from the DEH and completion of latching, meets the

requirements of combined startup of high and intermediate pressure cylinders, startup of the

IP cylinder and activity test of the valves, and has the functions of over-speed limitation, fast

reliable steam admission interruption and over-speed protection. The system comprises a LP

governing system and a HP fire-resistant oil system. The LP governing system is composed

of an emergency governor, an emergency governor device and its link lever, a manual stop

mechanism, a reset test valve block, a mechanical shutdown electromagnet and an oil guide

ring, etc. Main functions of it comprise latch, interruption, oil spray and speed hoisting. The

HP fire-resistant oil system consists of a hydraulic servo system, a HP trip system and a

fire-resistant oil supply system. The hydraulic servo system, consisting of a valve control

stage and a servomotor, is used for controlling opening of the valves and completing fast

shutdown of them. This unit is provided with four sets of servomotor for HP control valves, two

for HP main stop valves, IP main stop valves and IP control valves, respectively. All of said

servomotors, with unilateral oil feed, are started up by fire-resistant oil pressure and closed by

spring force of the control stage, so as to guarantee all of them can be shut down in case of

pressure oil loss. The oil supply system, mainly consisting of two sets of

pressure-compensated variable plunger pump, a regenerative device, an accumulator, oil

filtering components, etc., is used for supplying HP working oil for every actuating

mechanisms of the emergency governing system.The lubricating oil system is served as main oil pump-oil turbine system driven by the major

axis of the steam turbine. In addition to all bearings of the turbine generators, it supplies oil for

the hydrogen sealing system of the generators, the lubricating device of the turning gear and

the jacking oil pump as well. It comprises a packaged oil container, a main oil pump (MOP), an

AC auxiliary oil pump (TOP), a DC emergency oil pump (EOP), a boiler oil pump (BOP), a

jacking oil device, an oil purification and regeneration device, six sets of electric heater, two

sets of oil cooler with 100% volume, a change-over valve, a flume extractor, etc. The strainers

in the lubricating oil system are able to be replaced to clean. In view from the head, the

lubricating oil system locates on the right.

For the purpose of successfully putting the turning gear into operation, the jacking oil system

is applied to providing HP oil for every bearing at the time of startup and shutdown of the unit.

Therefore, two sets of jacking oil pump, with the advantages of high efficiency, low heat value

and noise, reliable performance and no leakage under continuous HP operation, and high

volumetric efficiency, etc., are applied in the system.

The unit employs a HLP two-stage series-wound pneumatic bypass system, in which the

capacity of high pressure bypass is 60%BMCR. This system is able to make the unit optimally

start and shut down, realize two operating modes in accordance with the operating conditions,


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startup and stop curves of the steam turbine, shorten the starting time of the unit in

cooperation of setting up a steam temperature of the steam turbine suitable for the boilers. In

case that the unit load is variable, the system can be applied to regulating it so as to improve

the stability of the boiler in operation.

The feed water system is configured to unit system, with two sets of 50% BMCR turbo-feed

pump and one set of 50% BMCR electro-driven variable-speed feed water pump for one set

of unit. The turbo-feed pump is put into normal operation and the electro-driven

variable-speed feed water pump is served as standby or startup. The turbo-feed pump is

provided with HP and LP steam sources and configured at the operating floor of the steam

turbine, and its steam is exhausted into the condenser of the turbine mainframe. The feed

water system also provides attemperating water for overheat and reheat attemperators, and

the bypass system.

The unit adopts a distributed control system (DCS) that has the functions of monitoring the

DEH, MEH operator stations and other control systems (data communication interface) and

meeting the requirements of various operating conditions. The DEH produced by Dongfang

Electric Automatic Control Cooperation Limited for controlling the rotating speed and load of

the steam turbine is employed in the turbine governing system.

Startup mode of the unit: IP cylinder startup, combined startup of the HP, IP cylinders,

whereas IP cylinder startup in priority. The combined startup mode is solely used in case that

the bypass system is cut off due to failure.

Operating mode of the unit: constant pressure, and constant pressure-to-slidingpressure-to-constant pressure

Load character: with the main functions of bearing base load, and peak load manual function

Arrangement of the unit: the turbine generating set is indoors longitudinal sequential

arrangement. The lubricating oil system is configured on the right in view from the head to the

generating set.

Cooling mode of the unit: unit system with counter-flow circulating water system

2. Main Design Specifications of the Unit

2.1 Main Design Specifications of the Steam Turbine

2.1.1 Steam Turbine Proper Specifications

S/N Item Unit Data

Unit specifications


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S/N Item Unit Data

1 Unit model Sub-critical,

single reheat,

three-cylinder

four-exhaust,

tandem and

condensing

2 Steam turbine model N600-16.7/538/5

38-3

3 TMCR output MW 600

4 VWO output MW 640.647

5 HP heater and omni-segmentation

output

MW 600

6 TMCR main steam pressure MPa(a) 16.7

7 TMCR main steam temperature 538

8 TMCR HP cylinder exhaust steam

pressure

Mpa(a) 3.849

9 TMCR inlet pressure of reheat steam Mpa(a) 3.464

10 TMCR inlet temperature of reheat steam 538

11 TMCR main steam throttle flow t/h 1876

12 Maximum throttle flow of main steam t/h 2028


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S/N Item Unit Data

13 TMCR throttle flow of reheat steam t/h 1596.377

14 TMCR exhaust steam pressure Mpa(a) 0.01013

15 Steam distribution mode Composite

(nozzle/throttle)

16 Design temp of cooling water Open

32.4/closed 38

17 TMCR feed temperature 277.2

18 Rated speed R/Min 3000

19 TMCR heat consumption kJ/kW.

h

kcal/kW

8130/1942

20 Regenerative heat grade of feed water 3+1+4 (high

pressure plus

de-oxidation plus

low pressure)

21 Length of low pressure last stage blade mm 851

22 Total internal efficiency of steam turbine %

High pressure cylinder efficiency %

Intermediate pressure cylinder

efficiency

%


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S/N Item Unit Data

Low pressure cylinder efficiency %

23 Series of flow passage

High pressure cylinder Grade 9

Intermediate pressure cylinder Grade 5

Low pressure cylinder Grade 2*2*7

24 Critical speed

25 Shafting torsion frequency Hz

26 Dimensions (Length, width and height) m 27.82*10.68*6.29

2.1.2 Operational parameter

Item Unit Data

Full vacuum idle time

min 6Idle time without vacuum min 3

Max. load in case of main switch disconnection and

over-speed trip

k

W

640647

Rotating speed of over-speed trip r.p.m 3330

3360(mechanical)33

00electronic

Max. o erational back ressure KPa a 18.6

Alarm back ressure of steam turbine KPa a 19.7

Turbine tri back ressure KPa a 25.3

Max. allowable o erational exhaust tem 12


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Alarm exhaust temp 8

Exhaust tem of manual shutdown 12

S ra flow of LP c linder t/h 4

Allowable min. continuous ratin M 9

Allowable runtime under min. continuous rating min No limit

Max. back pressure at allowable min. continuous rating MPa(a) 0.0186

Max. main steam pressure at allowable min. continuous MPa(a) 16.67

Max. main steam tem at allowable min. continuous ratin 53

Vibration limit value of shaft relative to double amplitude of

vibration at rated revolution

m Not greater

than 34

Vibration limit value of shaft block relative to double amplitu

of vibration at over-critical revolution

m Not greater

than 80

Load limit at the time of stopping one set of LP heater M 60

Revolution of turnin ear r. .m 1.5

Max. cylinder temp at turning gear shutdown 15

Max. rotor temp at turning gear shutdown 15

Requirements for other short-term abnormal condition -

2.1.3 Combined critical speed of every rotor in shaft system

First critical speed (r/min) Second critical speed (r/min)

Name Shafting design

value

Tandem design

value

Shafting design

value

Tandem design value

HIP rotor 17222 1621 Greater than 4000 Greater than 4000

LP rotor A 1839 1723 3521 Greater than 4000

LP rotor B 1903 1750 Greater than 4000 Greater than 4000

Generator

rotor

984 1070 Greater than 3400 3338


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2.1.4 Allowable load variation rate of the unit

10050MCR Not less than 5/min.

5030MCR Not less than 3/min.

Less than 30MCR Not less than 2/min.

2.2 Index of Steam and Water Quality

Item Unit Index Remarks

Electrical

conductivity s/cm 0.3

After hydrogen ion

exchange at 25

Sodium g/kg 10

Silicon dioxide g/kg 20

Iron g/kg 20

Steam

Copper g/kg 5

Hardness mol/L 0

Less than or equal to

5.0 when boiler

startup

Silicon dioxide QualifiedLess than or equal to

80 boiler startup

Dissolved oxygen g/L 7


30 when boiler

startup

Iron g/L 20


75 when boiler

startupCopper g/L 5

Hydrazine g/L 1050

pH 9.0-9.5

Oil mg/L 0.3

Feed water

Electrical

conductivitys/cm 0.3

After hydrogen ion

exchange at 25

Hardness mol/L 0Condensate

Electrical

conductivity of

S/cm 0.3


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Item Unit Index Remarks

Electrical

conductivitys/cm 0.3

After hydrogen ion

exchange at 25

Sodium g/kg 10

Silicon dioxide g/kg 20

Iron g/kg 20

Steam

Copper g/kg 5

Hardness mol/L 0


5.0 when boiler

startup

hydrogen

Dissolved oxygen g/L 30Sodium g/L 10

3. Main auxiliaries and system specifications

3.1 Feed water pump set

3.1.1 General introduction

There are two 50% BMCR-capacity steam-driven feed water pumps in each unit and one 50%

BMCR-capacity electric feed water pump for start (standby). The steam-driven feed water pump is

made up by the main feed water pump and its forepump providing a continuous water supply to theboiler and desuperheating water to the superheater, reheater of the boiler and the HP-bypass of the

steam turbine. The electric feed water pump (including its forepump) is used when the unit starts,

the main feed water pump is maintained or an accident occurs. When the main feed water pump

set and the electric feed water pump set are operating in parallel, the characteristic curves of the

two coordinate with each other within a certain speed adjustable range to enable the two pump sets

run in parallel. If one set of the feed water pump fails, the electric feed water pump set can be put

into operation within 30 seconds and achieve the required pressure, running with another main

feed water pump set in parallel.

3.1.2 Equipment specifications

3.1.2.1 Technical data of the main pump forepump

Operation condition

Item UnitRating

(efficiency point

Design rate

Maximum

flow for

Minimum

flow for

Pump model SQ300-670


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Water inlet 178.5 181.5 178.5 178.5

Water inlet pressure MPa(g) 1.079 1.12 1.079 1.079

Flow m3/h 1104.8 1347.4 1500 305

Pump delivery m 135 131 130 144.9

Efficiency % 84 84 82 39

NPSH required m 2.9 4.6 6 1.6

Seal form mechanical seal

Speed r/min 1485 1485 1485 1485

Outlet pressure MPa(g) 2.26 2.26 2.21 2.34

Shaft power kW 429.6 506.5 575.4 274.2

Weight kg 1598

inlet MPa(g) 4.0Interface

flange outlet MPa(g) 4.0

inlet mm DN400Specifications

of the

interface pipe

outlet mm DN350

Rotation direction clockwise (C.W.)(from the drive end to the pump)

Bearing type inlet rolling bearing

Drive mode electric motor

Note: (g) refers to gauge pressure in the table

3.1.2.2 Technical data of the main feed water pump

Operation condition

Item UnitRating

(efficiency point

Design rate

Maximum

flow for

Minimum

flow for

pump model CHTC6/5

Water inlet

tem erature

178.5 181.5 178.5 178.5

Water inlet density kg/m3

887.9 884.6 887.9 887.9


Water inlet flow m3/h 1104.8 1347.4 1350 270


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Water outlet flow m3/h 1056.4 1298.8 1350 270

Pump delivery m 2111 2248 1820 2550

Efficiency % 82.5 83 81 36

NPSH required m 34 43 40 22

Seal form inlet Burgmann mechanical seal

Speed r/min 4673 5008 4678 4678


Shaft power kW 6626.5 8609.7 7339 4627.4

Tap pressure MPa(g) 9.34 9.96

Tap flow m3/h 48.5 48.6

Supercharging MPa(g) no superchargingSupercharging flow m

3/h no supercharging

Shaft vibration mm 0.03 0.03 0.03 0.03

Weight kg 7220

Rotation direction clockwise (C.W.)(from the feed water turbine to the feed water

Bearing type Rolling bearing+ Kingsbury-type thrust bearing

Drive mode turbine

3.1.2.3 Technical data of the electric pump forepump

Operation condition

Item UnitRating

(efficiency point

Design rate

Maximum

flow fo

Minimum

flow for

Pump model SQ300-670

Water inlet

temperature

178.5 181.5 178.5 178.5


Flow m3/h 1104.8 1347.4 1500 305

Pump delivery m 135 131 130 144.9

Efficiency % 84 84 82 39

NPSH required m 2.9 4.6 6 1.6

Seal form Mechanical seal


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Speed r/min 1485 1485 1485 1485


Shaft power kW 429.6 506.5 575.4 274.2

Rotation direction clockwise (C.W.)(from the drive end to the

Bearing type Inlet trolling bearing

Drive mode electric motor (driven by the same axle with

3.1.2.4 Technical data of the electric feed water pump

Operation condition

Item UnitRating

(efficiency point

Design rate

Maximum

flow for

Minimum

flow for

Pump model CHTC6/5

Water inlet 178.5 181.5 178.5 178.5

Water inlet density kg/m3

887.9 884.6 887.9 887.9


Water inlet flow m3/h 1104.8 1347.4 1350 270

Water outlet flow m3/h 1056.4 1298.8 1350 270

Pump delivery m 2111 2248 1820 2550

Efficiency % 82.6 83 81 36

NPSH required m 34 43 40 22

Seal form Inlet Burgmann mechanical seal

Speed r/min 4673 5008 4678 4678


Shaft power kW 6626.5 8609.7 7339 4627.4

Tap pressure MPa(g) 9.34 9.96

Tap flow m3/h 48.5 48.6

Shaft vibration mm 0.03 0.03 0.03 0.03

Rotation direction clockwise (C.W.)(from the feed water pump turbine to the feed

water pump)

Bearing type Rolling bearing+ Kingsbury-type thrust bearing


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Drive mode turbine

3.1.2.5 Electric motor parameter

Equipment

Item Unit Motor of the forepum

of the main feed wate

Motor of the electric

feed water pump

Rated power kW 560 10050

Rated voltage kV 6.6 11

Synchronous speed. r/min 1500 1500

Frequency Hz 50 50

Rotation direction Anticlockwise (from the

forepump to the motor)

Anticlockwise (from the

forepump to the motor)

3.2 High and low-pressure bypass

3.2.1 General Introduction

Every unit is equipped with a B-MCR high-pressure bypass with 60% capacity and two

low-pressure bypasses whose capacity is coordinate with the high-pressure bypass. The actuator

is hydraulic. Bypass device can improve the start-up facility of the unit. When the unit starts in a

variety of operating conditions (cold, warm state, hot and very hot), we can use the bypass system

to control the temperature of the boiler steam to make the temperature of the steam match with

that of the metal of the cylinder in short period of time, thus to reduce the time for the unit to start,

the quantity of the steam as well as loss of steam turbine cycle life to achieve the best

performance of start-up. When the unit operates normally, the high-pressure bypass device has

over-pressure safety protection features. Once the pressure of main steam exceeds the setted

value of the high-pressure bypass, the valve of the high-pressure bypass will open quickly to

reduce the take off of PCV valve and safety valve and automatically adjust the pressure of the

main stream till it returns to be normal. Low-pressure bypass device should have the function of

reheater overpressure protection and condenser protection. Bypass can run in two ways: constant

pressure matching appropriate unit operation and sliding pressure operation. The bypass

installation can work together with the unit to achieve the role of regulation. When the power grid

or the unit appears load rejection because of the fault trip, the bypass device will operate quickly

to maintain the minimum load operation function of the boiler by using belting factory electricity,

idling or shutdown thus the unit can be ready to re-grid to resume normal operation. Reducing the

load while starting up and load rejection can prevent the reheater setting in the area with highergas temperature from burning out. High pressure and low pressure bypass device are in the hot


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standby state under normal conditions. The water which High temperature bypass uses to reduce

the temperature comes from the high-pressure water; the water of low pressure bypass comes

from the condensing water. This machine consists of high-pressure bypass (main steam) and

low-pressure bypass (re-heat steam) two series bypass system devices. High-pressure bypass

system device consists of high-pressure bypass valve (high side valve), water-jet control valve

and water isolating valve etc. Low pressure bypass system device consists of low-pressure

bypass valve (low side valve), water-jet control valve and water isolating valve etc. Water

temperature control valve and reducing isolating valve are both hydraulic enforcement agency. HP

bypass and LP bypass are both with the same pattern.

The fuel supply device (petrol station) of the Bypass systems hydraulic actuator allocated

one set (high pressure bypass and low pressure bypass share a set). The time of automatically

using petrol station is 1 second, after 60 seconds, the working hydraulic can be achieved. There is

storage accumulator of petrol station to store energy, in case of power failure; it can still provide

sufficient hydraulic power to all system valves of the bypass to complete two-time All-trip on or off.

Petrol station sets up with one accumulator and high-pressure bypass device sets up a separate

accumulator as well. The working media of the Hydraulic actuator is anti-burning oil. Oil system

consists of two parts of pressure oil: 16MPa control-oil and 13.5MPa pilot oil.

3.2.2 Technical Parameter of the Equipment

Parameter table of the turbine bypass of medium-pressure tank start-up (IP) operation

condition

Name of the Technical

ParameterUnit

Starting

up in

cold

state

Starting

up in

warm

state

Starting

up in hot

state

Startin

g up

in

very

hot

Stop

the

machin

e

without

stoppin

Designe

d

conditio

n

Steam

Pressure of

the Entry

MPa(a) 6 8.62 8.62 12.9 8.77 17.5High

Pressure

Steam

Transformin

g ValveSteam

Temperatur

e of the

Entry

390 420 440 510 541 541


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Steam

Flow of

the Entry

t/h 240 240 320 320 608.4 1216.8

Steam

Pressure

of the

Exit

MPa(a) 1.3 1.3 1.3 1.3 1.2 4.1

Steam

Temperat

ure of the

Exit

~200 ~235 ~255 ~330 291.433

5

Steam

Flow of

the Exit

t/h 27542 26849 35811 35086 7179 13992

Pressure MPa(a) ~10 ~12 ~12 ~16.5 ~122

2

Temperat

ure 110 110 110 110 110 185

High

Pressure

Water-jet

Control

Valve

Flow t/h 3542 2849 3811 3086 1095 18248

Low Pressure

Steam

Transforming

Valve

Steam

Pressure

of the

Entry

MPa(a) 1.1 1.1 1.1 1.1 1.19 3.7


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Steam

Temperat

ure of the

Entry

340 400 420 480 540 540

Steam

Flow of

the Entryt/h 138 134 179 175

358

9570

0

Steam

Pressure

of the

Exit

MPa(a) 0.6 0.6 0.6 0.6 0.6 0.6

Steam

Temperat

ure of the

Exit

160 160 160 160 16016

0

Steam

Flow of

the Exit

t/h 15829 16037 2172 22111471

6591307

Pressure MPa(a) 3.3 3.3 3.3 3.3 3.3 3.3

Temperat 46.3 46.3 46.3 46.3 46.3 46.3Low Pressure

Water-jet

Control

Valve Flow t/h 2029 2637 382 4611 1127 21307


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3.2 High and Low Pressure Heater and Deaerator


The heat extraction system of the unit consists of 3 high-pressure heaters, 4 low-pressure

heaters and 1 deaerator.

High-pressure feed-water heaters are horizontal heat exchanger with surface condenser which

consists of drain cooler, condenser and steam cooler. The shell of high-pressure feed-water heater

is with all welded structure. At the side of the heater installs the pressure relief valve to prevent the

shell from damaging while the pipe is damaged. Water side also equips with pressure relief valve to

prevent the heater from overpressure due to heat expansion when the heaters inlet valve and outlet

valve is closed and the side has extraction stream. High-pressure feed-water heaters equips with

normal drain and emergent drain as well as related accessories. During the process of starting up

and continuous operation of the unit, in order to remove the non-condensing gas gathered in the

steam dead zone, there is enough vent connection and internal baffle equipped in the heater whose

displacement is designed according to 0.5 % of the steam into the heater. The drain cooler of the

heater has sufficient depth to ensure water seal is not damaged when the water level reaches

minimum. When high-pressure heater is put into operation, it can meet the requirement of the speed

to unit load as well as meet the water temperature change rate reaches 3 / min while loading up

and 2 / min while loading down without affec ting the safety and duration of the heater.

Low-pressure heaters are horizontal all welded which can withstand the change of full vacuum,

extraction pressure, the reaction of connected pipeline and thermal stress. When the adjacent

heater failure is removed, the water heater can adapt to the increase of the gas-side flow and

operate continuously. At the side of the tuber of the heater and shell separately sets up with

pressure relief valve, (delete, ) and the shell-side pressure relief valve (No. 7,8 dont equip with

pressure relief valve) to ensure the safety of the shell when the tube is damaged. The material of

the bundle of heater is stainless steel. When the steam turbine trip, to prevent excessive flash steam

come into the steam turbine, the No. 7, 8 (part of exhaust device) equips with stainless steel

anti-flash baffles .To prevent the bundle from shocking, vibrating and scouring, in the inner side of

steam trap inlet connection equips with stainless steel anti-shock plate. All low-pressure feed-water

heaters equips with normal drain and emergent drain. Normal drain connects with drain cooler while

emergent drain connects with condenser.

Deaerator is horizontal and inner setting. It is installed in the 24m layer, B-C column of the steam

room. The deaerator operation mode is constant pressure - sliding pressure - constant pressure.

Deaerator has 3 low-pressure water pipe interfaces. The diameter of each pipe is designed

according to 50% of the largest water flow. The water tank of the inner setting deaerator equips with

overflow electric valve to maintain the water level of the tank

3.2.2 Equipment parameter3.2.2.1 Design parameter of the high-pressure heater


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Heater No. Unit 1 # 2 # 3 #

1 Heater model horizontal typeU-tube

2 Heater quantity 1 1 1

3 Bypass type of high-pressure

heater(largesmall bypass)

small

bypass

I Operation condition of adjusting valve wide open (VWO) of the steam turbine

Feed water

1 Flow t/h 2028 2028 2028

2 Inlet pressure MPa(a) / / /

3 Inlet temperature 250.5 219.3 185.2

4 Inlet enthalpy kJ/kg 1088.5 946.1 795.6

5 Outlet temperature 282.3 250.5 219.3

6 Outlet enthalpy kJ/kg 1242.6 1088.6 946.1

7 Maximum allowable pressure drop MPa 0.1 0.1 0.1

8 Maximum allowable flow rate m/s 3 3 3

9 Design pressure (interim) MPa(g) 28 28 28

10 Design temperature 310 280 250

11 Test pressure MPa(g) Refer toASME-

Steam extraction

12 Flow t/h 152.166 127.47 101.295

13 Inlet pressure MPa(a) 6.672 4.133 2.36



16 Maximum allowable pressure drop MPa 0.07 0.07 0.07

17 Design pressure MPa(g) 7.3 4.65 2.5

18 Design temperature 415/290 355/260 485/230

19 Test pressure MPa(g) Refer to ASME-

Drainage entering in the heater

20 Source of the Drainage / 1 # 2 #

21 Flow t/h / 152.164 279.634

22 Temperature / 256.1 224.9

23 Enthalpy kJ/kg / 1115.4 966.3

Drainage drained from the heater


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Heater No. Unit 1 # 2 # 3 #

24 Flow t/h 152.164 279.634 380.93

25 Temperature 256.1 224.9 190.8

26 Enthalpy KJ/kg 1115.4 966.3 811

27 Drain approach 5.6 5.6 5.6

II Operation condition of turbine maximum continuous output (T-MCR)

Feed water

1 Flow t/h 1876 1876 1876

2 Inlet pressure MPa / / /



5 Outlet temperature 277.2 246.3 215.7

6 Outlet enthalpy kJ/kg 1217.5 1068.9 929.9

Steam extraction

7 Flow t/h 135.3 115.215 91.82

8 Inlet pressure MPa 6.183 3.849 2.2




11 Source of the Drainage / 1 # 2 #

12 Flow t/h / 135.3 250.516

13 Temperature / 251.9 221.3

14 Enthalpy kJ/kg / 1094.8 949.4


15 Flow t/h 135.3 250.516 342.345

16 Temperature 251.9 221.3 187.7

17 Enthalpy KJ/kg 1094.8 949.4 797.4

3.2.2.2 Design parameter of low-pressure heater (T-MCR operation condition)

Heater No. Unit

5 # 6 # 7 # 8 #

1Heater model U-tubehorizontal type

2Heater quantity 1 1 2 2

Condensate


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1 Flow t/h 1434.493 1434.493 1434.493 1434.493

2 Inlet pressure (working pressure,

interim)

MPa(a) 4 4 4 4

3

Inlet temperature

118.8 100.8 83.6 474 Inlet enthalpy KJ/Kg 500.7 424.7 352.6 199.4

5 Outlet temperature 137.4 118.8 100.8 83.6

6 Outlet enthalpy KJ/Kg 579.6 500.7 424.7 352.6

Steam extraction

7 Flow t/h 46.546 44.003 41.067 79.658

8 Inlet pressure MPa(a) 0.382 0.22 0.121 0.064

9 Inlet temperature 245.3 186.6 129.1 87.8

10Inlet enthalpy KJ/Kg 2955.4 2842.2 2732.8 2631.8


11Flow t/h 0 46.547 90.550 131.616

12Temperature 0 124.4 106.4 89.2

13Enthalpy KJ/Kg 0 522.7 446.2 373.7


14Flow t/h 46.547 90.550 131.616 213.836

15Temperature 124.4 106.4 89.2 52.6

16Enthalpy KJ/Kg 522.7 446.2 373.7 220.2

3.2.2.3 Design parameter of deaerator

Item Built-in deaerator

Type Built-in horizontal type

Model

YC-1876

Shell material

SA-516 Gr.70

Head material

SA-516 Gr.70

Design pressureMPa.g

1.27/-0.1

Design temperature steam connection371/bulk: 250

Diameter / length / thicknessmm

~3860/28300/30


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Total height after installation (including

supports)mm ~5700

Weld joint factor

1

Corrosion allowance cm vessel head 0.25/connection pipe0.15

Weight (net)kg

107300

Full water weight kg

469000

Operating weight kg

350900

3.3 Condenser


The condenser is with double shells, single process and double-pressure surface. It is with side by

side horizontal layout. The condenser is with all welded steel structure which includes two oblique

throats, two shells (hot well, water room and reheating pipe system), recycled water connecting

pipe and fixed bearing. The condenser not only accepts the drain of the host, jack-engine and

ontology, but also accepts that of low pressure bypass, high-pressure and low-pressure accident as

well as that of deaerator overflow. The throat part of the condenser equips with No. 7, 8 low

pressure heater, water-feed pump turbine as well as triple desuperheating station at the side of

Bypass system of steam turbine. When the condensed water, drained water and supplementary

water come into the condenser, they can be effectively heated and sprinkled to achieve the best

effect of deaerating. The condenser can be hemi-run, under this condition, the steam turbine can

reach 60% of the rated power.

3.2.2 Parameter of the condenser

No. Item Unit Data

1 The total valid area of the condenser m2 30500

2 The drained valid area m2 1830

3 Flow number/shell number 1/2

4 Net heat brought away by circulating

water of VWO operation condition

kJ/s 795300.3

5 Heat transfer coefficient W/m2. 3234.4/3303.3

6 Circulatin water flow t/h 71500

7 Maximum flow rate of circulating water in m/s 2.3

8 Design flow rate of the cooling tube m/s 2.3

9 Cleanin coefficient 0.85


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10 Increase of the circulatin water of VWO 10.2

11 The degree of supercooling of condensate 0.5

12 Desi n terminal tem erature difference of 6.02/5.85

13 Desi n ressure of water chamber MPa. 0.4

14 Desi n ressure of shell side MPa. Vac.0.15

15 Oxygen content required of the g/l 3016 Total water resistance of tube kPa 61

17 Condenser steam resistance kPa 0.1

18 Circulating ratio (design operation 55

19 Weight of water chamber(each) kg 15000

20 Net wei ht of the condenser k 750000

21 Condenser wei ht o eratin k 1350000

22 Condenser wei ht full water k 2550000

23 Test pressure of water chamber 1.5 times of the design

pressure

3.4 Condensate pump

3.4.1 General introduction of condensate pump

Transfer the condensate in the turbine condenser to the deaerator, and provide the turbinelow-pressure bypass and desuperheater with desuperheating water and other things. Each unit is

equipped with two condensate pumps, one for work and the other for standby. The condensate

pumps are vertical and vessel type multistage centrifugal pumps with 4-stage impeller. The

condensate pump is constituted by shell, outlet connection pipe, pump spindle, 4-stage impeller,

coupling, sealing element, pump base, etc.

3.4.2 Operating parameter of the condensate pump

Mode of pump

NLT500-570X4S

Pump operation condition

point

Item Unit

Nameplate operation

condition

Rating operatio

conditionTMCR

(efficiency point

required)

Water inlet

temperature

46.3 46.3

Water inlet

pressure MP

0.01 0.01


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a

-

a

Flow

t

/

h

1693 1434.493

Total outlet

pressure M

p

a

-

a

3.25 3.41

Pump

lift M 333 350

efficiency

% 83.6 83

NPSH

m

H

2

O

5.2 5

Speed

r

/

m

i

n

1480 1480

Shaft

power

K

w 1835.8 1646.7

Total outlet pressure

M

P

a

3.25 3.41

inlet/outlet nominal

diameter mm/mm

800/500 800/500

inlet/outlet nominal

pressure M

1.6/5.0 1.6/5.0


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P

a

-

g

Design pressure of

pump MPa(g)

5 5

Rotation direction Anticlockwise (from the motor to the condensate

pum)

3.5 Oil purifier

Each unit is equipped with an oil purifier, which is able to purify the steam turbine lubricating oil

while on-line or shutdown, to remove impurities particles, moisture, break emulsification, so that the

main steam turbine or feed water pump would drive the small steam turbine lubricating oil to be

reborn.

No. Item Unit Data

1 Manufacturer Made by Alfa Laval, Sweden

Assembled by Beijing Touping New Technology Development

2Manufacturing

Made by Alfa Laval, Sweden, assembled in Beijing

M MAB206

4 Type Offcenter pattern

5Purification devices rated

outputL/h 10600

6 Suitable oil 3246 or 68

7 Filtration m 3

moistu 33PPm

8 The quality of treated oil particle

countNAS standard 7 or Morgan 6

9 Oil-providing pump model KFUG42

10 Oil-providing pump type horizontal type gear pump

11Oil-providing pump m

3/h 13

12 Oil-providing pump delivery M a 0.15

13 Shaft power of oil-providing KW 11

14 oil-providing pump speed r/min 1500


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15Motor model of

oil-providing Made by ABB company, provided byAlfa Laval, Sweden

16Rated power of

KW 12

17 Rated voltage of V 415

18 Speed of oil-providing r/min 1500

19 Centrifuge model MAB206

20 Centrifuge type vertical type

21 Centrifuge capacity m3/h 10.6

22 Centrifuge shaft power KW 11

23 Centrifuge speed r/min 8425

24 Centrifuge motor model Share the same motor with oil-providing pump

25 Rated power of centrifuge K 12

26Rated power of centrifuge

V 415

27 Centrifuge motor speed r/min 1500

28 Maximum noise level dB(A) 85

29Equipment dimensions

(length, width, height)

Mm 180014001300

oil inlet Mm DN40

oil outlet Mm DN40

drain outlet Mm DN2030

The interface

size

water sealedMm 1/2 inch internal thread

31 The interface pressure M a 16

32 Net weight of the K 1000

33 Weight of running Kg 1020

34 Maximum maintenance Kg 1020

35 Material of centrifuge oil pum cast steel

36 Material of centrifuge oil pump lid cast steel

37Material of centrifuge oil pum

im eller stainless steel

38Material of centrifuge oil pum

stainless steel

39 Power of electric heater KW 96


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Oil purifier specifications

3.6 Performance of water-ring vacuum pump unit:

(1) Minimum suction pressure (ultimate vacuum) of the water-ring vacuum pump: 2900 Pa(a)

(2) Pump speed: 490r/min

(3) Impeller nominal diameter: 76.5cm

(4) Speed: 19.62m/s

(5) Shaft power: (maximum) 150 kW (minimum): 94kW Shaft power: 10.13kPa: 113KW;

11.8kPa: 117KW

(6) Starting power: 94KW

(7) Pumping capacity100 kg/h (inlet pressure is 10.13kPa and cooling water temperature is

32.5 )

(8) Electric motor model: Y450S-12 rated power: 185 KW speed: 490r/min voltage: 415Vmotor protection level: IP54 motor insulation level: F motor temperature rise: B

(9) The cooling water amount of pump heat exchanger: 40m3/h, water quality: seawater, water

temperature: 32.5 , separator make -up water flow:


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Chapter II Protection, Control and Test of the Unit

1. General Rules of Interlock Protection Test

1.1 Purpose and Division of Interlock Protection

1.1.1 Test purposes: check thermal interlock protection circuit action for correctness, including the

action of primary single circuit and interlock protection.

1.1.2 Division of test

1.1.2.1 Inspection associated with thermal device, and thermal technicians in responsible of

forcing, stimulating and resetting of thermal single

1.1.3.2 Field apparatus inspection associated with the test, and operators in responsible of the

operation of the electric switches and OPR

1.2 Test Method of Interlock Protection

1.2.1 Single imitation

1.2.2 Transmission test

1.3 Verification for Interlock Protection Test Results

1.3.1 Hard wired circuit test

1.3.2 Interlock protection test

1.3.2.1 Mainframe protection test (see thermal protection of the mainframe)

1.3.2.2 Auxiliary protection test

2. Interlock Protection of Mainframe

2.1 Main Thermal Protection of Steam Turbine

2.1.1 Turbine DEH and ETS trip protection

ETS over-speed protection

TST over-speed protection

DEH over-speed protection

High metal temperature (left and right) protection for inner walls of the HP cylinder exhaust

1. Send an alarm signal of high metal temperature in case that the metal temperature of the

HP cylinders exhaust is greater than or equal to 420 degrees centigrade.

2. Shut down by the action of protection in case that the metal temperature of the HPcylinders exhaust is greater than or equal to 432 degrees centigrade.


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High metal temperature (back and right) protection for LP cylinder exhaust

3. Send an alarm signal of high metal temperature in case that the metal temperature of the

LP cylinders exhaust is greater than or equal to 80 degrees centigrade.

4. Shut down by the action of protection in case that the metal temperature of the LP

cylinders exhaust is greater than or equal to 107 degrees centigrade.

Low vacuum protection of condenser: Shut down by the action of protection in case of low

vacuum of condenser.

Low lube oil pressure protection:

5. Send an alarm signal of low lube oil pressure in case that the lube oil pressure is less

than 0.115MPa;

6. Shut down by the action of protection in case that the lube oil pressure is less than

0.069MPa;

Shut down by the action of projection in case of low EH oil pressure (one of two logic) (1, 3

and/or 2, 4).

Large vibration protection of bearings

Send an alarm signal of large vibration in case that the vibration of any bearing is greater

than or equal to 125um; Shut down by the action of protection in case that the vibration is

greater than or equal to 250um.

1. Send an alarm signal of large axial displacement in case that the axial displacement of

the steam turbine is less than negative 1.05mm or greater than positive 0.6mm.

2. Shut down by the action of protection in case that the axial displacement of the steamturbine is less than negative 1.65mm or greater than positive 1.2 mm.

Differential expansion protection of HIP cylinders

1. Send alarm signal of large differential expansion in case that the differential expansion is

less than negative 5.3mm or greater than positive 10.3mm;

2. Shut down by the action of protection in case that the differential expansion is less than

negative 6.6mm or greater than positive 11.6mm.

Differential expansion protection of LP cylinder

1. Send alarm signal of large differential expansion in case that the differential expansion is

less than negative 4.6mm or greater than positive 19.8mm;

2. Shut down by the action of protection in case that the differential expansion is less than

negative 8mm or greater than positive 30mm.

DEH electricity loss protection

Generator protection

Malfunction of a trip protection button on the console

Trip by the action of protection in case that temperature of any bearing shell of #1-#8

journal bearings is high (5 seconds delay) (alarm when temperature of #1-#6 bearing shells

reaches 110 degrees centigrade and trip when reaching 115 degrees centigrade;


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meanwhile, alarm and trip temperatures of the #7 and #8 bearing shells are 110 and 115

degrees centigrade, respectively);

Trip by the action of protection in case that the temperatures of #1-#8 working thrust pads

are high (time delay 5s) (alarm and trip temperatures of them are 85 and 110 degrees

centigrade, respectively);

Trip by the action of protection in case that the temperatures of #1-#8 locating thrust pads

are high (time delay 5s) (alarm and trip temperatures of them are 85 and 110 degrees

centigrade, respectively);

Shut down by the action of protection in case that the steam temperature of the main stop

valve at the inlet is LL (low, low);

Shut down by the action of protection in case that cooling water inlet flow of the generator

stator is LL;

Shut down by the action of protection in case that inlet cooling water pressure of the

generator stator is LL;

Shut down by the action of protection in case that outlet cooling water temperature of the

generator stator is HH (high, high).

2.1.2 Over-speed protection

2.1.2.1 Over-speed protection control system (OPC): the momentary speed of the steam turbine

will reach maximum in case that the trip signal of the generator main switch does not send out due

to control single lag and residual steam at the time of load rejection of the unit. In order to prevent

the unit from tripping for a rotating speed capable of causing tripping, the HIP control valve mustbe closed fast and immediately to prevent speed rise when the rotating speed reaches 103% of

the rated.

2.1.2.2 When the rotating speed of the steam turbine reaches 110%-111% of the rated speed, the

eccentric ring mechanical emergency governor drives the mechanical trip valve into action to drain

the oil in the emergency trip system (ETS), to close the high pressure main stop valve and the high

pressure control valve and to open the vent valve. And then the steam turbine is stopped after

closing the intermediate pressure main stop and control valves, the extraction check valves and

exhaust check valve of the HP cylinder at all levels and opening the dump valve.

2.1.2.3 Electric over-speed protection: immediately close the HIP MSV and CV to stop feeding

steam while the rotating speed of the unit reaches 111% of the rated speed; meanwhile, the DEH

sends out a stop signal.

2.1.3 Manual shutdown

2.1.3.1 Manual field tripper: it is set at the front box of the steam turbine. While operating, the

tripper is first drawn out after counter-clockwise rotating 90, and then the HP MSV and HP CV, IP

MSV and IP CV, the exhaust check valve of the HP cylinder and check valves at all level are

closed and the vent valve is opened after the safety oil is drained by the action of the mechanical

trip valve.


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2.1.3.2 Manual remote tripper: it is of double-button and equipped on the control desk of the

central control room. Pressing the buttons will bring the mechanical solenoid and the main trip

solenoid A and B into action to close HP MSV and HP CV, IP MSV and IP CV, the exhaust check

valve of the HP cylinder and check valves at all level and open the vent valve.

2.1.4 Protection system for preventing water induction

Principal for classification of water induction-preventing control

Divide the turbine steam source piping, steam turbine proper and drain valves of every

extraction piping into HP, IP, LP drain valves;

Exclude every extraction check valves for the reason that the said valves are totally used for

preventing water into steam turbine;

Open and close the said three valves in accordance with the load level, they are divided into

10%, 20% and 30% MCR;

Set one operating button for three of them;

The said three drain valves include the drain valves of 1-6 segments extraction pipeline.

LBA41AA560VC

Pneumatic drain valve of the main steam pipe LBA41AA560VC

Open conditions of interlock

Load less than or equal to 10%

Steam turbine trip

Generator trip

Closure conditions of interlockLoad greater than 10%

Low-low condenser vacuum (similarly to the said drain valves) (with the use of an

analogue value less than 50kpa)

Pneumatic drain valves of main steam pipe on the left and right sides LBA21AA560VC/

LBA31AA560VC

Open conditions of interlock


Steam turbine trip

Generator trip

Closure conditions of interlock

Load greater than 10%

Low-low condenser vacuum (similarly to the said drain valves) (with the use of a

analogue value less than 50kpa)

Pneumatic drain valves of main steam pipe on the left and right sides LBA21AA560VC/

LBA31AA560VC




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Steam turbine trip

Generator trip


Steam turbine more than 20%

Low-low condenser vacuum

Pneumatic drain valves of upper and lower valve blocks of right and left main steam

valves MAL70AA560VO/ MAL30AA560VO/ MAL60AA560VO/ MAL40AA560VO



Steam turbine trip

Generator trip


Steam turbine greater than 10%


Pneumatic drain valves of right and left RSV 1/2 MAL10AA560VO/ MAL20AA560VO



Steam turbine trip

Generator trip


Steam turbine greater than 10%Low-low condenser vacuum

Pneumatic drain valve for outlet of the HP control valve MAL50AA560VO



Steam turbine trip

Generator trip


Steam turbine greater than 10%


Over-speed protection control system action (OPCACT for short)

Steam turbine trip

Generator trip

Following valves will automatically open in case that the load is less than 10% of the rated.

Steam turbine trip

Generator trip


Drain valve of the left main steam pipe


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Drain valve of the right main steam pipe

Drain valve of HP steam conduit

Drain valve for the left upper valve block of the HP MSV

Drain valve for the left lower valve block of the HP MSV

Drain valve for the right upper valve block of the HP MSV

Drain valve for the right lower valve block of the HP MSV

Drain valve for the left exhaust pipe of the HP cylinder

Drain valve for the right exhaust pipe of the HP cylinder

Drain valve for the exhaust manifold of the HP cylinder

Outlet drain valve for the 1st extraction electric valve

Inlet drain valve for the 1st extraction electric valve

Outlet drain valve for the 2nd extraction electric valve

Inlet drain valve for the 2nd extraction electric valve

Drain valve of HP bypass pipe

Following valves will automatically close in case that the load is greater than 10%:


Drain valve of the left main steam pipe

Drain valve of the right main steam pipe

Drain valve of HP steam conduit

Drain valve for the left upper valve block of the HP MSV

Drain valve for the left lower valve block of the HP MSVDrain valve for the right upper valve block of the HP MSV

Drain valve for the right lower valve block of the HP MSV




Outlet drain valve for the 1st extraction electric valve

Inlet drain valve for the 1st

extraction electric valve

Outlet drain valve for the 2nd extraction electric valve

Inlet drain valve for the 2nd extraction electric valve

Drain valve of HP bypass pipe

Following valves will automatically open in case that the load is less than 20%:

Steam turbine trip

Generator trip


Drain valve of left reheat steam pipe

Drain valve of right reheat steam pipe

Drain valve of left IP union valve


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Drain valve of right IP union valve

Inlet drain valve of 3ird extraction electric valve

Outlet drain valve of 3ird extraction electric valve

Inlet drain valve of 4th extraction electric valve

Outlet drain valve of 4th extraction electric valve



Drain valve of left reheat steam pipe

Drain valve of right reheat steam pipe

Drain valve of left IP union valve

Drain valve of right IP union valve

Inlet drain valve of 3ird extraction electric valve

Outlet drain valve of 3ird extraction electric valve


Outlet drain valve of 4th


Following valves will automatically open in case that the load is less than 30%:

Steam turbine trip

Generator trip



Outlet drain valve of 5th extraction electric valveInlet drain valve of 6th extraction electric valve




Inlet drain valve of 5th



Inlet drain valve of 6th


Outlet drain valve of 6th



High-high water level in the drain pot triggers the drain valve to open, whereas to close.





Drain valve for the exhaust pipe at the inlet A of the LP bypass valve


Drain valve for the exhaust pipe at the inlet B of the LP bypass valve


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Drain valve for the exhaust pipe at the outlet A of the LP bypass valve


Drain valve for the exhaust pipe at the outlet B of the LP bypass valve


Steam turbine trip or generator asynchronous protection or OPC action will close the left

exhaust check valve of the HP cylinder.

Steam turbine trip or generator asynchronous protection or OPC action will close the right

exhaust check valve of the HP cylinder.

2.1.5 Interlock protection for lubricating oil system of mainframe

2.1.5.1 The turbine AC auxiliary pump is self-driven in case of meeting one of following conditions:

1) Low outlet pressure of the main oil pump

2) The period before turbine rotating speed down to 2900r/min

3) Low lube oil

4) Steam turbine trip

2.1.5.2 The manual shutdown of the turbine AC auxiliary pump is available in case of meeting one

of following conditions:

1) Zero rotating speed of steam turbine

2) Stable and constant rotating speed of the steam turbine up to 3000r/min and normal lube oil

pressure2.1.5.3 The mainframe startup pump (MSP) is self-driven in case of meeting one of following

conditions:

1Turbine rotating speed less than or equal to 2850 r/min

2Low inlet pressure of the main oil pump (MOP) (less than Mpa)

3Steam turbine trip.

2.1.5.4 The manual shutdown of the mainframe startup pump (MSP) is available in case of

meeting one of following conditions:

1) Stable and constant rotating speed of the steam turbine up to 3000r/min

2) Zero rotating speed of steam turbine.

2.1.5.5 The DC emergency oil pump (EOP) is self-driven in case of meeting one of following

conditions:

1) Non-zero rotating speed of the steam turbine and low-low lube oil pressure of the mainframe

(less than Mpa)

2) Standby AC lube oil pump startup with the AC lube oil pump trip

3Low inlet pressure of the MOP and TOP.

2.1.5.6 The manual shutdown of the DC emergency oil pump (EOP) is available in case of meeting

one of following conditions:


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1) Zero rotating speed of steam turbine

2) Normal lube oil pressure (0.137Mpa- 0.176Mpa).

2.1.5.7 The startup of the mainframe jacking oil pump is allowable under the following condition:

1) Inlet pressure of the jacking oil pump more than 0.03Mpa

2.1.5.8 The mainframe jacking oil pump is allowable for shutdown in case of meeting one of

following conditions:

1) The AC auxiliary oil pump out of service

2) The turbine rotating speed is greater than or equal to 2000r/min (tentative speed)

3) Allowable for one standby in two sets of jacking oil pump

2.1.5.9 The jacking oil pump is self-driven in case of meeting one of following conditions:

1When the rotating speed of the steam turbine MAA00CS002 is less than 2000, a specified

standby pump will bring into action; if the standby delays 10s, the other one will be put into

operation;

2When the rotating speed of the steam turbine MAA00CS002 is less than 2000, the working

pump is in operation and the outlet manifold pressure of the jacking oil pump is low, the standby

jacking oil pump is put into operation;

3When the rotating speed of the steam turbine MAA00CS002 is less than 2000 and the

working pump trips, the standby jacking oil pump is brought into action.

2.1.5.10 the jacking oil pump automatically stops in case of meeting one of following conditions:

1) Rotating speed of the steam turbine is greater than or equal to 2000r/min (tentative speed);

260s delay time of the steam turbine at zero rotating speed2.1.5.11 the electric heater of the lube oil box is self-driven in case of meeting one of following

conditions:

1) Lube oil temperature in the main oil tank less than 32

2Surface temperature of the electric heater of the main oil tank less than 100

2.1.5.12 the electric heater of the main lube oil automatically stops in case of meeting one of


1) High lube oil temperature in the main oil tank greater than 37

2) High surface temperature of the electric heater of the main oil tank greater than 150

2.1.6 Interlock protection for EH oil system of the mainframe

2.1.6.1 The EH oil pump is allowable for starting in case of full meeting following conditions:

1) Main EH oil pump allowable for being operated

2) Normal oil level of the EH oil tank

320 Oil temperature of the EH oil tank higher than 20

2.1.6.2 The standby EH oil pump will automatically start in case of meeting one of following

conditions:

1) One set in operation and pressure of the EH oil manifold less than or equal to Mpa

2) Motor trip of a EH oil process pump


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2.1.6.3 The EH oil pump will automatically stop in case of meeting one of following conditions:

1Excessively low oil level of the EH oil tank (less than negative 200mm)

2Breaker trip of the EH oil pump or overload protection of the motor in action

2.1.6.4 The electric heater of the EH oil tank will automatically start in case of full meeting following

conditions:

1Normal oil level of the oil tank

2#1 and #2 circulating pumps of the oil tank in operation

3The breaker of the heater at on-position

4Oil temperature less than or equal to 20

2.1.6.5 The electric heater of the EH oil tank will automatically stop in case of meeting one of


1The oil temperature greater than or equal to 35

2The breaker of the heater tripped

3Excessively low oil level

4Both the #1 circulating pump and #2 circulating pump of the oil tank out of service

2.1.7 Turning gear interlocks protection of the mainframe

2.1.7.1 The turning gear will automatically start in case of full meeting following conditions:

1) The interlock switch of its motor at AUTO position

2) Lube oil pressure of the bearing greater than 0.103MPa

3) Jacking oil pressure of every bearing greater than or equal to 3.43MPa

4) A manual turning interlock switch in standby5) Both of the MSV in fully closed state

6) Zero rotating speed of the steam turbine and 30s delay time

2.1.7.2 The turning gear will automatically trip in case of meeting one of following conditions:

1) Jacking oil pressure of any bearing less than 2.7Mpa

2) Lube oil pressure less than or equal to 0.07Mpa

3) Overload protection for the turning motor in action

2.1.8 Control and interlock protection of HP and LP bypass system

2.1.8.1 Control mode of the HP and LP bypass system

Decentralized control system (DCS) control modes of the HP bypass system: minimum opening,

boost, fixed pressure and follow modes

DCS control modes of the LP bypass system: minimum opening, fixed pressure and track

modes

2.1.8.2 Bypass attemperating water control

1) The control modes include AUTO and MAN; in the AUTO mode, the outlet temperature of the

bypass valve is able to be automatically regulated by setting the inlet temperature of the HP

bypass valve; in another case, the outlet temperature is maintained through manually controlling

the opening of an attemperating water valve by the operator. Meanwhile, automatic control mode


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of the HP bypass pressure into operation is to bring the HP bypass attemperating water control

mode automatically into operation.

2) The control modes of the LP bypass attemperating water include AUTO and MAN; in the

AUTO mode, the outlet temperature of it is automatically controlled at 160 ; in another case,

the outlet temperature is maintained through manually controlling the opening of an

attemperating water valve by the operator. Meanwhile, the automatic control mode of the LP or

HP bypass pressure into operation is to bring the LP bypass attemperating water control mode

automatically into operation.

2.1.8.3 Interlock protection of bypass

1HP bypass pressure reducing valve

Allowable fast-opening conditions:

Pressure to be regulated to greater than or equal to 30% prior to triggering the

fast-opening action

In HP cylinder control before triggering the fast-opening action

Bypass in operation

No fast-closing condition (the fast-closing in prior to the fast-closing)

Trigger conditions of fast-opening

A changeover switch has already put into operation. The HP cylinder control is put

into operation and the steam turbine trips.

Fast-closing conditions:

5s duration at an outlet temperature of the HP bypass valve higher than 3800% opening

2HP bypass spray valve (set temperature ranging from 250 to 330 )

Fast-opening condition: The fast-opening of the HP bypass pressure valve is

available.

Fast-closing condition: The fast-closing of the HP bypass pressure valve is

available.

Less than 2.5% opening of the HP bypass pressure control valve (PCV) is to jointly

close the LP bypass PCV after 5s delay time.

3HP bypass spray isolation valve

1. The spray isolation valve is triggered to open in case that the opening of the HP bypass

valve is greater than or equal to 2.5%;

2. The spray isolation valve is triggered to close after 15s delay in case that the opening of the

HP bypass valve is less than 2.5%.

4LP bypass pressure reducing valve

Fast-closing conditions include but not limit to, the following:

1. Low condenser vacuum

2. High condenser temperature


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3. Low spray pressure of the LP bypass spray valve

4. High outlet steam temperature of the LP bypass spray valve

Fast-closing opening: 0

Fast-opening conditions (the fast-closing in prior to the fast-opening) include, but not limit to,

the following:

1. Reheater pressure more than 4.4Mpa

2. Fast-opening of the HP bypass valve is available.

Opening: The LP bypass pressure valve is put into control mode as it is pre-opened to 80%

and in automatic operation.

5LP bypass spray valve

Fast-closing condition: Fast-closing of the LP bypass pressure reducing valve is available.

Fast-closing opening: 0

Fast-opening condition: Fast-Opening of the LP bypass pressure reducing valve is available.

Opening: The LP bypass pressure valve is put into control mode as it is pre-opened to 80%

and in automatic operation.

6LP bypass spray isolatio

Date post:	04-Apr-2018
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Turbine Operation Manual

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