30621127-000-3bd-ee-01826 1_25 r-001 plant startup and shutdown philosophy

Project Title

Client

Consultant

Contractor

09-Nov-10 J.B.KIM

CERT.

J.L.WON

CONVERSION OF QURAYYAH OPEN CYCLE POWERPLANT TO COMBINED CYCLE POWER PLANT

PROJECT C

APPD.DATE BY:

Issue for Approval

12-Dec-11 J.L. WON

J.L. WON

REV

000

001

S.H.YOON

J.B.KIM S.H.YOON

CHKD.DESCRIPTION

Issue for Approval J.L.WON

Document Title

CREATED BY: CHECKED BY:

DATE STARTED: DATE COMPLETED:

OPR'G. DEPT.: ENG. DEPT.:

DOC. NO. REV. NO.

QURAYYAH SAUDI ARABIA

PLANT STARTUP AND SHUTDOWN PHILOSOPHY

3BD

THIS DOCUMENT IS NOT TO BE USED FORCONSTRUCTION OR FOR ORDERING

MATERIAL UNTIL CERTIFIED AND DATED

APPROVAL/CERTIFICATION INFORMATION

30621127 000 EE-01826 001

PROJECT SUBDIVISION DOCUMENT TYPE CODE DOCUMENT NUMBER REV. NO.

JOB ORDER NO.

JOB NO.

1-0923053.01

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Project : QURAYYAH CCCP Subject : Plant startup and shutdown philosophy Doc. No. : 30621127-000-3BD-EE-01826

TABLE OF CONTENT

1. INTRODUCTION .............................................................................................................................................................3

2. STARTUP AND SHUTDOWN SEQUENCES ...........................................................................................................3

2.1 Normal Combined Cycle Start ....................................................................................................................3

2.2 Add-on Start .......................................................................................................................................................3

2.3 Normal Block Shutdown ................................................................................................................................4

2.4 Unit Shutdown ...................................................................................................................................................4

3. PLANT START-UP PROCEDURE ................................................................................................................................4

3.1 General ..................................................................................................................................................................4

3.2 Accomplished conditions prior for plant start up ..............................................................................4

3.3 Plant start-up procedure ...............................................................................................................................5

3.3.1 Gas Turbine Start .................................................................................................................................5

3.3.2 HRSG purge ...........................................................................................................................................6

3.3.3 Gas Turbine exhaust gas temperature match ..........................................................................6

3.3.4 Steam generation and Bypass operation ..................................................................................7

3.3.5 Steam stop (isolation) valve operation during lead HRSG start-up ...............................8

3.3.6 Vacuum system start up ................................................................................................................ 10

3.3.7 Steam turbine start up ................................................................................................................... 10

3.3.8 Adding lag GT/HRSG ...................................................................................................................... 11

4. PLANT SHUTDOWN PROCEDURE........................................................................................................................ 12

4.1 General ............................................................................................................................................................... 12

4.2 Plant shutdown procedure ......................................................................................................................... 12

4.2.1 Gas turbine shutdown .................................................................................................................... 12

4.2.2 HRSG shutdown ................................................................................................................................ 12

4.2.3 Steam turbine shutdown ............................................................................................................... 13

4.2.4 Steam Cycle Shutdown ......................................................................................................... １３14

5. ABNORMAL PROCESS CASE STUDY ................................................................................................................... 15

5.1 General ............................................................................................................................................................... 15

5.2 Abnormal Case Study .................................................................................................................................. 16

6. REFERENCE .................................................................................................................................................................... 21

7. ATTACHMENT ............................................................................................................................................................... 21

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1. INTRODUCTION

This document describes overall start-up and shut-down procedure of Qurayyah Combined Cycle Power Plant. To avoid unnecessary duplication of description, this document refers to relevant section in operational philosophy (EE-00400), HRSG system description (EE-01509) and several GEKs.

2. STARTUP AND SHUTDOWN SEQUENCES

The plant configuration consists of three GT/HRSG sets supplying steam to one ST. The plant configuration allows various operating modes.

Equipment starts from a ready condition. Ready condition is defined as all BOP systems are ready to start.

The types of automated startup and shutdown logic are defined as follows:

2.1 Normal Combined Cycle Start

A normal plant start is defined as a GT startup and gradual loading from an initial shutdown condition. The GTs and steam cycle are started from the ready condition. The steam cycle may be in any condition from cold to hot at the initiation of start. Startup with the ST hot, warm or cold is defined with respect to the ST RH bowl and HP bowl metal temperature.

Above 700℉ (371℃) is defined as a hot start

Less than 700℉ (371℃) but greater than 400℉ (204℃) is considered as a warm

start

Less than 400℉ (204℃) is a cold start

The temperature of the ST metal temperature and HRSG HP superheater metal determine the GT exhaust temperature required during initial steam generation, prior to ST roll. The ST initial metal temperature is also accounted for by the ST control which establishes acceleration rates, speed and load holds, and loading rates. Further loading of the steam cycle and GT is coordinated with the ST stress control logic.

2.2 Add-on Start

There are two cases of add-on start. First case is adding GT/HRSG stream(s) to running

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GT/HRSG streams. Second case is adding only HRSG(s) to running GT(s). These two cases are considered in automatic plant start-up/shutdown sequence. Detail add-on procedure is described in section 3.3.7 and 3.3.8 of this document.

2.3 Normal Block Shutdown

The normal plant shutdown is defined as a complete shutdown of the plant equipment. The shutdown operation is conducted to minimize ST stress during shutdown and to leave the steam cycle in the hottest condition for restart.

2.4 Unit Shutdown

The unit shutdown is defined as the removal of one GT/HRSG set from the steam cycle, while the remaining GT and steam cycle continues to operate.

3. PLANT START-UP PROCEDURE

3.1 General

It is described in this section that Auto Plant Start with APS ON including GT start, HRSG purge procedure, Diverter damper position, valve operations, Vacuum operation and STG start-up procedure during Plant start-up in each ST mode (Cold, Warm, Hot) are described in this section. Below is a summary of APS start-up in Combined cycle case.

1) GT in remote mode, GT GCB not closed, D/D closed Feeback(FB)

2) APS ON Command

3) Group Auto command and FB (to/from Plant common, block common, HRSG group)

4) CCW/ACW system start command and FB

5) Condensate system start command and FB

6) Feedwater group start command and FB

7) Condensate vacuum system start command and FB

8) GT start command (customer permissive to start GT ready to start FB GT start command & combined cycle purge request)

9) HRSG purge (Diverter Damper open and close)

10) GT auto synchro permissive and GCB closed FB

11) GT exhaust temp matching and Diverter Damper open

(Lag GT/HRSGs have same sequence as from 8 to 11)

12) Condenser vacuum achieved (<0.5 bara) & vacuum breaker valve closed FB

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13) ST start command (customer permissive to start ST ready to start FB ST start command & MSV, MCV not closed FB)

14) ST auto synchro permissive and GCB closed FB

15) APS OFF

3.2 Accomplished conditions prior for plant start up

Auto Plant Startup (APS) starts with APS ON and proper mode selection on each step of the APS start sequence. Ready conditions of below listed system are required prior to first Gas turbine start sequence. These conditions are to be accomplished by operator manually.

- MSF ready

- Demin/Remin plant ready

- Electro-Chrolination plant ready

- Generator Hydrogen/Nitrogen ready

- Instrument/Service Air ready

- Electrical system ready

- HRSG drum start level

- Gas turbine and auxiliary system

- Steam turbine and generator auxiliary system (Oil supply, evacuation, generator cooling)

3.3 Block start-up procedure

3.3.1 Gas Turbine Start

When GT auto start command is coming from operator or APS start sequence, GT Mark VI controller starts the GT and raises its load to a minimum load.

Starting the gas turbine involves proper sequencing of command signals to the accessories, starting device and fuel component system. Since a safe and successful startup depends on proper functioning of almost all of the gas turbine equipment, it is important to verify the state of selected devices in sequence. Much of the control logic circuitry is associated not only with actuating control devices, but enabling protective circuits, and obtaining permissive conditions before proceeding. Reference to the SPEEDTRONIC™ is necessary for complete understanding of all the logic functions included for the particular equipment provided with a gas turbine. The operating sequences of the Control Specifications are written to explain significant functions which

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pertain to a specific gas turbine. Detailed starting/shutdown sequence and control for GT is described in GEK 111084 and Fundamentals of SPEEDTRONIC™ Mark VI control system.

Overall plant of Gas turbine, HRSG and Steam turbine can starts with Gas turbine start command. Gas turbine start command will be generated by auto plant start-up/shutdown sequence and gas turbine will reach to its target load as per gas turbine`s own start up procedure integrated in gas turbine control system(TCS). Distributed Control System(DCS) is monitoring exhaust temperature of gas turbine and operate diverter damper according to exhaust temperature condition.

3.3.2 HRSG purge

HRSG purge concept is same for all case no matter which temperature mode of HRSG is. The purging concept involves that the bypass stack and the HRSG will be purged prior every GT start (ignition) for both simple cycle and combined cycle start. Once the purge has been completed, it remains set in memory if the GT has remained in continuous operation with no trips. Provided that the purge completed remains set, GT exhaust flow can re-enter HRSG without re-purge for the HRSG start.

HRSG and bypass stack side shall be purged by GT with around 850prm and 6min for purge and by change the position of the diverter damper. The purge duration is determined according to NFPA requirement.. According to the NFPA requirements, the exhaust gas temperature for purging purpose is selected at least 56 deg.C below the

lowest autoignition temperature of the fuel (below 364℃). In this project, the purge will

be done by spinning of the GT without firing, thus exhaust gas temperature for purging process will be ambient air

After HRSG has been purged, the diverter damper is moved to HRSG closed position to prevent HRSG from thermal stress caused by GT exhaust temperature after GT firing.

3.3.3 Gas Turbine exhaust gas temperature match

Temperature set point of GT exhaust gas to HRSG is combination of HRSG HP superheater metal temperature and reference temperature of HP and HRH comes from STG Mark Vie. Temperature matching can be for both of HRSG and ST, and it start for HRSG temperature matching first.

In Cold HRSG (metal temperature of HRSG HP superheater is lower than 371 deg.C), set point of GT exhaust temperature becomes 371deg.C. In Warm/Hot HRSG (metal temperature of HRSG HP superheater is higher than 371 deg.C), set point of GT exhaust temperature becomes 50 deg. C higher than HRSG HP superheater metal temperature. This is to prevent unnecessary cooling down of HRSG. Diverter damper opens when GT exhaust temperature reach to its set point.

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When GT temperature matching for HRSG succeeds (which means D/D opened to HRSG, HRSG superheater metal temperature higher than 371 deg.C and gap between GT exhaust temperature and HRSG superheater metal temperature is lower than 50deg.C), set point of GT exhaust temperature is changed for ST temperature matching. STG Mark Vie is continuously sending reference target temperature of HP steam and HRH steam to DCS. Set point for ST temperature matching is determined considering lower value of HP and HRH target temperature.

The set point for GT exhaust temp is increased with the lower ramp rate in HP steam temperature ramp rate and HRH seam temperature ramp rate which is come from STG

control system (STG Mark Vie). The ramp rate varies between zero and 22 ℃/min (40

℉/min)

3.3.4 Steam generation and Bypass operation

After GT run-up, ignition and synchronizing and GT exhaust gas temperature matching on, HRSG diverter damper is opened to HRSG side. The heat transfer to the HRSG begins. The metal of the heat transfer surfaces is heated up and steam begins to form in the evaporators. HRSG HP/IP/LP drum generates steam as per GT load increase.

The HP main steam line is warmed up by opening HP steam stop valve. HP steam stop valve for lead HRSG is available to be opened when combined cycle mode is selected and GT flame is ON condition and Diverter Damper is opened. All MOV in drain line should be in auto mode throughout auto plant start-up/shutdown sequence.

HP steam bypass valve will be opened 10%(tentative) when HP steam stop valve open for entering steam to HP steam bypass line and cold reheat line for IP steam admission. 10% bypass valve opening position will be changed to control set point pressure(minimum inlet pressure of HP ST, 50 barg, 720 psig) when steam pressure reached to that set point pressure. Bypass valve operates to maintain HP steam pressure to 50 barg which steam turbine allows steam to admit to turbine. Generated HP steam will be passed to cold reheat line through bypass line. Reheated steam vents to air through vent valve in Hot reheat line until Hot reheat bypass valve start to operate.

HRH and LP steam lines are warmed up by opening HRH and LP steam stop valve when steam generated (HRSG ON which means GT flame on & D/D not closed). When condenser vacuum is available (condenser pressure below 0.5 bara), Hot reheat steam bypass and LP steam bypass valve starts to operate.

Intercept valve(IV) of IP steam turbine started to open when condenser pressure reached to around 0.17 bara (5inHg, according to STG document ‘GEK 100478 Allowable exhaust pressure operation’) and HRH steam pressure reaches to 4.35barg.

All bypass system shall be normally controlled with enthalpy logic (HP bypass – Cold Reheat process value and HRH/LP bypass – 2849kJ/kg. The HRH and LP bypass

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downstream temperature as high high temperature is selected as 215℃ for HRH bypass

downstream and 200℃ for LP bypass downstream in order to protect condenser from

High High downstream Temperature. The maximum HP bypass downstream temperature

(450℃) is the same as those of cold reheat system.

IP turbine IV open is the first steam admission of Steam turbine and it causes steam turbine speed increase. When ST speed is reached to 2400rpm, reverse flow valve(RFV) and reverse flow discharge valve(RFDV) will be opened to avoid overheating of the HP turbine.. HP turbine MSV opens when IP steam flow reaches higher than 50% of maximum flow of IP steam turbine and HP steam pressure/temperature is ready to be admitted to HP turbine. RFV and RFDV will be closed at the same time. ST LP admission valve will be started to open its position at the condition of HP Flow Mode (HP turbine in operation) and Steam turbine load greater than 20% of rated ST load. LP bypass steam valve will gradually close its position by opening of ST LP admission valve as per ST control system to maintain LP header setpoint (3bara).

STG IPC mode is available when HP bypass valve is opened below 10% and HP forward flow mode.

When ST is in IPC mode, HP and HRH steam bypass valve change its target pressure little higher than steam header pressure so that HP steam bypass valve maintain close.

In case of lag HRSG mode, HP/HRH/LP steam bypass valve operates same as lead mode steam bypass valve. Lead mode HRH steam bypass valve may wait for vacuum available and lag mode HRH steam bypass valve may not need to wait for vacuum available. This is the difference between lead mode and lag mode operation of bypass valve.

3.3.5 Steam stop (isolation) valve operation during lead HRSG start-up

1) HP steam stop valve (LBA-90-AA-003)

These valves make HRSG isolation from the steam header in case of HRSG not in service. Also these valves are used to connect the HRSG into the operation steam header during start-up.

The HP steam stop valve is opened at the initiation of the HRSG start (Diverter Damper Open and GT Flame On) while the bypass stop MOV is closed. And the HP main steam header is warmed, drained and pressurized along with the HRSG.

The lag HRSG is started with closed steam stop valves. When the following conditions are satisfied, open small bypass stop valve first.

- Temperature difference between lag HRSG HP steam temperature and HP

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steam header steam is lower than 50 deg.C.

- The lag HRSG (HP) steam pressure is 2 bar higher than the HP steam header pressure.

After small bypass stop valve is opened, then open the main stop valve and close the small bypass stop valve. The last HRSG HP steam stop MOV’s operation is the same with lag HRSG.

2) Hot reheat steam stop valve(LBB-29-AA-008)

The HRH steam stop MOV is opened at the initiation of HRSG start while the bypass stop MOV is closed.

The lag HRSG is started with closed HRH steam stop MOV. When the following conditions are satisfied, open small bypass stop valve first.

- Temperature difference between lag HRSG steam and operation header steam is lower than 50 deg.C.

- The lag HRSG(HRH) steam pressure is 1 bar higher than the operation header pressure.

After small bypass stop valve open, then open the main stop valve and close the small bypass stop valve. The last HRSG HRH steam stop MOV`s operation is the same with lag HRSG.

3) Cold reheat steam stop valve (LBC-90-AA-001)

The CRH steam stop MOV is opened at the initiation of the HRSG start. And the CRH steam header is warmed, drained and pressurized along with the HRSG.

The lag HRSG reheater is started with closed steam stop valves. Thus, the reheater is initially isolated from the steam header. Steam from the HP steam bypass system passes through the reheater to the condenser via the HRH steam bypass system. When the steam conditions are satisfied, the lag HRSG HRH steam isolation valve open initiated. At this moment, the CRH steam stop valve will be opened simultaneously.

4) LP steam stop valve(LBC-90-AA-002)

The LP steam stop MOV is opened at the initiation of the HRSG start while the bypass stop MOV is closed. And the LP main steam header is warmed, drained and pressurized along with the HRSG.

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The lag HRSG is started with closed steam stop valves. When the following conditions are satisfied, Open small bypass stop valve first.

Temperature difference between lag HRSG steam and operation header steam is lower than 30 deg.C.

The lag HRSG (LP) steam pressure is higher (Approximately, 0.5 bara) than the operation header pressure.

After small bypass stop valve open, then open the main stop valve and close the small bypass stop valve. The last HRSG LP steam stop MOV’s operation is the same with lag HRSG.

3.3.6 Vacuum system start up

Steam seals are used on condensing steam turbines to keep air (which is non-condensable) from entering the turbine casing at the ends where the rotor exits.

Vacuum pump starts under following condition.

- Seal steam supplied to turbine

- Vacuum breaker valve closed

Estimated time from atm pressure to vacuum ready(0.5bara) after vacuum pump start is 25 minutes

3.3.7 Steam turbine start up

Steam turbine start and shutdown is described in GEK 107170(Control Description and Operation) section iii, Control operations.

The steam turbine is rolled and initially loaded using the intercept valves with the main control valves closed.

When condenser vacuum is ready (5 in HgA), IP turbine allows steam to be admitted and turbine starts to roll and increase its speed. Reheated IP steam is flowing to condenser through LP turbine. During such steam flowing, the reverse flow valve (RFV) in cold reheat line and reverse flow discharge valve (RFDV) in HP steam to condenser line opens when ST speed reaches to 2/3 of its rated speed. These two valves open only in warm/hot mode to prevent overheating HP steam inside.

Transfer to Forward flow will be available as IV (Intercept Valve) flow demand exceeds 50%. The turbine controls will predict high pressure rotor stresses after transfer to Forward Flow considering mismatch between steam and metal temperature. If in Automatic mode and the transfer is permitted, the turbine controls will automatically to Forward Flow.

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Main stop valve (MSV) of HP turbine will be opened when HP steam pressure and temperature are reached to allowable condition of HP turbine. As load increase, main control valve (MCV) is opening and HP steam bypass valve is closing.

LP steam admission into LP turbine is permissive when the HPT is in forward flow mode and the HP steam flow and steam turbine load is > 20%.

IPC may be enabled at any time after the turbine is in Forward Flow and MCV is keep opening to maintain ST inlet pressure to floor pressure while ST load(flow) increase. STG load is increased by increasing GT load, limited by the steam turbine recommended loading rate (ST signal “ldr_r_rec”) generated from STG control system. When the HP steam bypass pressure control valve reaches it’s minimum open position (<10%), MCV will be 100% opened as per the generated steam flow increase and the HP steam bypass valve is fully closed. ST will follow GT/HRSG load, called sliding pressure control.

3.3.8 Adding lag GT/HRSG

The start-up procedure of the lag GT and HRSG from GT start-up to steam production of the HRSG is similar to the lead one. During start-up of lag GT and HRSG, the each pressure bypass valve is operated until the target pressure and temperature of the HP, RH and LP steam of the operating HRSG are met.

The lag GT/HRSG module is increasing its load to 60% of GT base load to make a tie-in condition with the steam condition of the operated HRSG.

When lag HRSG is added to operating HRSG, lead GT load will be reduced to 60% of GT base load. Steam stop valve of lag HRSG will be opened when temperature difference between lag HRSG steam and operation header steam is lower than 50 deg.C for HP stop valve, 50 deg.C for IP stop valve and 30 deg.C for LP stop valve, respectively. Lag HRSG steam pressure is higher (approximately 2 bar in HP, 1 bar IP and 0.5 bar in LP) than the operation header pressure.

Drain valves in each lag HRSG stop valve discharge line will be opened to prevent clogged steam in the line until lag HRSG stop valve opened.

The following step will be adopted to make a steam balance in both of lead and lag HRSG:

- Lag GT/HRSG to Start-up

- Lag HRSG to be in Bypass Operation with the close of each steam stop valves

- Lag GT/HRSG Load increasing to 60% of GT base load

- Lead GT/HRSG Load decreasing to 60% of GT base load

- After all GT load is reached at around 60% of GT base load and steam condition is matched between the lead HRSG steam condition and the lag, steam stop valves of

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lag HRSG will be opened and each bypass valve will be closed. Note: Bypass Valve target pressure is the header pressure of ST inlet.

Time difference of lag GT start will be indicated later considering timing of vacuum ready.

4. PLANT SHUTDOWN PROCEDURE

4.1 General

This document describes normal plant shutdown procedure with single pushbutton shutdown and emergency shutdown case is not considered in this document.

4.2 Plant shutdown procedure

4.2.1 Gas turbine shutdown

Gas turbine can operate by itself even in case of failure condition of HRSG or STG. To avoid unnecessary Gas turbine shutdown, auto plant startup/shutdown sequence does not include gas turbine trip in plant shutdown sequence. Gas turbine will be shutdown in below case by plant protection logic.

- Diverter damper failure

- HRSG trip and Diverter damper not closed to HRSG

4.2.2 HRSG shutdown

Detail procedure of HRSG shutdown is described in HRSG description(EE-01509) section 2.5.

Normal shut down is organized to leave the steam cycle pressurized and hot. This is done to obtain the fastest restart possible and to minimize life expenditure for the plant. The HRSG shutdown is performed by the diverter damper close to HRSG as following actions.

The HRSG shut down is performed by the diverter damper close with normal speed (60~90 seconds) and major valve operation is as below

1) Diverter damper close to HRSG and HRSG can be isolated from Gas turbine

2) HP/IP/LP steam bypass system will be operated, thereby diverting steam from the

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HRSG through the associated steam bypass system.

3) HP steam stop valve(LBA-90-AA-003) will be closed when HRSG shutdown initiated and HP steam bypass system open sufficiently. The last HP steam stop valve will be closed when ST MCV closed to reduce HP steam header pressure.

4) Cold reheat(CRH) steam stop valve(LBC-90-AA-001) will be closed when HRSG shutdown initiated and HP steam bypass system open sufficiently. The lead HRSG HP steam is isolated from the HP header. At this moment, HRH, CRH and LP steam stop valve will be closed simultaneously. The last CRH steam stop valve will be closed when ST MCV closed to reduce CR steam header pressure.

5) LP steam isolation valve(LBD-90-AA-002) will be closed when HRSG shutdown initiated and LP steam bypass system open sufficiently. The lead HRSG HP steam is isolated from HP header. The last LP steam stop valve will be closed when ST LP control valve closed.

6) IP steam stop valve(LBA-95-AA-002) will be closed when IP steam PCV(LBA-95-AA-002) fully closed.

7) Continuous blowdown valve from HP drum, IP drum will be closed when HP/IP steam flow is lower than 20% MCR flow.

4.2.3 Steam turbine shutdown

1) Take the Admission Pressure Control out of service by reducing the admission flow setpoint to zero percent. Admission flow must be zero.

2) Check that the Standby Bearing Oil Pump has a ready source of power and that its control switch is in the AUTO START position. A continuous supply of oil must be maintained throughout the shutdown process.

3) Select the Load Control function and close the V1’s by selecting a target load of near 0% and a ramp rate consistent with the CRT guidance. As the load falls through 15% the group B(refer to note) drain valves will open.

4) As the IV demand decreases below 30% and the generator armature current drops below 20% of rated, transfer to Reverse Flow will occur automatically, and include opening of RFV and VV

5) Adjust the Exciter’s AC regulator to reduce the VARS to zero.

6) The operator may trip the unit as soon as the generated power is approximately zero. The load setpoint will be forced to zero and reverse power will cause the generator breaker to open.

7) Check that all group A(refer to note) drains have opened after tripping.

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8) It should be verified that below 95% speed the excitation system is turned off.

9) When the unit coasts down to two or three RPM, check that the turning gear has automatically engaged. If it hasn’t, it should be manually engaged. Refer to the separate instruction, “Turning Gear Control”.

10) Keep the Bearing Oil Pump RUNNING for at least four hours after Shutdown to cool the journals and bearings. Adjust the Oil Coolers for maximum cooling of the lubricating oil. The lube oil must remain on until the Turning Gear Motor is shut off. If the duration of Shutdown is to be less than two days, leave one Bearing Oil Pump RUNNING.

11) Shut down the Hydraulic Power Unit.

12) The vacuum may be broken if the turbine speed is less than two-thirds of design speed.

13) Turn off the steam seal system.

14) Secure the Gland Exhauster.

15) After the lube oil system and turning gear have been turned off the cooling water for the lube oil coolers bay be turned off.

16) Secure the steam supply to the Turbine and the auxiliary equipment.

Note. Drain valves controlled by the turbine control system are broken into three groups. Group A Main Stop before seat drain Main Stop after seat drain Group B Steam packing drain Reheat Combined Valve after seat drain Group C Admission Control Valve before seat drain Admission Control Valve after seat drain

4.2.4 Steam Cycle Shutdown

The Steam cycle shutdown goes proceeded while maintaining the gas turbines in operation as follows:

The first and/or second HRSGs are closing the diverter damper to the HRSG inlet in order to make offline.

The HRSG is then isolated from the steam header by closing the steam isolation valve. The remaining steam is relieved to the condenser via the bypass systems if the steam pressure is reached at its maximum steam pressure.

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The steam turbine begins to unload in proportion to steam flow diminution. The main control valve throttles to maintain pressure. Before closing the last HRSG’s diverter damper to the HRSG inlet, the steam turbine is given a shutdown order and the main control valve is ramped closed by ST control system. When the steam turbine control valve reaches minimum position, the steam turbine is tripped and the steam turbine generator is automatically placed on turning gear operation when it reaches zero speed.

The last HRSG is taken offline by closing the diverter damper to the HRSG inlet. The HRSG is then isolated from the steam header by closing the steam isolation valve. The remaining steam is relieved to the condenser via the bypass systems.

In case of steam cycle shutdown with gas turbines, Plant shutdown from base load or any load is accomplished by unloading the gas turbines. This is done to reduce steam flow while still maintaining allowable steam temperature (full steam temperature to 510 deg C)_GEK111301). Since the steam turbine operates in the IPC In mode, the HP, HRH and LP steam pressures are reduced as the steam flow is diminished. the procedure is as below:

All gas turbine loads are reduced up to 25MW based on the ST ATS MW Rate.

STG stop command is issued. The steam turbine main control valves are ramped closed as per ST control system. As each ST control valves begin to throttle, pressure control is transferred to the respective steam bypass valve at that pressure level. When the steam turbine control valves reach their minimum position, the steam turbine is tripped.

All HRSG stop command is issued. All HRSGs are taken offline by closing the diverter damper to the HRSG inlet. The HRSG shut-off valves are closed to minimize heat loss from the HRSG.

The gas turbine load is further reduced about 9MW. GTs is stopped.

* The detailed shutdown description in GT, HRSG and ST is referred to Section 4.2.1 to 4.2.3.

5. ABNORMAL PROCESS CASE STUDY

5.1 General

Abnormal condition and its influence to plant operation are described in this section.

The abnormal condition is taken into account with the trip scenarios in the following equipment:

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1) Gas Turbine Generator

2) Heat Recovery Steam Generator

3) Steam Turbine Generator

4) Feed Water Pump (FWP)

5) Condensate Extraction Pump (CEP)

6) Circulating Water Pump (CWP)

The abnormal events / Scenarios are occurred in the below case:

- GT trip with its HRSG

- HRSG Trip while GT(s) is continuously operated

- FWP Trip (One FWP Trip without the startup of Standby pump)

- CEP Trip (One CEP Trip without the startup of Standby pump)

- CWP Trip (One CWP Trip in one block)

5.2 Abnormal Case Study

The following table lists the various situations that are taken into account together with the proposed responses.

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Table 1-1. CASE ANALYSIS

CASE NO. NORMAL CASE 1 CASE 2 CASE 3 CASE 4

Event No One GT

Trip

Two GTs

Trip One HRSG

Trip Two HRSGs

Trip

GT #1 100% Load

[In CC Mode] Trip Trip

100% Load

[In SC Mode]

100% Load

[In SC Mode]

GT #2 100% Load

[In CC Mode]

100% Load

[In CC Mode] Trip

100% Load

[In CC Mode]

100% Load

[In SC Mode]

GT #3 100% Load

[In CC Mode]

100% Load

[In CC Mode]

100% Load

[In CC Mode]

100% Load

[In CC Mode]

100% Load

[In CC Mode]

HRSG #1 100% Load Trip

(Bypass Mode)

Trip

(Bypass Mode)

Trip

(Bypass Mode)

Trip

(Bypass Mode)

HRSG #2 100% Load 100% Load Trip

(Bypass Mode)100% Load

Trip

(Bypass Mode)

HRSG #3 100% Load 100% Load 100% Load 100% Load 100% Load

STG

(as per event) 100% Load

Go to Partial Load

Go to Partial Load

Go to Partial Load

Go to Partial Load

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Table 1-2. CASE ANALYSIS

CASE NO. CASE 5 CASE 6 CASE 7 CASE 8

Event Three HRSG

Trip One FWP Trip w/o Standby Operation

One CEP Trip w/o Standby Operation

One CWP Trip

GT #1 100% Load

[In SC Mode]

100% Load

[In SC Mode]

60% Load

[In SC Mode]

60% Load

[In CC Mode]

GT #2 100% Load

[In SC Mode]

100% Load

[In CC Mode]

60% Load

[In CC Mode]

60% Load

[In CC Mode]

GT #3 100% Load

[In SC Mode]

100% Load

[In CC Mode]

60% Load

[In CC Mode]

60% Load

[In CC Mode]

HRSG #1 Trip

(Bypass Mode)

Trip

(Bypass Mode)

Trip

(Bypass Mode) 60% Load

HRSG #2 Trip

(Bypass Mode) 100% Load 60% Load 60% Load

HRSG #3 Trip

(Bypass Mode) 100% Load 60% Load 60% Load

STG

(as per event) TRIP Go to Partial Load Go to Partial Load Go to Partial Load

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TABLE 2. Event & Response

CASE No. Event Gas Turbines

/ HRSG Steam

Turbines Response

CASE 1 One GT trip & loss of HRSG

2 GTs and 2 HRSGs at 100% load

&

1 GT Trip & 1 HRSG Trip

Partial Load

1) In case of one GT trip, its train HRSG is automatically out of service.

2) Two operating GTs and HRSGs are in service with 100% load.

3) Tripped GT and HRSG will be in shutdown mode with bypass mode, if required.

4) The Bypass Valve will be followed of the preselected setpoint before GT Trip.

5) STG output will be partially unloaded as per two operating HRSGs steam generation.

CASE 2 Two GT trip & loss of HRSG

1 GT and 1 HRSG at 100% load

&

2 GTs Trip & 2 HRSGs Trip

Partial Load

1) In case of two GTs trip, their HRSGs are out of service.

2) One operating GT and HRSG is in service with 100% load.

3) Tripped GT and HRSG will be in shutdown mode with bypass mode, if required.


5) STG output will be partially unloaded as per one operating HRSG steam output.

CASE 3 One HRSG trip


&

1 HRSG Trip

Partial Load

1) Three operating GTs are in service with 100% load (or the previous operating load).

2) Tripped HRSG diverter damper is closed to the HRSG.

3) Tripped HRSG will be in shutdown mode with bypass mode, if required.


5) STG output will be partially unloaded as per two operating HRSG steam output.

CASE 4 Two HRSGs trip

3 GTs and 1 HRSG at 100% load

&

2 HRSGs Trip

Partial Load




4) The Bypass Valve will be followed of the preselected setpoint before GT Trips.


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/ HRSG Steam

Turbines Response

CASE 5 Three HRSGs trip

3 GTs at 100% load

&

3 HRSGs Trip

Trip



3) Tripped HRSG will be in shutdown mode with bypass mode.

4) The Bypass Valve will be followed of the preselected setpoint.

5) STG is in shutdown.

CASE 6 One FWP Trip w/o Standby Operation in one HRSG


&

1 HRSG Trip

Partial Load


2) Two HRSGs are in service with 100% load (or the previous operating load)





RUNBACK MODE

CASE 7 One CEP Trip w/o Standby Operation in one HRSG


&

1 HRSG Trip

Partial Load

1) Three operating GTs load is decreased up to 60% load.

2) Two HRSGs load are reduced 60% load as per GT load decrease.





RUNBACK MODE

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/ HRSG Steam

Turbines Response

CASE 8 One CWP Trip


Partial Load

1) Three operating GTs load is decreased up to 60% load.

2) Three HRSGs load are reduced 60% load as per GT load decrease.


4) The Bypass Valve will be followed of the preselected setpoint..

5) STG output will be partially unloaded as per three operating HRSG steam output.

6) If one (1) CW pump of any block, selected to run in single mode of operation, will trip, then the other remaining CW pump of the same block will be ramped to higher speed. When operating in Grouped mode, if one (1) CW pump of any block will trip, the stand-by CW pump of ‘follow block’ will start running at higher speed. However, if the stand-by pump fails to start, then both the STG’s of Grouped block will runback to the corresponding load of as per three operating HRSG steam output.

RUNBACK MODE

6. REFERENCE

- HRSG system Description (EE-01509)

- Operational Philosophy (EE-000400)

- Control Description and Operation (GEK 107170)

7. ATTACHMENT

- Plant overall diagram (steam & water)

- Vent and Drain valve operation table

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START-UP VENT AND DRAINS OPERATIONThe purpose of the vent and drain sequencing is to remove the non-condensable gasses from the HRSG, remove any accumulated condensate from the steam lines and provide a flow path for steam to heat the piping. This involves opening the low point and end point drains. The following tables provide the conditions when the drains are open and closed.

Ref. P&ID Valve Number Valve Description Start Up NormalOperation Secure To Warm

H.P Econ. & Evap. Section [EA-685642] LAB-90-AA-001 HP Feedwater main stop MOV Auto(Open) Auto(Open) Auto(Close)LAB-90-AA-002 HP Feedwater small stop MOV Auto(Close) Auto(Close) Auto(Close)HAC-90-AA-002 HP Drum low load LCV isolation MOV Auto(Close) Auto(Open) Auto(Close)HAC-90-AA-082 HP Drum low load LCV Auto(Close) Auto Auto(Close)HAC-90-AA-001 HP Drum Full load LCV isolation MOV Auto(Close) Auto(Open) Auto(Close)HAC-90-AA-081 HP Drum Full load LCV Auto(Close) Auto Auto(Close)HAD-91-AA-002 HP Drum C.B.D MOV Auto(Close) Auto(Open) Auto(Close)HAD-91-AA-001 HP Drum I.B.D MOV Auto(Close) Auto(Close) Auto(Close)

H.P Superheater. Section [EA-685640] HAH-91-AA-001 HP SH 1 inlet drain MOV Auto(Close) Auto(Close) Auto(Close)HAH-90-AA-001 HP SH 2 drain MOV Auto(Close) Auto(Close) Auto(Close)LBA-90-AA-001 HP SH 3 drain MOV Auto(Close) Auto(Close) Auto(Close)LBA-90-AA-005 HP steam line drain MOV Auto(Close) Auto(Close) Auto(Close)LBA-90-AA-002 HP start up vent MOV Auto(Close) Auto(Close) Auto(Close)LBA-90-AA-004 HP steam small stop MOV Auto(Close) Auto(Close) Auto(Close)LBA-90-AA-003 HP steam Main stop MOV Auto(Close) Auto(Open) Auto(Close)LAE-90-AA-001 HP DESH. Spray block MOV Auto(Close) Auto Auto(Close)LAE-90-AA-081 HP DESH. Spray TCV Auto(Close) Auto Auto(Close)LAE-90-AA-002 HP DESH. Spray Bypass MOV Auto(Close) Auto(Close) Auto(Close)

I.P Section [EA-685643] LAB-94-AA-001 IP Feedwater main stop MOV Auto(Open) Auto(Open) Auto(Close)LAB-94-AA-002 IP Feedwater small stop MOV Auto(Close) Auto(Close) Auto(Close)HAC-94-AA-001 IP Drum LCV bypass MOV Auto(Close) Auto(Close) Auto(Close)HAC-94-AA-081 IP Drum LCV Auto(Close) Auto Auto(Close)HAD-95-AA-002 IP Drum C.B.D MOV Auto(Close) Auto(Open) Auto(Close)HAD-95-AA-001 IP Drum I.B.D MOV Auto(Close) Auto(Close) Auto(Close)LBA-95-AA-003 IP steam line drain MOV Auto(Close) Auto(Close) Auto(Close)LBA-95-AA-001 IP start up vent MOV Auto(Close) Auto(Close) Auto(Close)LBA-95-AA-081 IP steam PCV Auto(Close) Auto(Open) Auto(Close)LBA-95-AA-002 IP steam stop MOV Auto(Open) Auto(Open) Auto(Close)

Reheater Section [EA-685641] LBC-90-AA-001 CRH steam stop MOV Auto(Close) Auto(Open) Auto(Close)LBC-90-AA-002 CRH steam line drain MOV Auto(Close) Auto(Close) Auto(Close)HAJ-90-AA-001 Reheater drain MOV Auto(Close) Auto(Close) Auto(Close)LBB-90-AA-002 HRH steam line drain MOV Auto(Close) Auto(Close) Auto(Close)LBB-90-AA-001 HRH start up vent MOV Auto(Close) Auto(Close) Auto(Close)LBB-90-AA-081 HRH start up vent PCV Auto(Close) Auto(Close) Auto(Close)LAF-90-AA-001 RH DESH. Spray block MOV Auto(Close) Auto Auto(Close)LAF-90-AA-081 RH DESH. Spray TCV Auto(Close) Auto Auto(Close)LAF-90-AA-002 RH DESH. Spray Bypass MOV Auto(Close) Auto(Close) Auto(Close)

Condensate Preheater Section [EA-685645] LCA-90-AA-001 Condensate stop MOV Auto(Open)(*) Auto(Open) Auto(Close)

LCA-90-AA-081 CPH 3-way valve Auto(Open tobypass direction) Auto Auto(In place)

LCA-94-AA-081 CPH Recirculation TCV Auto Auto AutoL.P Section [EA-685644] LCA-91-AA-001 LP Drum LCV bypass MOV Auto(Open) Auto(Close) Auto(Close)

LCA-91-AA-081 LP Drum LCV Auto(Close) Auto Auto(Close)LBA-96-AA-001 LP Drum Pegging stop MOV Auto(Close) Auto Auto(Close)LBA-96-AA-081 LP Drum Pegging PCV Auto(Close) Auto Auto(Close)HAD-97-AA-001 Deaerator vent MOV Auto(Close) Auto(Open) Auto(Close)HAD-98-AA-001 LP Drum I.B.D MOV Auto(Close) Auto(Close) Auto(Close)LBD-90-AA-004 LP steam line drain MOV Auto(Close) Auto(Close) Auto(Close)LBD-90-AA-001 LP start up vent MOV Auto(Close) Auto(Close) Auto(Close)LBD-90-AA-081 LP start up vent PCV Auto(Close) Auto(Close) Auto(Close)LBD-90-AA-003 LP steam small stop MOV Auto(Close) Auto(Close) Auto(Close)LBD-90-AA-002 LP steam Main stop MOV Auto(Close) Auto(Open) Auto(Close)

HP Steam System [EA-682801-001] C10-LBA-46-AA-005 HP common header steam drain MOV Auto(Close) Auto(Close) Auto(Close)C10-LBA-46-AA-006 HP common header steam drain MOV Auto(Close) Auto(Close) Auto(Close)

HP Steam System [EA-682801-002] C11-LBA-46-AA-003 HP individual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBA-46-AA-004 HP individual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBA-46-AA-005 HP individual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBA-46-AA-003 HP individual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBA-46-AA-004 HP individual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBA-46-AA-005 HP individual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C13-LBA-46-AA-001 HP individual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C13-LBA-46-AA-005 HP individual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)

VENT AND DRAIN VALVE OPERATION TABLE

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HP Steam System [EA-682801-003] C11-LBA-25-AA-002 HP bypass steam MOV Auto(Open) Auto(Open) Auto(Open)C11-LBA-25-AA-081 HP bypass PCV Auto Auto(Close) Auto(In place)C11-LAB-25-AA-002 HP bypass spray water MOV Auto(Open) Auto(Open) Auto(Open)C11-LAB-25-AA-081 HP bypass spray water TCV Auto(Close) Auto(Close) AutoC12-LBA-25-AA-002 HP bypass steam MOV Auto(Open) Auto(Open) Auto(Open)C12-LBA-25-AA-081 HP bypass PCV Auto Auto(Close) Auto(In place)C12-LAB-25-AA-002 HP bypass spray water MOV Auto(Open) Auto(Open) Auto(Open)C12-LAB-25-AA-081 HP bypass spray water TCV Auto(Close) Auto(Close) AutoC13-LBA-25-AA-002 HP bypass steam MOV Auto(Open) Auto(Open) Auto(Open)C13-LBA-25-AA-081 HP bypass PCV Auto Auto(Close) Auto(In place)C13-LAB-25-AA-002 HP bypass spray water MOV Auto(Open) Auto(Open) Auto(Open)C13-LAB-25-AA-081 HP bypass spray water TCV Auto(Close) Auto(Close) Auto

Auxiliary Steam System [EA-682802-001] C10-LAB-30-AA-001 HP PRDS spray water MOV Auto(Open) Auto(Open) Auto(Open)C10-LAB-30-AA-081 HP PRDS spray water TCV Auto Auto AutoC10-LBA-30-AA-001 PRDS HP steam MOV Auto(Open) Auto(Open) Auto(Open)C10-LBA-30-AA-081 PRDS HP steam PCV Auto Auto AutoC10-LAB-30-AA-003 CRH PRDS spray water MOV Auto(Open) Auto(Open) Auto(Open)C10-LAB-30-AA-082 CRH PRDS spray water TCV Auto(Close) Auto(Close) Auto(Close)C10-LBC-30-AA-002 PRDS CRH steam MOV Auto(Close) Auto(Close) Auto(Close)C10-LBC-30-AA-022 PRDS CRH steam PCV Auto(Close) Auto(Close) Auto(Close)C10-LBG-46-AA-023 PRDS HP downsteam drain MOV Auto(Close) Auto(Close) Auto(Close)C10-LBG-46-AA-025 PRDS CRH downsteam drain MOV Auto(Close) Auto(Close) Auto(Close)C10-LBG-48-AA-001 Gland steam, Turbin seal system MOV Auto(Open) Auto(Open) Auto(Open)

Auxiliary Steam System [EA-682802-002] C00-LCA-40-AA-001 LP PRDS spray water MOV Auto(Open) Auto(Open) Auto(Open)C00-LCA-40-AA-081 LP PRDS spray water TCV Auto Auto AutoC00-LBG-40-AA-081 PRDS LP steam PCV Auto(Close) Auto(Open) Auto(Close)

Auxiliary Steam System [EA-682802-003] C10-LBA-46-AA-007 PRDS HP upsteam drain MOV Auto(Close) Auto(Close) Auto(Close)C10-LBA-46-AA-008 PRDS HP upsteam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBG-46-AA-006 PRDS HP upsteam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBG-46-AA-006 PRDS HP upsteam drain MOV Auto(Close) Auto(Close) Auto(Close)C13-LBG-46-AA-006 PRDS HP upsteam drain MOV Auto(Close) Auto(Close) Auto(Close)

LP Steam System [EA-682803-002] C10-LBD-26-AA-003 LP steam header drain MOV Auto(Close) Auto(Close) Auto(Close)C10-LBD-26-AA-004 LP steam header drain MOV Auto(Close) Auto(Close) Auto(Close)

LP Steam System [EA-682803-003] C11-LBD-26-AA-001 LP bypass steam MOV Auto(Open) Auto(Open) Auto(Open)C12-LBD-26-AA-001 LP bypass steam MOV Auto(Open) Auto(Open) Auto(Open)C13-LBD-26-AA-001 LP bypass steam MOV Auto(Open) Auto(Open) Auto(Open)C11-LBD-26-AA-081 LP bypass steam PCV Auto Auto(Close) Auto(Close)C12-LBD-26-AA-081 LP bypass steam PCV Auto Auto(Close) Auto(Close)C13-LBD-26-AA-081 LP bypass steam PCV Auto Auto(Close) Auto(Close)C11-LCE-26-AA-001 LP bypass spray water MOV Auto(Open) Auto(Open) Auto(Open)C12-LCE-26-AA-001 LP bypass spray water MOV Auto(Open) Auto(Open) Auto(Open)C13-LCE-26-AA-001 LP bypass spray water MOV Auto(Open) Auto(Open) Auto(Open)C11-LCE-26-AA-085 LP bypass spray water TCV Auto Auto AutoC12-LCE-26-AA-085 LP bypass spray water TCV Auto Auto AutoC13-LCE-26-AA-085 LP bypass spray water TCV Auto Auto Auto

LP Steam System [EA-682803-004] C10-LBD-46-AA-010 LP common header steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBD-46-AA-002 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBD-46-AA-010 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBD-46-AA-002 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBD-46-AA-010 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C13-LBD-46-AA-002 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C13-LBD-46-AA-003 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C13-LBD-26-AA-010 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)

LP Steam System [EA-682803-005] C11-LBD-46-AA-011 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBD-46-AA-012 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBD-46-AA-013 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBD-46-AA-011 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBD-46-AA-012 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBD-46-AA-013 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C13-LBD-26-AA-012 LP indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)

Cold Reheat Steam System [EA-682828-001] C10-LBC-46-AA-005 CRH common header steam drain MOV Auto(Close) Auto(Close) Auto(Close)C10-LBC-46-AA-006 CRH common header steam drain MOV Auto(Close) Auto(Close) Auto(Close)C10-LBC-46-AA-007 CRH common header steam drain MOV Auto(Close) Auto(Close) Auto(Close)

Hot Reheat Steam System [EA-682829-001] C11-LBB-29-AA-001 HRH Steam isolation MOV Auto(Open) Auto(Open) Auto(Close)C12-LBB-29-AA-001 HRH Steam isolation MOV Auto(Open) Auto(Open) Auto(Close)C13-LBB-29-AA-001 HRH Steam isolation MOV Auto(Open) Auto(Open) Auto(Close)C11-LBB-29-AA-008 HRH Steam isolation small MOV Auto(Close) Auto(Close) Auto(Close)C12-LBB-29-AA-008 HRH Steam isolation small MOV Auto(Close) Auto(Close) Auto(Close)C13-LBB-29-AA-008 HRH Steam isolation small MOV Auto(Close) Auto(Close) Auto(Close)C12-LBB-29-AA-010 HRH indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)

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Hot Reheat Steam System [EA-682829-002] C11-LCE-29-AA-002 HRH bypass spray water MOV Auto(Open) Auto(Open) Auto(Open)C12-LCE-29-AA-002 HRH bypass spray water MOV Auto(Open) Auto(Open) Auto(Open)C13-LCE-29-AA-002 HRH bypass spray water MOV Auto(Open) Auto(Open) Auto(Open)C11-LCE-29-AA-081 HRH bypass spray water TCV Auto Auto AutoC12-LCE-29-AA-081 HRH bypass spray water TCV Auto Auto AutoC13-LCE-29-AA-081 HRH bypass spray water TCV Auto Auto AutoC11-LBB-29-AA-005 HRH bypass steam MOV Auto(Open) Auto(Open) Auto(Open)C12-LBB-29-AA-005 HRH bypass steam MOV Auto(Open) Auto(Open) Auto(Open)C13-LBB-29-AA-005 HRH bypass steam MOV Auto(Open) Auto(Open) Auto(Open)C11-LBB-29-AA-081 HRH bypass steam PCV Auto Auto(Close) Auto(Close)C12-LBB-29-AA-081 HRH bypass steam PCV Auto Auto(Close) Auto(Close)C13-LBB-29-AA-081 HRH bypass steam PCV Auto Auto(Close) Auto(Close)

Hot Reheat Steam System [EA-682829-003] C10-LBB-46-AA-004 HRH common header steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBB-46-AA-004 HRH indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBB-46-AA-007 HRH indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBB-46-AA-009 HRH indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C11-LBB-46-AA-010 HRH indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBB-46-AA-004 HRH indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C12-LBB-46-AA-007 HRH indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C13-LBB-46-AA-004 HRH indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)C13-LBB-46-AA-007 HRH indivisual line steam drain MOV Auto(Close) Auto(Close) Auto(Close)

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30621127-000-3bd-ee-01826 1_25 r-001 plant startup and shutdown philosophy

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