EPGL Turbine Operation Manual

7/25/2019 EPGL Turbine Operation Manual

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India 2×600MW Salaya

Coal Fired Thermal Power Plant

Operation and Maintenance Manual

Volume I: Operation Manual

Part 1: Operation Manual of Steam Turbine

Harbin Power Engineering Company Limited

Harbin Huitong Electric Power Engineering Co.,Ltd

December, 10th, 2010



Content

1 Technical specifi cations and characteristics of main and auxiliary equipments ofturbine-generator unit ..................................................................................................................3

1.1

Technical speci fications of turbine proper ......................................................................3 1.2

Turbine characterist ic ........................................................................................................5

1.3 Boiler and generator specif ication ...................................................................................5

1.4

Auxi liary speci fi cat ion .......................................................................................................7

1.5 Regulation and protecting system .................................................................................26

1.6

Turbine unit protection ....................................................................................................30

2 Turbine unit start .................................................................................................................31

2.1

Unit star t general rules ....................................................................................................31

2.2 Preparat ion before uni t start ...........................................................................................32

2.3

Test before start ...............................................................................................................33

2.4 Turbine un it cold state start ............................................................................................34

2.5

Unit warm, hot, very hot star t .........................................................................................43

2.6

DEH operation mode explanation...................................................................................44

2.7

Unit stop ...........................................................................................................................45

2.8 Maintaining after turbine stops .......................................................................................49

3 Unit operation and maintenance........................................................................................49

3.1 Operat ion and main tenance............................................................................................49

3.2

Motor normal operation and maintain ing ......................................................................50

3.3 Unit operation mode ........................................................................................................52

3.4

Parameter supervision in normal operation ..................................................................53

3.5 Periodic work ...................................................................................................................60

3.6

Unit interlock protection and test...................................................................................62

4

Unit trouble shooting ..........................................................................................................76

4.1 Principles of trouble shooting ........................................................................................76

4.2 Condi tions and t reatment of emergency stop and treatment ......................................77

4.3

Steam parameters are abnormal ....................................................................................80

4.4 Unit load vibration ...........................................................................................................81

4.5 Unit load rejec tion............................................................................................................81

4.6 Condenser vacuum drop .................................................................................................82

4.7

Unit high vibration ...........................................................................................................83

4.8 Turbine water impact .......................................................................................................84

4.9 Turbine blades break .......................................................................................................85

4.10 Turbine abnormal axial displacement ............................................................................86

4.11

Turbine lubricate oi l system fault ...................................................................................86

4.12

Turbine bearing temperature high ..................................................................................88 4.13

EH oi l sys tem fault ...........................................................................................................89

4.14 Sealing oi l pressure low ..................................................................................................90

4.15

Closed circulating water system fault............................................................................90

4.16 Auxi liary equ ipment faul t ................................................................................................91

4.17

Motor fault ........................................................................................................................92

4.18 Auxi liary power lost ......................................................................................................... 94

4.19

Hydrogen system fault ....................................................................................................95

4.20 Stator cooling water interrupt .........................................................................................96

4.21

Fire ....................................................................................................................................96

4.22 DCS fault...........................................................................................................................97

4.23 Measures avoiding water entering into turbine and bearing bend..............................98

4.24

Measures avoiding turb ine oi l leakage ........................................................................100

4.25

Main steam valve or governor valve blocks after turb ine tr ips ..................................101

4.26 Measures avoiding turbine over speed........................................................................101

1



2

5 Start curve ...........................................................................................................................102

5.1

Cold state curve .............................................................................................................102

5.2 Warm state s tart curve ..................................................................................................103

5.3

Hot state s tart curve ......................................................................................................105

5.4 Very hot state curve.......................................................................................................106

5.5

Recommended values of keeping turbine running speed .........................................107

5.6 Cold state rotor heating curve......................................................................................108

5.7

Hot state start recommended value .............................................................................109

5.8 Main steam parameters during start ............................................................................110

5.9

Changing load recommeded value——fixed pressure mode ....................................111

5.10 Recommeded value of changing load.......................................................................... 111

5.11 Circulating indexes under dif ferent load increase rate and decrease rate ...............112

5.12 Gland sealing steam temperature recommended valves ........................................... 113

5.13

Typical HP cylinder cool ing curve................................................................................114

6

Auxi liary operat ion regulat ions ........................................................................................ 115

6.1

General ...........................................................................................................................115

6.2 Start & stop of circulating water system......................................................................117

6.3

Open cooling water system start and stop..................................................................118

6.4 Closed c irculat ing coo ling water system start and stop ............................................119

6.5

Start & stop of auxi liary steam system ........................................................................121

6.6 Condensing water system start and stop ....................................................................122

6.7

Deaerator star t and stop................................................................................................124

6.8 Motorized feeding water pump start and stop.............................................................127

6.9

Steam driven feed water pump group start & stop .....................................................129

6.10 Heaters star t and stop ...................................................................................................134

6.11 Turbine gland sealing start and stop............................................................................137

6.12 Vacuum system stop .....................................................................................................139

6.13

Turbine lubricate oil system start and stop .................................................................140

6.14 Turbine oil cooler start and stop ..................................................................................142

6.15

EH oil system start and stop.........................................................................................143 6.16 Generator sealing oil sys tem start and stop ...............................................................145

6.17

Generator hydrogen cool ing system start and s top ...................................................148

6.18 Start and stop of generator stato r cooling water system ...........................................152



1 Technical specifications and characteristics of main and auxiliaryequipments of turbine-generator unit

1.1 Technical specif ications of turbine proper

1.1.1 Turbine specifi cations:

Name Specification

Unit Model N600-16.67/538/538

TypeSub-critical, once-middle reheat, single-shaft, three cylinder and four stages

steam extraction, double back pressure condenser type turbine

Rated power 600 MW（TMCR working condition)

Maximum power 647 MW（VWO working condition）

Rated runningspeed

3000 r/min

Running direction (from turbine to generator) clockwise

Working frequency 50 Hz

Steam exhaustpressure

9.60KPa

Flow stages

Total 40 stages

HP cylinder: one (1) single-row governing stage ＋ nine (9) pressure

stages

IP cylinder: six (6) pressure stages

LP cylinder: 2×2×6 pressure stages (two double flow low pressurecylinders)

Turbine outlinedimension

（L×W×H）

27.8×11.4×7.24 m

Final stage bladehighness

680 mm

Elevation fromcenter line to

operation layer1070 mm

Steam distributionmode

Nozzle governing

Starting mode HP-IP combined start-up mode

Feed water heatreturning stage

numberThree HP heaters＋one deaerator ＋four LP heaters

Feed watertemperature

276℃

Rotor Ⅰ stage Ⅱ stageCritical rotating

speed of shaftHP &IP rotor 1704 4181

3



LP rotor A 1648 3859

LP rotor B 1610 3584

Generator rotor 780 2073

Turning gear

running speed

3.35 r/min

Noise level ≤90 dB(A)

Manufacturer Harbin Turbine Co., Ltd.

1.1.2 Main parameters of turb ine designed work ing condi tion

Unit TMCRcondition

TMCRcondition+3% makeup water

TMCRcondition(maximumback-pressure)

VWOcondition

VWOcondition+3%makeup water

All HPheatercut off condition

75%TMCR(Slidingpressure)



Unit output MW 600 600 600 649.748 645.559 600 450.004 360 240.143

Heat rate

kJ/kW

.h 8122.4 8185.6 8269.1 8113.4 8168.2 8393.3 8275.7 8468.5 9047.9Main steampressure

MPa(a)

16.7 16.7 16.7 16.7 16.7 16.7 13.64 11.07 7.64

Reheat steampressure

MPa(a)

3.423 3.434 3.473 3.753 3.728 3.560 2.556 2.068 1.452

Exhaustingpressure of HPcylinder

MPa(a)

3.804 3.815 3.859 4.170 4.142 3.956 2.84 2.297 1.613

Main steamemperature

℃ 538 538 538 538 538 538 538 538 524.7

Reheat steamemperature

℃ 538 538 538 538 538 538 538 531.3 497.6

Main steamflow

t/h 1866.68 1885.03 1908.71 2060 2060 1628.3 1359.21 1086.77 765.21

Reheat steamflow

t/h 1572.73 1579.13 1597.75 1725.9 1716.431603.4

31168.13 945.26 674.75

Averageback-pressure

KPa 9.60 9.60 11.87 9.60 9.60 9.60 9.60 9.60 9.60

Exhaustingflow of LPcylinder

t/h 1122.39 1112.22 1131.1 1226.39 1205.291206.1

1866.36 718.75 518.27

Make-up waterrate

% 0 3 3 0 3 0 0 0 0

Final feedwateremperature

℃ 275.3 275.7 276.5 281.7 281.4 181.1 256.7 244.3 225.1

1.1.3 All stages extraction parameters when turbine in TMCR working condition

Extraction SeriesFlowkg/h

PressureMPa(a)

Temperature

℃

1st extraction (to no.1 HP heater) 128990 6.00 386.7

2nd extraction (to no.2 HP heater) 122580 3.804 325.0

3rd extraction (to no.3 HP heater) 79790 1.84 444.7

4th extraction (to deaerator) 86580 0.878 339.5

4th extraction (to BFP turbine) 92960 0.873 339.4

4th extraction (to aux. steam header) ≤65000 0.873 339.4

5th extraction (to no.5 LP heater) 46950 0.336 226.8

6th extraction (to no.6 LP heater) 46130 0.189 166.6

7th extraction (to no.7 LP heater) 56240 0.099 105.18th extraction (to no.8 LP heater) 58400 0.0391 75.4

4



1.2 Turbine characterist ic

1.2.1 This turbine is sub-critical, once-middle reheat, single-shaft, three cylinders and fourstages steam extraction, condenser type turbine; it adopts reversal type impeller blade,whole forged rotor, multi-layer cylinder and digital electric hydraulic regulation. Its structureis compact and economic with high operation efficiency and safe reliability. This turbine is

used for offer basic load for middle sized power grid and is also suitable for load regulationand supplying basic load for large scale power grid. Life of this unit is more than thirty (30)years. This kind of unit is fit to drought area, use air cooling system. Operation hours peryear of this unit is more than 8000 hours.

1.2.2 #7 bearing in bearing system of turbine generator unit adopt Jingshiboli bearing, #1～6

bearing are four tile tilting-pad bearing. Bearing vibration measuring devices are installedon X and Y up tile of bearings and measuring devices are installed on down bearing.Thrust bearing is in bearing box and it is a equally loaded bearing with automatic and evenload distribution between tiles, pile is supported on fixing inner balancing block composedof two halves.

There’re 3 absolute anchor point of the unit: first is at #2 bearing box, the other two is at

center of #1 and #2 LP cylinder, two horizontal anchor keys and two axial anchor keyspre-buried in foundation limit the moving center of them, which forms absolute anchorpoint of the unit.

HP & IP cylinder are supported by four ‘cylinder claws’, which is built on bearing box.‘Cylinder claw’ can slide freely on keys through cooperation between ‘cylinder claw’ andbearing box.

Flange form steel joint connect rotators, thrust bearing at #1 bearing box which formsrelative anchor point of the unit.

1.2.3 Two steam-driven feed water pumps with BMCR capacity of 50% and one motorizedspeed changing feed water pump with BMCR capacity of 50% for start/standby. Normalworking steam source is from fourth stage extraction steam, steam source for low load

operation and commission is from auxiliary steam system. Exhaust steam of small turbineis extracted to condenser of the turbine.

1.2.4 Three vertical condenser pumps with capacity of 50% are installed in condensing watersystem. Extractive treatment of condensing water adopts IP system. Condenser is singleflow, double back pressure surface type; it has double shells and arranged horizontally.

1.2.5 Open circulating cooling water system and closed circulating cooling water system areadopted as cooling water system. Open circulating cooling water system is from circulatingwater, closed circulating cooling water system supply cooling water to auxiliaryequipments in main hall.

1.2.6 Control oil system of turbine adopts HV fire resistant oil and is completely separated fromlubricate oil system, which improves the speediness of speed regulation system, reliability

and agility.

1.2.7 Unit is designed as HP cylinder starting mode. Bypass system adopts HP, LP bypass oftwo stages in series with capacity of 60% BMCR, which can protect unit operation safely.

1.3 Boiler and generator specif ication

1.3.1 Boiler designed specification

ITEMS UNIT BMCR TMCR

Steam flow rate of superheater outlet t/h 2060 1866.68

Steam pressure of superheater outlet MPa(g) 17.5 17.34

Steam temperature of superheater outlet ℃ 541

541

Steam flow rate of reheater outlet t/h 1725.9 1572.73

5



6

Steam temperature of reheater outlet ℃ 541 541

Steam pressure of reheater outlet MPa. (g) 3.817 3.472

Steam temperature of reheater inlet ℃ 335.0 335.0

Steam pressure of reheater inlet MPa(g) 4.007 3.646

Temperature of feed water ℃ 281.0 275

Flue gas temperature at air preheater outlet(unrevised)

℃ 138 137

Flue gas temperature at air preheater outlet(revised)

℃ 131 131

Boiler efficiency (based on HHV) % 87.1

1.3.2 Generator designed specification

Item Unit Data

Generator type QFSN-660-2YHG

Rated capacity SN MVA 705.88

Rated power PN MW 600

Rated power factor cosφN 0.85(lagging)

Stator rated voltage UN kV 20

Stator rated current IN A 20377

Empty load excitation voltage V 144.2

Empty load excitation current A 1480

Rated excitation voltage UfN V 465.6

Rated excitation current IfN A 4557

Full load frequency η ％ 98.85

Rated frequency Hz 50

Rated running speed r ／min 3000

phase 3

Stator winding connection mode YY

Excitation mode Static self and shunt excitation



1.4 Auxiliary specification

1.4.1 Bypass system

1.4.1.1 HP & LP bypass system

Technical parameter name Unit

Cold

statestart

Warm statestart

Hot statestart

Extreme hotstate start

VWO

working condition

Inlet steampressure

MPa 5.9 5.9 7 8 17.6

Inlet steamtemperature

℃ 340 420 450 485 541

Inlet steam flow t/h 102.3 251.3 259.6 288.5 1236

Outlet steampressure

MPa 1.1 1.1 1.1 1.1 4.17

Outlet steamtemperature

℃ ~200 ~250 ~270 ~300 335.6

Highpressure

steam

change-overvalve

Outlet steamflow

t/h 111 283 293 326 1423

Pressure MPa ~12 ~12 ~15 ~15 23.33

Temperature ℃ 150 150 150 150 180.2

HP spraying

governingvalve

Flow t/h 18 32 34 38 187

Inlet steampressure

MPa 1.0 1.0 1.0 1.0 3.753

7



Technical parameter name UnitColdstatestart

Warm statestart

Hot statestart

Extreme hotstate start

VWO

working condition

Inlet steamtemperature

℃ 300 400 435 470 538

Inlet steam flow(total flow of LP

bypass)t/h 111 283 293 326 1423

Outlet steampressure

MPa 0.04 0.1 0.11 0.12 0.5884

Outlet steamtemperature

℃ 82 99 102 105 160

LPchange-over

valve

Outlet steamflow t/h 2x65 2x177 2x188 2x214 2x968

Pressure MPa 3.16 3.16 3.16 3.16 3.16

Temperature ℃ 46.5 46.5 46.5 46.5 46.5

LP sprayingwater

governingvalve

Flow t/h 2x9 2x35 2x41 2x51 2x257

8



1.4.1.2 Hydraulic actuator

Sort HP bypass

Item Bypass constitutionHP bypass valve

Spraying governingvalve

Sprayingisolation valve

L

Type HBSE280-350 100DSV 840 NBS

Model Angle Angle Through

Drive mode Hydraulic Hydraulic Hydraulic

State after losing electricity Lock-up Lock-up Lock-up

Pressure Mpa 17.6 22.81 23.33 Valvefront

Temperature oC 541 180.2 180.2

Pressure Mpa4.17 4.69 22.81

Valve rearTemperature oC 335.6 180.2 180.2

Maximum differential pressure Mpa 17.6 22.81 23.33

Rated value t/h 1236 187 187

FlowMaximum value t/h - - -

Flow characteristic linear =% On/off

Valve seat diameter mm 199.7 38.1 76.2

Required thrust kN 87 <36 36

Valve stem Stroke mm 145 63.5 40

Valverelated

parameter

Valve material F91 WCB WCB

9



Leakage rate(or grade) V V V

Connection mode BWE BWE BWE

Material F91/F22 G20Mo5 G20Mo5

Inlet mm ID368x38 - -

Joint

Outlet mm OD914x23.83 - -

Weight kg About 2050 About 250 About 250

1.4.1.3 Oil cylinder of bypass valve and spraying valve

High pressure bypass oil cylinder Low pre

NameUnit

High pressurebypass valve

Sprayinggoverning valve

Spraying isolationvalve

Low pressurebypass valve

Manufacturer CCI CCI CCI CCI

TypeGHZ100 GHZ80 GHZ50 GHZ80

Oil pressure MPa16 16 16 16

Diameter mm100 80 50 80

Section area mm2

7150 4320 1650 4320

Force N115752 69000 26380 69000

Journey mm175 65 65 300

10



Quickopen 3

4 4 4

Quickclose

- 4 4 4

Thewhole

journeyactiontime

Adjust

s

15-20 - - 15-20

Weight kg Valve included

1.4.1.4 Working oi l station equipment

NO. Name Item Unit Number NO. Name Item

Type QX Type

Model Internal gear pump Quant

Quantity Set 2 Powe

Rated oilpressure

MPa 24 Voltag

Rated flow l/min 7.2 Freque

Rotatingspeed

r/min 1420 Rotating s

1 Oil pump

Manufacturer Truninger

5Oil pump

motor

Manufac

Type AX Type

Quantity Set 1 Quant

Workingpressure

MPa 0.1 Capabi

2 Oil tank

Volume l（liter ） 190

6 Accumulator

Working pr

11



12

Maximum oilstorage

l（liter ） 310Safety valv

pressu

Outerdimension

mm 1100*600*600Bufferi

medium/pr

Weight kg 505Maintain tim

power

Outer dime

Type Hydac Group qu

Strainermaterial

Fabric Powe

Straineraperture

μm 10

7 Electric heater

Voltage/p

Permit

differentialpressure

MPa 0.2 Quant

Outerdimension

mm 100*200 powe

3 Filter

Weight kg 0.3

Type Internal gear pump Voltag

Quantity set 2

Rated oilpressure

MPa 24Freque

Rated flow l/min

speed r/min 1420Rotating s

4Filter

pump

Manufacturer Truninger

8Filter

pump motor

Manufac



13

1.4.2 Turb ine lube oil system

Mail oil tank

Type Horizontal cylinder Volume 45.7 m3

Oil type 32L-TSA/GB11120-89turbine oil Outer dimension φ3032×7000

Mail oil pump

Type Double suction centrifugalpump

Outlet pressure 2.352MPa(g)

Flow 7600L/min Suction pressure 0.1764 MPa

Runningspeed

3000 r/min Manufacturer Harbin Turbine Co., Ltd

Oil tank gas exhausting air fan

Air amount 824m3/h Head 3530pa

Motor type YB90L-2 Power 2.2kw

Turning speed 2840r/min Voltage 415V

Hydrogen seal oil pump

Type SNH660-51T4 Flow 753 L/min

Outletpressure

1.0 Mpa Rotating speed 1450 r/min

Manufacture Zigong dongfang

Motor type YB180M-4 Power 18.5 kW

Voltage AC 415V Running speed 1450 r/min

Insulationgrade

F

AC lube oil pump

Type Vertical centrifugal oil pump Type LDX294-44

Flow 4900 L/min Outlet pressure 0.37 MPa

Rotatings eed

1450 r/min

Motor type YB250M-4 Power 55 kW

Voltage 380v Running speed 1450 r/min

Insulationgrade

F

DC lube oil pump

Type Vertical centrifugal oil pump Type LDX294-44

Flow 4900 L/min Outlet pressure 0.37 MPa（g）



14

Runnings eed

1500 r/min

Motor type Z2-91 Power 55kW

Voltage 220v Insulation grade F

Runnings eed

1500 r/min

#I Oil injector

Outlet flow 5660L/min Power oil pressure 2.27MPa

Outletressure

0.23MPa

#II Oil injector

Outlet flow 4950L/min Power oil pressure 2.27MPa

Outlet

pressure 0.37MPa

Turbine oil cooler

Type Plate type Type MX25-MFMS

Oil flow 322m3/h cooling area 2 X348.1m

2

Cooling waterflow

581.5 m3 /h Manufacturer APV

Inlet /outletoil temp.

65℃/45℃

Jacking oil pump

Type AH37-FR01KK-10-X33 Quantity 2 sets

Capacity 3.7 m3/h

Outlet maximumpressure

32 MPa

Manufacturer Nichiyu Giken Kogyo Co., Ltd

Motor type YB2-200L-4 Power 30 kW

Voltage 415V Rotating speed 1470r/min

ManufacturerNanyang explosion-proof

group

Lube oil transfer pump

Oil pump Motor

Type KCB-1000 Type YB200L-4

Head（MPa） 0.6 Voltage (V) 415

Capacit（m3/h） 60 Power (KW) 30

Manufacturer Zigong dongfangRotating speed

（r/min） 1450



15

Oil purification device

Type LYJ-8 Flow 7800L/h

Working Oiltemp.

50～65℃ Filter fineness ≤5μm

Heatingpower

48kW Manufacture Zigong chuanlv

Turbine turning gear motor

Type YB280S-6 Power 45 kW

Voltage 415 V Current 85.4 A

Rotatingspeed

980 r/min Insulation grade F

Turning gear

speed3.35 r/min

1.4.3 EH oil sys tem

EH oil pump

Model Piston variation pump Type HQ31.01Z

Flow（maximum） 6.6 m3/h Outlet pressure 31.5MPa

Rotating speed 1450 r/min Working pressure 14MPa

EH oil pump motor

Motor type M2JA-225 Power 45 kW

Voltage 415 V Current 84.7 A

Rotating speed 1450 r/min

EH oil tank

Model Container type Capacity 1.3 m3

Oil type Fyrquel EHC-plus Manufacturer Harbin Turbine Co., Ltd

EH oil cooler

Model Plate type Cooling area 2×4.2m2

Workingtemperature

≤38℃(water

temperature )

Workingpressure

0.2～0.5 MPa(water pressure)

Manufacturer Shanghai



16

1.4.4 Steam driven feed water pump group

Small turbine

Model

Single shaft, singlecylinder, auxiliary

steam out change,

condensing type

Running speedcoordination

control range

3000～5900 r/min

Type NGZ83.6/83.5/06Turning gear

speed40.8 r/min

Control system MEHMax. rotating

speed5900r/min

Flow stages 6 stageMaximumcontinuous

power9MW

Exhaust pressure 11.1kPaRunningdirection

Clockwise(see from turbinehead to pump)

Mechanical overspeed

6160 r/minElectric over

speed6050r/min

1 stage 2246r/minCritical rotating speed

2 stage 6532 r/min

ManufacturerHarbin Turbine Co.,

Ltd.

Steam source

fourth extraction, auxiliarysteam two lines

Low pressure steam:

0.834Mpa/338.5℃

Auxiliary steam:

0.8MPa/300℃

Steam driven feed water pump

ModelHorizontal

centrifugal pumpType CHTC6/5

Seal type Mechanical sealingRunningdirection

Clockwise from driven end topump

Flow（m3/h） 1179 Head（m） 2368

Shaft power （KW） 9012.5

Inlettemperature

（℃） 171.4

Tap Pressure(MPa) 10.5 Tap flow(t/h) 49

Rotating speed（r/min） 5074 Efficiency（%） 82.3

ManufacturerShanghai Kaishibi

Pump

Small turbine oil system

Small turbine AC lube oil-pump motor Small turbine DC emergency oil-pump motor

Type YB160L-2 Type Z2-51

Power 18.5kw Power 10kw

Voltage 415 V Voltage 220 V

Rotating speed 2950 r/min Rotating speed 3000r/minManufacturer Shenyang pump company



17

Small turbine AC lube oil pump Small turbine DC lube oil pump

Type 2LYD-100 Type 2LYD-50

Characteristic centrifugal Characteristic centrifugal

Flow 500L/min Flow 400L/min

Outlet Oil pressure 0.75MpaOutlet oilpressure

0.34Mpa

Rotating speed 2950r/min Rotating speed 3000r/min

Small turbine lube oil transfer pump

Type KCB-200 Capacity 12m3/h

Head 0.6MPa ManufactureZigong chuanlv equipment

Co.,Ltd.

Motor type YN132S-4 Voltage 415V

Power 5.5kW Rotating speed 1450r/min

Power factor 0.7

Turning gear motor

Type YB132S2-2 Rotating speed 2900r/min

Power 7.5KW Voltage 415V

Steam pump booster pump

Type SQC300-670 Flow（t/h） 1179

Inlet temperature（℃） 171.4 NPSH_R（m） 4.2

Head（m） 134Running speed

（r/min） 1490

Efficiency（%） 82.5 ManufacturerShanghai Kaishibi Pump Co.,

Ltd.

Steam pump booster pump motor

Type YKS450-4 Power 710 kW

Voltage 3.3kV Current 150A

Rotating speed 1490 r/minInsulation

gradeF

Power factor 0.87Connection

method Y

Manufacturer Jiamusi Motor Co., Ltd.

1.4.5 Motor-driven feed water pump group

Main pump

ModelSleeve type multi-stage

centrifugal pumpType CHTC6/5

Seal type Mechanical seal Inlet flow（t/h） 1179

Inlet temperature

（℃）

171.4 Inlet pressure

（MPa）

2.267

Outlet pressure

（MPa） 23.088 Head（m） 2368



18

Tap pressure

（MPa） 10.5 Tap flow（t/h） 49

Efficiency（%） 82.3Rotating speed

（r/min） 5074

Running directionclockwise（from driven

end）

Manufacturer Shanghai Kaishibi Pump Co., Ltd.

Feed water pump motor

Type YKS1000-4TH Power 13000 kW

Voltage 11kV Current 762A

Rotating speed 1496 r/min Power factor 0.916

Efficiency（%） 97.7 Manufacturer Shanghai Motor Co., Ltd

Booster pump

ModelSingle stage

double-suction shellpump

Type SQN300-670

Flow（t/h） 1179 Head（m） 134

NPSH_R (m) 4.2Rotating speed

（r/min） 1490

Seal type Mechanical seal ManufacturerShanghai Kaishibi Pump

Co., Ltd.

Efficiency（%） 82.5

Hydraulic coupling

Type R18K-500MRated Input

running speed1490 r/min

Maximum outputrunning speed

5032 r/minSpeed

adjustment range25％～100％

Gear ratio 111/32 Driver power 8685kW

1.4.6 Deaerator

Type GC-2180 Model Horizontal type deaerator

Designedpressure

1.07 MPa Maximumworking pressure

0.8564MPa(a)

Designedtemperature

345 oCMaximumworking

temperature340.3 oC

Total capacity 345 m3 Efficient capacity 235 m3

Rated output 2180 t/h Maximum output 2400 t/h

Nozzle pressure

drop0.014MPa

Safety valve openpressure

1.0 MPa

Manufacturer Shanghai Electrical Power Station Equipment Co., Ltd.



19

1.4.7 Condensing equipment

1.4.7.1 Condenser

Condenser

Type N-38000-13 Cooling area 38000 m2

ModelDouble shell and single

flow, double backpressure

Cooling wateramount

70980m3/h

Back pressure 0.0096KPaWater chamberdesign pressure

0.46MPa(g)

Condensate overcooling degree

≤0.5℃ Condenser end

difference(LP / HP) 4.7/4.5℃

Condenser copperpipe total quantity

41248 Pieces Cooling medium Sea water

Cooling water

temperature 33℃

Manufacturer Harbin Turbine Co., Ltd.

1.4.7.2 Condenser water pump

Condenser water pump

Model Vertical sleeve type pump Type B640Ⅲ-6

Head（m） 339.6 Seal type Mechanical seal

Flow （m3/h） 823 Required steamcorrosion sur lus

2.69m

Manufacturer Changsha Water Pump

Co., Ltd

Pump running speed

（r/min）

1480

Condensate water pump motor

Type YKKL500-4TH Power 1120 kW

Voltage 3.3kV Current 233A

Running speed 1500 r/min Power factor 0.89

Manufacturer Xiangtan Motor Co., Ltd Insulation grade F/B

1.4.7.3 Circulating water sump drainage pump

Circulating water pump

Type LCX100-20 Model Vertical

Flow 40m3/h Head 20m H2O

Manufacturer Shanghai kaiquan Pump Co., Ltd

Motor type Y2132S2-2 Rotating speed 1450 r/min

Voltage 415V Power 7.5 KW



20

1.4.7.4 Sponge ball cleaning device

Sponge ball pump

Type IZJ125-18BⅢ Model Horizontal type

Flow 110 m3/h Head 18 mH2O

Motor type Y60L-4 Rated power 15KW

Rated voltage 415 V Rotating speed 1460 r/min

Protected stage IP55

Ball collector

Type DZQS-1012 Model Vertical cylinder

Diameter Ф480

Ball screen

Type WBS-2200 Model Horizontal

Diameter Ф2228

1.4.7.5 Water-ring vacuum pump

Water-ring Vacuum pump

Type TC11EExtractionamount

≥78kg/h

Min. suction pressure 3.4KPa(a) Running speed 590 r/min

Stage 2 stages Manufacturer Jidina mechanical Co., Ltd.

Vacuum pump motor

Type Y2 355M-10TH Voltage 415V

Rated Power 132KW Protected stage IP54

Insulation grade F Running speed 590 r/min

Manufacturer Beijing Huajie Motor Co., Ltd.

1.4.8 Sealing oil system

Seal oil pump

Item AC/DC seal oil pump at air side AC/DC seal oil pump at sealing oil side

Type 3GR85×2 3GR42×4A

Model Cubage Cubage

Flow 2×40 m3/h 2×10.5 m3/h

Outlet pressure 1MPa 1MPa

Shaft power 18 KW 4.9 KW



21

Manufacturer Tianjin Dingjia Indusrial PumpCo., Ltd.

Tianjin Dingjia Indusrial Pump Co., Ltd.

Item Alternate current oil pumpmotor at air side

AC oil pump motor at hydrogen side

Type 180L-4 Y132S1-2

Power 22KW 5.5KW

Voltage 415V 415V

Current 44.5 11.1

Running speed 1470 2900

Manufacturer Harbin Motor Co., Ltd. Harbin Motor Co., Ltd.

DC oil pump motor at air side DC oil pump motor at hydrogen side

Type Z2-62 Z2-41

Power (kW) 22KW 5.5KW

Voltage 220V/110V 220V/110V

Current (A) 113.7 30.3

Running speed(r/min)

3000 3000

Manufacturer Harbin Motor Co., Ltd. Harbin Motor Co., Ltd.

1.4.9 Stator cool ing water system

Stator cooling water pump

Type centrifugal Flow 115t/h

Head 75m Rotatingspeed

2970 r/min

Manufacturer Jiangsu changzhou

Stator cooling water pump motor

Type Y225M-2 Power 45 kW

Voltage 415V Current 84A

Runningspeed

2970 r/min Manufacturer Changzhou power station auxiliaryequipments factory

1.4.10 Heater and pressure container

1.4.10.1 HP heater

Item Unit #1 HP heater #2 HP heater #3 HP heater

Type JG-2250-3-3 JG-2680-3-2 JG-2070-3-1

Model Horizontal type

Manufacturer Shanghai power station equipment Co.,Ltd.



22

Heater total area m2 2550 2680 2070

Steam coolingsection heat

exchange aream

2316 245 232.5

Condensingsection heat

exchange aream2 1899.5 1996.5 1401.8

Drainage watercooling sectionheat exchange

area

m2 334.5 438.5 435.7

Designed pressureat shell side

MPa 6.96 4.35 2.05

Designedtemperature at

shell side

℃ 414.2/286.4 349.1/256.7 459.5/216.1

Designed pressureat pipe side

MPa 30 30 30

Designedtemperature at pipe

side

℃ 286.4 256.7 216.1

Test pressure atshell side

MPa 11.3 6.87 3.65

Test pressure ati e side

MPa 45.53 45.53 45.53

Feed water enddifference (TTD)

℃ -1.7 0 0

Drain enddifference (DCA)

℃ 5.6 5.6 5.6

Flow t/h 1875.12 1875.12 1875.12

Inlet temperature ℃ 245.8 206.9 177.0

Outlet temperature ℃ 275.6 245.8 206.9

Heating steam flow t/h 129.81 123.41 80.30

Heating steampressure

MPa 5.852 3.706 1.793

Heating steamtemperature

℃ 387.4 325.8 444.7

Drainage watertemperature

℃ 251.4 212.5 182.6



23

1.4.10.2 LP heater

Item Unit #5 LP heater #6 LP heater #7 LP heater #8 LP heater

Type JD-1418-15 JD-1106-24 JD-640-21 JD-764-21

Model Single row horizontal type

Manufacturer Harbin steam turbine Co., Ltd.

Heat transfer area m 1418 1106 640 764

Designedtemperature at shell

side

℃ 300 200 120 95

Designed pressureat shell side

MPa 0.6 0.6 0.6 0.6

Design temperatureat pipe side

℃ 150 150 110 90

Designed pressure

at pipe side

MPa 4.0 4.0 4.0 4.0

Condensing flow t/h 1554.83 1554.83 777.35 777.35

Heating steam flow t/h 52.55 51.48 31.38 33.475

Working pressure atshell side

MPa 0.351 0.198 0.104 0.041

Workingtemperature at

shell side

℃ 227.4 167.3 100.6 76.4

Working pressure atpipe side

MPa 3.35 3.35 3.35 3.35

Workingtemperature at pipe

side

MPa 136.2 117.1 97.9 73.5

1.4.10.3 Gland sealing steam heater

ModelHorizontal surface

coolingType LQ-150-7

Designed pressure(pipeside)

4.6 MPaDesigned pressurevacuum(shell side)

0.3 MPa

Designedtemperature(pipe side)

90℃ Designed

temperature(shell side)300℃

Maximum workingpressure(pipe side)

3.2 MPaMaximum working

pressure(shell side)0.095 MPa

Cooling area 150 m2

Steam side flow 1.46 t/h

Cooling water amount 1662.23 t/hCooling water pipe

dimension25×1.0 mm

Materialstainless steel

TP304Manufacturer

Harbin Turbine Co.,Ltd.



1.4.10.4 Gland sealing heater air fan

Gland steam heater air fan

Type 17Y30-1000-11L Original motorpower

11KW

3 kPa Flow 1800 m3/hFull pressure

Manufacturer Yuhang Special Air fan Co.,Ltd.

Running speed 2930 r/min

Gland sealing heater air fan motor

Voltage 415V Power 11 kW

Runningspeed

2930 r/min Insulation grade F

1.4.10.5 Auxil iary steam header

m3 3.2Capacity

Working pressure Mpa 1.0

℃ 250～335Working temperature

Mpa 1.6Designed pressure

℃ 350Designed temperature

Manufacturer Changshu HP container Co.,Ltd.

1.4.10.6 Continuous f lash tank

m3 6Capacity

Designed pressure Mpa 1.6

℃ 220Designed temperature

Manufacturer Changshu HP container Co.,Ltd.

1.4.11 Open/closed cooling water

1.4.11.1 Open cooling water

Open cooling water pump

Type KPS20-600 Head 0.1MPa

Flow 2330 m3/h Shaft power 72 kW

590 r/min Efficiency 89.3％ Running speed

Water inletpressure

~0.2 MPaWater inlet

temperature33℃

NPSH_R 4.5m Manufacturer Guangdong foshan water

pump factory

Open cooling water pump motor

Type Y3 315L2-10 Power 90 kW

Voltage 415VInsulation

gradeF

24



25

Running speed 590 r/min Manufacturer Jiamusi Motor Co., Ltd.

Open circulating water filter

Type LDS-800 Type LDS-350

Designed flow 2330 t/hDesigned

flow 660t/h

Working flow 2110t/h Working flow 581.5t/h

Driven Power 1.1 KWDrivenPower

0.55kW

Strainer aperture Ф2 mmStraineraperture

Ф2 mm

Designedpressure

0.6 MPa(g)Designedpressure

0.6 MPa(g)

Working pressure ～0.2MPa(g)Working

pressure～0.2MPa(g)

Manufacture Zigong dongfang filter Co.,Ltd ManufactureZigong dongfang filter

Co.,Ltd

1.4.11.2 Closed cooling water

Closed cooling water pump

Type KPS50-350 Head 0.5 MPa

Flow 1780 m3/h Running speed 1480 r/min

Shaft power 282 kW Efficiency 87.8 ％

Water inletpressure ~0.2 MPa Water inlettemperature 45℃

NPSH_R 5.6 m ManufacturerGuangdong foshan water pump

Co., Ltd.

Closed cooling water pump motor

Type YKK4003-4 Power 315kW

Power factor 0.86 Current 175 A

Voltage 3.3KV Rotating speed 1483 r/min

Efficiency 93.3 ％ Manufacturer Jiamusi Motor Co., Ltd.

Closed cooling water heat exchanger

Model Plate type Type CZ450A

Designpressure

1.0/1.0MPa(pipe/shellside)

Cooling waterFlow

1989t/h

Heat transferarea

618.19m2 Manufacturer APV Co., Ltd. (China)

1.4.12 Other equipments

Boiler water circulating pump cooling water

Emergency shutdown cooling water pump

Type AZ50-315 Head 100m H2O



26

Running speed 2960 r/min Manufacturer Shanghai kaiquan pumpCo. Ltd.

Emergency shutdown cooling water pump motor

Voltage 415V Power 30kW

Running speed 2940 r/min Insulation grade F

1.5 Regulation and protecting system

Turbine regulation and protecting system can be divided into: mechanical emergencygovernor, HP & LP interface device (diaphragm valve), HP fire resistant fuel oil system andsafety supervision protection system.

1.5.1 ResetTwo reset methods: manual and remote control

1.5.1.1 Remote control: the lights indicated DEH reset and RSV actuator open shall be lighted by

pushing the reset button in control room. If unit fails to be reset, it shall be checkedwhether 0.7MPa protection oil pressure has been established in diaphragm valve upperchamber and whether 20/ASR solenoid valve has been energized by using iron wire orsaw blade. If there is no excitation, the solenoid valve has not been energized by DEH.

1.5.1.2 Local control: the reset handle shall be wheeled counterclockwise by hand and thenloosened slowly which make handle back to normal position. If 0.7MPa protection oilpressure has been established in diaphragm valve upper chamber, unit successfullyresets.

1.5.2 Breaking

Three redundant breaking methods of electric, mechanical & manual are installed in speedgoverning protecting system.

1.5.2.1 Electric stop

The function is completed by HP breaking module. Once electric stop signal is received,HP breaking module lose power until HP protecting oil is discharged, all the main steamand regulation valves are closed, which stops steam feeding to the turbine.

1.5.2.2 Mechanical over-speed protection

Mechanical over speed and manual trip deviceMechanical over speed and manual trip device consists of emergency governor, pilot valveof emergency governor and safety operation device.Emergency governor, pilot valve of emergency governorEmergency governor shall be equipped with one set of centrifugal stop bolt, which controlspilot valve of emergency governor. When steam turbine operation speed reaches to110%-112% of rated speed, centrifugal force of centrifugal stop bolt overcomes therestriction force of spring and throws the centrifugal stop bolt outward striking pilot valvetrigger which make pilot valve move towards right and then protection oil is connected withdrain to open diaphragm valve rapidly.Pilot valve of emergency governor that is installed inside front bearing housing is thecontrol and test device in emergency trip system, and it includes one trip pilot valve, onetest isolation pilot valve, one manual trip lever and one test lever.Test isolation pilot valve could be used to isolate pilot valve of emergency governor fromLP protection oil header. During oil injection test, test stop valve could be opened bymanual to allow pressure oil coming into the chamber beneath centrifugal stop boltthrough nozzle, and centrifugal stop bolt overcomes the restriction force of spring flyingoff.

1.5.2.3 Manual stop A manual shutoff valve id installed for emergency stop in front of turbine head. Press theshutoff button manually to discharge the lube oil above diaphragm valve, open diaphragm



27

valve to discharge HP protecting oil and close all main steam valves, regulation valvesquickly to stop feeding steam.

1.5.3 EH (electro-hydraulic ) system As per the function, EH control system could be constituted of three parts, which are EHfluid supply system, actuators and emergency trip part.

1.5.3.1 EH fluid supply systemEH fluid supply system can be divided into EH fluid supply device, self-circulation coolingsystem, fluid regeneration system as well as EH fluid piping & accessory.The main function of EH fluid supply system shall be to supply necessary hydraulic powerto actuators, and maintain the normal physical chemistry characteristics of hydraulic fluid.

1.5.3.2 Actuators Actuator part shall be constituted of two MSV (main stop valve) actuators, two RSVactuators, four GV (governor valve) actuators and four ICV (reheat interceptor valve)actuators.

1 RSV actuator

Two RSV actuators equipped with valve activity testing solenoid valve shall beinstalled on RSV at unit side. RSV actuator shall be of “ON-OFF Control” type.RSV actuator will receive the control signal from DEH system, and a plug-in typedump valve is installed on the actuator. Should emergency condition occur duringsteam turbine operation, auto stop emergency trip (AST) fluid is discharged so thatdump valve will open immediately to discharge the pressure fluid at working chamberof actuator cylinder and RSV will close quickly by spring force.There is an activity testing solenoid valve (2 position, 2 way) on actuator, which isconnected with cylinder working chamber and return fluid. When valve activity test isperformed, DEH control device will send out a signal to make the solenoid valve openfor discharging part of pressure fluid in cylinder working chamber, then RSV is closedby spring force to perform valve activity test.

2 MSV actuator

MSV actuator is “Proportional Control” type actuator, which can control MSV at anyposition and control steam admission to meet steam turbine operation requirement

according to control requirement.DEH control signal drives servo valve to move main valve core and control servovalve pass to make HP fire resistant fluid go into actuator working chamber to moveactuator piston, and finally to open MSV or to discharge pressure fluid from workingchamber to close MSV through piston converse movement by spring force. Whenactuator piston moves, it will drive two linear displacement transducers (LVDT) totransform actuator piston displacement into electrical signal (as feedback signal) plusthe aforesaid signal after computer treatment; however, it’s actually minus each otherbecause of the opposite polarity. Only in the condition of original input signal plusfeedback signal to make input servoamplifier signal zero and main pilot valve of servovalve be back to center position without high-pressure fluid coming into workingchamber, MSV will stop moving and remain at a new working position.

A plug-in type dump valve is installed on MSV actuator. Should emergency stopcondition occur during steam turbine operation, emergency trip system will act todischarge AST header fluid so that dump valve will open immediately to discharge thepressure fluid at working chamber of actuator cylinder and MSV will all close quicklyby spring force.

3 GV, ICV actuator

GV ,ICV actuators are “Proportional Control” type actuators, which can controlGV,ICV at any position and control steam admission to meet steam turbine operationrequirement according to control requirement.The control principle of servo valve shall be the same as that of MSV actuator.The GV actuator is equipped with one plug-in type dump valve. When steam turbinerunning speed exceeds 103% of rated speed or emergency stop caused by failure

happens, after emergency trip system acts over speed protection control (OPC)header fluid will be discharged, dump valve will open immediately to dischargepressure fluid inside actuator working chamber and each GV will be closed quickly by



28

spring force.The control principle of ICV actuator shall be the same as that of GV actuator.

1.5.3.3 Emergency tr ip protection sys temFor avoiding serious damage accident of unit caused by failure of some equipment duringsteam turbine operation, emergency trip protection system shall be prepared for the unit.

1 Emergency trip testing device

Emergency trip testing device shall be constituted of one EH oil pressure test block, onebearing oil pressure test block, two condenser vacuum test block and two BOP & EOPstart test block, which could be on-line tested and maintained.

2

OPC/AST solenoid valve unit

OPC/AST solenoid valve unit consists of two OPC solenoid valves (20/OPC-1、2), two

check valves, four AST solenoid valves (20/AST-1、2、3、4) and one control block. Two

OPC solenoid valves are in the parallel arrangement, and four AST solenoid valves arein the series-parallel arrangement. When turbine speed exceeds 103% of rated speed,OPC acting signal will be sent out. OPC solenoid valves open when they are energizedso that OPC header fluid drains to EH fluid reservoir through no pressure return (DV)fluid line. In that case, discharge valve of the corresponding control valve actuator willopen fast so that each HP control valve will be closed immediately.

When emergency happens to unit, AST signal will be sent out. Four AST solenoidvalves will open for losing power so that AST header fluid drains to EH fluid reservoirthrough DV fluid line. In that case, dump valves of main steam valve actuator andcontrol valve actuator will open fast to close each steam valve immediately.

3 Diaphragm valve

Diaphragm valve provides an interface between the HP fire-resistant hydraulic fluid andLP turbine oil, thus the LP over speed tripping can be accomplished by the diaphragmvalve to shutdown the steam turbine.

4

Mechanical over speed and manual trip device

Mechanical over speed and manual trip device consists of emergency governor, pilotvalve of emergency governor and safety operation device.Emergency governor shall be equipped with one set of centrifugal stop bolt, which

controls pilot valve of emergency governor. When steam turbine operation speedreaches to 110%-112% of rated speed, centrifugal force of centrifugal stop boltovercomes the restriction force of spring and throws the centrifugal stop bolt outwardstriking pilot valve trigger which make pilot valve move towards right and then protectionoil is connected with drain to open diaphragm valve rapidly.Pilot valve of emergency governor that is installed inside front bearing housing is thecontrol and test device in emergency trip system, and it includes one trip pilot valve, onetest isolation pilot valve, one manual trip lever and one test lever.Safety operation device provides remote reset solenoid valve and reset air cylinder forunit. When it receives DEH reset signal and air cylinder moves upwards pushingconnecting rod of emergency governor pilot valve, pilot valve of emergency governorresets.

1.5.4 Turbine supervisory inst rument system

TSI is an reliable multi-way supervision system for supervising generator-turbine unit rotorand mechanical working parameters continuously.

1.5.4.1 Casing expansion measurementWhen the unit turns into temperature rise and on-load conditions from cold condition,changes of temperature will certainly cause casing expansion. Casing expansionmeasurement is performed to measure casing’s axial expansion value in the directionfrom the dead point to front bearing box, and the front bearing box can move freely alongthe longitudinal key for filling lubricants. When casing expansion occurs, if the movementof unit’s free end on the guide key is blocked, the unit will be severely damaged. Actually, casing expansion measurement is performed to measure the movement value of

bearing box relative to the dead point (foundation) and record casing’s expansion &contraction values under start-up, shut-down and load & temperature change conditionsof the unit. If the indicated values are abnormal under these transient conditions, then



29

operation personnels shall analyse them. Under similar load, steam parameters andvacuum conditions, the relative positions of front bearing box indicated by this instrumentshall be identical basically.

1.5.4.2 Axial displacement measurementThis device indicates and records the axial displacement of rotor thrust disc relative to theaxial position of bearing seat, to monitor the abrasion conditions along the thrust direction

and of thrust bearing pad. For the existence of steam, thrust disc applies axial pressure tothe thrust pads on its two sides, which will cause bearing pad abrasion, and the axialdisplacement due to this bearing pad abrasion will be displayed on TSI measurementdevice. Each measurement block is equipped with alarm and trip switching value outputs,which will alarm automatically once the rotor’s axial displacement exceeds the first presetposition. If the rotor’s axial displacement value exceeds the second preset position, thentripping relay will operate to trip out the turbine.

1.5.4.3 Differential expansion measurementWhen steam enters into turbine, the rotating & static parts will expand along with steam.For the rotor can be heated, it will also expand faster. Although the axial clearancesbetween rotating and static parts allow certain differential expansion inside the turbine, itwill cause abrasion and even crash of rotating and static parts if the differential expansion

exceeds allowable limits.Differential expansion measurement is performed to show the relative displacement ofrotating and static parts, and continuously indicate the axial clearances of turbine duringoperation. The measurement blocks are equipped with alarm and trip outputs, and therelay will operate when axial clearances reach the limits due to differential expansion. Aftera transient process, temperatures of rotating and static parts will gradually tend to be thesame, and differential expansion reduces accordingly. Then, it is permitted to change thesteam flow and temperature for another time.

1.5.4.4 Rotor eccentricity measurement

This device is used to indicate and record the rotor eccentricity with a rotating speed lessthan 600rpm. When turbine’s rotating speed is more than 600rpm, this device can beswitched off automatically by rotating speed signal controls.If it is possible to measure at

bearing oil retainer with portable rotor eccentricity meter, the double amplitudeeccentricity value measured before turbine rotation impulsing should not exceed0.025mm.. The rotor eccentricity measurement is equipped with alarm signal outputs,which will alarm when eccentricity value reaches the limits.

1.5.4.5 Vibration measurement

Vibration measurement instrument is used to measure and record vibration of rotors with

rotating speed higher than 600r ／min. A couple of eddy current sensors vertical to each

other and a bearing pad vibration probe fixed vertically are installed at each bearing seatof this turbo-generator unit, and signals from sensors are connected to turbinesupervisory instruments, which will measure the rotor’s vibration value directly. Excessivevibration indicates that accidents of turbine may occur or that turbine is operatingabnormally. Each vibration measurement is equipped with alarm and trip switching value

outputs, and relay will operate accordingly when excessive vibration value is measured onany bearing.TSI can supply the vibration signals to vibration analysis and failure diagnosis systemTDM via buffer outputs for performing analysis, diagnosis, dynamic balance, etc. of unitvibration.

1.5.4.6 Key phase measurement

Key phase signals show the angular relation between the protruding position of certainbearing and one reference point on the rotor. TDM system can accurately calculate thephase of rotor vibration via key phase signals.

1.5.4.7 Speed & zero speed measurement

Speed indicator is provided with the function of monitoring the shaft rotating speed

continuously. There is rotating speed sensor arranged in front bearing box, and speedindicator receives signals from eddy current probe, after that, it calculates the speed inRPM. When the speed drops to zero, it will send an interlock signal to automatic barring



30

gear to start the barring gear.When the rotating speed exceeds certain preset value, relevant relay will operate tocontrol water spray device and jacking device of steam exhaust casing.

1.6 Turbine unit protection

1.6.1 Over speed protection

1.6.1.1 OPC overspeed limitation

DEH

When the unit running speed exceeds 103% of rated running speed or is under load ofmore than 30% rated load and the oil switch trips, OPC solenoid acts and dischargesprotecting oil pressure of oil-servo motor under HP & IP speed regulation valves andclose HP & IP speed regulation valves quickly.

1.6.1.3 Electric overspeed protection

When running speed reaches to 110% of rated running speed, over speed protecting

signal from the electric is sent to ETS, which makes 20－1/AST—20－4/AST shutoff

solenoid valve lose power and open to discharge HP protecting oil, the HP & IP automaticmain steam valve and speed regulation valve close to stop the unit.

1.6.1.2 Mechanical overspeed protection

A mechanical shutoff protecting system consists of emergency governor, emergencybreaking oil valve, constant close & constant open solenoid valve, orifice plate anddiaphragm valves installed at turbine head inside of front bearing box of turbine unit.Emergency breaker runs with the same speed of main bearing. When turbine running

speed reaches to rated running speed (110～112％), the flying hammer of emergency

governor flies out under effect of centrifugal force of the flying hammer of emergencybreaker, which strikes on emergency breaking oil valve damper and makes the pothookdrop; meanwhile, under the force of bottom spring, sliding valve of emergency breakingoil valve upspring quickly, which opens LP protecting oil discharging orifice and closesmain steam valve and steam regulation valve quickly to stop the unit.

1.6.2 ETS (Turb ine emergency trip sys tem)

ETS receives alarm or stop signals from TSI system or other system of turbine-genratorunit for logical treatment and outputs signal indicating or turbine shutoff signal. ETSsends stop instructions under following situations:

1.6.2.1 When turbine is over speeding to 3300rpm.

1.6.2.2 When condenser pressure is more than 65Kpa.

1.6.2.3 When axial displacement is more than +1.0mm or less than -1.0mm.

1.6.2.4 When lube oil pressure is as low as 0.049Mpa.

1.6.2.5 HP /LP casing expansion difference reachs to +11.1mm or -5.1mm.

1.6.2.6 LP casing expansion difference reachs to +27.8mm or -4.3mm.

1.6.2.7 When generator trips.

1.6.2.8 When boiler MFT.

1.6.2.9 When EH oil pressure is as low as 8.5MPa.

1.6.2.10 DEH is in fault (power off).

1.6.2.11 ETS is in fault (power off).

1.6.2.12 X or Y bearing vibration of any bearing of #1～8 is ≥250μm.

1.6.2.13 Stop unit manually by button on standby manual operation panel.

1.6.2.14 Stop turbine remotely.

1.6.2.15 Local STOP button in turbine hall.



31

2 Turbine uni t start

2.1 Unit s tart general rules

2.1.1 Unit start states can be divided into

Unit start adopts HP, IP cylinder combined mode, turbine should adopt single valve

control mode during first six (6)-month operation. Five (5) start state are decided by firststage temperature of HP cylinder:

Cold state start: first stage metal temperature ＜120℃ and after long term stop;

Warm state-1 start: 120℃≤ first stage metal temperature ＜260℃ and turbine stops for

more than 72 hours;

Warm state-2 start: 260℃≤ first stage metal temperature ＜415℃ and turbine stops from

10 to 72 hours;

Hot state start: 415℃≤ first stage metal temperature ＜450℃ and turbine stops from 1

to10 hours;

Extreme hot state start: 450℃ ≤first stage metal temperature and turbine stops for lessthan one hour.

2.1.2 Measures should be taken if any condition occurs, otherwise turb ine is prohibitedto start

2.1.2.1 Any trip protection of turbine is in failure.

2.1.2.2 Main meters can not be put in operation or are in failure and there are no othersupervision measures: such as unit load, running speed, axial displacement,differential expansion, rotor eccentricity, vibration, absolute expansion, cylinder mainmetal temperature, vacuum degree of condenser, levels in deaerator, condenser, mainoil tank and EH oil tank and lubricate oil pressure, EH oil pressure and oil temperatureetc.

2.1.2.3 HP & IP main steam valve, speed regulation steam valve, HP steam discharging checkvalve, steam extraction check valve is blocked or is not in agility.

2.1.2.4 Rotor eccentricity exceeds 0.075mm.

2.1.2.5 Any differential expansion or axial displacement of turbine HP, IP or LP cylinderexceeds limitation.

2.1.2.6 During running turning gear, there is obvious metal friction sound at dynamic and staticpart of turbine or current of turning gear obviously increases or swings greatly.

2.1.2.7 HP or LP bypass system fault, and can’t satisfy system start .

2.1.2.8 Instrument-air supply system fault, and can’t supply the normal air to the unit.

2.1.2.9 Differential temperature of up and down cylinder of turbine HP outer cylinder is higherthan 50℃; differential temperature of up and down cylinder of turbine HP inner cylinder

is higher than 35℃.

2.1.2.10 Main oil pump, AC, DC lubricate oil pump, generator sealing oil pump, EH oil pump, jacking oil pump works abnormally or emergency pump automatic starting device is infailure.

2.1.2.11 DEH and DCS and main control system works abnormally, which affects unit operationand supervision.

2.1.2.12 Controlling air source or regulation protection power is lost.

2.1.2.13 Reason of turbine trip has not been found out.

2.1.2.14 There are defects that seriously threaten safe start or safe operation.

2.1.2.15 Steam, water or oil (turbine oil, fire resistant oil) is not qualified or oil temperature, oil



32

level is abnormal.

2.1.2.16 Generator sealing oil system is abnormal.

2.1.2.17 Main automatic regulation control system (such as HP & LP bypass control system,gland sealing pressure regulation system) is in failure.

2.1.2.18 Speed regulation system acts abnormally.2.1.2.19 Insulation for main pipelines and turbine proper is not complete or there is serious

leakage in main pipeline system.

2.1.2.20 Main and reheat steam temperature lower than HP-IP rotor’s average temperatureexceed 50 , degree of superheat under 30 .℃ ℃

2.1.2.21 Regulation system can not keep empty load operation, or running speed can not becontrolled after load rejection, and the speed is lower than emergency shutoff actingspeed.

2.1.2.22 Automatic main steam valve, steam speed regulation valve tightness tests are notqualified.

2.1.2.23 Over speed test disqualification2.1.2.24 Cooling water system or hydrogen system in generator can not be put into operation.

2.1.3 Unit start principles

2.1.3.1 Turbine adopts HP-IP cylinders unite start-up

2.1.3.2 Turbine stop and start should be done according to shift manager’s instruction.

2.1.3.3 Following works should be done under guidance of general engineer or personneldesignated by general engineer:

1) Turbine start after major or minor maintenance.

2) Unit actual over speed test.

3) Unit load rejection test.

4) First start of main equipments or systems after important modification or first trialoperation of relevant new technology.

5) Special test items.

2.1.3.4 When turbine is in cold state start, steam temperature at inlet of main steam valve at

least should be with overheating temperature of 56℃ but no higher than 430℃. Main

steam valve inlet steam temperature and pressure should be within curve of ‘Mainsteam parameters during start’. Heating up time and speed rise should be confirmedaccording to cold state start curve.

2.1.3.5 When start the unit in hot state, turbine main steam, reheating steam temperature

should with overheating temperature of no less than 56℃, starting parameters andtime is decided according to cylinder metal temperature and hot state start steamparameter curve and steam inlet temperature of HP & IP cylinder in start workingcondition.

2.2 Preparation before unit s tart

2.2.1 After receiving the order for starting unit from the shift manager, monitor should inform allchief shifters and relevant positions and inform the measures for dangerous points andsign.

2.2.2 Necessary tools, instrumental meters should be prepared, all positions should be readyand notebooks and operation tickets should be prepared.

2.2.3 Check and make sure that all maintenance works are completed and all work permittickets are concluded. All safety precautions are dismantled and site is cleaned up,equipment pipelines insulation are complete, roads are smooth and lighting is good.



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2.2.4 After maintenance, operators should acknowledge and grasp equipment conditions ofmaintenance, improvement and modification.

2.2.5 According to the operate card of unit start, check and make sure that valves positions insystem are right and equipments are complete and in fine condition.

2.2.6 Contact with I&C personnel to send power to all instrumental meters and protectors.

Check and make sure that DCS, DEH work normally and all parameters are right. I&Cpersonnel should calibrate the instrumental meters and protectors and static tests aresuccessful for starting the unit after major and minor maintenance.

2.2.7 Contact with I&C and electric personnel to send power to regulation valves andmotorized valves; switch tests are successful. Up and down stroke tests should be donefor the repaired motorized valves. Check and make sure that openness on DCS areconsistent with local indications. Check and make sure that signals on local control boxand control panel are right and all indications are normal.

2.2.8 Contact with boiler to start air compressor. Check and make sure that all instrumentalmeters and air source of pneumatic control valves are normal. All the switch tests ofpneumatic control valves are successful. The openness on DCS are consistent with local

indications.2.2.9 Check and make sure that all switches of running machines are at ‘OPEN’ position and

interlock switches are at ‘RELEASED’ position; contact with the electric to measureinsulation and send power after qualification. Make sure that all mechanical parts ofauxiliary equipments are not blocked and bearing lubricate oil is in good quality and oillevel is normal. Cooling water and sealing water are normal.

2.2.10 Make up water for cooling water tower, condenser, deaerator, cooling water tank andvacuum pump air-water separator is normal. Oil levels in main oil tank, fire resistant oiltank, HP & LP bypass oil station tank, oil tank of hydraulic check butterfly valve ofcirculating water pump, hydraulic coupler oil tank of feeding water pump and generatorsealing oil tank are normal. Oil supplement for bearing of auxiliary equipments are normal.Inform the chemical analyzers to analyze water and oil.

2.2.11 Put industrial water system into operation. Check and make sure that industrial waterpressure is normal. Put industrial cooling water system into operation according to actualrequirements.

2.2.12 All interlock protection tests are completed according to operation tickets before startingunit and all the tests are qualified.

2.2.13 Check and make sure that primary valves of pressure meters in all systems are open.

2.2.14 Safety valves in all systems should be regulated on test-bed after maintenance.

2.2.15 Audible and visual alarm are work normal.

2.3 Test before start

2.3.1 Test regulations

2.3.1.1 Equipment tests and trial operation can only be executed after maintenanceapplication and shift manager’s approval and instruction.

2.3.1.2 Tests are coordinated by maintenance principal and cooperated by operator; relevantpersonnel should be at site.

2.3.1.3 All oil pumps can satisfy remote control requirement conditions; test can only be doneafter all conditions are satisfied by forcing before protection and interlock tests.

2.3.1.4 Dynamic test must be done after static test is qualified.

2.3.1.5 Test should not be done for the systems in operation or motorized valve, regulation

valve bearing pressure.

2.3.1.6 Remote and local test should be done for servo actuators with remote control and localcontrol; special personnel should record open & close time and test information.



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2.3.2 Test method

2.3.2.1 According to test card, full open and full close tests with remote & local control shouldbe done for all the motorized valves. Openness indications should be consistent withlocal indications. Motorized valves needs to be stopped intermediately should betested normally.

2.3.2.2 Pneumatic regulation devices should act in agility with no air leakage or abnormity.

2.3.2.3 All interlock and protection tests should be done according to regulated items one byone.

2.3.3 Test item

2.3.3.1 Unit complete interlock test.

2.3.3.2 Turbine regulating system static characteristic test.

2.3.3.3 Turbine AC lubricate oil pump, generator sealing oil standby pump, turbine DClubricate oil interlock test.

2.3.3.4 Interlock test for main oil pump and lubricate oil pump of feeding water pump turbine.

2.3.3.5 EH oil pump interlock test.

2.3.3.6 Jacking oil pump interlock test.

2.3.3.7 Generator water-break protection test.

2.3.3.8 Sealing oil air discharging air fan and turbine lubricate oil air discharging air faninterlock test.

2.3.3.9 Vacuum pump interlock test.

2.3.3.10 Circulating water pump test.

2.3.3.11 Closed circulating cooling water pump interlock test.

2.3.3.12 Closed circulating cooling water pump interlock test.

2.3.3.13 Condensing water pump interlock test.

2.3.3.14 Interlock test for cooling water pump in generator stator.

2.3.3.15 Motorized water pump and steam driven water pump interlock test.

2.3.3.16 Condenser, HP & LP heaters and deaerator water level protection test.

2.3.3.17 ETS channel test.

2.3.3.18 OPC solenoid valve test.

2.3.3.19 Turbine protection interlock test.

2.3.3.20 On-off test for all motorized valves, pneumatic valves and regulation valves.

Above tests are executed after major or minor maintenance. Some tests can be doneseparately after maintenance according to actual requirement.

2.4 Turbine unit cold state start

2.4.1 Check before start

2.4.1.1 Maintenance of the unit is completed and all work permit tickets are concluded.

2.4.1.2 Ladders, fences and platforms are complete and there is no foreign materials inchannels and around equipment disturbing work or passing.

2.4.1.3 Insulations of turbine proper should complete, all the connections in system should becomplete and pipeline supporters and suspending devices are fixed.

2.4.1.4 Lighting in turbine hall is good and emergency lighting system works normally.

2.4.1.5 Communication system in turbine hall is normal.



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2.4.1.6 Fire fighting water system is normal and fire fighting facilities are complete.

2.4.1.7 HP & IP main steam valve, governor valve and control actuator are normal.

2.4.1.8 Turbine sliding pin system is normal and cylinder proper can expand freely.

2.4.1.9 LP cylinder safety valve is complete and in fine condition.

2.4.1.10 Emergency oil discharging valve of main oil tank is closed and sealed with lead. Beforestart, all original parameters of turbine and main auxiliary equipments should berecorded.

2.4.2 Put auxiliary equipments and systems into operation before start

Put the following systems into operation according to check cards and relevantregulations in Unit Auxiliary Equipment Start and Stop and make sure that they arerunning normally. Balance of load distribution in all sections should be comprehensivelyconsidered.

2.4.2.1 Before boiler ignition, put the following systems into operation one by one and makesure that they are running normally.

1） Put fire fighting system into operation.

2） Put circulating water system into operation, condenser works normally.

3） Put opened circulating water system into operation.

4） Put closed circulating water system into operation, all coolers are filled with water and air isdischarged. All valves state is right.

5） Put unit air compressor system into operation, air pressure is normal.

6） Put EH oil system into operation.

7） Put lubricate oil system into operation, one AC lubricate oil pump is running and the other oneis in standby. DC lubricate oil pump in standby and all returning oil for bearings are normal.

Oil temperature can regulate itself. Water passes water side of oil cooler that is running; oilcooler in standby is isolated after filled with water.

8） Put the generator oil sealing system into operation, AC sealing oil pumps at air, hydrogen sideof generator sealing oil are running, DC sealing oil pump is in standby, Water side of air andhydrogen side oil cooler is put into operation, all the oil pressure, oil temperature and oil levelsin oil tanks are normal.

9） Generator changes hydrogen. Put hydrogen system into operation.

10） When the hydrogen pressure in generator is 0.2MPa, make sure that water in make up watertank is qualified and air in stator is completely discharged; put cooling water system ingenerator into operation. Adjust the differential pressure keep normal.

11） Start jacking oil pump, check and make sure that jacking oil supplying head pipe pressure,bearing jacking oil pressure are normal. Confirm the relevant interlocks of turning gear deviceare in fine condition and protection test is successfully completed; lubricate oil temperature

should be higher than 21℃. Put turning gear into operation and check the turning gear current

is normal. There is no abrasion sound at running parts and rotor eccentricity should be nobigger than 110% of original value. Record relevant parameters. Continuous turning gear timeshould be no less than 4 hours before starting the turbine.

12） Put condensing water system into operation.

a. Start make up water pump and fill water into condenser.

b. Make sure that protection tests of relevant interlocks of condensing water are successful, whenthe water level is normal, run the condensate pump, each LP-heater transit water .Air

discharging and water filling at water side of LP heater are completed and water level protectionhas been put into operation.



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c. Make sure that condenser and system flushing water are qualified and feed water to deaerator.Make sure that flushing water in deaerator is qualified.

13） Auxiliary steam system drain and warming pipes, put it into operation, check the head pipepressure and temperature are normal.

14） Put deaerator water tank for heating

a. Fill deaerator water tank to normal water level and contact chemical to dose to deaerator.

b Make sure that turning gear runs normally, open regulation valve from auxiliary steam todeaerator and put deaerator for heating. Regulate the pressure regulation valve from auxiliarysteam to deaerator and make the water temperature rise according to boiler need.

（temperature-rise ratio not exceed 1.5℃/min）

15） Oil system of two (2) steam driven feeding water pumps are put into operation and, waterpasses through water side of running oil cooler; water side of standby oil cooler is isolatedafter air discharging and oil temperature regulation automation is in operation. Before boilerignition, turning gear of feeding water pump should be running for more than three (3) hours.

16） Feeding water temperature reaches to the requirement of deeding water to boiler; run the

electric feed pump transmit the feed water to boiler when water quality in deaerator isqualified. HP-heater connect water.

17） After water side of gland sealing heater putting into operation, put the turbine gland sealingsystem into operation.

a. Start one gland sealing heating air fan, open general valve from auxiliary steam to gland sealingsteam head pipe and isolation valve heating pipes before and after gland sealing steamregulation valve.

b. After discharging all the drainage water, open gland sealing steam regulation valve and keep

gland sealing steam pressure at 0.007～0.021MPa and LP gland sealing steam temperature at

120～180℃ and, LP gland sealing steam desuperheater water temperature control automation

is in operation.c. During unit start or stop, differential temperature between HP & IP rotor gland sealing steam

temperature and rotor surface metal should <110℃.

Note: Steam supplying is prohibited when rotor is in stationary state. Turning gear operationshould be strictly supervised during supplying gland sealing steam. Vacuum pump can only bestarted after gland sealing supplied to rotor to establish condenser vacuum.

18） Put gland sealing system of feed water pump turbine into operation.

19） Close the vacuum break-valve, open the sealing water valve, open the drain butterfly valve offeed pump turbine, start the vacuum pump,(according to the need decided how many pumprun)

20） After establishing condenser vacuum, open drainage valves of turbine, feed pump turbinecylinder proper, main and reheat steam pipelines, extraction pipeline.

21） Make sure the all the works before starting are completed, equipments and systems inoperation run normally and equipments and systems in standby can be put into operation atany moment.

2.4.2.2 Work after boiler ignition

1） After boiler ignition, inform the boiler about required parameters according to cylindertemperature.

2） Put bypass system into operation according to requirements. Put LP bypass system intooperation first and then HP bypass system. Pressure before main steam valve should keep

above 0.1MPa. Put HP & LP bypass attemperating water into operation according totemperature after bypass. Pay attention to vacuum and steam discharging temperature,contact with chemical to analyze condensing water quality.



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3） Following parameters should be recorded before starting turbine: temperature and pressureof main and reheat steam, rotor eccentricity, absolute expansion, differential expanse, axialdisplacement, temperature of cylinder metal, vacuum, drain steam temperature, turning gearcurrent, oil level of lube oil tank, lube oil pressure and temperature, jacking oilpressure ,hydrogen side sealing oil tank oil level, hydrogen pressure, hydrogen-oil differentialpressure, stator cooling water flow and pressure, oil level of EH oil tank, EH oil pressure and

temperature.

2.4.3 Turb ine start

2.4.3.1 Check and preparation before starting turbine

1） Interlock protection test of turbine is qualified and in operation

2） Auxiliary equipments and systems run normally and there is no condition prohibiting unit start.

3） When turbine is in cold state start, steam temperature at inlet of main steam valve at least

should be with overheating temperature of 56℃ but no higher than 430℃. Main steam valve

inlet steam temperature and pressure should be within curve of ‘Main steam parametersduring start.

4） Turning gear device runs normally, rotor eccentricity ＜0.075mm, and turning gear runs formore than 4 hours, cylinder inside and shaft seal part without clash sound or other abnormalsound .(regulation of minimum continuous running time before starting turbine must beexecuted).

5） Check and make sure that gland sealing steam head pipe pressure is 0.007-0.021Mpa, glandsealing steam temperature and rotor surface metal temperature match with each other with

differential temperature less than 110℃, LP gland sealing temperature control automation is

in operation.

6） Affirm that turbine lubricate oil pressure is 0.1～0.18MPa, lubricate oil temperature is 38℃～

42℃.

7） Generator sealing oil system, stator cooling water system and hydrogen cooling system worknormally.

8） Turbine TSI indication is normal.

2.4.3.2 Conditions for turb ine latch

1） There is no condition prohibiting unit start.

2） Make sure that HP & LP differential expansion, axial displacement, HP & IP & LP up anddown differential temperature, eccentricity, differential temperature of inner & outer wall ofsteam chamber are in limited range. Changing trend should not exceed limitation after turbinestarts.

3） Cold state start parameter ：

Main steam pressure: 5.9MPa Reheat steam temperature: 300℃

Main steam temperature: 340℃ Reheat steam pressure: 1Mpa.

Main and reheat steam have >56℃ superheat degree.

4） Condenser vacuum at HP & LP side >80KPa。

5） Lubricate oil temperature is higher than 35℃, returning oil of all bearings are normal.

6） Lubricate oil pressure: 0.1～0.18MPa。

7） Turbine turning gear works normally and sound is normal.

8） LP cylinder water spraying valve is in ‘automation’.

9） Close HP & LP bypass valves.



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10） Remote and manual latch handle is recovered.

11） DEH screen check:

Stick chart or explanation State Literal explanation

HP main steam valve position

indication 0％ valve position TV1，2

hp regulating valve positionindication

0％ valve position GV1，2，3，4

Reheating regulating valve positionindication

0％ valve position IV1，2，3，4

Reheating main steam valve positionindication

CLOSED Closed (green light shine)

Main breaker state Breaker Open Breaker Open

Turbine state Turbine stop Trip

Valve control mode SINGLE Single valve

Generator power control loop OFF Cut-off

Main steam pressure control loop OFF Cut-off

Turbine control mode MANUAL Manual

2.4.3.3 Turb ine latch

1） Select ‘Latch turbine’ button on screen and click ‘ETS recover’, click ‘Latch turbine’ after ETSrecovered and select ‘YES’ for turbine latch. After successful latch, check that IP main steam

valve is open, green light of ‘Enable Roll’ is on.2） Select ‘automation’ in ‘control mode’ on DEH screen.

3） Select ‘Valve position high limitation’ from ‘Limitation value’ on DEH screen, enter ‘120’ andclick ‘GO’, check that IP regulation valves and HP regulation valves are open.

4） Operate over speed trip actuator with remote trip button or manual trip pole installed at frontbox, close all steam inlet valves. Test and check whether trip system is normal or not.

5） Repeat above operations, turbine latch again.

2.4.3.4 Operation and check before starting turbine

1） Test the OPC function on DEH screen, click ‘OPC Test’ button and click ‘IN’, check OPC

solenoid valve action. HP & IP governor valves, HP steam discharging check valve and checkvalves of all steam extraction are closed. Click ‘OPC Protection’ button, OPC protection ‘IN’,above valves open.

2） Select ‘Single valve’ mode from ‘Valve Mode’ on DEH screen.

3） Make sure that main steam pressure, temperature meet the requirements of cold state start.

4） Make sure that turbine first stage metal temperature is less than 120 , according to IP℃ cylinder steam inlet blades metal temperature, turbine should be heated up for 150min when

running speed is 2000r ／min.

5） Make sure that turning gear is running and turbine is latched.

6） Make sure that all the auxiliary system and equipments are running normally with no

abnormal alarm signals.

7） Make sure that drainage valves of turbine proper, HP & IP system and LP cylinder water



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spraying control switch are at ‘Automation’.

8） Lubricate oil cooler, coolers at air & hydrogen side of sealing oil, hydrogen cooler andgenerator stator water cooler are ready for operation.

9） LP heater start with the turbine and start the LP heater steam supplying motorized valve,drainage water flows automatically stage by stage.

2.4.3.5 Start turbine with target speed of 600r/min, check the turb ine clash

1） Click ‘Control set value’ button on DEH screen and set speed rise rate of 150r/min with targetspeed of 600r/min. Click ‘GO’ button, turbine starts to rise speed.

2） When running speed >3r/min, make sure that turning gear on CRT really exit from runningand turning gear motor stops.

3） When running speed reaches to 200r/min, check and make sure that turning gear oil sprayingsolenoid valves are closed automatically.

4） When the turbine rotate speed reach 600r/min, keep 600r/min, press the “emergency shut

down” button，check that HP-LP main throttle valve closed, rotate speed downgrade. Check

turbine clash, listen sound of the cylinder inside, check that if the running part and static parthave abnormal sound, check that if the rotor eccentricity normal, when eccentricity >0.075mmmust forbid unit start.

5） After checking the friction, turbine latch again, the turbine rotate speed reach 600r/min, keep

600r/min,check the unit completely:

a. Up and down gas side start with the turbine.

b. Check bearing vibration, axial displacement ,differential expanse, cylinder absoluteexpansion, bearing metal temperature, return oil temperature, up and down cylinderdifferential temperature and so on in normal range. check eccentric recorderautomatically disengage, vibration recorder begin to record the final rotor eccentric

degree at rotate speed is 400～600r/min.

c. Check condenser hot well level, deaerator water level, up and down feeding water levelall adjusting put into automatic control and operating normally.

d. Check turbine lube oil pressure and temperature, EH oil pressure and temperature, oillevel of EH oil tank, bearing current are normal.

e. Check the generator hydrogen pressure, hydrogen temperature, sealing oil pressure and

hydrogen-oil differential pressure are normal.

f. Confirm the LP watering door open automatically, LP exhaust temperature is less

than70℃,vacuum is normal.

g. If the gauge above parameters or close to the parameters and may rise, should report

immediately, identify the reason and prohibit to increase the speed.

2.4.3.6 Continue to rise speed with target of 2000r/min

1） Click ‘Control set value’ button on DEH screen and set speed rise rate of 150rpm/min withtarget speed of 2000r/min. Click ‘GO’ button, turbine continues to rise speed.

2） Unit continues to rise speed to 2000r/min and keep running speed of 2000r/min for heating upturbine. During heating up, heat up pipes with auxiliary steam.

3） During speed rise, if running speed needs to stay, click the ‘HOLD’ button in ‘Control set value’on screen. It is prohibited to stay in resonance running speed range to avoid turbineresonance.

(1)700～900rpm

(2)1300～1700rpm(3)2100～2300rpm



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(4)2650～2850rpm

4） Heating up time should be decided according to first stage metal temperature, when thistemperature is ≤120 , heating up time should be 150min. Heat time should not be shortened℃ under any condition. During medium speed heating up time, main steam temperature slowlyslide to 380 ,reheated steam temperature slowly slide to 335 (during this process,℃ ℃ inlet

steam can increase to 430 ,but the temperature rise rate can not more than℃ 55 /hour.)℃ 5） During heating up, main steam temperature should not exceed 430 and reheating steam℃

temperature should be higher than 300 . Temperature rise should be controlled at℃ 0.92 /min.℃

6） During heating up, auxiliary equipments and systems should be checked completely, soundsin running parts are normal with no abnormal alarm.

7） After pipe heating, check and make sure that parameters for starting turbine are qualified andstart the first steam driven pump with auxiliary steam according to actual conditions to avoidwater impact.

8） The finishing condition of medium speed heating up :

a. Make sure that time is up and heating up is completed.

b. Check and make sure that steam cylinder is evenly expanded.

c. HP & LP differential expansion decreases stably and gradually.

d. Indications do not exceed limitation and are stable.

2.4.3.7 Turbine running speed rise from 2000r/min to 2900r/min, transfer the valves

1） Click ‘Control set value’ button on DEH screen and set speed rise rate of 150rpm/min withtarget speed of 2900r/min. Click ‘GO’ button, turbine continues to rise speed.

2） When turbine rotate speed is 2850r/min,check that jacking oil pump stop automatically, orstop manual, put into standby.

3） Running speed continues to rise to 2900 r/min and running speed keeps at 2900 r/min; it isready for valve transfer.

Make sure that inner wall temperature in steam chamber at least equals to saturationtemperature under main steam pressure. See as annex of turbine inlet steam state whichshows the relationship between inlet temperature and pressure of main steam valve in coldstate start. If you want to make the temperature of steam chamber meet the required value,this parameter relationship should be obeyed.

4） ‘TV-GV’ transfer operation

“（TV/GV CHANGE）”button, GV will close slowly, TV/GV CHANGE IN PROGRESS in the

information bar will bright, when GV close to certain valve, TV will open slowly when TV

completely open, switch is finished, unit increase speed to 3000rpm automatically, “TV/GVCHANGE IN PROGRESS” become dark. During the recorder valve switching process, speedfluctuation value does not exceed 30r/min.

5）Check EH oil system, regulate that hydraulic mechanism of system is not leakage and abnormal,

it can continue to increase the speed.

2.4.3.8 Unit running speed increase to 3000 r/min

1） Click ‘Control set value’ button on DEH screen and set speed rise rate of 150r/min with targetspeed of 3000r/min. Click ‘GO’ button.

2） Running speed continues to rise to 3000 r/min and running speed keeps at 3000 r/min.

3） After turbine operating in normal speed, completely check unit and each system is normal.

a. Check and make sure that main oil pump outlet pressure is 2.0～2.5MPa and inlet oil

pressure is 0.12～0.14MPa，main oil pump work normal.



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b. Stop AC lubricate oil pump, sealing oil standby oil pump and put them in standby.

c. Regulate lubricate oil temperature to be 38～42 and bearing returning oil temperature℃

<77 .℃

4） The following experiments as needed

a. ETS channel online experimentb. Critical protection device injection test(running 2000 hours)

c. Main steam valve, regulating steam valve strict test(after each overhaul, before speed (test)

2.4.4 Unit synchronization and loading

2.4.4.1 Following conditions should be prepared for turbine during unit synchronization:

1） Make sure that turbine runs with speed of 3000r/min and is stable; DEH device is normal.

2） All control indications are normal when turbine runs with empty load; auxiliary equipments arenormal.

3） Tests under 3000r/min for unit are completed.

4） Main steam temperature and steam pressure are stable.

2.4.4.2 After completely checking that unit is operating normally, report to dispatcher, shiftchief supervisor orders that the generator is synchronization

2.4.4.3 With 5% rated load

2.4.4.4 Check after synchronization

Heating up 30min at 5% rated load, during this period, maintain steam temperature,pressure stability, temperature rising rate is maximum not more than 83 /h,regulating℃

metal temperature rising rate is maximum not more than 110 /h.℃

1） Check and make sure that vibration, differential expansion, absolute expansion, axial

displacement and metal temperatures of all bearings are normal, lubricate oil pressure,bearing returning oil temperature and EH oil pressure are normal. Temperature difference ofup & down wall of cylinder is within permit range.

2） Make sure that following control devices are in automation:

a. Motorized feeding water pumps re-circulating control.

b. Steam driven feeding water pump re-circulating control.

c. Deaerator pressure and water level control.

d. Turbine lubricate oil temperature control.

e. Hydrogen temperature control.

3） After heating up with primary load, check and make sure that turbine differential expansion iswithin permit range and absolute expansion of cylinder is normal.

2.4.4.5 Increase load to 60MW(10%rated load)

1） Check small turbine lubricate oil system, MEH system is normal, meet the small turbine

operating condition to make the first small turbine standby.

2） Check turbine main steam pipe all the drain valve close automatically.

2.4.4.6 When load increase to 90MW,check LP cylinder injecting valve open automatically.

2.4.4.7 Increase load to 100MW

1） Station-service power supplying to start-up/stand by transformer changes to be supplied by

high plant transformer, common part power supplying to start-up/stand by transformerchanges to be supplied by high common transformer.

2） Steam supplying to gland sealing changes to be supplied cold reheater.

2.4.4.8 Increase load to120MW (20%rated load)



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1） Check turbine proper, reheat steam pipe, bypass system pipe and each part extraction pipe

and so on all the drain valve close.

2） The first start after new installation or overhaul, the unit should operate at least seven hours at

the condition that 120MW load, reheat steam temperature is not more than 400 then to heat℃

up, according to the normal stop process, unit load reduce to zero, after cutting off do theturbine exceed test after exceed test, recover the rotate speed 3000r/min,contact todispatcher, generator synchronizes again and with load.

3） When load is 120MW,after the drum water level stability, according to the operating condition

of pneumatic feeding water pump, parallel the first pneumatic feeding water pump and power

pump and put into automatically control.

4） When the fourth steam extraction pressure is more than0.165MPa,Deaerator steam source

returns to be supplied by fourth section steam extraction.

2.4.4.9 Increase the load to 240MW, start and heat up the secondary pneumatic feeding water

pump.

2.4.4.10 Increase load to 300MW,open the proper reheat cooling part to high pressure auxiliarysteam header automatic isolation valve, steam supplying to proper auxiliary steam

connecting box by fourth steam extraction, completely check to close drain/dewateringoutlet valve, secondary pneumatic pump put into system, stop power pump standby,maintain the combustion stability when switching.

2.4.4.11 Increase load to 600MW

1） When load is 420MW, proper auxiliary steam connecting steam source supplying to high

auxiliary slowly changed to be supplied by fourth section steam extraction.

2） Check turbine bearing sealing steam source supplying to cooling reheat automatically

changed to supplied by sealing, bearing sealing supply steam header pipe pressure is

0.028～0.031MPa,open each standby steam source valve to maintain the heating standby

condition.

3） When the parameters of the turbine pump auxiliary steam source and fourth section steam

extraction are matching, and the temperature differential of two part is not great, avoid waterrushing.

4）Maintain single valve operating one day, when load is 540MW,single valve and sequence valve

control methods changed with each other, to reduce solid particle corrosion(during the first sixmonth operating period, the turbine valve control method must be single valve control, tomake regulating blade uniform heating, improve the stress distribution of regulating blade,reduce the rush for the blade, to make sure the safety of the unit operation).

5） When load is 600MW,completely check and regulate each equipment, system in normal

operating condition, confirm each parameter is normal, make recorder, report to shift chiefsupervisor, start-up stop.

2.4.5 Notice during start

2.4.5.1 During the start, condenser, deaerator, heaters, closed water tank, stator cooling water

tank level is normal, oil levels in all oil tanks are normal and oil temperature complieswith requirements.

2.4.5.2 After starting the turbine, lubricate oil temperature should be regulated and maintainedat 40±2 ; parameters should be stable when turbine running speed is rising.℃

2.4.5.3 When running speed is <600r/min, turbine eccentricity should be supervised strictly;when running speed is >600 r/min, unit vibration should be supervised strictly. Whenunit running speed is increased to resonance area, vibration should be strictlysupervised and stop the unit as emergency stop immediately if any bearing vibrationreaches to 0.25mm at any running speed. When decreasing running speed due to highvibration and running speed is decreased to be less than 600r/min, rotor eccentricityshould be supervised; when eccentricity is higher than 0.075mm, stop the unit and

start turning gear; the unit can only be started again until eccentricity is lower than0.075mm.

2.4.5.4 During turbine speed rising, unit abrasion sound should be listened carefully at local; if



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any abnormity is found, unit should be stopped for finding out the reason. During speedrising, DEH should keep running speed if any of the following conditions occurs; if therunning speed is within critical sunning speed range, then it should keep the runningspeed after running speed rises and exceeds critical running speed:

1） Bearing vibration is higher than 0.125mm.

2） Expansion difference of HP and IP is high.

3） Bearing returning oil temperature is 75 higher.℃

4） Thrust bearing metal temperature is 85 higher.℃

5） LP cylinder steam exhausting temperature is 80 higher.℃

2.4.5.5 AC lubricate oil pump should be put into standby in time after stops.

2.4.5.6 LP cylinder steam exhausting temperature should not exceed 80 before generator℃ synchronization.

2.4.5.7 During load increasing, nitrogen should be charged to generator in time.

2.4.5.8 Coordination control should be put into operation as soon as possible when unit load ishigher than 30%.

2.5 Unit warm, hot, very hot start

2.5.1 Unit warm, hot , very hot start general rules

Before unit warm, hot, very hot start, completely check it. The auxiliary equipment startoperating step is the same as cooling condition start, other operation and regulationaccording to the cooling condition start requirement to operate for there is no specialrepresentation. When warm, hot, very hot start, should load immediately to avoid the rotormetal temperature reducing to have over hot stress. Unit increase speed rate, load rate andheating up time should reference the relevant start curve to confirm.

2.5.2 Unit warm, hot, very ho t start regulation

2.5.2.1 Before exhaust air vacuum, first put into sealing supplying air, then vacuum, vacuumbreak valve should close before vacuum. Sealing supplying air temperature should matchcylinder metal temperature.

2.5.2.2 After boiler burning, exhaust air equipment vacuum qualified, put into bypass system.Strictly according to increase temperature and increase pressure rate to control mainreheat steam temperature, to make sure the unit life.

2.5.2.3 The rotor eccentricity is normal.

2.5.2.4 Before starting, should make sure that the turbine is at the condition of turning gear or stillat idling step, but rotate speed is not at the critical period, starting and increase the speedof turbine when it is idling at critical period is prohibited.

2.5.2.5 Before turbine starting, should make sure turbine proper and each steam pipe drain valve

opening and can drain water 15 min continuously. When turbine staring, pay attention tosupervise up and down temperature differential of the HP and IP cylinder is less than42 ,if the temperature℃ differential is exceed and axial displacement alarm at the sametime, should trip to stop immediately and drain steam pipe fully.

2.5.2.6 When turbine starting, make sure main steam superheat temperature is above 56 ,and℃

the first grade steam temperature and metal temperature is matching at any condition, firststeam temperature can’t above first metal temperature110 or below 56 .℃ ℃

2.5.2.7 When main, reheat steam near to starting parameters, turbine have to install again, thenshould pay attention to the changing of turbine rotate speed.

2.5.2.8 Turbine doesn’t need 2000r/min heating up during starting(except warm-1)

2.5.2.9 Very hot, hot and warm start should make expansion differential, absolute expansion of thecylinder, vibration, axial displacement, each bearing temperature and oil temperature at

the regulating range, after starting, turbine should increase speed, parallel and load assoon as possible, not let metal cool and appear temperature differential.2.5.2.10 In very hot start, after synchronization should increase the load to 300MW by the speed



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18MW/min,to avoid making HP cylinder exhaust air temperature high, and turbine trip,influence the unit start.

2.5.2.11 When unit increase speed, pay attention to LP cylinder exhaust air temperature is notmore than 80 .℃

2.5.2.12 When unit start, condenser water system and feeding water system rushing should

operate normally.2.5.2.13 During hot start, for the load increasing rate is great, pay attention to the change of thecondenser water level.

2.5.2.14 When warm start should maintain single valve control one day to reduce solid corrosion.

2.5.3 Unit warm, hot, very hot start reference parameter

Start parameterStartcondition

Regulating metaltemperature

Mainsteam

pressure

Main steamtemperature

Reheat steampressure

Reheatsteam

temperature

cold T＜120℃ 5.9MPa 340℃

1MPa 300℃

warm-1 260℃＞T≥120℃ 5.9MPa 340℃ 1MPa 300℃

warm-2 415℃＞T≥260℃ 5.9MPa 420℃ 1MPa 400℃

hot 450℃＞T≥415℃ 7MPa 450℃ 1MPa 435℃

very hot T≥450℃ 8MPa 485℃ 1MPa 470℃

2.6 DEH operation mode explanation

There are four basic control modes:

Automatic control;

CCS remote control;

Manual control;

Synchronize Control.

2.6.1 Automatic cont rol

2.6.1.1 During rising speed, speed rising rate and target running speed can be confirmed orcorrected.

2.6.1.2 Transfer from main steam valve to HP regulation valve control can be done.

2.6.1.3 When unit reaches rated running speed, automatic synchronization can be done.

2.6.1.4 After unit synchronization, speed rising rate and target running speed can be confirmed orcorrected.

2.6.1.5 Remote control can be put into operation.

2.6.1.6 It has valve management function——single valve and sequence valve control.

2.6.2 CCS remote contro l

2.6.2.1 Conditions for putting into operation

1） DEH device is at automatic mode.

2） Outlet breaker of generator is closed.

3） DEH did not put main steam pressure circuit into operation.

4） DEH did not put power control circuit into operation.

5） Contact point allowable for remote control is closed.



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2.6.2.2 Method for put ting in to operation

After pressing ‘remote control’, control device is put into coordination control operationmode; ‘remote control selection’ is sent form contact point to CCS, it indicates that DEHhas accepted parameter increasing or decreasing pulse from CCS.

2.6.2.3 Cutting off method

When any of the above five conditions is not satisfied or press ‘remote control’ buttonagain, it exits from remote control mode and enters into DEH ‘automation’ mode.

2.6.3 Manual cont rol

2.6.3.1 Conditions for DEH changing from automation to manual control mode

Unit has not been synchronized, speed measuring system is in fault; the system switchesautomation to manual control mode directly.

2.6.3.2 In manual control mode, operator controls HP main steam valve, HP regulation valveopenness directly; slow velocity is 10% valve position/min and quick velocity is 30% valveposition/min. Valves will be closed or opened according to set velocity of correspondingbutton that is long time pressed.

2.6.3.3 Notices

1） During unit speed rise, manual control mode is prohibited.

2） During speed rise, if automation is transferred to manual control, unit speed risingshould be stopped. When unit is in manual control, latch should be opened and thenclosed, then automatic control can be put into operation.

2.6.4 Synchronization cont rol

2.6.4.1 Conditions for synchronization putting into operation

1） DEH device is at automatic mode.

2） HP regulation valve is at control mode.3） Outlet breaker of generator is opened.

4） Turbine running speed is within synchronization range （2985～3015r/min）.

2.6.4.2 Method for putting synchronization into operation

Click ‘Control Mode’ button on DEH screen in main control room and select‘synchronization’ and confirm; dialog box displays ‘IN’.

2.6.4.3 Conditions for cutting off synchronization

1） Outlet breaker of generator is closed.

2） System is in manual control or actual running speed exceeds synchronous running

speed.

2.7 Unit stop

2.7.1 Preparation before Stopping Unit

2.7.1.1 Start and put AC, DC oil pump, jacking oil pump into trial operation, check that theirrunning are normal and trial operation of turning gear motor is normal.

2.7.1.2 Preparation of steam source transfer should be done for auxiliary steam, gland sealing anddeaerator.

2.7.1.3 Inform all personnel check the equipment system completely, collect the defects andprepare for stop unit.



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2.7.2 Unit stopping with sliding parameter

2.7.2.1 Unit load from 600MW to 540MW

1） Accept the command of the shift chief supervisor to stop. report to dispatcher to stop

AGC, Accept the sliding stop command of the shift chief supervisor to make the loadchanging rate 15MW/min,reduce unit load,≯ boiler combustion rate is reducing,

according to unit sliding parameter stop curve to reduce load.2）When load reduce to 540MW,turbine sequence valve and single valve control method

switch with each other.

2.7.2.2 Unit load from 540MW to240MW

1）Continue to reduce the load with the load changing rate 15MW/min,reduce main steam≯

with main steam pressure reducing speed 0.15MPa/min.slowly reduce boiler≯

combustion rate, unit begin to sliding stop step, unit load reduce with the drop of themain steam pressure.

2）When load reduce to 480MW, according the condition to do the vacuum sealing test.

3）When load reduce to 420MW,proper auxiliary connecting box steam source transfer from

fourth steam extraction to high pressure auxiliary header pipe can be done, check that

proper auxiliary steam connecting box’ pressure and temperature is normal.4）Check turbine bearing sealing steam source transfer from sealing automatically to cold

reheater can be done, sealing supplying temperature is normal.

5）When load is 300MW,according to the condition, one feeding water pump changed to

manual control, slowly reduce its output and check another feeding water automaticallyadd output, maintain drum water level normal.

6）When load is 240MW,after starting electric pump and parallel pump, stop one steam

pump.

2.7.2.3 Unit load from 240MW to 30MW

1）Continue to reduce the load with load changing rate≯15MW/min, reduce main steam

pressure with main steam pressure changing rate 0.1MPa/min.≯

2）When cold reheater pressure is below 1.27Mpa(load is 190MW),high pressure auxiliary

steam header pipe steam source transfer from cold reheat to starting boiler oradjacent equipment can be done, check that high pressure auxiliary steam header pipepressure and temperature are normal.

3） Load is 180MW and unit operating stability, station service power supplying to highstation transformer changed to be supplied by start/standby transformer, commonsection power supplying to high common transformer changed to be supplied bystart/standby transformer. after transferring, unit continuously reduce the load.

4） When load reduce to 120 MW(20%rated load),check turbine proper, reheat steam pipe,bypass system, each section steam extraction pipe and so on all drain water valve openautomatically.

5） Check turbine sealing steam source transfer from cold reheater automatically toauxiliary steam can be done ,bearing sealing supplying temperature is normal.

6） When fourth steam extraction pressure is less than 0.147MPa, deaetator heating steamsource transfer from fourth steam extraction to auxiliary steam can be done.

7） When load reduce to 90MW or LP cylinder exhaust air temperature is more than 70 ,℃ check LP cylinder injecting valve open automatically.

8） When load reduce to 60MW (10%rated load),check turbine main steam pipe all drainwater valve open automatically.

9） HP,LP heater adopt random sliding way, when #3 high heater steam side and deaeratorpressure differential is not enough, should check #3 high heater failure drain waterregulating valve open automatically, regulate that high heater water level is normal.

10）Unit should not stay at low load condition for long time, and pay attention to the change

of HP,LP cylinder exhaust air temperature.

11）When load reduce to 30MW,start turbine AC lube oil pump, hydrogen sealing oil standby

pump and AC jacking oil pump, check it operating normal, check jacking oil headerpipe and each bearing jacking oil pressure is normal and make record.



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12） Contact to shift chief supervisor, turbine is ready for trip.

2.7.3 Operation after turbine parallel off

2.7.3.1 When the load decreases to minimum value after generator parallel off, open the latch first,then start reverse power protection and open the breaker of generator-transformer unit tostop the unit.

2.7.3.2 Press ‘Turbine Trip’ on control panel or latch manually at local, check and make sure thatall the HP & IP main steam valves, HP & IP governor valves, steam extraction checkvalves of all stages and check valves of HP steam discharging are strictly closed.

2.7.3.3 After turbine trips, make sure that turbine HP & IP main steam valves, governor valves areclosed to ensure that protection of water entering into turbine is normal.

2.7.3.4 When running speed decreases, pay attention to critical vibration and listen to sound incylinder.

2.7.3.5 Make sure that running speed of turbine decreases and vacuum breaking valve isprohibited to open when running speed is high then 2000r/min if there is no specialsituation.

2.7.3.6 After turbine trips and running speed is 2850rpm (or lubricate oil is abnormal anddecreases to 0.076MPa), AC lubricate oil pump and standby oil sealing pump startsautomatically, otherwise start them manually; if oil pressure decreases, DC lubricate oilpump should start in interlock, otherwise start it manually.

2.7.3.7 During inertia, the lubricate oil pressure and temperature changing should be normal.Sealing oil/hydrogen differential pressure regulation should be normal, air/hydrogen sidesealing oil differential pressure balancing valve regulation should be normal.

2.7.3.8 When running speed decreases to 2800r/min, check jacking oil pump start automaticallynormal. Check all bearing jacking oil pressures are normal.

2.7.3.9 When turbine running speed is 600r/min, check and make sure that LP cylinder waterspraying valve closes automatically.

2.7.3.10 When running speed decreases to be lower than 400rpm, vacuum is allowed to bebroken.

2.7.3.11 When running speed is 0, rotate speed fall to 200rpm,check turning gear injectionsolenoid valve open automatically, put turning gear into operation manually. Recordsthe inertia time of rotor, check turning gear current, rotor eccentric degree, payattention to hear the inside sounds. After turning gear putting into operation, recordrotor eccentricity, HP & IP cylinder expansion, differential expansion, first stagetemperature and axial displacement periodically.

2.7.3.12 Start condensate water transfer pump.

2.7.3.13 After boiler flameout, make sure that bypass system and 5% bypass is isolated, close

the drainage valves before HP & IP main steam valve and check valve after HP steamdischarging, make sure that there is no steam or drainage water with pressure entersinto condenser (especially there should no auxiliary steam or drainage water entersinto cylinder or condenser), otherwise check and make sure that all the drainagevalves to condenser are closed and vacuum pump is closed and all vacuum breakingvalves of HP & LP condenser are stopped.

2.7.3.14 When condenser vacuum is zero, stop steam supplying for gland sealing, close alllines of steam source of gland sealing and stop gland steam air fan. Steam discharging

cylinder should be ＜50 .℃

2.7.3.15 Stop EH oil pump and maintain EH oil system operation according to actualrequirements.

2.7.3.16 Contact with chemical, cut off the condenser water fine treatment device.

2.7.3.17 When boiler do not need feeding water completely, stop deaeretor heating and feeding



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water pump.

2.7.3.18 Stop open cooling water pump according closed cooling water temperature.

2.7.3.19 When drum pressure is close to 0, LP cylinder steam discharging temperature shouldbe lower than 50 and there is no high℃ temperature steam or water enters intocondenser; when closed cooling water temperature is quite low, stop the other

circulating water pump.

2.7.3.20 Condenser pump can be stopped if there is no condenser water user or LP cylindersteam discharging temperature decrease to 50 .℃

2.7.3.21 Stop the turning gear device when all requirements for stopping turning gear aresatisfied.

2.7.3.22 Gas in generator is generally changed after turning gear stops, sealing oil levels in oiltanks should be strictly supervised during gas changing to avoid oil entering intogenerator.

2.7.3.23 Sealing oil system can only be stopped after gas changing and turning gear stopping.

2.7.3.24 Stop generator stator water system, to do the stator water backwash as needed.

2.7.3.25 Stop the lubricate oil system of the turbine.

2.7.3.26 Decide whether to stop closed cooling water pump or not according to closed coolingwater users.

2.7.3.27 Stop condensing water transportation pump.

2.7.3.28 After sealing oil system stop operating, according to the bearing temperature can stopmain unit lubricating oil system and oil purifier.

2.7.3.29 Equipment maintaining and isolation for maintenance after stop should be done well.

2.7.4 Notice for stopping the unit

2.7.4.1 During stopping the unit with sliding parameter, turbine and boiler should cooperate well.There should be return during decreasing temperature or pressure. When stopping mill,main steam pressure, temperature, furnace pressure and drum water level should besupervised strictly. Pay attention the decreasing speed of steam temperature and cylinderwall temperature, steam temperature decreasing speed should comply with requirement ofsliding stop curve strictly. If steam temperature decreases acutely 50 within℃ 10min,turbine should be stopped.

2.7.4.2 During decreasing load, all water levels should be normal. HP & LP heaters should exitfrom running in time. Feeding water minimum flow valve can be opened manually inadvance according to load conditions.

2.7.4.3 Bearing vibration, measuring should be strictly supervised during sliding stop, stop theturbine immediately if any abnormal vibration is found.

2.7.4.4 Unit should avoid running with 60MW for a long time, active power of generator should bedecreased o rapidly and reactive power is close to 0 before parallel off; Disconnect turbinemanually, check and make sure that HP & IP main steam valves, HP & IP regulationvalves, all stages steam extraction check valves and HP steam discharging valves areclosed.

2.7.4.5 Make sure that running speed decreases after open latch. Vacuum breaking valve isprohibited to be opened when running speed is higher than 400r/min if there is no specialsituation.

2.7.4.6 When speed decrease to 2800r/min, check jacking oil pump start normal. check thesealing oil ball cock and oil level in sealing oil tank to avoid oil entering into generator.

2.7.4.7 Before condenser vacuum decreases to zero, all the drainage valves to condenser shouldbe closed. When vacuum is at zero, stop the gland sealing system and close the generalmanual valve at 6.9m. Close pipe expansion attemperating water.



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2.7.4.8 Records the inertia time of rotor. Put turning gear into operation manually after rotor stops. After turning gear putting into operation, record rotor eccentricity, HP & IP cylinderexpansion, differential expansion, first stage temperature and axial displacement

periodically. During turning gear running, lubricate oil temperature should be within 38～

42 , keep sealing oil system of generator running normally. Listen to HP & LP gland℃ sealing sounds carefully. Supervise cylinder metal temperature changing strictly to avoid

cold steam or cold water entering into turbine.

2.7.4.9 Turning gear should keep in running until HP cylinder first stage metal inner walltemperature is less than 150 . During turning gear running after turbine stops, all℃ maintenance for systems relevant to turbine proper is prohibited to avoid cold air enteringinto cylinder. If any special situation occurs, it should be reported to general engineer andfollowing regulations should be executed:

2.7.4.10 When boiler absolutely does not need to be filled with water, stop deaerator heating,stop motorized feeding water pump, keep one circulating water pump running and stopcondenser water pump according to actual situation.

2.7.4.11 When LP cylinder steam discharging temperature decreases to be lower than 50 ,℃ one circulating water pump should be kept running after open circulating water systemstops.

2.7.4.12 Anti-freezing should be done well after stop in winter.

2.7.4.13 When load ≤300MW, record the cylinder temperature once per hour until the highesttemperature point decreases to 100 .℃

2.8 Maintaining after turbine stops

2.8.1 Maintaining princip les for stopping time less than one week

2.8.1.1 Discharge remaining water in hot well of deaerator and condenser.

2.8.1.2 Discharge the remaining water at steam side of HP & LP heaters.

2.8.1.3 All the steam water valves through which steam or water may enter into turbine should beisolated.

2.8.1.4 Open all the steam extraction pipelines, main steam, reheating steam pipelines anddrainage valves of turbine proper.

2.8.2 Maintaining princip les for stopping time more than one week

2.8.2.1 Above 1~4 measures should be executed.

2.8.2.2 Nitrogen should be charged to steam & water side of HP & LP heaters and deaerator formaintaining.

2.8.2.3 Accumulated water should be discharged for equipments that will stop for a long time.

2.8.2.4 Hot air should be used or drying for the long-term stop turbine.

3 Unit operation and maintenance

3.1 Operation and maintenance

3.1.1 Operators should periodically and rightly record the indications on meters according torequirements of operation log and record and abnormity and operations occurs duringshift.

3.1.2 When unit is in operation or standby, circuit check for equipments should be doneperiodically and routinely. Oil system should be checked to avoid fire accident. If anyproblem is found, it should be reported and cleaned by relevant department. Defectsshould be entered into computers and accident precautions should be done for defects.

When making isolation measures, make sure that it will not affect sampling by I&C; I&Cwill confirm it and dismantle protection that may act by mistake if it necessary.

3.1.3 Check operation conditions and supervise meter indications frequently. If any difference is



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found between meter indications and normal values, reason should be found out. Whenthere is defect, it should be reported to and necessary measures should be taken. Thecurrent, sound, temperature, vibration and bearing oil level of running equipments arenormal.

3.1.4 Standby equipments should be in good state and interlocks are in operation; bearing oil

quality is good and oil level is normal.3.1.5 Unit operation should be especially paid attention under following conditions:

3.1.5.1 Load changes acutely;

3.1.5.2 Steam parameters or vacuum changes acutely;

3.1.5.3 There is abnormal sound in turbine;

3.1.5.4 System is in failure;

3.1.5.5 Automation can not be put into operation.

3.1.6 Regulate operation mode reasonably and timely, analyze and treat the abnormity toensure safe and economic operation of the unit.

3.1.7 According to load variation, supervise and regulate turbine gland sealing steam pressureto ensure no air enters into turbine and no steam leaks from turbine.

3.1.8 The operators should do the periodic tests and transfer for equipments according toregulations and supervise the relevant personnel doing maintaining works such asperiodic oil filling, medium analysis, periodic bolts tightening and flushing meters and pipesetc.

3.1.9 Supervise the parameters and operation state of the running equipments strictly; exceptfor accident treatment, equipment is not allowed to run with over output.

3.1.10 Equipments newly put into operation or with defects should be inspected periodically andintensively supervised.

3.1.11 During unit operation, control equipment should be put into automation for supervising thereliability of automatic equipment; when automatic equipments is in failure, automationshould be cutoff and operate it manually to keep the parameters within permit range.

3.1.12 When abnormal working condition occurs or unit working condition changes greatly, theoperators on duty should cut off the relevant automatic regulation according to actualcondition and regulate it manually to ensure stable parameters. Cutting automation oroperating manually should be carefully done. Excessive regulation should be avoidedwhen regulating mill load, air fan output, main steam attemperating water and reheatingattemperating water. All aspects should be in contact and cooperation and coordination toavoid abnormity or accident.

3.2 Motor normal operation and maintaining

3.2.1 After maintenance of the motor, working personnel should conclude work permit ticketsand disclose the status and insulation resistant value to the operators.

3.2.2 Check items before motor start

3.2.2.1 Check and make sure that work permit ticket has been concluded, working personnel atlocal withdraw and there is no foreign material around the motor.

3.2.2.2 Check and make sure that power off protection and interlock devices are rightly put intooperation.

3.2.2.3 Check and make sure that motor and its driven equipment are with starting conditions anddo not run in reverse.

3.2.2.4 Bearing oil level is normal, oil is transparent with no foreign material and cover has no

defect. Oil system should be put into operation if oil circulating lubrication is adopted byforcing.



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3.2.2.5 For DC motors, rectifier bush should be in good contact, its surface should be smooth andspring pressure is proper.

3.2.2.6 Motor anchor bolts, earth wires, coupler, protection cover and connection box are fixed.

3.2.2.7 There is no block when turning gear manually and there is no block between stator androtor.

3.2.2.8 Electric meters and instrumental maters of motor and its driven equipment are completeand in operation.

3.2.3 Notice for motor start

3.2.3.1 Permit start times of rat cage type motor should be executed according to regulations fromthe manufacturer. If there is no regulation from the manufacturer, it can be decidedaccording to mechanical characteristics and start conditions of the motor. Under normalcondition, motor can be started for twice (2) with time interval of no less than 5min and can

be started once. Only motors that is in accident treatment and start time not exceeding 2～

3s can be started for once more. Motor produced by Shanghai Motor Co., Ltd only can bestarted again after four (4) hours of two (2) continuous starts in cold state and after 4 hoursof one (1) start in cold state. Motor should stop naturally during twice start operation.

3.2.3.2 Motor cold and hot state regulation:

1) Cold state: Motor temperature is under 60 ;℃

2) Hot state: Motor temperature is above 60 .℃

3.2.3.3 Current variation should be strictly supervised during motor start, if current does not returnafter start or current does change after closing switch or motor does not run, motor shouldbe stopped immediately. Start it again after finding out the reason.

3.2.4 Check during motor running

3.2.4.1 Current indication is stable and not exceeding rated value, otherwise, it should be reportedto the shift manager and measures should be taken according to indication. If current

indication reaches to maximum value suddenly, motor should be stopped immediately.

3.2.4.2 Motor sound is normal, vibration and axial moving do not exceed regulated value, indicatorlight is normal.

3.2.4.3 Temperatures of parts of motor do not exceed regulated values and there is no smoke,burning smell or over temperature.

3.2.4.4 Earth wires of motor shell and start device are in fine condition, anchor bolts are notloosened. Bearing oil level is normal with no oil spraying and oil leakage. Oil is transparentwith no foreign material and oil ring turns freely. Covers are well sealed.

3.2.4.5 There is no block in motor aeration, positions of cooling water valves and air channeldampers are right and there is no foreign material around motor.

3.2.5 Motor normal maintaining

3.2.5.1 Running motors that using oil ring to lubricate bearing should be added oil according to oillevel indications and rolling bearing should also be added with oil. Lubricant with same oilquality can be added with oil gun if it is necessary.

3.2.5.2 The changing of bearing lube oil is not less than one time in one year, bearing should becleaned completely when changing.

3.2.5.3 In normal condition,motor will hot as operating,although some area feel hot,motor heatstill in the limit range ,RIT or TC coil temperature is right.Measuring coil temperature(not temperature rising) is the basis of the motor safetyoperating.if using temperature measurer in the coil to measure the temperature,it doesnot pass 155 .if pass,the motor operating condition will be checked.℃

Stator temperature measurement,bearing temperature measurement and so ontemperature measurers are platinum resistance Pt100 as no special instruction.



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3.2.5.4 Stator temperature,bearing temperature’alarm and stop value should confirm according toactual operating condition,at the condition of highest circumstance temperature andbiggest load, the temperature of stator and bearing each add 5 will be the alarm℃

value,add 10 will be the stop value.℃

Stator temperature,bearing temperature’s alarm value and stop value （℃）

Bearing temperatureStator

temperature Rollbearing

Sliding bearing（ force

lubrication）

Sliding bearing （ auto

lubrication）

Alarmvalue

150 90 75 90

Stopvalue

155 95 80 95

3.3 Unit operation mode

3.3.1 Unit cont rol

3.3.1.1 Coordination control mode can be adopted for running when unit load is within 30%～

100%. Coordination control should be put into operation if there is no fault in system. Duringunit start and after three mills have been put into automation, coordination mode should beput into operation gradually and CBF should be chosen in priority. During normal operation,unit control mode is chosen according to equipment conditions and abnormity should betaken as following target. Coordination control should be rapidly released and manualregulation should be adopted to avoid accident, if any of following conditions occurs:

1) RB working condition occurs but RB function is not realized.

2) Regulation characteristic is getting worse and main parameters of the unit departuresfrom normal control range with no reply for a long time.

3) Unit is running with high load, main steam pressure continues to increase but mainsteam temperature decreases acutely. After generator-transformer unit trips, hot

standby of should be out and 500kV system should be put into closed-loop operation.

3.3.2 Unit cont rol mode

3.3.2.1 Unit fo llowing mode

1) Turbine following boiler (TFB): Boiler controls power and turbine controls pressure.

2) Boiler following turbine (BFT): boiler controls pressure, turbine controls power andpressure. This mode is common used mode that is transferred by changing buttons onCRT.

3.3.2.2 Base mode BASE

When boiler and turbine are in manual mode, control mode is base mode.

3.3.2.3 Boiler follow ing turbine (BFT)

1）In boiler following turbine mode, boiler automation should be put into operation to control

pressure and turbine controls power manually.

2） When boiler MFT, it transfers to turbine following boiler mode automatically.

3）When power measuring difference is big, it changes to turbine following boiler mode

automatically.

3.3.2.4 Turbine following boiler (TFB)

In turbine following boiler mode, turbine automation should be put into operation to controlpressure and boiler controls power manually.

3.3.2.5 Boiler fol lowing turbine coordination control sys tem (CCS)

1）In boiler following turbine mode, turbine automation should be put into operation and unit



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enters into boiler following coordination control system mode (CBF). This mode iscommon used coordination mode.

2）When RB occurs at boiler side, it changes to turbine following boiler mode automatically.

3）When boiler is in manual mode, it changes to turbine following boiler mode automatically.

3.3.2.6 Turbine follow ing turbine coordination cont rol sys tem (CCS)

1）In turbine following boiler mode, boiler automation should be put into operation and unit

enters into turbine following coordination control mode (CTF).

2） When RB occurs at turbine side, it changes to turbine following boiler modeautomatically.

3）When turbine is in manual mode, it changes to turbine following boiler mode

automatically.

3.3.2.7 Remote automatic dispatch system ADS

1）Unit can enter into ADS form CBF and CTF mode. In this control mode, middle power

dispatch authority is allowed to control the load of the unit.2） ADS mode may appear under CBF and CTF, and operation mode can be transferred

between these modes. ADS mode will be transferred to original control mode underfollowing conditions: load increase is blocked, load decrease is blocked, remotedispatch is invalid or unit is in load rejection. Unit maximum load and minimum load arestill valid in ADS mode.

3.3.3 Unit protection interlock operation mode

3.3.3.1 All protections and interlocks for running and standby equipments should be put intooperation. If there is any problem, protection or interlock needs to exit, it must be approvedaccording to relevant regulations. If any abnormal parameter is found during operationwhich is confirmed to be measuring loop fault or measuring element fault, I&C personnel

must be contacted for releasing the protection that may act by mistake. After powerequipment trips, electric protection must be checked firstly and then check the I&Cprotection; if the reason is unclear, this equipment can not be put into operation again(except for accident treatment).If standby equipment acts by interlock, the reason shouldbe completely found out and it is due to running equipment fault, it should be stopped formaintenance.

3.3.3.2 For generator-transformer unit, part protections can be stopped in emergency, but two kindprotections can not be stopped at the same time.

3.3.3.3 When any fault occurs to running electric equipments, protection and automatic deviceacts should be checked timely, report to the shift manager and take records. Signal canonly be recovered after a second person check and makes sure that this no mistake.

3.3.3.4 After unit trips, protections of ‘generator trips after turbine trips’ and ‘turbine trips aftergenerator trips’ should be released. After synchronization, protections of ‘generator tripsafter turbine trips’ and ‘turbine trips after generator trips’ should be put into operationimmediately.

3.4 Parameter supervision in normal operation

3.4.1 Parameter limit of turb ine

NO. Parameter Unit Normal High limit Low Trip

1 Running speed r/min 3000 3300

2 Load MW 600 647

3 Main steamtemperature

℃ 538 546 530 566（manual）



54

Parameter Unit Normal High limit Low TripNO.

4HP steam exhaust

temperature℃ 326.6 404 427

5 Back pressure KPa 60 65

6 Exhaust steamtemperature ℃ <70 80 120（manual）

7HP & IP cylinder

differentialexpansion

mm 10.3 -4.5 +11.1/-5.1

8LP differential

expansionmm 27 -3.5 +27.8/-4.3

9 Axial displacement mm 0.9 -0.9 +1.0/-1.0

10 Turbine bearingvibration

mm 0.125 0.25

11 EH oil pressure MPa 14±0.5 16.2 11.2 9.8

12 EH oil temperature ℃ 37～60 60 37

13 Lube oil pressure MPa 0.1~0.18 0.083 0.049

14 Lube oiltemperature

℃ 45～55

15 Jacking oilpressure

MPa

16 Bearing returningoil temperature

℃ 77

17 Support bearingtemperature

℃ 107 113

18 Thrust padtemperature

℃ 99 107

19 Main oil tank level mm 50 300 -200 -300

20 EH oil tank level mm 500～730 370 230(select)

21 Turbine glandsteam sealing

pressureKPa 27 30.99 10

22 Gland steamheater negativepressure

KPa

23 Condenser A hotwell level

mm 1580 1810 1350

24 Condenser B hotwell level mm 480

1120(I)

1600(II)

250(I)

100(II)

25 LP gland sealingsteam temperature

℃ 150 177 121



55

3.4.2 Feed water pump group parameter limit

NO. Parameter Unit Normal High limit Low limit Trip

Feed water pump turbine

1Running speed r/min 3100--5900 Electrical:6050

Mechanical:6160

2 Exhaust steam pressure KPa 25 30

3 Exhaust steam temperature ℃ 40～50 90 120

4 Bearing vibration mm 0.036 0.08 0.13

5 Lube oil pressure MPa 0.137

6Differential pressure

between front and rear lubestrainer

KPa 90

7 Lube oil temperature ℃ 40～45

8 Axial displacement mm +0.18 -0.18 0.25

9Support bearing

temperature℃ 95 115

10 Thrust bearing temperature ℃ 100 115

11Gland steam sealing

pressureKPa

12Gland steam sealing

temperature℃ 150～177 190

Booster pump, main pump

1Booster pump radial bearing


2 Booster pump outlet flow t/h 1179

3Booster pump inlet strainer

differential pressureKPa 60

4Booster pump motor radial

bearing temperature℃ 80 90

5Main pump thrust bearing


6 Main pump support bearingtemperature

℃ 90 100

7 Main pump mechanicalsealing water temperature

℃ 80 90

Motorized pump

1 Booster pump support bearingtemperature

℃ 90 100

2 Motor support bearingtemperature

℃ 80 90

3 Booster pump thrust bearingtemperature℃

90 100



56

Parameter Unit Normal High limit Low limit TripNO.

4 Motor coil temperature ℃ 135 140

5 Main pump support bearingtemperature

℃ 90 100

6 Main pump thrust bearingtemperature ℃ 90 100

7 Main pump mechanical sealingwater temperature

℃ 80 90

8 Coupler support bearingtemperature

℃ 90 95

9 Coupler thrust bearingtemperature

℃ 90 95

10 Main pump support bearingvibration

mm 0.036

11 Lube oil pressure KPa 250～350 150 80

12 Lube oil strainer differentialpressure

KPa 80

13 Working oil cooler inlettemperature

℃ 110 60 130

14 Working oil cooler outlettemperature

℃ 75 35 85

15 Lube oil cooler inlettemperature

℃ 65 45 70

16 Lube oil cooler outlettemperature℃

55 35 60

17 Main pump water inlet & outletwater ends sleeve differential

temperature

℃ 25

18 Main pump inlet flow t/h 1179

3.4.3 HP & LP heater, deaerator parameter limit

No. Parameter Unit Normal High limit Low limit Override

1#1 HP heaterwater level

mm -802 -764(I)、-714(II) -840 -664


mm -736 -698(I)、-648(II) -774 -598


mm -690.5 -652.5 (I)、-602.5(II) -728.4 -552.5

4#5 LP heaterwater level

mmNot

availableNot available Not available 540

5#6 LP heaterwater level

mmNot

availableNot available Not available 555

6#7 LP heater

water level

mmNot

available

Not available Not available 787

7 #8 LP heater mm Not Not available Not available 787



57

Parameter Unit Normal High limit Low limit OverrideNo.

water level available

8Deaerator water

levelmm 1100

1300(I)、1400(II)

1600（Ⅲ） 900(I) -1140(II)

Notavailable

3.4.4 Generator hydrogen, oil and water system parameter limit

Parameter Unit Rated Normal High limit Low limit Trip value

Hydrogenpressure ingenerator

MPa 0.4 0.38~0.42 0.43 0.385

Hydrogenpressure

MPa 0.35

Cold hydrogentemperature ingenerator

℃ 45 44~46 48 42Hydrogen

Hydrogen purity

in turbine

% 98 95~98 100 95 90

Input waterpressure

MPa 0.25~0.35 0.25~0.35 0.36 0.2Hydrogen

cooler Input water flow m3/h 240 230~250 75%of

Normal30%ofNormal

Total input watertemperature

℃ 45~50 45~50 60 40

Total outputwatertemperature

℃ 69~75 69~75 85 90

Stator bartemperature

between stage

℃ ＜90 90

Output watertemperaturedifferencebetween statorbar in samestage

℃ ＜8 8 12

Total input waterpressure

MPa 0.25~0.35 0.25~0.35 0.36 0.20

Statorcoil

Total input flow m3/h 90 87~93 66% 52%

Stator coolingwater filter

pressuredifference

MPa 0.02~0.04 Higherthan actual

0.021

Stator coolingwater tank level

mm 500~550 650 450

Stator coolingwater tankpressure

MPa 0~0.01 0.04

Stator coil waterpressuredifference

MPa Higherthannormal0.035

Ion exchanger

conductivity

μS/cm 0.1~0.2 0.5

Stator coil inputwater

μS/cm 1.0~1.5 High：5

Super





59

Control index (under different drum pressure)（MPa））Name Item

3.8-5.8 5.9-12.6 12.7-15.6 15.7-18.3

Dissolved oxygen (ug/L) ≤50 ≤50 ≤40 ≤30

Conductivity (uS/cm) ≤0.3 ≤0.3

Sodium（ug/L） ≤10 ≤10

Condensingwater

Silicon dioxide（ug/L） ≤15

Rigidity (umol/L) ≈0 ≈0

Conductivity (uS/cm) ≤0.15 ≤0.15

Sodium（ug/L） ≤10 ≤10

Silicon dioxide（ug/L） ≤20 ≤20

Iron（ug/L） ≤8 ≤8

Outlet ofcondensing

mixture

Copper （

ug/L）

≤3 ≤33.4.5.2 Inner-cooled water

IndexName Item

Standard Control standard

Conductivity（μs/cm）

（25℃） ≤2.0 ≤2.0

PH（25℃）＞6.8 8.5＞PH＞7.0

Rigidity（μmol/L） 0 0

Inner-cooledwater

Copper （μg/L） ≤40 ≤28

3.4.5.3 Turbine new oil quality standard

Quality standardNo. Item

#20 #32

Remark

1 Appearance Transparent Transparent

2 Mechanical impurity None None

3 Moving viscidity (mm2/s) 18-22 28-32 30℃

4 Flash point ( )℃ 180≮ 180≮

5 Solidifying point( )℃ ≯-15 ≯-15

6 Acid number (mg KOH/g) 0.03≯ 0.03≯

7 Oxidation acid number

(mg KOH/g)

0.2≯ 0.2≯

8 Sediment after oxidation（%） 0.1≯ 0.1≯

9 Emulsification break (min) 8≯ 8≯

10 Water-solubil ity acid or alkali None None

11 Sodium hydroxide test(grade)

2 2



60

3.4.5.4 Turbine oil quality standard

No. Item Quality standard Supervision method orusage standard

1 Appearance Transparent Eyeballing

2 Water content None Eyeballing or YS-12-1-783

Moving viscidity (mm2/s)Less than or equals to 1.2

new oil standardGB265-75 YS-9-1-84

4Flash point ( )℃

No less 8 lower than former℃

measured valueGB267-77

5 Mechanical impurity None GB511-77 or Eyeballing

6 Acid number (mg KOH/g) 0.2 GB264-83

7 Hydraulic rust No rust YS-21-1-84

8 Emulsification break (min) 60 YS-C-1-1-84

3.5 Periodic work

3.5.1 Periodic work during normal running

No. Work content Date Shift Operator Supervisor Requirement

1 I&C signal test Once per shiftWhen

changingshift

Vice dutyoperator

--Light and sound are

normal

2Clean trash remover outlet of

circulating water pump strainerOnce per shift Inspector -- Clean it timely if it is dirty

3Calibration of local & remote

water level indicators ofdeaerator and condenser

Once per shiftDuty

operator,inspector

-- Indications on metersare in consistent

4Turbine AC & DC oil pump

interlock, manual start test, HVstandby pump start test

8th,every monthMorning

shiftDuty

operator Unit chief

EOP should run for morethan 30min

5Condenser water pump

transfer8th,every month

Afternoonshift

Dutyoperator

Unit chief

6

Feed water pump turbinetransfer

DC oil pump start test

8th,every monthLatter

night shiftDuty

operator Unit chief

DC oil pump shouldcontinuously run for

more than 10min

7 Mechanical vacuum pump 9th,every monthLatter

night shiftInspector

Dutyoperator

Measuring insulationbefore start

8Closed circulating water


Afternoonshift

Inspector Duty

operatorMeasuring insulation

before start

9 Open circulating water transfer 9th,every monthUp night

shiftInspector

Dutyoperator

Measuring insulationbefore start

10Boiler feed water pump start

test10th,every month

Latternight shift

Inspector --Running should be more

than 30min

11 Oil pump transfer 10th,every month Afternoon

shiftInspector Unit chief

12 Gland steam air fan transfer 10th,every monthUp night

shiftInspector

Dutyoperator



61

No. Work content Date Shift Operator Supervisor Requirement

13

Boiler water pump emergencystop

Cooling water pump start



Dutyoperator

Running should be morethan 30min

14 Boiler water pump coolingwater booster pump transfer 11th,every month Afternoonshift Inspector Dutyoperator

15 DC sealing oil pump start test 11th,every monthUp night

shiftDuty

operator Unit chief

DC oil pump shouldcontinuously run for

more than 10min

16Turbine oil tank, A&B feedwater pump turbine oil tank

water discharging12th,every month

Latternight shift

Inspector --

17Stator cooling water pump


Morningshift

Dutyoperator

Unit chief

18Motorized pump auxiliary oilpump low pressure test,motorized pump start & stop

test

12th,every month Afternoon

shiftInspector

Dutyoperator

Oil pump shouldcontinuously run for

more than 10min

19Turbine oil tank air dischargingair fan and generator air sideair discharging air fan transfer

12th,every monthUp night

shiftInspector

Dutyoperator

20 Turbine vacuum tightness test 13th,every monthMorning

shiftDuty

operator Unit chief 550MW≥load≥480MW

21Feed water pump HP & LP

main steam valve moving test13th,every month

Up nightshift

Dutyoperator

Unit chiefThere is no block after

low load

22Stator water tank, main oil tank

and air discharging pointhydrogen measurement

13th,every month Afternoon

shiftInspector --

23Main steam valve, governor

valve tightness testOnce per year Unit chief

Shiftmanager

Execute after shutdownevery year

24Generator hydrogen leakage

detection test15th,every month

Morningshift

Inspector Duty

operator

Start from 11:00 andcomplete it at 11:00 in

the next day

25Turbine steam extractioncheck valve moving test



Dutyoperator

300MW—400MW

26Turbine HP main steam valve& governor valve moving test

8th, 14th

, 20th, 26

th

every monthUp night

shiftDuty

operator Unit chief

Load is less than 420MW,supervise it normally andcontact with I&C to

complete it

27Emergency protector action

testFour times every

yearDuty

operator Unit chief

Execute during start everyseason

28Sealing oil strainer dirty

discharging15th,every month

Afternoonshift

Inspector Duty

operatorPay attention to sealing

oil pressure

29Miscellaneous water pump

transfer test22nd,every month

Morningshift

Vice dutyoperator

Dutyoperator

30 Oil filter transfer Morningshift

Vice dutyoperator

Dutyoperator

Oil filter front and reardifferential pressure≥0.05MPa



62

3.5.2 Work before and after maintenance

No. Item Requirement

1 Turbine over speed

Two tests after major maintenance, action running

speed is 3300～3330r/min, running speed

difference between two actions <18r/min

2Oil filling for emergency protector and filling oil speed rise

test After maintenance or 6～12 months after

maintenance

3 Turbine, boiler, generator main protection tests After unit major & minor maintenance

4 Auxiliary equipments interlock and protection tests After unit major & minor maintenance

5 Motorized valve and pneumatic valve test After unit major & minor maintenance

6 Turbine speed regulation system captive test After major maintenance or regulating speed

regulation system

7 Main steam valve, governor valve tightness test Before and after major maintenance

8 Safety valve calibration of HP&LP heaters, deaerator,auxiliary steam system and boiler steam water system

After major maintenance or safety valve regulation

9 Deaerator hydraulic tests Once every six years

10 Over speed test of feed water pump turbine After major maintenance or regulating speed

regulation system

11 Unit thermal testOnce before and after major maintenance

respectively

3.6 Unit interlock protection and test

3.6.1 Turbine interlock protecti on

3.6.1.1 Turbine main protection

1）Over speed mechanical trip

When turbine running speed reaches to 110％～111％ of rated running speed, mechanical

emergency governor actuates; LP protection oil is discharged through sliding valve ofmechanical emergency governor, diaphragm valve opens to make AST oil head pipe dischargeoil, to close HP & IP main steam valves and governor valves and to close all stages steamextraction check valves and HP steam discharging check valves, and then the turbine stops.

2） Local manual mechanical trip

This trip device lies in front of turbine front box. During operation, turn it for 90° and then pull itout; LP protection oil is discharged through sliding valve of mechanical emergency governor,

diaphragm valve opens to make AST oil head pipe discharge oil, to close HP & IP main steamvalves and governor valves and to close all stages steam extraction check valves and HPsteam discharging check valves, and then the turbine stops.

3） Remote manual trip

Two buttons are installed on DEH panel in main control room. During operation, press the twobuttons at the same time, then four automatic stop emergency governor protecting solenoid

valves （ AST-1.2.3.4）actuate to make AST oil head pipe discharge oil, to close HP & IP main

steam valves and governor valves and to close all stages steam extraction check valves andHP steam discharging check valves, and then the turbine stops.

4) Any of the following abnormities occurs, automatic stop emergency governor protecting

solenoid valves （ AST-1.2.3.4）actuate, and then turbine trips:

a. Unit bearing vibration reaches to 0.25mm;

b. Turbine lubricate oil pressure is low as 0.049MPa;



63

c. Thrust bearing abrasion is high and axial displacement reaches to ±1.0 mm;

d. EH oil pressure is low ≤8.5MPa;

e. Condenser vacuum is ≥65KPa(absolute value);

f. HP IP differential expansion reaches to 11.1mm (Rotor extends) or —5.1mm (rotor shortens);

g. LP differential expansion reaches to 27.8mm (Rotor extends) or —4.3 mm (rotor shortens);

h. Turbine generator unit supporting bearing metal temperature reaches to 113 ;℃

i. Turbine thrust bearing metal temperature reaches to 107 ;℃

j. DEH TSI over speed ≥3300r/min;

k. Generator main protection actuates (turbine trips after generator trips);

l. Boiler MFT (turbine trips after boiler MFT);

m. DEH loses power.

5） Stop the turbine manually if any of the following happens:

a. Reach over speed protection value, but turbine over speed protection device does notactuate;

b. Protection device does not actuate when unit vibrates heavily;

c. Turbine impeller blade breaks or there is obvious metal friction sound in cylinder;

d. There is water impact in turbine;

e. There is friction sound or spark at turbine gland sealing;

f. Any bearing of turbine is in short of oil or in smoke;

g. Oil system is on fire or there is fire around turbine generator unit, which can not beextinguished and threatens safety operation;

h. Smoke comes out from generator or hydrogen explodes;

i. LP cylinder steam exhausting temperature is within 80～120 and running exceeds 15min or℃

the temperature is higher than 120 ;℃

j. HP & IP up and down cylinder metal temperature difference reaches to 56 ;℃

k. Main steam temperature exceeds 565 ;℃

l. Reheating temperature exceeds 565 ;℃

m. Main steam, reheating steam temperature decreases to 454 ;℃

n. Bearing returning oil temperature is higher than 82 ;℃

o. Turbine lubricate oil tank level is lower than normal level 300mm;

p. Control value reaches to protection device actuation value, but protection refuses to actuate.

3.6.1.2 OPC interlock protection

1) When load is ≥30% rated load, generator overrides, over speed limit solenoid valveactuates to discharge over speed limit oil (OPC), all steam regulating valves close quicklyunder forces of valve operation seat spring and steam pressure. When running speeddecreases to 3090r/min, over speed limit solenoid valve recovers and opens all thesteam regulating valves again to keep turbine running speed of 3000r/min.

2) When running speed reaches to 103% rated running speed, over speed limit solenoidvalve actuates to discharge over speed limit oil (OPC), all steam regulating valves closequickly under forces of valve operation seat spring and steam pressure. When running

speed decreases to 3090r/min, over speed limit solenoid valve recovers and opens allthe steam regulating valves again to keep turbine running speed of 3000r/min.

3.6.1.3 Turbine oil system interlock pro tection



64

1) When bearing lubricate oil is lower than 0.083MPa, #1 AC lubricate oil pump startsautomatically and alarm;

2) When bearing lubricate oil is lower than 0.076MPa, #2 AC lubricate oil pump startsautomatically and alarm;

3) When bearing lubricate oil is lower to 0.06MPa, start DC lube oil pump and stop unit put

turning gear into operation;

4) When bearing lubricate oil is lower to 0.03MPa, switch to auto turning gear and interruptturning gearing manually.

5) When jacking oil pump inlet oil pressure is lower than 0.0823MPa, AC lubricate oil pumpstarts automatically;

6) When turbine running speed increase more than 200 r/min, jacking oil pump stopsautomatically; running speed decrease to 200 r/min , jacking oil pump startsautomatically;

7) When turbine oil tank oil temperature is lower than 25 , electric heaters put into℃

operation automatically; when the temperature is higher than 30 , electric heaters stop℃

automatically;8) When EH oil pressure is lower than 11.2MPa, standby EH oil pump starts automatically;

9) When EH oil temperature is lower than 15 , electric heaters put into operation; when it℃

is higher than 25 , heaters stop;℃

10) When EH oil temperature is higher than 55 , put cooling water solenoid valve into℃

operation and circulating water pump starts automatically; when the temperature islower than 40 , close cooling water solenoid valve and circulating water pump stops℃

automatically;

11) EH oil tank level is lower than 370mm, it alarms;

3.6.1.4 LP steam exhausting cylinder water spraying protection interlock

1) LP steam exhausting cylinder water spraying is under automatic control, when runningspeed reaches to 600r/min, it starts to spray water until unit is running with 15% load.

2) When LP cylinder steam exhausting temperature reaches to 70 , LP steam exhausting℃

cylinder water spraying system puts into operation automatically; When LP cylindersteam exhausting temperature reaches to 80 ,℃ alarm, and if reach to 120 , stop unit℃

at once.

3.6.1.5 Bypass system protection

1) Conditions for automatic open of HP bypass control valve

a. Main steam pressure exceed regulating value when pressure recover to rated valueand lower than it, HP bypass close automatically;

b. When turbine trip, auto main steam valve close;

c. When outlet switch of generator trip;

d. When generator reject 60% load or more than 60%.

2) Conditions for automatic close of LP bypass control valve:

a. HP & LP condenser vacuum is low to 60KPa.

b. HP & LP condenser steam exhausting temperature ≥120 .℃

c. Condenser hot well water level is high to 1300mm.

d. LP bypass outlet temperature is high to 160 .℃

e. LP bypass attemperating water pressure is low to 1.5MPa.



65

3.6.1.6 Turbine turning gear device interlock protection

1) Automatic start conditions for turning gear motor:

a. Turning gear motor interlock switch is at ‘Automatic’;

b. Bearing lubricate oil pressure ＞0.028MPa;

c. All jacking oil pressures are not low;

d. Turning gear motor has no electric fault;

e. Turning gear device is at ‘Automatic’;

f. Turbine tripped;

g. Turbine running speed is zero (0).

2) Turning gear motor trips when any of the following conditions occurs:

a. Any jacking oil pressure ＜ 6MPa;

b. Bearing lubricate oil pressure ＜ 0.028MPa;

c. Turning gear motor has electric fault;

d. Shaft protection is in fault.

3.6.1.7 Turbine water entering proof protection

1) When turbine load is lower than 20％, following drainage valves start automatically:

a. Drainage valves after first extraction motorized valve and before check valve;

b. Drainage valves after second extraction motorized valve and before check valve;

c. Drainage valves after third extraction motorized valve and before check valve;

d. Drainage valves before and after fourth extraction motorized valve, before first checkvalve and after second check valve;

e. Drainage valve of fifth extraction motorized valve;

f. Drainage valves before and after fifth extraction check valve;

g. Drainage valves before and after sixth extraction check valve;

h. Main steam head pipe drainage valve;

i. Drainage valve after main steam governor valve;

j. Drainage valve at hot section head pipe;

k. Drainage valves before and after HP steam exhausting check valve.

2) After boiler ignition, check and make sure that condensing water system, circulating water

system, vacuum system run normally; all drainage valves at turbine side should beopened according to actual situation. When load is higher than 20％, close all the

drainage valves (following drainage valve are closed automatically); during stopping theunit, when load is lower than 20%, unit drainage water valves should be opened manually:

a. HP & IP cylinder inner cylinder drainage water;

b. HP & IP cylinder outer cylinder drainage water;

c. HP governor valve guiding pipe drainage water;

d. IP governor valve guiding pipe drainage water.

3.6.1.8 HP heater water level protection

1) HP heater water level high value, alarm;Ⅰ

2) HP heater water level highⅡ value, HP heater emergency drainage water opens byinterlock;



66

3) HP heater water level high value, any two of switch value, high value simulationⅢ Ⅲ

value and high value switch value reach to actuation value, HP heater overrides andⅡ

HP heater water side bypass works, HP heater steam extraction motorized isolationvalve and check valve close and steam extraction pipeline drainage water open at thesame time.

4) HP heater water level low value, alarm;Ⅰ

3.6.1.9 LP heater water level protection

1) LP heater water level high value, alarm;Ⅰ

2) LP heater water level highⅡ value, LP heater emergency drainage water opens byinterlock;

3) LP heater water level high value, any two of switch value, high value simulationⅢ Ⅲ

value and high value switch value reach to actuation vaⅡ lue, LP heater overridesand LP heater water side bypass works, LP heater steam extraction motorizedisolation valve and check valve close and steam extraction pipeline drainage wateropen at the same time.

4) LP heater water level low value, alarm.Ⅰ 3.6.1.10 Deaerator water level and pressure protection

1) When deaerator pressure is lower than 0.15MPa, motorized isolation valve from fourthsection steam extraction to deaerator closes by interlock, motorized valve of standbysteam source opens by interlock, standby steam source puts into operation(transferred to be fourth section steam extraction before putting HP heater intooperation);

2) When deaerator pressure is higher than 0.15MPa, standby air source motorized valveclose by interlock; motorized isolation valve from fourth section steam extraction todeaerator opens by interlock.

3) Deaerator water level high value,Ⅰ open deaerator overflow valve by interlock.

4) Deaerator water level highⅡ value, deaerator emergency water discharging valveopens by interlock.

5) Deaerator water level high value,Ⅲ close water level main governor front and backmotorized valve of deaerator and motorized valve of bypass by interlock.

6) Deaerator water level low value, alarm.Ⅰ

7) When deaerator water level low value and deaerator low value hydraulic level actsⅠ

(or soft act produced by deaerator water level transmitter), booster pump of steamdriven pump and motorized pump trip by interlock.

8) When feeding water flow is higher than 30%, deaerator water level is allowed to be

transferred from single impulse to three pulses.3.6.1.11 Steam extraction check valve interlock :

1) When all steam extraction check valves, HP cylinder steam discharging checkvalves are at ‘Automation’ position and turbine main steam valve trip device closes,all above valves close by interlock.

2) When all steam extraction check valves, HP cylinder steam discharging checkvalves are at ‘Manual’ position, all above valves can be opened or closedindividually.

3.6.1.12 Pump equipment interlock

1) Condensing water pump trips or outlet head pipe pressure is lower than 2.5MPa,

standby pump puts into operation by interlock.2) Circulating water pump trips, standby pump puts into operation by interlock.



67

3) Vacuum pump trips, standby pump puts into operation by interlock.

4) When open cooling circulating water pump trips or outlet head pipe pressure is lowerthan 0.20MPa, standby pump puts into operation by interlock.

5) When closed cooling circulating water pump trips or outlet head pipe pressure islower than 0.35MPa, standby pump puts into operation by interlock.

6) When stator cooling water pump trips or outlet head pipe pressure is lower than0.40MPa, standby pump puts into operation by interlock.

7) When turbine oil tank discharging air fan trips, standby discharging air fan puts intooperation by interlock.

3.6.1.13 Steam driven feed water pump main protecti on

1) Local stop button

a. Press ‘Emergency stop’ button on front bearing box of feed water pump turbine,stop solenoid valve actuates to discharge control oil and close HP & LP mainsteam valve and governor valve, the turbine stops.

b. Press ‘Emergency stop’ button on operation panel in earth room, stop solenoidvalve actuates to discharge control oil and close HP & LP main steam valve andgovernor valve, the turbine stops.

c. Press ‘Emergency stop’ button DSC-CRT, stop solenoid valve actuates todischarge control oil and close HP & LP main steam valve and governor valve, theturbine stops.

2) Remote stop button

3) Protection actuates to stop the turbine if any of following abnormities occurs insteam driven feed water group:

a. Feed water pump turbine bearing vibration is high to 0.125mm;

b. Rotor axial displacement is high to ±0.25mm;

c. Lubricate oil pressure is low to 0.07MPa;

d. Steam exhausting pressure reach to 30KPa;

e. Feed water pump turbine is in over speed to 6050r/min;

f. Feed water pump turbine steam discharging temperature is 120 ;℃

g. Booster pump stops;

h. MEH loses power;

i. LP safety oil pressure is low to 0.25MPa;

j. Oil tank level low to 400mm;k. Bearing metal temperature at water inlet & outlet side of steam driven pump

≥100 ;℃

l. Steam driven feed water pump thrust bearing temperature ≥100 ;℃

m. Mechanical sealing water temperature at water inlet & outlet side of steam drivenpump ≥90 ;℃

n. Steam driven feed water pump inlet flow low, overtime 90s and recirculating valveis not open.

o. Steam driven feed water pump inlet pressure is low, overtime 3s;

p. Deaerator level low II, overtime 3s;

q. Turbine trip.

r. Local emergency button is pressed down.



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3.6.1.14 Steam driven pump booster pump trip protection

1) Deaerator level low II, overtime 3s;

2) Booster pump drive end, non-drive end bearing temperature ≥100 ;℃

3) Booster pump inlet valve is closed;

4) Steam driven feed water pump inlet flow low, overtime 90s and recirculating valveis not open.

5) Steam-drive feed water pump trip, overtime 3s.

6) Booster pump inlet pressure low, overtime 30s.

7) Local emergency button is pressed down.

3.6.1.15 Motorized feed water pump trip protection

1) Motorized pump inlet flow is low, and minimum flow valve position<30%.

2) Deaerator low, overtime 3s;

3) Motorized pump inlet pressure is low, overtime 3s.

4) Oil pressure after lubricate oil filter of motorized pump ≤0.08 MPa, the pump trips.

5) Motorized pump operated 30s and outlet valve closed.

6) Motorized pump inlet, outlet end radial bearing temperature ≥90 , alarms;℃

≥110 , the pump trips.℃

7) Motorized thrust bearing temperature ≥90 , alarms; ≥110 , the pump tri℃ ℃ ps.

8) Motorized pump motor coupler end bearing temperature ≥80 , alarms; ≥90 ,℃ ℃

the pump trips.

9) Motorized pump booster pump drive end and non-drive end radial bearingtemperature ≥90 , alarms; ≥100 , the pump trips.℃ ℃

10) Motorized pump motor non-drive end thrust bearing temperature ≥90 , alarms;℃


11) Motorized pump inlet & outlet end sealing water temperature ≥80 , alarms;℃


12) Motorized pump motor drive end and non-drive end radial bearing temperature≥80 , alar ℃ ms; ≥90 , the pump trips.℃

13) Motorized pump hydraulic coupler radial bearing & thrust bearing temperature≥90 , alarms; ≥95 , the pump trips.℃ ℃

14) Motorized pump lubricate oil cooler inlet oil temperature ≥65 , alarms; ≥70 ,℃ ℃

the pump trips.

15) Motorized pump lubricate oil cooler outlet oil temperature ≥55 , alarms; ≥60 ,℃ ℃

the pump trips.

16) Motorized coupler working oil cooler inlet oil temperature ≥110 , alarms; ≥130 ,℃ ℃

the pump trips.

17) Motorized pump coupler working oil cooler outlet oil temperature ≥75 , alarms;℃


18) Local emergency stop button is pressed down.

3.6.1.16 Motorized feed water pump system interlock protection

1) During motorized pump running, lubricate oil pressure after lubricate oil filter ≥0.22

MPa, the auxiliary oil pump stops in interlock.2) During motorized pump running, lubricate oil pressure after lubricate oil filter ≤0.15

MPa, the auxiliary oil pump stops in interlock.



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3) Oil pressure after motorized pump working oil 0.3 MPa＜p＜0.4 MPa.

4) Motorized pump working oil pressure is normally ≥0.17 MPa.

5) Working oil pressure before motorized working oil control valve ＞0.1 MPa.

6) Working oil pressure after motorized pump spoon pipe ＞0.15 MPa.

3.6.1.17 Condensing water pump

1) Condensing water pump up & down bearing temperature ≥95 .℃

2) Condensing water pump motor thrust bearing ≥80 .℃

3) Inlet valve of condenser water pump is confirmed to be closed.

4) Condensing water flow ≤380t/h and condensing water re-circulating valve doesnot open with a timely of 15s.

5) Hot well water level low II value ≤100mm and water level low I value ≤250mm.

6) Press emergency stop button locally.

3.6.1.18 Generator hydrogen, oil and water system interlock protecti on1) Front and rear differential pressure of AC sealing oil pump at air side is less than

0.035MPa, DC sealing oil pump starts by interlock.

2) Main oil pump is working and AC oil pump at air side is in operation; whenhydrogen-oil differential pressure decreases to 0.056MPa, standby differentialpressure valve actuates and first standby oil source puts into operation controlledby standby differential pressure valve automatically.

3) Main pump does not work normally and AC oil pump at air side is in operation;when hydrogen-oil differential pressure decreases to 0.056MPa, HP sealing oilstandby pump starts automatically, standby differential pressure valve actuatesand second standby oil source puts into operation automatically.

4) AC oil pump at air side is in operation; when hydrogen-oil differential pressuredecreases to 0.035MPa, third standby oil source of DC standby oil pump at airside starts automatically.

5) Stator water pump out and inlet differential pressure ＜0.14MPa, standby pump

starts with a time delay of 3－5s.

6) When stator water tank level is low than 450mm, make up water solenoid valveopens.

7) When generator stator winding inlet water conductivity is >9.5μs/cm, reject load or

stop the unit.

8) When stator water flow is <52% rated flow, generator trips with a time delay of

30s.

3.6.1.19 Other interlock protecti ons of the turb ine

1) When condensing water pump outlet head pipe pressure is lower than 2.5MPa,standby condensing water pump starts by interlock.

2) 300m3 water tank level ≤1.2m, condensing water transportation pump trips.

3) When open circulating water pump outlet head pipe pressure is lower than 0.20MPa,standby open circulating water pump starts by interlock.

4) When closed circulating water pump outlet head pipe pressure is lower than0.35MPa, standby closed circulating water pump starts by interlock.

5) When closed circulating water tank level is lower than 700mm, closed circulatingwater pump trips.

6) When condenser vacuum is lower than 75KPa, standby vacuum pump starts by



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interlock.

7) When condenser hot well water level is high to 710mm, it alarms.

8) When condenser hot well water level is low to 250mm, it alarms.

9) When condensing water pump motor winding temperature is high to 105 , it℃

alarms.10) When boiler circulating water pump cooling water booster pump returning pipe

pressure is lower than 0.45MPa, the pumps run together.

11) When boiler circulating water pump cooling returning pipe pressure is lower than0.45MPa, emergency cooling water pump starts.

3.6.2 Unit test

3.6.2.1 Unit interlock protection test

Equipments and systems interlock protection test should be simulated by I&C personnelafter all the test conditions are satisfied (unsatisfied conditions should be forced by I&Cpersonnel) to check whether actions and alarms are normal or not.

3.6.2.2 Motorized valve (damper) and pneumatic valve (damper) test

Before test, make sure that motorized valves (damper) turning directions are right,pneumatic valve (damper) switches are right and light signal status indications are right.Record the time and act information of all the valves (dampers) and switches.

3.6.2.3 Main steam valve and governor valve test

1) Test regulations and notices

a. DEH chooses ‘Automation’ mode and CRT shows relevant screens.

b. DEH must be under ‘Single valve’ control mode and test should be done with 5%～

69% rated load and 25%～100% rated main steam pressure. Tests out of the above

range are strictly prohibited.c. Test should be done from left side to right side; tests can not be done on both left and

right side at the same time. An other side test only can be done after one side valvetest and five (5) minutes stable operation

d. Parameters (such as load, main reheating steam pressure and temperature, bearingmetal temperature, vibration and axial displacement) should be supervised duringtest.

e. Contact with I&C personnel for cooperation at site, test should be stoppedimmediately if abnormal change occurs during test or control device is changed to bemanual. Test can only be restarted after valves are recovered manually and reasonfor abnormity is found out.

f. During test, make sure that whether valves act normally or not, there is block or not.Test time for each side should be recorded.

g. When DEH manual, full stroke test is not allowed be done and only flexibility test canbe done.

h. It is regulated that this test should be done once a week and operation log should berecorded. Test period can be extended to once per two weeks if special conditionoccurs and it is approved by the managers.

2) Test method

a. Make sure that DEH is at ‘Automatic’ and ‘Single Valve’ button light is on.

b. Unit load and pressure complies with regulated range.c. Click “TV1” on DEH screen and then click “TEST” (take #1 HP main steam valve as

an example) button, button changes color. The test starts.



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d. The governor valves GV1/GV4 at the same side of selected main steam valve closeby speed of 1.5%/s at first, after governor valves closed, TV1 close by speed of1.5%/s, it should be confirmed from CRT and local that valves are closed and actfreely.

e. After TV1 fully closed, open it by speed of 1.5%/s, when TV1 fully opened, governor

valves GV1/GV4 open by speed of 1%/s. It should be confirmed from CRT and localthat valves are open. When GV opened again and reach to the position same as theposition before test, test is over.

f. During close or start, press ‘Intermit Test’ button if any abnormity occurs and valvesrecover to status before test.

g. Test other main steam valves according to above process.

3.6.2.4 Steam extraction check valve test

1) Turn test switch of steam extraction check valve to ‘Test’ position.

2) Check and make sure that all check valves close freely with no block.

3) Turn test switch to normal position as soon as possible to confirm open of check valve.

4) During test, it should not be closed for too long a time. Pay attention to unit load and axialdisplacement variation.

5) Test all the steam extraction check valves one by one with the same process.

3.6.2.5 Low oil pressure interlock test for auxil iary lubricate oil pump, hydrogen sealing oilstandby pump and DC lubricate oil pump

1) Check and make sure that all the switches of the above pumps are at ‘Interlock’ position.Test personnel should be in contact with main control room and open test oil dischargingvalve slowly.

2) Watch test oil pressure meter indication and record the oil pressure when oil pump isinterlocking; check and make sure that oil pump runs normally.

3) Stop the interlocked oil pump.

4) Turn the switches of test oil pump to ‘Automation’.

3.6.2.6 Jacking oil pump and turning gear low oil pressure test

1) Turbine oil system and sealing oil system are running normally.

2) Jacking oil and turning gear system are running normally.

3) Contact with I&C personnel to prepare conditions of oil pressure low.

4) Record oil pressures when jacking oil and turning gear trip.

3.6.2.7 Turbine protection device test


a. According to periodic test regulations, test should be done once per month, restrecords should be taken and analyzed and compared with former test record.

b. Reason should be found out and it should be cleaned if any error is found.

c. This test must be done before starting the turbine and after protection devices arecalibrated and set in unit major maintenance and minor maintenance. Oil control overspeed trip valve test should be done when turbine speed is 3000r/min.

d. When turbine speed increases to 3000r/min, protection test should be qualified beforesynchronization and load increase.

e. The production chief and engineers of the test must be at site and strictly executeoperation and supervision mechanism, and special person will be responsible foroperation and supervision.





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pressure switch oil pressure isolation valve, slowly open drain oil valve, when

pressure meter reduce to0.035MPa,air side DC sealing oil pump should open

automatically.

e. Close drain oil valve after confirming it’s normal, open differential pressure switch

isolation valve, stop air side DC sealing oil pump until differential pressure recover

normal.

2) Sealing oil standby differential pressure valve operating test

a. Check air side AC sealing oil pump operating normally, oil hydrogen differential

pressure is 0.084MPa, standby oil pressure is normal, record air side oil pressure.

b. Slowly close air side oil pump outlet valve, when oil hydrogen reduce to 0.056MPa,

standby differential pressure valve should open automatically.

c. Continue to close air side oil pump outlet valve, oil hydrogen differential pressure

should keep at the level of 0.056MPa and not reduce. if oil hydrogen differential

pressure continuously reduce, contact to maintenance personnel to regulate again.

Confirm standby differential pressure valve can maintain oil hydrogen differential

pressure is 0.056MPa,slowly open air side oil pump outlet valve, recover system.

3.6.2.10 EH oil pump interlock test

1) Check and make sure that EH oil system runs normally and standby oil pump switchis at ‘Standby’ position.

2) Press ‘EH oil pump test magnet’ on CRT and then press ‘Open’ button, make surethat magnet valve is open.

3) Watch EH oil pressure drop. When EH oil pressure drops to 11.0～11.4MPa, start

standby oil pump, record self-start oil pressure and confirm that oil pump runsnormally and EH oil pressure recovers.

4) Press ‘EH oil pump test magnet’ on CRT and then press ‘Close’ button, make surethat magnet valve is closed.

5) Stop the former running EH oil pump and test the other standby EH oil pump.

3.6.2.11 Turb ine over speed test


a. Over speed test must be done after unit major maintenance or half-year or oneyear continuous running and individual maintenance of emergency protector.

b. Over speed test during cold start of the unit only can be done after seven (7) hoursof unit runs with 20% rated load and reheating steam temperature above 400 .℃

c. This test must be agreed by shift manager and should be charged by chief

engineer. Test must be done under supervision of assigned person, and turbineengineer must direct at site.

d. This test can only be done after HP & IP main steam valve, governor steam valvetightness test, oil filling test and manual trip test.

e. During test, special person should be in charged of the manual trip handle and hecan open it timely avoid trip equipment does not work when running speed reachto 3300r/min.

f. Twice (2) mechanical over speed trip test should be done when unit is with emptyload, the running speed difference of the two over speed test should be no higherthan 18r/min. Unit running speed, vibration, axial displacement and LP steamexhausting temperature should be strictly supervised during test.

g. Sufficient test personnel, instrumental meters and tools should be prepared beforetest.



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2) OPC over speed test

a. After 3000RPM stable speed, open(over speed test)screen.

b. Click “OPC test” button, open RCM operation panel; choose “YES. Click “OK”.

c. “OPC test” button change to blue, mean that OPC over speed test have been put

into.d. Automatically set objective running speed is 3100RPM and rising speed rate is

200RPM/min.

e. Click “continue/hold”, set continue, start test.

f. When running speed is more than 3090 RPM, OPC solenoid valve close, test stop.

3) Electric over speed test


b. Click “electric over speed test” button, open RCM operation panel; click “OK”.

c. “electric over speed test” button change to blue, mean that electric over speed test

have been put into.

d. Automatically set objective running speed is 3100 RPM ,click “rising speed rate”

button, rising speed rate is 200RPM/min.

e. Click “continue/hold”, set continue, start test.

f. When running speed is more than 3300 RPM, AST solenoid valve operate, turbine

trip, test stop.

4) Mechanical over speed test


b. Click “mechanical over speed test” button, open RCM operation panel; click “OK”.

c. “mechanical over speed test” button change to blue, mean that mechanical over

speed test have been put into.

d. Automatically set objective running speed is 3360RPM ,click “Acc Rate” button,

rising speed rate is 200RPM/min.

e. Click “continue/hold”, set continue, start test.f. Turbine running speed rising to mechanical centrifugal stop bolt, security system

operate, turbine trip, test stop.

3.6.2.12 Small turb ine MEH captive test and trip test

1) Test regulation and notes

a. This test must be done before small turbine cold starting or regulating system

maintenance, test have to be done before boiler burning.

b. One main oil pump operating normally, fire-resistant fluid system operating

normal.

c. Contact I&C personnel to match, small turbine latch normal.

d. Check that quick closing valve open, open speed regulation valve and pipe

regulating valve, confirm each valves switch flexible on local.

e. On MEH screen, push “tripper” button, check small turbine quick closing valve,

speed regulating valve and pipe regulating should close quickly, tripper light.

f. Test finish, recover former operating mode.

2) Small turbine trip protection test

Other trip protection test should operate according to I&C requirement.



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3.6.2.13 Small turbine LP main steam valve operating test (1/4 route test)

1) Test regulation and notes

a. When test, should confirm whether LP main steam valve have fasten

phenomenon on local.

b. During test, should supervise small turbine’s speed, vibration, axial displacement

and so on parameters.

2) Test methods

a. Come into “small turbine control” screen from MEH.

b. Confirm “running speed automatically” light, “boiler remote control” light.

c. Confirm quick closing oil pressure is normal, quick closing valve completely

open.

d. Push the button “LP main stop valve test” to close the main stop valve for 1/4

travel.

e. When the LP main stop valve closed to required travel, the test button light will

be on.

f. During LP main stop valve test, confirm no clip phenomenon on local.

g. After the test, the main stop valve will open automatically. The indication light of

button will be off.

3.6.2.14 Small turbine over speed protection test

Small turbine should be disconnected from feed water pump coupler before test, and testthe small turbine separately. Small turbine manual trip test should be done before the test.Check and make sure that main steam valve and governor valve close rapidly; otherwiseover speed test is prohibited.

1) Electric over speed test

a. Increase running speed of feed water pump turbine to normal working running speedaccording to normal speed rise process. Press ‘over speed test’, press ‘electrical’,make it bright.

b. Press ‘increase speed’. Set target running speed is 6100r/min.

c. When feed water pump turbine speed increases to 6050r/min, electric over speedprotection acts and the feed water pump turbine trips.

d. HP main steam valve, LP main steam valve and LP governor valve close automatically;running speed should decrease.

e. After test, ‘electrical’ test button extinguished.

2) Mechanical over speed test

a. Increases the running speed of feed water pump turbine to normal running speedaccording to normal speed rise process. Press ‘over speed test’, press ‘mechanical’,make it bright.

b. During mechanical over speed test, electrical trip does not work, and relative indicatelamp bright in operator station.

c. Press ‘increase speed’, keep rising running speed to the value of emergency protectortuning value.

d. When running speed increase to 6160r/min, mechanical over speed protection operate,small turbine trip.

e. After mechanical test, ‘mechanical’ over speed lamp extinguished.

3.6.2.15 Small turb ine emergency protector filling oil test

1) Raise the running speed of small turbine to 3500-3550r/min according to normal start



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process.

2) Keep the rated steam parameter of 0.72MPa/346 , check and make sure that℃ parameters of bearing vibration, oil temperature, oil pressure and vacuum are normal.

3) Press ‘Spraying oil test’ button on MEH screen of small turbine, ‘Spraying oil test’dialog box springs out; press ‘In’ button.

4) Excitation of isolation solenoid valve closes and excitation of oil spraying solenoidvalve opens. When ‘Latch’ becomes grey, signal of ‘Oil pressure for latch not formed’and ‘Primary oil pressure low’ appear, oil spraying test ‘Successful’ light on CRTshines.

5) After spraying oil test succeeds, latch locally. When ‘Latch’ signal appears, ‘Oilpressure for latch not formed’ and ‘Primary oil pressure low’ disappears at the sametime.

6) Press ‘Cut off’ button. Test is completed.

7) I&C personnel should be contacted for treatment If isolation solenoid valve or oilspraying solenoid valve do not actuate normally, oil spraying test is not successful or

feed water pump turbine trips.

4 Unit trouble shooting

4.1 Principles of trouble shooting

4.1.1 When accident occurs, duty operator should guide all the unit personnel to treat theaccident rapidly according to regulations in manual book under the direct guidance of theshift manager. Shift manager’s instructions (except for that direct endanger personal orequipment safety) should be executed immediately, otherwise reason should be declared.If the shift manager insists on his instruction, it should be reported to superior manager.

4.1.2 When accident occurs, operators should find out the main reason of accident rapidly,eliminate the threats to personal and equipment safety and try their best to ensure safe

operation of non-fault equipments. The influence of all operations to relevant systemsshould be fully considered during accident treatment to avoid accident expansion. Auxiliary power should be ensured not to be lost during emergency stop.

4.1.3 When accident occurs, operators should treat the accident according the followingprocesses:

4.1.3.1 According to parameters change, CRT display, equipment interlock, screen alarm, faultprint and exterior phenomenon of the unit, it is confirmed that fault occurs in the unit, thus:

1) Rapidly eliminate the threats to personal and equipment safety, disconnect theequipments in fault immediately if it necessary.

2) Rapidly find out the character, location and range of the accident and then treat and

report.3) To keep the non-faults equipment running.

4) During every step of accident treatment, it should be reported to the shift manager forreporting to superior manager to take right measures to avoid accident expanding.

4.1.3.2 When it is confirmed that fault happens in other equipment of the system, measuresshould be taken to keep the unit running, which will benefit for recovering whole unit startnormal operation as soon as possible.

4.1.3.3 During accident treatment, all positions should inform each other and cooperate with eachother, treat the accident rapidly according to regulations of manual book to avoid accidentexpanding.

4.1.3.4 Accident treatment should be rapid and right. Repeat the instruction after receiving it andreport the execution result rapidly.

4.1.4 When accident or fault out of this manual occur, duty operators should make right



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judgment according to their own experience, take measures positively and treat it rapidly.If time is allowed, ask for instruction from the shift manager and treat it under the guidanceof the shift manager.

4.1.5 During accident treatment, when conditions of emergency stop of boiler and turbine aresatisfied but the protectors have not actuated, MFT or latch open should be done manually

immediately. When conditions of emergency stop of auxiliary equipment are satisfied butthe protectors have not actuated, the auxiliary equipment should be stopped immediately.

4.1.6 If the unit trips suddenly, after accident treatment and reason found out, unit should berecovered to run as soon as possible.

4.1.7 During fault and accident treatment, operators should not make bold to leave away fromhis position. If the accident treatment happens during shifts changing time, shift changingshould be delayed. Before issuing handing over procedures, the operators should becontinue to work until to accident treatment completion or part completion. The successiveoperators should assist initiatively to treat the accident.

4.1.8 During accident treatment, unrelated personnel are prohibited to gather in main controlroom or stay in fault location.

4.1.9 After accident treatment, the duty operators should be immediately report the accident andtreatment information according to the facts and, record in details about the accident time,phenomenon, development, treatment course and analysis. All the personnel in the shiftshould be organized on meeting after shift to analyze the accident and prepare accidentreport.

4.2 Condi tions and treatment of emergency stop and treatment

4.2.1 Any of the following conditions occurs, stop the unit in emergency by vacuum:

4.2.1.1 Unit running speed rises to 3300rpm and emergency governor vibrating.

4.2.1.2 Unit vibrates suddenly and acutely or turbine impeller blades break and are with obviousmetal friction sound and clash (any bearings of T-G vibration reach to 0.25mm).

4.2.1.3 There is water impact in turbine, main steam and reheat steam temperature decreased50% suddenly, or HP and LP cylinder temperature difference between up and down morethan 56 .℃

4.2.1.4 Any bearing of turbine-generator is in shortage of oil or in smoke, or temperature of thrustbearing and bearing returning oil more than limit value.

4.2.1.5 Turbine oil system, generator sealing oil system is on fire that can not be extinguished andthreats personal and equipment safety.

4.2.1.6 Oil-hydrogen differential pressure of sealing oil system loses or there is hydrogen leakageat sealing pad of the generator.

4.2.1.7 Oil system leaks oil seriously, main oil tank level decreases to extreme low value and it

alarms and it can not be remedied.

4.2.1.8 Turbine axial displacement reaches to trip value.

4.2.1.9 Any differential expansion of HP, IP or LP cylinder exceeds limit value.

4.2.1.10 Lubricate oil pressure drops to 0.049 MPa (trip value), start AC and DC lube oil pumpstill can’t recover.

4.2.1.11 Generator is in smoke or on fire or hydrogen explodes.

4.2.1.12 Turbine gland sealing abrades abnormally with spark.

4.2.2 Any of the following conditions occurs, it should be reported to the shift managerimmediately and approved to stop the unit w ithout b reaking the vacuum:

4.2.2.1 Unit runs for more than 15min when main steam temperature, reheating temperature riseto 552～566 or the steam temperatures exceed 56℃ 6 .℃



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4.2.2.2 Pressure before HP main steam valve of turbine exceeds 21.71MPa.

4.2.2.3 Condenser vacuum drops and can not recover.

4.2.2.4 Generator stator cooling water flow is lower than 45T/H and can not be recovered and, theprotector does not actuate.

4.2.2.5 When DEH, TSI, DCS, O/I system fault caused some important parameters can’t becontrolled, can’t keep unit operation normally.

4.2.2.6 DEH works abnormally and turbine running speed and load can not be controlled.

4.2.2.7 Fault of EH oil pump or EH oil system threats unit safety.

4.2.2.8 LP cylinder exhausting steam temperature is high to 120 .℃

4.2.2.9 Sealing oil system of the generator is in fault and can not maintain necessary oil pressureand oil level.

4.2.2.10 Main, reheating steam pipes, HP feed water pipes or pressure bearing parts break,and unit can not keep running.

4.2.2.11 All auxiliary power loses.

4.2.2.12 When operation station in DSC system is in fault (CRT ‘blank screen’ or ‘Crush’) andthere is no reliable supervision measure.

4.2.2.13 During full load operation, temperature differences between main steam and reheatsteam more than 42 , or during 0 load operation, temperature differences between℃ main steam and reheat steam more than 83 (only when reheat steam temperature℃ lower than main steam temperature.)

4.2.2.14 Unit runs for more than 1min with no steam.

4.2.2.15 Control steam source pressure is low or disappeared which can not maintain theoriginal operation mode.

4.2.2.16 Refer to turbine and boiler protection controller is in fault and can not be recovered.

4.2.2.17 Any protector should actuate but not actuate (except for stop due to vacuum break).

4.2.3 Operation process for stopping the unit by breaking vacuum:

4.2.3.1 Press ‘Emergency stop’ button in main control room or open turbine trip handle manuallyat local.

4.2.3.2 Check load decrease to 0, turbine running speed is dropping. Check and make sure thatHP & IP main steam valve, governor valve, HP steam exhausting check valve and allcheck valves of all stages steam extraction are closed, HP cylinder extraction valve open.make sure that generator is disconnected, G-T outlet switch and exciter switch trip,auxiliary power has been transferred successfully. Make sure boiler MFT operated, all coalmill, coal feeder, primary fan, sealing fan trip, all burning gun oil feeding valve and closing

valve closed.

4.2.3.3 Check AC lubricate oil pump, hydrogen sealing oil standby pump start automatically, orstart them manually at once. check and make sure that lubricate oil pressure andtemperature are normal.

4.2.3.4 Check jacking oil pump start automatically when turbine running speed drops to 2800r/min,or start it manually at once.

4.2.3.5 Release vacuum interlock, open air exhaust equipment break valve, stop vacuum pump.

4.2.3.6 Check HP, LP bypass operate or not, if it opened should close manually at once.

4.2.3.7 Check turbine proper drainage valve open automatically, close drainage valve of mainsteam and reheat steam and extracting pipe, prohibit to drain hot water and exhaust steam

to air exhaust equipments.

4.2.3.8 Check motorized pump operation normally, adjust drum, deaerator, air exhaust



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equipments to keep water level at normal range, make sure that reheater, superheaterattemperating water control governor valve and isolating valve closed.

4.2.3.9 Check switch auxiliary steam to neighbor unit or start boiler feeding HP,IP auxiliary steamconnecter pressure and temperature is normal.

4.2.3.10 Check switch turbine gland sealing to auxiliary steam main pipe pressure and

temperature is normal. When vacuum decrease to 0, stop gland sealing steamfeeding system.

4.2.3.11 Check LP cylinder water sprinkler open automatically and adjust LP cylinderexhausted steam temperature is at normal range.

4.2.3.12 During running speed decreasing, check carefully, notice sound in unit, check vibration,differential expansion, shaft displacement, bearing metal temperature, lube oiltemperature, pressure difference between oil and hydrogen and so on of the unit. Ifthere’s clashing inside the unit or rotor coasting time decrease obviously, prohibit tostart unit again.

4.2.3.13 Waiting for running speed decrease to 0, put turning gearing into operation, recordrotor coasting time and turning gear current & rotor eccentricity.

4.2.3.14 Stop turbine and boiler by normal operation.

4.2.4 Operation process for stopping the unit without breaking vacuum:

4.2.4.1 Press ‘Emergency stop’ button in main control room or open turbine trip handle manuallyat local.

4.2.4.2 Check load decrease to 0, turbine running speed is dropping. Check and make sure thatHP & IP main steam valve, governor valve, HP steam exhausting check valve and allcheck valves of all stages steam extraction are closed, HP cylinder extraction valve open.make sure that generator is disconnected, G-T outlet switch and exciter switch trip,auxiliary power has been transferred successfully. Make sure boiler MFT operated, all coalmill, coal feeder, primary fan, sealing fan trip, all burning gun oil feeding valve and closing

valve closed.

4.2.4.3 Check AC lubricate oil pump, hydrogen sealing oil standby pump start automatically, orstart them manually at once. check and make sure that lubricate oil pressure andtemperature are normal.

4.2.4.4 Check jacking oil pump start automatically when turbine running speed drops to 2800r/min,or start it manually at once.

4.2.4.5 Check and make sure that all the drainage valves of turbine proper, reheating steam pipes,steam extraction pipes open automatically.

4.2.4.6 If HP, LP bypass open automatically, check HP, LP bypass attemprating water operationnormally, air exhaust equipment vacuum should be normal.

4.2.4.7 Check motorized pump operation normally, adjust drum, deaerator, air exhaustequipments to keep water level at normal range, make sure that reheater, superheaterattemperating water control governor valve and isolating valve closed.

4.2.4.8 Check switch auxiliary steam to neighbor unit or start boiler feeding HP,IP auxiliary steamconnecter pressure and temperature is normal.

4.2.4.9 Check switch turbine gland sealing to auxiliary steam main pipe pressure and temperatureis normal.

4.2.4.10 Check LP cylinder water sprinkler open automatically and adjust LP cylinderexhausted steam temperature is at normal range.

4.2.4.11 During running speed decreasing, check carefully, notice sound in unit, check vibration,

differential expansion, shaft displacement, bearing metal temperature, lube oiltemperature, pressure difference between oil and hydrogen and so on of the unit. Ifthere’s clashing inside the unit or rotor coasting time decrease obviously, prohibit to



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start unit again.

4.2.4.12 Open vacuum break valve when turbine running speed drops to 400r/min.

4.2.4.13 Waiting for running speed decrease to 0, put turning gearing into operation, recordrotor coasting time and turning gear current & rotor eccentricity.

4.2.4.14 Complete other operations for stopping the unit.4.3 Steam parameters are abnormal

4.3.1 Phenomenon

4.3.1.1 All main, reheating steam pressures and temperatures are over high or over low.

4.3.1.2 Parameters exceed limitation and alarm.

4.3.1.3 Unit load changes.

4.3.1.4 Turbine axial displacement, differential expansion change.

4.3.2 Reason

4.3.2.1 Pressure or temperature control system is in failure or attemperating water is improperlyregulated.

4.3.2.2 Unit rejects load suddenly.

4.3.2.3 HP heaters step out system suddenly.

4.3.2.4 Steam system safety valves open suddenly.

4.3.2.5 Coal quality changes suddenly or system runs abnormally.

4.3.3 Treatment

4.3.3.1 Control system is in fault, treat it according to faults, regulate pressure and temperature tobe normal manually if it is necessary and regulate it through regulating combustion andload.

4.3.3.2 If it happens due to too fast or too slow load variation, load variation should be regulated. Ifload changes due to working conditions such as protector action, it should be treatedaccording to relevant regulations.

4.3.3.3 If HP protector steps out of system, unit load should be regulated in time.

4.3.3.4 If pulverizing system runs abnormally and coal powder is not well-proportioned that makesboiler hot load unstable, pulverizing system should be regulated and stop the unit if it isnecessary.

4.3.3.5 When main, reheating steam temperature is abnormal, treat it according to followingregulations:

1) When main, reheating steam temperature changes within range of 5388 , unit is℃

allowed to run continuously in a long time.

2) When steam temperature rises to 552 , annual accumulated time should not exceed℃

400 hours. If accumulated time exceeds 400h, unit should be stopped as fault stop

when temperature exceeds 545～551 .℃

3) Main, reheating steam temperature is allowed to increase from rated temperature to

566 at most within 15min. Unit runs within temperature of℃ 552～566 with annual℃

accumulated time of no more than 80 hours; if the time exceeds 80 hours, unit should bestopped immediately as fault stop. If steam temperature exceeds 566 , unit should be℃

stopped as fault stop immediately.

4) If main steam temperature and reheating steam temperature is abnormal, measures

should be taken rapidly to recover steam temperature to be normal. During treatment, ifmain steam and reheating steam temperature continues to decrease to be 83 lower℃

than rated value or steam temperature decrease rapidly more than 50 , unit should be℃



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stopped immediately as fault stop.

5) When steam pressure or temperature changes abnormally, watch turbine differentialexpansion, axial displacement, bearing vibration, pressure and all control indexes; ifthey exceed limitation, unit should be stopped as fault stop.

4.4 Unit load v ibration

4.4.1 Reason

4.4.1.1 System is impacted, vibrates or boiler runs abnormally.

4.4.1.2 Generator is in asynchronous.

4.4.1.3 Turbine control system is abnormal or speed regulating steam valve acts abnormally.

4.4.1.4 HP, LP bypass act wrongly or returning extraction steam stops suddenly.

4.4.2 Treatment

4.4.2.1 Release CCS coordination control and find out the reason according to CRT display andrelevant meters indications.

4.4.2.2 If the system vibrates, relevant operations should be executed according to shiftmanager’s instructions.

4.4.2.3 If generator is asynchronous, generator active power should be decreased and increaseexcitation manually.

4.4.2.4 If unit load changes suddenly due to grid frequency, unit output should be controlled strictly,no over output is allowed.

4.4.2.5 If it happens due to abnormal control system, it should be changed to be manual control;unit should be stopped if it can not be treated during running.

4.4.2.6 If load changes suddenly due to boiler abnormal operation, steam inlet amount to turbineshould be regulated to stabilize steam parameters.

4.4.2.7 When speed regulating steam valve drops, load should be done according to steam inletamount; load should not be increased or decreased by force when the valve is blocked.

4.4.2.8 Check whether thrust bearing, bearing oil exhausting temperature, axial displacement,differential expansion and vibration are normal or not.

4.4.2.9 Check whether water level of deaerator, condenser, heaters and gland sealing heater arenormal or not.

4.5 Unit load rejection

4.5.1 Phenomenon

4.5.1.1 Unit load drops suddenly, local sound changes suddenly and axial displacement changes.

4.5.1.2 Steam pressure rises, boiler safety valve (or PVC valve) may acts.

4.5.1.3 Extraction steam pressures at all sections drop.

4.5.1.4 When ‘RUN BACK’ occurs, relevant interlocks at boiler at actuate.

4.5.2 Reason

4.5.2.1 Electric power system is in fault, power sending line trips.

4.5.2.2 Unit protector acts.

4.5.2.3 Speed regulating system is in fault, governor valve wrongly close or important auxiliaryequipment trips.

4.5.3 Treatment

4.5.3.1 Supervise the changing of main, reheating steam parameters, try best to maintain normalparameters of the boiler.



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4.5.3.2 Check the unit completely, find out the reason and treat it. If there is no obvious fault,report to the shift manager immediately and prepare to increase the load.

4.5.3.3 If speed regulation system is in fault that can not be treated during running, unit should bestopped for treatment.

4.5.3.4 Check steam driven pump and feed water automatic regulation; if feed water automatic

regulation can not satisfy boiler requirement, release the automation of main feed waterand small turbine. Pay attention to minimum flow valve action of feed water pump.

4.5.3.5 Pay attention to auxiliary power, condenser vacuum and LP cylinder steam exhaustingtemperature. Supervise and regulate water levels of condenser, deaeratoor and heaters.Maintain the auxiliary steam head pipe pressure to be normal.

4.5.3.6 Pay attention to deaerator pressure and gland sealing steam supplying.

4.5.3.7 If the unit protector acts wrongly, it should be reported to the shift manager immediatelyand execute the instructions from the shift manager rapidly.

4.6 Condenser vacuum drop

4.6.1 Phenomenon

4.6.1.1 CRT and local condenser vacuum indications drop.

4.6.1.2 Exhausting steam temperature rises and condensing water temperature rises.

4.6.1.3 Unit steam flow increases and regulation stage pressure increases under the same load.

4.6.1.4 Vacuum decreases to 75KPa or exhausting temperature rises to 80 ; alarm sends.℃

4.6.2 Reason

4.6.2.1 Circulating water pump works abnormally or trips, butterfly valve openness at circulatingpump outlet decrease or fully closed, condenser circulating inlet or outlet valve is wronglyclosed, which makes the circulating water decrease or intermit.

4.6.2.2 Condenser stainless pipes are dirty.4.6.2.3 Vacuum pump works abnormally or trips; vacuum pump cooling device is in fault or heat

exchanger is dirty.

4.6.2.4 Vacuum breaking valve open wrongly or not strictly closed; there is leakage or damage atpipes in vacuum system or other equipment system; water sealing in valves of vacuumsystem is unavailable.

4.6.2.5 Gland sealing supplying steam pressure drops obviously and gland sealing heater waterlevel and negative pressure are abnormal.

4.6.2.6 Condenser hot well water level is too high.

4.6.2.7 Small turbine vacuum system leaks.

4.6.2.8 Turbine LP cylinder explosion proof valve breaks.

4.6.2.9 Heat load of condenser is too high.

4.6.3 Treatment

4.6.3.1 If condenser vacuum is found dropping, all vacuum meters indications should be checkedrapidly, clarify the vacuum drop according to exhausting steam temperature increase.

4.6.3.2 Circulating water system should be checked as following:

1) Whether circulating water pressure is normal or not; if pressure is low, check whetherthere is any leakage or block in circulating water system.

2) Check whether suction water well level is normal or not; if water level is low, inlet

strainer of circulating water pump should be leaned timely. Check whether coolingwater tower level is normal or not, otherwise supplement water timely.

3) Check whether circulating water temperature rises or not.





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4.7.2.7 Cold steam or water enters into turbine or there is water impact inside the turbine.

4.7.2.8 Vacuum drops which causes turbine central line deviate or end stage blade vibrate.

4.7.2.9 During start and stop, unit running speed should be within critical running speed area.

4.7.2.10 Unit vibrates due to generator, such as unbalanced magnetic field.

4.7.3 Treatment

4.7.3.1 When unit vibrates abnormally to protector actuate value, turbine should trip, otherwisestop the unit manually in emergency.

4.7.3.2 Check and make sure that whether lubricate oil pressure and temperature are normal ornot, whether bearing metal temperature and returning oil temperature are normal or not;otherwise they should be regulated.

4.7.3.3 During turbine running speed rising, it is prohibit to keep running speed or warm up atcritical running speed.

4.7.3.4 If vibration caused by bearing oil film vibrating, it is hard to solve during operation, it shouldbe started after oil film vibration solved.

4.7.3.5 If the unit vibrates due to water impact, cold steam, water source should be isolated anddrainage water for turbine proper should be enhanced.

4.7.3.6 If unit vibrates due to generator, load should be decreased for watch and treatment.

4.8 Turbine water impact

4.8.1 Phenomenon

4.8.1.1 Main, reheating steam temperature drop acutely and alarm, reheat ratio decreased.

4.8.1.2 Turbine up and down cylinder temperature difference gets bigger and alarm.

4.8.1.3 There is water clash in turbine or steam pipes, unit or steam pipes vibrate more acutely.

4.8.1.4 Load fluctuation decreases, differential expansion decreases, axial displacementincreases and thrust bearing temperature rises. There is steam leakage or water dropspraying at steam pipe flange, valve stem, cylinder combination surface and gland sealing.

4.8.1.5 Turning gear current increases when it is running.

4.8.2 Reason

4.8.2.1 Drum is full of water or steam flow increases suddenly which makes boiling og water andsteam.

4.8.2.2 Boiler combustion regulation is improper or out of control.

4.8.2.3 Boiler main, reheating steam attemperating water is improperly regulated or in failure.

4.8.2.4 During start, drainage water in pipes is not smooth.

4.8.2.5 Heaters or deaerator is full of water, which enters into turbine.

4.8.2.6 Drainage water in gland sealing system is not smooth, accumulated water or drainagewater enters into cylinder.

4.8.2.7 Main steam or reheating steam temperature indications are abnormal.

4.8.2.8 During unit start and stop, HP bypass attemprating water fault, feed water through reheatcooling section pipe.

4.8.3 Treatment

4.8.3.1 When main steam or reheating steam temperature is found dropping abnormally, relevantmeters should be checked immediately to confirm the real drop.

4.8.3.2 If it is confirmed that there is water impact in unit, unit should be stopped in emergency bybreaking vacuum.



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4.8.3.3 During operation, if main steam or reheating steam temperature drops suddenly andexceeds regulated value, unit should be stopped in emergency by breaking vacuum.

4.8.3.4 When main steam or reheating steam temperature drops abnormally, temperatures andtemperature difference between up and down cylinder should be intensively supervised.Temperature difference between up and down of HP, IP cylinder more than 56 .℃

4.8.3.5 Check and make sure that all the drainage valves in turbine proper and relevant steampipes for sufficient water drainage.

4.8.3.6 Find out and eliminate the reason of water impact and isolate the equipments in fault.

4.8.3.7 Rightly record and analyze the inertia time, put turning gear into operation in time,measure bearing bend and listen to the sound inside turbine. If inertia time, thrust bearingtemperature, axial displacement, differential expansion and temperature differencebetween up and down cylinders are normal; there is no friction or abnormal soundbetween stator and rotor; eliminate the water impact reason and drain water in proper,main & reheating steam pipes and steam extraction pipes completely. Contact with theshift manager to restart the unit.

4.8.3.8 If there is water impact, axial displacement or thrust bearing temperature exceed limit,

inertia time is obviously shortened or there is abnormal sound or friction between statorand rotor, cylinder should be opened for check.

4.8.3.9 If it is found that there is water in turning gear, it should keep running until the temperaturedifference between up and down cylinders. At the same time, supervision should beenhanced for sound inside turbine, rotor eccentricity and turning gear current.

4.9 Turbine blades break

4.9.1 Phenomenon

4.9.1.1 There is metal clash inside cylinder or there is friction sound when turning gear is running.

4.9.1.2 Unit vibrates acutely.

4.9.1.3 Axial displacement, differential expansion change abnormally; thrust pad temperature andreturning oil temperature rises.

4.9.1.4 Pressures at supervision sections rise.

4.9.1.5 If LP cylinder blade breaks, broken blades enter into condenser and break stainless steelpipes, which may rise conductivity and rigidity of condensing water and makes water levelin hot well extremely high.

4.9.2 Treatment

4.9.2.1 If it is confirmed that blades are broken and unit vibrates acutely, break vacuum and theunit should be stopped immediately.

4.9.2.2 If regulation stage or extraction pressure is found to be abnormal, it should be analyzed

immediately and vibration, axial displacement and metal temperature changing should betaken as references. If it is confirmed that blades are broken, unit should be stoppedimmediately for treatment.

4.9.2.3 Condenser water level rises, water should be discharged from #5 LP heater outlet valve tokeep a normal water level or discharge water to condensing water storage tank.

4.9.3 Prevention

4.9.3.1 Keep the unit run within permit range of frequency.

4.9.3.2 Keep the unit steam parameter normal.

4.9.3.3 Keep heaters and deaerator run normally and relevant drainage water smooth.

4.9.3.4 To keep unit output normal. Over limit running is prohibited.

4.9.3.5 Turbine over speed is strictly prohibited.







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manual regulation.

4) Electric heater of main oil tank is put into operation by mistake, stop the electric heaterimmediately.

5) Unit vibration is high, bearing works abnormally and gland sealing leaks steam heavily,all of which may cause oil temperature rise. Confirm the reason and treat it

correspondingly.

4.11.4 Reason and treatment of main oil tank level drop

4.11.4.1 Lubricate oil pipe breaks, measures should be taken for isolation, contact withmaintenance for treatment and add oil timely. If oil pipeline is seriously broken,decrease load or stop the unit in emergency according to actual conditions. Make surethat oil is sufficient for inertia when stop the unit.

4.11.4.2 Sealing oil system is in fault and leaks oil, treat it according to regulations for faulttreatment in sealing oil system.

4.11.4.3 Oil cooler leaks. Transfer it to standby oil cooler for operation and isolate it fortreatment.

4.11.4.4 Oil purifying device is in fault and leaks oil, oil inlet valve of the device should beclosed immediately and oil purifying device should be stopped.

4.11.4.5 If main oil tank level slowly decreases to 60%, oil should be added timely; if time islimited for adding oil and oil level in main oil tank drops acutely to 20%, unit should bestopped in emergency.

4.11.5 Reason and treatment of unqualif ied lubricate oil

4.11.5.1 For new unit or unit after maintenance, mechanical impurity or water is brought in dueto incompletely cleaning of oil system. Oil purifying or changing should be enhanced.

4.11.5.2 Gland sealing supplying steam pressure is high, which makes moisture in oil increases.Under the condition of not affecting condenser vacuum, regulate bearing steam

supplying pressure to be lower and gland sealing heater negative pressure to behigher properly.

4.11.5.3 There is over temperature point in oil system and oil is aging. Oil filtering and changingshould be enhanced and over temperature points should be eliminated.

4.12 Turbine bearing temperature high

4.12.1 Phenomenon

4.12.1.1 CRT shows bearing temperature is high or alarms.

4.12.1.2 “turbine bearing temperature high” alarm.

4.12.1.3 Bearing returning oil temperature indication is high.

4.12.1.4 Unit vibration may be higher.

4.12.2 Reason

4.12.2.1 Cooling water system of oil cooler is in fault, lubricate oil temperature is high.

4.12.2.2 Lubricate oil pressure is low or oil is unqualified.

4.12.2.3 Bearing oil inlet and outlet are not smooth.

4.12.2.4 Unit vibrates acutely.

4.12.2.5 Bearing is damaged.

4.12.2.6 Gland sealing leaks steam seriously.

4.12.2.7 Unit is in overload, steam extraction system, vacuum system are running abnormally;thrust bearing temperature and returning oil temperature will rise.



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4.12.3 Treatment

4.12.3.1 When bearing temperature and returning oil temperature are higher than normalvalues, following parameters should be checked immediately:

1) Whether the same bearing temperature on CRT and returning oil temperature atlocal rise or not.

2) All bearing temperatures rise, generally it is due to lubricate oil temperature high,lubricate oil pressure low, unit running speed rise or unit vibration high, all of whichshould be regulated to be normal.

3) Check bearing return oil flow and listen to the sound inside bearings.

4.12.3.2 Regulate lubricate oil temperature and pressure to normal values.

4.12.3.3 If oil is unqualified, oil filtering and changing should be enhanced. If oil is agingseriously, unit should be stopped according to requirements.

4.12.3.4 Thrust bearing temperature rises due to over load, unit load should be regulated.

4.12.3.5 If gland sealing leaks too much steam, gland sealing steam pressure should be

properly decreased under the precondition of ensuring condenser vacuum.4.12.3.6 Supporting bearing temperature reaches to 113 or thrust bearing temperature℃

reaches to 107 and its returning oil temperature reaches to℃ 77 ; if it is treated but℃ with no effect, unit should be stopped as fault stop.

4.13 EH oil system fault

4.13.1 Familiar fault

4.13.1.1 Oil pressure swings.

4.13.1.2 Oil pressure drops.

4.13.1.3 Oil tank level decreases.

4.13.1.4 Oil pipe leaks.

4.13.1.5 Oil temperature is abnormal.

4.13.1.6 Oil is unqualified.

4.13.2 Fault treatment

4.13.2.1 When EH oil pressure swings, running oil pump should be checked: whether overflowvalve acts or not, whether oil tank level is normal or not; check working condition ofstandby oil pump outlet check valve. If the oil pump does not work normally, oil pumpshould be transferred.

4.13.2.2 Oil pressure drops, it may due to oil pump not working normally, system leaking,strainer block or overflow valve action; it should be treated according to different

conditions:

1) If oil pump does not work normally, standby oil pump should be transferred foroperation.

2) If oil system leaks, try to isolate the leaking point under precondition of keep EH oilpressure is not too low and contact with maintenance for oil supplement; if oil leaksseriously and can not be isolated, unit should be stopped as fault stop.

3) If strainer differential pressure is high or overflow valve acts, it should be isolated fortreatment.

4) When oil pressure decreases to value ”Low I”, standby pump starts automatically,otherwise start it manually; when oil pressure decreases to value ”Low II”, protector

actuates to stop the unit, otherwise unit should be stopped manually.

4.13.2.3 When oil tank level decreases to 450mm, alarm sends, oil should be supplementedtimely. Oil level drops generally because of oil pipes leak or oil cooler leak. If it is the



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reason, the leaking point should be isolated, if it can not be isolated and oil levelcontinues to drop, unit should be stopped for treatment.

4.13.2.4 When oil temperature is abnormal, heating pump should be checked, cooling watershould be checked locally and oil cooler should be checked.

4.13.2.5 When oil is unqualified, check whether system regeneration pump is in normal

operation or not, check diatomite strainer runs normal or not and change it if it isnecessary.

4.14 Sealing oil pressure low

4.14.1 Reason

4.14.1.1 Sealing oil pump does not run normally.

4.14.1.2 Sealing oil strainer is seriously blocked.

4.14.1.3 Sealing pad leaks oil seriously.

4.14.1.4 Sealing oil pump re-circulating valve wrongly open or is in failure.

4.14.1.5 Differential pressure regulation valve does not work normally.

4.14.2 Treatment

4.14.2.1 Check and make sure that standby oil source is working; standby oil differentialpressure regulator is working, which ensures that oil/hydrogen differential pressure isnormal.

4.14.2.2 If it is due to sealing oil strainer block, the strainer should be changed and relevantperson should be contacted for treatment.

4.14.2.3 If it is due to sealing oil pump re-circulating valve, the re-circulating valve should beregulated.

4.14.2.4 If sealing pad leaks oil seriously, it should be reported to the shift manager; if it can not

keep running, ask for stopping the unit.4.14.2.5 If differential pressure regulation valve is in failure, bypass valve can be regulated

manually; keep supplying oil to sealing pad and contact with maintenance fortreatment.

4.15 Closed circulating water system fault

4.15.1 Familiar faul ts

4.15.1.1 Closed cooling water intermits.

4.15.1.2 Closed cooling water head pipe pressure drops or fluctuates.

4.15.1.3 Closed cooling water tank level is low.

4.15.1.4 Closed cooling water pump vibration is high.

4.15.1.5 Closed cooling water pump motor current increases abnormally.

4.15.1.6 Closed cooling water quality gets worse.

4.15.2 Fault treatment

4.15.2.1 If closed cooling water head pipe pressure drops, check the working condition ofclosed water pump: whether closed cooling water tank is too low or not, whethersystem water discharging valve is strictly closed or not. If pump output is not sufficientor output pressure is lower than 0.35MPa, it should be confirmed that standby pumpstarts automatically, otherwise start it manually.

4.15.2.2 If closed cooling water head pipe pressure fluctuates greatly and motor current

fluctuates, it is generally because closed cooling water tank level is low or air entersinto pump. If it is because water tank level low, water should be supplemented to benormal. If it is because pump inlet strainer is blocked with differential pressure ≥0.02



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MPa and standby pump starts automatically, the former running pump should bestopped and inlet strainer should be cleaned. If it because air enters into pump, all airdischarging valves should be opened to discharge air, standby pump should beimmediately transferred for running during gasification.

4.15.2.3 If closed cooling water pump vibrates highly, check whether gasification happens in

pump or not, whether there abnormal sounds in pump and pump group bearings or not.When above abnormities happen, standby pump should be transferred immediately forrunning.

4.15.2.4 If motor current displays it is increasing, it should be measured. The reason may betwo phases running or bearing damage. Standby pump should be transferred forrunning. Contact with maintenance for treatment.

4.15.2.5 If closed cooling water quality gets worse, it may due to that supplement water sourceis polluted. Water should be changed and contact with chemical for dosing.

4.16 Auxi liary equipment fault

4.16.1 Running equipment should be stopped in emergency if any of the following occurs:

4.16.1.1 Equipment vibrates heavily and, stator and rotor abrade.

4.16.1.2 Metal friction sound is clear inside equipment.

4.16.1.3 Motor is in smoke or on fire.

4.16.1.4 Bearing is in shortage of oil or in smoke.

4.16.1.5 Other faults threatening personal and equipment safety happen.

4.16.2 Standby auxiliary equipments should started first ly and stop the equipments in faultunder following conditions:

4.16.2.1 Equipment sound is abnormal.

4.16.2.2 Motor current increases abnormally, insulation has burning smell or motor winding

temperature exceeds limit.

4.16.2.3 Generator runs with two phases.

4.16.2.4 Gasification occurs in running pump.

4.16.2.5 Bearing temperature exceeds limit.

4.16.2.6 Air cooling system of big scale air fan is in fault.

4.16.2.7 Gland packing gets hot, smokes or leaks oil or water greatly.

4.16.2.8 Other conditions that threatening auxiliary equipment safety operation happen.

4.16.3 During starting motor, it should be stopped immediately if follow ing abnormitiesoccur:

4.16.3.1 Current does not return for a long time after starting.

4.16.3.2 After switch is closed, motor does not run but buzzes.

4.16.3.3 Motor has spark or smoke inside.

4.16.3.4 Equipment vibrates abnormally and there are serious leakages at connection pipesand flanges.

4.16.4 Auxil iary equipment vibration high

4.16.4.1 Phenomenon

1) Vibration values both measured locally and indicated remotely are high, correspondingvibration high alarm of auxiliary equipment occurs and, the auxiliary equipment tripswhen vibration value reaches to action value.

2) There is abnormal sound locally and bearing temperature may rise.



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3) When water pump vibrates greatly due to gasification inside water pump, generallythere is abnormal sound at local.

4.16.4.2 Reason

1) Coupler alignment does not comply with requirement or coupler is damaged.

2) Rotor center is not right.3) Bearing installation clearance is too big or bearing is damaged.

4) Anchor bolts or mechanical parts are loosened.

5) Water pump’s gasification.

4.16.4.3 Treatment

1) Rotor center is not right and it should be aligned again.

2) Check whether bearing is damaged or not, loosened anchor bolts or mechanical partsshould be tightened.

3) When there is breathing vibration or gasification, it should be regulated effectively.

4) For equipment with no protections, it should be stopped when vibration valueincreases to limit value.

5) Auxiliary equipment vibration value exceeding following values should be deemed asvibration high:

Rated running speed (r/min) 7600 3000 1500 1000 750

Vibration value

(Double amplitude um)40 50 85 100 120

4.17 Motor fault4.17.1 Conditions for stopping motor

Any of the following conditions occurs, motor should be stopped immediately:

4.17.1.1 It is threatening personal safety.

4.17.1.2 Motor and its affiliated electric equipments are in smoke and on fire.

4.17.1.3 The mechanical equipment is damaged and can not run.

4.17.1.4 Motor vibrates heavily or impacts inside, stator and rotor abrades.

4.17.1.5 Motor running speed drops acutely, current rises or drops to zero.

4.17.1.6 Motor temperature and bearing temperature rise acutely, which exceed permit values.

4.17.1.7 Flood or fire threatening motor safety occurs.

4.17.2 Conditions of motor fault stop

For important auxiliary motor, firstly start the standby equipment, then stop the motor whenthe following happen:

4.17.2.1 Motor has abnormal sound or insulation has burning smell.

4.17.2.2 There is spark or smoke in generator or starting regulation device.

4.17.2.3 Stator current exceeds normal operation value (under same load);

4.17.2.4 Cable down-lead of motor is over heated.

4.17.2.5 Cooling system of large scale motor is in fault.

4.17.2.6 Motor three phases unbalancing current exceeds 10%.



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4.17.3 If the tripped motor affecting uni t output or safe operation, and there is no standbymotor or standby motor can not be started rapidly; the tripped motor can berestarted except for following conditions:

4.17.3.1 There is an obvious sign of short circuit or damage on regulation device or powercables before starting the unit.

4.17.3.2 Personal accident happens and unit has to be stopped immediately.

4.17.3.3 Motor affiliated machinery is damaged.

4.17.3.4 Motor that tripped due to protector action.

4.17.4 Important motor loses voltage or its voltage drops, manually cutting off auxil iarymotor is prohibited within 1min.

4.17.5 Motor trips automatically during running

4.17.5.1 Reason

1) Stator winding is in short circuit in circles or phases.

2) Power cable is in failure.

3) Mechanical parts are blocked to death.

4) Voltage drops.

5) Relay protector actuates or is wrongly operated.

4.17.5.2 Treatment

1) Start standby equipment.

2) If there is no standby equipment, check the motor as soon as possible. Restart it afterno problem is confirmed. It can be started immediately after wrong operation isconfirmed.

3) If the motor trips during start, it can not be started before finding out the reason.

4) Check the following to the tripped motor:

a. What kind of protector action it is.

b. Whether motor winding and cable have short circuit, earth and broken line or not.

c. Whether affiliated machinery is blocked to death or not, fuse is broken or not andinterlock circuit is in fine condition or not.

d. Whether switch actuator is in fine condition or not, power switch and brake are wellclosed or not.

e. Measure motor insulation resistance (including cables).

4.17.6 Motor is in smoke and on fire with burning smell4.17.6.1 Reason:

1) Bearing center is not right or bearing pad abrade, which makes stator and rotor clash.

2) Stator winding insulation is wet, dirty or aging and, short circuit between phases orearth fault occurs.

3) Motor rat cage bar break.

4.17.6.2 Treatment

1) Open the power supply switch of motor immediately.

2) Dry powder, 1211, oxidation carbon fire extinguisher or spraying water is used for

putting out fire. Water flow, sand or foam is prohibited.3) Check the motor in details.



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4.17.7 Motor vibrates acutely

4.17.7.1 Reason

1) The centers of motor and affiliated equipment are not the same, bearing bends andmechanical part damages.

2) Unit bearing is damaged or balance weight displacement is unbalanced.3) Stator and rotor abrade or fan drops.

4) Rotor rat cage bar breaks.

5) Mechanical part vibrates and anchor bolts are loosened.

4.17.7.2 Treatment

1) Start standby motor.

2) If there is no standby motor, motor load should be decreased, check whether vibrationis lightened or eliminated or not; otherwise contact with maintenance for treatment.

4.17.8 When motor temperature rises abnormally, the following should be checked:

4.17.8.1 Whether voltage is lower than or current exceeds regulated value or not:

4.17.8.2 Check whether cooling air exceeds 35 or not, cooling system is blocked or not and℃ fan runs normally or not.

4.17.8.3 Three phases current are in balance or not, whether exceed regulated values or not.

4.17.8.4 Whether affiliated mechanical parts are blocked which causes over load.

4.18 Auxi liary power lost

4.18.1 Phenomenon

4.18.1.1 Unit trips, boiler MFT, turbine trips and generator steps out of the system; alarmsounds and corresponding light-word plate shines.

4.18.1.2 Auxiliary bus line voltages at all sections drop to zero (0) and their power supplyswitches green lights are on.

4.18.1.3 All running AC auxiliary equipments stop and standby AC auxiliary equipments do notstart by interlock; motorized valve can not be operated.

4.18.1.4 All DC equipments actuate by interlock.

4.18.1.5 AC head lamps are off, DC head lamps are on and control room gets dark.

4.18.2 Reason

Generator steps out of the system, auxiliary power supply at all sections are lost, standbypower supply can not be transferred successfully or standby transformer trips but

emergency power supplies have not put into operation successfully.4.18.3 Treatment

4.18.3.1 Make sure that turbine, small turbine DC oil pump, DC sealing oil pump at air side arestarted; otherwise they may be closed manually by force 2 times. Check and makesure that turbine lubricate oil pressure, oil-hydrogen differential pressure are normal. IfDC sealing oil pump can not start, exhaust hydrogen from generator at once, avoidhydrogen leaking caused exploding.

4.18.3.2 Open condenser vacuum breaking valve manually and close all the drainage valves tocondenser. Put air pre-heater pneumatic motor into operation. Close manual valve offuel oil trip valve before boiler and retuning oil manual valve.

4.18.3.3 Inform relevant positions fro corresponding treatments. Recover all the trippedequipments and release standby equipment interlocks.

4.18.3.4 Check and operate the emergency power supply:



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4.18.3.5 After emergency power recovered, following works should be done:

1) Start turbine AC lubricate oil pump, jacking oil pump, AC sealing oil pumps at air andhydrogen side, sealing oil standby pump, small turbine AC oil pump, air pre-heatermotor and AC flame detection air fans.

2) Put lubricate oil systems of all auxiliary equipments into operation.

3) Start emergency stop cooling water pump of boiler and put boiler water pump LPcooling water system into operation.

4) Close outlets of steam driven feed water pump and motorized feed water pump; checkand make sure that pump do not run in reversal.

5) Check and make sure that HP & IP main steam valve, governor valve, HP steamextraction check valve and check valves of all extraction steam are closed. Closerelevant motorized valve and open relevant drainage valve at boiler side.

6) Check and regulate all the air valves, dampers of stopped pulverizing system are right.Motorized valves of super heaters and re-heaters are closed.

7) Put turning gear into operation when turbine running speed reaches to zero (0). If

turning gear stops before rotor, rotor should be turned 180O and put turning gear intooperation after a period of time.

8) Check and make sure that DC system and UPS power transfers normally.

4.18.3.6 Open all the closed switches at all sections of HP, IP auxiliary power. Check the reasonwhy auxiliary standby power supply can not be put into operation successfully. Afterdefects are cleaned, recover power supplies at all sections of LV transformer.

4.18.3.7 Recover auxiliary power supplies gradually and recover all systems graduallyaccording to unit actual conditions.

4.18.3.8 If circulating water interrupted and LP cylinder exhausting steam temperature is higherthan 50 , firstly start condensing water pump and start one vacuum pump and keep℃

condenser vacuum of -20KPa. Circulating water system only can be put into operationafter stainless steel pipes are cooled and exhausting steam temperature is lower than50 .℃

4.18.3.9 Feed water to boiler according to drum wall temperature difference and after chiefengineer’s approval. Keep drum water level and deaerator water temperature normal.

4.18.3.10 Do the other operations gradually to recover unit operation.

4.19 Hydrogen system fault

4.19.1 Generator is in smoke, on fire or explodes, unit should be stopped in emergency anddischarge hydrogen.

4.19.2 During generator operation, hydrogen purity in generator is low to 96％, it should be

supplemented. It should be confirmed that there are no fire near outlets of pollutantdischarging when discharging pollutant. The operation should be slow to avoid explosionand fire due to static.

4.19.3 Hydrogen temperature is abnormal, check hydrogen cooler working condition; if hydrogentemperature automatic regulation is in failure, regulate the temperature manually throughbypass valve and inform maintenance for treatment.

4.19.4 One hydrogen cooler is in fault and stops and unit load decreases to 80%, temperature ofgenerator stator iron core and winding should be strictly supervised.

4.19.5 Hydrogen purity meter is in fault, inform maintenance immediately for treatment andcontact with chemical to sample and analyze hydrogen purity once every four hours until

hydrogen purity analysis meter recovers and works normally.4.19.6 Hydrogen pressure inside generator drops or hydrogen leaks, the reason should be found

out immediately and eliminated. Reason and treatment of much hydrogen leakage and



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hydrogen pressure dropping are as following:

1) Sealing oil intermits. Stop the unit and discharge hydrogen in emergency.

2) Sealing oil pressure is low, which can not keep a normal oil-hydrogen differentialpressure. Try to regulate it to be normal or start an other standby pump. If sealingoil pressure can not be improved, keep the unit running by decreasing hydrogen

pressure. When hydrogen pressure decreases, unit load should be controlledaccording to corresponding curve between hydrogen pressure and load.

3) Hydrogen leaks due to pipe break, valve flange leakage or generator measuringdown-lead leakage. Treat the leakages under precondition of not effecting unitnormal operation; if it can not be treated, stop the unit.

4) Generator sealing pad or outgoing line bushing ia damaged, which should be rapidlyreported to the shift manager and stop the unit for treatment.

5) Wrong operation or hydrogen discharging valve is not strictly closed, operationshould be corrected immediately and the valve should be strictly closed;supplement hydrogen to normal pressure.

6) If it is due to generator stator winding or hydrogen cooler leakage, it should bereported the to shift manager immediately; stop the unit for treatment if it isnecessary.

7) If hydrogen leaks to workshop, all the doors and windows in relevant area should beopened and air fan at roof should be started to enhance aeration. Any fire forworking is prohibited.

4.20 Stator cool ing water interrupt

4.20.1 Check standby stator cooling water pump start or not. If not start automatically, startstandby pump manually by force at once, if not successful, start primary pump by forceonce more and adjust cooling water flux and pressure normal.

4.20.2 Check stator cooling water system, find the reason why stator cooling water pump trip.4.20.3 If stator cooling water system can not recover, decrease generator load, take preparation

for generator trip, switch auxiliary power to start standby transformer instead at once.

4.20.4 Supervise temperature of each section of generator, can not exceed allowed value.

4.20.5 Water interrupt protection operated after generator water interrupting for 30 seconds,disconnection at once. If protection not operation, make G-T trip manually.

4.20.6 Waiting for stator cooling water system recovery and make sure that unit is normal,generator synchronizing.

4.21 Fire

4.21.1 When fire occurs with his working area, operators shou ld:

4.21.1.1 Not to leave away from his position by himself or run in a rush.

4.21.1.2 Enhance unit operation and maintenance according to accident treatment regulations.

4.21.1.3 Execute the instruction from superior positions rightly and immediately.

4.21.2 Treatment during fire

4.21.2.1 When fire alarm sends out, relevant person should go to fire spots to see the fire, tocheck the fire fighting system and to use relevant extinguisher for putting out the fire.

4.21.2.2 When electric equipments are on fire, power supply should be cut off first then useextinguisher for putting out the fire. When fire occurs around electric equipments thatthreatening equipments safety, the equipments also should be stopped and power

supply should be cut off.

4.21.2.3 When fire is still not threatening unit operation, try to limit the fire and move away thetinder around fire and put out the fire as soon as possible.





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4.22.1.3 Treatment

1) If DCS is in fault and boiler extinguishes, it should be treated as extinguishing.

2) If boiler has not extinguished and main standby manual operation and supervisionmeters are available which can keep normal running of the unit temporarily, transfer tostandby operation mode for operation, eliminate faults and recover running mode of

operators’ station. Otherwise, turbine and boiler should be stopped. If there is noreliable standby operation supervision measures, turbine and boiler also should bestopped.

3) Supervise drum level, furnace negative pressure, temperature, pressure and boilercombustion by local water level video, flame video, drum water level indicator,supervision meters for furnace negative pressure, main, reheating steam pressureand temperature.

4) Keep unit load stable, when steam pressure in unstable, regulate load manually andproperly to maintain normal pressure.

5) Contact with IC immediately for treatment.

6) If boiler combustion working conditions is out of control, parameters are abnormal andfault in DCS can not be cleaned in time, boiler should be stopped.

7) After boiler stops, close all oil, air, gas valves or dampers and stop all the runningequipments that have to be stopped for boiler emergency stop.

4.22.2 Part operator stations of DCS fault

4.22.2.1 When part operator stations are in fault, use the operator station that still available forsupervising the running of the unit.

4.22.2.2 Stop important operations.

4.22.2.3 Contact with I&C for treatment.

4.22.2.4 If fault can not be eliminated, it should be treated according to running conditions.

4.22.3 Treatment when contro ller or corresponding power supply are in fault:

4.22.3.1 When auxiliary controller or corresponding power supply is in fault, it can betransferred to manual mode running and treat it rapidly; if the conditions are notallowed to transfer, the auxiliary equipment should exit from running.

4.22.3.2 When regulation circuit controller or corresponding power is in fault, it should bechanged to manual mode foe keeping running; treat the fault in system rapidly andrelevant measures should be taken according to treatment.

4.22.3.3 When controller of boiler protection is in fault, controller should be renewed or repaired;when power supply of boiler protection is in fault, measures for sending power by forceshould be taken. At this time, measures for avoiding controller initialization should be

done well. If it can not be recovered, stop the boiler in emergency.

4.23 Measures avoiding water entering into turbine and bearing bend

4.23.1 Before starting turbine, check and make sure that condition of insulation for turbine is good;it is prohibited to be started if insulation is not completely to ensure that there will be no toohigh temperature difference during normal start and stop. When temperature differencebetween up and down cylinder is higher than 42 , speed rise should be stopped or℃ increase load to heat up the turbine until the temperature difference is lower than 30 .℃

4.23.2 All metal temperature detection points of turbine should be complete and reliable, bearingeccentricity indication should be right. Bearing eccentricity should not exceed 0.075mmbefore starting the turbine. Otherwise it is not allowed to start.

4.23.3 Continuous running of turning gear should be no less than 4 hours before starting theturbine. After stop the unit, turning gear should be put into continuous running immediately.If turning gear can not be put into continuous running, turning gear should be turned 180°



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every 30min to eliminate rotor flexible distortion and hot distortion and, then out turninggear into continuous running.

4.23.4 During start or stop, unit should avoid running a long time with load of 60MW. Duringnormal running, check the unit periodically, listen to the sound in cylinder and at glandsealing, report and treat it immediately if any abnormity is found.

4.23.5 Check cards should be strictly executed before starting. Check and make sure that all thedrainage valves are fully open before starting the turbine; touch locally to confirm thatdrainage water is smooth.

4.23.6 During hot state start, gland sealing steam should be supplied first and then extract thevacuum. After unit stopped, only when condenser vacuum decrease to 0, gland sealingsteam feeding can stop. Before supplying steam to gland sealing, gland system should becompletely heated and then drain water; cold steam or drainage water is prohibited toenter into gland sealing. Choose steam source according to cylinder temperature in orderto make feeding steam temperature match with cylinder steam temperature; maximumsteam temperature of gland sealing should not be higher than 375 . Boiler ignition only℃ can be done after vacuum is established.

4.23.7 Turbine starting should adopt ‘Automation’ mode to the best. 600r/min low speed frictioncheck should be strictly executed. During start, there should be special person tosupervise turbine TSI system vibration, pad temperature, differential expansion and metaltemperature and there should be special person at local to supervise bearing vibration andtotal cylinder expansion. Critical running speed area is prohibited to stay. Once vibrationvalue exceeding standard value (especially before first critical running speed area) isfound, the unit should be stopped immediately; it is prohibited to decrease speed andwatch.

4.23.8 Under any working condition, drum level, turbine axial displacement, differential expansion,vibration, main and reheating steam temperature should be strictly supervised; especiallyduring start & stop and changing working condition, main & reheating steam temperaturechanging rate should be strictly controlled. When main steam temperature drops to trip

value but protector does not actuate, unit should be stopped immediately and manually. Ifsteam temperature drops 50 acutely within 10min, unit should be stopped immediately.℃

4.23.9 When load is under 20%, HP heaters are not allowed to run. Under any working condition(especially during unit start & stop), water levels of HP & LP heaters and deaerator shouldbe strictly supervised. When heaters all full of water, check and make sure that protectorsact rightly; otherwise stop it manually, check whether steam extraction motorized valve,check valve are closed or not and feed water has been transferred to bypass line. Startdrainage water of steam extraction pipes.

4.23.10 After HP & LP bypass system stop, attemperating water manual valves should be closedreliably.

4.23.11 After unit stops or in maintenance, before cylinder temperature reaches to environment

temperature and steam water system is completely isolated, turbine should be deemed asrunning, condenser water level, cylinder metal temperatures should be supervised andparameters should be recorded periodically. Close the motorized valves and manualvalves at proper coal section and from fourth extraction to auxiliary steam, close make upwater valve from condensing water to hydrogen station, close condenser make up watervalve, close inlet valve from make up water tank to condensing booster pump and closeattemperating water valves for heating to avoid full water of condenser. When look forleakage of condenser, the water level of condenser should be no less than 8.5m,temporary measures for supervising water level should be prepared. After looking forleakage, all the drainage valves should be opened for water drainage.

4.23.12 After turbine trips; gland sealing steam supplying is not allowed to stop before vacuumreaches zero (0) to avoid cold air entering into turbine. During rotor inertia, breakingvacuum is prohibited; inertia time should be recorded and analyzed. Gland sealing steamis not allowed to supply without turning gear. Half an hour after rotor inertia, vacuum canbe decreased to about 30KPa. All the drainage valves to condenser should be closed



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before condenser vacuum reaches to zero (0), and then vacuum breaking valve can beopened.

4.23.13Execute all periodic works seriously and do the moving tests of main steam valve andsteam extraction check valve well. Report and treat it is any problem is found. Exit fromheaters operation if it necessary.

4.23.14Turbine cylinder temperature should not be lower than 400 when stopping the unit with℃ sliding parameter.

4.23.15During turning gear running time after turbine stops, maintenance for systems relevant toturbine proper is prohibited to avoid cold air entering into cylinder; under especialconditions, it should be approved and measures should be prepared.

4.24 Measures avoiding turbine oil leakage

4.24.1 During normal operation, main oil tank and small turbine oil tank level keeps at normallevel (Local oil mark is visible).

4.24.2 Move the main oil tank level indicator once a day, check and make sure that there is noblock at oil level indicator and oil level alarm is normal. Two oil level indications should be

basically in consistent.

4.24.3 Small turbine oil tank level alarm test is normal.

4.24.4 Oil purifying device fault alarm test is normal. It should be checked from time to time duringits operation; if oil leakage is fount, it should be isolated and main oil tank level should bepaid attention. Add it to normal level when oil level decreases.

4.24.5 Emergency oil discharging valve, water discharging valve of turbine and small turbine oiltank and ‘NO OPERATION’ warning plate should be hung.

4.24.6 Outdoor oil storage tank should be with a certain qualified turbine oil, lubricate oiltransportation pump should be ready for standby to ensure main oil tank and small turbineoil tank can be added with oil.

4.24.7 During normal operation, check it immediately if oil level in oil tank drops. If oil pipe leaks,isolation should be managed. Watch oil level changing in oil tank and supplement oil ifit isnecessary.

4.24.8 Check and make sure that whether oil cooler leaks or not; if it leaks, it should be changedfor isolation.

4.24.9 Check sealing oil system: sealing oil tank indicator at air side should be at normal level; ifoil pipe leaks, measures should be taken for isolation.

4.24.10 If main oil tank level drops and can not be added oil, oil level continues to drop to 20%,stop the unit in emergency with breaking vacuum for ensuring oil for inertia of turbine.

4.24.11Turbine oil system and relevant test and periodic works should be executed strictly

according to regulations in this manual book.4.24.12During unit start, stop and running, thrust pad, bearing pad and returning oil temperature.

When temperature exceeds limited value, it should be reported to shift manager andtreated according to regulations

4.24.13During operation, it is not allowed that standby pump work at the same time and lose itsstandby function.

4.24.14Unit is not allowed to run when unit vibration is not qualified.

4.24.15 Analyze oil periodically and treat it if oil quality is getting worse. Under oil quality andcondition of cleanness exceeds standard, unit is not allowed to start.

4.24.16During operation, bearing pad may be damaged (such as water impact or instantaneous

oil break), unit can only be started after it is confirmed that unit bearing pad is notdamaged.

4.24.17Low oil protection thrust bearing protection and low pressure interlock must be reliable and



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can not be released casually.

4.25 Main steam valve or governor valve blocks after turbine trips

4.25.1 Phenomenon

4.25.1.1 Turbine trips.

4.25.1.2 HP & IP main steam valve ‘Close’ signal are not completely sent out.

4.25.1.3 IP governor valve on DEH screen is not completely closed to ‘0’ position.

4.25.2 Treatment

4.25.2.1 Check and make sure that running speed decreases or not.

4.25.2.2 After turbine trips, if it is found out steam valve is blocked and not completely closedand running speed decrease quickly, unit should be stopped according to normal stop.

4.25.2.3 After turbine trips, if it is found that steam valve is blocked and not completely closedwhich makes running speed rise, unit should be stopped in emergency by breakingvacuum.

4.25.2.4 Stop vacuum pump and release pressure in boiler as soon as possible. Stop A, B smallturbine and EH oil pump.

4.25.2.5 Contact maintenance to treat the block of steam valve and find out the reason. Unitonly can be started after defects are cleaned.

4.26 Measures avoiding turbine over speed

4.26.1 Do the over speed test, oil spraying test and static test according to regulations. Make surethat speed change rate and stagnant rate comply with the regulation.

4.26.2 Unit oil filling test is normal and actions are right.

4.26.3 Over speed test should be done with rising speed method one month after majormaintenance and emergency protector disassembly.

4.26.4 If over speed test needs to be done during cold state start, it should be synchronized firstly.The test is then done after low load heating up according to regulations.

4.26.5 During emergency protector over speed test, speed rise should be stable.

4.26.6 I&C protection signals should be tested after minor or major maintenance to ensure thatI&C signals set values are right and all additional protections are reliable.

4.26.7 OPC test period should be the same with over speed test period.

4.26.8 When main steam valve or governor valve is found to be blocked, it should be reportedand eliminated and steam valve moving test should be done according to regulations.

4.26.9 Check the tightness of main steam valve, speed regulating valve and steam extraction

check valve before every start or stop. It any is found not strict, unit can only be startedafter defects are eliminated.

4.26.10Steam and turbine oil should be analyzed periodically; corresponding measures should betaken if the qualities are not qualified.

4.26.11Regulate gland sealing pressure of the unit properly to avoid water entering into oil. Watershould be eliminated as soon as possible if water enters into oil.

4.26.12During over speed test, governor valve should be opened gradually and running speedshould be increased gradually to emergency protector action running speed. If governorvalve suddenly open to maximum, unit should be stopped manually to avoid serious overspeed.

4.26.13Proper parameters should be chose during over speed test; pressure and temperatureshould be controlled within regulated range, over speed test can only be done afterparameters are stable.



5 Start curve

5.1 Cold state curve

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5.2 Warm state start curve

103



104



5.3 Hot state start curve

105



106

5.4 Very hot state curve





5.6 Cold state rotor heating curve

HP & IP Rotor Initial Metal Temperature （℉）

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5.7 Hot state start recommended value

Starting turbine and operating with minimum load

Note: 1) If main steam temperature pressure (parameter) is lower than the metal temperatureunder exact match line in figure 3, unit should raise its speed to rated running speed within 10min

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and synchronize and run with minimum load according to figure 4. Under this condition, it is notnecessary to hold long with minimum load, because long time starting and long time running withminimum load will cool turbine metal.

2) In order to decrease heat stress and shorten starting time, figure 3 can be used for choosingmain steam parameter in figure 1, which will make it closer to residual metal temperature.

5.8 Main steam parameters during start

Note: To avoid heat impact in steam chamber, this curve shows the relationship between inletsteam pressure of main steam valve, inlet steam temperature of main steam valve and inner wallmetal temperature in steam chamber. These parameters are the ones during control switchingfrom main steam valve to governor running speed.

When metal temperature in steam chamber is lower than corresponding saturation temperature ofmain steam pressure, temperature equals to or higher than minimum inlet steam temperature inabove will be obtained. Use pre-start valve of main steam valve to continue to run the unit untilmetal temperature in steam chamber reaches to saturation temperature. Then valves can be

switched.

During cold state start, before control switching from main steam valve to governor valve, inlet

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steam parameter of main steam valve should be in ‘Cold state start’. During hot state start, beforecontrol switching from main steam valve to governor valve, inlet steam parameter of main steamvalve should be higher than ‘Main seam valve minimum inlet steam temperature’.

5.9 Changing load recommeded value——fixed pressure mode

5.10 Recommeded value of changing load

Sliding pressure and sequence valve mode

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5.11 Circulating indexes under different load increase rate and decrease rate

112



5.12 Gland sealing steam temperature recommended valves

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5.13 Typical HP cylinder cool ing curve

English中文

Typical HP cylinder cooling time curve典型高压缸冷却时间曲线

If the unit trips at first stage, metal temperatureis different from the corresponding time in chart(i.e. 000F,4820C, ) removable time is R, whichmakes zero point of time correspond the firststage metal time when trip

如果机组在跳闸时的第一级，金属温度不同于图

中时间，所对应的温度（即 9000F，4820C，则

可移动时间比如R，使时间零点对应于发生跳闸

时的第一级金属温度

Time after trip hour跳闸后的时间小时

First stage metal temperature第一级金属温度

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6 Auxiliary operation regulations

6.1 General

6.1.1 Notices for start and stop

6.1.1.1 All interlocks, protection tests must be done for repaired equipments before trial operation,

its control circuit, automatic devices, I&C interlock protections, mechanical devices andpneumatic devices should be tested to be qualified according to regulations before trialoperation.

6.1.1.2 Repaired auxiliary equipments can only be put into operation or standby after its trialoperations are qualified. Trial operation should be presided by maintenance principal. Ifmotor is in maintenance, running direction should be right and then connect it to theauxiliary equipment. Static open & close test should be tested for 11kV & 3.3kV powerequipment or maintenance has made it clear.

6.1.1.3 Before trial operation, auxiliary equipments must be checked locally and only can be sentpower after all the conditions for starting are satisfied.

6.1.1.4 Insulation should be measured before sending power or starting for motors that stopped

for more than one (1) week or may be wet.

6.1.1.5 Special person should be sent to local for supervision when starting 11kV & 3.3kVequipments and important 415V equipments. Person at local should be stand besideemergency button and stop the equipment if any problem is found.

6.1.1.6 Two (2) or more 11kV & 3.3kV sets that are on same bus line can not be started at thesame time.

6.1.1.7 If the auxiliary equipment trips during starting, it can not be started before faults arecleaned.

6.1.1.8 Oil system of auxiliary equipments that equipped with forced circulating lubricate oilsystem or hydraulic control oil system should be started two (2) hours in advance after a

long term stop in winter.

6.1.1.9 Relevant personnel should be contacted before starting the auxiliary equipments.

6.1.1.10 Start of auxiliary equipments should be done according to logic relationship and trybest not to start with load.

6.1.1.11 Special personnel should be sent to supervise current and start time during auxiliaryequipment start; if start time exceeds regulations and current does not recover, theequipment should be stopped at once.

6.1.1.12 Start and stop of auxiliary equipments are generally operated on relevant CRT screen;pay attention that control switch should be at ‘Remote’ position. If it needs to be startedor stopped locally, the control switch should be at ‘Local’ position.

6.1.1.13 When starting auxiliary equipments or selecting standby equipment, pay attention thatload at sections of unit power is evenly distributed to avoid load collecting at onesection.

6.1.2 Checking content before start

6.1.2.1 Check and make sure that all work permit tickets relevant to starting equipment areconcluded. All working personnel checking locally have withdrawal. Check and make surethat there is no foreign material in or round the equipment and lighting is sufficient.

6.1.2.2 Check and make sure that equipment appearances are complete and connections arefixed and reliable. Safety sleeve for running parts should be installed. Manholes are strictlyclosed and anchor screws and connecting bolts are not loosened. Relevant meters shouldbe in operation.

6.1.2.3 Check and make sure that lubricate oil is filled for bearings; oil quality, oil level and oiltemperature comply with requirements. Cooling water and sealing water of equipments are

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6.1.2.4 Check and make sure that motor connections are fixed, earth wires are good andinsulation is measured to be qualified.

6.1.2.5 Check and make sure that local emergency button connections are good and safety

sleeve is complete.

6.1.2.6 Check the system completely according to check card; discharge air and fill oil or water forrelevant oil, water system and pump proper.

6.1.2.7 Turn the rotors of auxiliary equipments that can be turned manually; make sure thatrunning is agile with no block.

6.1.2.8 Complete the check before starting auxiliary equipments and send relevant dynamicpower and control power to auxiliary equipment and relevant system devices after startingconditions are confirmed.

6.1.3 Check after start

6.1.3.1 Temperature rise for bearing (tile) of running equipments and speed reducing box should

obey regulations from the manufacturer; if there is no regulation from manufacturer,generally sliding bearing should not exceed 80 ; rolling bearing temperature should not℃

exceed 100 (environment temperature is calculated as 40 ). Slid℃ ℃ ing bearingtemperature of motors produced by Shanghai Motor Co., Ltd should not exceed 90 and℃

rolling bearing temperature should not exceed 95 .℃

6.1.3.2 Vibration of equipments complies with regulations. Bearing vibration should be controlledas following table:

Bearing vibration permit value

Running speed（rpm） 3000 1500 1000 750及以下

Vibration permit double

amplitude (mm) 0.05 0.085 0.10 0.12

6.1.3.3 Temperature rise and current indications of motors comply with regulations.

6.1.3.4 Oil levels in lubricate oil tank is normal and there is no oil leakage in the system.

6.1.3.5 Sealing part of equipments should be well sealed.

6.1.3.6 There is no abnormal sound and friction in motor or equipments.

6.1.3.7 Mechanical connections of regulation devices should be complete with no drop.

6.1.3.8 Inlet, outlet pressure and flow are normal.

6.1.3.9 Make sure that all interlocks and automatic regulation devices are in operation and arenormal.

6.1.3.10 There is no water leakage, steam leakage or oil leakage in system.

6.1.4 Auxi liary equipment stop

6.1.4.1 Auxiliary equipments should be stopped according to logic relation among the equipments.

6.1.4.2 Relations between protections and interlocks should be fully considered during stoppingauxiliary equipments to avoid appearance of interlock act and trip etc.

6.1.4.3 Stopped auxiliary equipment also should be normally supervised, it should be isolated ifany reversal running happens.

6.1.4.4 Necessary anti-freezing measures should be prepared for relevant stopped equipments inwinter.

6.1.4.5 During isolation for maintenance, isolation only can be done after stopping auxiliaryequipments.

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6.1.5 Conditions for auxiliary equipments emergency stop

6.1.5.1 There is acute vibration or axial moving which may damage equipment.

6.1.5.2 Bearing temperature increases abnormally or exceeds regulated value.

6.1.5.3 Motor stator and rotor abrade heavily or are in smoke or on fire.

6.1.5.4 Auxiliary rotor and shell abrade heavily or impact with each.

6.1.5.5 Auxiliary equipment is on fire or immersed in water.

6.1.5.6 Equipment threatens personal safety.

6.2 Start & stop of ci rculating water system

6.2.1 Start of circu lating water system

6.2.1.1 Feeding water into circulating water system

1) Start circulating pump trash remover.

2) Start circulating water pump rotating strainer.

3) Open outlet of circulating water pump manually, check and make sure that inlet &outletwater valve of condenser are fully open.

4) Start circulating water vacuum pump, extract air and fill water to circulating watersystem.

5) Make sure that interlock protection test of circulating water system is qualified and inoperation, I&C power is working.

6.2.1.2 Check of circulating water system and circulating water pump

1) Circulating pump group alignment is completed and anchor bolts are complete and tight.

2) Circulating water pump outlet butterfly valve is closed, circulating water pump butterflyvalve oil pump station works normally, butterfly valve interlock switch is at ‘Remote’position, outlet butterfly valve control mode on CRT is at ‘Pump valve interlock’ position.

3) Circulating water pump inlet suction well water level is normal, circulating water pumpinlet trash remover trial operation is good and is ready for operation at any moment.

4) Circulating water pump motor oil system is at normal standby.

5) Condenser circulating water inlet valve is open.

6) Condenser circulating water outlet valve is open.

7) Circulating vacuum pump runs normally and system is fulfilled with water.

8) Water discharging valves in circulating water system are closed.

6.2.1.3 Circulating water pump start

1) Check and make sure that oil levels in high position oil tank and low position oil tank arehigher than 1/2.

2) Check and make sure that circulating water pump and bearing oil levels are normal andoil is qualified. All oil discharging valves are strictly closed.

3) Check and make sure that oil level in butterfly valve oil station is higher than 1/2 and oilpressure is normal.

4) Open the general stop valve from industrial water head pipe to circulating water pumpmotor.

5) Open manual isolation valves before and after cooling water strainer of circulating waterpump motor.

6) Open the outlet hydraulic butterfly valve of circulating water pump to be started remotelyto 150, start circulating water pump.

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7) Fully open outlet hydraulic check valve of running circulating water pump manually.

8) Check and make sure that circulating water pump current, outlet pressure and vibrationare normal. Outlet hydraulic butterfly of running pump is in interlock.

9) Stop circulating water vacuum pump, completely check and make sure that all parts ofcirculating water system are normal.

10) When start the second circulating water pump, start the circulating water pump remotely.Check and make sure that outlet butterfly valve opens normally by interlock.

11) Pay attention to the working condition of circulating water pump motor cooling water.

6.2.2 Circulating water stop

6.2.2.1 Check and make sure that pump valve local control mode is at ‘Remote’ position; outletbutterfly control mode on CRT is at ‘Pump valve interlock’ position. Special personnelshould be at site for supervision before stopping pump.

6.2.2.2 Stop circulating water pump, check and make sure that outlet butterfly valve should closeby interlock and pump does not run in reversal; otherwise relief pressure and close thevalve manually.

6.2.2.3 Stop the last circulating water pump after all auxiliary equipment stop, LP cylinder ( , )Ⅰ Ⅱ

temperature is lower than 50 and there is no user of circulating water.℃

6.2.3 Circulating water system operation and maintenance

6.2.3.1 Circulating water pump outlet pressure is 0.18— 0.25 MPa and motor current is lower than368A.

6.2.3.2 Circulating water pump motor oil chamber level is at 1/2 -- 3/4, temperatures of circulatingwater pump motor upper guide pad and circulating water pump thrust pad temperature arelower than 75 .℃

6.2.3.3 Pump group coupler horizontal vibration is no higher than 0.05 mm, axial vibration is nohigher than 0.03 mm, the sound is normal and generator stator winding temperature is nohigher than 140 .℃

6.2.3.4 Circulating water pump outlet butterfly oil pump station is working normal. Oil pump startswhen oil pressure is lower than 6MPa and stops when oil pressure is higher than 11MPa.

6.2.3.5 Check trash remover and rotating strainer working condition to prevent strainer fromblocking by impurities.

6.2.3.6 Trash remover starts automatically when front and rear water level difference reaches to200mm and stops automatically when the water level difference reaches to 30mm.

6.3 Open cool ing water system start and stop

6.3.1 Open circu lating cooling water system

6.3.1.1 Check before starting open circulating cooling water pump

1) Make sure that system and pump interlock test id qualified.

2) Circulating water system is working normally.

3) Open inlet strainer front and rear check valves of open circulating water pump, closebypass valve, close blow down valve after blowing down and put inlet strainer into‘Automation’ control mode.

4) Close all water discharging valve in the system and open inlet valve of open coolingcirculating water pump.

5) Open air discharging valves in open circulating water pump proper and the system; closethe valves when water is seen.

6) Open cooling water inlet & outlet valves of closed cooling water heat exchanger (A, B or

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C) to offer access of open circulating water.

6.3.1.2 Open circulating water system start

1) Start open circulating water pump A or B, check and make sure that outlet valve actuatesnormally. Motor current, vibration, sound, pressure and bearing temperature are normal.

2) Fully Open outlet valves of standby open circulating cooling water pump and put intostandby.

6.3.2 Open circu lating cooli ng water system stop

6.3.2.1 Make sure that open circulating cooling water users are with conditions for cutting off watersupply.

6.3.2.2 Release ‘Standby’ interlock of standby pump and close outlet valve of standby pump.

6.3.2.3 Stop the pump, outlet valve of the former running open circulating cooling water pumpcloses automatically.

6.3.3 Open circu lating cooling water pump switching

6.3.3.1 Check and make sure that standby open circulating cooling water pump is in fine condition

and with conditions for starting.

6.3.3.2 Check and make sure that standby open circulating cooling water pump inlet valve isopen.

6.3.3.3 Release standby open circulating cooling water pump from ‘Standby’.

6.3.3.4 Start standby open circulating cooling water pump, check and make sure that it current,vibration, sound and outlet pressure are normal.

6.3.3.5 Stop the former running open circulating cooling water pump, check and make sure thatCRT indications are right and pump does not run in reversal locally.

6.3.3.6 Check the signal of open circulating cooling water head pipe pressure low; put the formerrunning pump into ‘Standby’ according to requirement.

6.3.4 Open circu lating system operation and maintenance

6.3.4.1 Open circulating cooling water pump inlet strainer differential pressure is not higher thanspecified value.

6.3.4.2 Open circulating cooling water pump and motor bearing temperature are normal.

6.3.4.3 Open circulating cooling water pump motor winding temperature, the sound, vibration andfriction between pump and motor are normal.

6.4 Closed circulating cooling water system start and stop

6.4.1 Closed circu lating cooling water system start

6.4.1.1 Check before start1) Open the head pipe inlet valve from closed water tank to closed water returning water.

2) Put closed cooling water tank water level indicator into operation.

3) Close all the water discharging valves in the system; open air discharging valve andclose it as water is seen.

4) Open check valves before and after closed cooling water tank level automatic regulatingvalve.

5) Start condensing water transfer pump to supplement water to closed cooling water tankto normal level (Make-up water valve from condensing water pump outlet to closedwater tank can be open).

6) Open closed cooling water pump inlet motorized valve.

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7) Open closed cooling water cooler inlet and outlet valve, feed water and discharge air forthe pump proper and the system, close air discharging valve after air discharged.

8) Offer closed cooling water access.

9) Check and make sure that closed water pump bearing oil is qualified.

6.4.1.2 Make sure water feeding and air discharging is completed, close pump outlet valve.6.4.1.3 Start closed cooling water pump (A or B), pay attention that pump outlet valve opens by

interlock until it is fully open and closed water tank level is normal; otherwise open bypassvalve for water supplement. Check and make sure that motor current, pump groupvibration, sound, outlet pressure, bearing temperature are normal; regulate the closedcooling water system users to ensure that closed pump is in over current.

6.4.1.4 After standby closed pump water feeding and air discharging is completed, open the outletvalve of standby pump and put the pump into ‘Standby’.

6.4.1.5 Closed cooling water pump interlock protection.

6.4.1.6 Conditions of starting closed circulating cooling water pump

6.4.1.7 Open circulating cooling water system is working normal.6.4.1.8 Closed circulating cooling water level is not low.

6.4.1.9 Closed circulating cooling water pump trip conditions

1) Closed circulating cooling water pump on for 60s and it’s outlet valve closed.

2) Closed water pump suction header pressure low low.

3) Closed water pump motor drive end bearing temperature ≥95 .℃

4) Closed water pump motor non-drive end bearing temperature ≥95 .℃

5) Local emergency button is pressed down.

6.4.1.10 Closed water pump interlock start conditions

1) The closed water pump outlet main pipe pressure still low, while one of the pumpsrunning more than 10s.

2) Running closed water pump trips.

6.4.2 Closed circu lating cooling water system stop

6.4.2.1 Make sure that all the closed water users are with conditions for cutt off water supply.

6.4.2.2 Release standby pump from ‘Standby’ and close it outlet valve.

6.4.2.3 Stop closed cooling water pump.

6.4.2.4 Check and make sure that running pump outlet valve closes automatically, otherwise close

it manually.6.4.2.5 Stop supplementing water to closed cooling water tank.

6.4.2.6 Close closed cooling water and cooling water inlet & outlet valve according to requirementand stop closed water cooler.

6.4.3 Closed cool ing water pump switching

6.4.3.1 Check and make sure that standby pump is in fine condition and with start conditions.

6.4.3.2 Check and make sure that closed water tank level is normal.

6.4.3.3 Check and make sure that standby pump inlet valve is open.

6.4.3.4 Release standby pump from ‘Standby’.

6.4.3.5 Start standby pump. Check and make sure that current, vibration, sound and outletpressure are normal; CRT status indications are right.

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6.4.3.6 After complete check, make sure that former running pump outlet valve and closed waterhead pipe pressure is normal.

6.4.3.7 Stop former running pump, check and make sure that CRT indications are right.

6.4.3.8 Start former running pump outlet.

6.4.3.9 Check that closed water head pipe has no low pressure signal, put former running pumpinto ‘Standby’.

6.5 Start & stop of auxi liary steam system

6.5.1 Preparation for starting auxiliary steam

6.5.1.1 Preparation for machinery, see as in valve operation card.

6.5.1.2 Make sure that auxiliary safety is calibrated and normal.

6.5.2 Start HP auxiliary steam connection

6.5.2.1 Contact start-up boiler to start auxiliary steam.

6.5.2.2 Make sure that all drainage valves before HP auxiliary steam head pipe and user’s valve

are fully open, Slightly open HP auxiliary motorized valve from start-up boiler, keep the

pressure of HP auxiliary steam connection is 0.05～0.1MPa, heat HP auxiliary steam

connection pipes about 20 minutes.

6.5.2.3 When there is steam emitting from all drainage water pipe, Slightly open HP auxiliary

motorized valve from start-up boiler, and rise the pressure of HP auxiliary steam

connection to 1.27MPa.

6.5.2.4 Check start-up boiler HP auxiliary steam desuperheat valve adjust normally, HP auxiliary

steam connection temperature is between 315～335 .℃

6.5.2.5 Put all auxiliary users into operation according requirements, and make sure that auxiliary

steam head pipes are sufficiently heated.6.5.3 Start IP auxiliary steam connection

6.5.3.1 Contact start-up boiler to start auxiliary steam.

6.5.3.2 Open HP auxiliary steam to IP auxiliary steam connection motorized valve, front and back

drainage valve, and IP auxiliary steam connection to drainage valves of head pipe, slightly

open HP auxiliary steam to IP auxiliary steam valve, keep IP auxiliary steam connection is

0.05～0.1MPa, heat IP auxiliary steam connection pipes about 20 minutes.

6.5.3.3 Open HP auxiliary steam to IP auxiliary steam motorized valve, rise the pressure of IP

auxiliary steam connection to 0.75～1MPa, put HP auxiliary steam to IP auxiliary steam

valve into automatically control, check HP auxiliary steam to IP auxiliary steam valve

adjust normally.

6.5.3.4 Check HP auxiliary steam to IP auxiliary steam valve adjust normally, IP auxiliary steam

connection temperature is between 250 .℃ 6.5.4 Switching HP auxiliary steam to reheating cold section:

6.5.4.1 Switching HP auxiliary steam header to reheating cold section when pressure of reheatingcold section higher than pressure of HP auxiliary steam header.

6.5.4.2 Confirm that isolation valve after auxiliary steam regulation valve from reheating coldsection to auxiliary steam head pipes is open, drainage valve before check valve from coldsection to auxiliary is open and drainage valve before isolation valve is open.

6.5.4.3 Check and make sure that auxiliary cold section inlet steam regulation valve set pressurevalue is lower than auxiliary head pipe pressure; regulation valve is at automatic closeposition.

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6.5.4.4 Sufficiently open auxiliary cold section steam inlet motorized valve, then set auxiliary clodsection inlet steam regulation valve pressure a little higher than auxiliary header pressure.Make sure that auxiliary steam cold section inlet steam regulation valve open slowly andregulates automatically to required set value. Start up boiler may run with decreased load.

6.5.4.5 Check and make sure that all drainage valves of auxiliary steam headers and users are at

regulation position; auxiliary pipe and auxiliary steam safety valve have no leakage.6.5.5 Switching from IP auxiliary steam to four th section extraction

6.5.5.1 Switch IP auxiliary steam to fourth section extraction when pressure of fourth sectionextraction higher than pressure of IP auxiliary steam header.

6.5.5.2 Make sure that all drainage water regulations in pipes from fourth extraction are normal,slowly open steam incoming motorized valve from auxiliary steam. Make sure that there isno impact or vibration in pipes.

6.5.5.3 Regulate auxiliary steam cold section inlet steam regulation valve pressure to be lightlylower than auxiliary steam fourth extraction pressure. Check and make sure that auxiliarysteam cold section inlet steam regulation valve closes gradually with the rising of auxiliarysteam fourth extraction steam.

6.5.5.4 Stop start up boiler according to requirement.

6.5.6 Auxil iary steam system stop

6.5.6.1 If auxiliary steam system needs to be stopped, it can be stopped after confirming that thereis no auxiliary steam user and shift manager’s approval.

6.5.6.2 Close auxiliary steam cold section steam inlet isolation valve, motorized valve, auxiliarysteam head pipe connection valve, fourth extraction motorized valve, auxiliary steamisolation valve and motorized from start up boiler.

6.5.6.3 Sufficiently open all the drainage water valves of auxiliary steam head pipe.

6.5.6.4 Auxiliary steam system start, stop and switching should be reported to shift manager

timely.

6.6 Condensing water system start and stop

6.6.1 Preparation before starting condensing water system

6.6.1.1 Preparation part for machinery, please see as in check cards.

6.6.1.2 Make sure that closed cooling water system and air compress system is working normally.

6.6.1.3 Contact with chemical to supplement water to desalt water tank to about normal value,condensate water make-up water tank make-up control valve put into automaticallycontrol.

6.6.1.4 Start condensing water transfer pump.

1) Confirm that condensing water pump inlet valve, re-circulating valve is open and pumpoutlet valve is closed.

2) Open condensing water transfer pump air discharging valve, inlet strainer air dischargingvalve; close them when water is seen.

3) Slightly open outlet valve, start condensing water transfer pump, check and make surethat pump and motor sound, vibration, bearing temperature, motor current and outletpressure are normal.

6.6.1.5 Water feeding to condensing water system and water supplement for condenser

1) Open condensing water transfer pump outlet valve gradually and regulate re-circulatingvalve openness properly.

2) Open condenser water supplement bypass valve to supplement water to condenser.

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3) When condenser water level is normal, close water supplement bypass valve and slightlyopen condensing water transfer pump re-circulating valve.

4) Open check valves before and after condenser water supplement regulation valve andput water level into automatic control.

5) Open feeding water valve from condensing water transfer pump to condensing water

system, open air discharging valves in condensing water system to feed water anddischarge air. Close all air discharging valves when continuously water is seen.

6.6.2 Conditions for starting condensing water pump:

6.6.2.1 Condenser water pump motor up and down bearing temperature <85 .℃

6.6.2.2 Condenser water pump thrust bearing temperature <75 .℃

6.6.2.3 Open condenser water pump inlet valve.

6.6.2.4 High and low back pressure condenser water level is not low.

6.6.2.5 Condenser water pump sealing water pressure is not low.

6.6.2.6 Condenser water pump re-circulating valve is open >95%.

6.6.2.7 No fault signals for condensing water pump.

6.6.3 Condensing water pump start:

6.6.3.1 Make sure that condenser water pump water level is normal; all interlock protection testsof condenser water pump are qualified.

6.6.3.2 Make sure that condensing water system is feeding water and air discharging iscompleted.

6.6.3.3 Make sure that condensing water transfer pump outlet pressure is normal.

6.6.3.4 Start sealing water valve from condensing water transfer pump outlet to condensing waterpump, put condensing water pump sealing water into operation.

6.6.3.5 Open air discharging valves of condenser water pump inlet strainer, pump proper and airdischarging valve before outlet valve.

6.6.3.6 Open condenser water pump inlet valve, feed water to condenser water pump. Make surethat condenser water pump re-circulating valve is open.

6.6.3.7 Send power to condenser water pump.

6.6.3.8 According to actual conditions, start condensing water pump with frequency conversion orworking frequency. Make sure that current, vibration, sound and pressure indications arenormal. Make sure that outlet valve opens automatically after pump starts; otherwise openit manually.

6.6.3.9 Check whether water level of condenser hot well and pressure of condensate water pipe is

normal, check system has no leakage phenomenon.

6.6.3.10 Open sealing water valve form condenser water pump outlet to pump proper, closesealing water valve from condenser water transfer pump to condenser water pump.

6.6.3.11 Open inlet valve of the other condenser water pump, open extraction valve beforepump proper and outlet valve, open outlet valve (notice: pump should not runningreverse)and put into standby.

6.6.4 Condensing water stop:

6.6.4.1 After unit stop, make sure that LP cylinder steam exhausting temperature (HP, LPcondenser) is lower than 50 and there is no other users suing water, then stop the℃ condenser water pump.

6.6.4.2 Release standby condenser water from ‘Standby’.

6.6.4.3 Stop condenser water pump.

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6.6.4.4 Make sure that condenser water pump outlet valve should close automatically; otherwiseclose it manually.

6.6.5 When condenser water pump should be isolated for maintenance after stoppingcondenser water pump, close pump proper and outlet valve, close inlet valve, closesealing water pump from condenser water pump outlet to pump, close sealing water valve

from condensing water transfer pump to condenser water pump.6.6.6 Condensing water pump switching:

6.6.6.1 Make sure that condenser water pump is in standby and with starting conditions.

6.6.6.2 Make sure that sealing water of condenser water pump is working normally.

6.6.6.3 Make sure that standby condenser water pump inlet valve is open.

6.6.6.4 Make sure that standby condenser water pump outlet is open.

6.6.6.5 Make sure that condensing water system is working normally.

6.6.6.6 Make sure that pump proper and outlet valve are open.

6.6.6.7 Release standby condenser water pump from ‘Standby’.

6.6.6.8 Start standby condenser water pump.

6.6.6.9 Check and make sure that motor current, vibration and sound are normal after condenserwater pump starts, CRT indications are right.

6.6.6.10 Check and make sure that condensing water system pressure is normal.

6.6.6.11 Stop the former running pump, outlet valve closes automatically. Make sure that CRTindications are right.

6.6.6.12 Check and make sure that pump does not run in reversal after the running pump stops.

6.6.6.13 Check and make sure that there is no signal of pressure low at outlet head pipe ofcondenser water pump, open outlet valve of former running pump and put the former

running pump into standby according to requirement.

6.6.7 Condensing water pump operation and maintenance

6.6.7.1 Condenser water pump outlet pressure is normal and current does not exceed set value.

6.6.7.2 Condenser water pump thrust bearing oil is qualified. Condenser water pump motorbearing does not exceed 85 .℃

6.6.7.3 Condenser water pump gland packing has no leakage, sealing water and motor bearingcooling water are working normally.

6.6.7.4 There is abnormal sound in water pump or motor, motor up and down bearing vibration donot exceed set value.

6.6.7.5 Condenser water pump motor winding temperature does not exceed set value.6.7 Deaerator start and stop

6.7.1 Preparation before starting deaerator

6.7.1.1 Make sure that compressed air system is working normal and air pressures of instrumentalmeters are normal.

6.7.1.2 Make sure that all instrumental meters of deaerator are complete and all water levelindicators are working normally.

6.7.1.3 Make sure that auxiliary steam system is working normally; auxiliary steam pressure andtemperature comply with requirements.

6.7.1.4 Make sure that condensing water system is working normally and water is qualified.

6.7.1.5 Deaerator water, pressure interlock protection tests are qualified. Put measuring and

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6.7.1.6 Make sure that following valves are closed:

1) Continuous air discharging primary and secondary valves from #1, 2, 3 HP heaters todeaerator.

2) Relevant isolation valves for nitrogen charging protection of deaerator.3) Deaerator emergency water discharging valve and over flow valve.

4) Open normal discharged water control valve and front, back manually valve fromdeaerator to #3 HP heater before #3 HP heater is running.

5) Motorized isolation valve and check valve from fourth steam extraction to deaerator.

6) Pressure regulating valve and its isolation valve from auxiliary steam to deaerator.

7) Valve from boiler air heater drainage water to deaerator.

8) Valve from continuous blow down to deaerator.

6.7.1.7 Start deaerator and open air discharging valve.

6.7.1.8 All the pipes of deaerator should be flushed and cleaned after major or minor maintenanceor for the first start.

6.7.2 Deaerator start

6.7.2.1 Supply water to deaerator can use condensate pump or condensate transformation pump.

6.7.2.2 Supply water from condensate water to deaerator after deaerator cleaning is over andquality of condensate water is ok, keep deaerator water level at about 1400mm, slightlyopen deaerator water level control valve, feed water into pipe, increase flux when air hasbeen exhausted, avoid damage nozzle.

6.7.2.3 Open motorized pump booster pump inlet valve, open isolation valve before and afterre-circulating regulation valve of motorized pump. Feed water and discharge water for the

motorized pump.

6.7.2.4 Open inlet valve of A, B steam driven steam pump booster pump; open isolation valvesbefore and after A, B steam driven pump re-circulating; feed water and discharge water for A, B steam driven pump booster pump.

6.7.2.5 Check whether motorized pump comply with start conditions or not, start motorized pump(or start steam driven feed water pump booster pump, put deaerator into operation forheating).

6.7.2.6 Check and make sure that drainage valve after motorized valve from HP auxiliary steam todeaerator, open motorized valve from HP auxiliary steam to deaerator slowly for heatingpipe. Pay attention to control pipe temperature rise rate to avoid pipe vibration.

6.7.2.7 After heating pipes, close the drainage water valves. Open motorized valve from auxiliarysteam to deaerator. Open regulation valve slowly to keep deaerator temperature rise ratebe within 1.5 /min and heat and deoxidize the water in deaerator water tank.℃

6.7.2.8 Heat the water in deaerator according to boiler feed water temperature requirement,control the temperature difference of drum inlet water and inner wall metal to be lower than90 to make the drum inner & outer wall temperature difference and up & down wall℃

temperature difference be within regulated values.

6.7.2.9 After putting condensing water system into operation, control deaerator water level withdeaerator water level regulation valve.

6.7.2.10 When feed water pump starts and deaerator water level and flow are normal, putdeaerator water level automatic regulation into operation according to requirement.

6.7.2.11 During unit start and feeding water to boiler, deaerator pressure should be controlled at0.147MPa and deaerator is working with fixed pressure.

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6.4.7.8 When feed water pump stopped, water level control valve of deaerator should switch tomanual control and then close it, stop supply water to deaerator.

6.4.7.9 Take good care of deaerator after stop it. If deaerator stops for more than one week, itshould be protected by charging nitrogen. Cut off all steam source and water source, closewater discharging valve after water in water tank is completely discharged. After fullisolation, open nitrogen charging valve and isolation valve to charge nitrogen into

deaerator and keep a certain pressure.

6.8 Motorized feeding water pump start and stop

6.8.1 Check before start

6.8.2 All interlocks of motorized feeding water pump should be tested to be qualified, allinterlocks and relevant meters are working:

6.8.2.1 Check and make sure that cooling water is working normally.

6.8.2.2 Check and make sure that motorized feeding water pump oil tank level is normal and oilsystem is ready for operation.

6.8.2.3 Start motorized feeding water pump, check and make sure that oil system is working

normally.

6.8.2.4 Regulate oil cooler water outlet valve of motorized feeding water pump, keep oil

temperature within 36～54 .℃

6.8.2.5 Check and make sure that all water discharging valves of pump group and its pipelines areclosed.

6.8.2.6 Check and make sure that deaerator water tank level is normal, water is qualified andwater temperature meets the requirement of feeding water to boiler. Slightly open boosterpump inlet valve and feed water to booster pump, feeding water pump and pipeline anddischarge air in them. Air valve closes after seeing water. After water feeding and airdischarging, fully open inlet valve.

6.8.2.7 Outlet motorized valve of motorized feeding water is closed.6.8.3 Open check valves before and after minimum flow valve of motorized feeding water

pump, open circu lating valve after it is conf irmed.

6.8.3.1 Open closed water inlet valve of mechanical sealing of motorized feeding water pump,open the outlet valve after feeding water and discharging air.

6.8.3.2 Open mechanical sealing water magnetism filter inlet & outlet valves of motorized feedingwater pump, close bypass valve.

6.8.3.3 Put mechanical sealing water of motorized feeding water pump booster pump intooperation.

6.8.3.4 Check and make sure that spoon actuator power supply of motorized feeding water is

normal.

6.8.3.5 Send power to motorized feeding water pump.

6.8.4 Motorized feeding water pump start

6.8.4.1 Make sure that all the conditions for motorized feed water pump start are satisfied.

1) Motorized feeding water pump temperature is normal.

2) Motorized feeding water pump re-circulating regulation valve is open.

3) Lubricate oil pressure is not low.

4) Motorized feeding water pump outlet valve is closed.

5) Motorized feeding water pump booster pump inlet valve is open.6) Deaerator water level is not low.

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7) Motorized feeding water pump spoon pipe is at minimum position.

6.8.4.2 Make sure that motorized feeding water pump outlet motorized valve is closed.

6.8.4.3 Set motorized feeding water pump spoon pipe at 10%~15% position.

6.8.4.4 Start motorized feeding water pump; make sure that motor cooling water is working. If 10s

after motorized feeding water pump start, current has not recovered to be normal, pumpshould be stopped immediately.

6.8.4.5 Completely check and make sure that all bearing inlet oil and returning oil temperatures,vibration, sound and strainer differential pressure are normal.

6.8.4.6 Open motorized feeding water pump outlet valve, regulate motorized feeding water pumpspoon pipe to required position to feed water to feeding water pipes and discharge air;after air is completely discharged, regulate motorized feeding water pump spoon pipe tofeed water to boiler.

6.8.4.7 When motorized feeding water pump lubricate oil pressure is higher than 0.22MPa,motorized feeding water pump auxiliary oil pump stops normally by interlock.

6.8.4.8 After pump runs normally, pay attention to the change of motorized feeding water pump

sealing water temperature, regulate oil cooler cooling water timely to make lubricate oil ofmotorized feeding water pump be within 36～54 and working oil temperature be within℃

36～70 .℃

6.8.4.9 Check and make sure that motorized feeding water pump lubricate oil pressure andworking oil pressure are normal.

6.8.4.10 Open the tap valve in the middle according to requirement.

6.8.5 Motorized feeding water pump stop

6.8.5.1 Check and make sure that motorized feeding water pump minimum flow valve is at‘Automation’ position.

6.8.5.2 Close motorized feeding water pump spoon pipe gradually and make sure that minimumflow valve is normally open.

6.8.5.3 When motorized feeding water pump lubricate oil pressure is lower than 0.15MPa,motorized feeding water pump auxiliary pump can start normally by interlock.

6.8.5.4 Continue to close motorized feeding water pump spoon pipe until it is fully closed.

6.8.5.5 Close tap valve in the middle of motorized feeding water pump.

6.8.5.6 Stop motorized feeding water pump and close outlet motorized valve of the pump.

6.8.6 Conditions for motor ized feeding water pump standby

6.8.6.1 All AC & DC power supply of motorized feeding water pump are sent (power supply ofactuator of pump spoon pipe) .

6.8.6.2 Motorized feeding water pump oil tank level is normal and oil is qualified.

6.8.6.3 Motorized feeding water pump has been put into ‘Standby’.

6.8.6.4 Motorized feeding water pump auxiliary lubricate oil pump runs continuously; oil pressure,oil temperature and all flows of all bearings are normal.

6.8.6.5 Motorized feeding water pump booster pump inlet valve are fully open.

6.8.6.6 Motorized feeding water pump spoon pipe is at ‘5%’ position.

6.8.6.7 Motorized feeding water pump outlet motorized valves are fully open.

6.8.6.8 Isolation valves before and after motorized feeding water pump minimum flow are fully

open. Minimum flow valve is fully open and in ‘Automation’.6.8.6.9 Manual isolation valves of motorized feeding water pump tap valve are fully open.

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6.8.6.10 All interlock protectors of motorized feeding water pump are working and all measuringmeters, transmitters are working.

6.8.7 Motorized feeding water pump operation and maintenance

6.8.7.1 Motorized feeding water pump inlet and outlet pressure are normal, current does notexceed rated value.

6.8.7.2 Motorized feeding water pump oil tank level is normal, oil is qualified. Motorized feedingwater pump lubricate oil pressure is higher than 0.17MPa, filtered lubricate oil pressure of

motorized feeding water pump is normal within 0.25～0.35 MPa. Motorized feeding water

pump lubricate oil cooler inlet temperature is lower than 65 , lubricate oil cooler outlet℃

temperature is ＜55 , working oil cooler inlet oil temperature is lower than 1℃ 10 ,℃

working oil cooler outlet oil temperature is lower than 75 . All bearings returning oil℃

temperature do not exceed 65 .℃

6.8.7.3 Motorized feeding water pump radial bearing temperature is lower than 80 , thrust℃

bearing temperature is lower than 90 , booster pump bearing temperature is lower than℃

90 , all bearing metal temperatures of motorized feeding water pump coupler are less℃

than 90 , mechanical sealing water temperature is normal and s℃ ealing ring temperature

is no higher than 80 .℃

6.8.7.4 Motor cooling water is normal, cooling water temperature is lower than 38 , wa℃ terpressure is normal.

6.8.7.5 There is no abnormal sound in water pump and motor. Motorized feeding water pumpdrive end and non-drive end bearing vibration is lower than 7.1 mm/s and do not exceed11.2 mm/s at most.

6.8.7.6 Motorized feeding water pump and booster pump axial displacement is normal.

6.8.7.7 Pump shell and oil system have no leakage. Motorized feeding water pump and boosterpump strainer differential pressure is normal.

6.9 Steam driven feed water pump group start & stop

6.9.1 Conditions should be prepared for starting steam driven feed water pump group

6.9.1.1 Feed water pump turbine is in shutoff.

6.9.1.2 MEH control power supply and other power supplies in system are working.

6.9.1.3 All compressed air source valves are open.

6.9.1.4 Steam parameters comply with requirement.

6.9.1.5 Cooling water source could supply water for oil cooler and steam seal desuperheater atany time.

6.9.1.6 Preparation of mechanical part, see as in valve check cards.

6.9.2 Start lubr icate oil system

6.9.2.1 Make sure that lubricate oil system are with conditions for starting, start oil-fume extractorand make sure that it runs normally.

6.9.2.2 Make sure that conditions for starting #1, #2 lubricate oil pumps and emergency oil pumpare satisfied.

6.9.2.3 Send the power of emergency oil pump and put emergency oil pump interlock intooperation. Check automatic start of emergency oil pump and make sure that it runsnormally; stop the emergency oil pump.

6.9.2.4 Send #1 lubricate oil pump power and put #1 lubricate oil pump interlock into operation; #1lubricate oil pump starts automatically. Make sure that #1 lubricate oil pump runs normally.

6.9.2.5 Send #2 lubricate oil pump power and put #2 lubricate oil pump interlock into operation;open #1 lubricate oil pump test magnet and check #1 lubricate oil pump outlet pressure

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6.9.2.6 Stop #1 lubricate oil pump and start interlock, test #2 lubricate oil pump with abovemethod.

6.9.2.7 Put emergency oil pump interlock, check the interlock of emergency oil pump interlock withabove method.

6.9.2.8 Decide whether supplement oil or not according to oil tank level and decide whether put oilcooler into operation or not according to oil temperature.

6.9.3 Put HP control oil system into operation

6.9.3.1 Turbine fire-resistant oil system is in operation and runs normally.

6.9.3.2 Check and make sure that fire-resistant oil HP accumulator is in normal operation.

6.9.3.3 Open the inlet for supplying fire-resistant oil to feed water pump turbine from turbine, openthe oil returning valve and check whether is leakage or not.

6.9.4 Small turb ine could put into operation when oil pressure of lube oil is satisfied.Small turbine can start only when turning gear running more than 45 minutes in

order to avoid rotor bending and librating.6.9.5 Put gland sealing system into operation and start exhaust valve of small turbine,

vacuum of small turbine is established.

6.9.5.1 Check and make sure that #1, #2 small turbine gland sealing steam inlet isolation valve isopen, gland sealing steam returning valve is open, isolation valves before and after LPattemperating regulation valve of small turbine gland sealing steam supplying are openand bypass valve of attemperating water is closed.

6.9.5.2 Slightly open gland sealing steam inlet isolation valve of small turbine, check and makesure that drainage water in gland sealing air supplying pipes are smooth and small turbinegland sealing sends steam for heating pipes. Regulate gland sealing supplying steamtemperature to about 0.101MPa and steam temperature to 150℃—177℃.

6.9.5.3 After gland sealing starts to supply steam, open small turbine steam exhausting butterflyvalve and try to maintain a high vacuum.

6.9.6 Start small turbine water drainage

6.9.6.1 Make sure that all drainage valve of small turbine and its steam pipe is open before smallturbine start up until turbine load reaches to 40% of rated load.

6.9.6.2 During unit stop, when turbine load decreases to 25% of rated value, above drain valvesshould be opened again.

6.9.6.3 When small turbine trips, pneumatic drainage valve should be opened immediately.

6.9.7 Booster pump start

Booster pump start conditions should be confirmed: Pump group re-circulating valve isopen; booster pump temperature is normal, booster pump inlet valve is open, steamdriven outlet motorized valve is closed, deaerator water tank level is normal and boosterpump feeding water is completed.

6.9.8 Small turbine start

Following conditions should be satisfied before starting small turbine:

6.9.8.1 Make sure that instrumental meters for supervising rotor vibration, axial displacement andrunning speed are complete and working normally.

6.9.8.2 EH oil system is normal, oil pressure is normal.

6.9.8.3 LP main steam valve and governor valve are closed.

6.9.8.4 Gland sealing system is working, gland sealing steam temperature is normal (150 ) and℃

pressure is controlled within 0.101MPa.

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6.9.8.5 Small steam turbine vacuum＞85KPa.

6.9.8.6 All drainage valves and steam exhausting valves of small turbine are open.

6.9.8.7 Lubricate oil pressure and temperature is normal.

6.9.8.8 Deaerator water tank water level is normal.

6.9.8.9 Pump re-circulating valve is fully open and governor valve is in AUTOMATION.

6.9.8.10 Valves of sealing water and cooling of the pump are open and water flow is smooth.

6.9.8.11 Make sure that protections of booster pump, small turbine and steam driven feedingwater pump are working.

6.9.8.12 Small turbine heating pipe. Open water discharging valves before and after LP steamsource motorized valve from auxiliary steam to small turbine, slightly open LP steamsource motorized valve from auxiliary steam to small turbine; close the waterdischarging valve after steam is seen. Fully open LP steam source motorized valvefrom auxiliary steam to small turbine and pay attention to pipe vibration when heatingpipes.

6.9.8.13 Parameters of starting small turbine

Steam pressure: 0.6～1.3MPa。

Steam temperature: with over temperature surplus of more than 50 .℃

6.9.9 Starting small turb ine

6.9.9.1 Press ‘Latch open’ button, unit latch opens.

6.9.9.2 Choose “open LP main steam valve” button at MEH operation station, open LP mainsteam valve.

6.9.9.3 ‘Target running speed’ sets as 800r/min, speed rising rate: 100～200r/min/min.

6.9.9.4 Press ‘GO’ button, LP regulation valve opens gradually, unit increases running speed

according to set velocity.

6.9.9.5 Check at 800r/min, check.

6.9.9.6 Under this speed, heat up the turbine for 15min, check the unit completely: whether statorand rotor abrade or not, vibration is high or not and axial displacement etc.

6.9.9.7 Speed rise to 1800r/min, min-speed warm up.

Press ‘GO’ button, running speed rises to target value.

Under this speed, heat up the turbine for 45min, check the unit completely.

6.9.9.8 ‘Target running speed’ sets as 3000r/min

Press ‘GO’ button, running speed rises to target value.

6.9.9.9 Note: Unit first critical running speed is about 2236 r/min, when turbine runs stably withspeed of 1800 r/min, check all parts are working normally or not, make sure that allsupervision and control meters are working. When there is no abnormity, then it canovercome first critical running speed rapidly.

6.9.9.10 When turbine actual running speed rises to 3000 r/min and it satisfies boiler automaticcontrol conditions, turbine control mode switches stably from running speedautomation to boiler automation. Later, turbine running speed changes with requiredsignals from of feeding water amount from CCS (Boiler feeding water coordinationcontrol system).

6.9.9.11 Start steam driven feed water pump outlet motorized valve and pumps run in parallel

(when steam driven pump outlet pressure approaches to feeding water head pipe,outlet valve opens).

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6.9.9.12 Open middle tap valve of steam driven pump according to requirement.

6.9.9.13 When unit load reaches to 40% of rated load, close small turbine main steam valve,governor valve and all drainage valve on steam pipelines and steam cylinder.

6.9.10 Regulations for feeding water pumps run in parallel

6.9.10.1 Motorized pump and single steam driven pump1) Check and make sure that boiler is at automatic control state, steam driven pump

outlet pressure and motorized pump outlet pressure are close and differentialpressure before and after steam driven pump is lower than 0.06MPa.

2) Make sure that motorized pump runs normally; motorized pump is at automaticcontrol and feed water control is at automation.

3) Unit load is about 180MW.

4) Open steam drive outlet valve, watch the motorized pump and steam driven pumpinlet flow, outlet pressure and minimum re-circulating flow.

5) During paralleling the pumps, try best to keep feeding water flow stable and watch

the variation of drum water level.6) If unit load decreases suddenly, switch steam driven pump from ‘Automatic’ to

‘Manual’ to avoid sudden flow decrease in ‘Automatic’ state and trip due to steamdriven pump inlet flow low protection because minimum floe valve can not opentimely.

6.9.10.2 Two steam driven pumps

1) Confirm that the second small turbine stars and running speed is at boiler control.

2) Regulate steam driven running speed and make its front and rear outlet differentialpressure be lower than 0.06 MPa.

3) Start steam driven outlet motorized valve and open middle tap valve.

4) Confirm that motorized pump and steam driven pump run normally, running speed isat automation and feeding water is at boiler control automation.

5) Regulate steam driven pump running speed, when the third pump outlet pressure isclose, decrease motorized pump running speed and stop motorized pump. Checkand make sure that motorized auxiliary oil pump automatic start and oil pressure isnormal.

6) When two steam driven pumps are running in parallel and at ‘Standby’ andmotorized pump is at standby, if one steam driven pump trips, motorized pumpstarts by interlock or manually, the running steam driven pump should be switchedto be manual regulation mode to ensure stable running speed of small turbine.

6.9.11 Small turbine stop6.9.11.1 Preparation before normal stop

1) Test standby main oil pump, emergency oil pump, turning gear, all of which can worknormally.

2) Make sure that main steam valve, governor valve should actuate freely with noblock.

6.9.11.2 Normal stop

1) When turbine load decreases to 60% of rated load, start motorized pump. Check iffeeding water system is normal, a steam driven pump may be stopped.

2) Release steam driven pump from automation, decrease steam driven pump running

speed and increase motorized pump load; check and make sure that the load thesteam driven pump to be stopped has already been transferred.

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3) Close the motorized valve from middle tap of the steam driven pump to be stoppedto re-heater attemperating water.

4) Close steam driven pump outlet motorized valve, check and make sure thatminimum flow valve is open.

5) When turbine load decreases to be lower than 25% rated value, open all the

drainage valves on small turbine cylinder and steam pipeline and, open pneumaticdrainage valves before LP main steam valve at the same time.

6) CCS will decrease small turbine running speed automatically with the turbine loaddecreasing, when small turbine running speed decreases to minimum value3000r/min of ‘Boiler Automation’ control mode, press ‘Trip’ button on ‘MEHoperation panel’.

7) Check and make sure that small turbine LP main steam valve, valve are closedshortly and corresponding lights are on.

8) When running speed decrease to 0 r/min, turning gear could be put into operationmanually. Turning gear must be operating at least 4 hours until cylinder temperaturedecrease to very low, and then turning gear also has to discontinuous running.

9) If small turbine stops fro a long time, following work should be done:

a. If turbine continues to run with load less than 50% rated load, boiler should besupplied with water through motorized valve; vacuum butterfly valve on smallturbine steam exhaustion should be closed to avoid breaking vacuum of thecondenser.

b. Stop supply to steam seal after vacuum is released.

10) Keep lube oil circulating for more than 4 hours after unit stopped in order to avoidheat can be transmitted from cylinder to bearing along rotor.

6.9.11.3 Emergency stop

1) Unit vibrates acutely with vibration amplitude that is higher than stop value, butprotection device does not act, or unit vibrates more acutely.

2) There is clear metal friction sound and clash inside turbine.

3) There is water impact in water.

4) Bearing temperature rises acutely to 113 or any bearing returning oil temperatureincreases to 75 .℃

5) Gland sealing or oil ring abrade seriously and sparkles.

6) Bearing lubricate oil is low to 0.059MPa, start standby oil pump but it is invalid.

7) Oil tank level is low to unit stop value, supplement oil but it is invalid.

8) Oil system is on fire and can not be put out.

9) Axial displacement exceeds ±0.25mm, and axial displacement protection devicedoes not act.

10) Turbine running speed rises to trip running value but unit is not in shut off.

6.9.12 Small turbine normal operation and maintenance

6.9.12.1 There is no impurities and leakages such steam, oil or water.

6.9.12.2 Oil tank oil level normal, if oil level is lower than 550mm, oil should be supplemented intimed.

6.9.12.3 Bearing returning oil temperature normally ＜60 and alarms at and above 65℃ .℃

6.9.12.4 Control oil pressure, lubricate oil pressure and oil temperature are normal.

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6.9.12.5 Measure the vibration of bearing and proper every day, vibration value should notexceed 0.08mm.

6.9.12.6 Check oil tank smoke discharging air fan and make sure it runs normally, keep smallturbine oil tank vacuum at 1KPa.

6.9.12.7 Check feeding water pump lubricate oil strainer differential pressure, differential

pressure should lower than 0.09MPa.

6.9.12.8 Check and make sure feeding water pump turbine lubricate oil cooling water pressureis normal at 0.3MPa.

6.9.13 Small turbine oil cooler switching

6.9.13.1 Confirm running or standby status of the two oil coolers.

6.9.13.2 Check and make sure standby oil cooler is in fine condition.

6.9.13.3 Slightly open standby oil cooler oil filling valve and standby oil cooler outlet highposition air discharging valve to fill oil and discharge air. When oil continuously emitfrom air discharging point, close the air discharging valve.

6.9.13.4 Fully open oil filling valve of oil cooler and rise the pressure of oil cooler to checkleakage.

6.9.13.5 Start standby oil cooler cooling water inlet & outlet water valve.

6.9.13.6 Turn oil cooler and switch handle slightly to watch working condition of standby oilcooler.

6.9.13.7 Continue to turn switching handle slowly. Stay for a moment to watch after slightturning and put standby oil cooler into operation gradually until switch it to the runningposition of former running oil cooler, pay attention to oil temperature changes.

6.9.13.8 Close oil filling valve of oil cooler and close inlet & outlet water valve of former runningoil cooler. Switch it into standby.

6.9.14 Small turb ine oil strainer switching

6.9.14.1 Open standby strainer oil filling valve slowly.

6.9.14.2 Open air discharging valve at top of standby strainer slowly.

6.9.14.3 After oil filling and air discharging for standby strainer, close air discharging valve attop of standby strainer and standby strainer oil filling valve.

6.9.14.4 Turn strainer switching handle slowly and switch the strainer to former standby strainerfor operation.

6.10 Heaters start and stop

6.10.1 Operation principles of heaters start and stop

6.10.1.1 When putting heaters into operation, water side should be put into operation firstly andthen steam side; during stop, stop steam side and then stop water side. LP heatershould be put into operation at water side when filling water to condensing watersystem or put into operation after condensing water system work normally.

6.10.1.2 Air-side of heater adopt stochastic sliding start and stop in principle, but when thiscondition is not allowed it should be start from LP to HP, and stop from HP to LP.

6.10.1.3 Heaters with serious leakage are not allowed to be put into operation.

6.10.1.4 Heaters are allowed to be put into operation when water level indicators are complete,alarm signal and protection device are working normally.

6.10.1.5 Temperature changing rate of heater outlet water should be controlled critically during

start and stop heaters.

6.10.1.6 During heaters start and stop, when heater drainage water flows stage by stage and

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6.10.2 Check before putting heaters into operation

6.10.2.1 Make sure that heaters and pipelines are flushed and relevant tests and calibrationsare qualified and, all protections for heaters are working.

6.10.2.2 Make sure that all meters working well.

6.10.2.3 Make sure that control air sources of all pneumatic valves are working normally.

6.10.2.4 Make sure that all drainage valves actuate normally and their automatic control hasbeen put into operation.

6.10.2.5 Open the quick-close valves of all instrumental meters.

6.10.2.6 Make sure that heaters are charged with nitrogen and moisture protection system areisolated.

6.10.2.7 Make sure that all water discharging valves are closed.

6.10.2.8 Slightly open primary and secondary valves from LP continuous air discharging to

condenser.

6.10.2.9 Make sure that primary and secondary valves from HP heater continuous airdischarging to deaerator are closed.

6.10.2.10 Make sure that HP heater start air discharging valve si open.

6.10.2.11 Make sure that check valve of normal drainage water valve of heater is open andisolation valves before and after emergency drainage valves are open.

6.10.2.12 Make sure that steam extraction check valve is closed and drainage valves beforeand after steam extraction check valve are open.

6.10.3 Put LP heaters into operation during operation

6.10.3.1 Put LP heater water side into operation and close air discharging valve when airdischarging valve in water chamber see water. Make sure that LP heater inlet 7 outletwater valves are normally open and bypass valve at water side is closed. Check andmake sure that LP heater steam side water level indicator has no water level andcondensing water flow does not change.

6.10.3.2 Open valve from heater drainage water to condenser, open steam extraction checkvalve of LP heater in operation, slightly open steam extraction motorized valve of LPheater in operation. Make sure that LP heater outlet water temperature changing rate≯1.5 /min.℃

6.10.3.3 Fully open LP heater steam extraction motorized valve gradually, open continuous airdischarging valve and close water discharging valve from heater to condenser

gradually. Make sure that condenser vacuum change and drainage valve actions arenormal.

6.10.3.4 Check and make sure that drainage valves before and after steam extractionmotorized isolation valve are closed.

6.10.4 Put HP heaters into operation during operation

6.10.4.1 Open small bypass valve of heater inlet valve to fill water to HP heater. Close airdischarging valve when air discharging valve at water side sees water. When HPheater pressure reaches to bypass pipeline pressure, open HP heater outlet valve,close HP heater outlet valve and open inlet motorized three-way valve. Put HP heaterwater side into operation.

6.10.4.2 Open valve from heater drainage water to condenser, open steam extraction check

valve of HP heater in operation, slightly open steam extraction motorized valve of HPheater in operation. Heater heats pipes. HP heater outlet temperature changing is

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6.10.4.3 Open HP starting air discharging valve.

6.10.4.4 Close water drainage valve from heater to condenser gradually, fully open steamextraction motorized valve of HPP heater in operation gradually. Make sure thatdrainage valve from drainage water to deaerator act normally.

6.10.4.5 Close starting air discharging valve and open continuous air discharging valve.

6.10.4.6 Check and make sure that drainage water valve in steam extraction pipe are closedand HP heater water level is within normal range.

6.10.5 HP heater operat ion and maintenance

6.10.5.1 Lighting for local water level indicator is normal; water level is clear and normal.Compare the indications on local meters and in control room; drainage valve actshould be normal.

6.10.5.2 Heater insulation is good and there is no vibration, steam water impact and steamwater pipe has no leakage.

6.10.5.3 Check and make sure that all the pressures and temperatures of heater are normalwith the unit load changing.

6.10.5.4 Check and make sure that heater drainage water temperature difference is normal at

about 5～6 .℃

6.10.5.5 During normal operation, drainage water of heater should floe automatically stage bystage. During low load period, neighboring heater pressure changing should bechecked to avoid reversal steam. At the same time, heater water level can becontrolled by emergency drainage water valve, but condenser vacuum change shouldbe paid attention.

6.10.6 Stop HP heater in unit operation6.10.6.1 Contact shift manager to decrease unit load properly, make sure that pressure of each

supervision section is less than limit.6.10.6.2 Switch normal drainage valve of HP heater to manual control then close, check accident

drainage valve of HP heater open gradually, water level in air-side of HP heater is normal.6.10.6.3 Close continuous exhaust manual valve from HP heater to deaerator.

6.10.6.4 Slowly close air extracting motorized valve of #1、#2、#3 HP heater from HP to LP in

sequence until fully closed, pay attention to control water temperature changing rate ofHP heater outlet, HP heater has no vibration.

6.10.6.5 When air extracting motorized valve of HP heater is fully closed, check steam extractingcheck valve of HP heater close automatically.

6.10.6.6 Check front & back drainage steam-drive valve of extracting motorized valve of HPheater open automatically.

6.10.6.7 Open accident drainage valve of HP heater, make pressure of HP heater air-side to 0.

6.10.6.8 Check turbine shaft position, metal temperature and vibration and expending differenceof thrust bearing is normal.

6.10.6.9 Close HP heater inlet motorized three-way valve until it is fully closed, close HP heateroutlet motorized valve. HP heater water side goes through bypass.

6.10.6.10 Open steam extracting valve and drainage valve of HP heater water-side to decreasepressure and drain water according to requirement, it should be avoid steam ejectinghurt people or influence equipment operate normally.

6.10.7 HP emergency stop condition

6.10.7.1 Heater steam water pipe and valve break, which threatens personal and equipmentsafety.

6.10.7.2 HP heater water level rises and is full.

6.10.7.3 All water level indications are in failure and water level can not be supervised.

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6.10.7.4 HP emergency drainage water acts frequently, which makes water supplementdifficult.

6.10.8 HP heater emergency stop

6.10.8.1 Close HP steam inlet motorized valve and steam extraction check valve immediately,open steam extraction pipe drainage water pneumatic valves.

6.10.8.2 HP heater water side steps out of system, feeding water goes through bypass.

6.10.8.3 Close valve from drainage water to deaerator.

6.10.8.4 When HP heater water level is too high and protector acts, the reason should be foundimmediately. HP heater is strictly prohibited to put into operation when there is leakage.

6.10.8.5 When HP steam side and water step out of system at the same time, feeding waterpressure and floe should be strictly supervised to avoid feeding water intermitting.

6.10.8.6 When unit runs without HP heater, pressure at all sections should be within limit. Loadcan be limited if it is necessary.

6.11 Turbine gland sealing start and stop

6.11.1 Check before starting gland sealing system

6.11.1.1 Make sure that unit is in turning gear running state; circulating water, condensing waterand auxiliary steam system are working normally.

6.11.1.2 Feed water and discharge air for gland sealing heater and switch returning water tocondenser.

6.11.1.3 Put gland sealing steam heater water side into operation.

6.11.2 Gland sealing system start

6.11.2.1 Check and make sure that drainage valves of auxiliary steam supplying steam pipesare open.

6.11.2.2 Check and make sure that auxiliary steam supplying pressure and temperature arenormal.

6.11.2.3 Gland sealing steam pressure set values:

1) Auxiliary steam supplying pressure regulation valve set value is 0.024MPa.

2) Re-heater steam supplying pressure regulation valve set value is 0.028MPa.

3) Gland sealing overflow valve set value is 0.031MPa.

6.11.2.4 Gland sealing steam temperature set values:

1) LP gland sealing steam temperature set value is 150 .℃

2) Small turbine gland sealing steam temperature set value is 150 .℃

6.11.2.5 Steam source using principles:

1) When starting in cold state, auxiliary steam is used. When starting in hot state, glandsealing air source is from re-heater; if auxiliary steam is used, its temperatureshould reach 310 .℃

2) After unit runs with load and when steam supplying pressure and temperature ofre-heater meet requirement, steam source should be switched to be supplied byre-heater.

3) When unit trips, rejects load and re-heater pressure is low, put auxiliary steam intooperation.

6.11.2.6 Slightly open auxiliary supplying steam bypass motorized valve to heat pipes.

6.11.2.7 Open drainage water manual valves of turbine proper and small turbine gland sealing

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6.11.2.8 Set pressure value and temperature value; regulation valve puts into operationautomatically.

6.11.2.9 Open manual valves before and after auxiliary steam source regulation valve, close

bypass valve and check that regulation valve works normally.

6.11.2.10 After gland sealing pressure is stable, start gland sealing air fan. Check and makesure that air fan vibration, sound, gland sealing vacuum and inlet & outlettemperature rise are normal.

6.11.2.11 Check and make sure that there is no steam leakage at steam sealing of all parts ofturbine; otherwise check the working condition of gland sealing pressure regulationstation and regulate it to be normal. Close drainage water valve in gland sealingsystem.

6.11.3 Gland sealing system stop

6.11.3.1 Close drainage water to condenser.

6.11.3.2 Stop vacuum pump and open vacuum breaking valve.

6.11.3.3 When condenser vacuum reaches to zero (0), close motorized valve before regulationvalve from re-heater to gland sealing. Isolation valves from auxiliary to gland sealingand from re-heater to gland sealing are fully closed. Make sure that isolation valve ofgland sealing attemperating water is strictly closed.

6.11.3.4 Release standby gland sealing air fan from ‘Standby’ on CRT, stop gland sealing airfan.

6.11.3.5 Open all drainage valve, water discharging valves in gland sealing system, systemreleases pressure.

6.11.4 Gland sealing system operation and maintenance

6.11.4.1 Supervision during normal operation

1) Gland sealing steam head pipe pressure 24～28KPa.

2) LP gland sealing steam supplying pressure and temperature.

3) Gland sealing steam supplying pressure and temperature of small turbine A, B.

4) Gland sealing heater drainage water level.

5) Gland sealing heater steam side negative pressure.

6) Gland sealing air fan operation condition.

6.11.4.2 Operation limits for gland sealing system

1) Gland sealing supplying steam should be with over temperature surplus of no lessthan 14 .℃

2) Gland sealing should be put into operation before running turning gear to avoid rotorbending.

3) LP gland sealing supplying steam temperature is 121-177 with control set value of℃

150 .℃

4) During start and stop, temperature difference between gland sealing steam androtor surface should be decreased as much as possible to avoid heat stress atgland sealing that may damage rotor.

5) If start the unit in hot state, auxiliary steam supplying gland sealing should be

adopted; steam temperature should be paid attention to, the temperature differencebetween gland sealing steam and rotor surface metal should nor exceed maximum

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permit value 85℃.

6.12 Vacuum system stop

6.12.1 Preparation before starting vacuum system

6.12.1.1 Completely check vacuum pump and vacuum system and confirm that all conditions

for starting are satisfied.6.12.1.2 Send power to vacuum pump.

6.12.1.3 Check and make sure that all the air discharging valves, water discharging vales areclosed and relevant meters are working.

6.12.1.4 Make sure that manual isolation valves from condenser too vacuum pumps inlets areopen.

6.12.1.5 Check and make sure that vacuum pump inlet valve is closed.

6.12.1.6 Make sure that condensing water system and closed circulating cooling water systemare working normally.

6.12.1.7 Open the manual isolation valves from condensing water to vacuum pump steamwater separator to fill water to separator; make sure that automatic water supplement

valve acts normally, supply water to steam water air discharging about 1/2～2/3 of

location water level meter.

6.12.1.8 Put vacuum pump cooler cooling water into operation.

6.12.1.9 Close condenser vacuum breaking valve.

6.12.1.10 Open vacuum breaking valve sealing water general valve regulate all the branchvalves and keep a certain sealing water level without overflowing.

6.12.1.11 Start the three vacuum pumps at the same time when initially establishing vacuum;when maintaining vacuum, two pump run and one is in standby.

6.12.2 Vacuum start6.12.2.1 Start the first vacuum pump, when vacuum pump inlet front and rear differential

pressure reaches to -4.5KPa, vacuum pump inlet pneumatic valve starts automatically.

6.12.2.2 Make sure that vacuum pump inlet vacuum indication and steam water air dischargingis normal.

6.12.2.3 Start the other 2 vacuum pump by sequence.

6.12.3 Vacuum pump operation and maintenance

6.12.3.1 Check and make sure that pump vibration is normal, no friction, no noise and motorcurrent is normal.

6.12.3.2 Check leakage of pump stuffing box.

6.12.3.3 Check and make sure that vacuum pump steam water separator water level, workingwater temperature is normal.

6.12.3.4 Check and make sure that condenser vacuum breaking valve sealing water level isnormal.

6.12.3.5 Check and make sure that vacuum cooler works normally

6.12.4 Vacuum pump stop

6.12.4.1 Release standby vacuum pump from ‘Standby’ and stop the running vacuum pump.

6.12.4.2 Make sure that vacuum pump inlet valve is closed.

6.12.4.3 If pump is in fault or maintenance, pump should be isolated for work.

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6.12.5 Vacuum pump switching

6.12.5.1 Check the standby vacuum pump completely and make sure that it is with startingconditions.

6.12.5.2 Release standby vacuum pump from ‘Standby’.

6.12.5.3 Start standby vacuum pump, check and make sure that its current, vibration and soundare normal. CRT status indications are right.

6.12.5.4 Check and make sure that after starting standby pump, when front and rear differentialpressure reaches to -4.5KPa, inlet valve starts automatically by interlock; otherwisecontact with I&C for treatment.

6.12.5.5 After complete check, stop one former running vacuum pump. Check and make surethat CRT indications are right and all valves are closed locally.

6.12.5.6 Check and make sure that condenser vacuum is normal, put the vacuum stopped into‘Standby’ according to requirement.

6.13 Turbine lubr icate oil system start and stop

6.13.1 Conditions for system start

6.13.1.1 All equipments interlock protection tests are completed and qualified.

6.13.1.2 Main oil tank is filled with suitable amount qualified oil (oil level should ≥500mm).

6.13.1.3 All oil & water discharging valves are closed.

6.13.1.4 Relevant oil coolers are working.

6.13.2 Equipment trial run and system leakage check

6.13.2.1 Start smoke discharging air fan of main oil tank, check and make sure that vibrationand sound are normal.

6.13.2.2 Check and make sure that lubricate oil temperature is normal and sealing oil check is

completed.

6.13.2.3 Close isolation valve from lubricate oil and HV standby oil to sealing oil, start AClubricate oil pump. Check and make sure that vibration, sound and pressure arenormal.

6.13.2.4 Check and make sure there is no oil leakage in lubricate oil system.

6.13.2.5 Stop AC lubricate oil pump, start DC emergency oil pump and hydrogen sealing oilpump. Check and make sure that vibration, sound and pressure are normal. Start DCemergency oil pump. Start hydrogen sealing oil pump for standby.

6.13.2.6 Check and make sure that all indications on pressure meters and thermometers areright.

6.13.2.7 Test oil cooler switching; make sure that oil pressure does not fluctuate duringswitching.

6.13.2.8 Start all jacking oil pumps in sequence; check and make sure that the vibration, sound,outlet pressure and all jacking oil pressures are normal.

6.13.2.9 Check and make sure there is no oil leakage in jacking oil devices.

6.13.2.10 Stop jacking oil pump.

6.13.2.11 Stop smoke discharging air fan of main oil tank.

6.13.3 Lubr icate oil system start

6.13.3.1 It should be ensured that all checks are completed before starting lube oil system.

6.13.3.2 Start smoke discharging air fan of main oil tank.

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6.13.3.3 Start AC lube oil pump and hydrogen sealing oil pump. Check and make sure that allthe indications of pressure meters are right.

6.13.3.4 Put DC lubricate oil pump interlock switch into operation.

6.13.3.5 Check valve installed at oil injector outlet should be regulated by maintenance personfor first start system and system after major maintenance. After regulation, fix it by

locking the handle.

6.13.3.6 Check oil flow in bearing returning oil watch hole is normal.

6.13.3.7 Check and make sure bearing lubricate oil temperature is normal. If oil temperature istoo low, put oil heater of main oil tank into operation.

6.13.4 Lubr icate oil system stop

6.13.4.1 Turning gear should continue to run until highest temperature point of turbine cylinderis lower than 150 ; turbine lubricate oil system only can be stopped when cylinder℃ highest temperature point is lower than 120 and sealing oil system is working℃ normally.

6.13.4.2 After turbine turning gear stops, release turbine DC oil pump from interlock and stop

jacking oil pump according to cylinder temperature. Pay attention to oil level rise ofmain oil tank, when oil level is too high, it should overflow into oil storage tank out ofturbine hall.

6.13.4.3 Close cooling water inlet & outlet valves of oil cooler.

6.13.4.4 Stop turbine lubricate oil purifying device if it is necessary.

6.13.4.5 Two hours after stopping lubricate oil system and sealing oil system, smokedischarging air fan of main oil tank can be stopped.

6.13.5 Turbine turning gear regulations

6.13.5.1 Turning gear must be put into operation four hours before starting turbine; duringcontinuous turning gear, if main bearing stops due to turning gear fault or necessary forwork, turbine can only be started after four (4) hours continuous running of turninggear.

6.13.5.2 During turning gear running, lubricate oil, jacking oil and sealing oil must be ensurednot to intermit and be with sufficient pressure and rotor eccentricity does not exceed0.075mm.

6.13.5.3 After turbine stops, turning gear and lubricate oil should run continuously for at least 48hours until rotor is cooled to be lower than 150 . All the relevant parameters of turbine℃ should be supervised.

6.13.5.4 When cylinder first stage metal temperature is lower than 150 , turning gear can be℃ stopped; after turning gear stops, lubricate oil system should continuously run.

6.13.5.5 If jacking oil pump can not be put into operation, turning gear must be continuouslyturned. If ‘Block-skid’ happens to turning gear, following measures should be doneuntil jacking oil pump recovers to normal operation:

a. Start DC emergency oil pump to increase lubricate oil amount and decrease oiltemperature as much as possible but no less than 27 .℃

b. Wait for one minute, if ‘Block-skid’ still exists, stop the turning gear for 15min andthen start it again.

c. If ‘Block-skid’ still exists, stop the turning gear and turn rotor for 180° every 10min.Repeat the above method until ‘Block-skid’ disappears and turning gear runsnormally.

6.13.5.6 During unit stop and turning gear period, maintenance related to turbine proper isprohibited to avoid cold steam and cold water entering into turbine. Pay attention tosupervise cylinder metal changing trend, temperature difference of up and down

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cylinder, temperature difference of main & reheating steam pipes, up 7 downtemperature difference of steam extraction pipes, vessel water levels, pressures andtemperatures. If up and down temperature difference increase acutely, reason shouldbe found out immediately and cut off the water, steam sources.

6.13.5.7 During continuous turning gear, turning gear stop due to work necessity or turning gear

fault should be approved by chief engineer and following principles should be obeyed:a. If turning gear needs to be stopped due to turning gear fault or other necessity, after

turning gear stops, corresponding position should be marked on rotor and stop timeshould be remembered.

b. After turning gear stops, turn the rotor for 180° before recover continuous running.Pay attention to rotor eccentricity and there should no over current or current swing.

6.13.5.8 During continuous running of turning gear and under special condition, jacking oildevice may be stopped, but turning gear current must be supervised; when its increasedoes exceed 120% of normal value, jacking device can be stopped and continue to runturning gear.

6.13.5.9 During continuous turning gear, if there is obvious metal friction sound in cylinder

and turning gear current swing (it is not turning gear device fault), turning gearshould be stopped immediately and manual turning according to above statuteshould be done until it recovers.

6.14 Turbine oil cooler start and stop

6.14.1 Oil cooler standby

6.14.1.1 During operation, standby oil cooler should be fulfilled with oil; oil cooler aftermaintenance only can be in standby after filling oil. Inlet and outlet oil valves are openand cooling water is stopped.

6.14.1.2 Check and make sure that oil level in main oil tank is above 0; otherwise oil should besupplemented to main oil tank.

6.14.1.3 When one oil cooler is running and the other is filled with oil after maintenance, oilfilling valve of oil cooler should be slightly open. Supervise the changing of lubricate oilpressure and close oil filling valve after air at oil side in oil cooler is completelydischarged.

6.14.2 Put water side of oil cooler into operation

6.14.2.1 Close oil cooler bottom water side discharging valve, close outlet valve of oil cooler.

6.14.2.2 Open oil cooler water side air discharging valve.

6.14.2.3 Make sure that isolation valves before and after oil cooler cooling water regulationvalve are open and its bypass valve is closed.

6.14.2.4 Slightly open oil cooler inlet water valve, fill water and discharge air for oil cooler. Closeair discharging valve when water is seen.

6.14.2.5 Open outlet valve of oil cooler.

6.14.2.6 Confirm that control air source of oil cooler cooling water regulation valve is workingand regulation is normal.

6.14.3 Oil cooler switching

6.14.3.1 When switching oil coolers during operation, main oil tank oil level, lubricate oilpressure and temperature should be paid attention to.

6.14.3.2 Confirm the running states of oil cooler A, B.

6.14.3.3 After standby oil cooler is fulfilled with oil, put standby oil cooler cooling water intooperation.

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6.14.3.4 Turn the handwheel of switching valve. After turning 90°, indication screw onhandwheel point middle, oil coolers run in parallel.

6.14.3.5 Continue to turn handwheel 90° to standby oil cooler direction, check and make sureindication screw on handwheel points to standby oil cooler, i.e. standby pump isswitched for running. Pay attention to cooling water regulation valve action and make

sure oil cooler outlet oil temperature is within 43～49 and lubricate oil pressure is℃

normal.

6.14.3.6 After normal switching, former running oil cooler cooling water and former running oilcooler switches into standby state.

6.14.4 Oil cooler stop

6.14.4.1 Check and confirm oil cooler A, B running state.

6.14.4.2 Switch the switching valve of oil cooler to the position of another oil cooler running, cutoff the oil line of oil cooler to be stopped.

6.14.4.3 If maintenance is necessary after stop for oil cooler, open the bottom oil dischargingvalve and air discharging valve at oil side to completely discharge oil from oil cooler.

6.14.4.4 Close inlet & outlet water valve of oil cooler, open oil cooler button water dischargingvalve and air discharging valve at water side to discharge water.

6.15 EH oil system start and stop

6.15.1 Check before EH oil system

6.15.1.1 Confirm that EH oil tank level is slightly higher than normal oil level and oil is qualified.

6.15.1.2 Confirm that all tests in EH oil system are qualified and all interlock protections areworking.

6.15.1.3 Open primary and secondary valves of all pressure switches, close all oil & waterdischarging valve.

6.15.1.4 Control power is working and signal is normal.

6.15.1.5 Start isolation valve and put one EH oil cooler into operation.

6.15.1.6 Confirm that closed cooling water system is working and air is completely discharged.

6.15.2 System leakage check

6.15.2.1 EH oil pump, cooling oil pump and filtering pump motor are sent with power.

6.15.2.2 Start cooling oil pump with following operation process:

1) Open cooling oil pump oil inlet valve.

2) Open oil cooler inlet valve.

3) Start cooling oil pump and make sure that there is no vibration and sound.4) Check and make sure that cooling oil pump pipeline system has no oil leakages.

5) Stop cooling oil water, if oil temperature inside oil tank is lower than 37 , heating℃

pump should be stopped.

6.15.2.3 Start and stop fire resistant oil regeneration pump

1) Start regenerating pump inlet oil valve.

2) Start diatomite filter bypass valve.

3) Start regenerating pump, check and make sure that vibration and sound are normal.

4) Open diatomite strainer inlet oil valve slowly.

5) Close diatomite strainer bypass valve gradually.

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6) Make sure that diatomite strainer differential pressure is normal and lower than0.24MPa.

7) Confirm that fire resistant oil regenerating system has no oil leakage and noabnormity.

8) Stop fire resistant oil regeneration pump.

6.15.2.4 Start and stop EH oil pump

1) Confirm that oil tank oil temperature is within 21℃～37 .℃

2) Start EH oil pump inlet oil valve, fill oil and discharge air for EH oil pump.

3) Confirm that following valves are fully open:

a. EH oil pump outlet valve.

b. Manual valve on head pipe supplying EH oil to turbine.

4) Start EH oil pump A or B, check and make sure that vibration, sound and pressureare normal and there is no oil leakage.

5) Check whether oil tank oil level is normal; otherwise supplement oil.

6) Check whether EH oil pipeline system has oil leakage or not.

7) Stop EH oil pump.

8) Start and stop the other EH oil pump with same operation processes.

6.15.3 Check for nitrogen accumulator

6.15.3.1 Make sure that inlet valves are fully closed and oil drainage valves are fully open.

6.15.3.2 Check and make sure that nitrogen has been charged to set pressure; if pressure islower than set value, nitrogen should be charged continuously.

6.15.3.3 After check, close oil drainage valve and open inlet valve of accumulator.

6.15.4 EH oil system start and stop

6.15.4.1 Make sure that closed cooling circulating is working.

6.15.4.2 Make sure that cooling pump is at ‘Automation’ position, if EH oil temperature is lowerthan 21 , heater starts automatically.℃

6.15.4.3 Start one EH oil pump and put the other pump into ‘Standby’ from CRT after completecheck.

6.15.4.4 Check and make sure that all indications of pressure meters in EH oil system devicepanel normal.

6.15.5 EH oil system stop

6.15.5.1 Except for that there is work in EH oil system, otherwise the system should not bestopped.

6.15.5.2 Release standby EH oil pump on CRT from ‘Standby’ and stop EH oil pump.

6.15.5.3 Close oil cooler cooling water inlet valve.

6.15.6 EH oil pump switching

6.15.6.1 Check and make sure that system is running stably and standby pump is in finecondition.

6.15.6.2 Start standby pump, check and make sure that everything is normal.

6.15.6.3 Stop former running pump, confirm that the pump is stopped and output head pipe

pressure is normal.

6.15.6.4 Stop EH oil pump on ‘CRT’ and put it into ‘Standby’.

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6.15.6.5 Check and make sure that EH oil system runs normally.

6.15.7 Oil system operation and maintenance

6.15.7.1 Lighting around the equipment is sufficient, oil tank level is normal and all indications ofpressure meters are right.

6.15.7.2 EH oil system has no oil leakage.6.15.7.3 Oil tank temperature is normal.

6.15.7.4 Oil pump and system pipeline vibrate and sound is abnormal.

6.16 Generator sealing oil system start and stop

6.16.1 Check before starting generator sealing oil system

6.16.1.1 All control power, signal power are in operation, all instrumental meters are completeand in operation.

6.16.1.2 Measure insulation for motors and send power after mechanical parts are ready.

6.16.1.3 Put closed circulating cooling water system into operation.

6.16.1.4 All the valves of pressure meters, differential pressure meters and regulators are open,isolation valve for detecting oil level is open and all strainers rotate freely.

6.16.1.5 Inlet valve of sealing oil pump at hydrogen side is open.

6.16.1.6 Outlet re-circulating valve of sealing oil pump at air side and hydrogen side areproperly open (fix it after regulation).

6.16.1.7 Inlet valves, outlet cooling water valves of oil coolers at air side and hydrogen side tobe put into operation are open; standby cooler inlet valve is closed, outlet valve isopen and outlet strainer at air side is open.

6.16.1.8 Inlet valves of sealing oil strainer at air side and hydrogen side are open and bypassvalve is closed.

6.16.1.9 Manual valve after sealing oil #1 pressure balance valve at hydrogen side is closed;sealing oil pressure meter valves at air side and hydrogen side are closed.

6.16.1.10 Manual valve after sealing oil #2 pressure balance valve at hydrogen side is closed;sealing oil pressure meter valves at air side and hydrogen side are closed.

6.16.1.11 Exit the manual screw of oil level regulation bobber valve of returning oil tank athydrogen side and make the two ball cocks be at free status.

6.16.1.12 Close pressure meter oil discharging valve at hydrogen side of main differentialpressure regulator.

6.16.1.13 Close pressure meter oil discharging valve at hydrogen side of standby differentialpressure regulator.

6.16.1.14 Open inlet valve of sealing oil pump at air side.

6.16.1.15 Open outlet head pipe manual valve of sealing oil pump at air side.

6.16.1.16 Oil returning check valve from hydrogen side to air side and oil discharging valvefrom hydrogen-oil separating tank to sealing oil tank are at automatic regulation state.Oil supplement valve of oil tank at hydrogen side is properly open and forcing oildischarging valve at hydrogen side is closed.

6.16.1.17 Following valves should be regulated according to regulations before sealing oilsystem works normally:

1) Pressure balancing valve at two ends of sealing oil at hydrogen side.

2) Air side sealing oil main differential pressure regulation valve and standbydifferential pressure regulation valve.

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3) Oil supplying depressurized valve of turbine main oil pump and safety valve afterthe valve.

4) Outlet re-circulating valve of sealing oil pump at air side.

5) Outlet re-circulating valve of sealing oil pump at hydrogen side.

6.16.2 Regulations of sealing oil system operation6.16.2.1 Sealing oil system should be put into operation before turning gearing running and

generator gas displacement.

6.16.2.2 When generator is charged with hydrogen or rotor is running, sealing oil pressure mustbe maintained.

6.16.2.3 When generator is charged with hydrogen, smoke remove machine of hydrogen-oilseparating tank at air side should run continuously.

6.16.2.4 Turbine lubricate oil system should be put into operation before starting sealing oilsystem.

6.16.2.5 Before discharging oil from main lubricate oil tank, hydrogen inside generator must be

completely discharged firstly.6.16.3 System start

6.16.3.1 Make sure that start conditions of sealing oil pump at air side are satisfied, start sealingoil pump at air side and make sure it runs well.

6.16.3.2 Regulate re-circulating valve of pump outlet and keep oil pressure after oil filter be at

0.8MPa and oil temperature be within 27～50 .℃

6.16.3.3 Oil smoke removing machine should starts automatically by interlock, put standby oilsmoke removing machine into interlock.

6.16.3.4 Open balancing valve at hydrogen side and oil side of pressure regulator, putdifferential pressure valve into operation. If differential pressure valve is in failure, use

pump outlet re-circulating valve to keep normal oil pressure for operation.

6.16.3.5 Supplement oil to returning oil tank at hydrogen side to normal level.

6.16.3.6 Open sealing oil supplying valve at air & hydrogen sides of balancing valve at twosides of sealing oil and put balancing valve into operation.

6.16.3.7 Put AC sealing oil pump at hydrogen side into operation, use pump outlet re-circulatingvalve to keep oil pressure after oil filter at 0.8MPa; make sure that sealing oil

differential pressure at air side and hydrogen side should not exceed 0.5KPa.

6.16.3.8 Have sealing oil system protection test and oil pump interlock test according toregulations.

6.16.3.9 If during putting balancing valve and pressure differential regulator into operation,

required oil pressure can not be ensured, bypass valve should be used to keep oilpressure, put them into operation after finding out the reason.

6.16.4 System operation and maintenance

6.16.4.1 Normal supervision during operation

1) Hydrogen pressure should be kept at 0.4MPa during unit normal operation.

2) Keep hydrogen-oil differential pressure within 0.084±0.01MPa.

3) Sealing oil supplying differential pressure at hydrogen side and air should be within

0.5KPa.

4) Sealing oil cooler outlet oil temperature should be kept within 27～49 .℃

5) Air side sealing oil returning oil temperature ≤56 .℃

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6) Hydrogen side sealing oil returning oil temperature ≤64 .℃

7) Oil pump and motor bearing oil level, temperature and vibration.

8) Oil tank level at hydrogen side and air side.

9) Air side returning oil tank vacuum should be kept within -250～-500Pa.

10) Turbine main oil source supplying pressure.

11) Oil smoke removing machine runs well.

6.16.4.2. Oil system operation1) Air-side seal oil system operationa Main operating oil source: the normal working oil source of the air-side seal oil is

supplied by the AC electric seal oil pump. The outlet pressure of seal oil pump is0.25- 0.8 MPa. Oil-supply of the shaft seal ring uses the by-pass differential pressureregulator to adjust the difference of hydrogen and seal oil. The differential pressureregulator adjusts the air-side oil pressure automatically according to the hydrogenpressure in the generator to ensure that the normal operation of the shaft seal ringand the difference of hydrogen and seal oil is 0.084MPa.

b The first spare oil source (that is the main spare oil source) is the 1.6～1.7MPahydraulic oil from the main oil pump of the steam turbine. This spare oil is suppliedfor the air-side shaft seal ring after pressure is reduced through the pressure-reliefvalve on the pipeline. The outlet oil pressure at the pressure-relief valve is0.7~0.8MPa. And the oil mass is 250L/min. when the operating oil source is out oforder and the difference of hydrogen and seal oil reduces to 0. 056MPa, the sparedifferential pressure regulator installed in the pipe will open automatically and thespare oil source will be also in operation automatically.

c The second spare oil source is also supplied by the steam turbine oil system, that is,the spare AC electric seal oil pump in the main oil tank of the steam turbine. The oilpressure is 1.0MPa. Since it is in the same pipeline as the first one, this spare oilsource enters the shaft seal ring through the spare differential pressure regulator

and is put into operation when the differential pressure reduces to 0.056MPa. Whenthe coaxial rotational speed of the steam turbine exceeds 2/3 of the specified speed,the main shaft oil pump of the steam turbine can supply oil with the first oil source;when it is lower than that number or when it is out of order, only the second oilsource can be in operation.

d The third spare oil source is supplied by the self-contained DC electric oil pump inthe seal oil system. The DC electric oil pump and the alternate current electric oilpump are merged in the same pipeline, when differential pressure reduces to0.035MPa, the DC oil pump will start, and hydrogen oil differential pressure willcome back to 0.084MPa. This oil source can only work for about 2 hour, so thealternate current oil pump should be checked and repaired as soon as possible.

e The fourth spare oil source is also supplied by the stream turbine oil system. The oilis supplied by the bearing lubricating oil pump of the stream turbine, and the oil

pressure is relatively low, that is, 0.035～0.105MPa. So at this time the hydrogen

pressure in the turbine should be reduced to 0.014MPa.

2) Hydrogen-side seal oil system operation

Normal working oil source of hydrogen-side seal oil is supplied by AC seal oil pump,

when AC seal oil pump has fault, DC seal oil pump will supply seal oil to it.

6.16.5 System stop

6.16.5.1 Stop conditions

1) Make sure that gas displacement in generator has already finished, air in generatorhas been exhausted.

2) Turning gear stops. When rotor runs, sealing oil system has to stop; otherwise it willdamage sealing pad.

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6.16.5.2 Stop seal oil system

1) Insolate pressure difference meter of compensation valve in air-side, hydrogen-side.

2) Close HP and LP spare oil source manual valve from lube oil to seal oil.

3) Close front & back manual valve of seal oil standby pressure difference valve.4) Release interlock of hydrogen-side DC seal oil pump, stop AC seal oil pump in

hydrogen-side.5) Release interlock of air-side DC seal oil pump, stop AC seal oil pump in air-side. When

seal oil system stopped, release interlock of oil scavenger tank standby draft fan inair-side, stop draft fan.

6.17 Generator hydrogen cool ing system start and stop

6.17.1 Check before generator gas replacement and notices for replacement

6.17.1.1 Sealing oil system runs reliably and oil-hydrogen differential pressure maintains withinabout 0.084MPa.

6.17.1.2 Gas displacement should be operated when generator is stop, and turning gear speedis lower than 1000r/min.

6.17.1.3 Relevant meters and alarming devices are tested and calibrated to be qualified.

6.17.1.4 All fire works in turbine hall are completed.

6.17.1.5 There is a certain pressure inside generator.

6.17.1.6 Confirm that sealing oil differential pressure regulation valve characteristic test isqualified. Pressure inside generator during gas replacement keeps at about 50KPa.

6.17.1.7 Inform hydrogen generator station to prepare sufficient hydrogen before charginghydrogen; make sure that hydrogen supplying stops before discharging hydrogen.There is sufficient CO2 at site for gas replacement and its purity is qualified.

6.17.1.8 Generator gas tightness test is qualified.

6.17.1.9 Valves in hydrogen system should be opened or closed slowly, operate it manually if itis possible, and copper spanner can be used under special conditions. Duringoperation, hydrogen should be prevented from sudden washing which may cause fire.

6.17.1.10 Check the switches status in system according to H2 system valve check card

（before replacing CO2 by air ）.

6.17.2 Replacing air ins ide generator with CO2

6.17.2.1 Close isolation valve to generator compressed air.

6.17.2.2 Close general valve from hydrogen generating station to hydrogen head pipe.

6.17.2.3 Close hydrogen cylinder supplying general valve.

6.17.2.4 Close check valve before hydrogen pressure regulation valve, check valve afterhydrogen pressure regulation valve and bypass valve of hydrogen pressure regulationvalve.

6.17.2.5 Close hydrogen supplying pipe general valve.

6.17.2.6 Open hydrogen replacement valve.

6.17.2.7 Close CO2 replacement valve.

6.17.2.8 Open CO2 supplying general valve.

6.17.2.9 Open general valve of CO2 supplying pipe of CO2 cylinder.

6.17.2.10 Open and regulate gas replacement general air discharging valve and keep

pressure inside generator be within 40～50KPa. Make sure sealing oil pressure is

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6.17.2.11 When purity inside generator is higher than 90％, clean generator and discharge

with CO2 totally, open liquid leakage detector discharging valve of stator air-side &supervision cabinet inlet discharging valve of generator working condition &supervision cabinet outlet discharging valve of generator working condition &

star-point liquid leakage detector discharging valve & outlet box liquid leakagedetector discharging valve & hydrogen dryer inlet discharging valve & hydrogendryer outlet discharging valve in sequence once time for about 2 minutes.

6.17.2.12 Open valve from hydrogen to hydrogen purity analysis meter. Close it after CO2 purity is qualified.

6.17.2.13 Open valve from hydrogen to hydrogen purity analysis meter. Open hydrogenhumidity meter air inlet manual valve and hydrogen humidity meter discharging airmanual valve.

6.17.2.14 Open hydrogen discharging valve. Close hydrogen humidity meter air inlet manualvalve and hydrogen humidity meter discharging air manual valve after CO2 purity isqualified.

6.17.2.15 Open valve from hydrogen to hydrogen dryer. Close hydrogen valves and hydrogendischarging valve.

6.17.2.16 Close valve from hydrogen to hydrogen humidity meter.

6.17.2.17 When CO2 purity inside generator is higher than 95%, close general valve of CO2 supplying pipe of CO2 cylinder, CO2 supplying general valve, H2 replacement valveand replacement general discharging valve.

6.17.3 CO2 replacement ins ide generator by H2

6.17.3.1 Check and make sure that hydrogen purity analysis meter inlet valve and returningvalve are closed.

6.17.3.2 Cut off power of H2 purity analysis meter and send power when H2 purity insidegenerator reaches to be higher than 90％.

6.17.3.3 Make sure that manual valve from unit compressed air to hydrogen pipe is strictlyclosed.

6.17.3.4 Make sure that CO2 inside generator is higher than 95% and pressure insidegenerator is about 40 KPa.

6.17.3.5 Contact with hydrogen generating station to supply hydrogen.

6.17.3.6 Open general valve from hydrogen generating station to hydrogen head pipe.

6.17.3.7 Open check valve before hydrogen pressure regulation valve and check valve afterhydrogen pressure regulation valve.

6.17.3.8 Open general valve of hydrogen supplying valve.

6.17.3.9 Check and make sure that hydrogen replacement valve is strictly closed.

6.17.3.10 Regulate hydrogen pressure regulation valve to make hydrogen supplying head pipepressure be higher than 50KPa.

6.17.3.11 Open CO2 replacement valve.

6.17.3.12 Open and regulate gas replacement general discharging valve and keep pressure at50KPa inside generator. Make sure that sealing oil differential pressure regulationvalve actuates normally to ensure sealing oil pressure is 84KPa higher than pressureinside generator.

6.17.3.13 When H2 purity inside generator is higher than 90％

, clean generator and dischargewith CO2 totally, open liquid leakage detector discharging valve of stator air-side &supervision cabinet inlet discharging valve of generator working condition &

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6.17.3.14 Open generator discharge valve, close generator discharging valve after H2 purity is

qualified.6.17.3.15 Open valve from hydrogen to hydrogen purity analysis meter after H2 purity is

qualified.


6.17.3.17 Open hydrogen discharging valve. Close discharge valve after H2 purity is qualified.

6.17.3.18 Open valve from hydrogen to hydrogen dryer. Open hydrogen discharge valve.Close hydrogen discharge valve after H2 purity is qualified.

6.17.3.19 When H2 purity inside generator is higher than 98%, close CO2 replacement valve

and gas replacement general discharging valve. Replacement is completed.6.17.4 Hydrogen cooler start

6.17.4.1 Close discharge valve of inlet & outlet pipes of cooler.

6.17.4.2 Open hydrogen cooler water inlet valve slowly, close air discharging valve when coolerair discharging pipe sees water.

6.17.4.3 Open outlet water valve of hydrogen cooler.

6.17.4.4 Open isolation valves before and after hydrogen temperature regulation valve, closebypass valve and put hydrogen cooler temperature regulation valve into ‘Automation’.

6.17.5 Hydrogen cooling system supervision during generator operation

6.17.5.1 When generator is running normally, hydrogen pressure inside generator should keepwithin 0.38～0.42MPa, it alarms when the pressure is higher 0.43MPa than or lower

than 0.385MPa. When hydrogen pressure is too high, air discharging valve can beopened to discharge part hydrogen and decrease pressure to normal value. Whenhydrogen pressure lower than 0.38MPa, contact chemical operator to supply hydrogenwith 0.40MPa.

6.17.5.2 During unit operation, H2 purity inside generator is higher than 96％, O2 purity inside

generator is lower than 1％, H2 humidity inside generator is lower than 29/M3 . if purity

or temperature is unqualified, blow down should be done and hydrogen should besupplemented to generator to improve purity and decrease humidity.

6.17.5.3 During generator normal operation, H2 moisture removal device should be put into

operation.

6.17.5.4 During generator normal operation, hydrogen cooling system should work normallyand sealing oil system must work normally.

6.17.5.5 During generator normal operation, hydrogen coolers should be working. If one of thehydrogen coolers exits, generator load limit is 80% of rated load.

6.17.5.6 During normal operation, it must be ensured that generator inlet hydrogen temperatureis lower than generator stator cooling water inlet temperature. It should be kept that allthe temperatures of four temperature detection points at outlet of hydrogen cooler arelower than generator stator cooling water inlet temperature.

6.17.5.7 When any detection point temperature at hydrogen outlet is higher than the average

value of the other three detection points, maintenance person should be contacted fortreatment.

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6.17.5.8 When temperature of any detection point at generator hydrogen cooler outlet is higherthan generator stator cooling water inlet temperature, hydrogen temperature or statorcooling water temperature should be checked and regulated to be normal. If it is due towrong detection point indication, maintenance person should be contacted fortreatment.

6.17.6 H2 replacement inside generator by CO2 6.17.6.1 Close isolation valve to generator compressed air.

6.17.6.2 Close general valve from hydrogen generating station to hydrogen head pipe.

6.17.6.3 Close hydrogen cylinder general supplying valve.

6.17.6.4 Close check valve before hydrogen pressure regulation valve, check valve afterhydrogen pressure regulation valve and bypass valve of hydrogen pressure regulationvalve.

6.17.6.5 Close hydrogen supplying pipe general valve.

6.17.6.6 Open hydrogen replacement valve.

6.17.6.7 Close CO2 replacement valve.6.17.6.8 Open CO2 supplying general valve.

6.17.6.9 Open general valve of CO2 supplying pipe of CO2 cylinder.

6.17.6.10 Open and regulate gas replacement general air discharging valve and keep

pressure inside generator be within 40～50KPa. Make sure sealing oil pressure is

84KPa higher than pressure inside generator.

6.17.6.11 When CO2 purity inside generator is higher than 90％, clean generator and

discharge with CO2totally, open liquid leakage detector discharging valve of statorair-side & supervision cabinet inlet discharging valve of generator working condition& supervision cabinet outlet discharging valve of generator working condition &

star-point liquid leakage detector discharging valve & outlet box liquid leakagedetector discharging valve & hydrogen dryer inlet discharging valve & hydrogendryer outlet discharging valve in sequence once time for about 2 minutes.

6.17.6.12 Open valve from hydrogen to hydrogen purity analysis meter. Close it after CO2 purity is qualified.


6.17.6.14 Open hydrogen discharging valve. Close hydrogen humidity meter air inlet manualvalve and hydrogen humidity meter discharging air manual valve after CO2 purity isqualified.

6.17.6.15 Open valve from hydrogen to hydrogen dryer. Close hydrogen valves and hydrogendischarging valve.

6.17.6.16 Close valve from hydrogen to hydrogen humidity meter.

6.17.6.17 When CO2 purity inside generator is higher than 95%, close general valve 122 ofCO2 supplying pipe of CO2 cylinder, CO2 supplying general valve, H2 replacementvalve and replacement general discharging valve.

6.17.7 CO2 replacement inside generator by compressed air

6.17.7.1 Close general valve from hydrogen generating station to hydrogen head pipe,hydrogen cylinder supplying general valve, check valve before hydrogen pressureregulation valve, check valve after hydrogen pressure regulation valve and bypass

valve of hydrogen pressure regulation valve.

6.17.7.2 Open drainage valve of gas replacement head pipe drainage valve from unit

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6.17.7.3 Close hydrogen replacement valve, CO2 supplying general valve and general valveof CO2 supplying pipe of CO2 cylinder.

6.17.7.4 Open CO2 replacement valve.

6.17.7.5 Open hydrogen supplying pipe general valve.6.17.7.6 Open and regulate gas replacement general air discharging valve and keep pressure

inside generator be within 40～50KPa.

6.17.7.7 Open isolation valve to generator compressed air, keep pressure in generator about

0.04MPa. when air purity inside generator is higher than 90％, clean generator and

discharge with CO2 totally, open liquid leakage detector discharging valve of statorair-side & supervision cabinet inlet discharging valve of generator working condition &supervision cabinet outlet discharging valve of generator working condition & star-pointliquid leakage detector discharging valve & outlet box liquid leakage detectordischarging valve & hydrogen dryer inlet discharging valve & hydrogen dryer outletdischarging valve in sequence once time for about 2 minutes.

6.17.7.8 When CO2 purity inside generator is lower than 5％, close hydrogen supplying pipe

general valve, CO2 replacement valve and air isolation valve to generatorcompressed air.

6.17.7.9 Close gas replacement general air discharging valve.

6.18 Start and stop of generator stator cooling water system

6.18.1 Check stator cooling water system before putting into operation

6.18.1.1 System interlock test are satisfied and stator water system valve position is rightly.

6.18.1.2 When supplementary water for stator cooling water tank is analyzed to be qualified,start water supplement valve to supplement water to full.

6.18.1.3 Closed cooling water system is working normally.

6.18.1.4 Control power supply and dynamical power is sent and instrumental meters andalarming devices are working.

6.18.1.5 Make sure that generator hydrogen system and sealing oil system are workingnormally.

6.18.1.6 Make sure that hydrogen pressure inside generator reaches to 0.2MPa.

6.18.2 Filling water to stator water system

6.18.2.1 Water in system should be completely discharged before filling water to stator watersystem.

1) Stator water system Water is generally filled to stator water system through ionexchanger with flow of 25～40L /min.

2) Make sure that water circulating pipes before ion exchanger are flushed and clean,water in pipelines is qualified. Open manual valve before solenoid valve.

3) Prepare resin of ion exchanger and fill water into stator, start condensing watertransfer pump.

4) Open ion exchanger inlet manual valve.

5) Close stator water returning valve and fill water to stator water system through watersupplement solenoid valve.

6) Supplement water inlet pressure is 0.36MPa; permit maximum inlet watertemperature is 50 .℃

152



7) Supplement water to water tank to normal level. Solenoid valve closes automatically.

8) Open the air valves on stator water tank, cooler and pipeline to discharge air; thenclose it.

6.18.3 Stator water cooling pump start

6.18.3.1 Stator cooling water should be reported to be qualified by chemical and cooling watertank level is normal.

6.18.3.2 Start stator water cooling pump and open outlet valve slowly. Check and make surethat vibration, sound and all bearing temperatures are normal.

6.18.3.3 Check and make that outlet pressure is normal. When water cooler, ion exchanger airdischarging valve see water, close air discharging valve, regulate re-circulating valve tokeep generator stator inlet water pressure be at about 320KPa (local indication).Regulate water supplement valve of water tank and regulate ion exchanger flow to be

within 25～40L /min.

6.18.3.4 After system runs normally, put the other stator water cooling pump into standby.

6.18.3.5 Put stator water cooler cooling water into operation.

6.18.4 Stator cooling water pump stop

6.18.4.1 Release standby stator water cooling pump from interlock.

6.18.4.2 Stop stator water cooling pump.

6.18.4.3 If repair is needed after stator water cooling pump stops, power should be cut off, inlet& outlet valves of the pump should be closed. Decrease the pressure and thendischarge water.

6.18.5 Stator cooling water pump switch ing

6.18.5.1 Check and make sure that standby stator cooling water pump bearing oil cup level isnormal and oil quality is good.

6.18.5.2 Start standby pump and check pump completely.

6.18.5.3 Check and make sure that stator cooling water head pipe pressure is normal.

6.18.5.4 Stop former running stator water cooling pump.

6.18.5.5 Put former running pump into standby.

6.18.6 Items should be supervised for stator water system

6.18.6.1 Stator water tank level and temperature.

6.18.6.2 Stator water pump inlet & outlet pressure and current.

6.18.6.3 Stator water pump motor and pump bearing oil level, bearing temperature, vibration

and sound.6.18.6.4 Stator water cooler outlet filter screen inlet & outlet pressure and differential pressure.

6.18.6.5 Generator stator cooling water inlet & outlet pressure difference.

6.18.6.6 Stator cooling water inlet flow.

6.18.6.7 Stator cooling water conductivity is 0.5-1.5S/cm.

6.18.6.8 Ion outlet stator water conductivity is 0.1-0.4S/cm.

6.18.6.9 Ion inlet and outlet pressure.

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Attachment: Saturation steam pressure, temperature comparison table (listing according topressure)

Pressure

（MPa）

Temperature

（℃）

Pressure

（MPa）

Temperature

（℃）

Pressure

（MPa）

Temperature

（℃）

0.001 6.982 0.040 75.89 2.7 228.06

0.0015 13.034 0.050 81.35 2.8 230.04

0.0020 17.511 0.060 85.95 2.9 231.96

0.0025 21.094 0.070 89.96 3.0 233.84

0.0030 24.098 0.080 93.51 3.1 235.66

0.0035 26.692 0.090 96.71 3.2 235.66

0.0040 28.981 0.10 99.63 3.3 237.44

0.0045 31.034 0.12 104.81 3.4 239.18

0.0050 32.90 0.14 109.32 3.5 240.88

0.0055 34.6 0.16 113.32 3.6 244.16

0.0060 36.18 0.18 116.93 3.7 245.75

0.0065 37.65 0.20 120.23 3.8 247.31

0.0070 39.02 0.25 127.43 3.9 248.84

0.0075 40.32 0.30 133.54 4.0 250.33

0.0080 41.53 0.35 138.88 4.5 257.41

0.0085 42.69 0.40 143.62 5.0 263.92

0.0090 43.79 0.45 147.92 5.5 269.94

0.0095 44.83 0.50 151.85 6.0 275.56

0.010 45.83 0.60 158.84 6.5 280.83

0.011 47.71 0.70 164.96 7.0 285.80

0.012 49.45 0.80 170.42 7.5 290.51

0.013 51.06 0.90 175.35 8.0 294.98

0.014 52.58 1.0 179.88 8.5 299.24

0.015 54.0 1.1 184.06 9.0 303.31

0.016 55.34 1.2 187.96 9.5 307.22

0.017 56.62 1.3 191.6 10 310.96

0.018 57.83 1.4 195.04 11 318.04

0.019 58.98 1.5 198.28 12 324.64

0.020 60.09 1.6 201.37 13 330.81

0.021 61.15 1.7 204.30 14 336.63

0.022 62.16 1.8 207.1 15 342.12

0.023 63.14 1.9 209.79 16 347.32

0.024 64.08 2.0 212.37 17 352.26

0.025 64.99 2.1 214.85 18 356.96

154



0.026 65.87 2.2 217.24 19 361.44

0.027 66.72 2.3 219.54 20 365.71

0.028 67.55 2.4 221.78 21 369.79

0.029 68.35 2.5 223.94 22 373.68

0.030 69.12 2.6 226.03Critical22.115

Critical374.12

155



Attachment: Air pressure, vacuum, relative saturation temperature comparison table

ts B

H666 668 670 672 674 676 678 686 682 684

670 7.9 11.5 13.6 16.3

665 9.1 12.7 15.4 17.2 19.4 21.4

660 7.9 11.5 13.6 16.3 18.6 20.1 22.0 236.8 25.4

655 12.7 15.4 17.2 19.4 21.4 23.2 24.3 25.9 27.3 28.2

650 18.6 20.1 22.0 23.8 25.4 26.4 27.7 29.0 30.2 31.0

645 23.2 24.3 25.9 27.3 28.2 29.4 30.6 31.8 32.6 33.6

640 26.4 27.7 29.0 30.2 31.0 32.2 33.2 33.9 34.8 35.8

635 29.4 30.6 31.8 32.6 33.6 34.5 35.2 36.1 37.0 37.8

630 32.2 33.2 33.9 34.8 35.8 36.7 37.3 38.1 39.0 39.5

625 34.5 35.2 36.1 37.0 37.8 38.4 39.2 40.0 40.5 41.2

620 36.7 37.3 38.1 39.0 39.5 40.2 41.0 41.6 42.1 42.7

615 38.4 39.2 40.0 4.05 41.2 41.9 42.5 43.0 43.6 44.2

610 40.2 41.0 41.6 42.1 42.7 43.4 43.8 44.5 45.1 45.7

605 41.9 42.5 43.0 43.6 44.2 44.9 45.3 45.9 46.4 46.8

600 43.4 43.8 44.5 45.1 45.7 46.0 46.6 47.1 47.5 48.0

595 44.9 45.3 45.9 46.4 46.8 47.3 47.8 48.4 48.7 49.3

590 46 0 46 6 47 1 47 5 48 0 48 6 48 7 49 4 49 9 50 3

Documents

EPGL Turbine Operation Manual