Text

Initial Exam 2009-301 Draft Simulator Scenarios
	ML100620144
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Site:	Saint Lucie
Issue date:	02/09/2010
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Appendix D Scenario Outline Form ES-D-1 Facility St. Lucie Scenario No.:

3 Op Test No.:

HLC-19 NRC Examiners:

Operators:

SRO:

RO:

BOP:

Initial Conditions:

2-3 % power, BOC. 2C Charging pump OOS for repack.

Turnover: 2-3% power. BOC, 1622 PPM boron, MTC approximately '0'. 2C Charging pump OOS for repack. MFW and SBCS are in service. Vacuum has been drawn in the Condenser.

Raise power and place the Turbine on line.

~-.,----

Critical Tasks Start 2B HPSI pump Block MSIS Close 2B MSIV Isolate 2B SG Event Malf.

Event Event No.

No.

Type*

Description 1

R/RO Raise Reactor power to 10-12%,

2 1

C/RO CEA # 8 slips 20 inches from current position T.S.I SRO 3

2 1/ RO HIC 1100 Spray Controller fails high 4

3 C/BOP CEDM Fan HVE-21A trips f-~--

5A 4

T.S. SRO SGTL (10 gpm) 2B SG 5B M I All SGTR (200 gpm) 2B SG 6

5 C/BOP B side SIAS does not actuate 2B HPSI does not start with manual SIAS 7

6 C/BOP 2A HPSI Pump becomes air bound 8

7 C/BOP 2B MSIV does not close from the Control Room during Appendix R 9

BOP Isolate 2B SG I--------.-~

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 Appendix D Scenario Outline Form ES-D-1 Facility St. Lucie Scenario No.:

3 Op Test No.:

HLC-19 NRC Examiners:

Operators:

SRO:

RO:

BOP:

Initial Conditions:

2-3 % power, BOC. 2C Charging pump OOS for repack.

Turnover: 2-3% power. BOC, 1622 PPM boron, MTC approximately '0'. 2C Charging pump OOS for repack. MFW and SBCS are in service. Vacuum has been drawn in the Condenser.

Raise power and place the Turbine on line.

.. -~... -

Critical Tasks:

Start 2B HPSI pump Block MSIS Close 2B MSIV Isolate 2B SG Event Malf.

Event Event No.

No.

Type*

Description 1

R/RO Raise Reactor power to 10-12%.

2 1

C/RO CEA # 8 slips 20 inches from current position T.S.I SRO 3

2 1/ RO H IC 1100 Spray Controller fails high 4

3 C/BOP CEDM Fan HVE-21A trips 1-'--

5A 4

T.S. SRO SGTL (10 gpm) 2B SG 58 M I All SGTR (200 gpm) 2B SG 6

5 C/BOP B side SIAS does not actuate 2B HPSI does not start with manual SIAS 7

6 C/BOP 2A HPSI Pump becomes air bound 8

7 C/BOP 2B MSIV does not close from the Control Room during Appendix R 9

BOP Isolate 2B SG (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1

Scenario Event Description NRC Scenario 3 st. Lucie The Unit is at 2-3 % power. MFW and S8CS is in service. The secondary is pressurized with main steam and a vacuum has been drawn. The crew will be instructed to increase power to 10-12% in preparation to place the Turbine on line.

During the power increase a CEA #8 will slip approximately 20 inches. The CEA can be manually retrieved. The SRO will refer to T.S. associated with the slipped CEA.

H IC 1100 Spray controller fails high requiring manual control. Pressurizer pressure will continue to lower until the crew takes manual control of spray valves.

CEDM Fan HVE-21 A will trip. The crew will start the standby CEDM fan after a wait time of 10 minutes as per the ~NP.

When the crew reaches 10-12% power a 10 gpm SGTL on the 28 SG will develop. The SRO will refer to T.S. to determine appropriate actions. The leak will get progressively worse and the crew should manually trip the unit. The leak will reach approximately 200 gpm.

As the unit depressurizes SIAS 8 side does not actuate. Manual actuation will be successful but the 28 HPSI pump does not start. It can be manually started. The 2A HPSI pump becomes air bound and will require venting to become operable.

When the 28 SG is being isolated lAW EOP-99 Appendix R, the 28 MSIV does not close from the control room. Local closure lAW EOP-99 Appendix I will be successful.

The scenario may be terminated when 2-EOP-04 Steam Generator Tube Rupture is implemented, the 2B SG is isolated and the RCS is being cooled down.

Procedures Used 2-GOP-201, Reactor Plant Startup Mode 2 to Mode 1 2-NOP-09.01, Main Feedwater System Operation 2-0110030, CEA Off-Normal Operation and Realignment 2-0120035, Pressurizer Pressure and Level 2-0NP-25.01, Loss of RCB Cooling Fans 2-0830030, Steam Generator Tube Leak 2-EOP-01, Standard Post Trip Actions 2-EOP-04, Steam Generator Tube Rupture 2-EOP-99, Appendix R 2-EOP-99, Appendix I Technical Specifications Entered 3.1.3.1 CEA Position 3.4.6.2 Operational Leakage 2 Scenario Event Description NRC Scenario 3 st. Lucie The Unit is at 2-3 % power. MFW and SBCS is in service. The secondary is pressurized with main steam and a vacuum has been drawn. The crew will be instructed to increase power to 10-12% in preparation to place the Turbine on line.

During the power increase a CEA #8 will slip approximately 20 inches. The CEA can be manually retrieved The SRO will refer to T.S. associated with the slipped CEA.

HIC 1100 Spray controller fails high requiring manual control. Pressurizer pressure will continue to lower until the crew takes manual control of spray valves.

CEDM Fan HVE-21A will trip. The crew will start the standby CEDM fan after a wait time of 10 minutes as per the ~NP.

When the crew reaches 10-12% power a 10 gpm SGTL on the 2B SG will develop. The SRO will refer to T.S. to determine appropriate actions. The leak will get progressively worse and the crew should manually trip the unit. The leak will reach approximately 200 gpm.

As the unit depressurizes SIAS B side does not actuate. Manual actuation will be successful but the 2B HPSI pump does not start. It can be manually started. The 2A HPSI pump becomes air bound and will require venting to become operable.

When the 2B SG is being isolated lAW EOP-99 Appendix R, the 2B MSIV does not close from the control room. Local closure lAW EOP-99 Appendix I will be successful.

The scenario may be terminated when 2-EOP-04 Steam Generator Tube Rupture is implemented, the 2B SG is isolated and the RCS is being cooled down.

Procedures Used 2-GOP-201, Reactor Plant Startup Mode 2 to Mode 1 2-NOP-09.01, Main Feedwater System Operation 2-0110030, CEA Off-Normal Operation and Realignment 2-0120035, Pressurizer Pressure and Level 2-0NP-25.01, Loss of RCB Cooling Fans 2-0830030, Steam Generator Tube Leak 2-EOP-01, Standard Post Trip Actions 2-EOP-04, Steam Generator Tube Rupture 2-EOP-99, Appendix R 2-EOP-99, Appendix I Technical Specifications Entered 3.1 3.1 CEA Position 3.4.6.2 Operational Leakage 2

Appendix 0 Operator Action Form ES-O-2 Op Test No.:

1 Scenario #

3 Event #

-.:... ____ Page 3 of 19 Event

Description:

Raise power to 10-12% in preparation to roll the Turbine Time Position A

licant's Actions or Behavior Booth Operator Instructions:

Initiate IC #78 and ensure 2C Charging Pump out of service I

Sign off applicable steps in 2-GOP-201 up to step 6.10 I Hand out 2*GOP-201 signed off up to step 6.10.

L-------------------------------------------~

I Indications Available:

SRO Direct power increase to 10-12% lAW 2-GOP-201 step 6.10 in preparation to roll the Turbine. (attached page_ 4_)

2-GOP-201 step 6.11, When Reactor is in Mode 1, direct i maximize SG blowdown lAW 2-NOP-23.02 Steam Generator Blowdown System Operations, (attached page_6_)

t-=--~---=--------------'

I If directed commence Dilution for power increase lAW 2 NOP RO i

02.24 step 6.5.12, 13, 14 (attached page_7_)

Withdraw CEAs in 'Manual Sequential' as directed to control Rx power.

NOTE: Power should be raised initially by CEA's. CEA's should be withdrawn to at least

, 102" prior to 20% power to meet L TSSIL BOP I

Monitor SBCS for proper operation during power increase.

When directed call Unit 1 to determine SG blowdown flow rate. 3 Appendix D Operator Action Form ES-D-2 I:P T"tNo I Event Description Scenario #

3 Event #

~

_____ Page 3

of 19 Raise power to 10-12% in preparation to roll the Turbine I! i~~~~r=~~~=r~~~~----~~~~~~~~~~~~--~~~I Time Position A

licant's Actions or Behavior I Booth Operator Instructions:

Initiate IC #78 and ensure 2C Charging Pump out of service Sign off applicable steps in 2-GOP-201 up to step 6.10 Hand out 2-GOP-201 signed off up to step 6.10.

I I Indications Available:

~-..

SRO Direct power increase to 10-12% lAW 2-GOP-201 step 6.10 in

~

preparation to roll the Turbine. (attached page_ 4_)

! 2-GOP-201 step 6.11, When Reactor is in Mode 1, direct i

maximize SG blowdown lAW 2-NOP-23.02 Steam Generator Slowdown System Operations, (attached page_6_l I

I

[ ______ j-----+--------------------___

-1 f-.

02.24 step 6.5.12,13,14 (attached page_7_)

RO i If directed commence Dilution for power increase lAW 2-NOP-I I

I Withdraw CEAs in 'Manual Sequential' as directed to control Rx I

I power.

I

~--~---~

I NOTE: Power should be raised initially by CEA's. CEA's should be withdrawn to at least

! 1 2" rior to 20% ower to meet L TSSIL

, 0 p

p

~--------------------------------~

~

I

[

I

---~-----____+---------------------------___i I

i SOP Monitor SSCS for proper operation during power i ncrease.

When directed call Unit 1 to determine SG blowdown flow rate. 3

REVISION NO.:

PROCEDURE TITLE:

PAGE:

1 __

~6..;;..0 __

~REACTOR PLANT STARTUP - MODE 2 TO MODE 1 PROCEDURE NO.:

2-GOP-201 6.8 (continued)

2.

P.

ST. LUCIE UNIT 2

( continued)

6.

Using the Single Down Arrow, CONTINUOUSLY and FULLY CLOSE LCV-9006, 2B 15% BYPASS Valve while VERIFYING FCV-9021, SG 2B FEED REG Valve OPENING and SG level being maintained at setpoint.

3.

RESTORE the AFW system to its normal standby lineup in accordance with 2-NOP-09.02, Auxiliary Feedwater System Operation.

NOTE 25 of 69 If the SBCS is already in service or Turbine startup on ADVs is desired, the next step is NOT required to be performed.

6.9

!f desired PLACE SBCS in service as follows:

1.

ENSURE the Steam Bypass Permissive switch is in the AUTO position.

2.

ENSURE all five SBCS controllers are in AUTOMATIC.

3.

NAVIGATE to the SBCS OVERVIEW screen and if the INFO TAG "COND VAC RESET REQUIRED" is on the SBCS OVERVIEW screen, Then PERFORM the following:

A.

SELECT the [COND VAC RESET] Button to bring up the COND VAC RESET Button Overlay.

B.

SELECT the [COND VAC RESET] Button and VERIFY this Button momentarily flashes from Gray to White.

C.

VERIFY the INFO TAG "COND VAC RESET REQUIRED" disappears from the screen.

4.

Slowly CLOSE the ADVs and ENSURE the SBCS valves begin to open and control RCS temperature at approximately 532°F.

6.10 When the Main Feedwater Control System and SBCS are in service, raise reactor power between 10% to 12%.

4

(

REVISION NO.:

PROCEDURE TITLE PAGE:

60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 1---...;;",;;,.------4 25 of 69 PROCEDURE NO.:

2-GOP-201 6.8 (continued)

2.

P.

ST. LUCIE UNIT 2 (continued)

6.

Using the Single Down Arrow, CONTINUOUSLY and FULLY CLOSE LCV-9006, 2B 15% BYPASS Valve while VERIFYING FCV-9021, SG 2B FEED REG Valve OPENING and SG level being maintained at setpoint.

3.

RESTORE the AFW system to its normal standby lineup in accordance with 2-NOP-09.02, Auxiliary Feedwater System Operation.

NOTE INITIAL If the SBCS is already in service or Turbine startup on ADVs is desired, the next step is NOT required to be performed.

6.9 if desired PLACE SBCS in service as follows:

1.

ENSURE the Steam Bypass Permissive switch is in the AUTO position.

2.

ENSURE all five SBCS controllers are in AUTOMATIC.

3.

NAVIGATE to the SBCS OVERVIEW screen and if the INFO TAG "COND VAC RESET REQUIRED" is on the SBCS OVERVIEW screen, Then PERFORM the following:

A.

SELECT the [COND VAC RESET] Button to bring up the COND VAC RESET Button Overlay.

B.

SELECT the [COND VAC RESET] Button and VERIFY this Button momentarily flashes from Gray to White.

C.

VERIFY the INFO TAG "COND VAC RESET REQUIRED" disappears from the screen.

4.

Slowly CLOSE the ADVs and ENSURE the SBCS valves begin to open and control RCS temperature at approximately 532°F.

6.10 When the Main Feedwater Control System and SBCS are in service, raise reactor power between 10% to 12%.

4

(

\\

REVISION NO.:

PROCEDURE TITLE:

PAGE:

60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 I--------i PROCEDURE NO.:

2-GOP-201 ST. LUCIE UNIT 2 6.11 When Reactor is in Mode 1, Then MAXIMIZE Steam Generator Blowdown per Chemistry direction. REFER to 2-NOP-23.02, Steam Generator Blowdown System Operations.

NOTE Steps 6.12 through 6.20 may be performed concurrently and/or in any order.

6.12 ENSURE Step 6.3, of this procedure is COMPLETE.

Date / Time _____

..:.../ ____ _

6.13 ENSURE the Reactor is critical and the RCS is at approximately 532°F and 2250 PSIA.

6.14 ENSURE that Steam Generators are being maintained between 60%

and 70% narrow range level.

6.15 ENSURE the DEH System is in service in accordance with 2-NOP-22.03, DEH System Operation.

6.16 ENSURE the status of the Main Generator disconnects are as follows:

1.

ENSURE 8G50, Unit 2 Generator Disconnect, is CLOSED and clear of switching clearance tags.

2.

ENSURE 8G51, Unit 2 Generator Disconnect, is CLOSED and clear of switching clearance tags.

5 26 of 69 INITIAL SRO SRO SRO SRO Switchman Switchman

(

REVISION NO.:

PROCEDURE TITLE:

PAGE:

60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 I--------------~

PROCEDURE NO..

2-GOP-201 ST. LUCIE UNIT 2 6.11 When Reactor is in Mode 1, Then MAXIMIZE Steam Generator Slowdown per Chemistry direction. REFER to 2-NOP-23.02, Steam Generator Slowdown System Operations.

NOTE Steps 6.12 through 6.20 may be performed concurrently andlor in any order.

6.12 ENSURE Step 6.3, of this procedure is COMPLETE.

Date 1 Time _____

..:../ ____ _

6.13 ENSURE the Reactor is critical and the RCS is at approximately 532°F and 2250 PSIA.

6.14 ENSURE that Steam Generators are being maintained between 60%

and 70% narrow range level.

6.15 ENSURE the DEH System is in service in accordance with 2-NOP-22.03, DEH System Operation.

6.16 ENSURE the status of the Main Generator disconnects are as follows:

1.

ENSURE 8G50, Unit 2 Generator Disconnect, is CLOSED and clear of switching clearance tags.

2.

ENSURE 8G51, Unit 2 Generator Disconnect, is CLOSED and clear of switching clearance tags.

5 26 of 69 INITIAL SRO SRO SRO SRO Switchman Switchman

REVISION NO.:

PROCEDURE TITLE:

PAGE:

13C PROCEDURE NO.:

STEAM GENERATOR BLOWDOWN SYSTEM OPERATION 19 of 39 2-NOP-23.02 ST. LUCIE UNIT 2 6.5 Adjusting Steam Generator Blowdown Flow NOTE If the respective Steam Generator Pressure Control Valve is Bypassed or in Manual, monitor and adjust as required.

CHECK High total Steam Generator Blowdown flows (in excess of 200 gpm total) may require use of two Closed Blowdown Cooling pumps to maintain Closed Blowdown outlet temperature less than 140 degrees F.

Refer to 2-NOP-34.02, Blowdown Cooling System - Closed, to start the second Closed Blowdown Cooling Pump.

1.

PERFORM the following to adjust 2A Steam Generator Blowdown Flow.

A.

If PCV-23-2 is in SERVICE, STATION an OPERATOR at PCV-23-2 to ensure pressure is maintained approximately 300 psig as indicated on PIC-23-2.

B.

If PCV-23-2 is BYPASSED, STATION an OPERATOR at V23252, PCV-23-2 Bypass, to adjust pressure to maintain approximately 300 psig as indicated on PIC-23-2.

C.

If FCV-23-12 is in AUTO, SLOWLY Adjust the setpoint on FIC-23-12 to desired flow.

D.

If FCV-23-12 is in MANUAL, SLOWLY depress the raise /

lower pushbuttons on FIC-23-12 to obtain the desired flow.

E.

If FCV-23-12 is bypassed, Then THROTTLE V23124, FCV-23-12 Bypass, as necessary to adjust flow.

2.

PERFORM the following to adjust 2B Steam Generator Blowdown Flow.

A.

If PCV-23-3 is in SERVICE, STATION an OPERATOR at PCV-23-3 to ensure pressure is maintained approximately 300 psig as indicated on PIC-23-3.

B.

If PCV-23-3 is BYPASSED, STATION an OPERATOR at V23255, PCV-23-3 Bypass, to adjust pressure to maintain approximately 300 psig as indicated on PIC-23-3.

C.

If FCV-23-14 is in AUTO, SLOWLY Adjust the setpoint on FIC-23-14 to desired flow.

6

--- --~----------

REVISION NO..

PROCEDURE TITLE:

PAGE 13C STEAM GENERATOR BLOWDOWN SYSTEM OPERATION 1 9 of 39 PROCEDURE NO.

2-NOP-23.02 ST. LUCIE UNIT 2 6.5 Adjusting Steam Generator Blowdown Flow NOTE If the respective Steam Generator Pressure Control Valve is Bypassed or in Manual, monitor and adjust as required.

CHECK High total Steam Generator Blowdown flows (in excess of 200 gpm total) may require use of two Closed Blowdown Cooling pumps to maintain Closed Blowdown outlet temperature less than 140 degrees F.

Refer to 2-NOP-34.02, Blowdown Cooling System - Closed, to start the second Closed Blowdown Cooling Pump.

1.

PERFORM the following to adjust 2A Steam Generator Blowdown Flow.

A.

If PCV-23-2 is in SERVICE, STATION an OPERATOR at PCV-23-2 to ensure pressure is maintained approximately 300 psig as indicated on PIC-23-2.

B.

If PCV-23-2 is BYPASSED, STATION an OPERATOR at V23252, PCV-23-2 Bypass, to adjust pressure to maintain approximately 300 psig as indicated on PIC-23-2.

C.

If FCV-23-12 is in AUTO, SLOWLY Adjust the setpoint on FIC-23-12 to desired flow.

D.

If FCV-23-12 is in MANUAL, SLOWLY depress the raise I lower pushbuttons on FIC-23-12 to obtain the desired flow.

E.

If FCV-23-12 is bypassed, Then THROTTLE V23124, FCV-23-12 Bypass, as necessary to adjust flow.

2.

PERFORM the following to adjust 2B Steam Generator Blowdown Flow.

A.

If PCV-23-3 is in SERVICE, STATION an OPERATOR at PCV-23-3 to ensure pressure is maintained approximately 300 psig as indicated on PIC-23-3.

B.

If PCV-23-3 is BYPASSED, STATION an OPERATOR at V23255, PCV-23-3 Bypass, to adjust pressure to maintain approximately 300 psig as indicated on PIC-23-3.

C.

If FCV-23-14 is in AUTO, SLOWLY Adjust the setpoint on FIC-23-14 to desired flow.

6

REVISION NO,:

PROCEDURE TITLE:

PAGE:

20 of 75 BORON CONCENTRATION CONTROL 24A PROCEDURE NO,:

2-NOP-02.24 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued)

CAUTION To preclude lifting the VCT relief valve while using V-2525, do NOT allow PMW flowrate to exceed the running Charging pump(s) capacity.

12.

DODD ADJUST FIC-2210X PMW Flow in AUTO or MANUAL to desired flowrate (and if using V-2525 do NOT exceed the flowrate for the number of running Charging Pumps).

13.

0 0 0 0 MAINTAIN VCT pressure less than or equal to 30 psig by opening and closing V2513, VCT Vent, as needed.

14.

0 0 0 0 !f necessary to maintain the desired VCT level, Then DIVERT the letdown flow to the Waste Management System by placing V2500, VCT Divert Valve, in the WMS position:

A.

0 0 0 0 ENSURE V2500 VCT Divert Valve indicates OPEN.

B.

0 0 DO When the desired VCT level is reached, PLACE V2500 in AUTO.

C.

0 0 0 0 ENSURE V2500 indicates CLOSED.

15.

0 0 0 0 When the desired amount of primary water has been added, Then CLOSE FCV-221 OX, Primary Makeup Water.

16.

0 0 0 0 !f V-2512 Reactor Makeup Water Stop Vlv was opened, Then PLACE V-2512 in CLOSE and ENSURE it indicates CLOSED.

17.

0 0 0 0 If V -2525 Boron Load Control Valve was opened, Then PLACE V-2525 in CLOSE and ENSURE it indicates CLOSED.

18.

DO 0 0 ENSURE FIC-2210X, PMW Flow controller is in MANUAL and RECUCE output to MINIMUM.

19.

0 0 0 0 MONITOR for any abnormal change in Tave.

20.

0 0 0 0

§1 RECORD on Data Sheet 1, Boration / Dilution Log, the number of gallons of Primary Makeup Water added as indicated on FQI-2210X, PMW Flow Totalizer.

21.

0 0 0 0 !f additional dilutions are desired, or if the expected changes to Tave or Boron concentration are NOT achieved, Then REPEAT Steps 6.5.1 through 6.5.20.

~

~----------------------------------------------------------~ t

~~~~~-----~~~-------~~~~~---~-

~-~-----

REVISION NO.:

PROCEDURE TITLE PAGE:

20 of 75 BORON CONCENTRATION CONTROL 24A PROCEDURE NO:

2-NOP-02.24 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued)

CAUTION To preclude lifting the VCT relief valve while using V-2525, do NOT allow PMW flowrate to exceed the running Charging pump(s) capacity.

12.

0 DOD ADJUST FIC-2210X PMW Flow in AUTO or MANUAL to desired flowrate (and if using V-2525 do NOT exceed the flowrate for the number of running Charging Pumps).

13.

0 DOD MAINTAIN VCT pressure less than or equal to 30 psig by opening and closing V2513, VCT Vent, as needed.

14.

0 0 0 0 if necessary to maintain the desired VCT level, Then DIVERT the letdown flow to the Waste Management System by placing V2500, VCT Divert Valve, in the WMS position:

A.

0 0 0 0 ENSURE V2500 VCT Divert Valve indicates OPEN.

B.

0 0 0 0 When the desired VCT level is reached, PLACE V2500 in AUTO.

C.

0 0 0 0 ENSURE V2500 indicates CLOSED.

15.

0 0 0 0 When the desired amount of primary water has been added, Then CLOSE FCV-221 OX, Primary Makeup Water.

16.

0 0 0 0 if V-2512 Reactor Makeup Water Stop Vlv was opened, Then PLACE V-2512 in CLOSE and ENSURE it indicates CLOSED.

17.

0 0 0 0 if V-2525 Boron Load Control Valve was opened, Then PLACE V-2525 in CLOSE and ENSURE it indicates CLOSED.

18.

0 0 DO ENSURE FIC-2210X, PMW Flow controller is in MANUAL and RECUCE output to MINIMUM.

19.

0 DOD MONITOR for any abnormal change in Tave.

20.

0 0 0 0

§1 RECORD on Data Sheet 1, Boration I Dilution Log, the number of gallons of Primary Makeup Water added as indicated on FQI-2210X, PMW Flow Totalizer.

21.

0 0 0 0 if additional dilutions are desired, or if the expected changes to Tave or Boron concentration are NOT achieved, Then REPEAT Steps 6.5.1 through 6.5.20.

REVISION NO.:

PROCEDURE TITLE:

PAGE:

60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 28 of 69 PROCEDURE NO.:

2-GOP-201 ST. LUCIE UNIT 2 "INITIAL 6.21 ENSURE the MSR tube side vents are aligned to the condenser to purge non-condensible gases as follows:

COMPONENT DESCRIPTION POSITION INITIAL V11508 2B Cndsr Vent From 2A MSR Isol OPEN V11446 2A MSR To Extr Stm Isol CLOSED V11507 2B Cndsr Vent From 2B MSR 1501 OPEN V11451 2B MSR To Extr Stm Isol CLOSED V11520 2B Cndsr Vent From 2C MSR Isol OPEN V11117 2C MSR To Extr Stm Isol CLOSED V11227 2A Cndsr From 20 MSR Tube OPEN Bundle Vent Isol V11122 20 MSR To Extr Stm 1501 CLOSED

1.

DEPRESS the Reset pushbutton on the Reheat Control Valve Panel.

2.

VERIFY locally the MSR TCVs are positioned as follows:

COMPONENT DESCRIPTION POSITION INITIAL TCV-08-1 MS to 2A MSR CLOSED TCV-08-7 MS to 2A MSR CLOSED TCV-08-3 MS to 2B MSR CLOSED TCV-08-9 MS to 2B MSR CLOSED TCV-08-4 MS to 2C MSR CLOSED TCV-08-10 MS to 2C MSR CLOSED TCV-08-2 MS to 20 MSR CLOSED TCV-08-8 MS to 20 MSR CLOSED

3.

ENSURE the manual isolation valves for the MSR TCVs are positioned as follows:

COMPONENT DESCRIPTION POSITION INITIAL V08381 TCV-08-7Isol OPEN V08370 TCV-08-7Isol OPEN V08378 TCV-08-8 Dwnstm 1501 OPEN V08382 TCV-08-8 Upstrm Isol OPEN V08383 TCV-08-9 Isol OPEN V08372 TCV-08-9 Isol OPEN V08375 TCV-08-10 Isol OPEN V08384 TCV-08-10 Isol OPEN 8

REVISION NO..

PROCEDURE TITLE:

PAGE 60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 28 of 69 PROCEDURE NO.:

2-GOP-201 ST. LUCIE UNIT 2 INITIAL 6.21 ENSURE the MSR tube side vents are aligned to the condenser to purge non-condensible gases as follows:

COMPONENT DESCRIPTION POSITION INITIAL V11508 2B Cndsr Vent From 2A MSR Isol OPEN V11446 2A MSR To Extr Stm Isol CLOSED V11507 2B Cndsr Vent From 2B MSR Isol OPEN V11451 2B MSR To Extr Stm Isol CLOSED V11520 2B Cndsr Vent From 2C MSR Isol OPEN V11117 2C MSR To Extr Stm Isol CLOSED V11227 2A Cndsr From 20 MSR Tube OPEN Bundle Vent Isol V11122 20 MSR To Extr Stm Isol CLOSED

1.

DEPRESS the Reset pushbutton on the Reheat Control Valve Panel.

(

2.

VERIFY locally the MSR TCVs are positioned as follows:

COMPONENT DESCRIPTION POSITION INITIAL TCV-08-1 MS to 2A MSR CLOSED TCV-08-7 MS to 2A MSR CLOSED TCV-08-3 MS to 2B MSR CLOSED TCV-08-9 MS to 2B MSR CLOSED TCV-08-4 MS to 2C MSR CLOSED TCV-08-10 MS to 2C MSR CLOSED TCV-08-2 MS to 20 MSR CLOSED TCV-08-8 MS to 20 MSR CLOSED

3.

ENSURE the manual isolation valves for the MSR TCVs are positioned as follows:

COMPONENT DESCRIPTION POSITION INITIAL V08381 TCV-08-7Isol OPEN V08370 TCV-08-7 Isol OPEN V08378 TCV-08-8 Dwnstm Isol OPEN V08382 TCV-08-8 Upstrm Isol OPEN V08383 TCV-08-9 Isol OPEN V08372 TCV-08-9Isol OPEN V08375 TCV-08-10Isol OPEN V08384 TCV-08-10 Isol OPEN 8

Appendix D Operator Action Form ES-D-2 I;

! I Op Test No.:

1 Scenario #

3 Event #

Page 4

of 19

~~I Event

Description:

Raise power to 10-12% in preparation to roll the Turbine Time II Position II Applicant's Actions or Behavior I Booth Operator Instructions:

Ilf NPO asked to ensure MSR tube side vents aligned to condenser (step 6.21 2*

GOP*201) state this step has been verified If Chemistry asked for SG Blowdown flow rate, state 100 gpm per SG.

If asked from SNPO state PCV*23*2 and PCV*23*3 SG blowdown PCV's are in auto.

. If Unit 1 asked for SG blowdown flow rate state 40 gpm per SG.

I Adjust SG blowdown to no more than 100 gpm per SG. lAW i

I ~

BOP 2-NOP-23.02 Steam Generator Blowdown System Operations step 6.5.1.C (2A SG). Step 6.5.2.C (2B SG) (attached page_6_)

i

~

I If directed depress RESET pushbutton on Reheat Control I

I Panel. Step 6.21.1. Notify NPO to verify locally TCV's closed.

(attached page_9_)

When Reactor power reaches 5%, make plant announcement BOP

~----.-

'Reactor is in Mode l' i

i I r----

r-I I I

1---------+-----+-------------------------1 9

(

Appendix 0 Operator Action Form ES-D-2 Scenario #

3 Event#

______ Page 4

of 19 Raise power to 10-12% in preparation to roll the Turbine A

licant's Actions or Behavior

[B ooth Operator Instructions:

I I If NPO asked to ensure MSR tube side vents aligned to condenser (step 6.21 2*

G OP*201) state this step has been verified Chemistry asked for SG Slowdown flow rate, state 100 gpm per SG.

i If Ilf asked from SNPO state PCV*23*2 and PCV*23*3 SG blowdown PCV's are in auto.

If Unit 1 asked for SG blowdown flow rate state 40 gpm per SG.

I I

I I,---.~-~

I I

~.-

I I

f-------"

I

~

i 1---.*.

~

--~-

~

~.

I I,'" --"--_..

r-~-**

I i

I,

I I

I i

I Adjust SG blowdown to no more than 100 gpm per SG. lAW BOP 2-NOP-23.02 Steam Generator Blowdown System Operations step 6.5.1.C (2A SG). Step 6.S.2.C (28 SG) (attached page_6_)

If directed depress RESET pushbutton on Reheat Control Panel. Step 6.21.1. Notify NPO to verify locally TCV's closed.

(attached page_9_)

When Reactor power reaches 5%, make plant announcement BOP

'Reactor is in Mode l' I

I I

L_. ______ ~

~

~ 9

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

3 Event #

2 Page 5

of 19

~~I Event

Description:

CEA #8 slips 20 inches from current position Time II Position II Applicant's Actions or Behavior I NOTE TO EXAMINER: Ensure power is >5% prior to initiating CEA failure.

Booth Operator Instructions:

When directed by Examiner initiate CEA #8 slip.

(CEA slips to 65")

I Indications Available: Control Room Indications Available: ADS indicates CEA slipped I Annuncaitors K-11 CEA Motion Inhibit K-30 CEA Position Deviation Motion Block (ADS)

SRO r

i I,,,

l I

~,

I T.S. SRO l--

i

~

I I

1--'

I

~----~--+-----

r------

I I

I i

1--------

I I

Recognize CEA # 8 slipped> 15" (not dropped)

Direct RO to place CEDMCS control panel in off.

Direct RO to secure dilution if initiated.

Implement 2-0110030, "CEA Off-Normal and Realignment", in the following order: Appendix D, Appendix A, and Appendix H (attached page_12-15_)

Consult Tech Spec 3.1.3.1 for CEA misalignment T.S. Action D Contact Reactor Engineering Notify SM of CEA misalignment Determines F/ from Physics curve C.3 to be 1.624 Consult COLR Figure 3.1-1 a and determines 63 minutes time to retrieve Direct RO to determine operability lAW Appendix A 2-0110030.

NOTE: step 1 of Appendix A is only step applicable.

Direct RO to realign lAW Appendix H 2-0110030 10 I

(

~.

ii Appendix 0 Operator Action Form ES-O-2 Ii Op Test No.

1 Scenario #

3 Event #

2 Page 5

of

~19'--"'1 t.Event

Description:

CEA #8 slips 20 inches from current position Time II Position II Applicant's Actions or Behavior

NOTE TO EXAMINER: Ensure power is >5% prior to initiating CEA failure.

i Booth Operator Instructions:

When directed by Examiner initiate CEA #8 slip.

k (CEA slips to 65")

Indications Available: Control Room Indications Available: ADS indicates CEA i slipped

! Annuncaitors K-11 CEA Motion Inhibit

~~~~. CEA Position Deviation Motion Block (ADS) l __.. _

I SRO Recognize CEA # 8 slipped> 15" (not dropped)

I I

.. ---... -~'------+'II -D-ir-e-c-t -R*-O-t-o-p-I-ac-e-C-E-D-M-C-S-c-o-n-trol panel i~~ff~*---*---1 i

t----i Direct RO to secure dilution if initiated.

l i Implement 2-0110030, "CEA Off*Normal and Realignment", in I

I I

the following order: Appendix D, Appendix A, and Appendix H (attached page_12-15_)

__ I TS_SRO Consult Tech Spec 3.1.3.1 for CEA misalignment T.S. Action D Contact Reactor Engineering I

I I

i Notify SM of CEA misalignment I

Determines Fe' from Physics curve C.3 to be 1.624 I---

i I

I Consult COLR Figure 3.1*1 a and determines 63 minutes time I

i I

I to retrieve i

I I

[

1=

.. - ---- [-._..

Direct RO to determine operability lAW Appendix A 2-0110030.

I NOTE: step 1 of Appendix A is only step applicable,

,,,.-.. -_.. r-[---

I Direct RO to realign lAW Appendix H 2-0110030 1--******t~-I~ __________

--.J 10

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

3 Event #

2 Page 6

of 19

--~I Event

Description:

CEA #8 slips 20 inches from current position Time II Position II Applicant's Actions or Behavior I' Booth Operator Instructions:

f**-------------------------------------j i Indications Available:

SRO When CEA realigned, direct BOP to reset DCS CEA position lAW 2-NOP-102.01 DCS Operations. (attached page_16_)

~----_r----+-----------------------~

i

~, -'

I I

i i.-------

~

I i

f-----,

i i--+

i i

~

RO Recognize CEA #8 slipped to 65" BOP Performs Immediate Operator actions of 2~011 0030, "CEA Off~

Normal and Realignment" Step 7.1.1 Place CEDMCS panel to OFF

Step 7.1.2 Not applicable Step 7.1.3 Not applicable When directed perform Appendix D (attached page_12_)

which directs implementation of Appendix A.

Determine operability lAW Appendix A (attached page_13_)

Recover CEA lAW Appendix H (attached page_14,15_)

Resume power ascension when directed Monitors SBCS to ensure operation commensurate with plant conditions.

When directed, reset CEA #8 on DCS. 2-NOP-102.01 'DCS Operations step 6.2.1' A-F. (attached page_16_) 11 I

I I

(

Appendix D

~

1 I

I Op Test No I Event Description c ____ _

I j

Position Operator Action Form ES-D-2 Scenario #

3 Event #

2 Page 6

of 19 CEA #8 slips 20 inches from current position A

licant's Actions or Behavior I Booth Operator Instructions:

Indications Available:

1 SRO When CEA realigned, direct BOP to reset DCS CEA position lAW 2-NOP-102.01 DCS Operations. (attached page_16_)

I I I

I RO Recognize CEA #8 slipped to 65" I

Periorms Immediate Operator actions of 2-0110030, "CEA Off-Normal and Realignment" Step 7.1.1 Place CEDMCS panel to OFF Step 7.1.2 Not applicable Step 7.1.3 Not applicable

--1-----1 When directed perio~m Appendix D (attached page_12_)

i which directs implementation of Appendix A.

_--== __ I

~

I I

I

------~

f---

r------ - ---y--

I I

-I BOP I

I I !----

I i l-..

i I

I

~-=t I

Determine operability lAW Appendix A (attached page_13_)

Recover CEA lAW Appendix H (attached page_14, 15_)

Resume power ascension when directed Monitors SBCS to ensure operation commensurate with plant conditions.

When directed, reset CEA #8 on DCS. 2-NOP-1 02.01 'DCS Operations step 6.2.1' A-F. 11 (attached page_16_)

i I

REVISION NO_:

PROCEDURE TITLE:

PAGE:

57A 16 of 33 PROCEDURE NO.:

CEA OFF-NORMAL OPERATION AND REALIGNMENT 2-0110030 ST. LUCIE UNIT 2 APPENDIX D ; { :

ONE CEA MISALIGNED BY GREATER THAN 15 INCHES BUT NOT A DRO'Ppl~DCEA (Page 1 of 3)

NOTE Refer to T.S. 3.1.3.1.d

1.

Ensure the following:

A.

CEDMCS panel in OFF.

B.

Turbine power adjusted to equal reactor power.

C.

CEA motion inhibit.

NOTE If in the previous 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months a dropped or slipped CEA has been successfully retrieved, upper plant management will make the decision to retrieve the CEA and continue operation.

2.

Maintain reactor power at or below, but NOT to exceed the power level which resulted from the CEA insertion.

3.

Determine from symptoms and CEA position indications, the operability of the CEA in accordance with Appendix A.

4.

During determination of the cause of the misaligned CEA, maintain reactor power at or below, but NOT to exceed the power level which resulted from the CEA insertion.

5.

If CEA determined to be inoperable for any reason, refer to Appendix B.

NOTE If difficulty is experienced in CEA realignment, a power reduction to less than or equal to 70% rated thermal power should be initiated.

6.

If in Mode 3, realign the CEA in accordance with Appendix H and proceed to Step 7.

7.

J.f in Modes 1 and 2, Then refer to plant curve book and obtain the most recent F\\ value. This value, when interpreted on the technical specification Fig. 3.1-1a, will indicate the amount of time to restore the CEA within 7 inches of all other CEAs in its group.

A.

Within the time allowed by Technical Specification COLR Fig. 3.1-1a, restore the CEA (per Appendix H) to within 7 inches of all other CEAs in its group.

12

- --------.-.. -~~-~--.---------------- -------------------~.

REVISION NO..

PROCEDURE TITLE:

PAGE:

57A 16 of 33 PROCEDURE NO:

CEA OFF-NORMAL OPERATION AND REALIGNMENT 2-0110030 ST. LUCIE UNIT 2 APPENDIX D ONE CEA MISALIGNED BY GREATER THAN 15 INCHES BUT NOT A DROPPED CEA (Page 1 of 3)

NOTE RefertoT.S.3.1.3.1.d

1.

Ensure the following:

A.

CEDMCS panel in OFF.

B.

Turbine power adjusted to equal reactor power.

C.

CEA motion inhibit.

NOTE If in the previous 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months a dropped or slipped CEA has been successfully retrieved, upper plant management will make the decision to retrieve the CEA and continue operation.

2.

Maintain reactor power at or below, but NOT to exceed the power level which resulted from the CEA insertion.

3.

Determine from symptoms and CEA position indications, the operability of the CEA in accordance with Appendix A.

4.

During determination of the cause of the misaligned CEA, maintain reactor power at or below, but NOT to exceed the power level which resulted from the CEA insertion.

5.

If CEA determined to be inoperable for any reason, refer to Appendix B.

NOTE If difficulty is experienced in CEA realignment, a power reduction to less than or equal to 70% rated thermal power should be initiated.

6.

If in Mode 3, realign the CEA in accordance with Appendix H and proceed to Step 7.

7.

A.

If in Modes 1 and 2, Then refer to plant curve book and obtain the most recent FT R value. This value, when interpreted on the technical specification Fig. 3.1-1 a, will indicate the amount of time to restore the CEA within 7 inches of all other CEAs in its group.

Within the time allowed by Technical Specification COLR Fig. 3.1-1a, restore the CEA (per Appendix H) to within 7 inches of all other CEAs in its group.

12

REVISION NO.:

57A PROCEDURE NO.:

2-0110030 PROCEDURE TITLE:

CEA OFF-NORMAL OPERATION AND REALIGNMENT ST. LUCIE UNIT 2 APPENDIX A CEA INVESTIGATION FOR OPERABILITY (Page 1 of 3)

CAUTION PAGE:

Reactor Power shall NOT be increased above the stable power level established following the CEA(s) misalignment.

Criticality shall be anticipated any time CEAs are being withdrawn.

1.

For the affected CEA(s), perform the following to determine operability:

A.

Place the mode select switch in the manual individual mode.

B.

Select the affected CEA on the individual CEA selection switches.

C.

Select the group of the affected CEA on the group select switch.

D.

!f CEA motion inhibit is present, Then:

9 of 33

1.

Depress and hold the CEA motion inhibit bypass pushbutton.

2.

Depress then release the bypass enable pushbutton.

E.

!f the CEA was dropped, Then first withdraw the affected CEA until core mimic CEA bottom light and lower electrical limit lights both deenergize.

CAUTION Do NOT exceed +/- 10 inches of the original position without permission from the US.

F.

Insert and withdraw the affected CEA and check for smooth operation and normal indications.

G.

If CEA is determined to be operable proceed to the applicable appendix for CEA realignment.

13

(

~--------------------------------------------------

REVISION NO.

57A PROCEDURE NO..

2-0110030 PROCEDURE TITLE:

CEA OFF-NORMAL OPERATION AND REALIGNMENT ST. LUCIE UNIT 2 APPENDIX A CEA INVESTIGATION FOR OPERABILITY (Page 1 of 3)

CAUTION PAGE:

Reactor Power shall NOT be increased above the stable power level established following the CEA(s) misalignment.

Criticality shall be anticipated any time CEAs are being withdrawn.

1.

For the affected CEA(s), perform the following to determine operability:

A.

Place the mode select switch in the manual individual mode.

B.

Select the affected CEA on the individual CEA selection switches.

C.

Select the group of the affected CEA on the group select switch.

D.

11 CEA motion inhibit is present, Then:

9 of 33

1.

Depress and hold the CEA motion inhibit bypass pushbutton.

2.

Depress then release the bypass enable pushbutton.

E.

11 the CEA was dropped, Then first withdraw the affected CEA until core mimic CEA bottom light and lower electrical limit lights both deenergize.

CAUTION Do NOT exceed +/- 10 inches of the original position without permission from the US.

F.

Insert and withdraw the affected CEA and check for smooth operation and normal indications.

G.

If CEA is determined to be operable proceed to the applicable appendix for CEA realignment.

13

REVISION NO.:

57A PROCEDURE NO.:

2-0110030 PROCEDURE TITLE:

CEA OFF-NORMAL OPERATION AND REALIGNMENT ST. LUCIE UNIT 2 APPENDIX H CEA REALIGNMENT (MODES 1! 2 AND 3)

(Page 1 of 2)

1.

While realigning CEAs, observe the following:

PAGE:

"24 of 33 A.

Regulating CEAs shall be withdrawn in sequence and overlap between groups shall NOT exceed 54 inches.

B.

Do NOT exceed a sustained SUR of 1.4 DPM (alarm 1.3 DPM).

C.

Criticality shall be anticipated any time CEAs are being withdrawn.

D.

If deviation between CEAs in any group approaches 3 inches, stop group withdrawal and realign CEAs.

E.

While CEA is misaligned, individual CEA positions within the group shall be determined at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months except when the CEA position deviation circuit is out of service, then verify CEA positions at least once every four hours.

2.

Misaligned CEA(s) while in Modes 2 and 3 (subcritical).

A.

Place the mode select switch in the manual individual mode.

B.

Select the misaligned CEA on the individual CEA selection switches.

C.

Select the group of the misaligned CEA on the group select switch.

D.

!f CEA motion inhibit is present then:

1.

Depress and hold the CEA motion inhibit bypass pushbutton.

2.

Depress then release the bypass enable pushbutton.

E.

REALIGN the CEA by performing ONE of the following:

INSERT the remainder of the group to the misaligned CEA and then withdraw the group to the pre-misaligned position.

ALIGN the misaligned CEA to the remainder of the group.

F.

Check the position of all CEAs in the group for proper alignment (CEDMCS and DCS).

14 REVISION NO.:

PROCEDURE TITLE:

PAGE:

57A PROCEDURE NO..

2-0110030 CEA OFF-NORMAL OPERATION AND REALIGNMENT ST. LUCIE UNIT 2 APPENDIX H CEA REALIGNMENT (MODES 1: 2 AND 3)

(Page 1 of 2)

1.

While realigning CEAs, observe the following:

24 of 33 A.

Regulating CEAs shall be withdrawn in sequence and overlap between groups shall NOT exceed 54 inches.

B.

Do NOT exceed a sustained SUR of 1.4 DPM (alarm 1.3 DPM).

C.

Criticality shall be anticipated any time CEAs are being withdrawn.

D.

If deviation between CEAs in any group approaches 3 inches, stop group withdrawal and realign CEAs.

E.

While CEA is misaligned, individual CEA positions within the group shall be determined at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months except when the CEA position deviation circuit is out of service, then verify CEA positions at least once every four hours.

2.

Misaligned CEA(s) while in Modes 2 and 3 (subcritical).

A.

Place the mode select switch in the manual individual mode.

B.

Select the misaligned CEA on the individual CEA selection switches.

C.

Select the group of the misaligned CEA on the group select switch.

D.

If CEA motion inhibit is present then:

1.

Depress and hold the CEA motion inhibit bypass pushbutton.

2.

Depress then release the bypass enable pushbutton.

E.

REALIGN the CEA by performing ONE of the following:

INSERT the remainder of the group to the misaligned CEA and then withdraw the group to the pre-misaligned position.

ALIGN the misaligned CEA to the remainder of the group.

F.

Check the position of all CEAs in the group for proper alignment (CEDMCS and DCS).

14

REVISION NO.:

57A PROCEDURE NO.:

2-0110030 PROCEDURE TITLE:

CEA OFF-NORMAL OPERATION AND REALIGNMENT ST. LUCIE UNIT 2 APPENDIX H CEA REALIGNMENT (MODES 1! 2 AND 3)

(Page 2 of 2)

3.

Misaligned CEA(s) while in Modes 1 and 2 (critical).

CAUTION Reactor Power shall NOT be increased above the stable power level established following the CEA(s) misalignment.

25 of 33 A.

Prior to realigning of CEA, contact Reactor Engineering and supply them with the following information.

1.

Power level at which recovery is to be made.

2.

Rate of CEA movement during recovery.

3, Movement of other CEAs to support recovery.

B.

Place the mode select switch in the manual individual mode.

C.

Select the misaligned CEA on the individual CEA selection switches.

D.

Select the group of the misaligned CEA on the group select switch.

E.

If CEA motion inhibit is present, Then:

1.

Depress and hold the CEA motion inhibit bypass pushbutton.

2.

Depress then release the bypass enable pushbutton.

F.

Realign CEA to the group position while borating as necessary to maintain Reactor Power at or below the power level which resulted from the CEA insertion.

G.

Check the position of all CEAs in the group for proper alignment (CEDMCS and DCS).

H.

Using manual group mode, readjust the group positions for proper automatic sequencing as necessary.

END OF APPENDIX H 15

(

REVISION NO.:

PROCEDURE TITLE:

PAGE:

57A CEA OFF-NORMAL OPERATION AND REALIGNMENT 25 of 33 PROCEDURE NO..

2-0110030 ST. LUCIE UNIT 2 APPENDIX H CEA REALIGNMENT (MODES 1, 2 AND 3)

(Page 2 of 2)

3.

Misaligned CEA(s) while in Modes 1 and 2 (critical).

CAUTION Reactor Power shall NOT be increased above the stable power level established following the CEA(s) misalignment.

A.

Prior to realigning of CEA, contact Reactor Engineering and supply them with the following information.

1.

Power level at which recovery is to be made.

2.

Rate of CEA movement during recovery.

3.

Movement of other CEAs to support recovery.

B.

Place the mode select switch in the manual individual mode.

C.

Select the misaligned CEA on the individual CEA selection switches.

D.

Select the group of the misaligned CEA on the group select switch.

E.

Jl CEA motion inhibit is present, Then:

1.

Depress and hold the CEA motion inhibit bypass pushbutton.

2.

Depress then release the bypass enable pushbutton.

F.

Realign CEA to the group position while borating as necessary to maintain Reactor Power at or below the power level which resulted from the CEA insertion.

G.

Check the position of all CEAs in the group for proper alignment (CEDMCS and DCS).

H.

Using manual group mode, readjust the group positions for proper automatic sequencing as necessary.

END OF APPENDIX H 15

REVISION NO.:

PROCEDURE TITLE:

PAGE:

8 of 81 8A DISTRIBUTED CONTROL SYSTEM (DCS) -

PROCEDURE NO.:

OPERATIONS 2-NOP-102.01 ST. LUCIE UNIT 2 6.2 Changing CEA Positions

1.

Changing Individual CEA Positions A.

From the Main Menu, SELECT the CEA Group that contains the individual CEA to be changed.

B.

SELECT the Realign button located at the bottom of the screen.

C.

SELECT the input box located just right of the current CEA position value.

D.

ENTER the new CEA position in the input box and press the enter key.

E.

SELECT the Adjust button and verify that the CEA Position value has changed to the new value.

F.

SELECT Close to return to the CEA group screen

2.

Changing all CEA positions in a single group A.

From the Main Menu, SELECT the CEA Group to be changed.

B.

SELECT the Realign button located at the bottom of the screen.

C.

SELECT the input box located at the bottom of the screen.

D.

ENTER the new CEA position in the input box and PRESS the Enter key.

E.

SELECT the Adjust All This Group button.

F.

VERIFY that the all of the CEA Position values have changed to the new value.

G.

SELECT Close to return to the CEA group screen.

END OF SECTION 6.2 16

(

REVISION NO.:

8A PROCEDURE NO..

PROCEDURE TITLE DISTRIBUTED CONTROL SYSTEM (DCS) -

OPERATIONS PAGE:

8 of 81 2-NOP-102.01 ST. LUCIE UNIT 2 6.2 Changing CEA Positions

1.

Changing Individual CEA Positions A.

From the Main Menu, SELECT the CEA Group that contains the individual CEA to be changed.

B.

SELECT the Realign button located at the bottom of the screen.

C.

SELECT the input box located just right of the current CEA position value.

D.

ENTER the new CEA position in the input box and press the enter key.

E.

SELECT the Adjust button and verify that the CEA Position value has changed to the new value.

F.

SELECT Close to return to the CEA group screen

2.

Changing all CEA positions in a single group A.

From the Main Menu, SELECT the CEA Group to be changed.

B.

SELECT the Realign button located at the bottom of the screen.

C.

SELECT the input box located at the bottom of the screen.

D.

ENTER the new CEA position in the input box and PRESS the Enter key.

E.

SELECT the Adjust All This Group button.

F.

VERIFY that the all of the CEA Position values have changed to the new value.

G.

SELECT Close to return to the CEA group screen.

END OF SECTION 6.2 16

.- ------------.---.---------------------------~

Appendix D Operator Action Form ES-D-2

. Op Test No..

1 Scenario #

3 Event #

-.;...3 _____ Page 7

of 19 Event

Description:

HIC 1100 Spray Controller fails high Time II Position II Applicant's Actions or Behavior

Booth Operator Instructions:

When directed by examiner initiate Hie 1100 Fails High.

i Indications Available: Pressurizer pressure lowering, both spray valves indicate I

full open.

I c-----

i r----...

I I,---

I I

i i

I I

I I f--

~--

~

I-I I

i I

r--

I i

I I,-_

I r----.... ---.

t-

[

SRO RO I

I Recognizes pressurizer pressure trending down / main spray valves fully open Directs RO to take manual control of HIC-11 00 Refers to 2-0120035, "Pressurizer Pressure and Level" step 7.2.1. A.3 (attached page_18, 19_) Direct spray controller operated in manual.

May direct hold on power increase (if still in progress)

Directs RO to control RCS pressure by energizing additional heaters, if available and manual control of spray valves.

Notifies SM and I&C of event Refers to Tech Spec 3.2.5 (DNB) if pressure <2225 psia.

Restore within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Recognizes pressurizer pressure trending down / main spray valves fully open i Secures dilution if directed by SRO (if still in progress)

I I Places HIC 1100 in manual as per step 7.2.1.A.3 17 I

I :

i I

Appendix 0

i ----------

Op Test No.

Scenario #

3 Operator Action Form ES-O-2 Event #

--,-3 _____ Page 7

of 19 II Event DesCription:

HIC 1100 Spray Controller fails high 1-L __ Tlrrle Position Applicant's Actions or Behavior Booth Operator Instructions:

When directed by examiner initiate Hie 1100 Fails High.

r---~-------- ---------------------------------j i Indications Available: Pressurizer pressure lowering, both spray valves indicate

full open.

SRO I

Recognizes pressurizer pressure trending down I main spray

. valves fully open

, r-I I \\--_.

L_

I I

! i I

-+---

I

-t i

I Directs RO to take manual control of HIC-11 00 I

I Refers to 2-0120035, "Pressurizer Pressure and Level" step 7.2.1. A.3 (attached page_18, 19_) Direct spray controller operated in manual.

i May direct hold on power increase (if still in progress)

I i

Directs RO to control RCS pressure by energizing additional heaters, if available and manual control of spray valves.

I I

~----~-----+I-N-o-ti-fi-es-S-M-a-n-d-I&--C-O-f-e-v-e-n-t---------------------~

f------+ ~~~__+I~~~~-----------------~~----i f-I i

r

"-TRO

+-

I i

t-----*

~---.. -- -

I Refers to Tech Spec 3.2.5 (DNB) if pressure <2225 psia.

Restore within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Recognizes pressurizer pressure trending down I main spray valves fully open

! Secures dilution if directed by SRO (if still in progress)

Places HIC 1100 in manual as per step 7.2.1.A.3

~ 17

REVISION NO:

PROCEDURE TITLE:

PAGE:,

~5 of 15 PRESSURIZER PRESSURE AND LEVEL 26 PROCEDURE NO.:

2-0120035 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions

1.

None 7.2 Subsequent Operator Actions INSTRUCTIONS CONTINGENCY ACTIONS NOTE Technical Specifications 3.3.3.5, Remote Shutdown System Instrumentation, and 3.3.3.6, Accident Monitoring Instrumentation, are applicable for Pressurizer Level and Pressure Instrumentation ma Ifu n ctions.

If SIAS has actuated, SIAS must be RESET before Pressurizer Heaters can be energized.

1.

ABNORMAL PRESSURIZER PRESSURE CONDITION NOTE

1.

Appendix "A" contains a listing of pressurizer pressures which are associated with automatic actions.

A. Verify pressurizer spray, proportional and back-up heaters are operating properly in automatic. Refer to Appendix "A" for expected automatic responses.

18 A. !f system is NOT operating properly in automatic, Then perform the following as necessary:

1. !f selected pressure channel has failed, Then shift to the operable pressure channel.

2. !f selected pressure channel has failed high (greater than 2340 psia),

Then after selecting the operable channel, reset heater control switches on RTGB 203.

(

REVISION NO.

PROCEDURE TITLE PAGE:.

26 PRESSURIZER PRESSURE AND LEVEL 5 of 15 PROCEDURE NO.:

2-0120035 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions

1.

None 7.2 Subsequent Operator Actions

1.

INSTRUCTIONS CONTINGENCY ACTIONS NOTE Technical Specifications 3.3.3.5, Remote Shutdown System Instrumentation, and 3.3.3.6, Accident Monitoring Instrumentation, are applicable for Pressurizer Level and Pressure Instrumentation malfunctions.

If SIAS has actuated, SIAS must be RESET before Pressurizer Heaters can be energized.

ABNORMAL PRESSURIZER PRESSURE CONDITION NOTE

1.

Appendix "A" contains a listing of pressurizer pressures which are associated with automatic actions.

A. Verify pressurizer spray, proportional and back-up heaters are operating properly in automatic. Refer to Appendix "AI! for expected automatic responses.

18 A. 11 system is NOT operating properly in automatic, Then perform the following as necessary:

1. 11 selected pressure channel has failed, Then shift to the operable pressure channel.

2. 11 selected pressure channel has failed high (greater than 2340 psia),

Then after selecting the operable channel, reset heater control switches on RTGB 203.

REVISION NO.:

PROCEDURE TITLE:

PAGE:

26 PROCEDURE NO.:

PRESSURIZER PRESSURE AND LEVEL

. 6 of 15 2-0120035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS

1.

A. (continued)

NOTE CONTINGENCY ACTIONS

1.

A. (continued)

3. !f both pressure channels are failed or automatic pressure control does NOT operate properly, Then operate spray controller in manual and energize or deenergize heaters as necessary.

Divergence of Spray Line Temperatures between 2B1 and 2B2 Spray lines may indicate a stuck open spray valve. The stuck open spray valve would have the spray line with the higher temperature approaching cold leg temperature.

B. Verify PCV 11 OOE, Spray Valve 2B2, and PCV 11 OOF, Spray Valve 2B1, CLOSED by observing BOTH of the following:

1. CLOSED valve position indication.

2. TIA-1103, Spray Line 2B1 Temperature, and TIA-11 04, Spray Line 2B2 Temperature, approximately equal.

19 B. !f either spray valve is OPEN, Then perform the following:

1. !f PCV 11 OOE, Spray Valve 2B2, is OPEN, Then PLACE the spray valve selector switch in PCV 1100F.

2. !f PCV 11 OOF, Spray Valve 2B1, is OPEN, Then PLACE the spray valve selector switch in PCV 1100E.

(

REVISION NO.

PROCEDURE TITLE:

PAGE:

26 PRESSURIZER PRESSURE AND LEVEL 6 of 15 PROCEDURE NO..

2-0120035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

1.

INSTRUCTIONS A.

(continued)

NOTE CONTINGENCY ACTIONS

1.

A. (continued)

3. If both pressure channels are failed or automatic pressure control does NOT operate properly, Then operate spray controller in manual and energize or deenergize heaters as necessary.

Divergence of Spray Line Temperatures between 281 and 282 Spray lines may indicate a stuck open spray valve. The stuck open spray valve would have the spray line with the higher temperature approaching cold leg temperature.

B. Verify PCV 11 OOE, Spray Valve 2B2, and PCV 11 OOF, Spray Valve 281, CLOSED by observing BOTH of the following:

1. CLOSED valve position indication.

2. TIA-1103, Spray Line 281 Temperature, and TIA-11 04, Spray Line 282 Temperature, approximately equal.

19 B. !! either spray valve is OPEN, Then perform the following:

1. !! PCV 11 OOE, Spray Valve 282, is OPEN, Then PLACE the spray valve selector switch in PCV 11 OOF.

2. !! PCV 11 OOF, Spray Valve 281, is OPEN, Then PLACE the spray valve selector switch in PCV 1100E.

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

3 Event #

4 Page 8

of 19

~~I Event

Description:

CEDM fan HVE-21A trips Ii II Time II Position II Applicant's Actions or Behavior I

i NOTE TO EXAMINER: Consider initiating SGTL, event SA, at this time.

I Booth Operator Instructions:

When directed by examiner initiate CEDM fan HVE-21A trip When directed by examiner initiate SGTL (10 gpm)

When asked the status of Brk. 2-20205 state the breaker is tripped, overcurrent flag dropped.

Indications Available: Annunciators:

X-2 CEDM Cooling air temp high

X-8 CEDM Cooling HVE-21A flow low I Ovrld I Trip Amp meter for HVE 21A indicate '0' SRO

~.

I t--_* J L-.------

i I

I I

I 1

.. ~-,..

I

~-i BOP I

i I

t-------

I

~

Recognize CEDM fan HVE-21A tripped. Implement 2-0NP-25.01 'Loss Of RCB Cooling Fans'. (attached page_21-23_)

After approximately 10 minutes from time of trip directs HVE-21B started. Step 6.1.1 (attached page_21_)

Verify operability of tripped CEDM cooling fan. Perform Appendix A (attached page_24_). Directs Brk. 2-20205 status determined.

Notifies Shift Manager Recognize CEDM fan HVE-21A has tripped.

Starts standby CEDM fan HVE-21 B when directed.

I Notifies SNPO to investigate status of Brk 2-20205 lAW Appendix A (attached page_24_) 20 i

I

{

----------- ------ ---------------~ ------------------

Appendix D Operator Action Form ES-D-2

~op T", No 1

I, Event Description Scenario #

Event #

3

-.;..4 _____ Page 8

of CEDM fan HVE-21A trips 19 L Position Ap licant's Actions or Behavior

NOTE TO EXAMINER: Consider initiating SGTL, event 5A, at this time.

I Booth Operator Instructions:

I When directed by examiner initiate CEDM fan HVE-21A trip When directed by examiner initiate SGTL (10 gpm)

When asked the status of Brk. 2-20205 state the breaker is tripped, overcurrent I flag dropped.

! Indications Available: Annunciators:

X-2 CEDM Cooling air temp high X-8 CEDM Cooling HVE-21A flow low I Ovrld I Trip

Am p meter for HVE 21 A indicate '0' f--

I I Recognize CEDM fan HVE-21A tripped. Implement 2-0NP-SRO 25_01 'Loss Of RCB Cooling Fans'. (attached page_21-23_)

1----------+-----+------------------------------1 I

I r----

I After approximately 10 minutes from time of trip directs HVE-I i

21B started. Step 6_1.1 (attached page_21_l

-+--------

I I

I 1------

i*

I I

Verify operability of tripped CEDM cooling fan. Perform I

I Appendix A (attached page_24_l-Directs Brk. 2-20205 status determined.

._-t-,

[

I I

Notifies Shift Manager I

I I

BOP Recognize CEDM fan HVE-21A has tripped.

~

1-----------

Starts standby CEDM fan HVE-21B when directed.

i I

, Notifies SNPO to investigate status of Brk 2-20205IAW==j t-=-~--!-

I Appendix A (attached page_24_1 II

~I-----+-----------------------~

i~' __

.1 20

REVISION NO.:

PROCEDURE TITLE:

PAGE:

6 of 19 LOSS OF RCB COOLING FANS 3

PROCEDURE NO.:

2-0NP-25.01 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS 6.1 Loss of CEDM Cooling Fan INSTRUCTIONS CONTINGENCY ACTIONS CAUTION

§1,2 At least one CEDM Cooling Fan (HVE-21A or HVE-21 B) must be in operation to maintain the reactor vessel support structure within design basis. Operator action is required within 45 minutes, to restore a CEDM Cooling Fan to operation or initiate reactor trip and cooldown to at least Hot Shutdown. The total time from the loss of CEDM Cooling Fan to Hot Shutdown is 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months .

To ensure motor is not started while rotating in reverse, a time delay of approximately 10 minutes shall be observed before starting a CEDM Cooling Fan.

1. After approximately 10 minutes from time of trip, START the standby CEDM Cooling Fan.

21

1. If the standby fan does NOT start, Then PERFORM the following:

A. PERFORM Appendix A, CEDM Cooling Fan Local Breaker Operations.

B. ATTEMPT one start of any available CEDM Cooling Fan.

C. INITIATE a rapid shutdown using 2-0NP-22.01, Rapid Downpower.

(

REVISION NO..

PROCEDURE TITLE:

PAGE:

6 of 19 LOSS OF RCB COOLING FANS 3

PROCEDURE NO.

2-0NP-25.01 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS 6.1 Loss of CEDM Cooling Fan INSTRUCTIONS CONTINGENCY ACTIONS CAUTION

§1,2 At least one CEDM Cooling Fan (HVE-21A or HVE-21 B) must be in operation to maintain the reactor vessel support structure within design basis. Operator action is required within 45 minutes, to restore a CEDM Cooling Fan to operation or initiate reactor trip and cooldown to at least Hot Shutdown. The total time from the loss of CEDM Cooling Fan to Hot Shutdown is 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months .

To ensure motor is not started while rotating in reverse, a time delay of approximately 10 minutes shall be observed before starting a CEDM Cooling Fan.

1.

After approximately 10 minutes from time of trip, START the standby CEDM Cooling Fan.

21

1.

11 the standby fan does NOT start, Then PERFORM the following:

A. PERFORM Appendix A, CEDM Cooling Fan Local Breaker Operations.

B. ATTEMPT one start of any available CEDM Cooling Fan.

C. INITIATE a rapid shutdown using 2-0NP-22.01, Rapid Downpower.

REVISION NO.:

PROCEDURE TITLE:

PAGE:....* :* '.:"

3 PROCEDURE NO.:

LOSS OF RCB COOLING FANS 7 of 19, 2-0NP-25.01 ST. LUCIE UNIT 2 6.1 Loss of CEDM Cooling Fan (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

1. (continued)

D. !f at least one fan does NOT start, Then NOTIFY the following:

Maintenance Supervisor EM E. §1,2 !f at least one CEDM Cooling Fan is NOT operating within 45 minutes of fan trip, Then PERFORM the following:

1. TRIP the reactor.

2.

TRIP the turbine.

3.

IMPLEMENT 2-EOP-01, Standard Post Trip Actions.

4.

COOL DOWN to at least Hot Shutdown within 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months from the loss of the fan in accordance with 2-GOP-305, Reactor Plant Cooldown - Hot Standby to Cold Shutdown.

22 REVISION NO.:

PROCEDURE TITLE:

PAGE:

3 LOSS OF RCB COOLING FANS 7 of 19 PROCEDURE NO 2-0NP-25.01 ST. LUCIE UNIT 2 6.1 Loss of CEDM Cooling Fan (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

1. (continued)

D.

11 at least one fan does NOT start, Then NOTIFY the following:

Maintenance Supervisor EM E.

§1,2 11 at least one CEDM Cooling Fan is NOT operating within 45 minutes of fan trip, Then PERFORM the following:

1.

TRIP the reactor.

2.

TRIP the turbine.

3.

IMPLEMENT 2-EOP-01, Standard Post Trip Actions.

4.

COOL DOWN to at least Hot Shutdown within 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months from the loss of the fan in accordance with 2-GOP-305, Reactor Plant Cooldown - Hot Standby to Cold Shutdown.

(

22

REVISION NO.:

PROCEDURE TITLE:

PAGE:

>8 of 19...

LOSS OF RCB COOLING FANS 3

PROCEDURE NO.:

2-0NP-25.01 ST. LUCIE UNIT 2 6.1 Loss of CEDM Cooling Fan (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

2.

VERIFY operability of the tripped CEDM Cooling Fan as follows:

A. PERFORM Appendix A, CEDM Cooling Fan Local Breaker Operations.

B. DETERMINE operability of the tripped fan.

C. !f the fan is inoperable, Then NOTIFY the SM/US.

END OF SECTION 6.1 23

(

REVISION NO..

PROCEDURE TITLE PAGE:

3 PROCEDURE NO..

LOSS OF RCB COOLING FANS

'8 of 19 2-0NP-25.01 ST. LUCIE UNIT 2 6.1 Loss of CEDM Cooling Fan (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

2.

VERIFY operability of the tripped CEDM Cooling Fan as follows:

A. PERFORM Appendix A, CEDM Cooling Fan Local Breaker Operations.

B. DETERMINE operability of the tripped fan.

C. 11 the fan is inoperable, Then NOTIFY the SM/US.

END OF SECTION 6.1 23

REVISION NO.:

3 PROCEDURE NO,:

2-0NP-25,01 PROCEDURE TITLE:

LOSS OF RCB COOLING FANS ST. LUCIE UNIT 2 APPENDIX A CEDM COOLING FAN LOCAL BREAKER OPERATIONS (Page 1 of 1)

1.

VERIFY electrical alignment of BOTH fans, as follows:

PAGE:

16 of 19 INITIAL A.

Bkr 2-20205, CEDM Cooling Fan HVE-21 A, on 4.16 KV Swgr 2A3:

RACKED IN Relay targets indicate normal status B.

Bkr 2-20408, CEDM Cooling Fan HVE-21 B, on 4.16 KV Swgr 2B3:

RACKED IN Relay targets indicate normal status

2.

ENSURE fuses are checked and replaced as necessary.

3.

NOTIFY the Control Room of breaker status.

4.

If any breaker is TRIPPED, Then IMPLEMENT OP 1250020, Valve, Breaker, Motor and Instrument Instructions.

END OF APPENDIX A 24

(

\\

REVISION NO..

3 PROCEDURE NO..

2-0NP-25.01 PROCEDURE TITLE LOSS OF RCB COOLING FANS ST. LUCIE UNIT 2 APPENDIX A CEDM COOLING FAN LOCAL BREAKER OPERATIONS (Page 1 of 1)

1.

VERIFY electrical alignment of BOTH fans, as follows:

PAGE:

16 of 19 INITIAL A.

Bkr 2-20205, CEDM Cooling Fan HVE-21 A, on 4.16 KV Swgr 2A3:

2.

3.

4.

RACKED IN Relay targets indicate normal status B.

Bkr 2-20408, CEDM Cooling Fan HVE-21 B, on 4.16 KV Swgr 2B3:

RACKED IN Relay targets indicate normal status ENSURE fuses are checked and replaced as necessary.

NOTIFY the Control Room of breaker status.

!f any breaker is TRIPPED, Then IMPLEMENT OP 1250020, Valve, Breaker, Motor and Instrument Instructions.

END OF APPENDIX A 24

Appendix D Operator Action Form ES-D-2 rO;Test No.:

Ii Scenario #

3 Event #

5A Page 9

of 19

i

. Event

Description:

SGTL 10 gpm.

Time Position A plicant's Actions or Behavior Sooth Operator Instructions:

If not previously initiated and when directed by examiner initiate SGTL (10 gpm)

Indications Available: Charging and letdown mismatch.

PC*11 SJAE trending up and eventual alarm PC*11 Slowdown trending up (10*15 minutes after SJAE)

-.-~-.-~~---

SRO Recognize Steam generator tube leak occurring on 2B SG

.--....... -j-------f------------------.----.. ----j SJAE alarm on PC-11 2B SG Blowdown radiation trending up Mismatch Chg / Letdown May refer to 2-0120031 Excessive RCS Leakage if I

Charging and Letdown mismatch identified prior to L ___.-+-____ +-___

S_J_A_E_ra_d_ia_t_io_n_a.la._rm_. ___________

j f-----

I,

I I

i i

i t-i i

T.S. SRO I

Implement 2-0830030, "Steam Generator Tube Leak" Implement Appendix A (attached page_27-39) and refer:

to Figure 2 (attached page 40 )

I Directs or Brief if leak becomes >capacity of charging pumps we will manually trip reactor Estimate primary to secondary leakage using daily chemistry report.

Contact HP and inform of present plant conditions, conduct secondary surveys Direct Chemistry to implement COP-06.05 High activity in a SG Step 11, Consider isolating U-1 Vacuum drag Step 12 Verify SGBD not aligned to Discharge Canal Direct field operators to perform step 13, 17, 18, 19 and 20 of Appendix A (attached page_36-38_).

Determine T.S. 3.4.6.2. c (Action a) HSB within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Contact Chemistry for secondary sampling 25

(

I

\\

AppendIx D r-

---~.

II Op Test No

,I Scenario #

3 SGTL 10 gpm.

Operator Action Form ES-D-2 Event #

SA Page 9

of 19 I

i Even.t Description l~*~*~~~=~~ ____ =~=~~~~= ____

=---II C'Gme.

PCl.sition A plicant's Actions or Behavior i Sooth Operator Instructions:

l If not previously initiated and when directed by examiner initiate SGTL (10 gpm)

! Indications Available: Charging and letdown mismatch.

I

PC-11 SJAE trending up and eventual alarm i

! PC-11 Slowdown trending up (10*15 minutes after SJAE)

I I

I

.. 1 SRO

Recognize Steam generator tube leak occurring 0~~~~

___ 1 i

I. SJAE alarm on PC-11 I

i L--... +-

2B SG Blowdown radiation trending up i

Mismatch Chg / Letdown May refer to 2-0120031 Excessive RCS Leakage if Charging and Letdown mismatch identified prior to SJAE radiation alarm.

r-~----- ---.-----+-----.-----~------------------------_i T.S. SRO i

1--.

i Implement 2-0830030, "Steam Generator Tube Leak" Implement Appendix A (attached page_27-39) and refer to Figure 2 (attached page_ 40_)

Directs or Brief if leak becomes >capacity of charging pumps we will manually trip reactor Estimate primary to secondary leakage using daily chemistry report.

Contact HP and inform of present plant conditions, conduct secondary surveys Direct Chemistry to implement COP-06.05 High activity in a SG Step 11, Consider isolating U-1 Vacuum drag Step 12 Verify SGBD not aligned to Discharge Canal Direct field operators to perform step 13, 17, 18, 19 and 20 of Appendix A (attached page_36-38_).

Determine T.S. 3.4.6.2. c (Action a) HSB within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Contact Chemistry for secondary sampling 25

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

3 Event #

...;;;5A~ ____ Page 10 of 1 9 Event

Description:

SGTL 10 gpm.

Time Position II Applicant's Actions or Behavior i Sooth Operator Instructions: Notify Control Room Appendix A steps 13, 17, 18, 19 i and 20 are complete approximately 10 minutes after request.

f* ____ **_*_**.. __

i Indications Available: Charging and letdown mismatch.

I PC-11 SJAE trending up and eventual alarm I PC-11 Slowdown trending up (10-15 minutes after SJAE)

I-'~-----"

i BOP/RO Recognize Steam generator tube leak occurring I

r----.-.

i i

RO BOP i

I I,

~---..

I,

~------~-.-i i

i i [------_.

t t..

I I

f----~.-

I r-._--+-

I,

l SJAE radiation alarms Blowdown radiation trending up Mismatch Chg. I Letdown Determines approximate leak rate of 10 gpm based on Charging / Letdown mismatch.

Communicate with NPO I SNPO to perform Appendix A steps 13, 17, 18, 19 and 20 of Appendix A when directed by SRO.

j---- 26 I

t l l !

Operator Action Form ES-O-2

~-

ii Op Test No..

II Event Description Scenano #

3 Event #

5A Page 10 of 19 SGTL 10 gpm.

I:

-'4F~~~~~~~~~~~~~~~~~~~~=---~~~~-~1 il__

Time Position Ap licant's Actions or Behavior

. Sooth Operator Instructions: Notify Control Room Appendix A steps 13, 17, 18, 19

and 20 are complete approximately 10 minutes after request.

Indications Available: Charging and letdown mismatch.

i PC-11 SJAE trending up and eventual alarm

! PC-11 Slowdown trending up (10-15 minutes after SJAE) r---*----*

u I

i--

i BOP/RO I Recognize Steam generator tube leak occurring I

SJAE radiation alarms I

Blowdown radiation trending up Mismatch Chg. I Letdown f----_._-... _---- --.

I RO Determines approximate leak rate of 10 gpm based I

Charging I Letdown mismatch.

i on BOP Communicate with NPO I SNPO to perform Appendix A steps 13, I

I

.. -.- ----.-+----r i

r--------

I L

I r----------- --.

--.-.-----.--... --.-~.

i,

_.- ---_.. -+----_.. _-

--i------

---~... ----

j---.

t-.. -

17, 18, 19 and 20 26 of Appendix A when directed by SRO.

I

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36B STEAM GENERATOR TUBE LEAK

.,' '9 of 35 PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 1 of 13)

INSTRUCTIONS

1. 1f at any time RCS leakage exceeds the capacity of the charging pumps and pressurizer level cannot be maintained, Then:

A. 1f in Modes 1 and 2, Then trip the reactor and turbine and implement 2-EOP-01, Standard Post Trip Actions.

B. 1f in Mode 3 (SIAS NOT Blocked),

Then implement 2-EOP-04, Steam Generator Tube Rupture.

NOTE CONTINGENCY ACTIONS

~1 Quick diagnosis of a tube leak and subsequent rapid isolation of the effected S/G will minimize secondary contamination and radiation exposure. Observation of S/G Blowdown Radiation Monitors may assist in validating SJAE Radiation Monitor indications, and may become the primary measured indication if the SJAE Radiation Monitor is out-of-service. Even before confirmation of a tube leak has been established, planning and preparation for unit shutdown and mitigating the affects should commence, by performing notifications, procedure reviews, crew briefings, and ensuring resources are available to tend to the unit conditions.

2.

Ensure sufficient charging pumps are operating and maintaining pressurizer level.

3.

1f the steam generator blowdown rad monitor is in High Alarm, Then ensure steam generator blowdown and sample valves from the affected steam generator have closed on high radiation.

4.

Notify Health Physics of present plant conditions and to conduct secondary area radiation surveys.

27

2. 1f pressurizer level is NOT being maintained, Then isolate letdown to assist in maintaining pressurizer level.

3. Manually close the S/G blowdown and sample valves from the affected steam generator.

(

REVISION NO' PROCEDURE TITLE:

PAGE:

36B STEAM GENERATOR TUBE LEAK 9 of 35 PROCEDURE NO.

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 1 of 13)

INSTRUCTIONS

1. If at any time RCS leakage exceeds the capacity of the charging pumps and pressurizer level cannot be maintained, Then:

A. If in Modes 1 and 2, Then trip the reactor and turbine and implement 2-EOP-01, Standard Post Trip Actions.

B. If in Mode 3 (SIAS NOT Blocked),

Then implement 2-EOP-04, Steam Generator Tube Rupture.

NOTE CONTINGENCY ACTIONS

~1 Quick diagnosis of a tube leak and subsequent rapid isolation of the effected S/G will minimize secondary contamination and radiation exposure. Observation of S/G Blowdown Radiation Monitors may assist in validating SJAE Radiation Monitor indications, and may become the primary measured indication if the SJAE Radiation Monitor is out-of-service. Even before confirmation of a tube leak has been established, planning and preparation for unit shutdown and mitigating the affects should commence, by performing notifications, procedure reviews, crew briefings, and ensuring resources are available to tend to the unit conditions.

2.

Ensure sufficient charging pumps are operating and maintaining pressurizer level.

3. If the steam generator blowdown rad monitor is in High Alarm, Then ensure steam generator blowdown and sample valves from the affected steam generator have closed on high radiation.

4.

Notify Health Physics of present plant conditions and to conduct secondary area radiation surveys.

27

2. If pressurizer level is NOT being maintained, Then isolate letdown to assist in maintaining pressurizer level.

3. Manually close the S/G blowdown and sample valves from the affected steam generator.

REVISION NO.:

PROCEDURE TITLE:

10 of 35..

STEAM GENERATOR TUSE LEAK 36S PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 2 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE A time delay may exist between an increase in SJAE monitor reading and Steam Generator Slowdown monitor readings.

Steam Generator Slowdown sample isolates on Steam Generator Slowdown process monitor high radiation signal.

CAUTION IF conditions of Steam Generator Tube Leakage Change, THEN REDIAGNOSIS of shutdown conditions is REQUIRED to ensure compliance with EPRI guidelines and Technical Specifications.

5.

CHECK Air Ejector and / or Steam Generator Slowdown monitor reading.

Log radiation monitor readings every 15 minutes. (Data Sheet 2)

6.

.!.f Air Ejector and I or Steam Generator Slowdown monitor shows step rise or continuous rise, Then perform the following:

A. DIRECT Chemistry to implement COP-06.05, High Activity in a Steam Generator.

B. ESTIMATE primary to secondary leakage by comparing Air Ejector monitor (preferred) and I or Steam Generator Slowdown monitor reading with Daily Chemistry Report.

28

5..!.f Steam Generator sample flow is isolated due to CIAS or high radiation, Then perform the following, to regain sample flow only:

PLACE control switch for FCV-23-7/9 to CLOSE /

OVERRIDE position OPEN FCV-23-7/9 B..!.f it is not possible to estimate primary to secondary leakage or the radiation monitors are out-of-service, Then determine leak rate by Chemistry sample.

(

REVISION NO.

PROCEDURE TITLE:

PAGE:

36S STEAM GENERATOR TUSE LEAK 10 of 35 PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 2 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE A time delay may exist between an increase in SJAE monitor reading and Steam Generator Slowdown monitor readings.

Steam Generator Slowdown sample isolates on Steam Generator Slowdown process monitor high radiation signal.

CAUTION IF conditions of Steam Generator Tube Leakage Change, THEN REDIAGNOSIS of shutdown conditions is REQUIRED to ensure compliance with EPRI guidelines and Technical Specifications.

5.

CHECK Air Ejector and! or Steam Generator Slowdown monitor reading.

Log radiation monitor readings every 15 minutes. (Data Sheet 2)

6. If Air Ejector and! or Steam Generator Slowdown monitor shows step rise or continuous rise, Then perform the following:

A.

DIRECT Chemistry to implement COP-06.05, High Activity in a Steam Generator.

B.

ESTIMATE primary to secondary leakage by comparing Air Ejector monitor (preferred) and! or Steam Generator Slowdown monitor reading with Daily Chemistry Report.

28

5. !f Steam Generator sample flow is isolated due to CIAS or high radiation, Then perform the following, to regain sample flow only:

PLACE control switch for FCV-23-7!9 to CLOSE!

OVERRIDE position OPEN FCV-23-7!9 B. !f it is not possible to estimate primary to secondary leakage or the radiation monitors are out-of-service, Then determine leak rate by Chemistry sample.

REVISION NO.:

PROCEDURE TITLE:

PAGE:. '..

'11 of 35 36B STEAM GENERATOR TUBE LEAK PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 3 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6.

(continued)

6. (continued)

CAUTION Downpower load rate should be consistent with allowed time. Use of most of the time allowed for the downpower will minimize possible plant perturbations.

NOTE The following step is used to estimate an increase in the rate of change of the leak.

Example: Initially estimated leak rate is 80 gpd. 30 minutes later estimated leak rate is 95 gpd. 95 gpd - 80 gpd = 15 gpd increase in 30 minutes, which is an increase of 30 gpd I hr.

Data Sheet 1 is available to facilitate monitoring leakage.

C. If BOTH the following conditions exist, C. Go TO Step 6.0 of Appendix A.

§3, 4 Estimated primary to secondary leakage is ?: 75 gpd.

Estimated rate of change in primary to secondary leakage is

?: 30 gpd I hr (as measured by an increase of?: 15 gpd in 30 minutes)

Then PERFORM the following:

1. REDUCE power at a rate of 10 mw/min to $ 50% in 1 hr and be in Mode 3 in the next 2 hrs, in accordance with 2-0NP-22.01, Rapid Downpower.

2. Go to Step 16 of Appendix A.

29 REVISION NO.

PROCEDURE TITLE PAGE:

368 STEAM GENERATOR TUBE LEAK 11 of 35 PROCEDURE NO.

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 3 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6.

(continued)

6. (continued)

CAUTION Downpower load rate should be consistent with allowed time. Use of most of the time allowed for the downpower will minimize possible plant perturbations.

NOTE The following step is used to estimate an increase in the rate of change of the leak.

Example: Initially estimated leak rate is 80 gpd. 30 minutes later estimated leak rate is 95 gpd. 95 gpd - 80 gpd ::: 15 gpd increase in 30 minutes, which is an increase of 30 gpd I hr.

Data Sheet 1 is available to facilitate monitoring leakage.

c. 11 BOTH the following conditions exist, C. Go TO Step 6.0 of Appendix A.

§3, 4 Estimated primary to secondary leakage is ~ 75 gpd.

Estimated rate of change in primary to secondary leakage is

~ 30 gpd I hr (as measured by an increase of ~ 15 gpd in 30 minutes)

Then PERFORM the following:

1. REDUCE power at a rate of 10 mw/min to ~ 50% in 1 hr and be in Mode 3 in the next 2 hrs, in accordance with 2-0NP-22.01, Rapid Downpower.

2. Go to Step 16 of Appendix A.

29

REVISION NO.:

PROCEDURE TITLE:

PAGE:.

J2 of 35 STEAM GENERATOR TUBE LEAK 36B PROCEDURE NO.:

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(Page 4 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6.

(continued)

6. (continued)

NOTE 150 gpd = 0.1 gpm D. !f RCS inventory balance or plant indications confirm primary to secondary leakage exceeds Tech Spec limits.

OR Valid SJAE and I or S/G Blowdown Radiation Monitor indicates S/G tube leakage is ~ 150 gpd, Then PERFORM the following:

1. COMMENCE a plant shutdown at a rate of 3 mw/min, be in Mode 3 in s;; 6 hrs, in accordance with ONE of the following:

2-GOP-123, Turbine Shutdown

- Full Load to Zero Load 2-0NP-22.01, Rapid Downpower

2. GO TO Step 16 of Appendix A.

D. Go TO Step 6.E of Appendix A.

0

~----------------------------------------------------------~ ~

30

(

REVISION NO.

PROCEDURE TITLE:

PAGE:

36B STEAM GENERATOR TUBE LEAK 12 of 35 PROCEDURE NO :

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 4 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6.

(continued)

6. (continued)

NOTE II 150 gpd = 0.1 gpm II D. 11 RCS inventory balance or plant indications confirm primary to secondary leakage exceeds Tech Spec limits.

OR Valid SJAE and / or S/G Blowdown Radiation Monitor indicates S/G tube leakage is ~ 150 gpd, Then PERFORM the following:

1. COMMENCE a plant shutdown at a rate of 3 mw/min, be in Mode 3 in

s; 6 hrs, in accordance with ONE of the following:

2-GOP-123, Turbine Shutdown

- Full Load to Zero Load 2-0NP-22.01, Rapid Downpower

2. GO TO Step 16 of Appendix A.

D. Go TO Step 6.E of Appendix A.

0

~------------------------------------------------------------~ ~

to>

30

REVISION NO.:

PROCEDURE TITLE:

PAGE:

13 of 35-STEAM GENERATOR TUBE LEAK 36B PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 5 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6.

(continued)

6. (continued)

CAUTION Downpower load rate should be consistent with allowed time. Use of most of the time allowed for the downpower will minimize possible plant perturbation.

E. !f BOTH the following conditions exist,

§3,4 Estimated primary to secondary leakage is ;:::: 75 gpd.

There is no operable SJAE or affected S/G Blowdown radiation

monitor, Then PERFORM the following:

1. REDUCE power at a rate of 3 mw/min and be in Mode 3 in the next 6 hrs, in accordance with 2-0NP-22,01, Rapid Downpower.

2. Go to Step 16 of Appendix A.

31 E.

Go TO Step 6.F of Appendix A.

(

REVISION NO PROCEDURE TITLE:

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.13 of 35 STEAM GENERATOR TUBE LEAK 36B PROCEDURE NO:

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(Page 5 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6.

(continued)

6. (continued)

CAUTION Downpower load rate should be consistent with allowed time. Use of most of the time allowed for the down power will minimize possible plant perturbation.

E. If BOTH the following conditions exist,

§3,4 Estimated primary to secondary leakage is ;::: 75 gpd.

There is no operable SJAE or affected S/G Blowdown radiation

monitor, Then PERFORM the following:

1. REDUCE power at a rate of 3 mw/min and be in Mode 3 in the next 6 hrs, in accordance with 2-0NP-22.01, Rapid Downpower.

2.

Go to Step 16 of Appendix A.

31 E.

Go TO Step 6.F of Appendix A.

(

REVISION NO.:

PROCEDURE TITLE:

PAGE,:_,_.>

-l40f 35:

36B STEAM GENERATOR TUBE LEAK PROCEDURE NO.:

2-0830030 ST, LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 6 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS 6,

(continued)

6. (continued)

CAUTION Downpower load rate should be consistent with allowed time. Use of most of the time allowed for the downpower will minimize possible plant perturbation, F. II either of the following condition exists:

§3,4 The estimated primary to secondary leakage is greater than or equal to 75 gpd and is sustained for greater than or equal to one hour.

OR

§2 Primary to secondary leak rate is unstable or increasing AND both SJAE and S/G Blowdown radiation monitors become inoperable.

Then PERFORM the following:

1. COMMENCE a plant shutdown at a rate of 3 mw/min and be in Mode 3 in less than or equal to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , in accordance with one of the following:

2-GOP-123, Turbine Shutdown Full Load to Zero Load 2-0NP-22.01, Rapid Downpower

2. Go to Step 16 of Appendix A.

32.,.. r F. Go TO Step 6.G of Appendix A.

~

REVISION NO..

PROCEDURE TITLE:

PAGE:

36B STEAM GENERATOR TUBE LEAK 14 of 35 PROCEDURE NO.

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 6 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6.

(continued)

6. (continued)

CAUTION Downpower load rate should be consistent with allowed time. Use of most of the time allowed for the downpower will minimize possible plant pertu rbation.

F.

1f either of the following condition exists:

§3.4 The estimated primary to secondary leakage is greater than or equal to 75 gpd and is sustained for greater than or equal to one hour_

OR Primary to secondary leak rate is unstable or increasing AND both SJAE and S/G Blowdown radiation monitors become inoperable.

Then PERFORM the following:

1. COMMENCE a plant shutdown at a rate of 3 mw/min and be in Mode 3 in less than or equal to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , in accordance with one of the following:

2-GOP-123, Turbine Shutdown Full Load to Zero Load 2-0NP-22.01, Rapid Downpower

2. Go to Step 16 of Appendix A.

32 F. Go TO Step 6.G of Appendix A.

0 w

en

0 w

en

REVISION NO.:

PROCEDURE TITLE:

36B STEAM GENERATOR TUBE LEAK PROCEDURE NO.:

~5 of

.;:~?~li');)**

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 7 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6.

(continued)

6. (continued)

NOTE A stabilized leak rate is when the rate of change is less than or equal to 10% of the last determined leak rate.

G..If estimated primary to secondary G. GO TO Step 6.H of Appendix A.

leakage is less than 75 gpd but greater than or equal to 30 gpd, Then PERFORM the following:

1. DETERMINE the affected Steam Generator.

2. ESTIMATE primary to secondary leakage by comparing Air Ejector and SIG Blowdown rad monitor readings with the daily Chemistry report using the following schedule.

a..If the primary to secondary leak rate is not stable, Then PERFORM the monitoring comparison every 15 minutes.

b..If the leak rate has been stable for more than one hour, Then PERFORM the monitoring comparison every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

c..If the leak rate has been stable for more than one 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , Then CONTINUE monitoring in accordance with Chemistry requirements.

3. CONSUL T with Chemistry on the contaminated water plan for operational requirements.

33

(

REVISION NO..

PROCEDURE TITLE:

PAGE:

j 5 of 35...

STEAM GENERATOR TUSE LEAK 36S PROCEDURE NO 2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 7 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6.

(continued)

6. (continued)

NOTE A stabilized leak rate is when the rate of change is less than or equal to 10% of the last determined leak rate.

G. If estimated primary to secondary G. GO TO Step 6.H of Appendix A.

leakage is less than 75 gpd but greater than or equal to 30 gpd, Then PERFORM the following:

1. DETERMINE the affected Steam Generator.

2. ESTIMATE primary to secondary leakage by comparing Air Ejector and S/G Slowdown rad monitor readings with the daily Chemistry report using the following schedule.

a. If the primary to secondary leak rate is not stable, Then PERFORM the monitoring comparison every 15 minutes.

b. If the leak rate has been stable for more than one hour, Then PERFORM the monitoring comparison every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

c. If the leak rate has been stable for more than one 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , Then CONTINUE monitoring in accordance with Chemistry requirements.

3. CONSUL T with Chemistry on the contaminated water plan for operational requirements.

33

REVISION NO.:

PROCEDURE TITLE:

36B STEAM GENERATOR TUBE LEAK PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 8 of 13)

INSTRUCTIONS

6.

G. (continued)

4. With concurrence from Chemistry, CONTACT I&C to adjust process monitor alarm setpoints.

5. GO TO Step 7 of Appendix A.

H. If estimated primary to secondary leakage is less than 30 gpd but greater than or equal to 5 gpd, Then PERFORM the following:

1. DETERMINE the affected Steam Generator

2. QUANTIFY Steam Generator leakage

3. RETURN out-of-service radiation monitoring instrumentation to service.

4. INCREASE monitoring frequency of radiation monitors to hourly.

5. With concurrence from Chemistry, CONTACT I&C to adjust process monitor alarm setpoints.

34 CONTINGENCY ACTIONS

6. G. (continued)

H. GO TO Step 7 of Appendix A.

REVISION NO.:

PROCEDURE TITLE:

36B STEAM GENERATOR TUBE LEAK PROCEDURE NO,:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 8 of 13) 6 of 35 INSTRUCTIONS CONTINGENCY ACTIONS

6.

G. (continued)

4. With concurrence from Chemistry, CONTACT I&C to adjust process monitor alarm setpoints.

5. GO TO Step 7 of Appendix A.

H. if estimated primary to secondary leakage is less than 30 gpd but greater than or equal to 5 gpd, Then PERFORM the following:

1. DETERMINE the affected Steam Generator

2. QUANTIFY Steam Generator leakage

3. RETURN out-of-service radiation monitoring instrumentation to

service,

4. INCREASE monitoring frequency of radiation monitors to hourly.

5. With concurrence from Chemistry, CONT ACT I&C to adjust process monitor alarm setpoints.

34

6. G. (continued)

H. GO TO Step 7 of Appendix A.

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36B STEAM GENERATOR TUBE LEAK PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 9 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE A full isotopic analysis of steam generator water activity could take up to an hour. If an expeditious indication of gross activity is required, a frisk in the Secondary Lab or a quick count gamma analysis in the Hot Lab, will yield the necessary information to determine the gross magnitude and source of the leak.

7.

Notify Chemistry of present plant conditions and to sample both steam generators for activity..if a CIAS or high radiation signal has closed the steam generator sample valves, Then they may be opened to permit sampling as follows:

A. Place control switch for FCV-23-7/9 to CLOSE / OVERRIDE position and then take switch to OPEN position.

NOTE A prompt determination of the leak rate takes precedence over fulfilling the 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months time requirement of Data Sheet 1.

8.

Determine the primary to secondary leak rate, per 2-0SP-01.03, Reactor Coolant System Inventory Balance.

NOTE

§1!f total tube leakage is greater than.1 GPM, Then the reactor must be in Hot Standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and Cold Shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . Reference Daily Chemistry Report for projected Condenser Air Ejector Reading (CPM) with a.1 GPM Primary /

Secondary Leak.

A prompt expeditious shutdown is desired, however a controlled shutdown with minimal pressure transients takes precedence over a short duration to shutdown.

9.

NOTIFY Plant Management of potential plant shutdown.

35 REVISION NO.

PROCEDURE TITLE PAGE:

36B STEAM GENERATOR TUBE LEAK 17 of 35 PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 9 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE A full isotopic analysis of steam generator water activity could take up to an hour. If an expeditious indication of gross activity is required, a frisk in the Secondary Lab or a quick count gamma analysis in the Hot Lab, will yield the necessary information to determine the gross magnitude and source of the leak.

7.

Notify Chemistry of present plant conditions and to sample both steam generators for activity. If a CIAS or high radiation signal has closed the steam generator sample valves, Then they may be opened to permit sampling as follows:

A. Place control switch for FCV-23-7/9 to CLOSE / OVERRIDE position and then take switch to OPEN position.

NOTE A prompt determination of the leak rate takes precedence over fulfilling the 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months time requirement of Data Sheet 1.

8.

Determine the primary to secondary leak rate, per 2-0SP-01.03, Reactor Coolant System Inventory Balance.

NOTE

§1 If total tube leakage is greater than.1 GPM, Then the reactor must be in Hot Standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and Cold Shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . Reference Daily Chemistry Report for projected Condenser Air Ejector Reading (CPM) with a.1 GPM Primary /

Secondary Leak.

A prompt expeditious shutdown is desired, however a controlled shutdown with minimal pressure transients takes precedence over a short duration to shutdown.

9.

NOTIFY Plant Management of potential plant shutdown.

35

0 W

Gl OJ

(

REVISION NO.:

PROCEDURE TITLE:

36B STEAM GENERATOR TUBE LEAK PAGE: '',.

~;::<.. ::~.~... :...

PROCEDURE NO,:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 10 of 13)

INSTRUCTIONS

10. REVIEW procedures and CONDUCT shift briefs as needed for plant shutdown.

11. CONSIDER isolating blowdown and vac drag on Unit 1.

12. VERIFY steam generator blowdown is not aligned to the discharge canal.

13. DIRECT a field operator to the SGBTF to perform ALL of the following:

A.

ENSURE SGBTF Truck Bay (roll-up) door is CLOSED.

B.

ENSURE SGBTF ventilation systems are in operation:

Supply Fans HVS-10A or HVS-10B Exhaust Fans HVE-41A or HVE-41B SGBTF Ventilation Process Monitor

14. VERIFY RCS water inventory balance and / or Chemistry samples indicate primary to secondary leak rate is less than or equal to 30 gpd.

15. !f RCS Inventory balance and / or Chemistry samples indicate primary to secondary leak rate is less than 5 gpd, Then EXIT this procedure and continue with the normal monitoring program.

36 CONTINGENCY ACTIONS

14. RETURN TO Step 6.B of Appendix A.

15. RETURN to Step 6.B of Appendix A.

(

REVISION NO" PROCEDURE TITLE:

PAGE:,

36B STEAM GENERATOR TUBE LEAK

,018 of 35 PROCEDURE NO, 2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 10 of 13)

INSTRUCTIONS

10. REVIEW procedures and CONDUCT shift briefs as needed for plant shutdown,

11. CONSIDER isolating blowdown and vac drag on Unit 1,

12. VERIFY steam generator blowdown is not aligned to the discharge canal.

13. DIRECT a field operator to the SGBTF to perform ALL of the following:

A.

ENSURE SGBTF Truck Bay (roll-up) door is CLOSED.

B.

ENSURE SGBTF ventilation systems are in operation:

Supply Fans HVS-10A or HVS-10B Exhaust Fans HVE-41A or HVE-41 B SGBTF Ventilation Process Monitor

14. VERIFY RCS water inventory balance and I or Chemistry samples indicate primary to secondary leak rate is less than or equal to 30 gpd.

15. 11 RCS Inventory balance and I or Chemistry samples indicate primary to secondary leak rate is less than 5 gpd, Then EXIT this procedure and continue with the normal monitoring program.

36 CONTINGENCY ACTIONS

14. RETURN TO Step 6.B of Appendix A,

15. RETURN to Step 6.B of Appendix A.

REVISION NO.:

PROCEDURE TITLE:

19 of 35 STEAM GENERATOR TUBE LEAK 36B

.eO PROCEDURE NO,:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 11 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS CAUTION Downpower load rate should be consistent with allowed time. Use of most of the time allowed for the downpower will minimize possible plant perturbation.

16. PERFORM ALL of the following:

11 necessary, Then INITIATE the Emergency Plan.

CONTINUE to monitor process monitors for changing conditions due to Steam Generator tube leakage every 15 minutes.

CONSULT with Chemistry to implement Contaminated Water Plan.

17. DIRECT a field operator to the SGBTF to perform ALL of the following:

A. ENSURE SGBTF Truck Bay (roll-up) door is CLOSED.

B. ENSURE SGBTF ventilation systems are in operation:

Supply Fans HVS-10A or HVS-10B Exhaust Fans HVE-41A or HVE-41B SGBTF Ventilation Process Monitor 37

(

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36B PROCEDURE NO.:

STEAM GENERATOR TUBE LEAK 19 of 35 2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 11 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS CAUTION Downpower load rate should be consistent with allowed time. Use of most of the time allowed for the downpower will minimize possible plant pertu rbation.

16. PERFORM ALL of the following:

11 necessary, Then INITIATE the Emergency Plan.

CONTINUE to monitor process monitors for changing conditions due to Steam Generator tube leakage every 15 minutes.

CONSUL T with Chemistry to implement Contaminated Water Plan.

17. DIRECT a field operator to the SGBTF to perform ALL of the following:

A. ENSURE SGBTF Truck Bay (roll-up) door is CLOSED.

B.

ENSURE SGBTF ventilation systems are in operation:

Supply Fans HVS-10A or HVS-10B Exhaust Fans HVE-41A or HVE-41B SGBTF Ventilation Process Monitor 37

REVISION NO.:

PROCEDURE TITLE:

PAGE.--

i1~ig~f3~.'****

36B STEAM GENERATOR TUBE LEAK PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 12 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS CAUTION To reduce the release of potentially radioactive steam from turbine auxiliary feedwater pump exhaust, motor driven auxiliary feedwater or main feedwater pumps should be used. If the motor driven auxiliary feedwater pumps are not available, steam from the unfaulted or least affected steam generator should be used to drive the turbine driven auxiliary feedwater pump.

18. Capture the CTCS sponge ball in accordance with 2-NOP-21.01, Condenser Tube Cleaning System Operation.

19. Ensure condenser air ejector is aligned to the plant vent.

20. Locally isolate auxiliary steam to auxiliary priming ejectors by closing V08245.

V~When the turbine is tripped and the reactor

~7 is NOT shutdown, Then shutdown the reactor as follows:

A. REFER TO 2-GOP-203, Reactor Shutdown.

B. Verify that shutdown margin is within the limits specified in COLR in accordance with 2-NOP-100.04, Surveillance Requirements for Shutdown Margin Modes 2, 3, 4 & 5 Subcritical.

38

21. !f the reactor is shutdown, Then go to Step 22 of Appendix A.

(

REVISION NO,:

PROCEDURE TITLE:

PAGE:

'20 of 35 36B STEAM GENERATOR TUBE LEAK PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 12 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS CAUTION To reduce the release of potentially radioactive steam from turbine auxiliary feedwater pump exhaust, motor driven auxiliary feed water or main feedwater pumps should be used. If the motor driven auxiliary feedwater pumps are not available, steam from the unfaulted or least affected steam generator should be used to drive the turbine driven auxiliary feedwater pump.

18. Capture the CTCS sponge ball in accordance with 2-NOP-21.01, Condenser Tube Cleaning System Operation.

19. Ensure condenser air ejector is aligned to the plant vent.

20. Locally isolate auxiliary steam to auxiliary priming ejectors by closing V08245, v~When the turbine is tripped and the reactor

~J is NOT shutdown, Then shutdown the reactor as follows:

A. REFER TO 2-GOP-203, Reactor Shutdown.

B. Verify that shutdown margin is within the limits specified in COLR in accordance with 2-NOP-1 00,04, Surveillance Requirements for Shutdown Margin Modes 2, 3, 4 & 5 Subcritical.

38

21. If the reactor is shutdown, Then go to Step 22 of Appendix A.

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36B STEAM GENERATOR TUBE LEAK

-21 of 35 PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 13 of 13)

INSTRUCTIONS

22. When the reactor is shutdown, Then PERFORM BOTH of the following:

A. COMMENCE an RCS cooldown until hot leg temperature is less than 510°F using the SBCS.

B. DEPRESSURIZE the RCS and maintain 20°F to 50°F subcooling per Figure 1, RCS Pressure /

Temperature.

23. If RCS pressure and level are being controlled, Then when RCS pressure reaches 1836 psia and annunciator R-8, SIAS Channel Block Permissive alarms, perform the following:

A.

Block channels A and B of SIAS by turning the SIAS block key switches (99 & 100) on RTGB 206 to the block position.

B. Ensure annunciators R-9 and R-10 SIAS Actuation Channel A (B) Blocked have annunciated.

24. GO TO Step 3 of main procedure.

22.

CONTINGENCY ACTIONS A. If the SBCS is NOT available, Then PERFORM both of the following:

1. Steam to the atmosphere using the atmospheric steam dump valves.

2. Reevaluate the E-Plan classification.

END OF APPENDIX A 39

(

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36B STEAM GENERATOR TUBE LEAK 21 of 35 PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE 1 THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 13 of 13)

INSTRUCTIONS

22. When the reactor is shutdown, Then PERFORM BOTH of the following:

A. COMMENCE an RCS cooldown until hot leg temperature is less than 51 oaF using the SBCS.

B. DEPRESSURIZE the RCS and maintain 20°F to 50°F subcooling per Figure 1, RCS Pressure /

Temperature.

23. !f RCS pressure and level are being controlled, Then when RCS pressure reaches 1836 psia and annunciator R-8, SIAS Channel Block Permissive alarms, perform the following:

A.

Block channels A and 8 of SIAS by turning the SIAS block key switches (99 & 100) on RTG8 206 to the block position.

B. Ensure annunciators R-9 and R-10 SIAS Actuation Channel A (8) Blocked have annunciated.

24. GO TO Step 3 of main procedure.

22.

CONTINGENCY ACTIONS A. !f the SBCS is NOT available, Then PERFORM both of the following:

1. Steam to the atmosphere using the atmospheric steam dump valves.

2. Reevaluate the E-Plan classification.

END OF APPENDIX A 39

REVISION NO.:

36B PROCEDURE NO.:

2-0830030 NO Grealer than or Equal 10 30 gpO NO PROCEDURE TITLE:

STEAM GENERATOR TUBE LEAK ST. LUCIE UNIT 2 FIGURE 2 MODE 1 THROUGH 3 (SIAS NOT BLOCKED)

(Page 1 of 1)

NO The rate Greeter than or Equal 10 108 gpd YES

)--_Y_ES_~I _ 8e less lhan 5O%Pomr in one ho'"

- ee In Mode 3 v.ithin tho next \\VI<) hou" YES NO YES f:!QIi A Stabilized leakrale IS \\\\!len the rate of change 1$10.. than" equal to 10%01 tho last determined leakrata Se in Mode 3 v.ittlin 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

. Detennine affecte<l SIG

- Es1imata PriiSec l.akrsie every 15 Min

- If le.krsta stable for great", than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months

>--------------1 then monitorevOfy 2 hou" YES

-II leakrale stable lor gr ** t", than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months then montier per Chemiolry requremenls

-Determine tha affected SIG

+-.j -Quantify S/G leokrat.

-I.\\onltor Hourly 40 PAGE:

32 of 35

(

REVISION NO..

36B PROCEDURE NO.

2-0830030 NO Greater than or Equal 10 30 gpd NO PROCEDURE TITLE:

STEAM GENERATOR TUBE LEAK ST. LUCIE UNIT 2 FIGURE 2 MODE 1 THROUGH 3 (SIAS NOT BLOCKED)

(Page 1 of 1 )

The rate of change IS grea!er then lY equal to 30 gpdIhr NO SJEAor affected SGSD Red MOniter operable YES Greeter than Of Equal to 108 gpd NO,

Greater than Of E qual to 75 gpd for Greater than or Equal 10 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months NO YES YES YES

Be le~ than 50% Pomr In one holS

- 8e In Mode 3 'Mthm the neXl two hours NO r------------J 8e In rnode 3 YJlthin SIX hours YES t:!Qlli A Stablli2:ed leakrate IS Wlen the rale of change IS less than or equal to 10% of the last determined Jeakra!e Be In Mode 3 vAthin 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

Detennine.Nectod SIG

- Estimele Pri/Sec ltlakrste every 15 Min

If leakrate stable Ie;( greater than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months

>-------------~I then monitor every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months If LeBkrate stable for greater than 24 t>ours Ihen mOOlil)l p&r Chemistry requ,emenls YES

. Determine the affected SIG

.---.----.~ *QlUlntify S/G leakrale

-Momtor Hourly 40 PAGE:

32 of 35

Appendix D Operator Action Form ES-D-2

! Op Test No.:

1 Scenario #

3 I! Event DescriPtion:- SGTR 200 gpm.

Event #

_5;,.;8_____ Page 11 of 19 Ii Time Position A

licant's Actions or Behavior I Booth Operator Instructions' When directed by examiner initiate SGTR (200 gpm)

Indications Available: Pressurizer level and pressure rapidly lowering i

SRO I

I I ;

I I

o-_n BOP

~

r---'

~

I r---'

i 1---_*-

RO I I,....

i f.... ',----

I I

Direct RO to isolate Letdown (Close V2515, V2516, V2522) as leak increases.

Notifies SM of SGTL and power reduction Direct power reduction to Mode 3 lAW step 6.F.1 then goes to step 16 of Appendix A. (attached page_32_)

Directs Reactor tripped when notified Pressurizer level cannot be maintained.

Monitors and maintains SG levels 60*70%

Communicate with HP and Chemistry as directed by SRO Makes plant announcement of Unit shutdown Trips the Reactor when directed by SRO Isolate letdown when directed as leak increases Recognize Pressuirzer level lowering with letdown isolated and both Charging pumps running.

Inserts CEA's in Manual Sequential when directed, to place the plant in Mode 3 Trips the Reactor when directed by SRO

- 11.

41 Appendix D Ii Op Test No.:

'I I! Event Description Scenario #

3 SGTR 200 gpm.

Position Operator Action Form ES-D-2 Event #

5B Page 11

-.;..;~----

of 19 A

licant's Actions or Behavior

Booth Operator Instructions:

When directed by examiner initiate SGTR (200 gpm)

~------.-~- -----------------------------------------------------------

-~~

I Indications Available: Pressurizer level and pressure rapidly lowering I 1-----

~------

.. -~-.-

1---

~~------.---

I I

~---

r---'

I >-----_

I,....,-.--

I r----

I I

I I ['

I SRO I

I BOP RO Direct RO to isolate Letdown (Close V2515, V2516, V2522l as leak increases.

i Notifies SM of SGTL and power reduction Direct power reduction to Mode 3 lAW step 6.F.1 then goes to step 16 of Appendix A. (attached page_32_l Directs Reactor tripped when notified Pressurizer level cannot be maintained.

I Monitors and maintainS SG levels 60-70%

Communicate with HP and Chemistry as directed by SRO Makes plant announcement of Unit shutdown Trips the Reactor when directed by SRO Isolate letdown when directed as leak increases Recognize Pressuirzer level lowering with letdown isolated and both Charging pumps running.

Inserts CEA's in Manual Sequential when directed, to place the plant in Mode 3 Trips the Reactor when directed by SRO 41 i I I I I

i I I I

I I

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

.1...- Event #

.....;;.;5B;.... ____ Page 12 of 19 Event

Description:

SGTR 200 gpm.

I Time II Position II Applicant's Actions or Behavior Booth Operator Instructions:

! Indications Available:

I Examiners note: SIAS will not actuate until the crew enters 2*EOP*04 SGTR and starts a cooldown.

SRO i

RO

~-

I !

I Directs implementation of 2-EOP-01, "Standard Post Trip Actions" as follows:

RO: Reactivity control, Inventory Control, Pressure control, Core Heat Removal BOP: Vital Auxiliaries, RCS heat removal, Containment Conditions.

Performs EOP-01 Safety Functions as directed for Reactivity Control, Inventory Control, Pressure Control, Core Heat removal Reactivity Control

~

Verify Reactor power is lowering Verify startup rate is negative.

Verify a maximum of one CEA is not fully inserted.

Inventory Control Verify pressurizer level is between 10 and 68%

Pressurizer level is trending to 30 - 35% (take manual control of chg pumps and isolate letdown if not already isoalted) 42

(

--.--~--------------------

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

3 Event #

5B Page 12 of 19 Event Description SGTR 200 gpm.

Position A plicant's Actions or Behavior I Booth Operator Instructions:

. Indications Available' I Examiners note: SIA~ will not actuate until the crew enters 2*EOp*Q4 SGTR and starts a cooldown,

~--~--.

SRO RO

~---

I i

I I

~ -_. --_..

I I

I Directs implementation of 2-EOP-01, "Standard Post Trip Actions" as follows:

RO: Reactivity control, Inventory Control, Pressure control, Core Heat Removal BOP: Vital Auxiliaries, RCS heat removal, Containment Conditions.

Periorms EOP-01 Safety Functions as directed for Reactivity Control, Inventory Control, Pressure Control, Core Heat removal Reactivity Control Verify Reactor power is lowering Verify startup rate is negative.

Verify a maximum of one CEA is not fully inserted.

Inventory Control Verify pressurizer level is between 10 and 68%

Pressurizer level is trending to 30 - 35% (take manual control of chg pumps and isolate letdown if not already isoalted) 42 i

I

Appendix D Operator Action Form ES*D*2 Op Test No.:

1 Scenario #

3 Event #

5B Page 13 of 19

~~------

~~I Event

Description:

SGTR 200 gpm.

Time II Position Il Applicant's Actions or Behavior Booth Operator Instructions:

Indications Available:

RO I

I I

I

~---.

~

i BOP f----

~---.----

I I I I i

I i

I I

I Pressure Control

Verify RCS pressure is between 1800-2300 psia (at 1736 psia verify SIAS and stop RCP in each loop)

Verify RCS pressure is trending 2225-2275 psia (control manually)

Verify RCS subcooling is >20 0 F Core Heat Removal

Verify at least one RCO running with CCW ( if> 10 minutes with no CCW must secure)

Verify loop delta T is <10 F Performs EOP-01 Safety functions as directed for: Vital Auxiliaries, RCS Heat Removal, Containment Conditions Maintenance of Vital Auxiliaries Verifies turbine governor and throttle valves closed Verify GEN Brk open (East breaker, Mid Breaker and Exciter Breaker)

Verify all vital and non vital AC Buses energized. (2A 1, 2A2, 2A3 2AB, 2B1, 2B2 and 2B3 6.9 and 4.16kv buses)

All vital and non vital DC Buses energized. 43

(

Appendix D Operator Action Form ES-D-2 Op Test No.

1 Scenario #

3 Event #

5B Page 13 of 19 Event

Description:

SGTR 200 gpm.

Time II Position II Aj)Qlicant's Actions or Behavior Booth Operator Instructions:

Indications Available:

I

~------'I ------,----------------------------1 Pressure Control e

Verify RCS pressure is between 1800-2300 psia (at I

1736 psia verify SIAS and stop RCP in each loop) i II RO e

Verify RCS pressure is trending 2225-2275 psi a (control I

manually)

_,,_I+-___

e __

V_e_ri_fy_R __

C_S_S_U_b_CO_o_li_n_g_is_>_2_0_0_F ________________ ~

r-Core Heat Removal I

I i

I e

Verify at least one RCO running with CCW ( if >10 minutes with no CCW must secure)

II I

I e

Verify loop delta T is <10 F f-------------+---~--+----------------------j 1"-

I BOP Performs EOP-01 Safety functions as directed for: Vital Auxiliaries, RCS Heat Removal, Containment Conditions 1---

i----------l------*1 Maintenance of Vital Auxiliaries I

I e

Verifies turbine governor and throttle valves closed e

Verify GEN Brk open (East breaker, Mid Breaker and Exciter Breaker) e Verify all vital and non vital AC Buses energized, (2A 1, 2A2, 2A3 2AB, 2B1, 2B2 and 2B3 6,9 and 4,16kv buses) e All vital and non vital DC Buses energized, L-~

~

~ 43

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

3 Event #

5B Page 14 of 19 Event

Description:

SGTR 200 gpm.

Time II Position II Applicant's Actions or Behavior Booth Operator Instructions:

Indications Available:

~--------.--

BOP i

f--------.. --

i I

BOP I

~

i I

~-------

~-----~-

i i

I i

i-------

I I

f...--____.* _________,_ --

I I i RCS Heat Removal Verify at least one SG has feedwater available (AFW or MFW)

Verify RCS Tavg is between 525 and 535 F

Verify SG pressure is between 835 and 915 psig.

Ensure MSR Block valves and warmup valves closed Containment Conditions

Verify containment pressure <2 psig Verify NO containment radiation monitors in alarm.

Verify containment temperature is less than 120 F Verify NO secondary plant radiation alarms (SG Blowdown may be in alarm Upon unit trip, notify NPO to perform App.X sect. 1 of EOP-99. 44

(

Appendix D Operator Action Form ES-O-2 I

illl Op Test No.

Event

Description:

Scenario #

SGTR 200 gpm.

3 Event#

5B Page 14 of 19 I

i~ime_ Jl Position II Applicant's Actions or Behavior

--.----~--.-.-----------------------------~

Booth Operator Instructions:

_. -_. -.. ---.---------~-----------------------"

Indications Available:

RCS Heat Removal

---~

.. - --~-----*-___rl--------------------------

I Verify at least one SG has feedwater available (AFW or I

MFW)

Verify RCS Tavg is between 525 and 535 F BOP I

I Verify SG pressure is between 835 and 915 psig.

I

~.---!

Ensure MSR Block valves and warmup valves closed I

Containment Conditions Verify containment pressure <2 psig I

i i

I BOP Verify NO containment radiation monitors in alarm.

Verify containment temperature is less than 120 F Verify NO secondary plant radiation alarms (SG Blowdown may be in alarm

~-.-

I I

Upon unit trip, notify NPO to perform App.X sect.1 of EOP-99.

i

i I,

1-*

I j

t~=~*~-=-~r---*-

r---~.

r-.----~-

I

>----~--..-~-.. -~.-.. -,- --------"

I I

I I I

I I 44 I

I

~--~-~.. -.---------------------------------------

Appendix D Op Test No.:

Event

Description:

Operator Action Form ES-D-2 Scenario #

3 Event #

~6'.;..7':..;8;..:.'.;.,9 ___ Page ~

of _1_9--"1 2-EOP-04 Steam Generator Tube Rupture. SIAS B side does not actuate. 2B HPSI pump does not start. 2A HPSI pump becomes air bound. 2B MSIV does not close from the control room. Isolate the 2B SG.

Time II Position II Applicant's Actions or Behavior

~~~~-&=========--===-U~~~~~~~~~=========-__ ~

Booth Operator Instructions:

I Indications Available:

I SRO I

~---------

I

~

I f--

I

.-~---~.

r----

i i---

i I

I

~

I I

I I I r

f----..... _

~-

I I

I f--------_+_

i I

I I I I

I I

Evaluate diagnostic flow chart of 2-EOP-01 Determines SGTR.

Directs entry to 2-EOP-04, "Steam Generator Tube Rupture" Direct BOP/STA to perform SFSC's of EOP-04 Implements place keeper (attached page_ 46-48_)

Notifies shift manager to classify the event Direct performance of EOP-99 Appendix A, sampling SG's (attached page_ 49,50_)

Direct BOP to verify Si flow per Figure 2 (attached page_51_)

Ensure all available charging pumps are operating Direct one RCP/LOOP stopped when SIAS received on low Pressurizer pressure.

Direct RO to monitor RCP Operating Limits per Table 13 (attached page_52_)

Direct EOP-99 Appendix J, CCW restoration to RCP's after SIAS (attached page_53,54_)

Directs RO to perform controlled cooldown to <510°F T hot using SBCS in manual, not to exceed 100°F in anyone hour period 45 I

i I I I

I I Appendix 0 p--

I. Op Test No..

I i: Event Description.

j:

Operator Action Form ES-D-2 Scenario #

3 Event#

~6'.;...7,~8~,,,;.9 ___ Page _15_ of _19_..,1 2-EOP-04 Steam Generator Tube Rupture. SIAS 8 side does not actuate. 28 HPSI pump does not start. 2A HPSI pump becomes air bound. 28 MSIV does not close from the control room. Isolate the 28 SG.

I:

1~~_~:="Ti-m-e-_=iF[~

-:£'::"'-f2.=s.-:ltl~~.0~_.. _~~~=~===~A-::-ilc-a-nt:':'"'s=A':'"'c-:ti-on-s-o-r-::8:-e-:-ha-v'":"'io~r====~===\\1 Booth Operator Instructions:

Indications Available:

I I

SRO f

_~ __________ 0 ____

I I--

~

I I f----

I I

--.----~------;--~----

f---"~-------

i f-----

i i

r--

1-------

I I

I,

I I

I

~-

i I

I I

f---- -

+-----

I I

I I,

I I

i f------.-----;-------------

i I

I I

I r

i r

I I

I

.~-.--- ---"-

J Evaluate diagnostic flow chart of 2-EOP-01 Determines SGTR.

Directs entry to 2-EOP-04, "Steam Generator Tube RuPture~

I I I Direct BOP/ST A to perform SFSC's of EOP-04 i

I Implements place keeper (attached page_ 46-48_)

Notifies shift manager to classify the event i

---1 Direct performance of EOP-99 Appendix A, sampling SG's (attached page_ 49,50_)

I I

-1 Direct BOP to verify Si flow per Figure 2 (attached page_51_)

Ensure all available charging pumps are operating Direct one RCP/LOOP stopped when SIAS received on low Pressurizer pressure.

i i

I I

Direct RO to monitor RCP Operating Limits per Table 13 (attached page_52_)

i I

Direct EOP-99 Appendix J, CCW restoration to RCP's after I,

SIAS (attached page_53,54_)

-J Directs RO to perform controlled cooldown to <510°F T hot using SBCS in manual, not to exceed 100°F in anyone hour period 45 I

REVISION NO PROCEDURE TITLE:

PAGE:

24 STEAM GENERATOR TUBE RUPTURE 44 of 46 PROCEDURE NO.:

2-EOP-04 ST. LUCIE UNIT 2 ATTACHMENT 2 PLACE KEEPER FOR SGTR (Page 1 of 3)

TIME:

EOP ENTRY DATE:

STEP INSTRUCTIONS STATUS START DONE 4

Sample Steam Generators 0

0

5.

Ensure Safety Injection Actuation 0

0

6.

Maximize SI Flow 0

0

7.

RCP Trip Strategy 0

0

8.

Ensure RCP Seal Cooling 0

0 A.

Time of CCW loss 0

0 B.

Time plus 10 0

0 C.

Time plus 30 0

0

9.

Verify RCP Operating Limits 0

0

10.

RCS Cool down to less than 510a F 0

0

11.

Depressurize the RCS 0

0

12.

Block MSIS and SIAS 0

0

13.

Protect Main Condenser 0

0

14.

Restore Instrument Air 0

0

15.

Determine the MOST Affected S/G 0

0

16.

Isolate the MOST Affected S/G 0

0

17.

Maintain ISOLATED S/G Below 915 psig (930 psia) 0 0

18.

Verify Correct S/G was Isolated 0

0

19.

HPSI Throttling Criteria 0

0

- Continuously Applicable or Non-Sequential Step 46 REVISION NO.

PROCEDURE TITLE:

PAGE:

24 STEAM GENERATOR TUBE RUPTURE 44 of 46 PROCEDURE NO..

2-EOP-04 ST. LUCIE UNIT 2 ATTACHMENT 2 PLACEKEEPER FOR SGTR (Page 1 of 3)

TIME:

EOP ENTRY DATE:

STEP INSTRUCTIONS STATUS START DONE

4.

Sample Steam Generators D

D

5.

Ensure Safety Injection Actuation D

D

6.

Maximize SI Flow D

D

7.

RCP Trip Strategy D

D

8.

Ensure RCP Seal Cooling D

D A.

Time of CCW loss D

D

(

B.

Time plus 10 D

D C.

Time plus 30 D

D

9.

Verify RCP Operating Limits D

D

10.

RCS Cooldown to less than 51 oaF D

D

11.

Depressurize the RCS D

D

12.

Block MSIS and SIAS D

D

13.

Protect Main Condenser D

D

14.

Restore Instrument Air D

0

15.

Determine the MOST Affected S/G 0

0

16.

Isolate the MOST Affected S/G D

D

17.

Maintain ISOLATED S/G Below 915 psig (930 psia)

D D

18.

Verify Correct S/G was Isolated D

D

19.

HPSI Throttling Criteria D

D

- Continuously Applicable or Non-Sequential Step 46

REVISION NO.

PROCEDURE TITLE PAGE:

24 STEAM GENERATOR TUBE RUPTURE 45 of 46 PROCEDURE NO.

2-EOP-04 ST. LUCIE UNIT 2 ATTACHMENT 2 PLACEKEEPER FOR SGTR (Page 2 of 3)

STEP INSTRUCTIONS STATUS START DONE

20.

HPSI Pump Restart Criteria 0

0

21.

LPSI Pump Stop Criteria 0

0

22.

LPSI Pump Restart Criteria 0

0

23.

Maintain RCS within Figure 1A limits 0

0

24.

Maintain the UNISOLA TED S/G Level 60 to 70% NR 0

0

25.

Evaluate Condensate Inventory 0

0

26.

Borate the RCS for SDM 0

0

(

27.

RCS Cooldown (to SOC) 0 0

28.

Sample RCS for Dilution 0

0

29.

Disable RCPs in the ISOLATED S/G loop 0

0

30.

Maintain ISOLATED S/G Level less than 90% NR 0

0

31.

Restore Letdown 0

0

32.

Verify RCS is NOT Water Solid 0

0

33.

Establish a Pzr Bubble 0

0

34.

Maintain Pzr Level 30 to 68%

0 0

35.

Restore Offsite Power 0

0

36.

RCP Restart 0

0

37.

Verify Single Phase Natural Circulation 0

0

38.

Ensure Two Phase Natural Circulation 0

0

39.

Sample for Secondary Activity 0

0

- Continuously Applicable or Non-Sequential Step 47 REVISION NO.:

PROCEDURE TITLE PAGE:

24 STEAM GENERATOR TUBE RUPTURE 45 of 46 PROCEDURE NO..

2-EOP-04 ST. LUCIE UNIT 2 ATIACHMENT2 PLACEKEEPER FOR SGTR (Page 2 of 3)

STEP INSTRUCTIONS STATUS START DONE

20.

HPSI Pump Restart Criteria 0

0

21.

LPSI Pump Stop Criteria 0

0

22.

LPSI Pump Restart Criteria 0

0

23.

Maintain RCS within Figure 1A limits 0

0

24.

Maintain the UNISOLATED S/G Level 60 to 70% NR 0

0

25.

Evaluate Condensate Inventory 0

0

26.

Borate the RCS for SDM 0

0

27.

RCS Cooldown (to SDC) 0 0

28.

Sample RCS for Dilution 0

0

29.

Disable RCPs in the ISOLATED S/G loop 0

0

30.

Maintain ISOLATED S/G Level less than 90% NR 0

0

31.

Restore Letdown 0

0

32.

Verify RCS is NOT Water Solid 0

0

33.

Establish a Pzr Bubble 0

0

34.

Maintain Pzr Level 30 to 68%

0 0

35.

Restore Offsite Power 0

0

36.

RCP Restart 0

0

37.

Verify Single Phase Natural Circulation 0

0

38.

Ensure Two Phase Natural Circulation 0

0

39.

Sample for Secondary Activity 0

0

- Continuously Applicable or Non-Sequential Step 47

REVISION NO.:

PROCEDURE TITLE:

PAGE:

24 PROCEDURE NO.:

STEAM GENERATOR TUBE RUPTURE 46 of 46 2-EOP-04 ST. LUCIE UNIT 2 ATTACHMENT 2 PLACEKEEPER FOR SGTR (Page 3 of 3)

STEP INSTRUCTIONS STATUS START DONE

40.

Monitor Spread of Contamination 0

0

41.

RCS Void Elimination 0

0

42.

Cool and Depressurize the Isolated S/G 0

0

43.

SIT Venting/lsolation 0

0

44.

L TOP Initiation 0

0

45.

Reset Safety Systems 0

0

46.

Exit to SDC Operation 0

- Continuously Applicable or Non-Sequential Step END OF ATTACHMENT 2 48 REVISION NO.

PROCEDURE TITLE:

PAGE:

24 STEAM GENERATOR TUBE RUPTURE 46 of 46 PROCEDURE NO.

2-EOP-04 ST. LUCIE UNIT 2 ATTACHMENT 2 PLACEKEEPER FOR SGTR (Page 3 of 3)

STEP INSTRUCTIONS STATUS START DONE

40.

Monitor Spread of Contamination 0

0

41.

RCS Void Elimination 0

0

42.

Cool and Depressurize the Isolated S/G 0

0

43.

SIT Ventingllsolation 0

0

44.

L TOP Initiation 0

0

45.

Reset Safety Systems 0

0

46.

Exit to SOC Operation 0

(

- Continuously Applicable or Non-Sequential Step END OF ATTACHMENT 2 48

REVISION NO.:

36A PROCEDURE NO.:

2-EOP-99 PROCEDURE TITLE:

APPENDICES I FIGURES I TABLES / DATA SHEETS ST. LUCIE UNIT 2 PAGE:

3 of 156 APPENDIX A SAMPLING STEAM GENERATORS (Page 1 of 2) o 1. !f a LOOP has occurred, Then PERFORM BOTH of the following:

o A. ENSURE 2AB 480V Load Center is aligned to an energized bus.

o B. DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 2B Instrument Air Compressors.

CAUTION A Train (..J)

B Train (..J)

Under SIAS conditions the CCW 'N' header should only be aligned to ONE essential header. This will maintain train separation while safeguards signals are still present.

NOTE HCV-14-9 (HCV-14-10) will open 5 seconds after HCV-14-8A (HCV-14-8B) starts to open When SIAS is present, placing the control switches in CLOSE and then OVERRIDE will open the CCW 'N' header valves, until SIAS is reset o 2. !f SIAS has closed the 'N' Header valves, Then RESTORE flow from EITHER 'A' or 'B' CCW Header by PLACING the control switches for the desired train to CLOSE and then to OVERRIDE:

HCV-14-8A HCV-14-9 OR HCV-14-8B HCV-14-10 49 REVISION NO.

PROCEDURE TITLE:

36A PROCEDURE NO.

APPENDICES! FIGURES! TABLES! DATA SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 1 of 2) o 1. !f a LOOP has occurred, Then PERFORM BOTH of the following:

o A. ENSURE 2AB 480V Load Center is aligned to an energized bus.

o B. DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 2B Instrument Air Compressors.

CAUTION A Train (-J)

PAGE:

3 of 156 B Train CY)

Under SIAS conditions the CCW 'N' header should only be aligned to ONE essential header. This will maintain train separation while safeguards signals are still present.

NOTE HCV-14-9 (HCV-14-10) will open 5 seconds after HCV-14-8A (HCV-14-8B) starts to open It When SIAS is present, placing the control switches in CLOSE and then OVERRIDE will open the CCW 'N' header valves, until SIAS is reset o 2. !f SIAS has closed the 'N' Header valves, Then RESTORE flow from EITHER 'A' or 'B' CCW Header by PLACING the control switches for the desired train to CLOSE and then to OVERRIDE:

HCV-14-8A HCV-14-9 OR HCV-14-S8 HCV-14-10 49

REVISION NO.:

PROCEDURE TITLE:

PAGE:.',"

36A APPENDICES I FIGURES I TABLES I DATA 4 of 156 PROCEDURE NO.:

SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERA TORS (Page 2 of 2) o 3. 11 CIAS or high radiation has closed the SGBD Sample Valves, Then OPEN FCV-23-7 and FCV-23-9 by PLACING the control switch to CLOSE I OVERRIDE and then to OPEN.

0 4. DIRECT Chemistry to perform S/G samples for activity and boron.

0 5. 11 S/Gs cannot be sampled, Then DIRECT Health Physics to conduct secondary plant local area radiation surveys.

END OF APPENDIX A 50 REVISION NO.:

PROCEDURE TITLE:

PAGE:

36A APPENDICES / FIGURES / TABLES / DATA 4 of 156 PROCEDURE NO.

SHEETS 2-EOP-99 ST_ LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 2 of 2) o 3. if CIAS or high radiation has closed the SGBD Sample Valves, Then OPEN FCV-23-7 and FCV-23-9 by PLACING the control switch to CLOSE / OVERRIDE and then to OPEN.

0

4. DIRECT Chemistry to perform S/G samples for activity and boron.

0 5. if S/Gs cannot be sampled, Then DIRECT Health Physics to conduct secondary plant local area radiation surveys.

END OF APPENDIX A

(

50

REVISION NO.:

PROCEDURE TITLE:

PAGE:,

APPENDICES I FIGURES I TABLES I DATA 36A

1:21 of 15'6 PROCEDURE NO.:

SHEETS 2-EOP-99 ST. LUCIE UNIT 2 FIGURE 2 SAFETY INJECTION FLOW VS. RCS PRESSURE (Page 1 of 1) 1300 I

I I

I 1200 NOTE This curve represents minimum expected

~

SI Flow. If measured flow is less than this p

1100 figure, Then SI System lineup should be R

\\\\

verified.

E S

1000 s

\\

U 900*

R I

Z 800

---I-.

E

\\-

R 700 p

\\

R 600 E

\\

s 1 Full Train S

500

< In OPTtion U

~\\

/

R E

400

\\

2 Full Trains in Operation 300 p

~

s 200 i

I\\,

a

--r---.

100

~

0:

0 1000 2000 3000 4000 5000 6000 TOTAL SAFETY INJECTION FLOW (gpm)

(P/OPSI2* EOP*99/Fig2lRev O/tif) 51

(

~---------------------~

REVISION NO_

PROCEDURE TITLE:

PAGE:

36A 121 of 156 PROCEDURE NO_:

APPENDICES / FIGURES / TABLES / DATA SHEETS P

R E

S S

U R

I Z

E R

p R

E S

S U

R E

p s

i a

2-EOP-99 ST. LUCIE UNIT 2 FIGURE 2 SAFETY INJECTION FLOW VS. RCS PRESSURE (Page 1 of 1 )

1300 ----~I I

I I

I I T-'-J 1200 I

- NOTE

+--+---f--_+_--i----__t This curve represents minimum expected II t

SI Flow. If measured flow is less than this 1100 --- ----

figure, Then SI System lineup should be 1-verified.

1000 - \\

900 - -

-t--tT----------~ ~- 1----- -----------+----i----4----- ---- -----f----i 800---- r---+-~_+__-----

~---+_--+_--+_-+_----1 700 I -

--\\- ~-_+_~+____i-___i_~+___+__~\\___+__---+___;I 600 r----

f---

\\

1 Full Train 500

-- in Operation +---j---I----I----+---+---+-----1 400 +----+t~ \\V.

~.... ~2}~!T-r~+~:-~~-+--+---f---+----t:---+----1 300 1

~l----*.----+-----+-----+~+---+----+-------

200-

\\

I-I------~::::jr----...=---t---+----Lr--_

100-1

~~

-r--r--

o ~

,--+

I I '

--+--+-1'----=---+---+---+--+--+--+--+---;--+----..:---+---1 o

1000 2000 3000 4000 5000 6000 TOTAL SAFETY INJECTION FLOW (gpm)

(P/OPS/2-EOP-99/Flg2fRevOltlf) 51

REVISION NO.:

PROCEDURE TITLE:

PAGE:-

36A APPENDICES / FIGURES I TABLES I DATA J:55 of 156 PROCEDURE NO_:

SHEETS 2-EOP-99 ST. LUCIE UNIT 2 TABLE 13 RCP OPERATING LIMITS (Page 1 of 1 )

ACCEPTABLE RANGE OF ACTIONS WHEN CONDITIONS ARE OPERATION OUTSIDE ACCEPTABLE RANGE T COLD must be greater than 500°F for 4 1f T COLD is approaching or is less than 500°F, RCPs to be RUNNING.

Then ENSURE at least ONE RCP is STOPPED.

RCS Pressure Temperature is above MONITOR RCP instrumentation for and to the left of the RCP NPSH cavitation or seal failure requirement curve of Figure 1 A or 1 B,

If cavitation or multiple seal failure is RCS Pressure Temperature.

indicated, Then STOP the affected RCPs Guide bearing temperatures are less STOP the affected RCPs.

than 185°F.

Thrust bearing temperatures are less STOP the affected RCPs.

than 200°F.

CCW flow greater than 200 gpm.

If CCW flow is lost and can NOT be re-established within 10 minutes Then STOP the affected RCPs.

Oil Reservoir Levels +2 to -2 inches.

If valid, rapidly changing or full scale high or low indicated level in either the upper or lower oil reservoir Then STOP the affected RCPs.

Controlled Bleedoff and Lower Cavity If Controlled Bleedoff or Lower Seal Cavity Seal temperature is less than 250°F.

temperature is greater than or equal to 250°F, Then STOP the affected RCPs.

END OF TABLE 13 52 REVISION NO, PROCEDURE TITLE PAGE 36A APPENDICES / FIGURES / TABLES / OAT A 155 of 156 PROCEDURE NO,'

SHEETS 2-EOP-99 ST. LUCIE UNIT 2 TABLE 13 RCP OPERATING LIMITS (Page 1 of 1 )

ACCEPTABLE RANGE OF ACTIONS WHEN CONDITIONS ARE OPERATION OUTSIDE ACCEPTABLE RANGE T COLD must be greater than 500°F for 4 If T COLD is approaching or is less than 500°F, RCPs to be RUNNING, Then ENSURE at least ONE RCP is STOPPED.

RCS Pressure Temperature is above MONITOR RCP instrumentation for and to the left of the RCP NPSH cavitation or seal failure requirement curve of Figure 1 A or 1 B,

If cavitation or multiple seal failure is RCS Pressure Temperature.

indicated, Then STOP the affected RCPs Guide bearing temperatures are less STOP the affected RCPs.

than 185°F, Thrust bearing temperatures are less STOP the affected RCPs.

than 200°F,

(

CCW flow greater than 200 gpm.

If CCW flow is lost and can NOT be re-established within 10 minutes Then STOP the affected RCPs.

Oil Reservoir Levels +2 to -2 inches.

If valid, rapidly changing or full scale high or low indicated level in either the upper or lower oil reservoir Then STOP the affected RCPs.

Controlled Bleedoff and Lower Cavity If Controlled Bleedoff or Lower Seal Cavity Seal temperature is less than 250°F, temperature is greater than or equal to 250°F, Then STOP the affected RCPs, END OF TABLE 13 52

REVISION NO:

36A PROCEDURE NO.:

2-EOP-99 PROCEDURE TITLE:

APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX J RESTORATION OF CCW AND CBO TO THE RCPs (Page 1 of 2)

PAGE:.;

62 of 156 o 1. ENSURE Instrument Air to Containment is available by PLACING HCV-18-1 to CLOSE I OVERRIDE and then to OPEN.

CAUTION Under SIAS conditions the CCW 'N' header should only be aligned to ONE essential header. This will maintain train separation while safeguards signals are still present.

NOTE HCV-14-9 (HCV-14-10) will open 5 seconds after HCV-14-8A (HCV-14-8B) starts to open.

When SIAS is present, placing the control switches in CLOSE and then OVERRIDE will open the CCW 'N' header valves, until SIAS is reset.

o 2. !f SIAS has closed the 'N' Header valves, Then RESTORE flow from EITHER 'A' or 'B' CCW Header by PLACING the control switches for the desired train to CLOSE and then to OVERRIDE:

HCV-14-8A 'N' Hdr Isol Discharge HCV-14-9 'N' Hdr Isol Suction OR HCV-14-88 'N' Hdr Isol Discharge HCV-14-10 'N' Hdr Isol Suction o 3. ALIGN CCW to I from the RCPs by OPENING ALL of the following valves:

o HCV-14-1, CCWTo RC PUMP o HCV-14-2, CCW From RC PUMP o HCV-14-7, CCW To RC PUMP o HCV-14-6, CCW From RC PUMP o 4. !f CIAS has isolated controlled bleedoff flow to the VCT, Then OPEN V2507, RCP Bleedoff Relief Stop Vlv.

53

(

REVISION NO

36A PROCEDURE NO.*

2-EOP-99 PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX J RESTORATION OF CCW AND CSO TO THE RCPs (Page 1 of 2)

PAGE.

62 of 156 o 1. ENSURE Instrument Air to Containment is available by PLACING HCV-1S-1 to CLOSE I OVERRIDE and then to OPEN.

CAUTION Under SIAS conditions the CCW 'N' header should only be aligned to ONE essential header. This will maintain train separation while safeguards signals are still present.

NOTE HCV-14-9 (HCV-14-1 0) will open 5 seconds after HCV-14-SA (HCV-14-SB) starts to open.

When SIAS is present, placing the control switches in CLOSE and then OVERRIDE will open the CCW 'N' header valves, until SIAS is reset.

o 2. 11 SIAS has closed the 'N' Header valves, Then RESTORE flow from EITHER 'A' or 'B' CCW Header by PLACING the control switches for the desired train to CLOSE and then to OVERRIDE:

HCV-14-SA 'N' Hdr Isol Discharge HCV-14-9 'N' Hdr Isol Suction OR HCV-14-SB 'N' Hdr Isol Discharge HCV-14-10 'N' Hdr Isol Suction o 3. ALIGN CCW to I from the RCPs by OPENING ALL of the following valves:

o HCV-14-1, CCWTo RC PUMP o HCV-14-2, CCW From RC PUMP o HCV-14-7, CCW To RC PUMP o HCV-14-6, CCW From RC PUMP o 4. If CIAS has isolated controlled bleedoff flow to the VCT, Then OPEN V2507, RCP Bleedoff Relief Stop Vlv.

53

REVISION NO.:

36A PROCEDURE NO,:

2-EOP-99 PROCEDURE TITLE:

APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX J RESTORATION OF CCW AND CSO TO THE RCPs (Page 2 of 2)

CAUTION PAGE:

'63 of 156 RCP Seal Cooler isolation valves automatically close on high Seal Cooler outlet temperature of 200°F. Maintaining the control switch in the OPEN position will override this function. CCW radiation monitors should be closely monitored for indication of RCS to CCW leakage should conditions warrant the valve(s) to be maintained in the open position. Consideration should be given to returning the control switch(es) to the AUTO position once the valves have been opened.

o 5. ENSURE ALL RCP Seal Cooler Isolation valves are OPEN:

o HCV 11-A 1, CCW From 2A 1 RCP Seal Cooler o HCV-14-11-A2, CCW From 2A2 RCP Seal Cooler o HCV-14-11-B1, CCW From 2B1 RCP Seal Cooler o HCV-14-11-B2, CCW From 2B2 RCP Seal Cooler o 6. VERIFY RCP CCW related alarms are CLEAR or have been evaluated and dispositioned.

END OF APPENDIX J 54

(

REVISION NO.

36A PROCEDURE NO.

2-EOP-99 PROCEDURE TITLE:

APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX J RESTORATION OF CCW AND CSO TO THE RCPs (Page 2 of 2)

CAUTION PAGE:

63 of 156 RCP Seal Cooler isolation valves automatically close on high Seal Cooler outlet temperature of 200°F. Maintaining the control switch in the OPEN position will override this function. CCW radiation monitors should be closely monitored for indication of RCS to CCW leakage should conditions warrant the valve(s) to be maintained in the open position. Consideration should be given to returning the control switch( es) to the AUTO position once the valves have been opened.

D 5. ENSURE ALL RCP Seal Cooler Isolation valves are OPEN:

D HCV-14-11-A 1, CCW From 2A 1 RCP Seal Cooler D HCV-14-11-A2, CCW From 2A2 RCP Seal Cooler D HCV-14-11-B1, CCW From 2B1 RCP Seal Cooler D HCV-14-11-B2, CCW From 2B2 RCP Seal Cooler D 6. VERIFY RCP CCW related alarms are CLEAR or have been evaluated and dispositioned.

END OF APPENDIX J 54

Appendix D IIOPTestNo.:

1 II Event

Description:

II II I

Time Position Operator Action Form ES-D-2 Scenario #

3 Event #

_6~,~7'...;;8.:..;' 9;..-. __ Page 12-of _1;.;;..9 __ 1 2-EOP-04 Steam Generator Tube Rupture. SIAS B side does not actuate. 2B HPSI pump does not start. 2A HPSI pump becomes air bound. 2B MSIV does not close from the control room. Isolate the 2B SG.

A plica nt's Actions or Behavior r--B-~oth Operator Instructions:

If SNPO called to investigate 2A HPSI pump, state the pump appears OK.

Trigger vent 2A HPSI pump when asked to vent the 2A HPSI pump. Wait 5 minutes and report back the 2A HPSI has been vented and a large volume of air was vented.

Indications Available: 2A HPSI pump Amps oscillating.

\\----

i I Direct RO to depressurize RCS lAW step 11 EOP-04 I

I I i

Within Figure 1A (attached page_56_)

I SRO I

<930 psia i

i I

Above RCP minimum pressure i

i i

Approx. Equal to 2A SG pressure (within 50 psia)

Recognize SIAS B side did not actuate at setpoint of 1736 psia.

I Directs manual actuation of B side SIAS t-------

r--

i Critical Recognize 2B HPSI pump failed to start upon B side SIAS i

Task actuation. Directs manual start of 2B HPSI pump.

I I I I

Recognize 2A HPSI pump low amps. Direct stopping 2A HPSI I !

I pump. Direct BOP to notify SNPO to investigate 2A HPSI I I pump.

~...... -

i Direct venting 2A HPSI pump I

I f---~

i Direct starting the 2A HPSI pump when venting complete r--'~

I Critical Direct MSIS blocked when block permissive received at 685 I

I 1

~ _______ ~

__ !ask _

psia.(must be done before MSIS occurs at 600 psia) 55 Appendix D Operator Action Form ES-D-2 I

I' II ii Op Test No.

1 II Event

Description:

I,

i

,i I:

,~

Scenario #

3 Event #

6,7,8,9 Page 16 of ~9 2-EOP-04 Steam Generator Tube Rupture. SIAS B side does not actuate. 2B HPSI pump does not start 2A HPSI pump becomes air bound. 2B MSIV does not close from the control room. Isolate the 2B SG.

Position A plicant's Actions or Behavior

! Booth Operator Instructions:

If SNPO called to investigate 2A HPSI pump, state the pump appears OK.

Trigger vent 2A HPSI pump when asked to vent the 2A HPSI pump. Wait 5 minutes and report back the 2A HPSI has been vented and a large I

volume of air was vented.

II~dications Available: 2A HPSI pump Amps oscillating.

1--

I I Direct RO to depressurize RCS lAW step 11 EOP-04 I

I. Within Figure 1A (attached page 56 )

1 - -

SRO

<930 psia Above RCP minimum pressure Approx. Equal to 2A SG pressure (within 50 psia)

C-_____.j __

I J----.. --

.--.--~-

---~--

I Recognize SIAS 8 side did not actuate at setpoint of 1736 psia.

Directs manual actuation of B side SIAS I

I t-_**

I Critical I Recognize 28 HPSI pump failed to start upon B side SIAS Task actuation. Directs manual start of 2B HPSI pump.

I

-~

Recognize 2A HPSI pump low amps. Direct stopping 2A HPSI i

pump. Direct BOP to notify SNPO to investigate 2A HPSI pump.

j I

I

~ - _. _... --- --.

i i Direct venting 2A HPSI pump I

i

~-~--_j__i ----------------------------ii I Direct starting the 2A HPSI pump when venting complet~~

Critical I Direct MSIS blocked when block permissive received at 685 Task

! psia.(must be done before MSIS occurs at 600 psia) i

___._. ___________. ____ l.. ___.. _______ ~. ____________________ ---' 55

~-----~~-

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36A APPENDICES I FIGURES I TABLES I DATA 119 of 156 PROCEDURE NO.

SHEETS 2-EOP-99 ST. LUCIE UNIT 2 FIGURE 1A RCS PRESSURE TEMPERATURE (Page 1 of 1)

(Containment Temperature Less Than or Equal to 200°F)

CAUTION The RCP NPSH curve assumes one pump is operating in each loop. RCP instrumentation should be monitored for seal and pump performance in accordance with 2-EOP-99, Table 13.

"00 I'"--'*~:"::*=~=-~ 1--:J~---

OII"""*" INly rc'l'lW,lon k> it1r$ t.(l1:;tK)n ~

t:n~ pt'CCiH!UO )h41l ylll>tr the VIII!dty 01 ~

OPl'"IIlror A,d and 11 cfl~nQrC~ 'M r.c.;;u~ry, MI:#y the EOPC'..QOI"OlI"\\i()tOl) 2200 Acceplable

"'00-!

2000 1800 Maximum

/

Su!)cooled' ',.

1600

~

1400 1!

CL l;

f I

~

1Z00

.1 I

\\

1!

I

\\

CL I

\\

II I

1

\\

~

1000 I

E I

MInimum I

Subcooled' I

800 I

RCP NPSH I

ReqUlremenl' "-

I I

I

~,

I 600

~.

~/

400

~Includes lm,tnJmen1 UncertaH,j~'S 200 Shutdown Envelop.;- ~

0

-:/

0 100 200 300 400 500 600 700 800 Indicaled RCS Temperalure (F) 1-'"<;<-'I'v'J I< :}~'.~I.~ 1 Mk"" :.~",

RCS Pressure Range Required QSPDS Subcooled Margin Reading (Rep CET) 2250 psi a to 1000 psia 40 to 180°F 1000 psia to 500 psi a 50 to 170°F Less than 500 psia 80 to 160°F 56 REVISION NO.:

PROCEDURE TITLE:

PAGE:

36A APPENDICES I FIGURES I TABLES I DATA 119 of 156 PROCEDURE NO.

SHEETS 2-EOP-99 ST. LUCIE UNIT 2 FIGURE 1A RCS PRESSURE TEMPERATURE (Page 1 of 1 )

(Containment Temperature Less Than or Equal to 200°F)

CAUTION The RCP NPSH curve assumes one pump is operating in each loop. RCP instrumentation should be monitored for seal and pump performance in accordance with 2-EOP-99, Table 13.

""" I[O_*.. *~:..:':-==-~f -:J~---

001-'<.... IAny I,*,,*t$l£ln 10 1/"0'$ t,.(j1:tt>n ot tn~ DfCC.ol'OI.Io ~h41l y\\l7>'1'r tho VIII!d:tyol tre OPl'"lolYr A,d and 11 C/1<l'noo ~I" J)OCI;!s:>ary. noUy!he EOPf'"QOI"(lll"\\(ltOlJ 2200 Acceptable

".~. !

2000 1800

(

Maximum

I Suixooled'.,.

1600 g

~

1400

~

l' (l.

if v

':J

~

1Z00 I

\\

l' (l.

I

\\

I

\\

I

\\

~

1000 I

I MInimum I

I Subcooled' 600 I

RCP NPSH I

Reqwremenl" ""'-

I I

I

~'-

I 600 I*

I

~/

400

~Includes !n~tT1Jmen1 Unctirt<unhes 200 Shutdown EnveloPl' ~

a

-/

a lOa 200 300 400 500 600 700 600 Indicated RCS Tempe, ature (F)

I-V-'~'J ".>~q.;':1 --3 l~,Jf"" :-".

RCS Pressure Range Required QSPDS Subcooled Margin Reading (Rep CET) 2250 psi a to 1000 psia 40 to 180°F 1000 psia to 500 psia 50 to 170°F Less than 500 psia 80 to 160°F 56

Appendix D Op Test No.:

Event

Description:

Operator Action Form ES-D-2 Scenario #

3 Event #

_6_."-'7.'-8.... _9___ Page 1Z-of _1_9_-i1 2-EOP-04 Steam Generator Tube Rupture. SIAS B side does not actuate. 2B HPSI pump does not start. 2A HPSI pump becomes air bound. 2B MSIV does not close from the control room. Isolate the 2B SG.

Time II Position

~

Applicant's Actions or Behavior I Booth Operator Instructions:

I Indications Available:

SRO Directs BOP to isolate 2B Steam Generator when Thot is Critical

<510oF lAW 2-EOP~99, Appendix R (attached page_58~60_)

Task Critical

. Direct performance of 2~EOP-99 Appendix I, MSIV local Task

! closure, to close HCV~08-1 B, 2B MSIV (attached page_62_)

I I

----- -_.. _---1---_.

i !,.. _---_.

I' I

I i

I I

i I

I I

(

Appendix D Operator Action Form ES-D-2 Op Test No.'

1 Scenario #

3 Event #

_6""'.;.07 '.;.08;.:..' _9___ Page

_1 7_ of _1_9_.."

Event

Description:

2-EOP-04 Steam Generator Tube Rupture. SIAS B side does not actuate. 2B HPSI pump does not start. 2A HPSI pump becomes air bound. 2B MSIV does not close from the control room. Isolate the 2B SG.

Time J

Position II Applicant's Actions or Behavior I Booth Operator Instructions:

I i Indications Available:

SRO Critical Task I

Critical i

Task i

I

~-.-~- -

_.-._-----1---_..

1-- -_.--- -----

i I r-I I

I I

Directs BOP to isolate 28 Steam Generator when Thot is

<510°F lAW 2-EOP-99, Appendix R (attached page_58-60_)

Direct performance of 2-EOP-99 Appendix I, MSIV local

. closure, to close HCV-08-1 8, 28 MSIV (attached page_62_)

i I 57 I

I i I

I I :

I i I I

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36A PROCEDURE NO.:

2-EOP-99 APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 4 of 6)

Section 2: 2B Steam Generator Isolation CAUTION 93 of 156 If S/G isolation is due to a SGTR the secondary plant may have higher than normal radiation levels. Contact Health Physics for area accessibility instructions.

o 1. ENSURE HCV-08-1 B, Main Steam Header 'B' Isolation Valve (MSIV), is CLOSED.

o 2. if HCV-08-1 B did not close remotely, Then PERFORM local closure.

REFER TO Appendix I, MSIV Local Closure.

o 3. ENSURE MV-08-1 B, MSIV Header 'B' Bypass Valve, is CLOSED.

NOTE Instrument air must be available to close MFIVs using RTGB control switch.

If instrument air is NOT available when MFIV closure is required, then manual initiation of MSIS should be considered.

o 4. ENSURE HCV-09-2A, Main Feedwater Header 'B' Isolation Valve, is CLOSED.

o 5. ENSURE HCV-09-2B, Main Feedwater Header 'B' Isolation Valve, is CLOSED.

o 6. if BOTH HCV-09-2A and HCV-09-2B, Main Feedwater Isolation Valves to S/G 2B, are NOT CLOSED or suspected of leaking, Then PERFORM ANY of the following AS NECESSARY:

o A. ENSURE ALL of the following valves are CLOSED:

o MV-09-6, Stm Gen 2B Reg Block Valve o LCV-9006, 2B 15% Bypass o MV-09-4, 2B 100% Bypass o B. STOP BOTH Main Feedwater Pumps.

o 7. ENSURE FCV-23-5, 2B SG Blowdown, is CLOSED.

58

(

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36A PROCEDURE NO..

2-EOP-99 APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 4 of 6)

Section 2: 2B Steam Generator Isolation CAUTION 93 of 156 If S/G isolation is due to a SGTR the secondary plant may have higher than normal radiation levels. Contact Health Physics for area accessibility instructions.

D 1. ENSU RE HCV-08-1 B, Main Steam Header 'B' Isolation Valve (MSIV), is CLOSED.

D 2. !f HCV-08-1 B did not close remotely, Then PERFORM local closure.

REFER TO Appendix I, MSIV Local Closure.

D 3. ENSURE MV-08-1 B, MSIV Header 'B' Bypass Valve, is CLOSED.

NOTE Instrument air must be available to close MFIVs using RTGB control switch.

If instrument air is NOT available when MFIV closure is required, then manual initiation of MSIS should be considered.

D 4. ENSURE HCV-09-2A, Main Feedwater Header 'B' Isolation Valve, is CLOSED.

D 5. ENSURE HCV-09-2B, Main Feedwater Header 'B' Isolation Valve, is CLOSED.

D 6. !f BOTH HCV-09-2A and HCV-09-2B, Main Feedwater Isolation Valves to S/G 2B, are NOT CLOSED or suspected of leaking, Then PERFORM ANY of the following AS NECESSARY:

D A. ENSURE ALL of the following valves are CLOSED:

D MV-09-6, Stm Gen 2B Reg Block Valve D LCV-9006, 2B 15% Bypass D MV-09-4, 2B 100% Bypass D B. STOP BOTH Main Feedwater Pumps.

D 7. ENSURE FCV-23-5, 2B SG Blowdown, is CLOSED.

58

REVISION NO.:

PROCEDURE TITLE:

PAGE: -.'

36A PROCEDURE NO.:

2-EOP-99 APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 5 of 6)

Section 2: 2B Steam Generator Isolation (continued) o 8. ENSURE FCV-23-6, 2B SG Blowdown, is CLOSED.

o 9. ENSURE MV-OB-19B, 2B S/G Atmos Dump Vlv, is CLOSED.

o 10.CLOSE MV-08-17, 2B S/G ADV Isol.

o 11. PLACE the control switch for auxiliary feed, Pump 2B, in STOP.

o 12.ENSURE MV-09-10, Pump 2B Disch to SG 2B Valve, is CLOSED.

o 13.ENSURE MV-09-12, Pump 2C to SG 2B, is CLOSED.

o 14.PLACE MV-08-12, SG 2B Stm to AFW PP 2C, in CLOSE.

o 1S.ENSURE MV-OB-1BB, 2B S/G Atmos Dump Vlv, is CLOSED.

o 16.CLOSE MV-08-16, 2B S/G ADV Isol.

o 17. PERFORM the following LOCAL operations:

o A. UNLOCK and CLOSE V0915B, 2C AFW Pump to 2B S/G Isolation.

o B. UNLOCK and CLOSE V09136, 2B AFW Pump to 2B S/G Isolation.

o C. CLOSE SE-08-1, Main Steam to 2C AFW Pump Warm-up Valve Solenoid.

o D. !f SE-08-1, Main Steam to 2C AFW Pump Warm-up Valve Solenoid is NOT CLOSED or suspected of leaking, Then CLOSE V08883, SE-08-1 Inlet Isolation.

(continued on next page) 59

(

{

REVISION NO 36A PROCEDURE NO.:

2-EOP-99 PROCEDURE TITLE:

APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 5 of 6)

Section 2: 2B Steam Generator Isolation (continued) o 8. ENSURE FCV-23-6, 2B SG Blowdown, is CLOSED.

o 9. ENSURE MV-08-19B, 2B S/G Atmos Dump Vlv, is CLOSED.

o 10.CLOSE MV-08-17, 2B S/G ADV Isol.

o 11. PLACE the control switch for auxiliary feed, Pump 2B, in STOP.

o 12. ENSURE MV-09-10, Pump 2B Disch to SG 2B Valve, is CLOSED.

o 13.ENSURE MV-09-12, Pump 2C to SG 2B, is CLOSED.

o 14. PLACE MV-08-12, SG 2B Stm to AFW PP 2C, in CLOSE.

o 15. ENSURE MV-08-18B, 2B S/G Atmos Dump Vlv, is CLOSED.

o 16.CLOSE MV-08-16, 2B S/G ADV Isol.

o 17. PERFORM the following LOCAL operations:

PAGE:

,94 of 156 o A. UNLOCK and CLOSE V09158, 2C AFW Pump to 2B S/G Isolation.

o B. UNLOCK and CLOSE V09136, 2B AFW Pump to 2B S/G Isolation.

o C. CLOSE SE-08-1, Main Steam to 2C AFW Pump Warm-up Valve Solenoid.

o D. If SE-08-1, Main Steam to 2C AFW Pump Warm-up Valve Solenoid is NOT CLOSED or suspected of leaking, Then CLOSE V08883, SE-08-1 Inlet Isolation.

(continued on next page) 59

REVISION NO.:

36A PROCEDURE NO.:

2-EOP-99 PROCEDURE TITLE:

APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 6 of 6)

Section 2: 28 Steam Generator Isolation (continued) 17. (continued)

PAGE:

95 of 156 o E. !f MV-08-12, S/G 2B Steam to AFW Pump 2C, is NOT CLOSED or suspected of leaking, Then PERFORM ANY of the following AS NECESSARY:

D 1. Locally CLOSE MV-08-12 using the handwheel.

D 2. ISOLATE steam to 2C AFW Pump as follows:

D a. CLOSE MV-08-3, 2C Pump.

o b. Locally CLOSE the following valves:

o V08622, CB #67 Drain o V08618, Drain off MV-08-3 Isol o V08619, Drain off MV-08-3 Isol End of Section 2 END OF APPENDIX R 60

(

REVISION NO..

36A PROCEDURE NO..

2-EOP-99 PROCEDURE TITLE:

APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 6 of 6)

Section 2: 28 Steam Generator Isolation (continued)

17. (continued)

PAGE 95 of 156 o E. !f MV-08-12, S/G 2B Steam to AFW Pump 2C, is NOT CLOSED or suspected of leaking, Then PERFORM ANY of the following AS NECESSARY:

o 1. Locally CLOSE MV-08-12 using the handwheel.

o 2. ISOLATE steam to 2C AFW Pump as follows:

o a. CLOSE MV-08-3, 2C Pump.

o b. Locally CLOSE the following valves:

o V08622, CB #67 Drain o V08618, Drain off MV-08-3 Isol o V08619, Drain off MV-08-3 Iso!

End of Section 2 END OF APPENDIX R 60

Appendix D Op Test No.:

Event

Description:

Operator Action Form ES-D-2 1

Scenario #

3 Event #

~6.:.:...7:..;. 8;;.:.,...;;,9 ___ Page 1L of _1..;.,9 __

1 2-EOP-04 Steam Generator Tube Rupture. SIAS 8 side does not actuate. 28 HPSI pump does not start. 2A HPSI pump becomes air bound. 28 MSIV does not close from the control room. Isolate the 28 SG.

il Ii

!F, =-=Ti-m~e=-~II~~p~o~si~tio-n--~i--=----=-=---=~A~ppll~ic=an~t'~s~A-ct~io-n~s-or~8~e~h-av~io-r----==--==--==91

. Booth Operator Instructions:

Indications Available:

RO

--+--

I I

'-'-'---'--~

I i

1 I

I f-*--"

I I

j **.. '._-.

i i

I Stop one RCP in each Loop when directed Monitor RCP's for operating limits lAW Table 13 (attached page_52_)

Cooldown the RCS to <510°F T hot using S8CS, in manual, not to exceed 100°F in anyone hour period.

When directed, depressurize the RCS lAW step 11 EOP-04.

Examiners Note: Use of Main or Auxiliary spray is acceptable.

Within Figure 1A (attached page_56_)

<930 psia Above RCP minimum pressure Approx. Equal to 2A SG pressure (within 50 psia)

Suggested termination point:

28 HPSI is started and 2A HPSI is vented and running 2B SG is isolated lAW Appendix R 28 MSIV is closed

- 61 I

(

Appendix D Op Test No.:

Event

Description:

Time J Position

... ~--. ----------

Operator Action Form ES-D-2 Scenario #

3 Event #

6,7,8, 9 Page

_19_ of _19_-1 1

2-EOP-04 Steam Generator Tube Rupture. SIAS B side does not actuate. 2B HPSI pump does not start. 2A HPSI pump becomes air bound. 2B MSIV does not close from the control room. Isolate the 2B SG.

Applicant's Actions or Behavior Booth Operator Instructions:

.--.-~-

Indications Available:

RO Stop one RCP in each Loop when directed

~----~ -

.-~.. ---~.

Monitor RCP's for operating limits lAW Table 13 (attached page_ 52 -)

~--*~-t I

1 I

Cooldown the RCS to <510°F Thol using SBCS, in manual, not to exceed 100°F in anyone hour period.

I i

I I I

When directed, depressurize the RCS lAW step 11 EOP-04.

Examiners Note: Use of Main or Auxiliary spray is acceptable.

Within Figure 1 A (attached page_56_)

i I

I

<930 psi a Above RCP minimum pressure Approx. Equal to 2A SG pressure (within 50 psia)

I 1.... -----'------+-------------------- 1 Suggested termination pOint:

I 2B HPSI is started and 2A HPSI is vented and running I

2B SG is isolated lAW Appendix R 2B MSIV is closed i

j I

I

~

~-------~-------------------------------- 61

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36A PROCEDURE NO.:

2-EOP-99 APPENDICES / FIGURES / TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX I MSIV LOCAL CLOSURE (Page 1 of1) 61 of 156 o 1. To locally CLOSE HCV-08-1A, 2A S/G MSIV, PERFORM the following:

o A. CLOSE V181197, Inst Air to 2A MSIV - Air Accum & HCV-08-1A Isol.

(Inside Steam Trestle just North of 2A MSIV) o B. CLOSE local instrument valve for PS-08-12A.

(Inside Steam Trestle just North of 2A MSIV) o C. REMOVE T-Handle swaglock cap from PS-08-12A test connection.

(Inside Steam Trestle just North of 2A MSIV)

CAUTION Loud noise and air blowing when venting; stay clear of vent path.

o D. OPEN PS-08-12A local instrument valve to bleed air from system through the test connection.

o 2. To locally CLOSE HCV-08-1 B, 2B S/G MSIV, PERFORM the following:

o A. CLOSE V181195, Inst Air to 2B MSIV - Air Accum & HCV-08-1 B Isol.

(Inside West of Steam Trestle door entrance) o B. CLOSE V08423, PS-08-12B Isol.

(Inside West of Steam Trestle door entrance) o C. REMOVE T -handle swag lock cap from PS-08-12B test connection.

(Inside Steam Trestle just South of 2B MSIV) o D. OPEN V08423, PS-08-12B Isol to bleed air from system through the test connection.

END OF APPENDIX I

~

w

~----------------------------------------------------------~ ~

62

(

REVISION NO.:

PROCEDURE TITLE:

PAGE:

36A APPENDICES / FIGURES / TABLES / DATA SHEETS 61 of 156 PROCEDURE NO.:

2-EOP-99 ST. LUCIE UNIT 2 APPENDIX I MSIV LOCAL CLOSURE (Page 1 of 1) o 1. To locally CLOSE HCV-08-1A, 2A S/G MSIV, PERFORM the following:

o A. CLOSE V181197, Inst Air to 2A MSIV - Air Accum & HCV-08-1A Isol.

(Inside Steam Trestle just North of 2A MSIV) o B. CLOSE local instrument valve for PS-08-12A.

(Inside Steam Trestle just North of 2A MSIV) o C. REMOVE T-Handle swag lock cap from PS-08-12A test connection.

(Inside Steam Trestle just North of 2A MSIV)

CAUTION Loud noise and air blowing when venting; stay clear of vent path.

I o D. OPEN PS-08-12A local instrument valve to bleed air from system through the test connection, o 2. To locally CLOSE HCV-08-1 B, 2B S/G MSIV, PERFORM the following:

o A. CLOSE V181195, Inst Air to 2B MSIV - Air Accum & HCV-08-1 B Isol.

(Inside West of Steam Trestle door entrance) o B. CLOSE V08423, PS-08-12B Isol.

(Inside West of Steam Trestle door entrance) o C. REMOVE T-handle swaglock cap from PS-08-12B test connection.

(Inside Steam Trestle just South of 2B MSIV) o D. OPEN V08423, PS-08-12B Isol to bleed air from system through the test connection, END OF APPENDIX I

0 w

OJ

~------------------------------------------------------------~ ~

62

Appendix D Scenario Outline Form ES-D-1 Facility:

St. Lucie Scenario No.:

5 Op Test No.:

HLC-19 NRC Examiners:

Operators:

SRO:

RO:

BOP:

Initial Conditions:

IC-14, 30% power, MOL. 6 gpm dilution to compensate for Xenon. 2B Main Feedwater pump is out of service to replace the oil cooler. 2C Charging pump is out of service for repack.

Turnover: Crew is to perform an up power to 45% power. 2B Main Feedwater pump is out of service to replace the oil cooler. Not expected back this shift. 2C Charging pump is out of service for repack. Chemistry limits have been cleared to perform an up power within the capacity of the operating Main Feedwater pump.

Critical Tasks:

Close 2A Diesel output breaker Crosstie 2A AFW pump to feed 2B SG Event Malf.

Event Event No.

No.

Type*

Description 1

R/RO Power increase to approximately 45%.

N/BOP 2

1 C/RO Loss of 2B Component Cooling Water Pump T.S, SRO 3

2 II RO Selected Pressurizer Level Channel L T 111 OX fails high 1----.

4 3

1.S, SRO PORV 1474 Acoustic Monitor fails f- ----

5 4

C/BOP Loss of Sups Vital AC Bus Inverter. Stabilize the plant after C/RO alternate source has energized the Vital AC bus.

6 5

M I All LOOP I Loss of Feedwater 7

6 C/BOP 2B Diesel does not start, 2A Diesel output breaker does not close 8

7 C/BOP 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open 9

8 C/BOP Crosstie 2A AFW pump to feed 2B Steam Generator (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 Appendix D Scenario Outline Form ES-D-1 Facility:

St. Lucie Scenario No.:

5 Op Test No.:

HLC-19 NRC Examiners:

Operators:

SRO:

RO:

BOP:

Initial Conditions:

IC-14, 30% power, MOL. 6 gpm dilution to compensate for Xenon. 2B Main Feedwater pump is out of service to replace the oil cooler. 2C Charging pump is out of service for repack.

Turnover: Crew is to perform an up power to 45% power. 2B Main Feedwater pump is out of service to replace the oil cooler. Not expected back this shift. 2C Charging pump is out of service for repack. Chemistry limits have been cleared to perform an up power within the capacity of the operating Main Feedwater pump.

Critical Tasks:

Close 2A Diesel output breaker Crosstie 2A AFW pump to feed 2B SG Event Malf.

Event Event No.

No.

Type*

Description 1

R/RO Power increase to approximately 45%.

(

N/BOP 2

1 C/RO Loss of 2B Component Cooling Water Pump T.S. SRO 3

2 II RO Selected Pressurizer Level Channel L T 111 OX fails high

~-

4 3

T.S. SRO PORV 1474 Acoustic Monitor fails 5

4 C/BOP Loss of Sups Vital AC Bus Inverter. Stabilize the plant after C/RO alternate source has energized the Vital AC bus.

6 5

M I All LOOP I Loss of Feedwater 7

6 C/BOP 2B Diesel does not start. 2A Diesel output breaker does not close 8

7 CI BOP 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open 9

8 C/BOP Crosstie 2A AFW pump to feed 2B Steam Generator

~,

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1

Scenario Event Description NRC Scenario 5 st. Lucie The unit will be turned over to the crew at 30% power. The 2B Main Feedwater Pump is out of service to replace the oil cooler. The crew will increase power to approximately 45%.

A loss of the 2B Component Cooling water pump will require the crew to swap the AB electrical to the B side to take T,S. credit for the 2C Component Cooling water pump, Selected Pressurizer Level L T 1110X fails high requiring the RO to swap level channels, Acoustic monitor for PORV 1474 will annunciate and fail high. The crew will determine this failure is only instrument failure and not a leaking PORV, The SRO is to evaluate T.S, for accident monitoring, A loss of the 2A Sups Vital bus inverter will occur during the up power. Numerous secondary alarms and loss of instrumentation will occur. The alternate dump valves on the heaters will open in addition to loss of DEH turbine control. The Vital bus can be re-energized from the alternate source. Plant stabilization will be required due to secondary perturbation, A LOOP combined with a loss of feedwater will occur. The 2B Diesel will not start and the 2A Diesel output breaker will not close. The output breaker can be closed from the RTGB, The 2C AFW pump will trip on AFAS or manual start and cannot be restarted. The 2A AFW pump MV-09-9, 2A AFW pump to 2A SG, will not open. The crew is expected to crosstie the 2A AFW pump to feed the 2B SG.

The Crew will probably enter 2-EOP-09. LOOP, LOFC prior to entering 2-EOP-06 due to AFAS-2 actuating approximately 15 minutes after the trip and AFAS-1 actuating approximately 20 minutes after the trip, 2-EOP-06 Total Loss of Feedwater will be entered, The scenario can be terminated when the crew has closed the 2A Diesel output breaker and the 2B SG is being fed by the 2A AFW pump, Procedures Used 2-GOP-201, Reactor Plant Startup - Mode 2 to Mode 1 2-GOP-1 01, Reactor Operating Guidelines During Steady State and Scheduled Load Changes 2-GOP-502, Data Sheets Required for Heatup 2-0NP-49,01, SUPS - NON - Safety Vital AC ISFSI Security or Fire and Security Inverter Malfunction 2-0310030, Component Cooling Water - Off-Normal Operation 2-NOP-52,02 Alignment Of 2AB Buses And Components 2-0120035, Pressurizer Pressure and Level 2-EOP-01, Standard Post Trip Actions 2-EOP-06, Total Loss of Feedwater 2-0NP-09,02, Auxiliary Feedwater Technical Specifications Entered 3.7,3 Component Cooling Water System 3,3,3,6 Accident Monitoring 2

(

Scenario Event Description NRC Scenario 5 st. Lucie The unit will be turned over to the crew at 30% power. The 2B Main Feedwater Pump is out of service to replace the oil cooler. The crew will increase power to approximately 45%.

A loss of the 2B Component Cooling water pump will require the crew to swap the AB electrical to the B side to take T.S. credit for the 2C Component Cooling water pump.

Selected Pressurizer Level L T 111 OX fails high requiring the RO to swap level channels.

Acoustic monitor for PORV 1474 will annunciate and fail high. The crew will determine this failure is only instrument failure and not a leaking PORV. The SRO is to evaluate T.S. for accident monitoring.

A loss of the 2A Sups Vital bus inverter will occur during the up power. Numerous secondary alarms and loss of instrumentation will occur. The alternate dump valves on the heaters will open in addition to loss of DEH turbine control. The Vital bus can be re-energized from the alternate source. Plant stabilization will be required due to secondary perturbation.

A LOOP combined with a loss of feedwater will occur. The 2B Diesel will not start and the 2A Diesel output breaker will not close. The output breaker can be closed from the RTGB. The 2C AFW pump will trip on AFAS or manual start and cannot be restarted. The 2A AFW pump MV-09-9, 2A AFW pump to 2A SG, Will not open. The crew is expected to crosstie the 2A AFW pump to feed the 2B SG.

The Crew will probably enter 2-EOP-09. LOOP, LOFC prior to entering 2-EOP-06 due to AFAS-2 actuating approximately 15 minutes after the trip and AFAS-1 actuating approximately 20 minutes after the trip.

2-EOP-06 Total Loss of Feedwater will be entered. The scenario can be terminated when the crew has closed the 2A Diesel output breaker and the 2B SG is being fed by the 2A AFW pump.

Procedures Used 2-GOP-201, Reactor Plant Startup - Mode 2 to Mode 1 2-GOP-1 01, Reactor Operating Guidelines During Steady State and Scheduled Load Changes 2-GOP-502, Data Sheets Required for Heatup 2-0NP-4901, SUPS - NON - Safety Vital AC ISFSI Security or Fire and Security Inverter Malfunction 2-0310030, Component Cooling Water - Off-Normal Operation 2-NOP-52.02 Alignment Of 2AB Buses And Components 2-0120035, Pressurizer Pressure and Level 2-EOP-01, Standard Post Trip Actions 2-EOP-06, Total Loss of Feedwater 2-0NP-09.02, Auxiliary Feedwater Technical Specifications Entered 3.7.3 Component Cooling Water System 3.3.3.6 Accident Monitoring 2

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

5 Event #

--:... ____ Page 3

of 19 Event

Description:

Power increase to approximately 45%.

Time II Position II Applicant's Actions or Behavior Booth Operator Instructions: Initiate Ie #14 30% power. Xenon building in, 6 gpm dilution rate. MOL. 2C Charging Pump OOS for repack. 28 MFW Pump OOS to repair oil cooler.

I Indications NOTE: Inform the crew 2*GOP*201 step 6.1.26 has been signed off by RE and power ascension is approved.

i SRO I

I I C"

I I

RO I

I I

i I

I I

I BOP i

~

I I

i Direct power increase lAW 2-GOP-201 step 6.128 (attached page_4_)

Directs Placing MSRs in service - 300 MW per 2-GOP-S02, Data Sheets Required For Heatup, Appendix - AA (attached page_S-8_) as directed.

Directs Control of Rx power and ASI lAW 2-GOP-101 Rx Operating Guidelines step 6.1 (attached, page_9_)

Commences dilution for power increase lAW 2-NOP-02.24 step 6.S (attached page_11-13_)

Withdraws CEA's to control Rx power and ASIIAW 2-GOP-101 Rx Operating Guidelines step 6.1 (attached, page_9_ )

CEA Withdrawal, select MS on the CEDMCS Control Switch Move the IN/HOLD/OUT Switch to the OUT direction Programs DEH for power increase at a rate lAW 2-GOP-101 step 6.1.2.0 Category 4. (attached page_9_)

Set reference by ensuring REF selected and then depress desired MW endpoint, select ENTER

Depress LOAD RATE type in desired load rate and select ENTER

Depress GO pushbutton Places MSRs in service - 300 MW per 2-GOP-S02, Data Sheets Required For Heatup, Appendix - AA as directed.

(attached page_S-8_) 3

(

Appendix D Operator Action Form ES-D-2 Op Test No 1

Scenario #

5 Event # -----

Page 3

of 19 Event Description' Power increase to approximately 45%.

Time II Position II Applicant's Actions or Behavior I Booth Operator Instructions: Initiate Ie #14 30% power. Xenon building in, 6 gpm dilution rate. MOL. 2C Charging Pump OOS for i

repack. 28 MFW Pump OOS to repair oil cooler.

I ndications NOTE: Inform the crew 2-GOP-201 step 6.1.26 has been signed off by l _

RE and power ascension is approved.

i SRO Direct power increase lAW 2-GOP-201 step 6.128 (attached I

page_4_)

I I i

Directs Placing MSRs in service - 300 MW per 2-GOP-502, Data Sheets Required For Heatup, Appendix - AA (attached I

page _ S-8 _) as directed.

I I

l Directs Control of Rx power and ASI lAW 2-GOP-1 01 Rx I

Operating Guidelines step 6.1 (attached, page_9_)

I I f----

i RO Commences dilution for power increase lAW 2-NOP-02.24 step I

6.S (attached page_11-13_)

I i

I Withdraws CEA's to control Rx power and ASI lAW 2-GOP-1 01 I

Rx Operating Guidelines step 6.1 (attached, page_9_ )

i CEA Withdrawal, select MS on the CEDMCS I

I Control Switch I

Move the IN/HOLD/OUT Switch to the OUT I

direction Programs DEH for power increase at a rate lAW 2-GOP-101 step 6.1.2.D Category 4. (attached page_9_)

I Set reference by ensuring REF selected and then I

BOP depress desired MW endpoint, select ENTER I

Depress LOAD RATE type in desired load rate and I

select ENTER I

Depress GO pushbutton I I

,-------------j----------------------------j I

Places MSRs in service - 300 MW per 2-GOP-S02, Data Sheets Required For Heatup, Appendix - AA as directed.

(attached page_S-B_) 3

REVISION NO PROCEDURE TITLE PAGE:

60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 f----........ ----I PROCEDURE NO.

51 of 69 2-GOP-201 ST. LUCIE UNIT 2 6.125 (continued)

6.

if Exhaust Hood temperatures are less than 150°F (TR-22-6B points 3,7,8 and 10), Then:

A.

B.

CLOSE V12396, 2A LP Turb Spray Hdr TCV-22-61A Bypass.

CLOSE V12403, 2B LP Turb Spray Hdr TCV-22-61 B Bypass.

6.126 When Turbine load is approximately 250 MW, Then VERIFY that secondary chemistry values are less than the minor inleakage limits of ONOP 2-0610030, Secondary Chemistry - Off Normal.

NOTE Based on JPN Engineering Evaluation, the RE Supervisor, may recommend to Operations that any or all of the 30% Reactor Power level surveillance may be performed at 45% following a power ascension that was NOT as a result of a refuelin9. outage.

6.127 ~'O if required, Then prior to Reactor Power reaching 30% as indicated on the highest reading instrument, PERFORM the following:

1.

STOP the power ascension.

2.

NOTIFY SCE or I&C to perform DCS Steam Generator INITIAL CHEM Feedwater Discharge Coefficients Verification per 2-NOP-102.01. __ _

3.

PERFORM 2-0SP-69.01, Nuclear I Delta T Power Calibration.

4.

ENSURE scheduled incore surveillance have been performed.

5.

ENSURE the Incore Detection System is OPERABLE in accordance with OSP-64.01. Reactor Engineering Periodic Tests, Checks and Calibrations.

NOTE The power ascension may continue while the MSRs are being placed in service.

6.128 When Turbine load is approximately 300 MW, Then PERFORM Appendix AA of 2-GOP-502, Placing MSRs In Service.

4 4

SCE II&C

(

REVISION NO PROCEDURE TITLE PAGE 51 of 69 60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 f---......;;..~---t PROCEDURE NO 2-GOP-201 ST. LUCIE UNIT 2 6.125 (continued)

6.

if Exhaust Hood temperatures are less than 150°F (TR-22-6B points 3,7,8 and 10), Then:

A.

B.

CLOSE V12396, 2A LP Turb Spray Hdr TCV-22-61A Bypass.

CLOSE V12403, 2B LP Turb Spray Hdr TCV-22-61 B Bypass.

6.126 When Turbine load is approximately 250 MW, Then VERIFY that secondary chemistry values are less than the minor inleakage limits of ONOP 2-0610030, Secondary Chemistry - Off Normal.

NOTE Based on JPN Engineering Evaluation, the RE Supervisor, may recommend to Operations that any or all of the 30% Reactor Power level surveillance may be performed at 45% following a power ascension that was NOT as a result of a refueling outage.

6.127 ~'0 if required, Then prior to Reactor Power reaching 30% as indicated on the highest reading instrument, PERFORM the following:

1.

STOP the power ascension.

2.

NOTIFY SCE or I&C to perform DCS Steam Generator Feedwater Discharge Coefficients Verification per 2-NOP-1 02.01.

3.

PERFORM 2-0SP-6901, Nuclear I Delta T Power Calibration.

4.

ENSURE scheduled incore surveillance have been performed.

5.

ENSURE the Incore Detection System is OPERABLE in accordance with OSP-6401, Reactor Engineering Periodic Tests, Checks and Calibrations.

NOTE The power ascension may continue while the MSRs are being placed in service.

6,128 When Turbine load is approximately 300 MW, Then PERFORM Appendix AA of 2-GOP-502, Placing MSRs In Service.

4 4

CHEM SCE II&C

REVISION NO PROCEDURE TITLE PAGE 51A PROCEDURE NO DATA SHEETS REQUIRED FOR HEATUP 1240f127 2-GOP*502 ST. LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 1 of 4)

INITIAL Date __ 1 __ 1-

1.

DEPRESS the Reset pushbutton on the Reheater Control System

2.

VERIFY locally the MSR TCVs are positioned as follows:

COMPONENT DESCRIPTION POSITION INITIAL TCV-08-i MS to 2A MSR CLOSED TCV-08*7 MS to 2A MSR CLOSED TCV*08-3 MS to 2B MSR CLOSED TCV*08*9 MS to 2B MSR CLOSED TCV*08-4 MS to 2C MSR CLOSED TCV-08-i0 MS to 2C MSR CLOSED TCV-08-2 MS to 20 MSR CLOSED TCV-08-8 MS to 20 MSR CLOSED NOTE A large steam demand may occur while opening the MSR Block Valves.

The MSR Block Valves should be opened one at a time. allowing time for the RCS to stabilize.

3.

POSITION the MSR Block Valves as follows COMPONENT DESCRIPTION POSITION INITIAL MV-08-4 2A Block TCV OPEN MV-08-6 20 Block TCV OPEN MV-08-8 2B Block TCV OPEN MV-08-10 2C Block TCV OPEN 5

5 REVISION NO PROCEDURE TITLE PAGE 51A DATA SHEETS REQUIRED FOR HEATUP 1240f127 PROCEDURE NO 2-GOP*502 ST. LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 1 of 4)

INITIAL Date

/

1.

DEPRESS the Reset pushbutton on the Reheater Control System

2.

VERIFY locally the MSR TCVs are positioned as follows COMPONENT DESCRIPTION POSITION INITIAL TCV-OS-1 MS to 2A MSR CLOSED TCV-OS*7 MS to 2A MSR CLOSED TCV-08*3 MS to 2B MSR CLOSED TCV*OS*9 MS to 2B MSR CLOSED TCV*OB-4 MS to 2C MSR CLOSED TCV*OS-10 MS to 2C MSR CLOSED TCV-OS-2 MS to 20 MSR CLOSED

(

TCV*OS*S MS to 20 MSR CLOSED NOTE A large steam demand may occur while opening the MSR Block Valves.

The MSR Block Valves should be opened one at a time. allowing time for the RCS to stabilize.

3.

POSITION the MSR Block Valves as follows COMPONENT DESCRIPTION POSITION INITIAL MV-OB-4 2A Block TCV OPEN MV-08-6 20 Block TCV OPEN MV-OS-8 2B Block TCV OPEN MV-08*10 2C Block TCV OPEN 5

5

REVISION NO PROCEDURE TITLE PAGE 51A PROCEDURE NO DATA SHEETS REQUIRED FOR HEATUP 1250f127 2-GOP-502 ST. LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 2 of 4)

INITIAL t!Q.I£ Quench water to the MSRs will be supplied immediately upon opening the MSR Block Valves.

4, When the MSR Block Valves are open, Then THROTILE OPEN the following components to adjust MSR subcooling flow to app 5 to 7 gpm on applicable indicator:

COMPONENT DESCRIPTION INDICATOR INITIAL V09322 SE-09-1A 2A, MSR Subcooling FI-09-4A = 5 Dwnstrm 1501 to 7 gpm V09319 SE-09-1 B 2B MSR, Subcooling FI-09-4B:: 5 Dwnstrm Isol to 7 gpm V09328 SE-09-1C 2C MSR, Subcooling FI-09-4C :: 5 Dwnstrm 1501 to 7 gpm V09325 SE-09-1D 20 MSR, Subcooling FI-09-4D ::: 5 Dwnstrm 1501 to 7 gpm NOTE

When the MSR TCVs have started the warm up period by either automatic or manual control, the Turbine startup should continue.

If the wrong pushbutton is depressed, the controller can be reset by depressing the Reset pushbutton.

Ramp starts a 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months timed opening of TCV-08-7, 8, 9 and 10 (small TCVs). This is followed by a 30 minute time delay and then a 10 minute timed opening of TCV-08-1, 2, 3 and 4 (large TCVs). Total time is 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and 40 minutes until TCV-08*1, 2, 3 and 4 indicate open.

5, if automatic startup is desired, Then DEPRESS the Ramp pushbutton. --

6 6

REVISION NO PROCEDURE TITLE PAGE 51A DATA SHEETS REQUIRED FOR HEATUP 1250f127 PROCEDURE NO 2-GOP-502 ST LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 2 of 4)

INITIAL NOTE Quench water to the MSRs will be supplied immediately upon opening the MSR Block Valves.

4, When the MSR Block Valves are open, Then THROTILE OPEN the following components to adjust MSR subcooling flow to app 5 to 7 gpm on applicable indicator:

COMPONENT DESCRIPTION INDICATOR INITIAL V09322 SE-09-1A 2A, MSR Subcoolmg FI-09-4A = 5 Dwnstrm Isol to 7 gpm V09319 SE*09*1 B 28 MSR, Subcooling FI*09-48 = 5 Dwnstrm Isol to 7 gpm V0932B SE-09*1C 2C MSR, Subcooling FI-09-4C = 5 Dwnstrm Isol to 7 gpm V09325 SE-09-1 D 2D MSR, Subcooling FI-09-4D = 5 Dwnstrm Isol to 7 gpm NOTE

When the MSR TCVs have started the warm up period by either automatic or manual control, the Turbine startup should continue.

If the wrong pushbutton is depressed, the controller can be reset by depressing the Reset pushbutton.

Ramp starts a 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months timed opening of TCV-08-7, 8, 9 and 10 (small TCVs) This IS followed by a 30 minute time delay and then a 10 minute timed opening of TCV-OB-1, 2, 3 and 4 (large TCVs). Total time is 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and 40 minutes until TCV-OB-1, 2, 3 and 4 indicate open 5,

11 automatic startup IS desired, Then DEPRESS the Ramp pushbutton 6

6

REVISION NO PROCEDURE TITLE PAGE:

51A PROCEDURE NO DATA SHEETS REQUIRED FOR HEATUP 126 of 127 2-GOP-502 ST. LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 3 of 4)

INITIAL CAUTION If the manual valve positioner is NOT on zero before pushing the Manual Valve Position pushbutton, the TCVs will OPEN to a position relative to the manual valve positioner setpoint and possibly damage the MSRs from the resultant thermal stresses.

6.

lf manual startup is desired, Then PERFORM the following:

A.

ENSURE the manual valve positioner IS on zero.

B.

DEPRESS the Manual Valve Position pushbutton.

C.

Slowly OPEN the TCVs by rotating the manual valve positioner.

Manual opening of the MSR TCVs should take approximately 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

7.

After the MSR TCVs are OPEN, Then PERFORM the following:

A.

POSITION the small TCV isolation valves as follows:

COMPONENT DESCRIPTION POSITION INITIAL V08381 TCV*08-7 Isol CLOSED V08370 TCV-08-7Isol CLOSED V08378 TCV-08-8 Dwnstm Isol CLOSED V08382 TCV-08-8 Upstrm 1501 CLOSED V08383 TCV-08-S 1501 CLOSED V08372 TCV-08-S 1501 CLOSED V08375 TCV-08-10 Isol CLOSED V08384 TCV-08-10 1501 CLOSED B.

ALIGN the MSR vents to the 5A and 58 Feedwater Heaters as follows COMPONENT DESCRIPTION POSITION INITIAL V11446 2A MSR to Extr Stm Isol OPEN V11451 2B MSR To Extr Stm 1501 OPEN V11117 2C MSR To Extr Stm 1501 OPEN V11122 2D MSR To Extr Stm Isol OPEN 7

7

~------ ---

REVISION NO PROCEDURE TiTLE PAGE 51A DATA SHEETS REQUIRED FOR HEATUP 1260f127 PROCEDURE NO 2-GOP~502 S1. LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 3 of 4)

INITIAL CAUTION If the manual valve positioner is NOT on zero before pushing the Manual Valve Position pushbutton, the TCVs will OPEN to a position relative to the manual valve positioner setpoint and possibly damage the MSRs from the resultant thermal stresses.

6.

lf manual startup is desired, Then PERFORM the following:

A.

ENSURE the manual valve posItioner IS on zero B.

DEPRESS the Manual Valve Position pushbutton C.

Slowly OPEN the TCVs by rotating the manual valve positioner Manual opening of the MSR TCVs should take approximately

(

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

7.

After the MSR TCVs are OPEN, Then PERFORM the following' A.

POSITION the small TCV Isolation valves as follows COMPONENT DESCRIPTION POSITION INITIAL V08381 TCV~08~7 Isol CLOSED V08370 TCV~08-7 Isol CLOSED V08378 TCV-08~8 Dwnstm Isol CLOSED V08382 TCV~08-8 Upstrm Isol CLOSED V08383 TCV~08-9 Isol CLOSED V08372 TCV-08-9 Isol CLOSED V08375 TCV-08-10 Isol CLOSED V08384 TCV-08-10 Isol CLOSED B.

ALIGN the MSR vents to the 5A and 58 Feedwater Heaters as follows COMPONENT DESCRIPTION POSITION INITIAL V11446 2A MSR to Extr Stm Isol OPEN V11451 28 MSR To Extr Stm Iso I OPEN V11117 2C MSR To Extr Stm Isol OPEN V11122 20 MSR To Extr Stm Isol OPEN 7

7

REVISION NO PROCEOURE TITLE PAGE 51A DATA SHEETS REQUIRED FOR HEATUP 1270f127 PROCEDURE NO.

2*GOP-502 ST. LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 4 of 4)

7.

(continued)

INITIAL C.

ALIGN the MSR vents to the Condenser as follows:

COMPONENT DESCRIPTION POSITION INITIAL V11508 28 Cndsr Vent From 2A MSR Isol CLOSED V11507 28 Cndsr Vent From 28 MSR Isol CLOSED V11520 2B Cndsr Vent From 2C MSR Isol CLOSED V11227 2A Cndsr From 20 MSR Tube CLOSED Bundle Vent Isol D.

ALIGN the MSR Warm Up Valves as follows COMPONENT DESCRIPTION POSITION INITIAL MV-08*5 Warmup 2A MSR CLOSED MV*08*7 Warmup 20 MSR CLOSED MV*08-9 Warmup 2B MSR CLOSED MV-08*11 Warmup 2C MSR CLOSED Reviewed by Date __ 1_1-SRO END OF APPENDIX AA 8

8 REVISION NO PROCEDURE TITLE PAGE 51A DATA SHEETS REQUIRED FOR HEATUP 1270f127 PROCEDURE NO 2-GOP-502 ST. LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 4 of 4)

7.

(continued)

INITIAL C.

ALIGN the MSR vents to the Condenser as follows COMPONENT DESCRIPTION POSITION INITIAL V11508 28 Cndsr Vent From 2A MSR Isol CLOSED V11507 28 Cndsr Vent From 28 MSR Isol CLOSED V11520 2B Cndsr Vent From 2C MSR Isol CLOSED V11227 2A Cndsr From 20 MSR Tube CLOSED Bundle Vent Isol D.

ALIGN the MSR Warm Up Valves as follows COMPONENT DESCRIPTION POSITION INITIAL MV-08-5 Warmup 2A MSR CLOSED MV-08-7 Warmup 2D MSR CLOSED MV*08-9 Warmup 2B MSR CLOSED MV-08-11 Warmup 2C MSR CLOSED Reviewed by Date _1_1-SRO END OF APPENDIX AA

(

8 8

~----.-------

REVISION NO PROCEDURE TITLE PAGE 9B REACTOR OPERATING GUIDELINES DURING STEADY 6 of 15 PROCEDURE NO STATE AND SCHEDULED LOAD CHANGES 2-GOP-101 S1. LUCIE UNIT 2 6.0 INSTRUCTIONS 6.1 Power Level Escalations NOTE CEAs should be above the Long-term Steady State Insertion Limit (102 inches withdrawn on Group 5) before reaching 20% core power and at a position to begin controlling ASI at the ESI between 20% and 50% power Refer to NOP-1 00.02, Axial Shape Index Control, for further guidance,

1.

As Main Generator loading commences, MAINTAIN T-avg at T-ref by A.

CEA withdrawal in Manual Sequential.

ANDfOR B.

Boron concentration changes in accordance with 2-NOP-02.24, Boron Concentration Control.

2.

At or above 50% power

(

A.

All planned reactivity additions should be made by boration or dilution In accordance with 2-NOP-02.24, Boron Concentration Control.

B.

USE CEAs for ASI control, CONSIDER the reactivity effect of CEAs when adjusting AS!.

C.

REFER to NOP-1 00,02, Axial Shape Index Control, for specific instructions regarding ASI control during power escalations.

D.

,-j, When raising Reactor power, all power escalation rates should be within the following fuel preconditioning guidelines:

Category Max Core Power Escalation Rate Max Equivalent Turbine Generator Load Rate 1---------

3%IHR at or above 15% Power

.42 MWIMIN 1

I 2

3%IHR above 50% Power

.42 MWfMIN i

e [

3 20%fHR above 50% Power 280 MWIMIN I

4 30%/HR above 50% Power 4.2 MWIMIN 9

9 REVISION NO PROCEDURE TITLE PAGE 9B REACTOR OPERATING GUIDELINES DURING STEADY 6 of 15 PROCEDURE NO STATE AND SCHEDULED LOAD CHANGES 2-GOP-101 ST. LUCIE UNIT 2 6.0 INSTRUCTIONS 6.1 Power Level Escalations NOTE CEAs should be above the Long-term Steady State Insertion Limit (102 inches withdrawn on Group 5) before reaching 20% core power and at a position to begin controlling ASI at the ESI between 20% and 50% power.

Refer to NOP-1 00.02, Axial Shape Index Control, for further guidance.

1.

As Main Generator loading commences, MAINTAIN T-avg at T-ref by:

A.

CEA withdrawal in Manual Sequential.

ANDfOR B.

Boron concentration changes in accordance with 2-NOP-02.24, Boron Concentration Control.

2.

At or above 50% power

(

A_

All planned reactivity additions should be made by boration or dilution In accordance with 2-NOP-02.24. Boron Concentration Control B.

USE CEAs for ASI control, CONSIDER the reactivity effect of CEAs when adjusting AS!.

C.

REFER to NOP-1 00.02, Axial Shape Index Control, for specific instructions regarding ASI control during power escalations_

D.

~,

When raising Reactor power, all power escalation rates should be within the following fuel preconditioning guidelines:

Category Max Core Power Escalation Rate Max Equivalent Turbine Generator Load Rate 1------- -

3%/HR at or above 15% Power

.42 MW/MIN 1

I 2

e 3%/HR above 50% Power

.42 MWfMIN i

[

3 20%/HR above 50% Power 280 MW/MIN I

4 30%/HR above 50% Power 4.2 MW/MIN 9

9

REVISION NO PROCEDURE TITLE:

PAGE 98 REACTOR OPERATING GUIDELINES DURING STEADY I-P-RO-C-E-OU-R"';'E"';"NO~---I STATE AND SCHEDULED LOAD CHANGES 7 of 15 2-GOP-101 ST. LUCIE UNIT 2 6.1 Power Level Escalations (continued)

2.

D.

(continued)

NOTE To determine the correct category for a power escalation, Appendix 8, Fuel Preconditioning Guidelines Worksheet, may be used. Contact Reactor Engineering if further assistance is required.

Category Definitions:

1.

Category 1 :

a.

INCREASE in power to a level which has not been previously sustained in this core cycle for at least 72 continuous hours.

2.

Category 2:

a.

INCREASE in power following 30 continuous days or more at a power level less than 70% of rated thermal power_

OR

b.

INCREASE in power to a level which has not been maintained for more than 3 continuous hours during the past 60 days.

3.

Category 3:

a.

INCREASE in power to a level which has not been maintained for 3 continuous hours or more during the past 8 days.

4.

Category 4:

a.

INCREASE in power to a level which has been maintained for 3 continuous hours or more during the past 8 days.

3.

11 available, Then ENSURE two Charging Pumps are operating.

If necessary, START an additional Charging Pump in accordance with 2-NOP-02.02, Charging and Letdown.

4.

PLACE the Pressurizer on recirculation in accordance with Appendix A, Pressurizer Recirculation Guidelines.

5.

CONTINUE to load the Main Generator in accordance with 2-GOP-201, Reactor Plant Startup, Mode 2 to Mode 1.

END OF SECTION 6.1 10 10

(

~~----------- ---

REVISION NO PROCEDURE TITLE PAGE 98 REACTOR OPERATING GUIDELINES DURING STEADY 7 of 15 i-P-RO-C-E-D-UR-E-N-O---;

STATE AND SCHEDULED LOAD CHANGES 2-GOP-101 ST. LUCIE UNIT 2 6.1 Power Level Escalations (continued)

2.

D.

(continued)

NOTE To determine the correct category for a power escalation, Appendix B, Fuel Preconditioning Guidelines Worksheet, may be used. Contact Reactor Engineering if further assistance is required.

Category Definitions:

1.

Category 1 :

a.

INCREASE in power to a level which has not been previously sustained in this core cycle for at least 72 continuous hours.

2.

Category 2:

a.

b.

INCREASE in power following 30 continuous days or more at a power level less than 70% of rated thermal power.

OR INCREASE in power to a level which has not been maintained for more than 3 continuous hours during the past 60 days.

3.

Category 3

a.

INCREASE in power to a level which has not been maintained for 3 continuous hours or more during the past 8 days.

4.

Category 4

a.

INCREASE in power to a level which has been maintained for 3 continuous hours or more during the past 8 days.

3.

If available, Then ENSURE two Charging Pumps are operating.

If necessary, START an additional Charging Pump in accordance with 2-NOP-0202, Charging and Letdown.

4.

PLACE the Pressurizer on recirculation in accordance with Appendix A, Pressurizer Recirculation Guidelines.

5.

CONTINUE to load the Main Generator in accordance with 2-GOP-201, Reactor Plant Startup, Mode 2 to Mode 1.

END OF SECTION 6.1 10 10

REVISION NO PROCEDURE TITLE:

PAGE:

24A 19 of 75 BORON CONCENTRATION CONTROL PROCEDURE NO 2-NOP-0224 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution NOTE An Operator Aid has been placed at RTGB-205 PNL "N". Any revision to this section of the procedure shall verify the validity of the Operator Aid and, if changes are necessary, a Label Request shall be initiated to Incorporate these changes on a new Operator Aid placard.

The Operations Supervisor SHALL be notified and a CR submitted of any unexplained or unplanned Reactivity change in accordance with OPS Policy 534 (i.e., >.5 deg Tcold change or >.5% power change).

If a Reactivity management issue occurs, refer to procedure ADM-09.11, Reactivity Management.

If constant dilution is desired then ensure flow on FIC-2210X is observable.

Engineering Assessment of FIC-2210X PMW Flow, shows that there could be an error up to -+/- 0.5 gpm, and the recommended minimum flow rate is 2 gpm

1.

0000 ENSURE Section 3.0, Prerequisites is completed at least once per shift.

2.

0000 ENSURE Section 40, Precautions / Limitations, has been reviewed at least once per shift.

3.

0000 ~2 ENSURE calorimetric power is less than 100.00% prior to any dilutions by obtaining a DCS calorimetric power.

4.

0000 DETERMINE the desired volume of primary water to be added.

5.

0000 PLACE the Makeup Mode Selector switch in MANUAl.

6.

0000 ENSURE FIC-2210X, PMW Flow, is in MANUAL and REDUCE the controller output to ZERO.

7.

0000 ENSURE FIC-2210Y, Boric Acid Flow is in MANUAL and REDUCE the controller output to ZERO.

8.

0000 ENSURE either Primary Makeup Water Pump is running.

9.

0000 PLACE FCV-2210X, Primary Makeup Water Control Switch in Auto.

10.

0000 11 diluting to the VCT, Then OPEN V-2512, Reactor Makeup Water Stop Vlv.

11.

0000 11 diluting to the Charging Pump suction, Then OPEN V-2525, Boron Load Control Valve.

11

0 N... >>

(

REVISION NO PROCEDURE TITLE.

PAGE.

24A PROCEDURE NO BORON CONCENTRATION CONTROL 19 of 75 2-NOP-0224 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution NOTE An Operator Aid has been placed at RTGB-205 PNL "N". Any revision to this section of the procedure shall verify the validity of the Operator Aid and, if changes are necessary, a Label Request shall be initiated to Incorporate these changes on a new Operator Aid placard.

The Operations Supervisor SHALL be notified and a CR submitted of any unexplained or unplanned Reactivity change in accordance with OPS Policy 534 (ie., > 5 deg Tcold change or >5% power change).

If a Reactivity management issue occurs, refer to procedure ADM-09.11, Reactivity Management.

If constant dilution is desired then ensure flow on FIC-2210X is observable Engineering Assessment of FIC-2210X PMW Flow, shows that there could be an error up to -+/- 0 5 gpm, and the recommended minimum flow rate is 2 gpm

1.

o 0 0 0 ENSURE Section 3.0, Prerequisites is completed at least once per shift.

2.

0 0 0 0 ENSURE Section 4.0, Precautions / Limitations, has been reviewed at least once per shift

3.

0 0 0 0

~2 ENSURE calorimetric power is less than 100.00% prior to any dilutions by obtaining a DCS calorimetric power

4.

0 0 0 0 DETERMINE the desired volume of primary water to be added

5.

0 000 PLACE the Makeup Mode Selector switch in MANUAL.

6.

0000 ENSURE FIC-2210X, PMW Flow, is in MANUAL and REDUCE the controller output to ZERO

7.

0000 ENSURE FIC-2210Y, Boric Acid Flow is in MANUAL and REDUCE the controller output to ZERO.

8.

0000 ENSURE either Primary Makeup Water Pump is running.

9.

0000 PLACE FCV-221 OX, Primary Makeup Water Control Switch in Auto.

10.

0000 Lf diluting to the VCT, Then OPEN V-2512, Reactor Makeup Water Stop Vlv.

11.

0000 Lf diluting to the Charging Pump suction, Then OPEN V-2525, Boron Load Control Valve 11 33 tv..

p 33 N..

P

REVISION NO PROCEDURE TITLE PAGE:

20 of 75 BORON CONCENTRATION CONTROL 24A PROCEDURE NO 2-NOP-02.24 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued)

CAUTION To preclude lifting the VCT relief valve while using V-2525, do NOT allow PMW flowrate to exceed the running Charging pump(s) capacity.

12.

DODD ADJUST FIC-2210X PMW Flow in AUTO or MANUAL to desired flowrate (and if using V-2525 do NOT exceed the flowrate for the number of running Charging Pumps).

13.

DODD MAINTAIN VCT pressure less than or equal to 30 psig by opening and closing V2513, VCT Vent, as needed.

14, 0 0 0 0 if necessary to maintain the desired VCT level, Then DIVERT the letdown flow to the Waste Management System by placing V2500, VCT Divert Valve, in the WMS position:

A.

DO 0 0 ENSURE V2500 VCT Divert Valve indicates OPEN.

8, 0 0 0 0 When the desired VCT level is reached, PLACE V2500 in AUTO.

C.

0 0 0 0 ENSURE V2500 indicates CLOSED.

15.

0 0 0 0 When the desired amount of primary water has been added.

Then CLOSE FCV-221 OX, Primary Makeup Water.

16.

0 0 0 0 if V-2512 Reactor Makeup Water Stop Vlv was opened, Then PLACE V*2512 in CLOSE and ENSURE it indicates CLOSED.

17.

0 0 0 0 if V*2525 Boron Load Control Valve was opened, Then PLACE V-2525 in CLOSE and ENSURE it indicates CLOSED.

18.

0 0 0 0 ENSURE FIC-2210X, PMW Flow controller is in MANUAL and RECUCE output to MINIMUM.

19.

0 0 0 0 MONITOR for any abnormal change in Tave

20.

0 0 0 0

§1 RECORD on Data Sheet 1, Boration I Dilution Log, the number of gallons of Primary Makeup Water added as indicated on FQI-2210X, PMW Flow Totalizer.

21.

0 0 0 0 if additional dilutions are desired, or if the expected changes to Tave or Boron concentration are NOT achieved, Then REPEAT Steps 6.5.1 through 6.5.20.

12

(

/ \\

REVISION NO PROCEDURE TITLE PAGE 24A PROCEDURE NO BORON CONCENTRATION CONTROL 20 of 75 2-NOP-02.24 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued)

CAUTION To preclude lifting the VCT relief valve while using V-2525, do NOT allow PMW flowrate to exceed the running Charging pump(s) capacity

12.

DODD ADJUST FIC-2210X PMW Flow in AUTO or MANUAL to desired flowrate (and if using V-2525 do NOT exceed the flowrate for the number of running Charging Pumps)

13.

DODD MAINTAIN VCT pressure less than or equal to 30 psig by opening and closing V2513, VCT Vent, as needed.

14.

DODD 11 necessary to maintain the desired VCT level, Then DIVERT the letdown flow to the Waste Management System by placing V2500, VCT Divert Valve, in the WMS position A.

DODD ENSURE V2500 VCT Divert Valve indicates OPEN.

B.

DODD When the desired VCT level is reached, PLACE V2500 in AUTO.

C.

DODD ENSURE V2500 indicates CLOSED.

15.

DODD When the desired amount of primary water has been added, Then CLOSE FCV-221 OX, Primary Makeup Water.

16.

DODD 11 V-2512 Reactor Makeup Water Stop Vlv was opened, Then PLACE V-2512 in CLOSE and ENSURE it indicates CLOSED.

17.

DODD 11 V-2525 Boron Load Control Valve was opened, Then PLACE V-2525 in CLOSE and ENSURE it indicates CLOSED.

18.

DODD ENSURE FIC-2210X, PMW Flow controller is in MANUAL and RECUCE output to MINIMUM

19.

DODD MONITOR for any abnormal change in Tav8 20, DODD §,

RECORD on Data Sheet 1, Boration / Dilution Log, the number of gallons of Primary Makeup Water added as indicated on FQI-2210X, PMW Flow Totalizer.

21.

DODD 11 additional dilutions are desired, or if the expected changes to Tav8 or Boron concentration are NOT achieved, Then REPEAT Steps 6.5 1 through 6.5 20.

12

0 N..

l>

REVISION NO PROCEDURE TITLE PAGE:

21 of 75 BORON CONCENTRATION CONTROL 24A PROCEDURE NO 2-NOP-0224 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued)

22.

0 0 0 0 11 it is desired to restore the Boron Concentration Control system to the Automatic Mode of Operation, Then REFER to Section 6.1, Aligning for Automatic VCT Makeup.

23.

After review by the Unit Supervisor is complete, this document may be discarded.

END OF SECTION 6.5 13

(

. -----~~-----.---.~------

REVISION NO PROCEDURE TITLE PAGE 24A BORON CONCENTRATION CONTROL 210f75 PROCEDURE NO 2-NOP-02.24 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued)

22.

0 0 0 0 11 it is desired to restore the Boron Concentration Control system to the Automatic Mode of Operation, Then REFER to Section 6.1, Aligning for Automatic VCT Makeup.

23.

After review by the Unit Supervisor is complete, this document may be discarded.

END OF SECTION 6.5 13

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

5 Event #

_2 _____ Page.L-of _1....

9~1 Event

Description:

Loss of 28 Component Cooling Water Pump Time II Position II Applicant's Actions or Behavior Booth Operator Instructions: When directed by examiner, trigger Loss of 2B CCW pump.

Trigger AB Battery Charger when requested by Control Room.

1------

Indications Available: Increasing amps on 2B CCW pump.

I Alarms: S-2: 2B CCW Hdr Flow High/Low S-32: 2B CCW PUMP OVRLD/ TRIP, alarms and will clear after pump trip.

I S-26: 2C CCW PUMP HDR VALVES/AB BUS MISALIGNMENT, while I

alignin~ 2C pump.

i i SRO/ROI Recognize loss of 28 CCW pump.

i BOP

~

Enters T.S. 3.7.3. (72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months action to restore 2 CCW pumps, 2 i

TS I

hours to ensure valve lineup commensurate with electrical I

SRO lineup)

I I

i

... ~- --------

NOTE SRO May elect to hold power increase.

r---'-- - ".--'

I Enters 2-0310030 and directs lineup of 2C CCW pump to replace 2B CCW pump per step 6.2.3.B 1 & 2 (attached i

page_ 15 -)

i Directs swapping of 2AB bus to the B side per step 6.2.3.B.4 i

thru 2-NOP-52.02, Alignment Of 2AB Buses And Components, I

step 4.1.4 A thru C (attached page_17 _for 4.16KV bus only)

~.-.----~

i Directs starting the 2C CCW pump per step 6.2.3.B.5 (attached I i

i page_16_)

I

~--

i i

o-----~ __

I Directs placing 2B CCW pump to Pull To Lock positions per step I i

6.2.3.8,7 (attached page_16_)

i 14 Appendix D Operator Action Form ES-D-2 Op Test No.

1 Scenario #

5 Event #

2 Page 4

of 19

-~-II Event Description Loss of 28 Component Cooling Water Pump Time II Position II Applicant's Actions or Behavior Booth Operator Instructions: When directed by examiner, trigger Loss of 2B CCW pump.

Trigger AB Battery Charger when requested by Control Room.

)--

,~----

Indications Available: Increasing amps on 2B CCW pump.

I Alarms: S-2: 2B CCW Hdr Flow High/Low S-32: 2B CCW PUMP OVRLD/ TRIP, alarms and will clear after pump trip.

i S-26: 2C CCW PUMP HDR VALVES/AB BUS MISALIGNMENT, while I

alignin~ 2C pump.

i i SRO/ROI I

I Recognize loss of 2B CCW pump.

i i

BOP I

I I

~

Enters T.S. 3.7.3. (72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months action to restore 2 CCW pumps, 2 I

I TS I

I hours to ensure valve lineup commensurate with electrical I

I SRO lineup)

~

i i

(

--_._-_._-_... _----'---------------------------j NOTE SRO May elect to hold power increase.

~'--------- -

I Enters 2-0310030 and directs lineup of 2C CCW pump to I I replace 2B CCW pump per step 6.2.3.B 1 & 2 (attached I

page_15_)

i i

I Directs swapping of 2AB bus to the B side per step 6.2.3.B.4 i

I thru 2-NOP-52.02, Alignment Of 2AB Buses And Components, step 4.1.4 A thru C (attached page_17 _for 4.16KV bus only)

I i

I Directs starting the 2C CCW pump per step 6.2.3.B.5 (attached I

16 -)

i 1

page_

i I

Directs placing 2B CCW pump to Pull To Lock positions per step i I

6.2.3.8.7 (attached page_16_)

~---

14

REVISION NO 37 PROCEDURE NO 2-0310030 PROCEDURE TITLE COMPONENT COOLING WATER*

OFF*NORMAL OPERATION ST. LUCIE UNIT 2 PAGE:

7 of 23 6.2 Subsequent Action (continued)

3.

A.

(conti nued)

CAUTION If 2AB AC and DC Busses are not all completely powered from the A side, Then do NOT take Technical Specification Credit for the 2C CCW pump until alignment has been completed.

6.

VERIFY the pressures and nows return to normal.

7.

PLACE the 2A CCW pump control switch to the PULL TO LOCK position.

8.

!! the 480V Load Center 2AB and DC bus 2AB are NOT completely aligned to the A side, Then REALIGN the 480V Load Center 2AB and DC bus 2AB to the A side per 2-NOP-52.02, Alignment of 2AB Busses and Components.

B.

Loss of the 2B CCW Pump.

1.

ENSURE Closed:

MV-14-1, 2C CCW Pump Discharge to A Header AND MV-14-3, 2C CCW Pump Suction from A Header

2.

ENSURE Open:

MV-14-2, 2C CCW Pump Discharge to B Header AND MV 4, 2C CCW Pump Suction from B Header

3.

!f SOC is in service and CCW is completely lost to an SOC Heat Exchanger, Then SOC flow must be terminated to the affected heat exchanger prior to restoring CCW now. REFER to ONOP 2-0440030, Shutdown Cooling Off-Normal.

4.

~2 If the 2C CCW Pump is NOT electrically aligned to the B Electrical Bus AND the Unit is in Modes 1-4, Then REALIGN the 2AB 4.16KV Bus to the B Side p;--

2-NOP-52.02 PRIOR to starting the 2C CCW Pump on the 26 CCW Header.

12 15

(

REVISION NO 37 PROCEDURE NO 2-0310030 PROCEDURE TITLE COMPONENT COOLING WATER -

OFF-NORMAL OPERATION ST. LUCIE UNIT 2 PAGE.

7 of 23 6.2 Subsequent Action (continued)

3.

A.

(continued)

CAUTION If 2AB AC and DC Busses are not all completely powered from the A side, Then do NOT take Technical Specification Credit for the 2C CCW pump until alignment has been completed.

6.

VERIFY the pressures and nows return to normal

7.

PLACE the 2A CCW pump control switch to the PULL TO LOCK position.

8.

l.f the 480V Load Center 2AB and DC bus 2AB are NOT completely aligned to the A side, Then REALIGN the 480V Load Center 2AB and DC bus 2AB to the A side per 2-NOP-52.02, Alignment of 2AB Busses and Components S.

Loss of the 2B CCW Pump.

1.

ENSURE Closed.

MV-14-1, 2C CCW Pump Discharge to A Header AND MV-14-3, 2C CCW Pump Suction from A Header

2.

ENSURE Open MV-14-2, 2C CCW Pump Discharge to B Header AND MV-14-4, 2C CCW Pump Suction from B Header

3.

11 SOC is in service and CCW is completely lost to an SOC Heat Exchanger, Then SOC flow must be terminated to the affected heat exchanger prior to restoring CCW noW. REFER to ONOP 2-0440030, Shutdown Cooling Off-Normal.

4.

~2 11 the 2C CCW Pump is NOT electrically aligned to the B Electrical Bus AND the Unit is in Modes 1-4, Then REALIGN the 2AB 4.16KV Bus to the B Side per 2-NOP-52.02 PRIOR to starting the 2C CCW Pump on the 28 CCW Header.

12 15

REVISION NO 37 PROCEDURE NO 2-0310030 PROCEDURE TITLE COMPONENT COOLING WATER-OFF-NORMAL OPERATION ST, LUCIE UNIT 2 PAGE:

8 of 23 6.2 Subsequent Action (continued)

3.

B.

( continued)

5.

START the 2C CCW Pump.

CAUTION If 2AB AC and DC Busses are not all completely powered from the B side, Then do NOT take Technical Specification Credit for the 2C CCW pump until alignment has been complete.

6.

VERIFY the pressures and flows return to normal.

7.

PLACE the 2B CCW pump control switch in the PULL TO LOCK position.

8.

~2 If the 480V Load Center 2AB and DC bus 2AB are NOT completely aligned to the B side, Then REALIGN the 480V Load Center 2AB and DC bus 2AB to the B side per 2-NOP-52.02, Alignment of 2AB Busses and Components, C.

Loss of two (2) CCW Pumps CAUTION REFER to off-normal operating procedure 2-0NP-25,01, Loss of RCB Cooling Fans, for appropriate direction.

§, 2 Sufficient Containment Fan Coolers (HVS-1 A, HVS-1 B, HVS-1 Cor HVS-1D) are required to be in operation to maintain Containment air temperature less than or equal to 120°F. This is necessary to maintain the reactor vessel support structure within design basis.

Operator action is required within 45 minutes, to restore air temperature to less than or equal to 120°F or initiate reactor trip cooldown to at least Hot Shutdown.

1.

~3!f the health and safety of the public is in jeopardy, Then ATTEMPT ONLY ONE restart.

16

(

REVISION NO 37 PROCEDURE NO 2-0310030 PROCEOURE TITLE COMPONENT COOLING WATER -

OFF-NORMAL OPERATION ST, LUCIE UNIT 2 PAGE 8 of 23 6,2 Subsequent Action (continued)

3.

B.

(continued)

5.

ST ART the 2C CCW Pump.

CAUTION if 2AB AC and DC Busses are not all completely powered from the B side, Then do NOT take Technical Specification Credit for the 2C CCW pump until alignment has been complete.

6.

VERIFY the pressures and flows return to normal.

7.

PLACE the 2B CCW pump control switch in the PULL TO LOCK position.

8.

,-]2 if the 480V Load Center 2AB and DC bus 2AB are NOT completely aligned to the B side, Then REALIGN the 480V Load Center 2AB and DC bus 2AB to the B side per 2-NOP-52 02, Alignment of 2AB Busses and Components.

C.

Loss of two (2) CCW Pumps CAUTION REFER to off-normal operating procedure 2-0NP-2501, Loss of RCB Cooling Fans, for appropriate direction

§12 Sufficient Containment Fan Coolers (HVS-1A, HVS-1B, HVS-1C or HVS-1 D) are required to be in operation to maintain Containment air temperature less than or equal to 120°F. This is necessary to maintain the reactor vessel support structure within design basis.

Operator action is required within 45 minutes, to restore air temperature to less than or equal to 120°F or initiate reactor trip cooldown to at least Hot Shutdown.

1.

~3 if the health and safety of the public is in jeopardy, Then ATTEMPT ONLY ONE restart.

16

~~- ---_

.. -----~-

_.. ----~-------

REVISION NO PROCEDURE TITLE PAGE' 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO 2-NOP*5202 ST LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

NOTE While performing Section 4.1 Step 4, the following annunciators will be received B-48,4 16KV SWGR 480V LC/MCC 2AB UV (RTGB 201)

S-26, 2C CCW PUMP HDR VALVES/AB BUS MISALIGNMENT (RTGB 206)

4.

ALIGN 4160V Bus 2AB to B side, as follows A.

At RTGB 201, VERIFY the following tie breakers are OPEN.

Bkr1-20501,1AB416KVBUSSBOTIE Bkr 2-20501, 2AB 416 KV BUS SBO TIE B.

VERIFY the following pump control sWitches are in PULl-TO-LOCK Component Cooling Water Pump 2C (RTGB 206)

Intake Cooling Water Pump 2C (RTGB 202)

C.

At RTGB 201, PERFORM the following (1)

OPEN Bkr 2-20505, 4.16KV BUS TIE 2AB/2A3 (2)

OPEN Bkr 2-20208, 4.16KV BUS TIE 2A3/2AB.

(3)

CLOSE Bkr 2-20409, 416KV BUS TIE 2B3/2AB.

(4)

CLOSE Bkr 2*20504,4 16KV BUS TIE 2AB/2B3.

5.

ALIGN 480V Load Center 2AB to B side, as follows A.

REFER TO Technical SpeCifications 3.3 3.1 for the Plant Vent Stack Radiation Monitor.

B.

IF Charging Pump 2C is running, THEN ALIGN charging pumps per 2*NOP*0202, Charging and Letdown, to prepare for the loss of Charging Pump 2C.

17 12 of 37

(

REVISION NO PROCEDURE TITLE PAGE' 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO 2-NOP-5202 ST LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

NOTE While performing Section 4.1 Step 4, the following annunciators will be received B-48, 4.16KV SWGR 480V LC/MCC 2AB UV (RTGB 201)

S-26, 2C CCW PUMP HDR VALVES/AB BUS MISALIGNMENT (RTGB 206)

4.

ALIGN 4160V Bus 2AB to B side, as follows A_

At RTGB 201, VERIFY the following tie breakers are OPEN B.

Bkr 1-20501, 1AB 416 KV BUS SBO TIE Bkr 2-20501, 2AB 416 KV BUS SBO TIE VERIFY the following pump control sWitches are in PULL-TO-LOCK Component Cooling Water Pump 2C (RTGB 206)

Intake Cooling Water Pump 2C (RTGB 202)

C.

At RTGB 201, PERFORM the following (1)

OPEN Bkr 2-20505. 4.16KV BUS TIE 2AB/2A3 (2)

OPEN Bkr 2-20208, 4.16KV BUS TIE 2A3/2AB.

(3)

CLOSE Bkr 2-20409,4 16KV BUS TIE 2B3/2AB (4)

CLOSE Bkr 2-20504.4 16KV BUS TIE 2AB/2B3.

5.

ALIGN 480V Load Center 2AB to B side, as follows A.

REFER TO Technical Specifications 3.3 3.1 for the Plant Vent Stack Radiation Monitor.

B_

IF Charging Pump 2C is running. THEN ALIGN charging pumps per 2-NOP-02 02, Charging and Letdown, to prepare for the loss of Charging Pump 2C 17 12 of 37

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

5 Event #

_2~ ____ Page L-of _1,.;;,,9---11 Event

Description:

Loss of 2B Component Cooling Water Pump Time II Position

~

Applicant's Actions or Behavior

! Booth Operator Instructions:

r;dications Available:

I Examiners Note: Due to the time needed to swap the 2AB 480V and 2AB DC bus, i consider moving on with scenario and initiate Event 3. (Typical time for crews to

! perform the below is 30*40 minutes) r-----

I I

SRO i

i i

i

~------

i i

T.S.

I I

I SRO I

i

~

i l--... __.. _---t-i RO I

I BOP l-i i

I i

I

. ----+-

I I

i I

I i

I

~------l-If time permits directs realignment of 2AB 480VAC Load Center and DC bus 2AB to B side per 2-NOP-52.02, alignment of 2AB Busses and Components, steps 4.1.1 thru 4.1.3, 4.1.5, 4.1.6 (attached page _ 19-29_)

T.S. 3.3.3.1, Radiation Monitoring Instrumentation, action 27 Plant Vent on 480 VAC Swgr swap loss of power.(72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months action)

Monitors primary plant.

Goes to Hold on turbine if directed.

Lines up 2C CCW pump to replace 2B CCW pump as directed per step 6.2.3.B 1 & 2 (attached page_15_)

Swaps of 2AB bus to the B side as directed per step 6.2.3.B.4 thru 2-NOP-52.02, Alignment Of 2AB Buses And Components, step 4.1.4 A thru C (attached page_17_)

Starts the 2C CCW pump as directed per step 6.2.3.B.5 (attached page_16_)

Places 2B CCW pump to Pull To Lock position as directed per step 6.2.3.B.7 (attached page_16_)

I lf directed realign the 2AB 480VAC Load Center and DC bus 2AB to B side as directed per 2-NOP-52.02, alignment of 2AB i

I Busses and Components steps 4.1.1 thru 4.1.3,4.1.5,4.1.6

~.. __ ~

-,-(_at_ta_c_h_e_d_p_ag_e ___ 1_9_-2_9_) _____________

..-I 18

(

~~~~~

Appendix D Operator Action Form ES-D-2 i~ Test No 1

l Event Description Scenario #

5 Event#

....;2~ ____ Page 5

of 19 Loss of 28 Component Cooling Water Pump i Booth Operator Instructions:

r;dications Available:

I I Examiners Note: Due to the time needed to swap the 2AB 480V and 2AB DC bus, I consider moving on with scenario and initiate Event 3. (Typical time for crews to I perform the below is 30-40 minutes)

r--------

I I

If time permits directs realignment of 2AB 480VAC Load Center SRO and DC bus 2AB to B side per 2-NOP-52.02, alignment of 2AB Busses and Components, steps 4.1.1 thru 4.1.3, 4.1.5, 4.1.6 i

I (attached page_19-29_)

~~.

i,

r--~---~

t T.S. 3.3.3.1, Radiation Monitoring Instrumentation, action 27 i

T.S.

SRO I Plant Vent on 480 VAC Swgr swap loss of power.(72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months action)

~

RO Monitors primary plant.

I i

BOP Goes to Hold on turbine if directed.

i i

i Lines up 2C CCW pump to replace 2B CCW pump as directed I

I per step 6.2.3.B 1 & 2 (attached page_15_)

i

.- --- _." ----i-~

I Swaps of 2AB bus to the B side as directed per step 6.2.3.B.4 I

thru 2-NOP-52.02, Alignment Of 2AB Buses And Components, i

step 4.1.4 A thru C (attached page_17_)

I----~-.--

I I

1 I

Starts the 2C CCW pump as directed per step 6.2.3.B.5 I

(attached page_16_)

i i

I I

I l

I Places 2B CCW pump to Pull To Lock position as directed per

~ ________ i II' step 6.2.3.B.7 (attached page_16_)

'0 __ -

- ------ ----t-i ------r. ----------------------------<

Ilf directed realign the 2AB 480VAC Load Center and DC bus I 2AB to B side as directed per 2-NOP-52.02, alignment of 2AB I Busses and Components steps 4.1.1 thru 4.1.3, 4.1.5, 4.1.6

_~ ___ ~~~

_ __'_(_a_tt_a_ch_e_d_p_a_g_e_-_19_-_2_9_) _____________

.J 18

~~--------------------

REVISION NO PROCEDURE TITLE PAGE 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 7 of 37 PROCEDURE NO 2-NOP-5202 ST LUCIE UNIT 2 4.0 INSTRUCTIONS 4_1 Transfer of 2AB Buses and Comgonents from A Side to B Side

1.

REMOVE the Vital AC SUPS Rectifier from service by performing the following A.

At 125V DC Bus 20. ENSURE Bkr 2-61303, PLANT VITAL AC SUPS, is ON B.

At 480V MCC 2AB, ENSURE Bkr 2-42434, CONST VOLTAGE TRANSFORMER, IS ON.

C.

At Vital AC SUPS Inverter, PERFORM the following (1 )

ENSURE the following breakers are ON CB1, BATTERY INPUT CB4. ALTERNATE SOURCE AC INPUT

( 2)

NOTIFY Control Room to expect the receipt of annunciator B-33, 120 VAC VITAUSECURITY/FIRE INVTR TROUBLE (RTGB 201), alarm.

(3)

PLACE CB3. AC INPUT, in OFF.

(4)

VERIFY INVERTER SUPPLYING LOAD light remains ON.

(5)

VERIFY the following lights are ON INVERTER ON DC BATTERY POWER 480 VOL TS AC FAILURE FAN FAILURE D.

At 480V MCC 2AB. PLACE Bkr 2-42433, INVERTER RECTIFIER, In OFF E.

NOTIFY Control Room the Vital AC SUPS rectifier is removed from service F.

VERIFY annunciator B-33, 120 VAC VITAUSECURITY/FIRE INVTR TROUBLE (RTGB 201), alarm received 19 REVISION NO PROCEDURE TITLE PAGE 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 7 of 37 PROCEDURE NO 2-NOP-5202 ST LUCIE UNIT 2 4.0 INSTRUCTIONS 4.1 Transfer of 2AB Buses and ComQonents from A Side to B Side

1.

REMOVE the Vital AC SUPS Rectifier from service by performing the following A.

At 125V DC Bus 20. ENSURE Bkr 2-61303, PLANT VITAL AC SUPS. is ON B.

At 480V MCC 2AB, ENSURE Bkr 2-42434, CONST VOL TAGE TRANSFORMER, IS ON.

C.

At Vital AC SUPS Inverter, PERFORM the following (1 )

ENSURE the following breakers are ON CB1, BATTERY INPUT CB4, AL TERNATE SOURCE AC INPUT

(

(2)

NOTIFY Control Room to expect the receipt of annunciator B-33, 120 VAC VITAUSECURITY/FIRE INVTR TROUBLE (RTGB 201), alarm.

(3)

PLACE CB3, AC INPUT, in OFF.

(4)

VERIFY INVERTER SUPPLYING LOAD light remains ON.

(5)

VERIFY the following lights are ON INVERTER ON DC BATTERY POWER 480 VOL TS AC FAILURE FAN FAILURE D.

At 480V MCC 2AB, PLACE Bkr 2-42433. INVERTER RECTIFIER, In OFF E.

NOTIFY Control Room the Vital AC SUPS rectifier is removed from service F.

VERIFY annunciator B-33, 120 VAC VITAUSECURITY/FIRE INVTR TROUBLE (RTGB 201), alarm received 19

REv'SION NO 12 PROCEDURE TITLE PAGE:

ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO 2-NOP-5202 ST LUCIE UNIT 2 4,1 Transfer of 2AB Buses and Components from A Side to B Side (continued) 2, REMOVE the Fire and Security SUPS Rectifier from service by performing the following:

A.

At 125VDC Bus 2D, ENSURE Bkr 2-61305, SECURITY VITAL SUPS, is ON.

B, At 480V MCC 2C, ENSURE Bkr 2-42508, PS & FD INVERT, is ON.

C.

At Fire Detection & Station Security Vital A.C. SUPS Inverter, PERFORM the following:

(1)

ENSURE the following breakers are ON:

CB1, BATTERY INPUT CB4, ALTERNATE SOURCE AC INPUT (2)

NOTIFY Control Room to expect the receipt of 8-33, 120 VAC VITAUSECURITY FIRE INVTR TROUBLE (RTGB 201), alarm_

(3)

PLACE CB 403, AC INPUT, in OFF_

(4)

VERIFY INVERTER SUPPLYING LOAD light remains ON.

(5)

VERIFY the following lights are ON:

FAN FAILURE AC POWER FAILURE BATTERY CURRENT D.

At 480V MCC 2AB, PLACE Bkr 2-42415, INVERTER SEC SUPS RECT, in OFF.

E.

NOTIFY Control Room the Fire and Security SUPS Rectifier is removed from service F.

VERIFY annunciator B-33, 120 VAC VITAUSECURITY FIRE INVTR TROUBLE (RTGS 201), alarm received.

20 8 of 37 FlFV'SION NO PROCEDURE TITLE PAGE 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 8 of 37 PfiOCEDURE NO 2*NOP*52 02 S1. LUCIE UNIT 2 4,1 Transfer of 2AB Buses and Components from A Side to B Side (continued) 2, REMOVE the Fire and Security SUPS Rectifier from service by performing the following.

A.

At 125VDC Bus 20, ENSURE Bkr 2-61305, SECURITY VITAL SUPS, is ON.

B, At 480V MCC 2C, ENSURE Bkr 2-42508, PS & FD INVERT, IS ON C,

At Fire Detection & Station Security Vital A.C. SUPS Inverter, PERFORM the following (1 )

ENSURE the following breakers are ON.

CB1, BATTERY INPUT CB4, ALTERNATE SOURCE AC INPUT

(

(2)

NOTIFY Control Room to expect the receipt of B-33, 120 VAC VITAUSECURITY FIRE INVTR TROUBLE (RTGB 201), alarm (3)

PLACE CB 403. AC INPUT, In OFF (4)

VERIFY INVERTER SUPPLYING LOAD light remains ON (5)

VERIFY the following lights are ON.

FAN FAILURE AC POWER FAILURE BATTERY CURRENT D.

At 480V MCC 2AB, PLACE Bkr 2-42415, INVERTER SEC SUPS RECT, In OFF E.

NOTIFY Control Room the Fire and Security SUPS Rectifier is removed from service F.

VERIFY annunciator B-33, 120 VAC VITAUSECURITY FIRE INVTR TROUBLE (RTGB 201). alarm received.

20

(

~-.-

REViSION NO PROCEDURE TITLE PAGE:

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO 2*NOP*52.02 ST. LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

3.

TRANSFER DC Bus 2AB to DC Bus 2B by performing the following A.

VERIFY Battery Charger 2A and/or 2-M is supplying power to 125V DC Buses 2A and 2M.

B.

VERIFY Battery Charger 2B and/or 2-BB is supplying power to 125V DC Buses 2B and 2BB.

C.

At 480V MCC 2AB, ENSURE Bkr 2-42413, BATTERY CHARGER 2AB, is positioned to ON.

0, At Battery Charger 2AB, PERFORM the following (1)

ENSURE the OFF/ON switch is positioned to ON (2)

ENSURE 2AB BATTERY CHARGER AC INPUT BREAKER IS positioned to ON CAUTION 9 of 37 If the AC Input breaker IS in OFF. then to ensure proper charger warm up, the AC input breaker should be positioned to ON at least 15 minutes prior to placing the DC output breaker to ON.

(3)

ENSURE 2AB BATTERY CHARGER DC OUTPUT BREAKER is positioned to ON.

(4)

VERIFY DC output voltage IS 132 to 137 VDC In the float mode (5)

IF DC voltage IS outside the 132 to 137 VDC range, THEN PERFORM the following

a.

PLACE 2AB BATTERY CHARGER DC OUTPUT BREAKER In OFF

b.

PLACE 2AB BATTERY CHARGER AC INPUT BREAKER in OFF

c.

NOTIFY the US/NWE (6)

IF the DC output voltage is satisfactory, THEN PLACE Battery Charger 2AB in the equalize mode by turning the equalizer timer to HOLD.

21 REV:SION NO PROCEDURE TITLE PAGE:

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO 2-NOP-S2 02 S1. LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

3.

TRANSFER DC Bus 2AB to DC Bus 2B by performing the following A.

VERIFY Battery Charger 2A and/or 2-M is supplying power to 125V DC Buses 2A and 2M B.

VERIFY Battery Charger 2B and/or 2-BB is supplying power to 125V DC Buses 2B and 2BB.

C.

At 480V MCC 2AB, ENSURE Bkr 2-42413, BATTERY CHARGER 2AB, IS positioned to ON.

0, At Battery Charger 2AB, PERFORM the following (1)

ENSURE the OFF/ON switch is positioned to ON (2)

ENSURE 2AB BATTERY CHARGER AC INPUT BREAKER IS positioned to ON CAUTION 9 of 37 If the AC Input breaker IS in OFF. then to ensure proper charger warm up, the AC input breaker should be positioned to ON at least 15 minutes prior to placing the DC output breaker to ON.

(3)

ENSURE 2AB BATTERY CHARGER DC OUTPUT BREAKER is positioned to ON.

(4)

VERIFY DC output voltage IS 132 to 137 VDC In the float mode.

(5)

IF DC voltage IS outside the 132 to 137 VDC range, THEN PERFORM the following

a.

PLACE 2AB BATTERY CHARGER DC OUTPUT BREAKER In OFF

b.

PLACE 2AB BATTERY CHARGER AC INPUT BREAKER in OFF

c.

NOTIFY the US/NWE (6)

IF the DC output voltage is satisfactory, THEN PLACE Battery Charger 2AB in the equalize mode by turning the equalizer timer to HOLD.

21

REVISION NO PROCEDURE TITLE PAGE:

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEJURE NO 2*NOP-5202 ST LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

3.

(continued)

NOTE 10 of 37 The following alarms on RTGB 201 may be received during the performance of Section 4.1 Step 3.E through Section 4.1 Step 3.J due to no charge conditions on the respective side A20, 125V DC BATT CHGR 2B/2BB TROUBLE A50, 125V BATT CHGR 2AB TROUBLE B20, 125V DC BATT CHGR 2A12AA TROUBLE E.

At 125V DC Bus 2AB, PLACE Bkr 2-60326, CKT #26 (Battery Charger 2AB), in ON F,

IF DC amperage on Battery Charger 2AB does NOT increase as expected, THEN PERFORM the following:

(1)

Immediately PLACE Bkr 2-60326, CKT #26 (Battery Charger 2AB), in OFF.

(2)

CONT ACT US/NWE for further instructions.

G.

NOTIFY Control Room that Battery Charger 2AB is powering 125V DC Bus ZAB.

NOTE When performing Section 4.1 Step 3. H, the following annunciators will ALARM:

S-16, EM ERG 125VDC/4.16KV/480V AB BUSES MISALIGNED (RTGB 206)

B-60, EMERG 125V DCf4.16KV/480V AB BUSES MISALIGNED (RTGB 201)

H.

At RTGB 201, PERFORM the following:

(1)

OPEN Bkr 2*60335, TIE 2AB/2A.

(2)

OPEN Bkr 2*60143, TIE 2A12AB.

22

(

. ----.. -.---.-------.~

ReVISION NO PROCEDURE TITLE PAGE' 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PRl)CEJURE NO 2 NOP-52 02 ST LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

3.

(continued)

NOTE 10 of 37 The following alarms on RTGB 201 may be received during the performance of Section 4 1 Step 3 E through Section 4.1 Step 3.J due to no charge conditions on the respective side A20, 125V DC 8ATT CHGR 28/28B TROUBLE A50, 125V BAn CHGR 2AB TROUBLE B20, 125V DC BATT CHGR 2A12AA TROUBLE E.

At 125V DC Bus 2AB, PLACE Bkr 2-60326, CKT #26 (Battery Charger 2AB), In ON F.

IF DC amperage on Battery Charger 2AB does NOT increase as expected, THEN PERFORM the following (1)

Immediately PLACE Bkr 2-60326, CKT #26 (Battery Charger 2AB), in OFF (2)

CONTACT USINWE for further instructions.

G.

NOTIFY Control Room that Battery Charger 2AB is powering 125V DC Bus 2A8.

NOTE When performing SectIOn 4.1 Step 3 H, the following annunciators will ALARM S-16, EM ERG 125VDC/4 16KV/480V AB BUSES MISALIGNED (RTGB 206) 8-60, EMERG 125V DC/4 16KV/480V AB BUSES MISALIGNED (RTGB 201)

H.

At RTGB 201, PERFORM the following (1)

OPEN Bkr 2-60335, TIE 2A8/2A.

(2)

OPEN Bkr 2-60143, TIE 2A12AB.

22

REYI$IO'J NO PROCEDURE TITLE PAGE:

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 11 of 37 PROCEDURE NO 2*NOP*5202 ST. LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

3.

H.

( continued)

(3)

CLOSE Bkr 2-60243, TIE 2B/2AB.

(4)

CLOSE Bkr 2-60333, TIE 2AB/2B.

I.

VERIFY the following annunciators are in ALARM:

S-16, EMERG 125VDC/4.16KV/480V AB BUSES MISALIGNED (RTGB 206)

B-60, EMERG 125V DC/4.16KV/480V AB BUSES MISALIGNED (RTGB 201)

J.

At Battery Charger 2AB, TURN the equalizer timer to zero (0).

K, VERIFY Battery Chargers 2B and/or 2-BB are carrying some load.

L.

At 125V DC Bus 2AB, PLACE Bkr 2*60326, CKT #26 (Battery Charger 2AB), in OFF.

M.

NOTIFY Control Room that Battery Charger 2AB is in hot standby.

N.

ENSURE the following battery charger trouble alarms are CLEAR by resetting their associated reflash panels, if necessary B*20, 125V DC BATT CHGR 2A12AA TROUBLE (RTGB-201). Reflash Panel RA-RAB*11/B-20 (RAB/49/RA2/RAJ) and Reflash Panel RA*RAB-26/B-20 (RAB/48/N-RA4/E-RAK)

A*20, 125V DC BATT CHGR 2B/2BB TROUBLE (RTGB*201) Reflash Panel RA*RAB*10/A*20 (RAB/48/N*RA3/E*RAK) and Reflash Panel RA-RAB-27/A-20 (RAB/48/S-RA3NV-RAK)

A*50, 125V DC BATT CHGR 2AB TROUBLE (RTGB-201)* Reflash Panel RA-RAB-12/A*50 (RAB/48/N*RA2/E*RAL) 23

~----.---------

R[VIS'O'J NO PROCEDURE TITLE PAGE.

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 11 of 37 PROCEDURE NO 2-NOP-52 02 ST. LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

3.

H.

(continued)

(3)

CLOSE Bkr 2-60243, TIE 2B/2AB.

(4)

CLOSE Bkr 2-60333, TIE 2AB/2B I.

VERIFY the following annunCiators are in ALARM S-16, EMERG 125VDC/416KV/480V AB BUSES MISALIGNED (RTGB 206)

B-60, EMERG 125V DC/4.16KV/480V AB BUSES MISALIGNED (RTGB 201)

J.

At Battery Charger 2AB, TURN the equalizer timer to zero (0)

K, VERIFY Battery Chargers 2B and/or 2-BB are carrying some

(

load L.

At 125V DC Bus 2AB, PLACE Bkr 2-60326, CKT #26 (Battery Charger 2AB), in OFF.

M.

NOTIFY Control Room that Battery Charger 2AB is in hot standby N.

ENSURE the following battery charger trouble alarms are CLEAR by resetting their associated reflash panels, if necessa ry B-20. 125V DC BATT CHGR 2N2AA TROUBLE (RTGB-201) - Reflash Panel RA-RAB-11/B-20 (RAB/49/RA2/RAJ) and Reflash Panel RA-RAB-26/B-20 (RAB/48/N-RA4/E-RAK)

A-20, 125V DC BATT CHGR 2B/2BB TROUBLE (RTGB-201) Reflash Panel RA-RAB-10/A-20 (RAB/48/N-RA3/E-RAK) and Reflash Panel RA-RAB-271A-20 (RAB/48/S-RA3/vv-RAK)

A-50, 125V DC BATT CHGR 2AB TROUBLE (RTGB-201) - Reflash Panel RA-RAB-12/A-50 (RAB/48/N-RA2/E-RAL) 23

REVISION NO 12 PROCEDURE TiTLE PAGE' ALIGNMENT OF 2AB BUSES AND COMPONENTS 13 of 37 PROCEDURE NO 4,1 2*NOP*5202 ST. LUCIE UNIT 2 Transfer of 2AB Buses and Components from A Side to B Side (continued)

5.

(continued)

C.

IF Control Room NC HVNACC-3C is operating, THEN ALIGN Control Room air conditioning per 2*NOP*25,07, Control Room Ventilation System, to prepare for the loss of HVNACC-3C.

NOTE Refer to Attachment 2. Expected Alarms When Transferring 480V Load Center 2AB Power Source, for alarms received when performing the following step, D.

At RTGB 201, PERFORM the following:

(1)

OPEN Bkr 2*40702, 480V BUS TIE 2AB/2A2, (2)

OPEN Bkr 2*40220, 480V BUS TIE 2A2/2AB (3)

CLOSE Bkr 2-40504, 480V BUS TIE 2B2/2AB, (4)

CLOSE Bkr 2-40706, 480V BUS TIE 2AB/2B2, 6,

VERIFY the following annunciators are CLEAR

7.

6*60, EM ERG 125V DC/4, 16KV/480V AB BUSES MISALIGNED (RTGB 201)

S-16, EMERG 125VDC/4,16KV/480V AB BUSES MISALIGNED (RTGB 206)

NOTE Section 4,1, Steps 7 through 19, may be completed in any order, ENSURE N-45, WASTE MANAGEMENT LOCAL ALARM (RTGB-205) is CLEAR by locally acknowledging alarms on Waste Management Panel. if necessary,

8.

VERIFY annunciators listed in Attachment 2 are CLEAR g,

RESTORE charging pumps to the desired lineup per 2-NOP-02,02, Charging and Letdown, 24

(

REVISION NO PROCEDURE TITLE PAGE 13 of 37 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PROUDURE NO 4.1 2 NOP*52 02 ST LUCIE UNIT 2 Transfer of 2AB Buses and Components from A Side to B Side (continued) 5, (continued)

C, IF Control Room AlC HVAlACC-3C is operating, THEN ALIGN Control Room air conditioning per 2-NOP-25 07, Control Room Ventilation System, to prepare for the loss of HVAlACC-3C Refer to Attachment 2, Expected Alarms When Transferring 480V Load Center 2AB Power Source, for alarms received when performing the following step.

0, At RTGB 201, PERFORM the following (1)

OPEN Bkr 2-40702, 480V BUS TIE 2AB/2A2.

(2)

(3)

OPEN Bkr 2*40220, 480V BUS TIE 2A2/2AB CLOSE Bkr 2-40504, 480V BUS TIE 2B2/2AB.

(4)

CLOSE Bkr 2-40706, 480V BUS TIE 2AB/2B2 6,

VERIFY the follOWing annunciators are CLEAR

7.

B-60. EMERG 125V DC/4.16KV/480V AB BUSES MISALIGNED (RTGB 201)

S-16, EMERG 125VDC/4.16KV/480V AB BUSES MISALIGNED (RTGB 206)

NOTE Section 4 1, Steps 7 through 19, may be completed in any order.

ENSURE N-45, WASTE MANAGEMENT LOCAL ALARM (RTGB-205) IS CLEAR by locally acknowledging alarms on Waste Management Panel, if necessary.

8.

VERIFY annunCiators listed in Attachment 2 are CLEAR.

g, RESTORE charging pumps to the desired lineup per 2-NOP*02,02, Charging and Letdown 24

REVISION NO PROCEDURE TITLE PAGE 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 14 of 37 P"<OCEOURc NO 2-NOP-5202 ST LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side INITlAL (continued) 1 Q, At RTGB-206, ALIGN 2C CCW Pump to 2B CCW header as follows A.

CLOSE MV-14-1, PUMP 2C DISCH TO HEADER A IV B.

CLOSE MV-14-3, HEADER A TO PUMP 2C.

IV C.

OPEN MV-14-4, HEADER B TO PUMP 2C IV D.

OPEN MV-14-2, PUMP 2C DISCH TO HEADER B IV

(

E.

VERIFY annunciator S-26, 2C CCW PUMP HDR VALVES/AS BUS MISALIGNMENT, is CLEAR.

F.

IF 2C CCW Pump is required to be running, THEN START 2C CCW Pump per 2-NOP-14 02, Component Cooling Water System Operation.

11.

ALIGN 2C ICW Pump to 2B ICW header, as follows:

A.

LOCK CLOSED SB21165, 2C ICW PUMP X-TIE DISCH To

'A' TRAIN ISOL (INTK/9/N-4!W-C)

IV B.

LOCK OPEN SB21211, 2C ICW PUMP X-TIE DISCH To '8' TRAIN ISOL (INTK/9/N-4!W-C).

IV C.

IF 2C ICW Pump IS required to be running, THEN START 2C ICW Pump per 2-NOP-21 03, Intake Cooling Water System Operation 25 REVISION NO PROCEDURE TITLE PAGE 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 14 of 37 P'<OCEIJURc NO 2*NOP*5202 ST LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side INITIAL (continued)

10.

At RTGB*206, ALIGN 2C CCW Pump to 2B CCW header as follows A.

CLOSE MV-14*1, PUMP 2C DISCH TO HEADER A.

IV B.

CLOSE MV-14-3, HEADER A TO PUMP 2C.

IV C.

OPEN MV-14-4. HEADER B TO PUMP 2C IV D.

OPEN MV-14*2, PUMP 2C DISCH TO HEADER B IV

(

E.

VERIFY annunciator S*26, 2C CCW PUMP HDR VALVES/AB BUS MISALIGNMENT, is CLEAR.

F.

IF 2C CCW Pump is required to be running, THEN START 2C CCW Pump per 2*NOP*14 02, Component Cooling Water System Operation 11.

ALIGN 2C ICW Pump to 2B ICW header, as follows:

A.

LOCK CLOSED SB21165, 2C ICW PUMP X-TIE DISCH To

'A' TRAIN ISOL (INTKl9/N*41W*C)

IV B,

LOCK OPEN SB21211, 2C ICW PUMP X*TIE DISCH To 'B' TRAIN ISOL (INTKl9/N*41W*C).

IV C.

IF 2C ICW Pump IS required to be running, THEN START 2C ICW Pump per 2-NOP-21 03, Intake Cooling Water System Operation 25

REVISION NO PROCEDURE TITLE PAGE:

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 15 of 37 PROCEDURE NO 2*NOP-5202 ST LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side INITIAL (continued)

12.

ALIGN HVAlACC-3C, Control Room Area Supply Air Handling Unit.

CCW supply and return headers to the 2B CCW header as follows:

A.

LOCK CLOSED V14510. SUPPLY HDR A TO HVAlACC-3C CNTL ROOM AlC ISOL (RABf70/S-RA21W-RAI)

IV B.

LOCK CLOSED V14518, HVAlACC-3C CNTL ROOM AlC TO RETURN HDR A ISOL (RAB/70/S-RA2/E-RAJ).

IV C.

LOCK OPEN V14506, SUPPLY HDR B TO HVAlACC-3C CNTL ROOM AlC ISOL (RAB/70/N-RA2IW-RAI).

-IV-D.

LOCK OPEN V14514, HVAlACC-3C CNTL RM AlC TO RETURN HDR B ISOL (RAB/70/S-RA2/E-RAJ).

IV

13.

IF HVAlACC-3C is required for operation, THEN START HVNACC-3C per 2-NOP-25 07. Control Room Ventilation System.

14.

IF the Instrument Air Emergency Cooling System radiator fan and recirculation pump were in service, THEN PERFORM the following A.

Locally START Recirculation Pump (TGB/24/24/E-B).

B.

Locally START Radiator Fan (TGB/24/24/E-B).

26

~.--------

(

REVISION NO PROCEOURE TITLE PAGE.

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 15 of 37 PROCEDURE NO 2-NOP-52 02 ST LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side INITIAL (continued)

12.

ALIGN HVNACC-3C, Control Room Area Supply Air Handling Unit.

CCW supply and return headers to the 2B CCW header as follows:

A.

LOCK CLOSED V14510. SUPPLY HDR A TO HVNACC*3C CNTL ROOM NC ISOL (RAB!70/S-RA2f\\N-RAI)

IV B.

LOCK CLOSED V14518, HVNACC-3C CNTL ROOM NC TO RETURN HDR A ISOL (RAB/70/S-RA2/E-RAJ)

IV C.

LOCK OPEN V14506, SUPPLY HDR B TO HVNACC-3C CNTL ROOM NC ISOL (RAB/70/N-RA2f\\N-RAI)

IV

(

D.

LOCK OPEN V14514, HVNACC-3C CNTL RM NC TO RETURN HDR B ISOL (RAB/70/S-RA2/E-RAJ)

IV

13.

IF HVNACC*3C is required for operation, THEN START HVNACC-3C per 2-NOP-25 07. Control Room Ventilation System

14.

IF the Instrument Air Emergency Cooling System radiator fan and reCIrculation pump were In service. THEN PERFORM the following A.

Locally START ReCIrculation Pump (TGB/24/24/E-B)

B.

Locally START Radiator Fan (TGB/24/24/E-B) 26

REVISION NO 12 PROCEDURE TITLE PAGE:

ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO 2-NOP-5202 ST. LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (contin ued) t:!Q.I£ Verification of proper Plant Vent Stack Radiation Monitor operation Includes pump restart when power is restored.

Tech Spec 3 3.3.1 is applicable.

15.

VERIFY proper operation of RC-26-90, PL T VENT STACK RAD MONITOR, by performing the following A.

On Plant Auxiliary Control Board No.2, VERIFY OPER green LED is ON for the following:

LOW RANGE EFF LEVEL B.

On PC-11 Radiation Monitor, VERIFY the following parameters on Grid 4 are GREEN (normal):

AAL621 AAE624 C.

If indications are NOT normal, PRESS the FLOW pushbutton on RC-26-90, PL T VENT STACK RAD MONITOR panel to start sample fiow D.

If indications are still NOT normal, CONTACT I&C.

16.

IF HVE-37, PASS Room Fan. was running, THEN locally VERIFY restart of the fan

17.

VERIFY annunciator N-45, WASTE MANAGEMENT LOCAL ALARM (RTGB 205). IS clear.

18.

RESTORE the Vital AC SUPS Rectifier to service by performing the follOWing A.

At 480V MCC 2AB, PLACE Bkr 2-42433. INVERTER RECTIFIER, in ON, 27 16 of 37

(

REVISION NO PROCEDURE TITLE PAGE:

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO 2*NOP*5202 ST. LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

NOTE Verification of proper Plant Vent Stack Radiation Monitor operation Includes pump restart when power is restored.

Tech Spec 3 331 is applicable.

15.

VERIFY proper operation of RC*26*90, Pl T VENT STACK RAD MONITOR, by periorming the following.

A.

On Plant Auxiliary Control Board No 2, VERIFY OPER green LED is ON for the following

8.

LOW RANGE EFF LEVEL On PC*11 Radiation Monitor, VERIFY the following parameters on Grid 4 are GREEN (normal):

ML621 ME624 C.

If Indications are NOT normal, PRESS the FLOW pushbutton on RC*26*90, PL T VENT STACK RAD MONITOR panel to start sample flow D.

If Indications are still NOT normal, CONTACT I&C.

16.

IF HVE*37, PASS Room Fan, was running, THEN locally VERIFY restart of the fan

17.

VERIFY annunciator N-45. WASTE MANAGEMENT LOCAL ALARM (RTGB 205), is clear

18.

RESTORE the Vital AC SUPS Rectifier to service by periorming the following A.

At 480V MCC 2AB, PLACE Bkr 2*42433, INVERTER RECTIFIER. In ON 27 16 of 37

REVISION NO PROCEDURE TITLE PAGE:

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 17 of 37 PROCEDURE NO 2*NOP*5202 ST. LUCIE UNIT 2 4.1 Transfer of 2A6 Buses and Components from A Side to B Side (continued)

18.

( continued)

B.

At Vital AC SUPS Inverter. PERFORM the following:

(1 )

VERIFY PRE-CHARGE light is ON.

(2)

PLACE CB3. AC INPUT, in ON.

(3)

VERIFY INVERTER SUPPLYING LOAD light remains ON.

(4)

VERIFY the following indicating lights are OFF INVERTER ON DC BATTERY POWER 480 VOLTS AC FAILURE FAN FAILURE (5)

MONITOR AC INPUT AC AMPERES meter for an increase Indicating the rectifier has picked up the load C.

NOTIFY Control Room the Vital AC SUPS rectifier is returned to service

19.

RESTORE the Fire and Security SUPS Rectifier to service by performing the following A.

At 480V MCC 2AB, PLACE Bkr 2-42415, INVERTER SEC SUPS RECT. in ON.

B.

At Fire and Security SUPS Inverter. PERFORM the following:

(1)

ENSURE PRE-CHARGE light is ON.

(2)

PLACE CB 403. AC INPUT, breaker in ON (3)

VERIFY INVERTER SUPPLYING LOAD is ON.

28

(

REVISION NO 12 PROCEDURE TITLE PAGE:

ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO ST. LUCiE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

18.

(continued)

B.

At Vital AC SUPS Inverter, PERFORM the following (1)

VERIFY PRE-CHARGE light is ON.

(2)

PLACE CB3, AC INPUT, in ON.

(3)

VERIFY INVERTER SUPPLYING LOAD light remains ON (4)

VERIFY the following indicating lights are OFF INVERTER ON DC BATTERY POWER 480 VOL TS AC FAILURE FAN FAILURE (5)

MONITOR AC INPUT A.C AMPERES meter for an Increase Indicating the rectifier has picked up the load C.

NOTIFY Control Room the Vital AC SUPS rectifier is returned to service

19.

RESTORE the Fire and Security SUPS Rectifier to service by performing the following A.

At 480V MCC 2AB, PLACE Bkr 2-42415, INVERTER SEC SUPS RECT, in ON.

B.

At Fire and Security SUPS Inverter, PERFORM the following (1)

ENSURE PRE-CHARGE light IS ON (2)

PLACE CB 403, AC INPUT. breaker In ON (3)

VERIFY INVERTER SUPPLYING LOAD is ON 28 17 of 37

REVIS'ON NO PROCEDURE TITLE PAGE:

12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO 2*NOP*5202 ST. LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side (continued)

19.

8.

(continued)

(4)

VERIFY the following indicating lights are off:

AC POWER FAILURE BATTERY CURRENT FAN FAILURE (5)

MONITOR AC INPUT AC AMPERES meter for an increase indicating the rectifier has picked up the load.

C.

NOTIFY Control Room the Fire and Security SUPS Rectifier is returned to service.

20.

VERIFY annunciator B-33, 120 VAC VITAl/SECURITY/FIRE INVTR TROUBLE, alarm CLEAR (RTGB 201).

21.

VERIFY Sewage Lift Station (located in the NE corner of the Turbine Building) is operating properly, as evidenced by the sound of the solenoids energizing and de-energizing.

29 18 of 37 PROCEDURE TITLE PAGE 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS PROCEDURE NO 2-NOP-5202 ST. LUCIE UNIT 2 4,1 Transfer of 2AB Buses and Components from A Side to B Side (continued) 19, B.

(continued)

(4)

VERIFY the following Indicating lights are off:

AC POWER FAILURE BATTERY CURRENT FAN FAILURE (5)

MONITOR AC INPUT AC AMPERES meter for an increase indicating the rectifier has picked up the load.

C.

NOTIFY Control Room the Fire and Security SUPS Rectifier is returned to service.

20.

VERIFY annunciator B-33, 120 VAC VITAL/SECURITY/FIRE INVTR TROUBLE, alarm CLEAR (RTGB 201).

21.

VERIFY Sewage Lift Station (located In the NE corner of the Turbine BUilding) is operating properly, as eVidenced by the sound of the solenoids energizing and de-energizing.

29 18 of 37

Appendix D Operator Action Form ES-D-2 II 'lOp Test No.

1 Scenario #

5 Event #

3 Page L-of il Event DescriPtion:-- Selected Pressurizer Level Channel L T 111 OX fails high 19

'~-=-=-==r~-=-=-=~---=-=======~~~~~----~~--=-----====---=91 L-Time Position A

licant's Actions or Behavior I Booth Operator Instructions: When directed by examiner, trigger L T 111 OX fails I

high.

i Indications Available: Alarms H-17 Pzr Channel X Level High/Low LA-S Pzr Channel X Level High

~.-.. --.-_._--_._----,-

8RO/RO Recognizes by numerous alarms that Selected Pressurizer Level Channel L T 111 OX failed high.

8RO Enters 2-0120035, Pressurizer Pressure And Level. (attached i

page_31-33_)

i-"~-.-

i I

T8 8RO Enters T.8 3.3.3.6a Accident Monitoring Action A (7 day action) i i

f-Directs verifying proper operation of the Letdown system

~'- -- _. _.

Directs restoring Pressurizer Heaters per 2-0120035 step

.. --_._.. _._.- -.~ _._.. _._. _.. _. __._---- 7.2.2.G. (attached page_33_)

i--

RO Verifies proper operation of the letdown system.

I I

I Restores Pressurizer Heaters as directed per 2-0120035 step 7.2.2.G. (attached page_33_)

~... _----"-

-- -.. -----.--.--~ BOP I Monitors balance of plant.

I r-30 Appendix 0 Operator Action Form ES-O-2

(

[I

1 Op Test No 1

il Event Description Scenario #

5 Event #

3 Page L-of 19 Selected Pressurizer Level Channel L T 111 OX fails high

~ I L-Time Position A

licant's Actions or Behavior Isooth Operator Instructions: When directed by examiner, trigger L T 111 OX fails i

high.

Indications Available: Alarms H-17 Pzr Channel X Level High/Low LA-S pzr Channel X Level High SRO / RO Recognizes by numerous alarms that Selected Pressurizer Level Channel L T 111 OX failed high.

~-.. --.-1-'

SRO Enters 2-0120035, Pressurizer Pressure And Level. (attached I

page_ 31-33 -)

r'.--

i I

TS I

Enters T.S 3.3.3.6a Accident Monitoring Action A (7 day action)

SRO f- ------ (

I I Directs verifying proper operation of the Letdown system I

.--------t--

I I Directs restoring Pressurizer Heaters per 2-0120035 step I

I 7.2.2.G. (attached page_ 33 -)

RO Verifies proper operation of the letdown system.

1--

i Restores Pressurizer Heaters as directed per 2-0120035 step 7.2.2.G. (attached page_33_)

BOP I Monitors balance of plant.

I

.... --.~

I i

-~--

--. ------1.

r-l-I

~-

i I

30

REVISION NO PROCEDURE TITLE PAGE 26 PRESSURIZER PRESSURE AND LEVEL PROCEDURE NO 9 of 15 2-0120035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

1.

(continued)

2.

G. if (LOOP) Loss of Offsite Power has occurred with diesel generators supplying power and pressurizer level is greater than 27%, Then perform the following to regain pressurizer heaters:

1. Manually close the breakers for pressurizer heater on 4160V buses Bkr 2-20204 on 2A3 bus Bkr 2-20403 on 2B3 bus.

2. Manually reset the backup heater breakers B1 and B4 only (200 kw each).

ABNORMAL PRESSURIZER LEVEL CONDITION NOTE

2.

Appendix "B" contains a listing of pressurizer levels which are associated with automatic actions.

A. Verify selected RRS channel is operating properly.

B. Ensure backup charging pump starts and letdown flow is decreasing, or the backup charging pump stops and letdown flow is increasing, whichever is applicable. (Appendix "B" contains expected automatic responses.)

31 A. if the selected RRS channel has failed, Then shift to the operable channel.

1.

NAVIGATE to the SBCS inputs screen on either FW FPD and reset the TAVE signal, if required B. if automatic actions have NOT occurred, Then manually control charging and letdown flow as required

(

.-----.--------~

~-~ - --_._-

~--

~-----------.-

REVISION NO PROCEDURE TITLE PAGE 26 PRESSURIZER PRESSURE AND LEVEL 9 of 15 PROCE CURE NO 2-0120035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

1.

(continued)

2.

G. Lf (LOOP) Loss of Offsite Power has occurred with diesel generators supplYing power and pressurizer level is greater than 27%, Then periorm the following to regain pressurizer heaters

1. Manually close the breakers for pressurizer heater on 4160V buses 8kr 2-20204 on 2A3 bus Bkr 2-20403 on 283 bus.

2. Manually reset the backup heater breakers 81 and 84 only (200 kw each).

ABNORMAL PRESSURIZER LEVEL CONDITION NOTE

2.

AppendiX "8" contains a listing of pressurizer levels which are associated with automatic actions.

A. Verify selected RRS channel is operating properly B.

Ensure backup charging pump starts and letdown flow is decreaSing, or the backup charging pump stops and letdown flow is Increasing, whichever IS applicable. (Appendix "8" contains expected automatic responses) 31 A. If the selected RRS channel has failed, Then shift to the operable channel.

1.

NAVIGATE to the S8CS inputs screen on either FW FPD and reset the T AVE signal, if required B. if automatic actions have NOT occurred, Then manually control charging and letdown flow as required

REVISION NO PROCEDURE TITLE PAGE 26 PRESSURIZER PRESSURE AND LEVEL 10 of 15 PROCEDURE NO 2-0120035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS 2,

(continued)

2.

(continued)

C. Verify level anomaly is NOT caused C. Slow the rate of change of by a large rate of change in T-avg.

T-avg or stabilize until level anomaly is controlled, D. Verify "Letdown Isol. Valves",

D. l! letdown has isolated, Then V-2515, V-2516, and V-2522 are secure charging and refer to open.

2-0NP-02,03, Charging and Letdown.

E.

Verify selected pressurizer level E. l! selected level control valve is control valve (LCV-2110P /

NOT operating properly, Then LCV-21100) is operating properly, take manual control of level control valve and refer to 2-0NP-02.03, Charging and

Letdown, F.

Verify selected letdown pressure F. l! selected pressure control control valve (PCV*2201 P /

valve is NOT operating PCV*22010) is operating properly, properly, Then take manual control of pressure control valve and refer to 2-0NP*02,03, Charging and Letdown.

32

.,--.-."~.'.'---

REVISION '<0 PROCEDURE TITLE PAGE 26 PRESSURIZER PRESSURE AND LEVEL 10 of 15 PROCEDURt NO 2-0120035 ST LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS 2,

(continued)

2.

(continued)

C.

Verify level anomaly is NOT caused C.

Slow the rate of change of by a large rate of change in T~avg.

T~avg or stabilize until level anomaly is controlled.

D, Verify "Letdown Isol. Valves",

D. if letdown has isolated, Then V-2515, V-2516, and V~2522 are secure charging and refer to open 2~ONP~0203, Charging and Letdown E.

Verify selected pressurizer level E. if selected level control valve IS control valve (LCV-211 OP I NOT operating properly, Then LCV-211 00) IS operating properly take manual control of level control valve and refer to 2~ONP~0203, Charging and

(

Letdown.

F, Verify selected letdown pressure F. if selected pressure control control valve (PCV-2201 PI valve is NOT operating PCV-220 10) is operating properly properly, Then take manual control of pressure control valve and refer to 2~ONP~02.03, Charging and Letdown.

32

REVISION NO PROCEDURE TITLE PAGE.

26 PRESSURIZER PRESSURE AND LEVEL 11 of 15 PROCEDURE NO 2*0120035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

2.

(continued)

2.

(continued)

NOTE With less than 27% level on Channel X, the "A" pressurizer heater transformer feeder breaker (2-20204) trips and the "B" side 480V power supplies deenergize. With less than 27% level on Channel Y, the "B" pressurizer heater transformer feeder breaker (2-20403) trips and the "A" side 480V power supplies deenergize. The backup interlock bypass keyswitch selected to the level position, allows the 480V heater power supplies to be reset.

G. Verify pressurizer level indicating controllers (selected and non-selected) are operating properly and power is available to pressurizer heaters.

33 G. !f pressurizer heaters are deenergized or level indicating controller(s) failed, Then perform the following:

1. J1 either level control channel has failed, Then shift to the operable channel and reset heaters as follows:

a. Place the backup interlock bypass keyswitch (RTGB-203) to the LEVEL position (This regains power to the proportional and backup heater banks controlled by the selected channel.)

b. Reset pressurizer heater banks as needed.

OR

(

--~---------- ------------------ ------

REVISION NO PROCEDURE TITLE PAGE 26 PRESSURIZER PRESSURE AND LEVEL PROCEDURE NO 11 of 15 2-0120035 ST_ LUCIE UNIT 2 7,2 Subsequent Operator Actions (continued) 2, INSTRUCTIONS CONTINGENCY ACTIONS (continued)

2.

(continued)

NOTE With less than 27% level on Channel X, the "A" pressurizer heater transformer feeder breaker (2-20204) trips and the "8" side 480V power supplies deenergize, With less than 27% level on Channel Y, the "8" pressurizer heater transformer feeder breaker (2-20403) trips and the "A" side 480V power supplies deenergize, The backup interlock bypass keyswltch selected to the level position, allows the 480V heater power supplies to be reset.

G. Verify pressurizer level indicating controllers (selected and non-selected) are operating properly and power is available to pressurizer

heaters, 33 G. If pressurizer heaters are deenergized or level indicating controller( s) failed, Then perform the following:

1. If either level control channel has failed, Then shift to the operable channel and reset heaters as follows:

a. Place the backup interlock bypass keyswitch (RTGB-203) to the LEVEL position (This regains power to the proportional and backup heater banks controlled by the selected channel)

b. Reset pressuriZer heater banks as

needed, OR

Appendix D Operator Action Form ES-D-2 II Op Test No.:

1 Scenario #

5 Event #

4 Page 7

of 19

~--------

~~I Event

Description:

PORV 1474 Acoustic Monitor fails Time II Position II Applicant's Actions or Behavior r--------------------------------------------------------------~

! Booth Operator Instructions: When directed by examiner, trigger PORV 1474 Acoustic Monitor fails

--~~------

Indications Available: Alarms LC-1 PZR PORV/SAFETY OPEN Examiners Note: If Applicants realize that only the Acoustic Monitor has failed, they may elect to swap PORV Block valves. (Open V1477 and Close V1476 and o~n breaker) This will allow T.S. 3.3.3.6 to be exited.

SRO/ROI Recognize that PORV 1474 Acoustic Monitor is in alarm.

BOP I

+-

Enters 2-0120036, Pressurizer Reliefl Safety Valve (attached i

SRO page_35_)

I TS Evaluates T.S. 3.3.3.6, Accident Monitoring Instrumentation (7 i

day action and monitor alt indicators every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , may refer I

to 2-0SP-1 00.17, Accident Monitoring Instrumentation Monthly i

SRO

-- -- ---------------1----

Channel Check, step 7.1.18 (attached page_36_)

Directs checking plant parameters to determine if PORV is open by 2-0120036, steps 7.2.1 by checking PORV 1474 i

Position indicating light, Discharge line temperature and Quench Tank parameters and documenting using Data Sheet

30.

I Determines that only the PORV 1474 Acoustic Monitor has

failed.

--.. -~-.--+--

~-----

i Observes tailpipe temperatures, pressurizer pressure stable, RO n

i

' a d determines PORV 1474 IS not open.

----------------+-*------+1 ------------------------------------------------i I

_-_______________ +---_______________________________________ ---1 RO Checks as directed plant parameters to determine if PORV is open by 2-0120036, steps 7.2.1 by checking PORV1474 Position indicating light, Discharge line temperature and Quench Tank parameters. Documents using Data Sheet 30.

--.-------------!---------t------------------------------~_______l BOP I Monitors balance of plant 34

(

AppelldIx D Operator Actioll Form ES-D-2 1

Scellario #

5 Evellt#

4 Page 7

of PORV 1474 Acoustic Monitor fails ii TIme

]I I~

POSitIOIl II Applicallt's Actiolls or Behavior

Booth Operator Instructions: When directed by examiner, trigger PORV 1474 Acoustic Monitor fails Indications Available: Alarms LC-1 PZR PORV/SAFETY OPEN Examiners Note: If Applicants realize that only the Acoustic Monitor has failed,

. they may elect to swap PORV Block valves. (Open V1477 and Close V1476 and

~~o~ breaker This will allow T.S. 3.3.3.6 to be exited.

i SRO/ROI BOP Recognize that PORV 1474 Acoustic Monitor is in alarm.

19

~.---.. ---------J-------J---------------------------l i

L------i------t-I --------------------------1 SRO I Enters 2-0120036, Pressurizer Reliefl Safety Valve (attached I

page_ 35 -)

I i

I I I

TS Evaluates T.S. 3.3.3.6, Accident Monitoring Instrumentation (7 I

day action and monitor alt indicators every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , may refer I

to 2-0SP-1 00.17, Accident Monitoring Instrumentation Monthly i

SRO I

Channel Check, step 7.1.18 (attached page ~ 36_)

---.. _--.---+-_.

._-- l I

Directs checking plant parameters to determine if PORV is open by 2-0120036, steps 7.2.1 by checking PORV 1474 i

Position indicating light, Discharge line temperature and i

I Ouench Tank parameters and documenting using Data Sheet

30.

I Determines that only the PORV 1474 Acoustic Monitor has failed.

---.~-->-

._+_....

i RO I

RO BOP i

Observes tailpipe temperatures, pressurizer pressure stable, i

.a nd de m

P V 4 ter Jnes OR 1 74 IS not open.

. Checks as directed plant parameters to determine if PORV is open by 2-0120036, steps 7.2.1 by checking PORV1474 Position indicating light, Discharge line temperature and Ouench Tank parameters. Documents using Data Sheet 30.

! Monitors balance of plant.

34

c.

REVISION NO PROCEDURE TITLE PAGE:

14 PRESSURIZER RELIEF I SAFETY VALVE 5 of 8 PROCEDURE NO 2-0120036 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions

1.

None 7.2 Subsequent Operator Actions

1.

INSTRUCTIONS RELIEF VALVE FAILURE OR LEAKAGE:

A. Determine which PORV is open or leaking by observing acoustic flow monitors or PORV position indicating lights.

B.

11 a PORV has failed OPEN, Then place the control switch to OVERRIDE position and verify valve closure by

1. Position indicating lights.

2. Acoustic flow monitoring.

3. Discharge line temperature.

4. Quench tank parameters.

35

1.

CONTINGENCY ACTIONS A. J! it is NOT known which PORV is stuck open, Then immediately close both block valves (V-1476 and V-1477).

B. !! the relief valve does NOT close and pressurizer pressure is less than 2300 psia, Then immediately close the applicable block valve (V-14 76 or V-1477).

(

REVISION NO PROCEDURE TITLE PAGE.

14 PRESSURIZER RELIEF / SAFETY VALVE 5 of 8 PRUCE DURE NO 2-0120036 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions

1.

None 7.2 Subsequent Operator Actions

1.

INSTRUCTIONS RELIEF VALVE FAILURE OR LEAKAGE:

A. Determine which PORV is open or leaking by observing acoustic flow monitors or PORV position indicating lights S. if a PORV has failed OPEN, Then place the control switch to OVERRIDE position and verify valve closure by

1. Position indicating lights.

2. Acoustic flow monitoring.

3. Discharge line temperature.

4. Quench tank parameters.

35

1.

CONTINGENCY ACTIONS A. if it is NOT known which PORV is stuck open, Then immediately close both block valves (V-1476 and V-1477).

B. 11 the relief valve does NOT close a nd pressurizer pressure is less than 2300 psia, Then immediately close the applicable block valve (V-14 76 orV-1477)

REVISION NO PROCEDURE TITLE PAGE:

4 PROCEDURE NO ACCIDENT MONITORING INSTRUMENTATION MONTHLY CHANNEL CHECK 11 of 17 2-0SP-100.17 ST. LUCIE UNIT 2 7.1 (continued) 7.2

16.

'Verify PORV block valve position indicators are illuminated and indicate desired position (not required if the PORV block valves are closed and power is removed).

A.

V1476

8.

V1477

17.

'Verify PORV Valve Position Indicators are illuminated and indicate desired position.

A.

V1474

8.

V1475

18.

'Verify the following on the PORV and Safety Valve acoustic fiow monitor (FI-01-1, FI-01-2, FI*01-3, FI*01-4 & FI-01-5):

A.

No flow indication Red LEDs is illuminated.

8.

Power available Red LEDs are illuminated.

if it has been evaluated that an accident monitoring instrument has failed the channel check, Then ensure that a plant work order is initiated and the instrument is entered in the equipment out-of-service program.

Additionally, ensure those instruments determined to be satisfactory are removed from the equipment out-of-service program. Equipment out-of-service entries for CETs and HJTCs are documented on a form similar to Table 1 of this data sheet. A single generic EOOS entry is utilized, Table 1 will be maintained in the EOOS notebook along with the green PWO tags associated with the individual plant work orders. A single yellow dot will be affixed to the QSPDS monitor to identify that the system has pending work orders.

7.3 Ensure that Table 1 is placed in the review file at the beginning of each fuel cycle and a new Table 1 is initiated (transferring all existing EOOS entries to the new Table 1).

7.4

~J

'The Accident Monitoring Instrumentation checked by this Data Sheet has been verified against and meets the requirements of Tech Spec 3.3.3.6, Table 3.3-10 36 INITIAL

(

~--------------------

REVISION NO PROCEDURE TITLE PAGE 4

ACCIDENT MONITORING INSTRUMENTATION MONTHLY CHANNEL CHECK 11 of 17

(

PROCEDURE NO 7.1 2-0SP-10017 ST. LUCIE UNIT 2 (continued)

16.

'Verify PORV block valve position indicators are illuminated and indicate desired position (not required if the PORV block valves are closed and power is removed).

A.

V1476 B.

V1477

17.

'Verify PORV Valve Position Indicators are illuminated and Indicate desired position.

A.

V1474 B.

V1475

18.

'Verify the following on the PORV and Safety Valve acoustic flow monitor (FI-01-1, FI-01-2, FI-01-3, FI-01-4 & FI-01-5):

A.

No flow indication Red LEOs is illuminated.

B.

Power available Red LEOs are illuminated.

7.2 li it has been evaluated that an accident monitoring instrument has failed the channel check, Then ensure that a plant work order is initiated and the instrument is entered In the equipment out-of-service program.

Additionally, ensure those instruments determined to be satisfactory are removed from the equipment out-of-service program. Equipment out-of-service entries for CETs and HJTCs are documented on a form similar to Table 1 of this data sheet. A single generic EOOS entry is utilized.

Table 1 will be maintained in the EOOS notebook along with the green PWO tags associated with the individual plant work orders. A single yellow dot will be affixed to the QSPOS monitor to identify that the system has pending work orders.

7.3 Ensure that Table 1 is placed in the review file at the beginning of each fuel cycle and a new Table 1 is Initiated (transferring all existing EOOS entries to the new Table 1) 7.4 113

'The Accident Monitoring Instrumentation checked by this Data Sheet has been verified against and meets the requirements of Tech Spec 3.3.3.6, Table 33-10 36 INITIAL

c.

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

5 Event #

_5;...-____ Page L-of _1;,;;.9 __

(1 Event

Description:

Loss of Sups Vital AC Bus Inverter. Stabilize the plant after alternate source has energized the Vital AC bus.

Time II Position II Applicant's Actions or Behavior I Booth Operator Instructions: When directed by examiner, trigger Loss Of SUPS Inverter.

When contacted by Control Room acknowledge communications and trigger Restore SUPS INV.

i When contacted by Control Room: will perform steps 6.3.1 thru 6.3.5 to restore t-alternate source of power to Vital AC SUPS (attached)

~ Indications Available:

, Alarms B*33, 120V AC Vital/ Security/Fire Invtr Trouble

~

SRO/ROI Recognize numerous alarms related to the Vital AC Bus BOP Inverter failure.

I I

SRO Enters 2-0NP-49.01, SUPS-Non Safety Vital AC, ISFSI Security Or Fire And Security Inverter Malfunction.

I I

Notifies SM

~

I

~

Directs SNPO to perform step 6.1.1A (attached page_38_)

r**--

\\--

~--.

Directs SNPO to perform step 6.3.1 thru 6.3.5 (attached page_39_) to place the Inverter on alternate source.

r-I I

I I r-!,

I I

I L.

37 Appendix D Operator Action Form ES-D-2 I

il Op Test No..

1 Ii

!I Event

Description:

I

~

Time Position Scenario #

5 Event #

5 Page _8_ of Loss of Sups Vital AC Bus Inverter. Stabilize the plant after alternate source has energized the Vital AC bus.

A licant's Actions or Behavior 19 Booth Operator Instructions: When directed by examiner, trigger Loss Of SUPS Inverter.

When contacted by Control Room acknowledge communications and trigger Restore SUPS INV.

! When contacted by Control Room: will perform steps 6.3.1 thru 6.3.5 to restore alternate source of power to Vital AC SUPS (attached)

~------~--------~------------~----------------------------------~

, Indications Available:

. Alarms B*33, 120V AC Vitali Security/Fire Invtr Trouble i

I SRO/ROI Recognize numerous alarms related to the Vital AC Bus BOP Inverter failure.

SRO Enters 2-0NP-49.01, SUPS-Non Safety Vital AC, ISFSI I

Security Or Fire And Security Inverter Malfunction.

I f--

Notifies SM I

r Directs SNPO to perform step 6.1.1 A (attached page_38_l f-----..

Directs SNPO to perform step 6.3.1 thru 6.3.5 (attached I

page __ 39_l to place the Inverter on alternate source.

i I

I I

[

I

[-

I I

~----

37

REVISION NO PROCEDURE TITLE PAGE 4C SUPS - NON-SAFETY VITAL AC, ISFSI SECURITY OR i-P-RO-C-EO-U-R-E.;:;.NO-----I FIRE AND SECURITY INVERTER MALFUNCTION 5 of 28 2-0NP-49.01 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS 6.1 SUPS - Non-Safety Vital AC, ISFSI Security or Fire and Security Inverter INSTRUCTIONS CONTINGENCY ACTIONS 1,

Diagnostic Actions NOTE SUPS Vital AC Inverter power sources are:

Main feed - Bkr 2-42433, Inverter Rectifier, MCC 2AB Bypass feed* Bkr 2-42434, Const. Voltage Transformer, MCC 2AB DC feed - Bkr 2-61303, Plant Vital AC SUPS, 125VDC Bus 20 Fire and Security Inverter power sources are:

Main feed* Bkr 2-42415, Inverter Sec SUPS Rect, MCC 2AB Bypass feed - Bkr 2-42508, PS & FD Invert, MCC 2C DC feed - Bkr 2-61305, Security Vital SUPS, 125VDC Bus 2D Vital AC and Fire and Security inverters automatically shift to the alternate source in the event of a degraded voltage situation if the alternate source is available (In Sync light LIT).

A. DIRECT an operator to CHECK Reflash Module RA-RAB-4 to determine which SUPS is in alarm and the cause (West wall of the Cable Spreading Room).

NOTE Inability to gain access to the Cable Spreading Room would indicate the Fire and Security Inverter is affected.

B. !f unable to gain entry to the Cable Spreading Room, Then:

1. CONTACT Security to man Control Room and Cable Spreading Room access.

2. GO TO Section 6.4.

38

(

REVISION NO 4C PROCEDURE NO 2-0NP-49.01 PROCEDURE TilLE SUPS - NON-SAFETY VITAL AC, ISFSI SECURITY OR FIRE AND SECURITY INVERTER MALFUNCTION ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS PAGE 6.1 SUPS - Non-Safety Vital AC, ISFSI Security or Fire and Security Inverter 5 of 28 INSTRUCTIONS CONTINGENCY ACTIONS

1.

Diagnostic Actions NOTE SUPS Vital AC Inverter power sources are:

Main feed - Bkr 2-42433, Inverter Rectifier, MCC 2AB Bypass feed - Bkr 2-42434, Const. Voltage Transformer, MCC 2AB DC feed - Bkr 2-61303, Plant Vital AC SUPS, 125VDC Bus 20 Fire and Security Inverter power sources are:

Main feed - Bkr 2-42415, Inverter Sec SU PS Rect, MCC 2AB Bypass feed - Bkr 2-42508, PS & FD Invert, MCC 2C DC feed - Bkr 2-61305, Security Vital SUPS, 125VDC Bus 20 Vital AC and Fire and Security inverters automatically shift to the alternate source in the event of a degraded voltage situation if the alternate source is available (In Sync light LIT).

A. DIRECT an operator to CHECK Reflash Module RA-RAB-4 to determine which SUPS is in alarm and the cause (West wall of the Cable Spreading Room)

NOTE Inability to gain access to the Cable Spreading Room would Indicate the Fire and Security Inverter is aHected.

B. !f unable to gain entry to the Cable Spreading Room, Then:

1. CONTACT Security to man Control Room and Cable Spreading Room access.

2. GO TO Section 6.4.

0,.

~

~ n 38

REVISION NO PROCEOURE TITLE PAGE:

4C SUPS - NON* SAFETY VITAL AC, ISFSI SECURITY OR 17 of 28 PROCEDURE NO FIRE AND SECURITY INVERTER MALFUNCTION 2*0NP-49.01 ST-LUCIE UNIT 2 6.3 Loss of Vital AC SUPS Inverter INSTRUCTIONS CONTINGENCY ACTIONS

1.

ENSURE alternate source Bkr 2*42434, Const. Voltage Transformer, on MCC 2AB, is CLOSED.

2.

ENSURE the following inverter breakers are positioned as indicated:

COMPONENT ID COMPONENT NAME POSITION CB-4 Alternate Source AC Input ON CB*6 2A Vital Instr. Bus ON CB*7 2B Vital Instr. Bus ON CB*8 Vital AC Bus 2A*1 & Vital AC Bus 2B-1 ON t!QIE

The Manual Bypass Switch may have to be taken past the Alternate Source to Load position to get it to snap into the Alternate Source to Load.

The Manual Bypass Switch will NOT allow automatic transfer of the inverter when in Alternate Source to Load.

3.

RESTORE power to the Vital AC SUPS bus by placing the Manual Bypass Switch to Alternate Source to Load.

4.

VERIFY the Alternate Source Supplying

4.

!f the Alternate Source Supplying Load light is LIT.

Load light is NOT LIT, Then NOTIFY the US.

S.

CHECK with the Control Room to verify power has been restored.

6.

NOTIFY EM to investigate the malfunction and repair the inverter.

7, When the inverter has been repaired, Then RESTORE the inverter to service in accordance with 2-NOP-49.01, 120 V Vital AC Sups (Non-Class 1E) Operation.

END OF SECTION 6.3 39 REVISION NO PROCEDURE TITLE PAGE' 4C SUPS - NON*SAFETY VITAL AC, ISFSI SECURITY OR 1? of 28 PROCEDURE NO FIRE AND SECURITY INVERTER MALFUNCTION 2*0NP*4901 ST LUCIE UNIT 2 6.3 Loss of Vital AC SUPS Inverter INSTRUCTIONS CONTINGENCY ACTIONS 1.

ENSURE alternate source Bkr 2*42434, Const. Voltage Transformer, on MCC 2AB, is CLOSED.

2.

ENSURE the following inverter breakers are positioned as indicated COMPONENT ID COMPONENT NAME POSITION CB-4 Alternate Source AC Input ON CB-6 2A Vital Instr. Bus ON CB-?

2B Vital Instr. Bus ON CB-8 Vital AC Bus 2A*1 & Vital AC Bus 2B-1 ON NOTE The Manual Bypass Switch may have to be taken past the Alternate

(

Source to Load position to get it to snap into the Alternate Source to Load The Manual Bypass Switch will NOT allow automatic transfer of the Inverter when in Alternate Source to Load.

3.

RESTORE power to the Vital AC SUPS bus by placing the Manual Bypass SWitch to Alternate Source to Load

4.

VERIFY the Alternate Source Supplying

4.

11 the Alternate Source Supplying Load light is LIT.

Load light is NOT LIT, Then NOTIFY the US.

5.

CHECK with the Control Room to verify power has been restored.

6.

NOTIFY EM to investigate the malfunction and repair the inverter.

7, When the inverter has been repaired, Then RESTORE the inverter to service in accordance with 2-NOP-4901, 120 V Vital AC Sups (Non-Class 1 E) Operation.

END OF SECTION 6.3 39

Appendix D Op Test No Event

Description:

Operator Action Form ES-D-2 1

Scenario #

5 Event #

_5::..-____ Page ~

of _1_9--11 Loss of Sups Vital AC Bus Inverter. Stabilize the plant after alternate source has energized the Vital AC bus.

Time II Position II Applicant's Actions or Behavior p3'ooth Operator Instructions:

Indications Available' i Examiners Note: On the DeS, both channels for SG Wide Range level and Steam

~ Pressure will be in bypass as indicated by the Yellow overlay. When SUPS Inverter

, power restored, FW Reg. valves will have to be placed in manual to remove the I above from bypass, then, placed back to automatic.

1 When SUPS inverter placed on bypass, DeS SG Wide Range I,

level and Steam Header pressure channels will require SRO restoring from bypass. Directs transfer of MFW from AUTO to i

MANUAL, reset channels, then place MFW back to AUTO control per 2-NOP-102.01 DeS Operations per step 6.7.4 (attached page_ 41-43_) and step 6.9.4 (attached page_ 44_)

I Notifies EM per step 6.3.6

~-.

i I

Transfers MFW valves from AUTO to MANUAL, then, restores Wide Range level from bypass. Places MFW back to AUTO BOP control per 2-NOP-102.01, DeS Operations, per step 6.7.4 as directed. (attached page_ 41-43_). Restores Steam Header pressure from bypass per step 6.9.4 (attached page_ 44_)

.--.--~

I I

~

!-- ~-

i

)---~--

I i

i 40 I

(

l Appendix D Operator Action Form ES-D-2 Op Test No 1

Scenario #

5 Event #

...;:.,5 _____ Page

_9 _

of _19_-11

, Event

Description:

Loss of Sups Vital AC Bus Inverter. Stabilize the plant after alternate source has energized the Vital AC bus.

Time II Position II Applicant's Actions or Behavior I Booth Operator Instructions:

i Indications Available'

Examiners Note: On the DeS, both channels for SG Wide Range level and Steam

Pressure will be in bypass as indicated by the Yellow overlay. When SUPS Inverter

__ power restored, FW Reg. valves will have to be placed in manual to remove the i above from bypass, then, placed back to automatic.

SRO When SUPS inverter placed on bypass, DeS SG Wide Range level and Steam Header pressure channels will require restoring from bypass. Directs transfer of MFW from AUTO to MANUAL, reset channels, then place MFW back to AUTO control per 2-NOP-102.01 DeS Operations per step 6.7.4 (attached page_ 41-43_) and step 6.9.4 (attached page_ 44_)

Notifies EM per step 6.3.6

,~---t

! --------+--T-ra-n-s-fe-rs-M-F-W-v-a-Iv-e-s-f-ro-m-A-U-T-O-to-M-A-N-U-A-L-, -th-e-n-,-r-e-st-o-re-s------i I

Wide Range level from bypass. Places MFW back to AUTO

.1 BOP control per 2-NOP-1 02.01, DeS Operations, per step 6.7.4 as directed. (attached page_ 41-43_). Restores Steam Header pressure from bypass per step 6.9.4 (attached page_ 44_)

.------------\\------+---------------------------1 I

I

~----~----~------------------------~

~-----+------+--------------------------------------------~

~----~-----r------------------------------~

>---.---------t-----t-------------------------l

~-----+-------+---------------------------~

I

~------------+--------------------------~

~---.---t-------t---------------------------I 40

.. ----.-------~--

REVISION NO PROCEDURE TITLE PAGE:

8A DISTRIBUTED CONTROL SYSTEM (DCS) -

20 of 81 PROCEOURE NO OPERATIONS 2-NOP-102.01 ST. LUCIE UNIT 2 6.7 DCS Input Signal Removal I Restoration - FWCS (continued)

INITIAL

3.

C.

5.

(continued)

b.

An Info Tag appears on the S/G FW INPUTS screen above theWR level digital indicator that reads HOLDING LAST GOOD VALUE RESET REQUIRED.

c.

The digital and graphical indicators for WR level on the S/G FW INPUTS and the S/G FW OVERVIEW screen indicate POOR (Black & Cyan)

d.

The digital and graphical indicators for SG NR level Validated Output on the S/G FW INPUTS and S/G FW OVERVIEW screens indicate POOR (Black & Cyan).

6.

RETURN FPD(s) to the default screen of S/G FW OVERVIEW or as directed by the US/SM.

4.

Restoring WR level input signal from LOW POWER or HIGH POWER Mode:

A.

VERIFY from I&C or Engineering that the signal to be removed from BYPASS is GOOD, within its DEVIATION Band and ready to be placed in service.

S, NAVIGATE to the S/G FW INPUTS screen on the affected FW Train and SELECT the [8YP] Button on the WR level section of the screen.

C.

On the Overlay, SELECT [BYPASS] for the WR level signal (L9012 or L9022).

D.

VERIFY the [BYPASS] Button on the Overlay has changed from a White background to a Gray background.

E.

CLOSE the Overlay and VERIFY the following:

1.

The input signal SELECTED in 6.7.4.C indicates it has been Removed from BYPASS by its [BYP]

Button changing from Black letters on a White background to Black letters on a Gray background and the letter (M) placed next to it removed.

2.

The digital and graphical indicators for WR level on the S/G FW INPUTS and the S/G FW OVERVIEW screen indicate GOOD (Green & White).

41

-~------~------

(

REVISION NO PROCEDURE TITLE PAGE' 8A DISTRIBUTED CONTROL SYSTEM (DCS) -

20 of 81 PROCEDURE NO OPERATIONS 2-NOP-10201 ST. LUCIE UNIT 2 6.7 DCS Input Signal Removal/Restoration - FWCS (continued)

INITIAL

3.

C.

5.

(continued)

b.

An Info Tag appears on the S/G FW INPUTS screen above the WR level digital indicator that reads HOLDING LAST GOOD VALUE RESET REQUIRED.

c.

The digital and graphical Indicators for WR level on the S/G FW INPUTS and the S/G FW OVERVIEW screen indicate POOR (Black & Cyan)

d.

The digital and graphical indicators for SG NR level Validated Output on the S/G FW INPUTS and S/G FW OVERVIEW screens indicate POOR (Black & Cyan)

6.

RETURN FPD(s) to the default screen of S/G FW OVERVIEW or as directed by the US/SM

(

4.

Restoring WR level input signal from LOW POWER or HIGH POWER Mode A.

VERIFY from I&C or Engineering that the signal to be removed from BYPASS is GOOD, within its DEVIATION Band and ready to be placed in service

--~

S, NAVIGATE to the S/G FW INPUTS screen on the affected FW Train and SELECT the [8YPl Button on the WR level section of the screen C.

On the Overlay, SELECT [BYPASS] for the WR level signal (L9012 or L9022).

D.

VERIFY the [BYPASS] Button on the Overlay has changed from a White background to a Gray background.

E.

CLOSE the Overlay and VERIFY the following

1.

The input Signal SELECTED in 6.7.4 C indicates it has been Removed from BYPASS by its [BYP]

Button changing from Black letters on a White background to Black letters on a Gray background and the letter (M) placed next to It removed

2.

The digital and graphical Indicators for WR level on the S/G FW INPUTS and the S/G FW OVERVIEW screen indicate GOOD (Green & White) 41

(

REVISION NO PROCEDURE TITLE PAGE 8A DISTRIBUTED CONTROL SYSTEM (DCS).

OPERATIONS ST. LUCIE UNIT 2 21 of 81 PROCEDURE NO 2*NOp*102.01 6.7 DCS Input Signal Removal I Restoration - FWCS (continued)

4.

(continued)

NOTE An Info Tag 2A (2B) FW REG SYS IN MANUAL will appear with any FW MIA Station in Manual F.

From either the T*800s or the DCS FPD. PERFORM the following

1.

PLACE the LOW POWER MIA ST ATION of the affected FW Train in Manual

2.

ENSURE the HIGH POWER MIA STATION of the affected FW Train is in Manual G.

From the SIG FW INPUTS screen, PERFORM the following.

1.

SELECT the [RESET] Button in the WR level section of the screen to bring up the RESET Overlay for the WR level input.

2.

SELECT [RESET] for the WR level Input signal

3.

VERIFY the HOLDING LAST GOOD VALUE RESET REQUIRED Info Tag is removed.

4.

The digital and graphical Indicators for NR level Validated Output indicators on both the SIG FW INPUTS and SIG FW OVERVIEW screens indicate GOOD (Green & White).

H.

CLOSE the RESET Overlay NOTE INITIAL The Info Tag 2A (2B) FW REG SYS IN MANUAL will be removed after Both MIA Stations are returned to Auto.

I.

From either the T*800s or the DCS FPD, PERFORM the following

1.

PLACE the LOW POWER MIA Station of the affected FW Train In Automatic.

2.

Ensure the HIGH POWER MIA Station of the affected FW Train IS in its required mode of control for current plant conditions.

42

(

REVISION NO PROCEDURE TITLE PAGE 8A DISTRIBUTED CONTROL SYSTEM (DCS).

OPERATIONS ST. LUCIE UNIT 2 21 of 81 PROCEDURE NO 2*NOp*102.01 6.7 DCS Input Signal Removal I Restoration - FWCS (continued)

4.

(continued)

NOTE An Info Tag 2A (2B) FW REG SYS IN MANUAL will appear with any FW MIA Station in Manual F.

From either the T*800s or the DCS FPD, PERFORM the following

1.

PLACE the LOW POWER MIA STATION of the affected FW Train in Manual

2.

ENSURE the HIGH POWER MIA STATION of the affected FW Train is in Manual.

G.

From the SIG FW INPUTS screen, PERFORM the following

1.

SELECT the [RESET] Button in the WR level section of the screen to bring up the RESET Overlay for the WR level input.

2.

SELECT [RESET] for the WR level mput signal

3.

VERIFY the HOLDING LAST GOOD VALUE RESET REQUIRED Info Tag is removed.

4.

The digital and graphical Indicators for NR level Validated Output indicators on both the SIG FW INPUTS and SIG FW OVERVIEW screens indicate GOOD (Green & White)

H.

CLOSE the RESET Overlay.

NOTE INITIAL The Info Tag 2A (2B) FW REG SYS IN MANUAL will be removed after Both MIA Stations are returned to Auto.

I.

From either the T*800s or the DCS FPD, PERFORM the following

1.

PLACE the LOW POWER MIA Station of the affected FW Train m Automatic.

2.

Ensure the HIGH POWER MIA Station of the affected FW Train IS in ItS required mode of control for current plant conditions.

42

REVISION NO PROCEDURE TITLE:

PAGE:

8A DISTRIBUTED CONTROL SYSTEM (DCS) -

OPERATIONS 22 of 81 PROCEDURE NO 2-NOp-102.01 ST. LUCIE UNIT 2 6.7 DCS Input Signal Removal I Restoration - FWCS (continued)

4.

(continued)

J.

VERIFY Automatic SG level control has been restored to the affected FW Train.

K.

RETURN FPD(s) to the default screen of S/G FW OVERVIEW or as directed by the US/SM.

5.

BYPASSING a FWCS Feedwater Flow input signal (A Side:

F9011, F0903A2, F0903A3; B Side F9021, F0903B2, F0903B3):

CAUTION I

The Feedwater Flow signals are Critical System Signals when in the High Power Mode of operation (see Appendix C).

INITIAL I

If 2 or more of the 3 input signals have been determined to be

'unavailable' for any reason, the FWCS will revert to Single Element control from 3 Element control (if in the High Power Mode). This condition is confirmed by the Feedwater Flow Validated Output value indicating BAD (Blue & White) and a 'Reset Required' Info Tag appearing next to the Feedwater Flow signals on the INPUTS screen.

The High Power Mode Info Tag on the FW Overview screen will still Indicate High Power Mode because the Feedwater flow signal is holding a Last-Good*Value NOTE Feedwater Flow input signals use a Median Select scheme in determining a single Validated Output. The DEVIATION Band limit among the redundant signals is 7.5% of full flow or ~ 445 klbm/hr.

Although a Median Select scheme can operate with no degradation with a single unavailable signal, ALL 3 inputs must be GOOD following 2 or more becoming unavailable before a [RESET] (and a return to 3-Element control) can occur.

BYPASSING a signal in the 3-signal Feedwater Flow inputs would result in either a color change in the Validated Output to POOR if the other 2 input signals are GOOD, in service and within DEVIATION of each other or a swap to Single Element control if in High Power Mode and 1 signal has already been established as being 'unavailable' after BYPASSING one of the remaining 2.

A.

NAVIGATE to the S/G FW INPUTS screen on the affected FPD and SELECT any [BYP] Button on the Feedwater Flow section of the screen.

43

(

REVISION NO SA PROCEDURE NO PROCEDURE TITLE:

DISTRIBUTED CONTROL SYSTEM (DCS) -

OPERATIONS PAGE 220f81 2-NOP-102.01 S1. LUCIE UNIT 2 6.7 DCS Input Signal Removal I Restoration - FWCS (continued)

4.

(continued)

J.

VERIFY Automatic SG level control has been restored to the affected FW Train.

K.

RETURN FPD(s) to the default screen of S/G FW OVERVIEW or as directed by the US/SM.

5.

BYPASSING a FWCS Feedwater Flow input signal (A Side:

F90 11, F0903A2, F0903A3; B Side F9021, F0903B2, F0903B3).

CAUTION The Feedwater Flow signals are Critical System Signals when in the High Power Mode of operation (see Appendix C).

If 2 or more of the 3 input signals have been determined to be

'unavailable' for any reason, the FWCS will revert to Single Element control from 3 Element control (if in the High Power Mode). This condition IS confirmed by the Feedwater Flow Validated Output value Indicating BAD (Blue & White) and a 'Reset Required' Info Tag appearing next to the Feedwater Flow signals on the INPUTS screen.

The High Power Mode Info Tag on the FW Overview screen will still Indicate High Power Mode because the Feedwater flow signal is holding a Last-Good-Value NOTE Feedwater Flow Input signals use a Median Select scheme in determining a single Validated Output. The DEVIATION Band limit among the redundant signals is 7.5% of full flow or - 445 klbm/hr.

Although a Median Select scheme can operate with no degradation with a single unavailable signal, ALL 3 inputs must be GOOD following 2 or more becoming unavailable before a [RESET] (and a return to 3-Element control) can occur.

BYPASSING a signal in the 3-slgnal Feedwater Flow inputs would result In either a color change In the Validated Output to POOR if the other 2 Input signals are GOOD, in service and within DEVIATION of each other or a swap to Single Element control if in High Power Mode and 1 signal has already been established as being 'unavailable' after BYPASSING one of the remaining 2 A.

NAVIGATE to the S/G FW INPUTS screen on the affected FPD and SELECT any [BYP] Button on the Feedwater Flow section of the screen.

43

REVISION NO PROCEDURE TITLE PAGE:

59 of 81 8A DISTRIBUTED CONTROL SYSTEM (DCS) -

PROCEDURE NO OPERATIONS 2-NOP-102.01 ST. LUCIE UNIT 2 6.9 DCS Input SHARED Signal Removal I Restoration - SBCS + FWCS (continued)

3.

(continued)

H.

RETURN FPD(s) to the default screens of FW OVERVIEW or as directed by the US/SM.

4.

Restoring Main Steam Header Pressure (P0802) from FW 2A, 2B, or SBCS:

A.

VERIFY from I&C or Engineering that the signal to be removed from BYPASS is GOOD and ready to be returned to operation.

B.

NAVIGATE to the A or B FWCS S/G INPUTS or SBCS OVERVIEW screens and PERFORM the following:

1.

Select the [BYP] Button on P0802, Main Steam Header Pressure indication.

2.

On the Overlay, SELECT [BYPASS] for P0802, Main Steam Header Pressure.

3.

VERIFY the [BYPASS] Button on the Overlay has changed from a White background to a Gray background.

4.

SELECT the [RESET] Button on the P0802 Overlay and VERIFY the Info Tag HOLDING LAST GOOD VALUE RESET REQUIRED is removed from Both FWCS S/G INPUTS and SBCS INPUTS screens.

5.

CLOSE the Overlay and VERIFY the following:

a.

P0802 indicates it has been Removed from BYPASS by its [BYP] Buttons changing from a White background to a Gray background on Both FW INPUTS and SBCS INPUTS screens and the letter (M) next to the [BYP]

Buttons are removed.

b.

The digital and graphical indicators for P0802 on Both FWCS S/G INPUTS and SBCS INPUTS screens indicate GOOD (Green &

White).

6.

RETURN FPD(s) to the default screens of FW OVERVIEW or as determined by the US/SM.

END OF SECTION 6.9 44 INITIAL c

(

REVISION NO PROCEDURE TITLE PAGE 8A DISTRIBUTED CONTROL SYSTEM (DCS) -

PROCEDURE NO OPERATIONS 59 of 81 2-NOP-10201 ST. LUCIE UNIT 2 6.9 DCS Input SHARED Signal Removal/Restoration - SBCS + FWCS (continued)

3.

(continued)

H.

RETURN FPD(s) to the default screens of FW OVERVIEW or as directed by the US/SM.

4.

Restoring Main Steam Header Pressure (P0802) from FW 2A, 2B, or SBCS:

A.

VERIFY from I&C or Engineering that the signal to be removed from BYPASS is GOOD and ready to be returned to ope ration.

B.

NAVIGATE to the A or B FWCS S/G INPUTS or SBCS OVERVIEW screens and PERFORM the following:

1, Select the [BYP] Button on P0802, Main Steam Header Pressure indication.

2.

On the Overlay, SELECT [BYPASS] for P0802, Main Steam Header Pressure.

3.

VERIFY the [BYPASS] Button on the Overlay has changed from a White background to a Gray backg round.

4.

SELECT the [RESET] Button on the P0802 Overlay and VERIFY the Info Tag HOLDING LAST GOOD VALUE RESET REQUIRED is removed from Both FWCS S/G INPUTS and SBCS INPUTS screens.

5.

CLOSE the Overlay and VERIFY the following

a.

P0802 indicates it has been Removed from BYPASS by its [BYP] Buttons changing from a White background to a Gray background on Both FW INPUTS and SBCS INPUTS screens and the letter (M) next to the [BYP]

Buttons are removed.

b.

The digital and graphical indicators for P0802 on Both FWCS S/G INPUTS and SBCS INPUTS screens indicate GOOD (Green &

White).

6.

RETURN FPD(s) to the default screens of FW OVERVIEW or as determined by the US/SM END OF SECTION 6.9 44 INITIAL

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

5 Event #

_6~,._7____ Page l2...- of _1;..;;..9-----i1 I Event

Description:

I:

LOOP / Loss of Feedwater, 26 Diesel does not start. 2A Diesel output breaker does not close.

il..

l Time II Position II Applicant's Actions or Behavior I Booth Operator Instructions: When directed by examiner, trigger LOOP! Loss of I

Feedwater, 2B EDG should not auto start and 2A i

output breaker does not close.

~dications Available:

I When SNPO called by Control Room Local 2B EDG alarms in are:

i 6-1: 2B EDG TRIP/LOCKOUT

6-2: START DC FAILURE/ SS ISOL

If asked, one minute later state, lockout unable to be reset.

~--.

I SRB06~OI Multiple alarms, recognize Reactor ITurbine trip

~

I Directs implementation of 2-EOP-01, "Standard Post Trip i

Actions" as follows:

I I

I

RO: Reactivity control, Inventory Control, Pressure i

SRO i

control, Core Heat Removal i

BOP: Vital Auxiliaries, RCS heat removal, Containment i

Conditions.(2B EDG does not auto start)

I I

Recognizes that the 2B EDG did not start and that 2B EDG has i

alarm A-26, 2B Emerg DIG Lockout/SS Isol.

r------.

I Critical i

Recognizes that 2A EDG breaker did not close.

I Task I

SRO Directs BOP to close the 2A EDG breaker.

1-.. __.

I Recognizes that the 2B EDG did not start and that 2B EDG has i

BOP alarm A-26, 2B Emerg DIG Lockout/SS Isol.

L Critical Recognizes that 2A EDG breaker did not close.

i Task I

BOP Close the 2A EDG breaker when directed.

~

I r---**------

i i

i

.~

45

(

Appendix D Operator Action Form ES-D-2 Op Test No.

1 Scenario #

5 Event #

_6;;.;. *...;..7 ____ Page _10_ of

_1;..;.9~1 I Event

Description:

LOOP I Loss of Feedwater, 2B Diesel does not start 2A Diesel output breaker does not close.

Tim~1 Position II Applicant's Actions or Behavior I Booth Operator Instructions: When directed by examiner, trigger LOOP / Loss of I

Feedwater, 2B EDG should not auto start and 2A output breaker does not close.

I

~dications Available:

! When SNPO called by Control Room Local 2B EDG alarms in are:

I 6-1: 2B EDG TRIP/LOCKOUT 6-2: START DC FAILURE/ SS ISOL

If asked, one minute later state, lockout unable to be reset.

I--~~~"--

I SRO/ROI Multiple alarms, recognize Reactor ITurbine trip I

BOP i r L

i I

Directs implementation of 2-EOP-01, "Standard Post Trip i

Actions" as follows:

I,,

RO: Reactivity control, Inventory Control, Pressure i

SRO control, Core Heat Removal BOP: Vital Auxiliaries, RCS heat removal, Containment I I Conditions. 2B EDG does not auto start

~------+-----------I~~~~---------1 i

I Recognizes that the 2B EDG did not start and that 2B EDG has

~ ____ + ___ +-a_la_r_m_A_-_2_6_, _2_B_E_m_e_r_g_D_I_G_L_o_c_k_o_u_VS_S_I_so_I_. ---------1 I Critical I

Task Recognizes that 2A EDG breaker did not close.

SRO Directs BOP to close the 2A EDG breaker.

=~=-~---~~T-----------+i-I =R=e=c=0=g=n=iz=e=s=t-h-a=t=t=h=e=2=B==E=D=G==d-i-d=n=0=t=s=ta=rt==a=n=d=t=ha=t=2=B==E=D=G==h=a:s BOP alarm A-26, 2B Emerg DIG LockouUSS Isol.

i I

r--__

.~

Critical Recognizes that 2A EDG breaker did not close.

Task i

I BOP Close the 2A EDG breaker when directed.

~-

- ~

-~---- _.. _----

I

_______ "'-------1---

45

Appendix D r

Op Test No Event

Description:

Operator Action Form ES-D-2 Scenario #

5 Event #

_6;.:....;..7 ____ Page _11_ of ~19~-l1 LOOP I Loss of Feedwater, 2B Diesel does not start. 2A Diesel output breaker does not close.

Time II Position II Applicant's Actions or Behavior LSooth Operator Instructions:

I Indications Available:

~

I i

RO I

,-- ----- --------t-r----. '~'----

~

r I

I 1-----

I I

i :

i I

. r

[-

i I

i I-I I-..*... --------r BOP Performs EOP-01 Safety Functions as directed for Reactivity Control, Inventory Control, Pressure Control, Core Heat removal Reactivity Control

Verify Reactor power is lowering.

Verify startup rate is negative.

Verify a maximum of one CEA is not fully inserted.

Inventory Control Verify Pressurizer level is between 10 and 68%

Pressurizer level is trending to 30 - 35%

Pressure Control

Verify RCS pressure is between 1800-2300 psia Verify RCS pressure is trending 2225-2275 psia Verify RCS subcooling is >20 0 F Core Heat Removal

Verify at least one RCP running with CCW. (LOOP, no RCP's running)

Verify loop delta T is <10° F Verifies turbine trip on reactor trip. Performs EOP-01 Safety functions as directed for: Vital Auxiliaries, RCS Heat Removal, Containment Conditions 46 I

I

(

Appendix D Operator Action Form ES-D-2 r

Op Test No.

Scenario #

5 Event #

6, 7 Page _11_ of

....;..;19~-I1 Event Description lOOP / Loss of Feedwater, 28 Diesel does not start. 2A Diesel output breaker does not close.

Position A

licant's Actions or Behavior Booth Operator Instructions:

i Indications Available:

I r-*-._-

.-----+---

~ -----

I I

i I

I I

r I

Performs EOP-01 Safety Functions as directed for Reactivity RO I Control, Inventory Control, Pressure Control, Core Heat I

BOP removal Reactivity Control Verify Reactor power is lowering, Verify startup rate is negative.

Verify a maximum of one CEA is not fully inserted.

Inventory Control Verify Pressurizer level is between 10 and 68%

Pressurizer level is trending to 30 - 35%

Pressure Control Verify RCS pressure is between 1800-2300 psi a Verify RCS pressure is trending 2225-2275 psia Verify RCS subcooling is >20 0 F Core Heat Removal Verify at least one RCP running with CCW, (LOOP, no RCP's running)

Verify loop delta T is <10 0 F Verifies turbine trip on reactor trip. Performs EOP-01 Safety functions as directed for: Vital Auxiliaries, RCS Heat Removal, Containment Conditions I

i I

I L__ ~~~~~~~~

________________________________________________ ~

46

Appendix D Op Test No.:

Event

Description:

il Operator Action Form ES-D-2 Scenario #

5 Event #

_6~'..;.7 ____ Page 1L-of...;.,;19:-""'1 LOOP I Loss of Feedwater, 2B Diesel does not start. 2A Diesel output breaker does not close.

Time II Position II Applicant's Actions or Behavior l~_ooth Operator Instructions:

i,lndications Available:

I BOP Ensures MSR Warmup Valves are CLOSED. Calls NPO to L-manually close due to loss of power.

~

Notifies NPO to perform Appendix X section 1 of EOP-99.

(outside CR actions) (attached page_ 48-51_)

~.

Maintenance of Vital Auxiliaries I

Verifies turbine governor and throttle valves closed Verify GEN Brk open (East breaker, Mid Breaker and i

Exciter Breaker)

I I

Verify all vital and non vital AC Buses energized.

(closes 2A EDG output breaker)

All vital and non vital DC Buses energized.

I,

~.

I RCS Heat Removal Verify at least one S/G has feedwater available.

Verify RCS T-avg is between 525 and 535°F by:

Places one ADV on 'A' side and one ADV on 'B' side in i

'Auto' / 'Auto'

~,

Containment Conditions Verify Containment pressure <2 psig.

Verify NO Containment radiation monitors in alarm.

Verify Containment temperature is less than 120°F.

i Verify NO secondary plant radiation alarms.

47

(

Appendix D I 0, TeetNo i Event

Description:

I Position Operator Action Form ES-D-2 Scenario #

5 Event #

6, 7 Page _12_ of _19_-{1 LOOP / Loss of Feedwater, 2B Diesel does not start. 2A Diesel output breaker does not close.

A plicant's Actions or Behavior L~ooth Operator Instructions:

Indications Available:

f-,

i,-

~-.--.

i I

I I I I

I I

I,

i !

i I

I I i I

~

l_

BOP I

I i

Ensures MSR Warmup Valves are CLOSED. Calls NPO to manually close due to loss of power.

Notifies NPO to perform Appendix X section 1 of EOP-99.

(outside CR actions) (attached page_ 48-51_)

Maintenance of Vital Auxiliaries Verifies turbine governor and throttle valves closed Verify GEN Brk open (East breaker, Mid Breaker and Exciter Breaker)

Verify all vital and non vital AC Buses energized.

(closes 2A EDG output breaker)

All vital and non vital DC Buses energized.

RCS Heat Removal Verify at least one S/G has feedwater available.

Verify RCS T-avg is between 525 and 535°F by:

Places one ADV on 'A' side and one ADV on 'B' side in

'Auto' / 'Auto' Containment Conditions Verify Containment pressure <2 psig.

Verify NO Containment radiation monitors in alarm.

Verify Containment temperature is less than 120°F.

Verify NO secondary plant radiation alarms.

47 I

REVISION NO PROCEDURE TITLE:

PAGE:

36A PROCEDURE NO.

2-EOP-99 APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 1 of 8)

NOTE This appendix contains two sections. Each section has instructions for stabilization of the secondary plant following a unit trip.

Section 1 provides the field instructions that are performed in the Turbine Generator Building during execution of 2-EOP-01 111 of 156 Section 2 provides the control room instructions that are performed after 2-EOP-01 has been exited Section 1: FIELD ACTIONS INSTRUCTIONS o 1. CONFIRM Turbine trip with the Control Room.

o 2. PERFORM ALL of the following from the Turbine Deck:

o A. VERIFY ALL Main Steam Safety Valves are CLOSED.

CONTINGENCY ACTIONS o A.1 !f ANY Main Steam Safety Valves are OPEN, Then immediately NOTIFY the Control Room.

o B. VERIFY ALL of the following 0 B.1 !f ANY Turbine Valves are NOT Turbine valves are CLOSED:

fully CLOSED, Then loca"y TRIP the Turbine.

o Governor Valves o Throttle Valves o Intercept Valves o Reheat Valves 48

(

REVISION NO..

PROCEDURE TITLE PAGE:

36A PROCEDURE NO 2-EOP-99 APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 1 of 8)

NOTE This appendix contains two sections. Each section has instructions for stabilization of the secondary plant following a unit trip.

Section 1 provides the field instructions that are performed in the Turbine Generator Building during execution of 2-EOP-01 111 of 156 Section 2 provides the control room instructions that are performed after 2-EOP-01 has been exited Section 1: FIELD ACTIONS INSTRUCTIONS o 1. CONFIRM Turbine trip with the Control Room.

o 2. PERFORM ALL of the following from the Turbine Deck:

o A. VERIFY ALL Main Steam Safety Valves are CLOSED.

o B. VERIFY ALL of the following Turbine valves are CLOSED:

o Governor Valves o Throttle Valves o Intercept Valves o Reheat Valves 48 CONTINGENCY ACTIONS o A.1 If ANY Main Steam Safety Valves are OPEN, Then immediately NOTIFY the Control Room.

o B.1 If ANY Turbine Valves are NOT fully CLOSED, Then locally TRIP the Turbine.

REVISION NO.:

36A PROCEDURE NO.:

2-EOP-99 PROCEDURE TITLE:

APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 2 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE:

112 of 156 INSTRUCTIONS CONTINGENCY ACTIONS II NOTE

~

II The remainder of the steps in this section may be performed in any order.

II o 3. PERFORM ALL of the following from the Ground Floor Level:

o A. ADJUST FCV-12-1, Condensate Hdr Recirc to Cndsr, as required to maintain Condensate flow of 8,000 gpm.

o B. PERFORM BOTH of the following to ALIGN cooling water to the Heater Drain Pumps, until water is flowing out the packing gland:

o THROTTLE OPEN V38238, DMW to 2A Htr Drain Pump Gland Quench Seallsol.

o THROTILE OPEN V38239, DMW to 2B Htr Drain Pump Gland Quench Seallsol.

o C. CLOSE V31190, Processed Bldn (Vacuum Drag) to 2B Cndsr 1501.

o D. OPEN SB13139, TCW Pumps Disch Cross-Tie. 1501.

49

(

--~----

--~---

REVISION NO.

36A PROCEDURE NO.

2-EOP-99 PROCEDURE TITLE:

APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 2 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE:

112 of 156 INSTRUCTIONS CONTINGENCY ACTIONS I

I NOTE II The remainder of the steps in this section may be performed in any order.

II o 3. PERFORM ALL of the following from the Ground Floor Level:

o A. ADJUST FCV-12-1, Condensate Hdr Recirc to Cndsr, as required to maintain Condensate flow of 8,000 gpm.

o B. PERFORM BOTH of the following to ALIGN cooling water to the Heater Drain Pumps, until water is flowing out the packing gland:

o THROTTLE OPEN V38238, DMW to 2A Htr Drain Pump Gland Quench Seallsol.

o THROTTLE OPEN V38239, DMW to 2B Htr Drain Pump Gland Quench Seallsol.

o C. CLOSE V31190, Processed Bldn (Vacuum Drag) to 2B Cndsr Isol.

o D. OPEN SB13139, TCW Pumps Disch Cross-Tie. Isol.

49

REVISION NO.:

36A PROCEDURE NO.:

2-EOP-99 PROCEDURE TITLE:

APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 3 of 8)

PAGE:

113 of 156 Section 1: FIELD ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS o 4. PERFORM BOTH of the following from on top of the TLO Reservoir:

o A. VERIFY ONE of the following:

o 1. Bearing Oil Pump and Seal Oil Backup Pump RUNNING.

o 2. Emergency Oil Pump RUNNING.

o B. VERIFY Bearing Oil Lift Pump RUNNING.

o 5. PERFORM ALL of the following from the Mezzanine Deck:

o A. THROTTLE OPEN V09218, S/G Fillisol, 15 to 20 turns.

o B. THROTTLE OPEN BOTH of the following valves to establish EACH Hood Spray between 200 and 250 psig:

o V12396, 2A LP Turb Spray Hdr TCV-22-61A Bypass o V12403, 2B LP Turb Spray Hdr TCV-22-61 B Bypass (continued on next page) 50

(

REVISION NO.

36A PROCEDURE NO..

2-EOP-99 PROCEDURE TITLE:

APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 3 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE:

113 of 156 INSTRUCTIONS CONTINGENCY ACTIONS o 4. PERFORM BOTH of the following from on top of the TLO Reservoir:

o A. VERIFY ONE of the following:

o 1. Bearing Oil Pump and Seal Oil Backup Pump RUNNING.

o 2. Emergency Oil Pump RUNNING.

o B. VERIFY Bearing Oil Lift Pump RUNNING.

o 5. PERFORM ALL of the following from the Mezzanine Deck:

o A. THROTTLE OPEN V09218, S/G Filiisol, 15 to 20 turns.

o B. THROTTLE OPEN BOTH of the following valves to establish EACH Hood Spray between 200 and 250 psig:

o V12396, 2A LP Turb Spray Hdr TCV-22-61 A Bypass o V12403, 2B LP Turb Spray Hdr TCV-22-61 B Bypass (continued on next page) 50

REVISION NO.:

36A PROCEDURE NO:

2-EOP-99 PROCEDURE TITLE:

APPENDICES / FIGURES / TA8LES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 4 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE:

114 of 156 INSTRUCTIONS CONTINGENCY ACTIONS

5. (continued)

C.

VERIFY ALL of the following valves CLOSED:

0 SC-10-3A, 3A LP Htr Extr Stm Non Return 0 SC-10-38, 38 LP Htr Extr Stm Non Return 0 SC-10-4A, 4A LP Htr Extr Stm Non Return 0 SC-10-48, 48 LP Htr Extr Stm Non Return 0 SC-10-5A, 5A HP Htr Extr Stm Non Return o SC-10-58, 58 HP Htr Extr Stm Non Return o 6. From the Turbine Deck, VERIFY the Turning Gear is ready for operation.

o 7. When Section 1 Field Actions are

COMPLETE, Then NOTIFY the Control Room.

End of Section 1 51

/

\\

REVISION NO..

36A PROCEDURE NO.

2-EOP-99 PROCEDURE TITLE:

APPENDICES! FIGURES ! TABLES ! DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 4 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE:

114 of 156 INSTRUCTIONS CONTINGENCY ACTIONS

5. (continued)

C.

VERIFY ALL of the following valves CLOSED:

0 SC-10-3A, 3A LP Htr Extr Stm Non Return 0 SC-10-3B, 3B LP Htr Extr Stm Non Return 0 SC-10-4A, 4A LP Htr Extr Stm Non Return 0 SC-10-4B, 4B LP Htr Extr Stm Non Return 0 SC-10-SA, SA H P Htr Extr Stm Non Return o SC-10-5B, 5B HP Htr Extr Stm Non Return o 6. From the Turbine Deck, VERIFY the Turning Gear is ready for operation.

o 7. When Section 1 Field Actions are

COMPLETE, Then NOTIFY the Control Room.

End of Section 1 51

Appendix D Op Test No.:

Event

Description:

Operator Action Form ES-D-2 1

Scenario #

5 Event #

_8;.:.,..;.9 ____ Page.11.- of

_1~9--11 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator Time II Position II Applicant's Actions or Behavior Booth Operator Instructions: Trigger Restore Instrument Air when contacted by Control Room Indications Available:

SRO Performs Diagnostic Flow Chart I

I Exits EOP-01 to EOP-09, LOOP Directs STA SFSC's for EOP-09 performed every 15 minutes.

Directs HP to perform secondary surveys i--

Directs RCS depressurized to 1800 to 1850 psi a using I

auxiliary sprays. (key 76 and 77 to operate SE-02-3 and SE-02-4)

I I

Directs Ensure EDG Loading i

I I

Directs Appendix H, to restore Instrument Air, of EOP-99.

(attached page_53-56_)

~

i Directs, If Appendix H, 'Restore Instrument Air' not I

completed within 30 minutes of loss of CCW, ensure CCW I

NOT restored to RCP's.

f 0-

Examiners Note: If Instrument air is restored after 30 minutes with RCP CCW valves in

auto, the CCW valves will re-open, which is in violation of above step.

I Directs closing of MSIV's I

~-

I Directs closing of S/G blowdown and sample valves I

I 52

(

Appendix D Op Test No.:

Event

Description:

Operator Action Form ES-D-2 Scenario #

5 Event #

_8,;.:,..,;;9 ____ Page ~

of

...;.;19~""1 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator Time II Position II Applicant's Actions or Behavior I Booth Operator Instructions: Trigger Restore Instrument Air when contacted by Control I

Room I

I Indications Available:

SRO Performs Diagnostic Flow Chart I

I Exits EOP-01 to EOP-09, LOOP i

I I

Directs STA SFSC's for EOP-09 performed every 15 minutes.

I Directs HP to perform secondary surveys I~-* -

~

Directs RCS depressurized to 1800 to 1850 psi a using i

auxiliary sprays. (key 76 and 77 to operate SE-02-3 and SE-02-4 l

~-

I i

I Directs Ensure EDG Loading I

I Directs Appendix H, to restore Instrument Air, of EOP-99.

i i

(attached page_53-56_l I

i I

i i

Directs, If Appendix H, 'Restore Instrument Air' not I

completed within 30 minutes of loss of CCW, ensure CCW I

I NOT restored to RCP's.

r i

, Examiners Note: If Instrument air is restored after 30 minutes with RCP CCW valves in

. auto, the CCW valves will re-open, which is in violation of above step.

i r--

Directs closing of MSIV's I

I-I Directs closing of S/G blowdown and sample valves I

I I

L 52

REVISION NO PROCEDURE TITLE:

PAGE' 36A APPENDICES I FIGURES I TABLES I DATA 57 of 156 PROCEDURE NO SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX H OPERATION OF THE 2A AND 26 INSTRUMENT AIR COMPRESSORS (Page 1 of 4)

Section 1: Placing 2A Instrument Air Compressor in Service o 1. ENSURE the following breakers are aligned as indicated.

Component 10 Component Name POSITION (,J)

Bkr 41331 (MCC 2A6)

Instr Air Compr 2A ON Bkr 42414 (MCC 2AB)

Instrument Air Compressor Cooler Fan ON Bkr 42416 (MCC 2AB)

Cooling System Water PP ON o 2. 11 TCW is NOT available, Then PERFORM the following:

0 A. ALIGN 2A Instrument Air Compressor for emergency cooling and operation Component ID Component Name POSITION (,J)

V 13197 2A Instr Air Comp Jacket Inlet 1501 OPEN V13201 2A Instr Air Comp Jacket Outlet 1501 OPEN V13383 Air Comprs Outlet Hdr 1501 CLOSE f-V13380 Air Comprs Inlet Hdr 1501 CLOSE V13417 Air Compr Coolers Inlet Hdr from Recire Pump 1501 OPEN V13420 Air Compr Coolers to Fan Cooler 1501 OPEN V13424 2A Recire Pump from 1 to 2A Expan Tank Isol OPEN V13419 Air Compr Coolers to Fan Cooler 1501 OPEN V13418 2A Recirc Pump Diseh 1501 OPEN I

V18109 Instr Air Revr Inlet from 2A Af\\ercooler 1501 OPEN V18660 2C 1 2D Instr Air Comps Disch 1501 CLOSE 0 6. ENSURE the Instrument Air Compressor Head Tank level is at least 3/4 full.

o C. START the Emergency Cooling System Recirculation Pump.

o D. START the Emergency Cooling System Radiator Fan.

7 53

(

REVISION NO PROCEDURE TITLE PAGE 36A APPENDICES I FIGURES I TABLES I DATA 57 of 156 PROCEDURE NO SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX H OPERA TION OF THE 2A AND 26 INSTRUMENT AIR COMPRESSORS (Page 1 of 4)

Section 1: Placing 2A Instrument Air Compressor in Service o 1. ENSURE the following breakers are aligned as indicated.

Component 10 Component Name POSITION c,j)

Bkr 41331 (MCC 2A6)

Instr Air Compr 2A ON Bkr 42414 (MCC 2AB)

Instrument Air Compressor Cooler Fan ON Bkr 42416 (MCC 2AB)

Cooling System Water PP ON o 2. if TCW is NOT available, Then PERFORM the following 0 A. ALIGN 2A Instrument Air Compressor for emergency cooling and operation

(

Component 10 Component Name POSITION (...J)

V13197 I 2A Instr Air Comp Jacket Inlet Isol OPEN V13201 2A Instr Air Comp Jacket Outlet Isol OPEN -

V13383 Air Comprs Outlet Hdr Isol CLOSE -

f-V13380 Air Comprs Inlet Hdr Isol CLOSE -

I V13417 Air Compr Coolers Inlet Hdr from Recirc Pump Isol OPEN V13420 Air Compr Coolers to Fan Cooler Isol OPEN V13424 2A Recirc Pump from / to 2A Expan Tank Isol OPEN V13419 Air Compr Coolers to Fan Cooler Isol OPEN V13418 2A Recirc Pump Disch Isol OPEN V18109 instr Air Rcvr Inlet from 2A Aftercooler Isol OPEN

~~_8660_,

2C / 2D Instr Air Comps Disch Isol CLOSE 0 6. ENSURE the Instrument Air Compressor Head Tank level is at least 3/4 full.

0 C. START the Emergency Cooling System Recirculation Pump 0 D. START the Emergency Cooling System Radiator Fan.

7 53

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX H PAGE' 58 of 156 OPERATION OF THE 2A AND 28 INSTRUMENT AIR COMPRESSORS (Page 2 of 4)

Section 1: Placing 2A Instrument Air Compressor in Service (continued) o 3. If TCW is available, Then ALIGN 2A Instrument Air Compressor for normal cooling and operation:

Component 10 Component Name POSITION (..J)

V13197 2A Inslr Air Comp Jacket Inlet 1501 OPEN V13201 2A Instr Air Comp Jacket Outlet 1501 OPEN V18109 Inslr Air Rcvr Inlel from 2A Aftercooler 1501 OPEN CLOSE V18660 2C / 2D Inslr Air Comps Disch Isol

__________ L-____

~

=

~

o 4. NOTIFY Unit 2 Control Room to RESET the 2A Instrument Air Compressor on the plant auxiliaries panel.

o 5. Locally START the 2A Instrument Air Compressor, o 6. NOTIFY Unit 2 Control Room that 2A Instrument Air Compressor is running, End of Section 1 54 REVISION NO 36A PROCEouRE NO 2-EOP-99 PROCEDURE TITLE APPENDICES / FIGURES / TABLES / DATA SHEETS ST, LUCIE UNIT 2 APPENDIX H PAGE 58 of 156 OPERATION OF THE 2A AND 28 INSTRUMENT AIR COMPRESSORS (Page 2 of 4)

Section 1: Placing 2A Instrument Air Compressor in Service (continued) o 3. !f TCW IS available, Then ALIGN 2A Instrument Air Compressor for normal cooling and operation

!component ID Component Name POSITION (..J)

I V13197 2A Instr Air Camp Jacket Inlet 1501 OPEN V13201 2A Instr Air Camp Jacket Outlet 1501 OPEN I

V18109 Instr Air Rcvr Inlet from 2A Aftercooler 1501 OPEN I

2C / 20 Instr Air Camps Disch Isol

~

-L-___

__==__!

CLOSE Y18660 o 4. NOTIFY Unit 2 Control Room to RESET the 2A Instrument Air Compressor on the plant auxiliaries panel.

o 5. Locally START the 2A Instrument Air Compressor, o 6, NOTIFY Unit 2 Control Room that 2A Instrument Air Compressor IS running, End of Section 1 54

REVISION NO PROCEOURE TITLE PAGE:

36A APPENDICES 1 FIGURES 1 TABLES 1 DATA 59 of 156 PROCEDURE NO SHEETS 2-EOP-99 ST, LUCIE UNIT 2 APPENDIX H OPERATION OF THE 2A AND 26 INSTRUMENT AIR COMPRESSORS (Page 3 of 4)

Section 2: Placing 26 Instrument Air Compressor in Service o 1. ENSURE the following breakers are aligned as indicated:

Component 10 Component Name POSITION (..J)

Bkr 42192 (MCC 2B6)

Instr Air Compr 2B ON Bkr 42414 (MCC 2AB)

Instrument Air Compressor Cooler Fan ON 6kr 42416 (MCC 2AB)

COOling System Water PP ON 0 2. If TCW is NOT available, Then PERFORM the following:

0 A. ALIGN 2B Instrument Air Compressor for emergency cooling and operation:

Component ID Component Name POSITION (..J)

L-V13209 26 Instr Air Comp Jacket Inlet Isol OPEN V13213 2B Instr Air Comp Jacket Outlet Isol OPEN V133B3 Air Comprs Outlet Hdr Isol CLOSE I

V133BO Air Comprs Inlet Hdr Isol CLOSE V13417 Air Compr Inlet Hdr from Recirc Pump 1501 OPEN V13420 Air Compr Coolers to Fan Cooler 1501 OPEN V13424 2A Recirc Pump from / to 2A Expan Tank Isol OPEN V13419 Air Compr Coolers to Fan Cooler Isol OPEN 1--

V13418 2A Recire Pump Disch Isol OPEN V18118 Instr Air Revr Inlet from 26 Aftereooler 1501 OPEN J----

V18660 I 2C / 20 Instr Air Comps D~~_:!:~:?I CLOSE 0 6. ENSURE the Instrument Air Compressor Head Tank level is at least 3/4 full, 0 C. START the Emergency Cooling System Recirculation Pump, 0 D. START the Emergency Cooling System Radiator Fan, 55 REVISION NO PROCEDURE TITLE PAGE 36A APPENDICES I FIGURES I TABLES I DATA 59 of 156 PROCE DURE NO SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX H OPERA TlON OF THE 2A AND 2B INSTRUMENT AIR COMPRESSORS (Page 3 of 4)

Section 2: Placing 28 Instrument Air Compressor in Service o 1. ENSURE the following breakers are aligned as indicated:

Component 10 Component Name POSITION ("-J)

Bkr 42192 (MCC 2B6)

Instr Air Compr 2B ON Bkr42414 (MCC 2AB)

Instrument Air Compressor Cooler Fan ON Bkr 42416 (MCC 2AB)

Cooling System Water PP ON 0 2. 11 TCW is NOT available, Then PERFORM the following 0

A. ALIGN 2B Instrument Air Compressor for emergency cooling and operation Component 10 Component Name POSITION ('-J)

L-V13209 2B Instr Air Camp Jacket Inlet Isol OPEN -

V13213 2B Instr Air Camp Jacket Outlet Isol OPEN V13383 Air Comprs Outlet Hdr 1501 CLOSE I

V13380 Air Comprs Inlet Hdr 1501 CLOSE I

V13417 Air Compr Inlet Hdr from Recirc Pump Isol OPEN V13420 Air Compr Coolers to Fan Cooler 1501 OPEN V13424 2A Recirc Pump from I to 2A Expan Tank Isol OPEN V13419 Air Compr Coolers to F an Cooler Isol OPEN I--~

V13418 2A Recirc Pump Disch 1so1 OPEN V18118

! Instr Air Rcvr Inlet from 2B Aftercooler Isol OPEN I

V18660

2C I 20 Instr Air Camps Disch 1501 CLOSE

.-.--~- --"--

0 8. ENSURE the Instrument Air Compressor Head Tank level is at least 3/4 full.

0 C. START the Emergency Cooling System Recirculation Pump.

0 D. START the Emergency Cooling System Radiator Fan.

55

REVISION NO PROCEDURE TITLE PAGE-36A PROCEDURE NO_

2-EOP-99 APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX H 60 of 156 OPERATION OF THE 2A AND 28 INSTRUMENT AIR COMPRESSORS (Page 4 of 4)

Section 2: Placing 28 Instrument Air Compressor in Service (continued) o 3. if TCW is available, Then ALIGN 2B Instrument Air Compressor for normal cooling and operation:

Component 10 Component Name POSITION (..J)

V13209 2B Instr Air Comp Jacket Inlet 1501 OPEN V13213 28 Instr Air Comp Jacket Outlet 1501 OPEN V18118 Instr Air Rcvr Inlet from 28 Aftercooler Isol OPEN I

V18660 2C I 2D Instr Air Comps Disch Isol CLOSE o 4. NOTIFY Unit 2 Control Room to RESET the 2B Instrument Air Compressor on the plant auxiliaries panel.

o 5. Locally START the 2B Instrument Air Compressor.

o 6. NOTIFY Unit 2 Control Room that 28 Instrument Air Compressor is running.

End of Section 2 END OF APPENDIX H 56 REVISION NO PROCEDURE TITLE PAGE 36A PROCEDURE NO APPENDICES I FIGURES I TABLES / DATA SHEETS 60 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX H OPERATION OF THE 2A AND 28 INSTRUMENT AIR COMPRESSORS (Page 4 of 4)

Section 2: Placing 2B Instrument Air Compressor in Service (continued) o 3. !.f TCW is available, Then ALIGN 2B Instrument Air Compressor for normal cooling and operation:

Component 10 Component Name POSITION (..J)

V13209 2B Instr Air Comp Jacket Inlet 1501 OPEN -

V13213 2B Instr Air Comp Jacket Outlet 1501 OPEN V18118 Instr Air Rcvr Inlet from 2B Aftercooler 1501 OPEN -

I V18660 2C I 2D Instr Air Camps Disch 1501 CLOSE o 4. NOTIFY Unit 2 Control Room to RESET the 2B Instrument Air Compressor on the plant auxiliaries panel.

o 5. Locally START the 2B Instrument Air Compressor o 6, NOTIFY Unit 2 Control Room that 2B Instrument Air Compressor is running.

End of Section 2 END OF APPENDIX H 56

Appendix D Op Test No.:

Event

Description:

Operator Action Form ES-D-2 1

Scenario #

5 Event #

_8:;.:"..;;,9 ____ Page ~

of _1.....

9--.,1 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator Time II Position II Applicant's Actions or Behavior l

Booth Operator Instructions: When contacted by Control Room perform 2-0NP-09.02, Auxiliary Feedwater Appendix C steps 1A thru 1 H as directed.

i Indications Available: Alarm: G-46, 2C AFW PUMP TURBINE I

FAILURE/Trip/OVRLD/SS ISOL r---

SRO Directs Stabilize RCS Temperature.

I Directs Ensure S/G Level 60 to 70%

I I

If AFAS NOT actuated, direct AFW restored by manual I

starting of pumps and opening of valves lAW 2-NOP-09.02 i

(attached page_58-66_)

i I

f-l

~

RCS depressurized to 1800 to 1850 psia using auxiliary sprays RO as directed.

I If Appendix H, 'Restore Instrument Air' not completed within 30 I

minutes of loss of CCW, ensures CCW is NOT restored to I

RCP's.

Stabilizes RCS Temperature as directed.

f------

I I--

Ensures S/G Level 60 to 70% as directed I I I

I Informs NPO to perform Appendix H, 2-EOP-99 restore BOP Instrument Air, as directed (attached page_53-56_)

i I

I I

Resets Instrument Air Compressors when notified by NPO i

I Aligns and initiates AFW flow to 2A and 2B SG lAW 2-NOP-09.02 (attached page 58-66_)

57 I

(

c_

(

Appendix D Op Test No.

Event

Description:

Operator Action Form ES-D-2 1

Scenario #

5 Event #

8, 9 Page _14_ of _19_-11 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 26 Steam Generator Time II Position JL Applicant's Actions or Behavior I Booth Operator Instructions: When contacted by Control Room perform 2-0NP-I 09.02, Auxiliary Feedwater Appendix C steps 1A thru 1 H as directed.

1-_____

Indications Available: Alarm: G-46, 2C AFW PUMP TURBINE FAILURE/Trip/OVRLO/SS ISOL I

!--~-

I SRO Directs Stabilize RCS Temperature.

[

i I

Directs Ensure S/G Level 60 to 70%

I I

i I

If AFAS NOT actuated, direct AFW restored by manual I

I I

starting of pumps and opening of valves lAW 2-NOP-09.02 I

i at ac e page_ -

( t h d 5866

-~.

l RO RCS depressurized to 1800 to 1850 psia using auxiliary sprays t

as directed.

~

I If Appendix H, 'Restore Instrument Air' not completed within 30 I

minutes of loss of CCW, ensures CCW is NOT restored to I

RCP's.

I I

~

Stabilizes RCS Temperature as directed.

I f---

I Ensures S/G Level 60 to 70% as directed I

I I

I Informs NPO to perform Appendix H, 2-EOP-99 restore I

BOP Instrument Air, as directed (attached page_53-56_)

L I

i I

Resets Instrument Air Compressors when notified by NPO f-----

I L

i Aligns and initiates AFW flow to 2A and 2B SG lAW 2-NOP-09.02 (attached page 58-66_)

57 I

REVISION NO PROCEDURE TITLE PAGE' 2A AUXILIARY FEEDWATER SYSTEM OPERATION 7 of 34 PROCEDURE NO 2-NOP-0902 ST, LUCIE UNIT 2 4,0 INSTRUCTIONS INITIAL 4.1 2A AFW PUMP to 2A S/G

1.

START PUMP 2A,

2.

OPEN SE-09-2, 2A PUMP DISCH TO 2A S/G VLV, (KEY 83) 3, THROTTLE MV-09-9, PUMP 2A DISCH TO SG 2A VALVE, as necessary to establish and maintain desired AFW flow to 2A S/G, 4,

WHEN desired level is achieved AND the 2A AFW PUMP is no longer needed, THEN PERFORM the following:

A.

CLOSE MV-09-9, PUMP 2A DISCH TO SG 2A VALVE, B.

PLACE key switch for SE-09-2, 2A PUMP DISCH TO 2A S/G VLV, to AUTO, IV C,

VERIFY SE-09-2, 2A PUMP DISCH TO 2A S/G VLV, is

CLOSED, D,

STOP PUMP 2A, E.

RETURN PUMP 2A switch to AUTO, IV Performed By:

PrinUSign Initials Date Verified By:

PrinUSign Initials Date 58 REVISION NO PROCEDURE TITLE PAGE' 2A AUXILIARY FEEDWATER SYSTEM OPERATION 7 of 34 PROCEDURE NO 2-NOP-0902 ST. LUCIE UNIT 2 4.0 INSTRUCTIONS INITIAL 4.1 2A AFW PUMP to 2A SfG

1.

START PUMP 2A.

2.

OPEN SE-09-2, 2A PUMP DISCH TO 2A S/G VLV. (KEY 83)

3.

THROTTLE MV-09-9, PUMP 2A DISCH TO SG 2A VALVE, as necessary to establish and maintain desired AFW flow to 2A S/G.

4.

WHEN desired level is achieved AND the 2A AFW PUMP is no longer needed, THEN PERFORM the following:

A.

CLOSE MV-09-9, PUMP 2A DISCH TO SG 2A VALVE.

B.

PLACE key switch for SE-09-2, 2A PUMP DISCH TO 2A S/G VLV, to AUTO.

IV

(

C.

VERIFY SE-09-2, 2A PUMP DISCH TO 2A S/G VLV, is CLOSED D.

STOP PUMP 2A.

E.

RETURN PUMP 2A switch to AUTO.

IV Performed By:

PrinUSign Initials Date Verified By:

PrinUSlgn Initials Date 58

REVISION NO PROCEDURE TITLE PAGE' 2A AUXILIARY FEEDWATER SYSTEM OPERATION 8 of 34 PROCEDURE NO 2-NOP-09.02 ST. LUCIE UNIT 2 4.2 28 AFW PUMP to 28 S/G INITIAL

1.

START PUMP 28.

2.

OPEN SE-09-3, 28 PUMP DISCH TO 28 S/G VLV. (KEY 84)

3.

THROITLE MV-09-10, PUMP 28 DISCH TO SG 28 VALVE, as necessary to establish and maintain desired AFW flow to 28 8/G.

4.

WHEN desired level is achieved AND the 28 AFW PUMP is no longer needed, THEN PERFORM the following:

A.

CLOSE MV-09-10, PUMP 28 DISCH TO SG 28 VALVE.

8.

PLACE key switch for SE-09-3, 28 PUMP DISCH TO 28 S/G VLV, to AUTO.

IV C.

VERIFY SE-09-3, 28 PUMP DISCH TO 28 S/G VLV, is CLOSED.

D.

STOP PUMP 28 E.

RETURN PUMP 28 switch to AUTO.

IV Performed By:

-.-~-.

PrinUSlgn Initials Date Verified By:

PrinUSign Initials Date 59

(

REVISION NO PROCEDURE TITLE PAGE*

2A AUXILIARY FEEDWATER SYSTEM OPERATION PROCEDURE NO 4.2 2-NOP-0902 ST. LUCIE UNIT 2 28 AFW PUMP to 28 S/G

1.

START PUMP 2B,

2.

OPEN SE-09-3, 2B PUMP DISCH TO 2B S/G VLV, (KEY 84)

3.

THROTILE MV-09-10, PUMP 2B DISCH TO SG 2B VALVE, as necessary to establish and maintain desired AFW flow to 2B S/G, 4,

WHEN desired level is achieved AND the 2B AFW PUMP is no longer needed, THEN PERFORM the following:

A.

CLOSE MV-09-10, PUMP 2B DISCH TO SG 2B VALVE,

8.

PLACE key switch for SE-09-3, 2B PUMP DISCH TO 2B S/G VLV, to AUTO, C.

D.

VERIFY SE-09-3, 2B PUMP DISCH TO 2B S/G VLV, is

CLOSED, STOP PUMP 2B E.

RETURN PUMP 2B switch to AUTO Performed By:

~----.----,------~------

PrinUSlgn Initials Verified By:

--~----------------------

PrinUSign Initials 59 8 of 34 IV IV Date Date

PROCEDURE TITLE PAGE:

REVISION NO 2A AUXILIARY FEEDWATER SYSTEM OPERATION 9 of 34 P"<OCEDURE NO 4.3 ST. LUCIE UNIT 2 2C AFW PUMP to 2A I 2B SIG NOTE If the 2C AFW PUMP has tripped, 2-0NP-09.02, Auxiliary Feedwater, provides instructions for restarting.

CAUTION When steam is isolated from the 2C AFW PUMP turbine, water may accumulate in the steam supply lines. Starting the pump with accumulated water could result in an overspeed trip.

1.

IF this pump start is for post-maintenance testing AND the steam was completely removed from the turbine, THEN PERFORM the following steps:

A.

CLOSE MV-08-3, 2C PUMP, by placing the key switch on RTGB 202 in the CLOSE position. (KEY 78)

B.

OPEN MV-08-12, SG 2B STM TO AFW PP 2C.

C.

OPEN MV-08-13, SG 2A STM TO AFW PP 2C.

D.

AFTER 5 minutes, CLOSE MV-08-12, SG 2B STM TO AFW PP 2C.

E.

CLOSE MV-08-13, SG 2A STM TO AFW PP 2C.

F.

OPEN MV-08-3, 2C PUMP, by placing the key switch on RTGB-202 in the OPEN position.

2.

IF the 2C AFW PUMP turbine is rotating, THEN PERFORM the following:

A.

UNLOCK AND CLOSE V08884, SE-08-2 INLET ISOL.

B.

WHEN the 2C AFW PUMP stops rotating, THEN SLOWLY OPEN V08884, SE-08-2 INLET ISO.

C.

IF the 2C AFW PUMP does NOT STOP rotating, THEN PERFORM Section 5.4.2.

60 IV

(

REVISION NO PROCEDURE TITLE PAGE:

2A AUXILIARY FEEDWATER SYSTEM OPERATION 9 of 34 PROCEDURE NO 4.3 2*NOP-0902 ST LUCIE UNIT 2 2C AFW PUMP to 2A / 2B S/G NOTE If the 2C AFW PUMP has tripped, 2-0NP-09.02, Auxiliary Feedwater, provides instructions for restarting.

CAUTION When steam is isolated from the 2C AFW PUMP turbine, water may accumulate in the steam supply lines. Starting the pump with accumulated water could result in an overspeed trip.

1.

IF this pump start is for post-maintenance testing AND the steam was completely removed from the turbine, THEN PERFORM the following steps:

A.

B.

C.

D.

E.

F.

CLOSE MV-08-3, 2C PUMP, by placing the key switch on RTGB 202 in the CLOSE position. (KEY 78)

OPEN MV-08-12, SG 2B STM TO AFW PP 2C.

OPEN MV-08-13, SG 2A STM TO AFW PP 2C.

AFTER 5 minutes, CLOSE MV-08-12, SG 2B STM TO AFW PP 2C.

CLOSE MV-08-13, SG 2A STM TO AFW PP 2C.

OPEN MV-08-3, 2C PUMP, by placing the key switch on RTGB-202 in the OPEN position

2.

IF the 2C AFW PUMP turbine is rotating, THEN PERFORM the following.

A.

UNLOCK AND CLOSE V08884, SE-08-2 INLET ISOL.

B.

WHEN the 2C AFW PUMP stops rotating, THEN SLOWLY OPEN V08884, SE-08-2 INLET ISO.

C.

IF the 2C AFW PUMP does NOT STOP rotating, THEN PERFORM Section 5.4.2.

60 IV

REVISION NO 2A PROCEDURE TITLE AUXILIARY FEEDWATER SYSTEM OPERATION PAGE:

10 of 34 PROCEDURE NO 4.3 2-NOP-09,02 ST, LUCIE UNIT 2 2C AFW PUMP to 2A I 2B S/G (continued)

2.

(continued)

D.

LOCK OPEN V08884, SE-08-2 INLET ISOL.

NOTE An operator will be required at the 2C AFW PUMP local station to verify speed.

CAUTION The 2C AFW PUMP turbine shall not be started if turbine bearing or governor oil temperature is less than 40°F.

3.

IF outside air temperature is less than 70a F, THEN CHECK (by pyrometer) turbine bearing and governor oil temperature.

A.

IF turbine bearing or governor oil temperature is less than 70°F, THEN provisions should be made to warm the oil by external source.

B.

IF turbine bearing or governor oil temperature is less than 60°F, THEN 2C AFW PUMP shall be declared OOS.

4.

ENSURE the governor oil level is visible between the level mark and top of sightglass.

61

(

ReVISION NO PROCEDURE TITLE PAGE:

10 of 34 2A AUXILIARY FEEDWATER SYSTEM OPERATION PROCEDURE NO 4.3 2*NOP*09.02 ST. LUCIE UNIT 2 2C AFW PUMP to 2A I 2B S/G (continued)

2.

(continued)

D.

LOCK OPEN V08884, SE-08-2 INLET ISOL.

NOTE An operator will be required at the 2C AFW PUMP local station to verify speed.

CAUTION The 2C AFW PUMP turbine shall not be started if turbine bearing or governor oil temperature is less than 40°F.

3.

IF outside air temperature is less than 70°F, THEN CHECK (by pyrometer) turbine bearing and governor oil temperature.

A.

IF turbine bearing or governor oil temperature is less than 70°F, THEN provisions should be made to warm the oil by external source.

B.

IF turbine bearing or governor oil temperature is less than 60°F, THEN 2C AFW PUMP shall be declared OOS.

4.

ENSURE the governor oil level is visible between the level mark and top of sightglass.

61

REVISiON NO PROCEDURE TITLE PAGE:

2A AUXILIARY FEEDWATER SYSTEM OPERATION 11 of 34 PROCEDURE NO 4.3 2-NOP-09.02 ST. LUCIE UNIT 2 2C AFW PUMP to 2A I 2B S/G (continued)

CAUTION If the oil in the 2C AFW PUMP turbine governor is not allowed to fully drain back to the reservoir, restarting may cause overspeed. This can be prevented by waiting 3 minutes after the pump stops rotating or taking the manual speed control knob on the side of the governor fully counter-clockwise then returning fully clockwise. (Section 7.1.3 Management Directive 3)

5.

ENSURE the 2C AFW PUMP Turbine is NOT rotating.

A.

VERIFY 3 minutes have passed since pump rotation stopped.

OR B.

CYCLE the manual speed control knob on the side of the governor fully counter-clockwise, then fully clockwise.

6.

START 2C AFW PUMP by performing the following:

OPEN MV-08-12, SG 2B STM TO AFW PP 2C.

AND/OR OPEN MV-08-13, SG 2A STM TO AFW PP 2C.

7.

VERIFY turbine speed is stable between 3700 and 3800 rpm AND the governor valve is NOT hunting / oscillating,

8.

OPEN the solenoid valve(s) in the header(s) to the S/Gs requiring feed SE-09-4, 2C PUMP DISCH TO 2A S/G VLV (KEY 85)

SE-09-5, 2C PUMP DISCH TO 2B S/G VLV (KEY 86)

9.

THROTTLE MV-09-11, PUMP 2C TO SG 2A, as necessary to establish and maintain desired flow to 2A S/G.

10.

THROTILE MV-09-12, PUMP 2C TO SG 28, as necessary to establish and maintain desired flow to 2B S/G.

62

(

REVISiON NO PROCEDURE TITLE PAGE:

2A AUXILIARY FEEDWATER SYSTEM OPERATION 11 of 34 PROCEDURE NO 4.3 2*NOP*0902 ST LUCIE UNIT 2 2C AFW PUMP to 2A I 2B S/G (continued)

CAUTION If the oil in the 2C AFW PUMP turbine governor is not allowed to fully drain back to the reservoir, restarting may cause overspeed. This can be prevented by waiting 3 minutes after the pump stops rotating or taking the manual speed control knob on the side of the governor fully counter-clockwise then returning fully clockwise. (Section 7.1.3 Management Directive 3)

5.

ENSURE the 2C AFW PUMP Turbine is NOT rotating.

6.

A.

VERIFY 3 minutes have passed since pump rotation stopped.

OR B.

CYCLE the manual speed control knob on the side of the governor fully counter-clockwise, then fully clockwise.

START 2C AFW PUMP by performing the following OPEN MV-08-12, SG 28 STM TO AFW PP 2C.

AND/OR OPEN MV-08-13, SG 2A STM TO AFW PP 2C.

7.

VERIFY turbine speed is stable between 3700 and 3800 rpm AND the governor valve is NOT hunting / oscillating,

8.

OPEN the solenoid valve(s) in the header(s) to the S/Gs requiring feed:

SE-09-4, 2C PUMP DISCH TO 2A S/G VLV (KEY 85)

SE-09-5, 2C PUMP DISCH TO 28 S/G VLV (KEY 86)

9.

THROTTLE MV-09-11, PUMP 2C TO SG 2A, as necessary to establish and maintain desired flow to 2A S/G.

10.

THROTILE MV-09-12, PUMP 2C TO SG 28, as necessary to establish and maintain desired flow to 28 S/G.

62

(

REVISION NO 2A PROCEDURE TITLE PAGE:

AUXILIARY FEEDWATER SYSTEM OPERATION PROCeDURE NO 4.3 ST. LUCIE UNIT 2 2C AFW PUMP to 2A I 26 S/G (continued)

11.

WHEN the 2C AFW PUMP is no longer being used for feed and it is desired to secure, THEN PERFORM the following:

A.

ENSURE MV-09-11, PUMP 2C TO SG 2A, is CLOSED.

6.

ENSURE MV-09-12, PUMP 2C TO SG 2B, is CLOSED.

C.

PLACE key switch for SE-09-4, 2C PUMP DISCH TO 2A S/G VLV, to AUTO.

D.

VERIFY SE-09-4, 2C PUMP DISCH TO 2A S/G VLV, is CLOSED.

E.

PLACE key switch for SE-09-5, 2C PUMP DISCH TO 2B S/G VLV, to AUTO.

F.

VERIFY SE-09-5, 2C PUMP DISCH TO 2B S/G VLV, is CLOSED.

G.

STOP the 2C AFW PUMP by performing any of the following:

CLOSE MV-08-3, 2C PUMP, with key switch #78 on RTGB-202.

DEPRESS the local TURBINE TRIP pushbutton located on the 2C AFW PUMP TURBINE CONTROL PANEL.

Locally STOP the 2C AFW PUMP by tripping the mechanical overspeed trip lever.

H.

VERIFY 2C AFW PUMP turbine is slowing by observing reduction of speed on 2C AFW PUMP TURBINE CONTROL PANEL.

63 12 of 34 IV IV REVISION NO PROCEDURE TITLE PAGE:

2A AUXILIARY FEEDWATER SYSTEM OPERATION PROUDURE NO 4.3 2-NOP-09.02 ST. LUCIE UNIT 2 2C AFW PUMP to 2A I 26 S/G (continued)

11.

WHEN the 2C AFW PUMP is no longer being used for feed and it is desired to secure, THEN PERFORM the following:

A.

ENSURE MV-09-11, PUMP 2C TO SG 2A, is CLOSED.

6.

ENSURE MV-09-12, PUMP 2C TO SG 2B, is CLOSED.

C.

PLACE key switch for SE-09-4, 2C PUMP DISCH TO 2A S/G VLV, to AUTO.

D.

VERIFY SE-09-4, 2C PUMP DISCH TO 2A S/G VLV, is CLOSED.

E.

PLACE key switch for SE-09-5, 2C PUMP DISCH TO 2B S/G VLV, to AUTO.

F.

VERIFY SE-09-5, 2C PUMP DISCH TO 2B S/G VLV, is CLOSED.

G.

STOP the 2C AFW PUMP by performing any of the following:

CLOSE MV-08-3, 2C PUMP, with key switch #78 on RTGB-202.

DEPRESS the local TURBINE TRIP pushbutton located on the 2C AFW PUMP TURBINE CONTROL PANEL.

Locally STOP the 2C AFW PUMP by tripping the mechanical overspeed trip lever.

H.

VERIFY 2C AFW PUMP turbine is slowing by observing reduction of speed on 2C AFW PUMP TURBINE CONTROL PANEL.

63 12 of 34 IV IV

PROCEDURE TITLE PAGE:

REVISION NO 2A AUXILIARY FEEDWATER SYSTEM OPERATION 13 of 34 PROCEDURE NO 4.3 2-NOP-09.02 ST. LUCIE UNIT 2 2C AFW PUMP to 2A { 28 S/G (continued)

11.

(continued)

NOTE An electrical overspeed trip results in closed indication for MV-08-3, and alarm and reset for annunciator G-46.

A mechanical overspeed trip results in closed indication for MV-08-3, and locked in alarm for Annunciator G-46.

Closing MV-08-3 alone will result in closed indication for MV-08-3 with no alarm for Annunciator G-46.

I.

IF applicable, THEN VERIFY annunciator G-46, 2C AFW PUMP TURBINE FAILURE I TRIP I OVRLD I SS ISOL, is in ALARM.

J.

VERIFY the 2C AFW PUMP is NOT rotating.

K.

ENSURE MV-08-3, 2C PUMP, is reset by placing the key switch on RTGB 202 in the CLOSE position.

NOTE Refer to ATTACHMENT 1 for correct mechanical overspeed mechanism latching.

L.

IF the 2C AFW PUMP was tripped using the mechanical overs peed trip lever, THEN PERFORM the following:

(1)

RESET the 2C AFW PUMP mechanical overspeed linkage.

(2)

VERIFY top surface of trip tappet nut is inline with the line marked on the head lever to ensure full engagement.

M.

ENSURE MV-08-12, SG 2B STM TO AFW PP 2C, is CLOSED.

64 IV

(

RE VISION NO PROCEDURE TITLE PAGE:

2A AUXILIARY FEEDWATER SYSTEM OPERATION 13 of 34 PROCEDURE NO 4.3 2-NOP-09.02 ST. LUCIE UNIT 2 2C AFW PUMP to 2A I 2B S/G (continued)

11.

(continued)

NOTE An electrical overspeed trip results in closed indication for MV-08-3, and alarm and reset for annunciator G-46.

A mechanical overspeed trip results in closed indication for MV-08-3, and locked In alarm for Annunciator G-46.

Closing MV-08-3 alone will result in closed indication for MV-08-3 with no alarm for Annunciator G-46.

I.

IF applicable, THEN VERIFY annunciator G-46, 2C AFW PUMP TURBINE FAILURE / TRIP / OVRLD / SS ISOL, is in ALARM.

J.

VERIFY the 2C AFW PUMP is NOT rotating.

K.

ENSURE MV-08-3, 2C PUMP, is reset by placing the key switch on RTGB 202 in the CLOSE position.

NOTE Refer to ATTACHMENT 1 for correct mechanical overspeed mechanism latching L.

IF the 2C AFW PUMP was tripped using the mechanical overspeed trip lever, THEN PERFORM the following:

(1)

RESET the 2C AFW PUMP mechanical overspeed linkage.

(2)

VERIFY top surface of trip tappet nut is inline with the line marked on the head lever to ensure full engagement.

M.

ENSURE MV-08-12, SG 26 STM TO AFW PP 2C, is CLOSED.

64 IV

REVISION NO 2A PROCEDURE TITLE PAGE' AUXILIARY FEEDWATER SYSTEM OPERATION PROCE DURE NO 4.3 2-NOP-09.02 ST. LUCIE UNIT 2 2C AFW PUMP to 2A /28 S/G (continued)

11.

(continued)

N.

ENSURE MV-08-13, SO 2A STM TO AFW PP 2C, is CLOSED.

O.

ENSURE the manual speed control knob on the side of governor is fully CLOCKWISE.

P.

OPEN MV-08-3, 2C PUMP, by placing the key switch on RTGB-202 in the OPEN position.

Q.

IF the 2C AFW PUMP is rotating, THEN PERFORM the following (1)

UNLOCK AND CLOSE V08884, SE-08-2 INLET ISOL.

(2)

WHEN the 2C AFW PUMP stops rotating, THEN slowly OPEN V08884, SE-08-2 INLET ISOL.

(3)

IF the 2C AFW PUMP does NOT stop rotating, THEN PERFORM Section 5.4.2.

(4)

LOCK OPEN V08884, SE-08-2 INLET ISOL.

12.

ENSURE MV-08-12, SO 2B STM TO AFW PP 2C, switch is in AUTO position.

65 14 of 34 IV IV IV

(

REVISION NO PROCEDURE TITLE PAGE:

2A AUXILIARY FEEDWATER SYSTEM OPERATION PROCE DURE NO 4.3 2-NOP-0902 ST. LUCIE UNIT 2 2C AFW PUMP to 2A / 28 S/G (continued)

11.

(continued)

N.

ENSURE MV-08-13, SG 2A STM TO AFW PP 2C, is CLOSED.

O.

ENSURE the manual speed control knob on the side of governor is fully CLOCKWISE.

P.

OPEN MV-08-3, 2C PUMP, by placing the key switch on RTG6-202 in the OPEN position.

Q.

IF the 2C AFW PUMP is rotating, THEN PERFORM the following (1 )

UNLOCK AND CLOSE V08884, SE-08-2 INLET ISOL.

(2)

WHEN the 2C AFW PUMP stops rotating, THEN slowly OPEN V08884, SE-08-2 INLET ISOL.

(3)

IF the 2C AFW PUMP does NOT stop rotating, THEN PERFORM Section 5.4.2.

(4)

LOCK OPEN V08884, SE-08-2 INLET ISOL.

12.

ENSURE MV-08-12, SG 26 STM TO AFW PP 2C, switch is in AUTO position.

65 14 of 34 IV IV IV

REVISION NO PROCEDURE TITLE PAGE' 2A AUXILIARY FEEDWATER SYSTEM OPERATION 15 of 34 PROCEDURE NO 2-NOP-0902 ST. LUCIE UNIT 2 4.3 2C AFW PUMP to 2A I 28 SIG (continued)

INITIAL

13.

ENSURE MV-08-13, 8G 2A 8TM TO AFW PP 2C, switch is in AUTO position.

IV Performed By:

PrinUSign Initials Date Verified By:

PnnUSlgn Initials Date 66 REVISION NO PROCEDURE TITLE PAGE' 2A AUXILIARY FEEDWATER SYSTEM OPERATION 15 of 34 PROCEDURE NO 2*NOP*0902 ST. LUCIE UNIT 2 4.3 2C AFW PUMP to 2A I 28 SIG (continued)

INITIAL

13.

ENSURE MV-OB-13, SG 2A STM TO AFW PP 2C, switch is in AUTO position.

IV Performed By:

PrinUSign Initials Date Verified By:

PnnUSlgn Initials Date 66

Appendix D Op Test No.:

Event

Description:

Operator Action Form ES-D-2 1

Scenario #

5 Event #

..,;8:;,:.,..;;.9____ Page 2.2..- of _1 __ 9--""1 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator Time II Position II Applicant's Actions or Behavior I Booth Operator Instructions:

i Indications Available:

I BOP Closes the MSIV's as directed.

~

I I

I i

Closes the S/G blowdown and sample valves as directed.

i Performs EOP-99 Appendix X section 2 (attached page 68 -

71 J as directed Recognizes 2C AFW pump trips when started. 2B AFW pump i

discharge valve solenoid fails to open.

I I

r-i I

I i I--

I I

L I ~

i I

I

~--

i I

I I

I

[

67

(

Appendix 0 I Op Test No.

I E",o'D",,,p'<o" Operator Action Form ES-O-2 1

Scenario #

5 Event #

_8...,;,_9 ____ Page.l2.- of _19'---11 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator Time II Position II Applicant's Actions or Behavior I Booth Operator Instructions:

Indications Available:

BOP Closes the MSIV's as directed.

~-

I I

i Closes the S/G blowdown and sample valves as directed.

I r-*

Performs EOP-99 Appendix X section 2 (attached page 68 -

71 J as directed

~

Recognizes 2C AFW pump trips when started. 2B AFW pump discharge valve solenoid fails to open.

I r-I I

i t

i-I

.. ~~.

I I

i i

I 1---

I I [

67

REVISION NO:

PROCEDURE TITLE:

PAGE:

36A PROCEDURE NO.:

APPENDICES I FIGURES I TABLES I DATA SHEETS 115 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 5 of 8)

Section 2: CONTROL ROOM ACTIONS INSTRUCTIONS o 1. ENSURE ONLY ONE MFW Pump is RUNNING, with the control switch in RECIRC.

o 2. ENSURE ONLY ONE Condensate Pump is RUNNING.

o 3..!f AFAS has actuated, and use of Main Feedwater is

desired, Then PERFORM ALL of the following:

o A. ENSURE AFAS is RESET.

o B. ENSURE BOTH S/G [Main FRV] Block valves CLOSED.

1. MV-09-5

2. MV-09-6 0 C. ENSURE BOTH Low Power MIA Stations in MANUAL.

0 D. For EACH MFW header to be placed in service, ENSURE the associated MFIVs are OPEN.

o E. DEPRESS BOTH push buttons to RESET the Low Power Feedwater Valves.

68 CONTINGENCY ACTIONS o 3.1.!f AF AS has NOT actuated and use of Main Feedwater is

desired, Then PERFORM ALL of the following:

o A. ENSURE BOTH S/G [Main FRV] Block valves CLOSED.

o B. For EACH MFW header to be placed in service, ENSURE the associated MFIVs are OPEN.

0 C. ENSURE BOTH Low Power MIA Stations in MANUAL.

0 D. DEPRESS BOTH pushbuttons to RESET the Low Power Feedwater Valves.

0 E. ADJUST the Low Power MIA Stations AS NECESSARY to control S/G levels.

(

REVISION NO.

PROCEDURE TITLE PAGE:

36A PROCEDURE NO.

APPENDICES I FIGURES I TABLES I DATA SHEETS 115 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 5 of 8)

Section 2: CONTROL ROOM ACTIONS INSTRUCTIONS o 1. ENSURE ONLY ONE MFW Pump is RUNNING, with the control switch in RECIRC.

o 2. ENSURE ONLY ONE Condensate Pump is RUNNING.

o 3..!1 AFAS has actuated, and use of Main Feedwater is

desired, Then PERFORM ALL of the following:

o A. ENSURE AFAS is RESET.

o B. ENSURE BOTH S/G [Main FRV] Block valves CLOSED.

1. MV-09-5

2. MV-09-6 o C. ENSURE BOTH Low Power MIA Stations in MANUAL.

o D. For EACH MFW header to be placed in service, ENSURE the associated MFIVs are OPEN.

o E. DEPRESS BOTH push buttons to RESET the Low Power Feedwater Valves.

68 CONTINGENCY ACTIONS o 3.1.!1 AFAS has NOT actuated and use of Main Feedwater is

desired, Then PERFORM ALL of the following:

o A. ENSURE BOTH S/G [Main FRV] Block valves CLOSED.

o B. For EACH MFW header to be placed in service, ENSURE the associated MFIVs are OPEN.

o C. ENSURE BOTH Low Power MIA Stations in MANUAL.

o D. DEPRESS BOTH push buttons to RESET the Low Power Feedwater Valves.

o E. ADJUST the Low Power MIA Stations AS NECESSARY to control S/G levels.

REVISION NO.:

36A PROCEDURE NO.:

2-EOP-99 PROCEDURE TITLE:

APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 6 of 8)

PAGE:

116 of 156 Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

3. (continued) o F. ADJUST the Low Power MIA Stations AS NECESSARY to control S/G levels.

o G. RESTORE AFW to the standby alignment.

o 4. ENSURE BOTH Heater Drain Pumps are STOPPED.

o 5. ENSURE BOTH of the following:

o A. Bearing Oil Pump and Seal Oil Backup Pump RUNNING.

o B. When the turbine reaches 600 rpm, Then Bearing Oil Lift Pump RUNNING.

o 6. ENSURE the Turbine Drain Valves are OPEN.

o 7. ENSURE ONLY ONE Turbine Cooling Water Pump is RUNNING.

o 8. VERIFY Turbine Generator Bearing Oil temperature between 110 to 120°F.

69 o A.1 ENSURE Emergency Bearing Oil Pump RUNNING.

o 8.1 DIRECT a field operator to adjust TCW to the in-service TLO Cooler to maintain outlet Oil temperature between 110 to 120°F.

(

REVISION NO..

PROCEDURE TITLE:

PAGE:

36A PROCEDURE NO APPENDICES I FIGURES I TABLES I DATA SHEETS 116 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 6 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS

3. (continued)

D F. ADJUST the Low Power MIA Stations AS NECESSARY to control S/G levels.

D G. RESTORE AFW to the standby alignment.

D 4. ENSURE BOTH Heater Drain Pumps are STOPPED.

D 5. ENSURE BOTH of the following:

D A. Bearing Oil Pump and Seal Oil Backup Pump RUNNING.

D B. When the turbine reaches 600 rpm, Then Bearing Oil Lift Pump RUNNING.

D 6. ENSURE the Turbine Drain Valves are OPEN.

D 7. ENSURE ONLY ONE Turbine Cooling Water Pump is RUNNING.

D 8. VERIFY Turbine Generator Bearing Oil temperature between 110 to 120°F.

69 CONTINGENCY ACTIONS D A.1 ENSURE Emergency Bearing Oil Pump RUNNING.

D 8.1 DIRECT a field operator to adjust TCW to the in-service TLO Cooler to maintain outlet Oil temperature between 110 to 120°F.

REVISION NO PROCEDURE TITLE:

PAGE:

36A PROCEDURE NO.

APPENDICES / FIGURES / TABLES / DATA SHEETS 117 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 7 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS o 9. When Turbine speed reaches ZERO 0 9.1 PERFORM ALL of the following:

rpm, Then VERIFY the turning gear automatically ENGAGES.

o 10.!f Reactor power history is low, Then CONSIDER reducing steam generator blowdown flow to maintain RCS temperature.

o 11. Place Boron Dilution Alarm System in Operation.

When indicated Reactor power is less than 10.5%,

Then PERFORM BOTH of the following:

o A. ENERGIZE BOTH channels of Startup Nuclear Instrumentation to place the Boron Dilution Alarm System in operation.

o B. VERIFY BOTH Boron Dilution Alarm System Channels are operating.

70 o A. PLACE Turning Gear in MANUAL.

o B. VERIFY the Turning Gear Permissive Light is ON.

o C. Locally ENSURE the Turning Gear is ENGAGED.

o D. Locally START the Turning Gear.

o 11.1 !f BOTH Boron Dilution Alarm System channels are NOT operating, Then PERFORM applicable actions of ONP-02.01, Boron Concentration Control.

(

REVISION NO.

PROCEDURE TITLE PAGE:

36A PROCEDURE NO APPENDICES I FIGURES I TABLES I DATA SHEETS 117 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 7 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS o 9. When Turbine speed reaches ZERO 0 9.1 PERFORM ALL of the following:

rpm, Then VERIFY the turning gear automatically ENGAGES.

o 10.11 Reactor power history is low, Then CONSIDER reducing steam generator blowdown flow to maintain RCS temperature.

o 11. Place Boron Dilution Alarm System in Operation.

When indicated Reactor power is less than 10-5%,

Then PERFORM BOTH of the following:

o A. ENERGIZE BOTH channels of Startup Nuclear Instrumentation to place the Boron Dilution Alarm System in operation.

o B. VERIFY BOTH Boron Dilution Alarm System Channels are operating.

70 o A. PLACE Turning Gear in MANUAl.

o B. VERIFY the Turning Gear Permissive Light is ON.

o C. Locally ENSURE the Turning Gear is ENGAGED.

o D. Locally START the Turning Gear.

o 11.1 11 BOTH Boron Dilution Alarm System channels are NOT operating, Then PERFORM applicable actions of ONP-02.01, Boron Concentration Control.

(

REVISION NO:

36A PROCEDURE NO.:

2-EOP-99 PROCEDURE TITLE:

APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 8 of 8)

PAGE:

118 of 156 Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE Excessive moisture can build up in CEDMC's room, and impact equipment reliability if 15 KW heaters are not enerqized after plant shutdown.

o 11. NOTIFY SNPO to energize 15 KW heater located in the CEDMC's room to minimize humidity build-up per 2-NOP-25.10, CEDMCS Air Conditioning System Operation.

o 12. CONSIDER contacting the Division Load Dispatcher for a switching order to OPEN the Main Generator disconnects.

END OF APPENDIX X 71

(

.-----~

~----

REVISION NO 36A PROCEDURE NO.

2-EOP-99 PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 8 of 8)

PAGE:

118 of 156 Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE Excessive moisture can build up in CEDMC's room, and impact equipment reliability if 15 KW heaters are not energized after plant shutdown.

o 11. NOTIFY SNPO to energize 15 KW heater located in the CEDMC's room to minimize humidity build-up per 2-NOP-25.10, CEDMCS Air Conditioning System Operation.

o 12. CONSIDER contacting the Division Load Dispatcher for a switching order to OPEN the Main Generator disconnects.

END OF APPENDIX X 71

Appendix D

~p Test No.:

I ! Event

Description:

I.

Position Operator Action Form ES-D-2 Scenario #

5 Event #

_8;;,.:.,..;;.,9 ____ Page 1L of

....;..19~-I1 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 26 Steam Generator Ap licant's Actions or Behavior ooth Operator Instructions:

B

In r-dications Available: No AFW flow available

~..

i i

i I

I I

--I i

i i

i I

I

.-.. -.--~---

I I

Re - diagnose using diagnostic flow chart and exit to EOP-06 SRO

'Total Loss of Feedwater' Direct STA perform SFSC's for EOP-06 performed every 15 minu es.

Direct HP to perform secondary surveys if not already performed, Direct RCS depressurized to 1800 to 1850 psia using auxiliary sprays if not already performed, Direct Appendix H, restore Instrument Air, of EOP-99 if not already performed, If Appendix H, 'Restore Instrument Air' not completed within 30 minutes of loss of CCW, ensure CCW NOT restored to RCP's if not already performed, NOTE:

, When AB Bus is swapped in App-H AFW flow indication on RTGB will be restored, f---

I i

I' Direct clOSing of S/G blowdown and sample valves If not a rea y pe orme I

d rf d

I j

Direct closing of MSIV's if not already performed,

r-Direct EOP-99 Appendix X section 2 if not already performed, 72 i

(

Appendix D Operator Action Form ES-D-2

~p~est No.

I Scenario #

5 Event #

_8;;.,:,...,;;9____ Page.:!.L of

~19;;...--11 I

! Event

Description:

2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator Ap licant's Actions or Behavior Booth Operator Instructions:

In dications Available: No AFW flow available I

I I

I

-~4 i

~-.

i I

I I

i I

I I

I i

Re - diagnose using diagnostic flow chart and exit to EOP-06 SRO

'Total Loss of Feedwater' Direct ST A perform SFSC's for EOP-06 performed every 15 minutes.

Direct HP to perform secondary surveys if not already performed.

Direct RCS depressurized to 1800 to 1850 psia using auxiliary sprays if not already performed.

Direct Appendix H, restore Instrument Air, of EOP-99 if not already performed.

If Appendix H, 'Restore Instrument Air' not completed within 30 minutes of loss of CCW, ensure CCW NOT restored to RCP's if not already performed.

NOTE:

en AB Bus is swapped in App-H AFW flow indication on RTGB will be restored, I

i I

---+--

I I

Direct closing of S/G blowdown and sample valves If not already performed Direct closing of MSIV's if not already performed.

Direct EOP-99 Appendix X section 2 if not already performed.

72 I

I i

I I

Appendix D r Op Test No_:

i!

II Event

Description:

I Operator Action Form ES-D-2 1

Scenario #

5 Event #

_8;;.:..'.,;.9____ Page lZ..- of _1;..;.,9--11 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 28 Steam Generator

'L-~=====-=--~~~~-=Y--=======---=~~~~~~--~~~ ______===-==-=41

~L_Time Position A

licant's Actions or Behavior i Booth Operator Instructions:

. Indications Available:

i

1 SRO I

Direct Replenishing S/G Inventory by using 2-0NP-09.02, Critical I

I Auxiliary Feedwater Appendix C steps 1 A thru 1 H (attached I

Task page_74-75_) if not already performed.

~ I

~

I i

I r----------

r--

I BOP Performs as directed SFSC's for EOP-06 every 15 minutes.

I

~--

I RO I RCS depressurized to 1800 to 1850 psia using auxiliary sprays SE-02-3 and SE-0204, as directed if not already performed.

~ --

--.---~--

If Appendix H, 'Restore Instrument Air' not completed within 30 I

minutes of loss of CCW, ensures CCW is NOT restored to I

RCP's.

I 1------

BOP Performs Appendix H, restore Instrument Air, of EOP-99.as directed if not already performed.(attached)

~--

_o-f r-Contacts NPO to perform local steps in Appendix H, restore

~

Instrument Air, of EOP-99 if not already performed.

i

.- --- ------------+-

i I

Resets Instrument Air Compressors when notified by NPO if not already performed.

i --

I I

I r-Closes the MSIV's as directed if not already performed.

r--

1

..... --~.-,---

I 73

(

Appendix 0 Operator Action Form ES-O-2

~~~est No.

Scenario #

5 Event #

8, 9 Page

_17_ of -.;.;19;"'-'-11 il Event

Description:

2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator i Booth Operator Instructions:

I- --

. Indications Available:

1 SRO i

Critical Direct Replenishing S/G Inventory by using 2-0NP-09.02, I

Auxiliary Feedwater Appendix C steps 1 A thru 1 H (attached I

Task page _74-75 _) if not already periormed.

I I

I BOP Performs as directed SFSC's for EOP-06 every 15 minutes.

+-

i-----

I--

I RO r ys i

SE-02-3 and SE-0204, as directed if not already performed I

i RCS depressurized to 1800 to 1850 PSI a uSing auxiliary sp a

---.~----

I If Appendix H, 'Restore Instrument Air' not completed within 30 I

minutes of loss of CCW, ensures CCW is NOT restored to RCP's.

--~-~----.. -

I BOP Periorms Appendix H, restore Instrument Air, of EOP-99.as I

directed if not already periormed.(attached)

I Contacts NPO to perform local steps in Appendix H, restore I

I Instrument Air, of EOP-99 if not already performed.

-~------ --.-.f-- -----

I

~---..

I Resets Instrument Air Compressors when notified by NPO if not already periormed.

I I

Closes the MSIV's as directed if not already performed.

.~-

73 I

I I

i I

I I I

REVISION NO PROCEDURE TITLE PAGE.

11 AUXILIARY FEEDWATER 19 of 29 PI,OCEDURE NO 2-0NP-09,02 ST, LUCIE UNIT 2 APPENDIX C CROSS-CONNECTING AFW (Page 1 of 4)

INITIAL NOTE If cross-tying AFW in Modes 1 - 3, Then the motor driven pump not being used to supply SGs must be declared out-of-service per the applicable Tech, Spec, 1,

!f 2A AFW Pump is to feed 28 S/G, Then PERFORM the following:

A.

ENSURE MV-09-10, Pump 28 Disch To S/G 28 Valve, is

CLOSED, B.

START Auxiliary Feedwater Pump 2A, C.

OPEN SE-09-2, 2A Pump Disch To 2A S/G Vlv Key 83, CAUTION Opening both MV-09-13 and MV-09-14 while in Modes 1, 2, 3 could make two independent AFW flow path inoperable.

NOTE Key-switches for MV-09-13 and MV-09-14 are located in 2A128 AFW Pump Room Two keys are required since the keys are removable in CLOSE

only, D.

Locally OPEN MV-09-13, 2A To 28 AFW Hdr Cross-tie.

NPO E.

Locally OPEN MV-09-14, 28 To 2A AFW Hdr Cross-tie, NPO CAUTION Ensure total pump flow does not exceed 425 QPm, F,

THROTILE MV-09-10, Pump 28 Disch To SG 28 Valve, to establish desired flow rate, NOTE While feeding both S/Gs indicated flow is pump flow to both S/Gs, G.

To feed the 2A S/G, THROTTLE MV-09-9, Pump 2A Disch To SG 2A Valve, to establish desired flow rate.

74

(

REVISION NO PROCEDURE TITLE PAGE 11 AUXILIARY FEEDWATER PllOCEOURE NO 19 of 29 2-0NP-0902 ST. LUCIE UNIT 2 APPENDIX C CROSS-CONNECTING AFW (Page 1 of 4)

INITIAL NOTE If cross-tying AFW in Modes 1 - 3, Then the motor driven pump not being used to supply SGs must be declared out-of-service per the applicable Tech. Spec.

1.

if 2A AFW Pump is to feed 28 S/G, Then PERFORM the following:

A.

ENSURE MV-09-10, Pump 28 Disch To S/G 28 Valve, is CLOSED B.

ST ART Auxiliary Feedwater Pump 2A.

C.

OPEN SE-09-2, 2A Pump Disch To 2A S/G Vlv Key 83.

CAUTION

(

Opening both MV-09-13 and MV-09-14 while In Modes 1, 2, 3 could make two Independent AFW flow path inoperable.

NOTE Key-switches for MV-09-13 and MV-09-14 are located in 2A128 AFW Pump Room Two keys are required since the keys are removable in CLOSE only.

D.

Locally OPEN MV-09-13, 2A To 28 AFW Hdr Cross-tie.

NPO E.

Locally OPEN MV-09-14, 28 To 2A AFW Hdr Cross-tie.

NPO CAUTION Ensure total pump flow does not exceed 425 qpm.

F.

THROTILE MV-09-10, Pump 28 Disch To SG 28 Valve, to establish desired flow rate.

NOTE While feeding both S/Gs indicated flow is pump flow to both S/Gs.

G.

To feed the 2A S/G, THROTTLE MV-09-9, Pump 2A Disch To SG 2A Valve, to establish desired flow rate.

(

74

REV'SION NO PROCEDURE TITLE PAGE:

11 AUXILIARY FEEDWATER 20 of 29 PROCEDURE NO 2-0NP-09.02 ST. LUCIE UNIT 2 APPENDIX C CROSS*CONNECTING AFW (Page 2 of 4)

1.

(continued)

INITIAL H.

When the system is to be returned to normal, Then PERFORM the following:

1.

CLOSE MV-09-10, Pump 2B Disch To SG 28 Valve.

2.

!! 2A S/G is being fed, Then CLOSE MV-09-9, Pump 2A Disch To SG 2A Valve.

3.

STOP Auxiliary Feedwater Pump 2A.

4.

CLOSE SE-09-2. 2A Pump Disch To 2A S/G Vlv Key 83. --

S.

Locally CLOSE MV-09-13, 2A To 28 AFW Hdr Cross-tie. --

NPO

6.

Locally CLOSE MV-09-14, 2B To 2A AFW Hdr Cross-tie. --

NPO

7.

PERFORM Independent Verification of the following:

COMPONENT POSITION IV INITIAL MV-09-9. Pump 2A Disch To SG 2A Valve CLOSED MV-09-10, Pump 26 Disch To SG 26 Valve CLOSED SE-09-2. 2A Pump Disch To 2A S/G Vlv Key 83 CLOSED MV-09-13. 2A To 26 AFW Hdr Cross-tie CLOSED MV-09-14. 26 To 2A AFW Hdr Cross-tie CLOSED NOTE If cross-tying AFW in Modes 1 - 3, Then the motor driven pump not being used to supply SGs must be declared out-of-service per the applicable Tech. Spec.

2.

!! 2B AFW Pump is to feed 2A S/G, Then PERFORM the following:

A.

ENSURE MV-09-g, Pump 2A Disch to 2A SIG Valve, is CLOSED. --

B.

START Auxiliary Feedwater Pump 2B.

C.

OPEN SE-09-3, 28 Pump Disch To 28 SIG Vlv Key 84.

75

(

REV'SION NO PROCEDURE TITLE PAGE 11 PROCEDURE NO AUXILIARY FEEDWATER 20 of 29 2-0NP-0902 ST. LUCIE UNIT 2 APPENDIX C CROSS*CONNECTING AFW (Page 2 of 4)

1.

(continued)

INITIAL H.

When the system is to be returned to normal, Then PERFORM the following

1.

CLOSE MV-09-10, Pump 2B Disch To SG 2B Valve.

2.

If 2A S/G is being fed, Then CLOSE MV-09-9. Pump 2A Disch To SG 2A Valve.

3.

STOP Auxiliary Feedwater Pump 2A.

4.

CLOSE SE-09-2. 2A Pump Disch To 2A S/G Vlv Key 83.

5.

Locally CLOSE MV-09-13, 2A To 28 AFW Hdr Cross-tie.

NPO

6.

Locally CLOSE MV-09-14, 28 To 2A AFW Hdr Cross-tie.

NPO

7.

PERFORM Independent Verification of the following:

COMPONENT POSITION IV INITIAL MV-09-9, Pump 2A Disch To SG 2A Valve CLOSED MV-09-10. Pump 28 Disch To SG 2B Valve CLOSED SE-09-2, 2A Pump Disch To 2A S/G Vlv Key 83 CLOSED MV-09-13, 2A To 28 AFW Hdr Cross-tie CLOSED MV-09-14. 2B To 2A AFW Hdr Cross-tie CLOSED NOTE If cross-tying AFW in Modes 1 - 3, Then the motor driven pump not being used to supply SGs must be declared out-of*service per the applicable Tech. Spec.

2.

Lf 2B AFW Pump is to feed 2A S/G, Then PERFORM the following:

A.

ENSURE MV-09-9, Pump 2A Disch to 2A S/G Valve, is CLOSED. ---

B.

ST ART Auxiliary F eedwater Pump 2B C.

OPEN SE-09-3, 28 Pump Disch To 2B S/G Vlv Key 84.

(

75

Appendix D Operator Action Form ES-D-2 I:

I Op Test No.:

I 1

Scenario #

5 Event #

_8;..:.,;..:.9 ____ Page ~

of _1;..,..9--11 I

D I Event escnptlon:

2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator

~me II Position II Applicant's Actions or Behavior I Booth Operator Instructions:

Indications Available:

f-I Closes the S/G blowdown and sample valves as directed if not I

I already performed.

i

~._-- -,._---_..

Performs EOP-99 Appendix X section 2 as directed if not i

already performed.

-.--.----~'.. -.----._t_-.-

i I ;

... ----i------I--------------------------1 I

BOP I

Critical Replenishes S/G Inventory by using 2-0NP-09.02, Auxiliary Feedwater Appendix C steps 1A thru 1 H as directed. Contacts Task NPO to perform steps (attached page_74-75_)

.N OTE: When NPO locally opens MV-09-10 this may cause an AFAS-1 lockout so 1-SE-09-2 will need to be opened.

------i i

L--

L.

--_o-j I

I 1

-.----~--

Suggested termination point:

2A Diesel output breaker has been closed and

2B S/G is being fed by the 2A AFW pump.

76 I

I I

(

\\,

(

Appendix D r,....-"***-~----*---

I' Op Test No 1

Ii Event Description il

~

~~

Position Operator Action Form ES-D-2 Scenario #

5 Event#

_8.;.,;,,,.,,9 ____ Page ~

of _19'---11 2C AFW pump trips and MV-09-9 2A AFW pump to 2A SG fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator A

licant's Actions or Behavior r-----------------------------------,

I Booth Operator Instructions:

Tndications Available:

i-~---T I

! Closes the S/G blowdown and sample valves as directed if not I

I : already performed.

I

,-- - --- ------ ----t-~-+-=--~~--------,-,---,~~-,-----::-------------I Performs EOP-99 Appendix X section 2 as directed if not i

already performed.

-,,---- -----..,.-----------+----"-----'---------------------------i

'------t--------------------------j BOP I

I I

Critical Replenishes S/G Inventory by using 2-0NP-09.02, Auxiliary Feedwater Appendix C steps 1 A thru 1 H as directed, Contacts

~_

--+_T_a_s_k_---+-N_P_O_t_o_p_e_rf_o_rm_s_te_p_s_(_a_tta_c_h_e_d_

p

_a_

g

_e ___

7_4_-7_5 __

l _____

---1

~----~------------------------~

NOTE When NPO locally opens MV-09-1 0 this may cause an AFAS-1 lockout so 1-SE-09-2 will need to be opened.

. -----------------,-----------------------------1 I

--- ---------+---------+-----------------------------i I

'--------------1--------------"1--------------------------------1

~--------+------t-------------------------------i i

1---------:-------\\-----------------------------------1

i i

" --------- ----t---------+-----------------------------i Suggested termination point:

2A Diesel output breaker has been closed and 2B S/G is being fed by the 2A AFW pump.

---~-~-- ------'------------------------------'

76

Facility:

St. Lucie Examiners:

Scenario Event Description NRC Scenario 7 Scenario No.:

Operators:

7 Op Test No.:

HLC-19 NRC SRO:

RO:

BOP:

Initial Conditions:

40% power, IC-72, xenon building in approximately 3177 pcm, 6 gpm dilution to the suction of the Charging pumps. 2C Charging pump OOS for repack. NOTE: Open FCV-12-3C 2C Condo PP recirc. and start the condensate transfer pump.

f-----.

Turnover: 40% power, 2C Charging pump OOS for repack. Unit was down powered to remove 2B Condensate from service due to motor oil leak. The 2C Condensate pump is ready to be started. Return to 100% power when 2C Condensate pump and 2B MFW pump are running.

Critical Tasks Stop all RCP's upon loss of all CCW Event Malf.

Event Event No.

No.

Type' Description 1

R I All Start 2C Condensate Pump. Unit up power to 100%

N/BOP 2

1 1/ RO TIC-2223 Letdown Temperature Controller malfunction. V2520 ion exchanger bypass, does not close.

e-'

3 2

T.S. SRO RWT LIS 07-2B fails low 4

3 II RO FCV 221 OX, primary water controller output fails high.

1---- --'-"-!--...

5 4

C/BOP RIM 26-61 fails high. CROAI valve FCV-25-16 trips on overload.

T. S. SRO HVE-13A does not auto start, when HVE-13A manually started, fan trips.

6 5

C/BOP 2A Intake Cooling Water pump sheared shaft.

7 6

M I All Loss of Instrument Air pressure. Plant down power I Unit trip 8

7 C/RO Three CEA's do not fully insert. Emergency Borate

~-"-~---

9 8

C/RO Stop All RCP's due to CCW valve closure on loss of air Natural Circulation Cooldown I Depressurizarion 10 9

M I All 2B2 RCP seal failure resulting in a LOCA

.. -.---.~.

k (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

(

Facility:

SL Lucie Examiners:

Scenario Event Description NRC Scenario 7 Scenario No,:

Operators:

7 Op Test No,:

HLC-19 NRC SRO:

RO:

BOP:

Initial Conditions:

40% power, IC-72, xenon building in approximately 3177 pcm, 6 gpm dilution to the suction of the Charging pumps, 2C Charging pump OOS for repack, NOTE: Open FCV-12-3C 2C Cond, PP recirc, and start the condensate transfer pump,

~--"

-~-

Turnover: 40% power, 2C Charging pump OOS for repack, Unit was down powered to remove 2B Condensate from service due to motor oil leak, The 2C Condensate pump is ready to be started, Return to 100% power when 2C Condensate pump and 2B MFW pump are

running, Critical Tasks:

Stop all RCP's upon loss of all CCW I

Event MaiL Event I

Event No, No, Type' Description 1

R I All Start 2C Condensate Pump, Unit up power to 100%

N/BOP 2

1 1/ RO TIC-2223 Letdown Temperature Controller malfunction, V2520 ion exchanger bypass, does not close, e--------

3 2

T,S, SRO RWT LIS 07-2B fails low 4

3 I I RO FCV 2210X, primary water controller output fails high, 1--- '"------1-----

5 4

C/BOP RIM 26-61 fails high, CROAI valve FCV-25-16 trips on overload, T, S, SRO HVE-13A does not auto start, when HVE-13A manually started, fan trips,

--"--~-'

6 5

C/BOP 2A Intake Cooling Water pump sheared shaft 7

6 M I All Loss of Instrument Air pressure, Plant down power I Unit trip 8

7 C/RO Three CEA's do not fully insert, Emergency Borate

.-~---

9 8

C/RO Stop All RCP's due to CCW valve closure on loss of air f-,----

Natural Circulation Cooldown I Depressurizarion 1-----

--~

10 9

M/AII 2B2 RCP seal failure resulting in a LOCA (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Scenario Event Description NRC Scenario 7 st. Lucie Unit was down powered to 40% power. 2B Condensate pump has been removed from service.

2C Condensate pump is ready to be started. 2C Condensate pump started, raise power to 100%.

TIC-2223 Letdown Temperature controller malfunctions requiring manual control. When high temperature is reached, Ion Exchanger bypass valve V2520 does not close. Manual closure will be required.

RWT level transmitter LIS 07-2B fails low. SRO to evaluate T.S.

FCV 221 OX controller fails high resulting in maximum dilution to the suction of the Charging pumps. Manual control will be needed to stop dilution.

RIM 26-61 fails high. This will result in Control room recirc. on the A train, however FCV 25-16 trips on overload and HVE-13A will not start. When HVE-13A is manually started, it will also trip.

SRO will be required to evaluate T.S.

2A Intake Cooling water pump will experience a sheared shaft. The 2C Intake Cooling water pump will be started in its place.

A loss of Instrument air requires a plant shutdown. Eventually a total loss of Instrument air occurs resulting in a manual trip. Upon the plant trip three CEA's will not fully insert requiring emergency boration. Due to loss of air, CCW to the RCP's will close requiring all RCP's to be stopped.

2-EOP-09 LOOP / Loss of Forced Circulation will be entered. Cooldown and depressurization will be required. During the cooldown, 2B2 RCP seals will fail resulting in a LOCA. The crew should exit 2-EOP-09 and enter 2-EOP-03 Loss of Coolant Accident.

The scenario may be terminated when the crew is implementing 2-EOP-03 and a controlled cooldown is being implemented.

Procedures Used 2-GOP-201, Reactor Plant Startup Mode 2 to Mode 1 2-GOP-1 01, Reactor Operating Guidelines During Steady State and Scheduled Load Changes NOP-100.02, Axial Shape Index Control 2-NOP-12.03 Condensate System Operation 2-0NP-02.03, Charging and Letdown 2-0NP-09.02. Auxiliary Feedwater 2-0NP-25.02. Ventilation Systems 2-0640030, Intake Cooling Water System 2-NOP-21.03C 2C Intake Cooling Water Pump Operation 2-1010030, Loss of Instrument Air 2-NOP-100.02, Rapid Downpower 2-EOP-01. Standard Post Trip Actions 2-EOP-09, Loss of Offsite Power / Loss of Forced Circulation 2-EOP-03, Loss of Coolant Accident Technical Specifications Entered 2

,----~-------------------~~--------------------,

Scenario Event Description NRC Scenario 7 st. Lucie Unit was down powered to 40% power. 28 Condensate pump has been removed from service.

2C Condensate pump is ready to be started. 2C Condensate pump started, raise power to 100%.

TIC-2223 Letdown Temperature controller malfunctions requiring manual control. When high temperature is reached, Ion Exchanger bypass valve V2520 does not close. Manual closure will be required.

RWT level transmitter LIS 07-28 fails low. SRO to evaluate T.S.

FCV 221 OX controller fails high resulting in maximum dilution to the suction of the Charging pumps. Manual control will be needed to stop dilution.

RIM 26-61 fails high. This will result in Control room recirc. on the A train, however FCV 25-16 trips on overload and HVE-13A will not start. When HVE-13A is manually started, it will also trip.

SRO will be required to evaluate T.S.

2A Intake Cooling water pump will experience a sheared shaft. The 2C Intake Cooling water pump will be started in its place.

A loss of Instrument air requires a plant shutdown. Eventually a total loss of Instrument air occurs resulting in a manual trip. Upon the plant trip three CEA's will not fully insert requiring emergency boration Due to loss of air, CCW to the RCP's will close requiring all RCP's to be stopped.

2-EOP-09 LOOP / Loss of Forced Circulation will be entered. Cooldown and depressurization will be required. During the cooldown, 282 RCP seals will fail resulting in a LOCA. The crew should exit 2-EOP-09 and enter 2-EOP-03 Loss of Coolant Accident.

The scenario may be terminated when the crew is implementing 2-EOP-03 and a controlled cooldown is being implemented.

Procedures Used 2-GOP-201, Reactor Plant Startup Mode 2 to Mode 1 2-GOP-1 01, Reactor Operating Guidelines During Steady State and Scheduled Load Changes NOP-100.02, Axial Shape Index Control 2-NOP-12.03 Condensate System Operation 2-0NP-0203, Charging and Letdown 2-0NP-0902, Auxiliary Feedwater 2-0NP-25 02, Ventilation Systems 2-0640030, Intake Cooling Water System 2-NOP-21.03C 2C Intake Cooling Water Pump Operation 2-1010030, Loss of Instrument Air 2-NOP-100.02, Rapid Downpower 2-EOP-01, Standard Post Trip Actions 2-EOP-09, Loss of Offsite Power / Loss of Forced Circulation 2-EOP-03, Loss of Coolant Accident Technical Specifications Entered 2

Scenario Event Description NRC Scenario 7 3.7.7 Control Room Emergency Ventilation System 3.3.2 ESFAS table 3.3-3 3

~~~--'--------"-'-

(

Scenario Event Description NRC Scenario 7 3.7.7 Control Room Emergency Ventilation System 3.3.2 ESFAS table 3.3-3 3

Appendix D Operator Action Form ES*D*2

.r--

II Op Test No.:

1 ii Event

Description:

Scenario #

7 Event #

...;... ____ Page i-- of _2..;;.0---."

bnm' Position Raise power to approximately 45% and start 2C Condensate pump. Perform up power A

licant's Actions or Behavior r ! Booth Operator Instructions: From NPO, inform the crew Appendix F of 2*NOP*

12.03 Condensate System Operation up to step 15 is complete. Also when the 2B Main Feedwater pump is to be started, state 4.5.13 is ready to be implemented.

Examiners Note: Crew may elect to start the 2C Condensate pump and 2B MFW pump prior to 45% power.

i I

1---,._-----

SRO Direct power ascension lAW 2-GOP-201 Reactor Plant Startup

- Mode 2 to Mode 1 (attached page_5-7_).

I Direct RO to increase dilution rate to raise power lAW 2-NOP-02.24 Boron Concentration Control (attached page_B*1 0_).

i

'~-'

r' I..... _--+

Direct RO to withdraw CEA's lAW 2-GOP-1 01 (attached i

page_11,12_)

.-.. ~.

Implement 2-NOP-12.03 Condensate System Operation, Appendix F, step 15 (attached page_14_). Start the 2C Condensate pump lAW 2-GOP-201 step 6.130.7 at approximately 45% power. When 2C started, direct recirc FCV-12-3C closed.

~----... ---i.. -----+--------------------------,

i When 2C Condensate pump has been started start the 2B Main Feedwater pump lAW 2-NOP-09.01 Main Feedwater System step 4.5.13 (attached page_15_).

f*.. ------i--*----j-------------------

t-~---II,.------+-----------------I When 2C Condensate and 2B Main Feedwater pump have been started, direct power increase toward 100%.

.. ---..... -......... --l-----+------------------------

RO Raise dilution rate for power increase lAW 2-NOP-02.24 Boron i Concentration Control step 6.5.12 (attached page_B-10_)

-~-----~-

.. -t***---+-W-it-hd-r-a-w* CEA's to control Rx power and ASI lAW 2-GOP-1 01 Rx Operating Guidelines step 6.1 (attached page_11_)

CEA Withdrawal, select MS on the CEDMCS Control Switch IN/HOLD/OUT Switch to the OUT direction

~-----~------~~

4

(

Appendix D Operator Action Form ES-D-2

~-~~~~~~~--~--~~~~~=-~~~~~~~=-~~~~~~

il Op Test No_

1 Scenario #

7 Event #

Page

_4 _

of

...;..20~"'1

1 Event

Description:

Raise power to approximately 45% and start 2C Condensate pump_ Perform up Ii power t::T~I~m~e_db~p~O~S~iti~On~db_~ ____ =-==_~A~I~ic~a~nt~'s~A~C~tio~n~s~o~r~B~e~ha~v~io~r _______

d

, Booth Operator Instructions: From NPO, inform the crew Appendix F of 2-NOP-1 12.03 Condensate System Operation up to step 15 is complete. Also when the 2B

_ Main Feedwater pump is to be started, state 4.5.13 is ready to be implemented.

, Examiners Note: Crew may elect to start the 2C Condensate pump and 2B MFW i pump prior to 45% power.

f---

Direct power ascension lAW 2-GOP-201 Reactor Plant Startup SRO

- Mode 2 to Mode 1 (attached page_5-7 _)-

, - --- --------------+-----------1

-- -------+--1 -------------i-----

Direct RO to increase dilution rate to raise power lAW 2-NOP-I 02.24 Boron Concentration Control (attached page_8-1 0_).

i

~-- --------___j___

1 1 __ -----+--**1 Direct-RO to withdraw CEA's lAW 2.GOP.1 01 (attached I

~~-~----~--_I---

_---+---1 p_a_

g e_-_11_,1_2_-) ______________ j Implement 2-NOP-12,03 Condensate System Operation, Appendix F, step 15 (attached page_14_). Start the 2C Condensate pump lAW 2-GOP-201 step 6.130.7 at I

approximately 45% power. When 2C started, direct recirc FCV*

_~--~-1-2---3-C-C-lo-s-e-d-. _______________ _

+---------+1--------------

! When 2C Condensate pump has been started start the 2B 1----- ---------+---

I Main Feedwater pump lAW 2-NOP-09.01 Main Feedwater I System step 4.5.13 (attached page 15

).

I

,-------------+----

I

,."~----~.-.. ----.-

When 2C Condensate and 2B Main Feedwater pump have been started, direct power increase toward 100%.

-.-_t- _-+-~~

__ ~~~~~~

~

1--

~

RO Raise dilution rate for power increase lAW 2-NOP-02,24 Boron

Concentration Control step 6.5.12 (attached page_8-1 0_)

____ ~i _____

I

- Withdraw-CEA's to control Rx power and ASI lAW 2-GOP-1 ~

Rx Operating Guidelines step 6.1 (attached page_11_)

v I I

i J

CEA Withdrawal, select MS on the CEDMCS I

Control Switch

~_____

IN/HOLD/OUT Switch to the OUT direction 4

REVISION NO PROCEDURE TITLE.

PAGE:

1-_.--;.6..;..0 __

-iREACTOR PLANT STARTUP - MODE 2 TO MODE 1 PROCEDURE NO 2*GOP-201 ST_ LUCIE UNIT 2 6.129 (continued)

7.

(continued) 54 of 69 INITIAL I

NOTE I

The following step will transfer the DEH System to automatic control.

I.

J.

DEPRESS Oper Auto.

REMOVE Maintenance Test Key.

8.

REMOVE the Impulse Pressure Feedback Loop from service as follows' A.

B.

DEPRESS Imp In/Imp Out.

VERIFY Imp Out light is LIT.

6.130 When Reactor Power is at approximately 45% as indicated on the highest reading instrument, Then PERFORM the following:

1.

STOP the power ascension.

2.

§,

PERFORM a Nuclear / Delta T power calibration in

3.

4.

accordance with 2-0SP-69.01, Nuclear and Delta T Power Calibration.

11 NOT performed at 30% Reactor Power, Then NOTIFY SCE or I&C to perform DCS Steam Generator Feedwater Discharge Coefficients Verification per 2-NOP-102.01.

]lNOT performed at 30% Reactor Power, Then ENSURE scheduled incore surveillance has been performed.

5.

!f NOT performed at 30% Reactor Power, Then ENSURE the Ineore Detection System is OPERABLE in accordance with OSP-64.01, Reactor Engineering Periodic Tests, Checks and Calibrations.

6.

11lhe Condensate Polisher is in service, Then ENSURE enough Powdex vessels are in service to support the increase in condensate flow.

7.

START the second Condensate Pump in accordance with 2-NOP-12 03, Condensate System Operation 5

SCE / IC

.~------------------------------~-.--.-~---

--~---------~------

REVISION NO PROCEDURE TITLE PAGE 1-__

5;.,.;0 __

--iREACTOR PLANT STARTUP - MODE 2 TO MODE 1 PROCEDURE NO 2*GOP*201 ST. LUCIE UNIT 2 6.129 (continued)

I

7.

(continued)

NOTE The following step will transfer the OEH S.l'stem to automatic control.

I.

DEPRESS Oper Auto.

J.

REMOVE Maintenance Test Key.

8.

REMOVE the Impulse Pressure Feedback Loop from service as follows A.

B.

DEPRESS Imp Inllmp Out.

VERIFY Imp Out light is LIT.

6.130 When Reactor Power is at approximately 45% as indicated on the highest reading instrument, Then PERFORM the following:

1.

STOP the power ascension.

2.

§1 PERFORM a Nuclear I Delta T power calibration in accordance with 2-0SP-59.01, Nuclear and Delta T Power Calibration.

3.

if NOT performed at 30% Reactor Power, Then NOTIFY SCE or I&C to perform DCS Steam Generator Feedwater Discharge Coefficients Verification per 2-NOP-102.01.

4.

!iNOT performed at 30% Reactor Power, Then ENSURE scheduled incore surveillance has been performed.

5.

if NOT performed at 30% Reactor Power, Then ENSURE the Incore Detection System is OPERABLE in accordance with OSP*54.01, Reactor Engineering Periodic Tests, Checks and Calibrations.

6.

11 the Condensate Polisher is in service, Then ENSURE enough Powdex vessels are in service to support the increase in condensate fiow.

7.

START the second Condensate Pump in accordance with 2-NOP-12.03. Condensate System Operation 5

54 of 59 INITIAL I

SCE IIC

REVISION NO PROCEDURE TITLE PAGE:

60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 1---..;..;;.----1 PROCEDURE NO 2-GOP-201 ST. LUCIE UNIT 2 6.130 (continued)

8.

9.

ENSURE the second Main Feed Pump is ready to start in accordance with 2-NOP-09.01, Main Feedwater System Operation.

WARMUP the Heater Drain Pumps in accordance with 2-NOP-11.02, Heater Drain and Vents System Operation

10.

VERIFY proper operation of heater Drain and Vent system.

A.

B.

VERIFY proper heater levels.

VERIFY proper operation of normal and alt drain valves.

CAUTION The second Main Feed Pump should NOT be started until the second Condensate Pump is running and total feedwater flow is approximately 10,000 GPM.

11.

IF Condensate Polisher System is in service, THEN ENSURE that four polisher vessels are in service or as recommended by Chemistry.

12.

START the second Main Feed Pump in accordance with 2-NOP-09.01.

13.

When total feedwater flow is between 15,000 GPM and 20,000 GPM, Then:

A.

PLACE the second Main Feed Pump control switch in AUTO RECIRC.

B.

VERIFY the Recirc Valve CLOSES.

CAUTION The power ascension should be stopped if Main Feed Pump suction pressure decreases to less than 400 psiq.

6.131 VERIFY the Moderator Temperature Coefficient is within limits as specified in TS 3.1.1.4.

Date I Time _____

'--1 ___

6 55 of 69 INITIAL RE

(

REVISION NO PROCE DURE TITLE PAGE 60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 f---"':;"';~---;

PROCEDURE NO 2-GOP-201 S1. LUCIE UNIT 2 6.130 (continued)

8.

ENSURE the second Main Feed Pump is ready to start in accordance with 2-NOP-0901, Main Feedwater System Operation.

9.

WARMUP the Heater Drain Pumps in accordance with 2-NOP-11.02, Heater Drain and Vents System Operation

10.

VERIFY proper operation of heater Drain and Vent system.

A.

B.

VERIFY proper heater levels.

VERIFY proper operation of normal and alt drain valves.

CAUTION The second Main Feed Pump should NOT be started until the second Condensate Pump is running and total reedwater flow is approximately 10,000 GPM

11.

IF Condensate Polisher System is in service, THEN ENSURE that four polisher vessels are in service or as recommended by Chemistry.

12.

START the second Main Feed Pump in accordance with 2-NOP-09.01

13.

When total feedwater flow is between 15,000 GPM and 20,000 GPM, Then A.

PLACE the second Main Feed Pump control switch in AUTO RECIRC.

B.

VERIFY the Recirc Valve CLOSES.

CAUTION The power ascension should be stopped If Main Feed Pump suction pressure decreases to less than 400 psig.

6.131 VERIFY the Moderator Temperature Coefficient is within limits as specified in TS 3.1 14.

Date 1 Time _____

-'1 ____ _

6 55 of 69 INITIAL RE Jj (Jl o

REVISION NO PROCEDURE TITLE' PAGE.

60 REACTOR PLANT STARTUP - MODE 2 TO MODE 1 1----..;.;..----1 PROCEDURE NO 56 of 69 2-GOP-201 ST. LUCIE UNIT 2 INITIAL 6.132 ~6 When Reactor Power is at approximately 50% as indicated on the highest reading instrument. Then PERFORM the following:

1.

ENSURE PCV-08-808. Gland Steam \\0 HP Seal Stm, is CLOSED

2.

3.

CLOSE valve V0880? PCV-08-808 Bypass.

ENSURE both Turbine Cooling Water Pumps are in operation.

A.

CLOSE SB 13139, TCW Pumps Disc Crosstie Isol.

NOTE Margin improvements may be captured in a future reload PCMs. This will delete the requirement for a specific Nuclear Delt T Power Calibration at 50% Rower.

4.

VERIFY the specific stop at 50% power is NOT required to perform 2-0SP-69.01, Nuclear Delta T Power Calibration. in accordance with the current Reload PCM.

PCM _______ Date ____ _

NOTE If 2-0SP-69.01 is NOT required due to Reload PCM, then the following two substeps may be marked N/A.

5.

STOP the power ascension.

6.

§1 PERFORM a Nuclear/Delta T Power Calibration in accordance with 2-0SP-69.01, Nuclear and Delta T Power Calibration 6.133 When Reactor power is approximately 60%. as indicated by the higher of Calorimetric or NI Power, Then PERFORM the following:

1.

VERIFY proper heater levels.

2.

VERIFY proper operation of normal and alt drain valves.

6.134 When Turbine load is approximately 660 MW, Then PLACE the Heater Drain Pumps in service in accordance with 2-NOP-11.02, Heater Drain and Vents System Operation.

7 RE

(

REVISION NO PROCEDURE TITLE PAGE.

56 of 69 1--_-..:::.6,:..0 __

-iREACTOR PLANT STARTUP - MODE 2 TO MODE 1 PROCEOURE NO 2-GOP-201 ST. LUCIE UNIT 2 INITIAL 6.132 ~6 When Reactor Power is at approximately 50% as indicated on the highest reading instrument, Then PERFORM the following:

1.

ENSURE PCV-08-808, Gland Steam to HP Seal Stm, is CLOSED.

2.

CLOSE valve V08807, PCV-08-808 Bypass.

3.

ENSURE both Turbine Cooling Water Pumps are in operation A.

CLOSE S813139, TCW Pumps Disc Crosstie Isol.

NOTE Margin Improvements may be captured in a future reload PCMs. This will delete the requirement for a specific Nuclear Delt T Power Calibration at 50% power.

4.

VERIFY the specific stop at 50% power is NOT required to perform 2-0SP-69 01, Nuclear Delta T Power Calibration, in accordance with the current Reload PCM.

PCM ________ Date _____ _

NOTE If 2-0SP-69.01 IS NOT required due to Reload PCM, then the following two substeps may be marked N/A.

5.

STOP the power ascension.

6.

§,

PERFORM a NuciearlDelta T Power Calibration in accordance with 2-0SP-69 01, Nuclear and Delta T Power Calibration 6.133 When Reactor power is approximately 60%, as indicated by the higher of Calorimetric or NI Power, Then PERFORM the following:

1.

VERIFY proper heater levels.

2.

VERIFY proper operation of normal and alt drain valves.

6.134 When Turbine load is approximately 660 MW, Then PLACE the Heater Drain Pumps in service in accordance with 2-NOP-11.02, Heater Drain and Vents System Operation.

7 RE

REVIS'ON NO PROCEDURE TITLE PAGE 24A 190f75 BORON CONCENTRATION CONTROL PROCEDURE NO 2-NOP-0224 ST LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution NOTE An Operator Aid has been placed at RTG8-205 PNL "N". Any revision to this section of the procedure shall verify the validity of the Operator Aid and, if changes are necessary, a Label Request shall be initiated to incorporate these changes on a new Operator Aid placard.

The Operations Supervisor SHALL be notified and a CR submitted of any unexplained or unplanned Reactivity change in accordance with OPS Policy 534 (i.e., >5 deg Tcold change or >.5% power change).

If a Reactivity management issue occurs, refer to procedure ADM-09.11, Reactivity Management.

If constant dilution is desired then ensure ftow on FIC-221 OX is observable Engineering Assessment of FIC*2210X PMW Flow, shows that there could be an error up to -+/- 0.5 gpm, and the recommended minimum ftow rate is 2 gpm

1.

DODD ENSURE Section 3.0, Prerequisites is completed at least once per shift

2.

DODD ENSURE Section 40, Precautions I Limitations, has been reviewed at least once per shift.

3.

DODD

~2 ENSURE calorimetric power is less than 100.00% prior to any dilutions by obtaining a DCS calorimetric power.

4.

DODD DETERMINE the desired volume of primary water to be added.

5.

DODD PLACE the Makeup Mode Selector switch in MANUAL

6.

DODD ENSURE FIC-2210X, PMW Flow, is in MANUAL and REDUCE the controller output to ZERO.

7.

DODO ENSURE FIC*2210Y, Boric Acid Flow is in MANUAL and REDUCE the controller output to ZERO.

8.

0000 ENSURE either Primary Makeup Water Pump is running.

9.

0000 PLACE FCV*2210X, Primary Makeup Water Control Switch in Auto.

10.

0000 11 diluting to the VCT. Then OPEN V*2512, Reactor Makeup Water Stop Vlv

11.

0000 11 diluting to the Charging Pump suction, Then OPEN V*2525, Boron Load Control Valve.

8

0 A >>

0 A >>

(

~----.--------

REVIS'O"l NO PROCEDURE TITLE PAGE 24A BORON CONCENTRATION CONTROL 19 of 75 PROCEDURE NO 2-NOP-0224 ST LUCIE UNIT 2 6,5 Aligning for MANUAL Dilution NOTE An Operator Aid has been placed at RTGB-205 PNL "N". Any revision to this section of the procedure shall verify the validity of the Operator Aid and, if changes are necessary, a Label Request shall be initiated to Incorporate these changes on a new Operator Aid placard The Operations Supervisor SHALL be notified and a CR submitted of any unexplained or unplanned Reactivity change in accordance with OPS Policy 534 (i.e, > 5 deg Tcold change or >5% power change)

1.

2.

3.

4.

5.

6.

7.

8, 9,

10.

11.

If a Reactivity management Issue occurs, refer to procedure ADM-0911, Reactivity Management.

If constant dilution IS deSired then ensure fiow on FIC-2210X is observable Engineering Assessment of FIC-2210X PMW Flow, shows that there could be an error up to -+/- 0.5 gpm, and the recommended minimum fiow rate is 2 gpm DODD ENSURE Section 30, Prerequisites is completed at least once per shift DODD ENSURE SectIOn 40, Precautions / Limitations, has been reviewed at least once per shift.

DODD

~2 ENSURE calorimetric power IS less than 10000% prior to any dilutions by obtaining a DCS calorimetric power DODD DETERMINE the desired volume of primary water to be added.

DODD PLACE the Makeup Mode Selector switch in MANUAL DODD ENSURE FIC-2210X, PMW Flow, IS In MANUAL and REDUCE the controller output to ZERO.

DODD ENSURE FIC-2210Y, Boric Acid Flow is in MANUAL and REDUCE the controller output to ZERO.

DODD ENSURE either Primary Makeup Water Pump IS running DODD PLACE FCV-2210X, Primary Makeup Water Control Switch In Auto.

DODD 11 diluting to the VCT. Then OPEN V-2512, Reactor Makeup Water Stop Vlv DODO 11 diluting to the Charging Pump suction, Then OPEN V-2525, Boron Load Control Valve 8

35 A

P

0

'V A

P

......* ----...... -.-.--------~

REVISION NO PROCEDURE TITLE:

PAGE:

20 of 75 BORON CONCENTRATION CONTROL 24A PROCEDURE NO 2-NOP-02.24 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued)

CAUTION To preclude lifting the VCT relief valve while using V*2525, do NOT allow PMW flowrate to exceed the running Chargingpump(sJ caJJ.acity.

12.

DODO ADJUST FIC*2210X PMW Flow in AUTO or MANUAL to desired flowrate (and If using V*2525 do NOT exceed the flowrate for the number of running Charging Pumps).

13.

0000 MAINTAIN VCT pressure less than or equal to 30 psig by opening and closing V2513, VCT Vent, as needed.

14.

0000 if necessary to maintain the desired VCT level, Then DIVERT the letdown flow to the Waste Management System by placing V2500, VCT Divert Valve, in the WMS position:

A.

0 0 0 0 ENSURE V2500 VCT Divert Valve indicates OPEN.

B.

0 0 0 0 When the desired VCT level is reached, PLACE V2500 in AUTO.

C.

0 0 0 0 ENSURE V2500 indicates CLOSED.

15.

0 0 0 0 When the desired amount of primary water has been added, Then CLOSE FCV*2210X, Primary Makeup Water 16, DODO if V*2512 Reactor Makeup Water Stop Vlv was opened, Then PLACE V*2512 in CLOSE and ENSURE it indicates CLOSED.

17.

00 0 0 if V*2525 Boron Load Control Valve was opened, Then PLACE V-2525 in CLOSE and ENSURE it indicates CLOSED.

18.

0000 ENSURE FIC*2210X, PMW Flow controller is in MANUAL and RECUCE output to MINIMUM

19.

DODO MONITOR for any abnormal change in Tave

20.

0 0 0 0

§,

RECORD on Data Sheet 1, Boratlon / Dilution Log, the number of gallons of Primary Makeup Water added as indicated on FQI*2210X, PMW Flow Totalizer.

21.

0 0 0 0 if additional dilutions are desired, or if the expected changes to Tave or Boron concentration are NOT achieved, Then REPEAT Steps 65.1 through 6.5.20

ij

~--------------------------------------------------________ _J ~

p 9

(

REVISION NO PROCEDURE TITLE PAGE 20 of 75 BORON CONCENTRATION CONTROL 24A PROCEDURE NO 2-NOP-0224 ST. LUCIE UNIT 2 6,5 Aligning for MANUAL Dilution (continued)

CAUTION To preclude lifting the VCT relief valve while using V-2525, do NOT allow PMW flowrate to exceed the running Charging pump(s) capacity.

12.

DODD ADJUST FIC-2210X PMW Flow In AUTO or MANUAL to desired flowrate (and If using V-2525 do NOT exceed the flowrate for the number of running Charging Pumps) 13, DODD MAINTAIN VCT pressure less than or equal to 30 psig by opening and closing V2513, VCT Vent, as needed.

14, DODD 11 necessary to maintain the desired VCT level, Then DIVERT the letdown flow to the Waste Management System by placing V2500, VCT Divert Valve, in the WMS position A,

DODD ENSURE V2500 VCT Divert Valve indicates OPEN B,

0000 When the deSifed VCT level is reached, PLACE V2500 In AUTO C,

DODD ENSURE V2500 indicates CLOSED 15, DODD When the desired amount of primary water has been added, Then CLOSE FCV-2210X, Primary Makeup Water 16, DODD 11 V-2512 Reactor Makeup Water Stop Vlv was opened, Then PLACE V-2512 in CLOSE and ENSURE it indicates CLOSED 17, DODD 11 V-2525 Boron Load Control Valve was opened, Then PLACE V-2525 in CLOSE and ENSURE it Indicates CLOSED.

18, 0000 ENSURE FIC-2210X, PMW Flow controller is In MANUAL and RECUCE output to MINIMUM 19, DODD MONITOR for any abnormal change in Tave 20, DODD §1 RECORD on Data Sheet 1, Boration I Dilution Log, the number of gallons of Primary Makeup Water added as Indicated on FQI-2210X, PMW Flow Totalizer 21, DODD 11 additional dilutions are desired, or if the expected changes to Toye or Boron concentration are NOT achieved, Then REPEAT Steps 6 5.1 through 6.5.20 9

u A P

REVISION NO PROCEDURE TITLE PAGE:

24A PROCEDURE NO BORON CONCENTRATION CONTROL 21 of 75 2*NOp*0224 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued)

22.

00 0 0

)J it is desired to restore the Boron Concentration Control system to the Automatic Mode of Operation. Then REFER to Section 6.1. Aligning for Automatic VCT Makeup.

23.

After review by the Unit Supervisor is complete, this document may be discarded END OF SECTION 6.5 10

(

rlEv'SION NO PROCEDURE TITLE PAGE' 24A BORON CONCENTRATION CONTROL 21 of 75 PROCEDURE NO 2-NOP-02.24 S1. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued)

22.

o 0 0 0 U it is desired to restore the Boron Concentration Control system to the Automatic Mode of Operation, Then REFER to Section 6.1, Aligning for Automatic VCT Makeup.

23.

After review by the Unit Supervisor is complete, this document may be discarded.

END OF SECTION 6.5 10

REVISION NO PROCEDURE TITLE PAGE 1--_---.,;9;,.;B;."...-_--i REACTOR OPERATING GUIDELINES DURING STEADY PRocmURE NO STATE AND SCHEDULED LOAD CHANGES 6 of 15 2-GOP-101 ST. LUCIE UNIT 2 6.0 INSTRUCTIONS 6.1 Power Level Escalations NOTE CEAs should be above the Long-term Steady State Insertion Limit (102 inches withdrawn on Group 5) before reaching 20% core power and at a position to begin controlling ASI at the ESI between 20% and 50% power.

Refer to NOP-1 00.02, Axial Shape Index Control, for further guidance.

1.

As Main Generator loading commences, MAINTAIN T -avg at T -ref by:

A.

CEA withdrawal in Manual Sequential.

AND/OR B.

Boron concentration changes in accordance with 2-NOP-02.24, Boron Concentration Control.

2.

At or above 50% power A.

All planned reactivity additions should be made by boration or dilution in accordance with 2-NOP-02.24, Boron Concentration Control.

B.

USE CEAs for ASI control, CONSIDER the reactivity effect of CEAs when adjusting AS!.

C.

REFER to NOP-1 00.02, Axial Shape Index Control, for specific instructions regarding ASI control during power escalations.

D.

111 When raising Reactor power, all power escalation rates should be within the following fuel preconditioning guidelines:

/category Max Core Power Escalation Rate Max Equivalent Turbine !

Generator Load Rate j

r'- f-- -- 3%/HR at or above 15% Power

.42 MW/MIN 2'

"-3%iHR above 50% Power

.42 MW/MIN

. --.-+-----'----'-'--'..:.:..:..:.-'-----1

~_.?

20%/HR above 50% Power i

2.80 MW/MIN

~

4 30%/HR above 50% Power i

4.2 MW/MIN 11

(

REVISION NO PROCEDURE TITLE PAGE 6 of 15 REACTOR OPERATING GUIDELINES DURING STEADY i-P-RO-C-E-D-UR-E-N-O------1 STATE AND SCHEDULED LOAD CHANGES 9B 2-GOP-101 ST. LUCIE UNIT 2 6.0 INSTRUCTIONS 6.1 Power Level Escalations NOTE CEAs should be above the Long-term Steady State Insertion Limit (102 inches withdrawn on Group 5) before reaching 20% core power and at a position to begin controlling ASI at the ESI between 20% and 50% power Refer to NOP-1 00.02, Axial Shape Index Control, for further guidance.

1.

As Main Generator loading commences, MAINTAIN T-avg at T-ref by A.

CEA withdrawal in Manual Sequential.

AND/OR B.

Boron concentration changes in accordance with 2-NOP-02.24, Boron Concentration Control.

2.

At or above 50% power A.

All planned reactivity additions should be made by boration or dilution in accordance with 2-NOP-02.24, Boron Concentration Control.

B.

USE CEAs for ASI control, CONSIDER the reactivity effect of CEAs when adjusting ASI.

C.

REFER to NOP-1 00.02, Axial Shape Index Control, for specific instructions regarding ASI control during power escalations.

D.

~1 When raising Reactor power, all power escalation rates should be within the following fuel preconditioning guidelines:

fcategory Max Core Power Escalation Rate GMax EqtUlvaLlendt TRurtbine I enera or oa a e I

1*_---.-.---

~---

I i

1 3%/HR at or above 15% Power

.42 MW/M1N i-3--~--,=1;:1~~ aabb';;;' 55%~;,PpOo:e;c-1 2~O ~~~

~N I

4 I

30%/HR above 50% P0'Ner i

4.2 MW/MIN i

11

REVISION NO PROCEOURE TITLE PAGE 9B REACTOR OPERATING GUIDELINES DURING STEADY I-P-RO-C-E-O-UR....:E:..;N;;..O-.. ---I STATE AND SCHEDULED LOAD CHANGES 7 of 15 2-GOP-101 ST. LUCIE UNIT 2 6.1 Power Level Escalations (continued)

2.

D.

(continued)

NOTE To determine the correct category for a power escalation, Appendix B, Fuel Preconditioning Guidelines Worksheet, may be used. Contact Reactor Engineering if further assistance is required.

Category Definitions:

1.

Category 1:

a.

INCREASE in power to a level which has not been previously sustained in this core cycle for at least 72 continuous hours.

2.

Category 2:

a.

INCREASE in power following 30 continuous days or more at a power level less than 70% of rated thermal power.

OR

b.

INCREASE in power to a level which has not been maintained for more than 3 continuous hours during the past 60 days.

3.

Category 3:

a.

INCREASE in power to a level which has not been maintained for 3 continuous hours or more during the past 8 days.

4.

Category 4:

a.

INCREASE in power to a level which has been maintained for 3 continuous hours or more during the past 8 days.

3.

!f available, Then ENSURE two Charging Pumps are operating.

If necessary, START an additional Charging Pump in accordance with 2-NOP-0202, Charging and Letdown.

4.

PLACE the Pressurizer on recirculation in accordance with Appendix A, Pressurizer Recirculation GUidelines.

5.

CONTINUE to load the Main Generator in accordance with 2-GOP-201,

Reactor Plant Startup, Mode 2 to Mode 1.

END OF SECTION 6.1 12

(

REVISION NO PROCEDURE TITLE PAGE 9S REACTOR OPERATING GUIDELINES DURING STEADY I-P-R-OC-E-D-U-R.::..E;;:.NO----l STATE AND SCHEDULED LOAD CHANGES 7 of 15 2-GOP-101 ST. LUCIE UNIT 2 6.1 Power Level Escalations (continued)

2.

D.

(continued)

NOTE To determine the correct category for a power escalation, Appendix S, Fuel Preconditioning Guidelines Worksheet, may be used. Contact Reactor Engineering If further assistance is required.

Category Definitions

1.

Category 1.

a.

INCREASE in power to a level which has not been previously sustained in this core cycle for at least 72 continuous hours.

2.

Category 2

a.

b.

INCREASE in power following 30 continuous days or more at a power level less than 70% of rated thermal power.

OR INCREASE in power to a level which has not been maintained for more than 3 continuous hours during the past 60 days.

3.

Category 3

a.

INCREASE in power to a level which has not been maintained for 3 continuous hours or more during the past 8 days.

4.

Category 4:

a.

INCREASE in power to a level which has been maintained for 3 continuous hours or more during the past 8 days.

3.

11 available, Then ENSURE two Charging Pumps are operating.

If necessary, START an additional Charging Pump in accordance with 2-NOP-0202, Charging and Letdown.

4.

PLACE the Pressurizer on recirculation in accordance with Appendix A, Pressurizer Recirculation Guidelines.

5.

CONTINUE to load the Main Generator in accordance with 2-GOP-201, Reactor Plant Startup, Mode 2 to Mode 1 END OF SECTION 6.1 12

Appendix D

. Op Test No.

II Event Descnption:

I' Operator Action Form ES-D-2 1

Scenario #

7 Event #

_____ Page _5_ of...;2;.;.0--11 Raise power to approximately 45% and start 2C Condensate pump. Perform up power I'~~====~~~~==y-==================-.-~~--~~~----~--==--~I

]I

.~_-~~P~o~s~iti~on~~=====-____==~A~~lic~a~nt~'s~A~c~tio~n~s~o~r~Be~h~a~vi~o~r============~

Booth Operator Instructions:

Indications Available:

I f------*--*-*-~----_,_-----------------------__j RO Control Rx power and ASIIAW 2-GOP-1 01 Rx Operating Guidelines step 6.1 (attached page_11-12_)

i

,-... ----+------+----------------------------1

!,.--. -.--+--------~--------.----------------__i Program or power Increase at a rate IA

-101 I

I step 6, 1.2.D Category 4.

I Set reference by ensuring REF selected and then I

BOP depress desired MW endpoint, select ENTER I I DEH f W2 GOP

Depress LOAD RATE type in desired load rate and I

select ENTER Depress GO pushbutton i

---.. ----t----

0-I I

I,

Communicate with NPO, make plant announcement, and start I

2C Condensate pump lAW 2-NOP-12.03 Condensate System Operation, Appendix F (attached page_14_). When directed, notify NOP to close FCV-12-3C 2C recirc, I

Communicate with NPO and start the 2B Main Feedwater I

pump lAW 2-NOP-09.01 (attached page_15_) Main I

Feedwater System

---+-

~

}-- --

I,

--~--

I

.~-.

I

(

Appendix D Operator Action Form ES-D-2 Op Test No.

Ii Event Description

i Scenario #

7 Event #

Page

_5 _of ~

Raise power to approximately 45% and start 2C Condensate pump. Perform up II power I

1 fl.

II L Position A

licant's Actions or Behavior Booth Operator Instructions:

Indications Available:

f.. -.---.-

-~---,,------------------------

RO BOP

! Control Rx power and ASI lAW 2-GOP-1 01 Rx Operating I Guidelines step 6.1 (attached page_11-12_l I

, Program DEH for power increase at a rate lAW 2-GOP-101 step 6.1.2.D Category 4.

II Set reference by ensuring REF selected and then depress desired MW endpoint, select ENTER I

Depress LOAD RATE type in desired load rate and I

select ENTER Depress GO pushbutton I

l I Communicate with NPO, make plant announcement, and start

'I:

i 2C Condensate pump lAW 2-NOP-12.03 Condensate System I Operation, Appendix F (attached page_14_l* When directed,

--i--- ___ ~_tify NOP to close FCV-12-3C 2C recirc.

I

+

I Communicate with NPO and start the 2B Main Feedwater1 I pump lAW 2-NOP-09.01 (attached page_15_l Main 1,1, i

I Feedwater System

. ----*----1----*

I

- --.----------i

--+:----- --+-I-------------------------------.j

.. __ +~-I--i ---

-+

i

.----------1-***l

___ _-.-L __________ _

REV!SION NO PROCEDURE TITLE PAGE 3

CONDENSATE SYSTEM OPERATION 39 of 85 PROCEDURE NO 2-NOP-1203 ST. LUCIE UNIT 2 APPENDIX F 2C CONDENSATE PUMP START WITH THE CONDENSATE HEADER PRESSURIZED (Page 4 of 4)

CHECK

14.

OPEN FCV-12-3C, 2C Condensate Pump Recirc in preparation for pump start.

A.

PLACE the recirc handswitch for FCV*12-3C, 2C Condensate Pump Recirc in the OPEN position.

8.

VERIFY FCV-12-3C, 2C Condensate Pump Recirc is OPEN.

15.

AFTER the Recirc Valve has been opened for at least 10 minutes, START the 2C Condensate Pump locally or at RTGB-202.

16.

VERIFY the flow on FIC-12-1, Condensate Recirc to Cndsr, controller remains approximately 10,000 GPM (50% of scale).

17.

CLOSE recirc valve for the 2C Condensate Pump.

A.

PLACE the handswitch for FCV-12*3C, 2C Condensate Pump Recirc in the CLOSED position.

B.

VERIFY FCV-12-3C, 2C Condensate Pump Recirc is CLOSED.

18.

SECURE Condensate Transfer Pump,

19.

CLOSE V12494 - Condensate Transfer Pump Discharge Valve.

NOTE The idle condensate pump seal water isolation valve should be opened to minimize potential air intrusion when vacuum is established in the main condenser.

20.

THROTTLE OPEN the individual seal water supply valve to the idle condensate pump as per US I SM direction:

1-COMPONENT POSITION CHECK

! V12242, 2A Condensate Pump Seallsol THROTTLE OPEN lY.2.?~45. 2B Condensate Pump Seal Isol THROTTLE OPEN END OF APPENDIX F 14

(

PROCEDURE TITLE PAGE 39 of 85 CONDENSATE SYSTEM OPERATION 3

PROCEDURE NO 2-NOP-1203 ST. LUCIE UNIT 2 APPENDIX F 2C CONDENSATE PUMP START WITH THE CONDENSATE HEADER PRESSURIZED (Page 4 of 4)

14.

OPEN FCV-12-3C, 2C Condensate Pump Recirc in preparation for pump start.

A, PLACE the recire handswiteh for FCV*12-3C, 2C Condensate Pump Recifc in the OPEN position

8.

VERIFY FCV-12-3C, 2C Condensate Pump Recifc is OPEN

15.

AFTER the Recirc Valve has been opened for at least 10 minutes, START the 2C Condensate Pump locally or at RTGB-202.

16.

VERIFY the flow on FIC-12-1, Condensate Recirc to Cndsr, controller remains approximately 10,000 GPM (50% of scale).

17, CLOSE recirc valve for the 2C Condensate Pump.

A.

B.

PLACE the handswitch for FCV-12-3C, 2C Condensate Pump Recirc in the CLOSED position.

VERIFY FCV-12-3C, 2C Condensate Pump Recire is CLOSED,

18.

SECURE Condensate Transfer Pump.

1 g, CLOSE V12494 - Condensate Transfer Pump Discharge Valve.

NOTE The Idle condensate pump seal water isolation valve should be opened to minimize potential air intrusion when vacuum is established in the main condenser

20.

THROTTLE OPEN the individual seal water supply valve to the idle condensate pump as per US I SM direction:

CHECK i----------------C-o-M~P-O-N-E-N-T----------------'Ii

---P-O--SI-T-IO-N----.-C~H-E-C-K~

r V12242, 2A Condensate Pump Seallsol I THROTTLE OPEN ly~?245, 28 Condensate Pump_S_e_a_I_ls __

o_1 ____________________ LT_H_R_O_T_~~~_O_P_E_~_'___ ____ _____'i END OF APPENDIX F 14

REVISION NO PROCEDURE TITLE PAGE:

5 MAIN FEEDWATER SYSTEM OPERATION 18 of 31 PROCEDURE NO 2*NOP*09.01 ST. LUCIE UNIT 2 4.5 Start 28 Main Feed Pump as the Second MFW Pump (continued)

13.

At RTG8-202, ENSURE the following initial conditions exist:

MV-09-2, PUMP 28 DISCHARGE VALVE, CLOSED FCV-09-1 B2, PUMP 2B DISCH RECIRC VALVE, CLOSED Pump 2B Aux Oil Pump RUNNING Two condensate pumps are IN SERVICE

14.

At RTGB-202, START Feedwater Pump 2B as follows:

A.

PLACE the FEEDWATER PUMP 28 control switch in START and then to the RECIRC position.

B.

VERIFY the following valves are OPEN:

MV-09-2, PUMP 2B DISCHARGE VALVE FCV-09-182, PUMP 28 DISCH RECIRC VALVE C.

VERIFY PUMP 28 AUX OIL PUMP is OFF.

D.

VERIFY all 28 MFW pump related annunciator alarms on Annunciator Panel G (RTGB-202) are CLEAR.

15.

IF the 28 MFW Pump shows evidence of unusual vibration, heat, noise or other malfunctions, THEN STOP 28 MFW Pump.

15

---.~-.-.. ---.-~--... ----... -~

.. -. ---... --~---.. -

... ~

REV'SION NO PROCEDURE TITLE PAGE 5

MAIN FEEDWATER SYSTEM OPERATION 18 of 31 PROCEDURE NO 2 NOP*09 01 ST LUCIE UNIT 2 4.5 Start 2B Main Feed Pump as the Second MFW Pump (continued) 13, At RTGB*202, ENSURE the following initial conditions exist MV-09-2, PUMP 28 DISCHARGE VALVE, CLOSED FCV-09-1 B2, PUMP 2B DISCH RECIRC VALVE, CLOSED Pump 2B Aux Oil Pump RUNNING Two condensate pumps are IN SERVICE 14, At RTGB*202, START Feedwa\\er Pump 2B as follows:

A, PLACE the FEEDWATER PUMP 28 control switch in START and then to the RECIRC position, B.

VERIFY the following valves are OPEN MV-09-2, PUMP 2B DISCHARGE VALVE

(

FCV-09-182, PUMP 28 DISCH RECIRC VALVE C.

VERIFY PUMP 28 AUX OIL PUMP is OFF D,

VERIFY all 26 MFW pump related annunciator alarms on Annunciator Panel G (RTG8-202) are CLEAR.

15, IF the 26 MFW Pump shows eVidence of unusual vibration, heat, noise or other malfunctions, THEN STOP 2B MFW Pump, 15

Appendix D Operator Action Form ES-D-2

, Op Test No_

1 Scenario #

7 Event #

_2 _____ Page _6_ of

...;2~0--l1

, Event

Description:

I~

Time Position TIC-2223 Letdown temperature controller malfunction. V2520 ion exchanger bypass does not close.

Ap licant's Actions or Behavior

! Booth Operator Instructions: Trigger TIC-2223 malfunction when directed 1----... -- --------------------------------j i Indications Available: Annunciator M-10 CVCS Ion Exchanger Temp High RO I

. _--------+-------

I

~ ---,.

~.--------+

I I r-r I

I L

i I

--T I

SRO 0 ** -

I I

Identifies increasing temperature on TIC-2224. When temperature alarm annunciates identifies V2520, ion exchanger bypass valve did not close. Manually places V2520 to the bypass reset position.

Observes FIS-14-6 'Letdown Hx Flow' increasing (CCW flow to LD heat exchanger)

Places TIC-2223 to manual. Controls letdown temperature in

! manual to less than alarm setpoint.

Places V2520 to the AUTO position when directed.

Implements 2-0NP-02.03 Charging and Letdown step 6.0.14 (attached page_17_)

Directs V2520 ion exchanger bypass placed to the Bypass Reset position. Step 6.0.14.A

Directs TIC-2223 placed in manual. Step 6.0.14.B I

I I

I

,._-------+-----+---------------------j I

i Direct placing V2520 back to auto when temperature has been lowered in manual control.

+-----+-------------------------1 i

Contact SM and IC

, ---- ----- ----1-----+-.

i

--.----+------t-----------------.

i

,6 l

Appendix 0 Operator Action Form ES-D-2 f------~-~~~~~~~~~--~~~~~~~~~~~~~----~--~~~~~

_2 _____ Page 6

of 20 I

Op Test No.

Event

Description:

Scenario #

7 Event #

TIC-2223 Letdown temperature controller malfunction. V2520 iO=hang:-l 1

bypass does not close.

I

~------------ -

L __ T~~1ie-L Position Ap licant's Actions or Behavior

Booth Operator Instructions: Trigger TIC-2223 malfunction when directed I Indications Available: Annunciator M-10 CVCS Ion Exchanger Temp High I

Identifies increasing temperature on TIC-2224. When RO I temperature alarm annunciates identifies V2520, ion exchanger i

! bypass valve did not close. Manually places V2520 to the I

! bypass reset POSition.

!- -.----~---~---___1----'------

Observes FIS-14-6 'Letdown Hx Flow' increasing (CCW flow to

----1--

I LD heatexchanger) d

Places TIC-2223 to manual. Controls letdown temperature in I

__ L~ I manual to less than alarm setpoin!.

_.1 I Places V2520 to the AUTO position when directed.

L

- J Ii Implements 2-0NP-02.03 Charging and Letdown step 6.0.14 (attached page_17_)

+-----+

+O~~~ts V2520 ion exchanger bypass placed to the Bypass I

Reset position. Step 6.0.14.A

______ J

---_._------;--"--+---------------------------1 Directs TIC-2223 placed in manual. Step 6.0.14.B

_---.,,-------.-- -------f------ -----------------------1

+-----+------------------------~

Direct placing V2520 back to auto when temperature has been.

lowered in manual control.

I I

rC~-ntact SM and IC---

I

+------j------- -----------------------1!

I

~-~.

i

.. -----~------------.-+----

*1~--------+-----

J

/6

REVISION NO PROCEOURE TITLE PAGE.

15B CHARGING AND LETDOWN 13 of 26 PROCEOURE NO 2-0NP-0203 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS 14, VERIFY TIC-2223 is responding 14, as expected. 11 Letdown Temperature Control is malfunctioning, Then PERFORM the following:

A.

BYPASS Letdown Ion Exchanger(s) by placing V2520 Ion Exchanger Bypass Valve to the BYPASS RESET position S, PLACE TIC-2223 in MANUAL S,

Dispatch an Operator to and ADJUST letdown Bypass TCV-2223 by temperature to setpoint.

performing the following:

1, THROTTLE OPEN SB14254, TCV-2223

Bypass,

2.

CLOSE SB14248, TCV-2223 Upstream Isol.

3.

ADJUST S814254 as directed by the SM /

US to Control Letdown Temperature.

C. 11 Letdown Temperature is stable at the desired temperature, Then PLACE the letdown Ion Exchanger(s) in service by placing V2520 Ion Exchanger Bypass Valve to the AUTO position.

END OF SECTION 6.0 17

~~~~--

---"---~--."-------

RE VISION "10 PROCEDURE TITLE PAGE 158 CHARGING AND LETDOWN 13 of 26 PROUDURE NO 2-0NP-0203 ST LUCIE UNIT 2 6"0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS 14, VERIFY TIC-2223 is responding

14.

as expected, 11 Letdown Temperature Control is malfunctioning, Then PERFORM the following A,

BYPASS Letdown Ion Exchanger( s) by placing V2520 Ion Exchanger Bypass Valve to the BYPASS RESET position

8. PLACE TIC-2223 in MANUAL B.

Dispatch an Operator to and ADJUST letdown Bypass TCV-2223 by temperature to setpoint.

performing the following

1.

THROTTLE OPEN SB14254, TCV-2223

Bypass,

2.

CLOSE SB14248, TCV-2223 Upstream Isol.

3.

ADJUST S814254 as directed by the SM I US to Control Letdown Temperature C"

11 Letdown Temperature is stable at the desired temperature, Then PLACE the letdown Ion Exchanger(s) in service by placing V2520 Ion Exchanger Bypass Valve to the AUTO position END OF SECTION 6.0 17

c Appendix 0 Operator Action Form ES-O-2 I-I Op Test No,:

Scenario #

7 Event #

_3 ______ Page 7

of 20 I_~v_ent Oescri ption:

RWT LIS 07-28 fails low, Time Position Applicant's Actions or Behavior i Booth Operator Instructions: Trigger LIS 07-2B fail low when directed I

I Indications Available: Annunciator S-19 RWT Level RAS Channel Trip I

RO Identifies channel B RWT level LIS 07-2B failed low, I

SRO Implements 2-0NP-99,01 Loss of Tech Spec Instrumentation step 6,3,2,B,1, (attached page_19_)

I

+-

Implements T,S, 3,3,2 Action 19, Within one (1) hour places the i

I T,S, SRO I failed channel In bypass or tnpped condition, Restore within 48

hours, I

1------*_- -----t I

BOP

, Bypassed ESFAS channel B for RAS per step 6,3,2,B, 1 (page_19_)

i C" ----.--~----+------------------------_l Review ARP for annunciator S-1 9

,----- -,,----+------1'--------------------------1

,,--------+------!---------------------------1 r---------+------+---------------------------4 r--------

1---------,--

f------+-------------------------+

.-----.----+------+----------------------------4

(

I' II Appendix D Operator Action Form ES-D-2 il Op Test No.'

1 Scenario #

7 Event #

3 Page

1 7

Of~

II Event Description RWT LIS 07-2B fails low.

,---- !lm~Liii:3ltiSiiCJI Applicant's Actions or Behavior il i Booth Operator Instructions: Trigger LIS 07*2B fail low when directed Indications Available: Annunciator S-19 RWT Level RAS Channel Trip I

__ =_.------:===_R-_-O~~~:l_--1 d~e~n~t-i_fi-e_-s c-h_a=n=n_e_I_B_RWT level LIS 07-28 failed low.--~

I SRO Implements 2-0NP-99.01 Loss of Tech Spec Instrumentation I

step 6.3.2.B.1. (attached page_19_l i

Implements T.S. 3.3.2 Action 19. Within one (1 l hour places th8i i T.S. SRO i failed channel in bypass or tripped condition. Restore within 48 i

---.-- __ 1 ______ ~Q2.LJrs.

i I

I i-** '--1'---

I BOP

Bypassed ESFAS channel B for RAS per step 6.3.2.B.1 I

I (page_19_l

.. -..------~-

I

~_ : ---4 Review ARP for a_n_n_un_c_i_at_o_r_S_-_19 _______. ______ _

I I

I

._".. _-!------+._-------

~

I

--+1---------*---

--l

~- ----.----t------~-------------------

.. ------.j I

I

-------i l

f---------------

I i

~------.-_l_---

-+1 ______ ---------------- _... _.""

1 1 i -

I

---.---.. - --+--.. ---.--t------------ ---------------;

I

.--~- ------

I,,, VISION NO PROCEDURE TITLE PAGE_

14 of 37 LOSS OF TECH SPEC INSTRUMENTATION 21 PROCEDURE NO 2-0NP-99.01 ST. LUCIE UNIT 2 6.3 ESFAS Channel Malfunction (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

2.

(continued)

2.

(continued)

CAUTION The ESFAS keyswitch and bistable trip unit to which it applies do NOT, in some instances, directly line up. It is necessary to verify the labels of the bypass key, key switch, and actuation trip unit being placed in Bypass to ensure that the correct trip unit is bypassed.

NOTE RWT level indications are covered by Tech Spec 3.3.2, Table 3.3.-3.

ESFAS cabinet door key, key 114, is required for bypassing ESFAS.

B.

Refueling Water tank Level instrumentation indication LlS-07*2A / B / C / D.

19 B.1 PERFORM ONE of the following:

1.

BYPASS the affected RAS channel using key 131.

2.

PLACE the affected ESFAS trips units in TRIP in accordance with Appendix A, Placing Trip Units in Trip.

(

PROCEDURE TITLE PAGE 21 LOSS OF TECH SPEC INSTRUMENTATION P'lOCE OURE NO 14 of 37 2*0NP*99.01 ST. LUCIE UNIT 2 6.3 ESFAS Channel Malfunction (continued)

2.

INSTRUCTIONS CONTINGENCY ACTIONS (continued)

2.

(continued)

CAUTION The ESFAS keyswitch and bistable trip unit to which It applies do NOT, in some Instances, directly line up It is necessary to verify the labels of the bypass key, key switch, and actuation trip unit being placed in Bypass to ensure that the correct trip unit is bypassed.

NOTE RWT level indications are covered by Tech Spec 3.3.2, Table 3.3.-3.

ESFAS cabinet door key, key 114, is required for bypassing ESFAS.

B.

Refueling Water tank Level instrumentation indication LlS-07*2A I B I C I D.

19 B.1 PERFORM ONE of the following.

1.

BYPASS the affected RAS channel using key 131.

2.

PLACE the affected ESFAS trips units in TRIP in accordance with Appendix A, Placing Trip Units in Trip.

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

7 Event #

4 Page 8 of 20 Event

Description:

FCV-2210X controller output fails high.

Time Position A

licant's Actions or Behavior

Booth Operator Instructions: Trigger FCV 221 OX fail when directed

! When IC called, state it will be a few minutes before we can investigate.

~--------------------------------------I

! Indications Available:

NOTE: no alarms with failure. Flow will initially rise to 150 gpm then stabilize at 93 gpm. (There is not procedure guidance for this failure)

I RO Identifies maximum dilution due to controller failure.

. ---.------t-----t----------------------~___1 I

I i

.-----~------

I Closes V2525 OR place FCV-221 OX to close when directed.

I i

~

Monitors Reactor power

[

- -----------J I

I

+

~......*

j i

8RO

+-_._-----

I

t--

I,

i

~.

r---- --- -

BOP

._-----+

i 1"'-

~---+---

L..

I I

, Direct V2525 closed or FCV-2210X to close.

Directs stopping power ascension I

I Contacts IIC to investigate controller failure I

Notifies 8M Places turbine on hold as directed.

I I I I

(

Event Description FCV-2210X controller output fails high.

Applicant's Actions or Behavior Booth Operator Instructions: Trigger FCY 2210X fail when directed i When IC called, state it will be a few minutes before we can investigate.

I

, Indications Available:

NOTE: no alarms with failure. Flow will initially rise to 150 gpm then stabilize at 93

gpm. (There is not procedure guidance for this failure)

.------*-L RO I Identifies maximum dilution due to controller f_a~ilu_r~e_._~

-=:--~ -~Io:es V2525 OR place FCV-2210X 10 close when direcled.

+-------~.-" --+------

I

.----1 Monitors Reactor power I

~--- ~~---~~~--=----+----------------11 8RO Direct V2525 closed or FCV-221 OX to close, 1

t--

,~~=~~~~=----

Directs stopping power ascensio~ ___________

_____i

~:---=--J _ -_ _ _

I Co nla cIs lie; t;;- inve s lig ale co n lroll er failure I

--+

i i

! Notifies 8M

.--------------.. ----~. ~-~ --I~

---~Bop-~I-Places turbine on hold as directed.

i

.~-----------L --.

I I

I!

~----___t_----_+------------------------------

r----~---L--------___+-~---~---*------------*---~------I

t-------r-------------- -------------------j

~ ----'--------------___ ~_~

___________ ~

_____ J

Appendix D Operator Action Form ES-O-2 r-----.

it Ii Op Test No 1

II Event oescnptlo~

Scenario #

7 Event #

_5=--____ Page _9_ of...;2;.;;.0 __

1 RIM 26-61 fails high. CROAI valve FCV-25-16 trips on overload. HVE-13A does not start. When HVE-13A is manually started, fan trips.

'I II

~G Position A

licant's Actions or Behavior I Booth Operator Instructions:

Trigger RIM 26-61 fails high when directed r-------

Indications Available: PC-11 alarm. OAI 501 and 503 indicate RED Annunciator V-22 CNTL Room Isol FCV-25-14/16 OVRLD/OVRD I

BOP

Responds to PC-11 alarm. Identifies OAI 501 and 503 in high, J

high alarm.

.. -***-.. ---.. -I~-+--I' -

~..... __.. _. -----..1 _____

L. --------------------------1 i NOTE: Because HVE-13A did not start, dampers D-17A and D-18 did not open. They

will momentarily open then close when HVE-13A is started then trips.

,~-l_S_RO -+I=--+-=::=====~~::::::~::: __

~I

~-.. -.. '=-~l*---

I Directs HVE-13A started per step 2. Determines one train of

CREACS has failed.

~.----.---+-----,---------------------------1

....... -....... ---t----... --+------------------------j I T.S. SRO ilmplement T.S. 3.7.7 (CREACS) Action B. Restore within 24

---~---.=l hours.

I i

i

]

_.. _+

BOP I Perform steps from 2-0NP-25.02, "Ventilation Systems" when I directed. (attached page 22-25)

~.... ---.... --... -.-.--.---... --.---------------------____o Identifies Control room recirc. initiated on A train but HVE-13A BOP did not auto start and FCV-25-16, north OAI isolation valve has tripped.

... ---1-------+-------------------------1 I

I'

Attempts to start HVE-13A when directed. Identifies HVE-13A

~----.

T ------t_tr_iP_s_. __________________________ ~

~ ___._ *. __._ *. ___

I

(

Appendix D Operator Action Form ES-D-2

[ Op Test No 1

II Event Description Scenario #

7 Event #

_5 _____ Page _9_ of

_2.;;.;O~-11 RIM 26-61 fails high. CROAI valve FCV-25-16 trips on overload. HVE-13A does not start. When HVE-13A IS manually started, fan trips.

[-- -r:1.rT18"::=J Position A

licant's Actions or Behavior l ~_~th Operator Instructions:

Trigger RIM 26-61 fails high when directed. __

i

Indications Available: PC-11 alarm. OAI 501 and 503 indicate RED Annunciator V-22 CNTL Room Isol FCV-25-14116 OVRLDIOVRD i,

1,

-~-~~~.-~

. Responds to PC-11 alarm. Identifies OAI 501 and 503 in high, I'

Ihi~_

i BOP i

---j--'-'

NOTE Because HVE-13A did not start, dampers D-17 A and D-18 did not open. They

. will momentarily open then close when HVE-13A is started then trips.

--.--~---..

I i,.----... --i l

"- ----.;--1-1 m-p---Cl-e-m-e-n-ts---C-2---C-O=-N:-:-=-P--2=-5c-.-=-0 2-:-C-V-e-n--Cti-:-1 a-tiC-o-n---cS=-y-s-te-m-s-,(-at-ta-cc-h-e-dc----

SRO page 22-25 ). Directs Appendix B to check system alignment.

[

i-------~-- j -

I I

~---------i--~~---

Directs HVE-13A started per step 2. Determines one tra-;~f-~il I

CREACS has failed.

---+----

I

~T-S-~R-o-+l-I m-pl-e-m-e-n-t -T-.S-.-3-. 7-.-7-(-C-R-E-A-C-S-)-A-c-t-io-n-B-.-R-e-s-to-r-e-w-i-th-in-2-4-l

-I __

'l_-r,_h_o_u_rs_. ~. ________. ___ ~ __._"'_'___

... _1 I Perform steps from 2-0NP-25 02, "Ventilation Systems" when i directed. (attached page 22-25)

.. ~--------------'

BOP I - --

,.... ------~'--------I---

BOP I

I Identifies Control room recirc. initiated on A train but HVE-13A did not auto start and FCV-25-16, north OAI isolation valve has tripped.

-=--~---L----l---------------------I

... __ ~L __... ___ +_~_~p_t~_~_p_t_s_t_o_s_ta_rt_H_V_E_-_1 3_A_W_h_e_n_d_i_re_c_t_ed_._I_d_e_n_tif_ie_s_H_V_E_-1_3_A_--1 I

- ---_._-- ~----.-----------'-----.

REVISION NO PROCEDURE TITLE PAGE:

21 VENTILATION SYSTEMS 12 of 33 PROCE DURE NO 2-0NP-25.02 ST, LUCIE UNIT 2 6,2 Control Room Ventilation INSTRUCTIONS

1.

if only one Control Room NC Unit is available, Then REFER TO Tech Spec 3.7.71, Control Room Emergency Ventilation System.

2.

if ANY of the following have occurred:

Control Room OAI Radiation Monitor alarm Unit 1 CIAS Unit 2 CIAS

~

GO TO Appendix B, CIAS and Control Room OAI High Radiation.

3,

'-b!! ANNUNCIATOR V*5, Cnt! Room To Outside t>P Low, is ALARMED, Then GO TO Appendix C, Control Room Low pressure Restoration.

4,

~2 If a freon leak from a Control Room

4.

HVA / ACC Unit has been verified, Then PERFORM the following:

A. EVACUATE all personnel from the H&V Room CAUTION CONTINGENCY ACTIONS Personnel entering the H&V Room with a freon leak should wear SCBA to avoid breathing a hostile environment.

B. CHECK H&V Room Oxygen concentration greater than 195%

22 B. 11 Oxygen concentration is less than 19.5%, Then PERFORM the following

1.

ENSURE personnel wear SCBA in the H&V Room.

(

REVISION NO PROCEDURE TITLE PAGE:

12 of 33 VENTILATION SYSTEMS 21 PROCE DURE NO 2~ONP~25.02 ST LUCIE UNIT 2 6.2 Control Room Ventilation INSTRUCTIONS

1.

11 only one Control Room NC Unit is available, Then REFER TO Tech Spec 37.7 1, Control Room Emergency Ventilation System.

2.

11 ANY of the following have occurred

3.

Control Room OAI Radiation Monitor alarm Unit 1 CIAS Unit 2 CIAS Then GO TO Appendix B, CIAS and Control Room OAI High Radiation.

~3 !! ANNUNCIATOR V-5, Cntl Room To Outside t.P Low, is ALARMED, Then GO TO Appendix C, Control Room Low pressure Restoration.

~2 11 a freon leak from a Control Room HVA I ACC Unit has been verified, Then PERFORM the following A. EVACUATE all personnel from the H&V Room CAUTION CONTINGENCY ACTIONS

4.

Personnel entering the H&V Room with a freon leak should wear SCBA to avoid breathing a hostile environment.

B. CHECK H&V Room Oxygen concentration greater than 195%

22 B. !f Oxygen concentration is less than 19.5%, Then PERFORM the following

1.

ENSURE personnel wear SCBA in the H&V Room.

REVISION NO PROCEDURE TITLE PAGE 21 VENTILATION SYSTEMS 28 of 33 PROCEDURE NO 2-0NP-25.02 ST. LUCIE UNIT 2 APPENDIX B CIAS AND CONTROL ROOM OAI HIGH RADIATION (Page 1 of 3)

INITIAL

1.

CHECK the following system alignment:

A B

REQUIRED HVAC PANEL TRjlN TRAIN STATUS L

~~~ (1) HVE*13A Inlet Damper (0-17 A)

OPEN N/A lOne (1) HVE-13A Inlet Damper (0*18)

OPEN I

N/A t---

! FCV-25-24. kitchen Exhaust Isolation Valve CLOSED N/A r-FCV-25.16, North OAllsolation Valve CLOSED N/A

FCV-25-17, South OAI Isolation Valve CLOSED N/A

FCV*25-18, Toilet Exhaust Isolation Valve CLOSED N/A lOne (1) Control Room Emergency Filter Fan (HVE*13A)

START N/A r-

! One (1) HVE*138 Inlet Damper (0*178)

OPEN N/A lOne (1) HVE*138 Inlet Damper (D-19)

OPEN N/A FCV-25-25. kitchen Exhaust Isolation Valve CLOSED N/A FCV-25*14. North OAllsolation Valve CLOSED N/A I FCV-25.15, South OAllsolation Valve CLOSED N/A FCV*25*19. Toilet Exhaust Isolation Valve CLOSED N/A

One (1) Control Room Emergency Filter Fan (HVE-138)

START N/A

2.

11 a Control Room Emerg Filter Fan did NOT start, Then manually START the applicable fan HVE-13A HVE-13B.

3.

11 any damper failed to position properly. Then manually POSITION the damper, as indicated in step 1.

4.

STOP HVE-14, Cntr Rm Toilet Exhaust Fan.

5.

STOP HVE-33, Kitchen Exhaust Fan.

6.

11 both Control Room OAI Radiation Monitors on any intake are Inoperable. Then REFER TO Tech Spec 33.3.1.

23 REVISION NO PROCEDURE TITLE PAGE 21 VENTILATION SYSTEMS 28 of 33 PROCE DURE NO 2-0NP-25_02 ST_ LUCIE UNIT 2 APPENDIX B CIAS AND CONTROL ROOM OAI HIGH RADIATION (Page 1 of 3)

INITIAL 1_

CHECK the following system alignment:

I A

B HVAC PANEL REQUIRED TRjlN TR?N STATUS I

lone (1) HVE-13A Inlet Damper (D-17A)

OPEN N/A lone (1) HVE-13A Inlet Damper(D-18)

OPEN N/A IFCV-25-24, kitchen Exhaust Isolation Valve CLOSED N/A L-.

, f'CV*25-16, North OAllsolation Valve CLOSED N/A FCV-25-17, South OAI Isolation Valve CLOSED N/A-j

-.. ~--'

FCV-25-18, Toilet Exhaust Isolation Valve CLOSED i ~

.-------~----

l i One (1) Control Room Emergency Filter Fan (HVE-13A)

START

~

r-lOne (1) HVE-13B Inlet Damper (D-178)

OPEN N/A I

lone (1) HVE-13B Inlet Damper (0-19)

OPEN N/A I

i FCV-25-25, kitchen Exhaust Isolation Valve CLOSED N/A I FCV*25-14, North OAllsolation Valve CLOSED N/A 1-.

, FCV*25*15, South OAllsolation Valve CLOSED N/A FCV-25-19, Toilet Exhaust Isolation Valve CLOSED N/A

One (1) Control Room Emergency Filter Fan (HVE*13B)

START N/A J 2_

Il a Control Room Emerg Filter Fan did NOT start, Then manually START the applicable fan HVE-13A HVE-13S_

3_

Il any damper failed to position properly, Then manually POSITION the damper, as indicated in step 1 4,

STOP HVE-14, Cntr Rm Toilet Exhaust Fan_

5, STOP HVE-33, Kitchen Exhaust Fan 6_

Il both Control Room OAI Radiation Monitors on any intake are trloperable, Then REFER TO Tech Spec 33.3_1_

23

REVISION NO PROCEDURE TITLE PAGE 21 VENTILATION SYSTEMS PROCEDURE NO 29 of 33 2-0NP-25.02 ST. LUCIE UNIT 2 APPENDIX B CIAS AND CONTROL ROOM OAI HIGH RADIATION (Page 2 of 3)

NOTE

~7 §, §2 Due to changing environmental conditions during long term events, it may be necessary to repeat steps 7 & 8 to maintain the lowest possible dose.

7.

DETERMINE which Control Room OAI has the least amount of radiation:

8.

North OAI South OAI When the OAI with the lowest amount of radiation has been determined, Then PERFORM the following:

A.

OPEN the FCV on the lowest reading side:

FCV-25-14, North OAI Isolation Valve FCV-25-15, South OAllsolation Valve B,

THROTTLE the FCV on the lowest reading side throttle:

FCV-25-16, North OAI Isolation Valve FCV-25-17, South OAI Isolation Valve C.

THROTTLE Control Room ventilation return air as necessary.

PLACE PDIC-25-23A1, Cont Room to Outside I".P to Man and ADJUST as necessary.

PLACE PDIC-25-23B1, Cont Room to Outside c.P to Man and ADJUST as necessary.

~------------------------------------------------------------~ ~

24 24

(

RC:VISION NO PROCEDURE TITLE PAGE 21 VENTILATION SYSTEMS PROCEDURE NO 29 of 33 2-0NP-2502 ST. LUCIE UNIT 2 APPENDIX B CIAS AND CONTROL ROOM OAI HIGH RADIATION (Page 2 of 3)

NOTE

~7 §, §, Due to changing environmental conditions during long term events, it may be necessary to repeat steps 7 & 8 to maintain the lowest possible dose.

7.

DETERMINE which Control Room OAI has the least amount of radiation

8.

Norih OAI South OAI When the OAI with the lowest amount of radiation has been determined, Then PERFORM the following A.

OPEN the FCV on the lowest reading Side FCV-25-14, Norih OAI Isolation Valve FCV-25-15, South OAI Isolation Valve B.

THROTTLE the FCV on the lowest reading side throttle FCV-25-16, North OAI Isolation Valve FCV-25-17, South OAI Isolation Valve C.

THROTTLE Control Room ventilation return air as necessary PLACE PDIC-25-23A1, Cont Room to Outside 6P to Man and ADJUST as necessary.

PLACE PDIC-25-23B1, Cont Room to Outside 6P to Man and ADJUST as necessary.

24 24

REVISION NO PROCEDURE TITLE PAGE:

30 of 33 VENTILATION SYSTEMS 21 PROCEJURE NO

8.

2*0NP*2502 ST. LUCIE UNIT 2 APPENDIX B CIAS AND CONTROL ROOM OAI HIGH RADIATION (Page 3 of 3)

(continued)

D.

I OAI i

I

NORTH

[ SOUTH E.

MAINTAIN parameters:

FCV

! CONTROL ROOM PRESS 'j FLOW FLOW MIN INDICATION RATE FCV*25*16 0.125 In. H2O FI*25*18A

<;450scfm FCV*25*17 0.125 In H2O FI*25*18B

> 450 sefm 11 Control Room pressure indication is erratic and the required pressure differential can't be verified, Then MAINTAIN outside air intake air flow rate between 440 to 450 SCFM.

INITIAL INITIAL

9.

~7§,.§2 Initiate a Data Sheet 30 to track wind direction on a (4) four hour frequency.

10.

~7§'§2 IJ wind directions changes 90 degrees or more, in (4) four hours, Then, RE*PERFORM steps 7 and 8 above.

11.

'h If desired, Then STOP ONE of the following Control Room Emerg Filter Fans:

HVE*13A HVE*13B

12.

V\\ihen initiating signals are CLEARED, Then PERFORM ALL of the following A.

ENSURE both Control Room Emerg Filter Fans are secured and their control switches are in auto.

HVE*13A HVE*13B B.

RESTORE Normal System Alignment per 2-NOP*25.07.

END OF APPENDIX B 25 25

-~-

i)

~

i)

(

'lEV'SION NO PROCEDURE TITLE PAGE 30 of 33 VENTILATION SYSTEMS 21 P",OCEJURE NO 2-0NP-2502 ST, LUCIE UNIT 2

8.

9.

10.

(continued)

D.

APPENDIX B CIAS AND CONTROL ROOM OAI HIGH RADIATION (Page 3 of 3)

I OAI i ______ --,-__

NORTH r SOUTH E.

if Control Room pressure indication is erratic and the required pressure differential can't be verified, Then MAINTAIN outside air intake air flow rate between 440 to 450 SCFM,

,-]7 §,§2 Initiate a Data Sheet 30 to track wind direction on a (4) four hour frequency,

,-]7§1 §z if wind directions changes 90 degrees or more, in (4) four hours, Then, RE-PERFORM steps 7 and 8 above, 11, 11, If desired, Then STOP ONE of the following Control Room Emerg Filter Fans HVE*13A HVE*136 12, When initiating signals are CLEARED, Then PERFORM ALL of the following A.

ENSURE both Control Room Emerg Filter Fans are secured and their control switches are in auto, HVE*13A HVE-136 B,

RESTORE Norma! System Alignment per 2-NOP*25.07 END OF APPENDIX B 25 25 INITIAL 33 33

Appendix D Operator Action Form ES-D-2 r- --

i i Op Test No.: Scenario #

...l.- Event #

6 Page 10 of _2_0--11 Ii Event

Description:

2A Intake Cooling Water Pump has a sheared shaft.

I ::_Iime

[_ Position A plica nt's Actions or Behavior B~ot-h-O~-~rator Instructions: Trigger event 6 ICW sheared shaft when directed !

When called to throttle 2C ICW PP discharge valve trigger throttle 2C ICW

When called to open 2C ICW PP discharge valve, trigger open 2C valve.

r---- -----------

i Indications Available: Annunciator: E*30 ICW Headers pressure low LB*4 3B1/3B2 Lube Wtr Supply Strn t.P High E*16 Circ Wtr Pump Lube Wtr B/U in service

. Low amperage on RTGB 2A ICW Pump amp meter.

~ ____________ t_B_~P_---+I_R_e_s_p_o_n_d_s __

to_IO_W_f_IO_w_a_nn_u_n_c_ia_t_o_r._I_d_e_n_t_ifi_e_s_lo_w_a_m_p_e_ra_g_e_'_-I

- ~~~~_--~*~~~-_-----t--I S_t_o_p_s_~A ICW pump_w_h_en_d_ir_ec_t_e_d _________ --i I Directs stopping 2A ICW pump

~

SRO

+

I I-------+-I m-pl-e-m-e-n-ts-2--0-6-4-00-3-0--ln-ta-k-e-C--oo-l-i n-g-W-a-te-r-S-y-s-te-m--7-.2-. -1.-B--1 1

' and C (attached page_28_). and 2-NOP-21.03C 2C Intake L-___ --..-L ______ ---'!_C_o_o_l_in_g_W_at_e_r_P_u_m_p __ O_p_er_a_ti_o_n_(a_t_ta_c_h_e_d_p_a_g_e_2_9_-_3_1-_) __

i

_ NOTE: As per NOTE in 2-NOP-21.03C (attached) steps 4.2.5 through 4.2.10 may be

skipped as directed by the US for an off normal or emergency condition. The SRO should recognize this as applicable and direct the above steps skipped.

--~-----------T

1 I

r-----t-Direct steps 421 through 4 implemented (attached I

page 29 l I

I i

I I

Direct start of 2C Intake Cooling Water Pump as per step I

I 4.2.11 (attached page _3o_)

l- -------

I After pump started direct steps 4.2.2.12 through 20 I

implemented. (attached page_30,31_)

i-****---** __

r---------

.. -----+-------+-----------------.------------------1 i

i BOP

Direct Field Operator to perform steps 4.2 1 through 4 of 2-

'---____ -__ -_:=~ ____

Li _N_O_P_-2_1.03C 2C Intake Cooling Water Pump Operation

(

Appendix D Operator Action Form ES-D-2

Op Test No..

1 Scenario #

7 Event #

6 Page _10_ of 2£J Ii Event

Description:

2A Intake Cooling Water Pump has a sheared shaft.

!::-=-~~~I_~~n~~fC)~

__ ----.J~--Tll~~~. """Po::S::lt::io::n:::::::::::::::::::::::::::::=::::A::p:lic::a::n:t'S::A:c::t::io::ns::~o.;..r=B:e::h::a::vi=or::::::::::::::::::::::::::::::

.. _---_... _---.- -- -~----,

Booth Operator Instructions: Trigger event 6 ICW sheared shaft when directed When called to throttle 2C ICW PP discharge valve trigger throttle 2C ICW I

~W~_=~called to open 2C ICW PP discharge valve, trigger open 2C vaIV:~--------------li

Indications Available: Annunciator: E-30 ICW Headers pressure low i LB-4 3B1/382 Lube Wtr Supply Strn liP High

E-16 Circ Wtr Pump Lube Wtr B/U in service I

Low amperage on RTGB 2A ICW Pump amp meter.

I BOP I Responds to low flow~a-n-n-u-n-c-ia-t-o-r.-I-d-e-nt-if-ie-s-Io-w-a-m-p-e-ra-g-e-.----:----11

n-j~--~--=r

~

i Stops 2A ICW pump when directed

--~-~~~--- ----~---

-------~I*

i i

,-------------+-

I SRO I Directs stopping 2A ICW pump

.~

Implements 2-0640030 Intake Cooling Water System 7.2.1.B

. and C (attached page~28~). and 2-NOP-21.03C 2C Intake I

. Cooling Water Pump Operation (attached page~29-31_)

--~-------.. --------------------

NOTE. As per NOTE in 2-NOP-21.03C (attached) steps 4.2.5 through 4.2.10 may be

skipped as directed by the US for an off normal or emergency condition. The SRO should recognize this as applicable and direct the above steps skipped.

- -----~- T-'--'-'-

r-----

! Direct steps 4.2 1 through 4 implemented. (attached a~ 29

)

Direct start of 2C Intake Cooling Water Pump as per step I

~ -:=t---

1421 ~(_a_tt_a_ch_e_d_p_a_g_e_-_3_0-~-)-----------_______11.1 I After pump started direct steps 4.2.2.12 through 20

__ ------j--

lim pi em ented. (attach ed~a_g_e_-_3_0_, 3_1_-_) _________

1'

~-J

,,---....;.------.--.-~---------

BOP

,Direct Field Operator to perform steps 4.2 1 through 4 of 2-

______ ~ ___ =-rP -21.D3C 2C Intake Cooling Water Pump Operatror

-~~--------.---------------------------------.----

Appendix D Operator Action Form ES*D*2 i;'"~--'----------=--==============--=----==========O,

" i; Op Test No II Event Description Scenario #

7 Event #

6 Page 11 of 20 2A Intake Cooling Water Pump has a sheared shaft.

t~

.. ~. __.;.T,;.;,i~;.;;~~*~~::;::,;..P==O;:S;;:it~I~'

o~n::::::::::::::::::A::;p;;pZli;;;;c~a;::nZt's;:;.;A~c;:t;,;;i=o,;.;.n~s;:.;;;o~r2B;:;e;:h;a,;.;v~i.;;;o~r::::::::::::::=J

. Booth

! minut Operator Instructions: Notify control room steps complete in about 5 es after called.

Indica tions Available:

T.

i I

BOP Start 2C Intake Cooling Water pump as per step 4.2.11

~.-

I Direct Field Operator to perform steps 4.2.12 through 20 after BOP pump started. (attached page_30,31_)

-+---

i

.. _._--_.--+---_.-----+-----

I I

i I

i

--+

'------------------------.----.---~-----... _--------.-- --------i i

1--"--...... __

n i

--f-----------------------------------

,1

,-.-.---~---.----

~

i

"'.---------+------+--------------------------------------1 I

i

'---------... '1'.... -----1--------------------.-------------1

--...... ------1... ----+----------------------1 I

--+-1------+--------------------_*_-_.. _*_*_----_........ -1 r~---*-*.. ----+-----+------------------------.-----

i

+i _____ -+ _______________________________ ----1

~------~-I r-----

i

,.------~---T'-------------------------I

"_. __.. _. __.. --+-----.,-------------------------------------j

.. _-------+-----............. ------------------------------1 1

I

... _..............J ____

........1 __________________________________..J c _

Appendix D Operator Action Form ES-D-2 il Op Test No.

Scenario #

7 Event #

6 Page 11 of 10 "I,

II Event Description 2A Intake Cooling Water Pump has a sheared shaft.

l-.-------.---.---~~~~~""T~~-=-------~~~-=~-------~~~

r~.;:;e-]I Position Applicant's Actions or Behavior J

Booth Operator Instructions: Notify control room steps complete in about 5 I minutes after called.

c* -.-------------

Indications Available:

BOP Start 2C Intake Cooling Water pump as per step 4.2.11

r-----+-I -

i***"-~ -.----.---~-+------.------+--------------------------------1 BOP Direct Field Operator to perform steps 4.2.12 through 20 after pump started. (attached page_30,31_)

--*---~+--_'

___ ~-----

_____ -+------I - - - - - - - - - 1

- ---- ----+---- ---.-T"------

I

.--;--~----+---

.----.. -. --.-- "-I

'---T~ -----+1---------------

- -.--~~--;-~---.----.-~-----

--~------~

+------t-I--

~

I

_.--j I

I

-- L-l'

-i

.-- -------.-.. --~-

~

I

. ____ I

~-----~:~~~~~I ~~~~~~~~~~-!~

-----------*-l-------r I

i I

~

I

".---- --- --7 I

.~-~---.----.--.---.---

REVISION NO PROCEDURE TITLE:

PAGE 6 of 67 INTAKE COOLING WATER SYSTEM 41A PROCEDURE NO 2-0640030 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7,1 Immediate Operator Actions 1,

None 7,2 Subsequent Operations Actions INSTRUCTIONS CONTINGENCY ACTIONS CAUTION If affected ICW header indicates 0 pressure, the standby pump discharge valve must be throttled prior to startinq.

1.

!1 an ICW pump indicates extremely high amps, OR an ICW pump trips unexpectedly. Then A.

!1 the health and safety of the public is in jeopardy, Then ATTEMPT ONLY ONE restart.

B.

Place the pump control switch to PULL TO LOCK position.

C.

Then align the standby pump to the header, lAW 2-NOP-2103A(B)(C). 2A(B)(C) Intake Cooling Water System Operation, and start the standby pump.

28 28 c, if an ICW pump cannot be restored to a header. Then:

1, Reduce MVARS to minimum.

2, Monitor Main Generator Gas Temperatures Refer to 2-0NP-53 01. Main Generator.

3. Reduce turbine load as needed to within the heat removal capability of the TCW system.

4. Isolate S/G blowdown, then place the Open Blowdown heat exchanger TCVs in MANUAL and close.

(

REVISION NO PROCEDURE TITLE PAGE 41A PROCEDURE NO INTAKE COOLING WATER SYSTEM 6 of 67 2-0640030 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions 1,

None 7.2 Subsequent Operations Actions INSTRUCTIONS CONTINGENCY ACTIONS CAUTION If affected ICW header Indicates 0 pressure, the standby pump discharge valve must be throttled prior to startinq.

1.

11 an ICW pump Indicates extremely high amps, OR an ICW pump triPS unexpectedly. Then.

A, U the health and safety of the public IS In Jeopardy, Then ATTEMPT ONLY ONE restart

8.

C.

Place the pump control switch to PULL TO LOCK position Then align the standby pump to the header, lAW 2-NOP-21 03A(B)(C), 2A(B)(C) Intake Cooling Water System Operation, and start the standby pump 28 28 c, if an ICW pump cannot be restored to a header, Then 1, Reduce MVARS to minimum

2. Monitor Main Generator Gas Temperatures Refer to 2-0NP-53 01, Main Generator.

3. Reduce turbine load as needed to within the heat removal capability of the TCW system 4, Isolate S/G blowdown, then place the Open Blowdown heat exchanger TCVs In MANUAL and close

~--- - -----

.-~.--------... -----_.. _.'.. ------- -..... _-._-

"iv,S,ON NO PROCEDURE f1TLE PAGE:

OA 2C INTAKE COOLING WATER PUMP OPERATION 8 of 20 PROCEDURE NO 2-NOP-2103C ST. LUCIE UNIT 2 4.2 Starting 2C ICW PumQ on A Header with Header De[!ressurized INITlAL NOTE If pump start is for an off-normal emergency condition, any or all steps of I

I Section 42 Step 5 thru Section 42 Step 10 may be skipped as directed by I

US/SM.

Proper CLOSED alignment of crosstie valve requires the valve indicator arrow to line up with the "V" notch on the indicator plate.

(Attachment 1 )

System Performance Group/OSE shall be notified if crosstie valve is not aligned properly,

1.

ENSURE 2A ICW Pump Control Switch in PULL TO LOCK position, ---

2.

ENSURE Locked Closed S821211. 2C ICW PUMP X-TIE DISCH TO

'8' TRAIN ISOL (INTKl9/N-4/W-C),

3.

ENSURE Locked Open S821165, 2C ICW PUMP X-TIE DISCH TO

'A' TRAIN ISOL (INTK/9/N-4/W-C),

--~

4, THROTTLE approximately 10 turns OPEN, S821206, 2C ICW PUMP DISCH ISOL (INTKl18/N-3/W-C).

5.

CHECK SS-21-1A Bearing Cartridge Lubrication Reservoir level between the HI LEVEL and LOW LEVEL tags on reservoir sightglass. ---

6.

ADD lubricant to SS-21-1A Bearing Cartridge Lubrication Reservoir as necessary per 2-NOP-21.03A, Intake Cooling Water System Train A Operation.

7.

ENSURE 2C ICW Pump motor lube oil level approximately at STANDSTILL level mark.

8.

CLOSE SH21204, PI-21-5C ISOL (INTK/23/N-3/W-C).

9.

CLOSE the local instrument isolation for PT-21-8A, 2A ICW PUMP DISCH HDR PRESS (INTK/12/N-4/W-C),

29 29

(

-- --_. --------~.---.- - -----

PROCEDURE flHE PAGE:

OA 2C INTAKE COOLING WATER PUMP OPERATION 8 of 20 PROCE DUR I: NO 4.2 2-NOP-21.03C ST. LUCIE UNIT 2 Starting 2C ICW Pump on A Header with Header Depressurized NOTE If pump start is for an off-normal emergency condition, any or all steps of I

Section 4 2 Step 5 thru Section 4 2 Step 10 may be skipped as directed by US/SM I

Proper CLOSED alignment of crosstie valve requires the valve indicator arrow to line up with the "V" notch on the indicator plate I

(Attachment 1 )

Ii I'

System Performance Group/OSE shall be notified if crosstie valve is not aligned properly

1.

2.

3.

4, 5,

6, ENSURE 2A ICW Pump Control Switch in PULL TO LOCK position ENSURE Locked Closed S821211. 2C ICW PUMP X-TIE DISCH TO

'8' TRAIN ISOL (INTKJ9/N-4/W-C).

ENSURE Locked Open S821165. 2C ICW PUMP X-TIE DISCH TO

'A' TRAIN ISOL (INTKJ9/N-4/W-C).

THROTILE approximately 10 turns OPEN, S821206, 2C ICW PUMP DISCH ISOL (INTKJ18/N*3/W-C)

CHECK SS-21-1A Bearing Cartridge Lubrication Reservoir level between the HI LEVEL and LOW LEVEL tags on reservoir sightglass.

ADD lubricant to SS-21-1A Bearing Cartridge Lubrication Reservoir as necessary per 2-NOP-2103A, Intake Cooling Water System Train A Operation.

7.

ENSURE 2C ICW Pump motor lube oil level approximately at STANDSTILL level mark.

8, CLOSE SH21204, PI-21-5C ISOL (INTK/23/N-3/W-C).

g, CLOSE the local instrument Isolation for PT-21-8A, 2A ICW PUMP DISCH HDR PRESS (INTK/12/N-4/W-C).

29 29

(

~~~~

- ---_.. ------.~~-

PROCEDURE TITLE PAGE' OA 2C INTAKE COOLING WATER PUMP OPERATION 9 of 20 Pf:\\OCT OuRf NO 4,2 ST, LUCIE UNIT 2 Starting 2C ICW Pump on A Header with Header Depressurized (continued)

F==================--==========-===~===--=--======~==~

NOTE Actual backwash FLOW does not occur until ICW Header is pressurized, 1O, Immediately prior to starting 2C ICW Pump, START a manual backwash of 2A Debris Filter System uSing MANUAL CONTROL FROM CONTROL PANEL in accordance with 2-NOP-21,03A, Intake Cooling Water System Train A Operation 11, ST ART 2C ICW Pump

12.

IF closed in Section 4.2 Step 8, SLOWLY OPEN SH21204, PI*21-5C ISOL 13, IF closed in Section 4,2 Step 9, SLOWLY OPEN the local instrument Isolation for PT*21-8A, 2A ICW PUMP DISCH HDR PRESS.

14, As pressure begins to rise In A ICW Header, SLOWLY OPEN SB21206, 2C ICW PUMP DISCH ISOL, until valve IS fully OPEN.

15, LOCK OPEN SB21206, 2C ICW PUMP DISCH ISOl, 16, ENSURE OPEN SH21520, 'A' TRAIN ICW TO HYPO SEAWATER BSTR PUMPS ISOL, (INTK/7/N*4/W-C),

17, OPEN SH40079, 2C ICW HYPO HDR ACID RETURN ISOL (INTK/17/N-3/E-C)

-~-

18, ENSURE Closed SH40077, 2A ICW HYPO HDR ACID RETURN ISOL (INTKJ17/N-3/E-C) 19, WHEN SB21206, 2C ICW PUMP DISCH ISOL has been FULLY OPEN for greater than 15 minutes, THEN ENSURE 2A Debris Filter System MANUAL BACKWASH IS secured using MANUAL CONTROL FROM CONTROL PANEL in accordance with 2-NOP-21,03A, Intake Cooling Water System Train A Operation 30 30

(

~-------- --.--------------

P['.IS'CN NO PROCEDURE TITLE OA 2C INTAKE COOLING WATER PUMP OPERATION 1;Jf:\\OC[ OuRF NO ST, LUCIE UNIT 2 4,2 Starting 2C lew Pump on A Header with Header Depressurized (continued)

PAGE' 9 of 20 F===================--==========--=~====~----======~==~

NOTE Actual backwash FLOW does not occur untillCW Header is pressurized, 30 30

(

-~---

PROCEDURE TITLE PAGE OA 2C INTAKE COOLING WATER PUMP OPERATION 10 of 20

[)~CC~ JUHE NO 4.2 2NOP21.0JC ST. LUCIE UNIT 2 Starting 2C lew Pump on A Header with Header Depressurized (conti nued)

I NOTE

1 The following step will require a ladder at the CCW platform for access to HX II vent valves and a pipe wrench to remove vent caps.

20.

VENT 2A ICW header by opening the following valves until a steady stream of water issues from vent, THEN CLOSE the valve:

A.

SH21332, SS-21-1 A VENT (CCW/28/S-AJW-4)

B.

SH212049, SS*21*1A BACKWASH OUTLET VENT (CCW/31 /S*AJW-4)

C.

SH21197, 2A CCW HX TUBE SIDE INLET HEAD VENT (CCW/34/N-B/W*4)

D.

SH21198, 2A CCW HX ICW OUTLET VENT (CCW/38/S-AlW*2)

E.

SH21358, SS-21-4A VENT (TGB/26/S-20/W-G)

F.

SH21171. 2A TCW HX TUBE SIDE OUTLET HEAD VENT (TGB/26/N-21/E -K)

G.

SH21172, 2A TCW HX TUBE SIDE INLET HEAD VENT (TGB/26/N-21/W-D) 31 31

~-

t

(

~--~-

~~~~~~~~~~~

PROCEDURE TITLE PAGE 4.2 OA 2C INTAKE COOLING WATER PUMP OPERATION 2 NOP21 OJC ST LUCIE UNIT 2 Starting 2C ICW Pump on A Header with Header Depressurized (continued) 11 NOTE I

\\ The following step will require a ladder at the CCW platform for access to HX II vent valves and a pipe wrench to remove vent caps.

20.

VENT 2A lew header by opening the following valves until a steady stream of water issues from vent, THEN CLOSE the valve:

A.

SH21332, SS-21-1A VENT (CCW/28/S-AJW-4)

B.

SH212049, SS-21-1A BACKWASH OUTLET VENT (CeW/31 /S-AJW-4)

C.

SH21197, 2A CCW HX TUBE SIDE INLET HEAD VENT (CeW/34/N-B/W-4)

D.

SH21198, 2A ecw HX ICW OUTLET VENT (CeW/38/S-A/W-2)

E.

SH21358, SS-21-4A VENT (TGB/26/S-20/W-G)

F.

SH21171. 2A TCW HX TUBE SIDE OUTLET HEAD VENT (TGB/26!N-21/E-K)

G.

SH21172, 2A TCW HX TUBE SIDE INLET HEAD VENT (TGB/26!N-21/W-D) 31 31 10 of 20

~-

~--

~-

Appendix D

!I Op Test No.:

I, Event

Description:

Operator Action Form ES-D-2 Scenario #

7 Event #

_7;..;.'..;,.8:..,;. 9;..-.__ Page.1l-of _2_0---11 Loss of Instrument Air pressure. Plant down power. Unit trip. Three CEA's do not fully insert. Stop all RCP's due to CCW unrecoverable.

Time II Position II Applicant's Actions or Behavior Booth Operator Instructions: Trigger event 7 loss of Instrument air.

. If directed trigger 7a for faster response of instrument air loss.

~.--'---"'-'- _.-

Indications Available: Annunciator F~15 Inst Air Pressure High/Low

Two minutes late annunciator F~30 Unit 1 / Unit 2 Inst Air Crosstie Open I

SRO Implement 2-1010030 Loss of Instrument Air step 7.2.2 verify I

2C or 2D has started. (attached page_35_)

1-._---=1=-

i----.-+-: ~---Ir--Notifies SM

~-----*------t i

r---------i- **-----il-E-ns-u-r-e-s-e-rv-ic-e--a-ir-o-r-c-o-n-s-tr-u-c-ti-o-n -a-ir-i-s -in-se-r-v-ic-e-. -------1 I ;----

I I ! -t--

I

-.J. -

c** -.. -------_--

Direct opening SH18718 Service air crosstie to Instrument air.

Step 7.2.3.B (attached page_35_)

i If air pressure drops to less than 75 psig evaluate the need to shut the unit down. Step 7.2.7 (attached page_37_)

Direct unit down power in response to lowering air pressure.

Direct Charging pumps stopped if Letdown isolates due to lowering air pressure

~.---..... _-+-----j----------------------------I

. Directs unit trip when instrument air pressure lowers to less

+_

I than 60 psig. Step 7.1.1 (attach ed page _ 34_)

r*****

"'"1'.

I i

Monitors Primary for Letdown valves, CCW valves to RCP's i

RO possible closure on lowering air pressure.

I

---.... -------T I

I BOP Identify lowering Instrument air pressure in response to i

annunciator. Refers to ARP F-15 i - '

I

(

--~--.. -.. ----------------.. ~~-

Appendix D Operator Action Form ES-D-2 r---'.

!i Op Test No..

1 Scenario #

7 Event #

7, 8, 9 Page _12_ of _20_-11 1

'1' Event

Description:

Loss of Instrument Air pressure. Plant down power, Unit trip. Three CEA's do not fully insert. Stop all RCP's due to CCW unrecoverable.

iL~..==JL __ ~6:J Applicant's Actions or Behavior Booth Operator Instructions: Trigger event 7 loss of Instrument air.

i If directed trigger 7a for faster response of instrument air loss.

~

Ind~~tion;Available: Annunciator F-15 Inst Air Pressure High/Low I

' Two minutes late annunciator F-30 Unit 1 / Unit 2 Inst Air Crosstie Open I

SRO I' Im-plement 2-1010030 Loss of Instrument Air step 7.2.2 verify Ii I

. 2C or 20 has started. (attached page_35~)

~==T*

INotifies SM

!I

-.----.-+-----~~-+-~~.-~-

~~~~~~~~-~~--~~~-

~

I Ensure Servic~ air or construction air is in service.

=I~==t=----

I I

Direct opening SH18718 Service air crosstie to Instrument air.

Step 7.2.3.B (attached page_35_)

._~~~l-*__

I

If air pressure drops to less than 75 psig evaluate the need to

--J._. ______ 1 shut_~he unit down. Step 7.2.7 (attached page_37 _)

I

-.. -. -----i

~~-+i~~--~~-

___. _____._~~' _____ ----LDirect unit do,":,n power~~ response to lowering air pre_~sure i

-- --------".--t-----

Direct Charging pumps stopped if Letdown isolates due to lowering air pressure I

--1 i.,

I

'---1 I

.--- ---+----- ~~--+: 1-' re-c-t-s-u-n-i-t -t r-i p-w-h-e-n~i n-s-tr--u-m-e-n-t-a-i-r-p-r-e-ss-u-r-e-I-o-w-e-r-s-t-o-I-e-ss~~--I I

than 60 psig. Step 7.1.1 (attached page_34_)

"----,---.-.-. -~--+I--.------~~~--~~--~~--~~-~---------1 RO

'Ii Monitors Primary for Letdown valves, CCW valves to RCP's possible closure on lowering air pressure.

BOP Identify lowering Instrument air pressure in response to annunciator. Refers to ARP F-15 i

I _____

. ___.c _____

-'---~ _____

~~

Appendix 0 i

op-;est N:~.-

I, ii Event Description II

~=~J_Position

~~-------------.. --~~.. --~~~-~-

Operator Action Form ES-D-2 Scenario #

7 Event #

_7;...:,...;;8,.:,.,.,;..9 ___ Page 21...- of _2_0_-11 Loss of Instrument Air pressure, Plant down power, Unit trip. Three CEA's do not fully insert, Stop all RCP's due to CCW unrecoverable.

Ap licant's Actions or Behavior

! Booth Operator Instructions: If NPO asked the status of the Instrument air I compressors, state both C and 0 are running.

... -.~.-----.-----.. -

Indications Available: Air operated valves that fail closed, begin to show red I 1 green light indication as air pressure degrades.

r 80 P N otifi-e-s-N-P-O-t-o-i-n-v-e s-t-i g-a-t-e-I-n s-t-ru-m-e-n-t -a-i r-s-y-s-te-m-for lea ks 80P/RO Initiates manual Reactor trip when directed, 1------------.-;---~

-+-------- ---------------~

e----~

.. -~~.---I--I---~

-~-l

~------- I i

1

~--r--~-J

~ _____ ~~~*_~~~___JI

, __ ~. __.~_+.-~

_~_~+__--------------------- I I

l I

I

___ 1_'...

i

;~~"~----I--~

~~

+--------1-----------------------

I c~-.. -~**--

-ri ------t---- ------ -------~--------------I

~.. ~-.~l-- ~~---+-----

I

-".----~--- ---_._--

---.J- ---+-----------------

==1 I

'~---.-=-:*~--+-----------------~JI

~--... -.. ____t__--...

1

__,~._",L_._... ~ __

(

Appendix 0 Operator Action Form ES-D-2 I~;est N:.-

Scenario #

7 Event #

7, 8, 9 Page ~

of _20_..."

II Event Description.

'I

'i L_-Ene J~

Position Loss of Instrument Air pressure, Plant down power, Unit trip. Three CEA's do not fully insert, Stop all RCP's due to CCW unrecoverable.

Ap licant's Actions or Behavior

Booth Operator Instructions: If NPO asked the status of the Instrument air

! compressors, state both C and D are running.

~.. -.~.----.-----.. -

..... I Indications Available: Air operated valves that fail closed, begin to show red I 1 green light indication as air pressure degrades.

r 80 P N otifi-e-s-N-P-O-t-o-i-n-ve-s-t-i 9-a-te-1 n-s-t-ru-m-e-n-t -a-i r-s-y-s-te-m-for lea ks

--.---. --------t-----------

I

.. ------ ----- -----t------ -.- --j--

'BOP/RO Initiates manual Reactor trip when directed,

~

! 1

___ ~-

.. _I----!-----______

l

'-r-~-

l e---

.---- ---.-~---------+1----- ------------- ----l

~.. ------_l___I --+--1 -----

-I

--+----*~1! --~--~--------------j

-_._._-_._._[ --

,---- ---*--t---

I-------------------------------~

I I

i I

_~--+'-----

=-J----~

~

1

~'

+------l---------------.----------

-T-----I --4---------- ---~_______I ------+-----

I

---.---------i--------~ ~---~

L

J I

'--1

,--------+----_.----+---------------------------1 I

I i

-~~--

.. --.. -~-----.--+-----------------l I

REVISION NO PROCEDURE TITLE:

PAGE:

5 of 19 LOSS OF INSTRUMENT AIR 27 PROCEDURE NO 2-1010030 ST LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions INSTRUCTIONS CONTINGENCY ACTIONS

1.

if the Instrument Air header pressure indicates less than 60 psig and is still lowering, Then PERFORM the following:

A. TRIP the Reactor and Turbine.

B.

GO TO 2-EOP-01, Standard Post Trip Actions.

END OF SECTION 7.1 34

(

REviSION NO PROCEDURE TITLE PAGE 27 PROCEDURE NO LOSS OF INSTRUMENT AIR 5 of 19 2-1010030 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions INSTRUCTIONS CONTINGENCY ACTIONS

1.

if the Instrument Air header pressure Indicates less than 60 psig and is still lowering, Then PERFORM the following:

A. TRIP the Reactor and Turbine.

B.

GO TO 2-EOP-01, Standard Post Trip Actions.

END OF SECTION 7.1 34

~~~~~~~~~--~~~~~~~~~~~~~---~-~--.. ----

REVISION NO PROCEDURE TITLE PAGE 27 LOSS OF INSTRUMENT AIR PROCEDURE NO 7 of 19 2-1010030 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

2.

INSTRUCTIONS CONTINGENCY ACTIONS NOTE The automatic cross-tie feature of the Instrument Air System occurs at approximately 85 psig lowering on the affected unit. The cross-tie valve on Unit 1 will close if EITHER of the following conditions occur:

The Unit 1 Instrument Air header pressure lowers below 85 psig.

The Unit 2 Instrument.Air header pressure rises above 95 psig.

if Instrument Air header pressure is lowering, Then VERIFY the standby instrument air compressor (2C or 20) has started NOTE

2.

if the standby instrument air compressor (2C or 20) has NOT started, Then manually START the standby instrument air compressor (2C or 20).

The time period that the Service Air header feeds the Instrument Air header through the cross-tie should be minimized to prevent oil intrusion into the Instrument Air header.

3.

If the Instrument Air header pressure is still lowering, Then PERFORM the following:

A.

ENSURE the Service Air Compressor is running, or Service Air is being supplied by Construction Air.

B. OPEN SH18718, Service Air Cross-tie to Instrument Air Isol C. if the Instrument Air header is fed from the Service Air header for greater than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , Then BLOW DOWN the Instrument Air receiver tank at V18126 hourly to check for oil, water and crud build-up.

35 C. 11 oil, water, or crud build-up is detected, Then CONTACT Engineering to evaluate continued use of the Service Air System.

(

REVISION NO PROCEDURE TITLE PAGE 27 LOSS OF INSTRUMENT AIR PROCEDURE NO 7 of 19 2-1010030 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

2.

3.

INSTRUCTIONS CONTINGENCY ACTIONS NOTE The automatic cross-tie feature of the Instrument Air System occurs at approximately 85 psig lowering on the affected unit. The cross-tie valve on Unit 1 will close if EITHER of the following conditions occur:

The Unit 1 Instrument Air header pressure lowers below 85 psig.

l. The Unit 2 Instrument Air header pressure rises above 95 psig Lf Instrument Air header pressure is lowering, Then VERIFY the standby Instrument air compressor (2C or 20) has started NOTE

2.

11 the standby instrument air compressor (2C or 20) has NOT started, Then manually START the standby instrument air compressor (2C or 20)

The time period that the Service Air header feeds the Instrument Air header tnrough the cross-tie should be minimized to prevent oil intrusion into the Instrument Air header.

lJ the Instrument Air header pressure is stili lowering, Then PERFORM the following A.

ENSURE the Service Air Compressor is running, or Service Air is being supplied by Construction Air

8. OPEN SH18718, Service Air Cross-tie to Instrument Air Isol C. lJ the Instrument Air header is fed from the Service Air header for greater than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , Then BLOW DOWN the Instrument Air receiver tank at V18126 hourly to check for oil. water and crud build-up

/

35 C. lJ oil, water, or crud build-up is detected. Then CONTACT Engineering to evaluate continued use of the Service Air System

(

REVISIOt-; NO PROCEDURE TlTl.E*

PAGE.

27 LOSS OF INSTRUMENT AIR 8 of 19 PROCEOURE NO.

2*1010030 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

4.

INSTRUCTIONS Check pressure drop across the in

4.

service air dryer and filters, to be less than 13 psig.

5.

U instrument air pressure can be stabilized, Then:

6.

A. Investigate the instrument air system for leaks, failures, or malfunctions B. Ensure dryers and filters are aligned properly and placed in service correctly.

Ensure power available to the 2C and

6.

20 instrument air compressors.

A. "2C Air Compressor (MCC 2A1)",

Bkr 2-40802 B. "20 Air Compressor (MCC 2B1 )",

Bkr.2-41608.

/

36 CONTINGENCY ACTIONS Jl pressure drop is greater than or equal to 13 psig, Then open V18075, air dryer and filter bypass.

Jl power is NOT available, Then perform the following as required:

A. Determine that malfunction of the motor or breaker was NOT the reason for loss of power.

B. Restore power to the appropriate MCC and start the instrument air compressor.

C.

Start Instrument Air Compressor 2A per Appendix A.

OR D. Start Instrument Air Compressor 28 per Appendix B.

(

~~~~~--~--~.-------.----.---.----------------------

Rf VISIO;; NO PROCEDURE TITLE PAGE.

27 LOSS OF INSTRUMENT AIR 8 of 19 PROCEDURE NO 2-1010030 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

4.

INSTRUCTIONS Check pressure drop across the in

4.

service air dryer and filters, to be less than 13 psig.

5.

U instrument air pressure can be stabilized, Then

6.

A.

Investigate the instrument air system for leaks, failures, or malfunctions B,

Ensure dryers and filters are aligned properly and placed in service correctly.

Ensure power available to the 2C and

6.

20 instrument air compressors.

A.

"2C Air Compressor (MCC 2A1)",

Bkr 2-40802.

B. "20 Air Compressor (MCC 2B1)",

Bkr. 2-41608.

/

36 CONTINGENCY ACTIONS

!! pressure drop is greater than or equal to 13 psig, Then open V18075, air dryer and filter bypass.

if power is NOT available, Then perform the following as required.

A.

Determine that malfunction of the motor or breaker was NOT the reason for loss of power.

B.

Restore power to the appropriate MCC and start the instrument air compressor.

C.

Start Instrument Air Compressor 2A per Appendix A.

OR D.

Start Instrument Air Compressor 28 per Appendix B.

REVISION NO PROCEDURE TiTLE PAGE 9 of 19 LOSS OF INSTRUMENT AIR 27 PROCEDURE NO 2*1010030 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS CAUTION The ability to maintain Steam Generator levels at full power conditions may be affected as instrument air pressure degrades below 75 PSIG. Air operated valves and instrumentation may lose full range operating capability. Appendix C contains a partial listing of air operated components and their mode of failure upon loss of air supply.

7.

if instrument air pressure decreases to less than 75 psig, Then evaluate the need to shut down the unit in accordance with 2-GOP-123, Turbine Shutdown Full Load to Zero Load, or 2-EOP-01, Standard Post Trip Actions.

8.

!f feedwater regulating 15% bypass valves are being used to maintain S/G level, Then use of the Auxiliary Feedwater System will be required if air pressure continues to degrade.

9.

!f SDC is in service, Then refer to ONOP 2*0440030, Shutdown Cooling Off-Normal.

10. U BOTH of the following conditions exist:

Loss of CCW to the RCPs, due to loss of Instrument Air pressure CCW can NOT be restored within 10 minutes Then PERFORM ALL of the following:

A.

TRIP the Reactor.

B.

TRIP the Turbine C. TRIP ALL the RCPs.

D. GO TO 2-EOP-01, Standard Post Trip Actions.

37

(

\\

PROCEDURE TiTLE PAGE 27 PROCeDURE NO LOSS OF INSTRUMENT AIR 9 of 19 2-1010030 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS CAUTION The ability to maintain Steam Generator levels at full power conditions may be affected as instrument air pressure degrades below 75 PSIG. Air operated valves and instrumentation may lose full range operating capability. Appendix C contains a partial listing of air operated components and their mode of failure upon loss of air supply.

7.

U instrument air pressure decreases to less than 75 psig, Then evaluate the need to shut down the unit in accordance with 2-GOP-123, Turbine Shutdown Full Load to Zero Load, or 2-EOP-01, Standard Post Trip Actions.

8.

U feedwater regulating 15% bypass valves are being used to maintain S/G level, Then use of the Auxiliary Feedwater System will be required if air pressure continues to degrade

9.

11 SOC is In serVice, Then refer to ONOP 2-0440030. Shutdown Cooling Off-Normal

10.

11 BOTH of the following conditions exist:

Loss of CCW to the RCPs, due to loss of Instrument Air pressure CCW can NOT be restored within 10 minutes Then PERFORM ALL of the following:

A.

TRIP the Reactor B.

TRIP the Turbine C.

TRIP ALL the RCPs.

D.

GO TO 2-EOP-01, Standard Post Trip Actions.

37

Appendix D IF--

Ii Op Test No_:

1 Event

Description:

1 Operator Action Form ES-D-2 Scenario #

7 Event #

_7;.;.,..;;.8:..;, 9~ __ Page ~

of Loss of Instrument Air pressure. Plant down power, Unit trip. Three CEA's do not fully insert. Stop all RCP's due to CCW unrecoverable.

,C'_' -~~='""i'F=====~=~=-======:====:~=======c==-=====~~1 il_

Time Position A

licant's Actions or Behavior 1--

h Operator Instructions:

Boot Indic ations Available:

Directs implementation of 2-EOP-01, "Standard Post Trip Actions" as follows:

Identifies three CEA's not fully inserted. Directs Emergency SRO I Boration.

RO: Reactivity control, Inventory Control, Pressure I

control, Core Heat Removal I

BOP: Vital Auxiliaries, RCS heat removal, Containment Conditions.

Critical Direct stopping RCP's within 10 minutes of loss of CCW Task

1----

---1---'

Notify NPO to perform Appendix X (NPO Actions) section 1 of BOP EOP-99. attached pa e 39-42_)

I g -

Performs EOP-01 Safety functions as directed for: Maint of Vital Auxiliaries RCS Heat Removal, Containment Conditions

---~i------+--------------------------------------

BOP

_ _____________ L_

Maintenance of Vital Auxiliaries Verifies turbine governor and throttle valves closed Verify GEN Brk open (East breaker, Mid Breaker and Exciter Breaker)

Verify all vital and non vital AC Buses energized. (2A 1, 2A2, 2A3 2AB, 2B1, 2B2 and 2B3 6.9 and 4.16kv buses)

{

\\

(

Appendix D ii I! Op Test No.

[i Event Description II

.1 Operator Action Form ES-D-2 Scenario #

7 Event #

7, 8, 9 Page ~

of dl Loss of Instrument Air pressure. Plant down power, Unit trip. Thre.e.CEA> I do not fully insert. Stop a(( RCP's due to CCW unrecoverable.

Booth Operator Instructions

f-.. --.. -.--.. ---~

.... -------------------------------------j Indications Available:

SRO

-rr?irects implementation of 2-EOP-01, "Standard Post Trip

! Actions" as follows:

I Identifies three CEA's not fully inserted. Directs Emergency I 80ration.

RO: Reactivity control, Inventory Control, Pressure control, Core Heat Removal i

BOP: Vital Auxiliaries, RCS heat removal, Containment I Conditions.

I

.. -------i--+--------------------..I

[

i I

Critical Task Direct stopping RCP's within 10 minutes of loss of CCW BOP I

Notify NPO to perform Appendix X (NPO Actions) section 1 of

EOP-99. (attached page_39-42_)

il-p-e-rf-o~r-ms EOP-01 Safety functions as directed for Maint of I Vital Auxiliaries RCS Heat Removal, Containment Conditions I

c-" -- -----1"--------1,--------------------------- --I i

-~---I I

I BOP Maintenance of Vital Auxiliaries Verifies turbine governor and throttle valves closed Verify GEN Brk open (East breaker, Mid Breaker and Exciter Breaker)

Verify all vital and non vital AC Buses energized. (2A1, 2A2, 2A3 2AB, 2B1, 282 and 283 6.9 and 4.16kv buses)

---~

REVISION NO PROCEDURE TITLE PAGE.

36A PROCEDURE NO 2-EOP-99 APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 1 of 8)

NOTE This appendix contains two sections. Each section has instructions for stabilization of the secondary plant following a unit trip.

Section 1 provides the field instructions that are performed in the Turbine Generator Building during execution of 2-EOP-01 111 of 156 Section 2 provides the control room instructions that are performed after 2-EOP-01 has been exited Section 1: FIELD ACTIONS INSTRUCTIONS o 1. CONFIRM Turbine trip with the Control Room.

o 2. PERFORM ALL of the following from the Turbine Deck:

o A. VERIFY ALL Main Steam Safety Valves are CLOSED.

CONTINGENCY ACTIONS o A.1 If ANY Main Steam Safety Valves are OPEN, Then immediately NOTIFY the Control Room.

o B. VERIFY ALL of the following 0 B.1 11 ANY Turbine Valves are NOT Turbine valves are CLOSED:

fully CLOSED, Then locally TRIP the Turbine.

o Governor Valves o Throttle Valves o Intercept Valves o Reheat Valves 39

(

I,EVISION NO PROCEDURE TITLE PAGE 36A PROCEDURE NO 2-EOP-99 APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 1 of 8)

NOTE This appendix contains two sections_ Each section has instructions for stabilization of the secondary plant following a unit trip_

Section 1 provides the field instructions that are performed in the Turbine Generator Building during execution of 2-EOP-01 111 of 156 Section 2 provides the control room instructions that are performed after 2-EOP-01 has been exited Section 1: FIELD ACTIONS INSTRUCTIONS D 1. CONFIRM Turbine trip with the Control Room_

D 2. PERFORM ALL of the following from the Turbine Deck:

D A. VERIFY ALL Main Steam Safety Valves are CLOSED D B. VERIFY ALL of the following Turbine valves are CLOSED D Governor Valves D Throttle Valves D Intercept Valves D Reheat Valves 39 CONTINGENCY ACTIONS D A.1 11 ANY Main Steam Safety Valves are OPEN, Then immediately NOTIFY the Control Room.

D B.1 11 ANY Turbine Valves are NOT fully CLOSED, Then locally TRIP the Turbine

REVISION NO 36A PROCEDURE NO.

2-EOP-99 PROCEDURE TITLE APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 2 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE 112 of 156 INSTRUCTIONS CONTINGENCY ACTIONS II NOTE II II The remainder of the steps in this section may be performed in any order.

II o 3. PERFORM ALL of the following from the Ground Floor Level:

o A. ADJUST FCV-12-1.

Condensate Hdr Recirc to Cndsr. as required to maintain Condensate flow of 8.000 gpm.

o B. PERFORM BOTH of the following to ALIGN cooling water to the Heater Drain Pumps. until water is flowing out the packing gland:

o THROTTLE OPEN V38238, DMW to 2A Htr Drain Pump Gland Quench Seallsol.

o THROTTLE OPEN V38239. DMW to 2B Htr Drain Pump Gland Quench Seal Isol o C. CLOSE V31190, Processed Bldn (Vacuum Drag) to 2B Cndsr Isol.

o D. OPEN SB13139, TCW Pumps Disch Cross-Tie. Isol.

40

(

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 2 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE 112 of 156 INSTRUCTIONS CONTINGENCY ACTIONS II NOTE II II The remainder of the steps in this section may beperformed in any order.

II o 3. PERFORM ALL of the following from the Ground Floor Level:

o A. ADJUST FCV-12-1, Condensate Hdr Recirc to Cndsr. as required to maintain Condensate flow of 8.000 gpm o B. PERFORM BOTH of the following to ALIGN cooling water to the Heater Drain Pumps, until water is flowing out the packing gland o THROTTLE OPEN V38238, DMW to 2A Htr Drain Pump Gland Quench Seal Isol.

o THROTTLE OPEN V38239. DMW to 2B Htr Drain Pump Gland Quench Seal Isol o C. CLOSE V31190, Processed Bldn (Vacuum Drag) to 2B Cndsr Isol o D. OPEN SB13139, TCW Pumps Disch Cross-Tie Iso1.

40

~~~~.~.-.--.--

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 3 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE:

113 of 156 INSTRUCTIONS CONTINGENCY ACTIONS o 4. PERFORM BOTH of the following from on top of the TLO Reservoir:

o A. VERIFY ONE of the following o 1. Bearing Oil Pump and Seal Oil Backup Pump RUNNING.

o 2. Emergency Oil Pump

RUNNING, o B. VERIFY Bearing Oil Lift Pump

RUNNING, o 5. PERFORM ALL of the following from the Mezzanine Deck:

o A. THROTTLE OPEN V09218, S/G Fill Isol, 15 to 20 turns.

o B. THROTTLE OPEN BOTH of the following valves to establish EACH Hood Spray between 200 and 250 psig:

o V12396, 2A LP Turb Spray Hdr TCV-22-61 A Bypass o V12403, 2B LP Turb Spray Hdr TCV-22-61 B Bypass (continued on next page) 41

(

REVISION NO 36A PRoceDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS S1. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 3 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE 113 of 156 INSTRUCTIONS CONTINGENCY ACTIONS o 4. PERFORM BOTH of the following from on top of the TLO Reservoir:

o A. VERIFY ONE of the following o 1. Bearing Oil Pump and Seal Oil Backup Pump RUNNING.

o 2. Emergency Oil Pump RUNNING.

o B. VERIFY Bearing Oil Lift Pump RUNNING o 5. PERFORM ALL of the following from the Mezzanine Deck o A. THROTTLE OPEN V09218, S/G Fill Isol, 15 to 20 turns.

o B. THROTTLE OPEN BOTH of the following valves to establish EACH Hood Spray between 200 and 250 psig:

o V12396, 2A LP Turb Spray Hdr TCV-22-61A Bypass o V12403, 26 LP Turb Spray Hdr TCV-22-61 B Bypass (continued on next page) 41

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 4 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE 114 of 156 INSTRUCTIONS CONTINGENCY ACTIONS

5. (continued)

C.

VERIFY ALL of the following valves CLOSED:

0 SC-10-3A, 3A LP Htr Extr Stm Non Return 0 SC-10-38, 3B LP Htr Extr Stm Non Return 0 SC-10-4A, 4A LP Htr Extr Stm Non Return 0 SC-10-48, 4B LP Htr Extr Stm Non Return 0 SC-10-5A, 5A HP Htr Extr Stm Non Return o SC-10-58, 5B HP Htr Extr Stm Non Return o 6. From the Turbine Deck, VERIFY the Turning Gear is ready for operation.

o 7. When Section 1 Field Actions are

COMPLETE, Then NOTIFY the Control Room.

End of Section 1 42

(

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS S1. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 4 of 8)

Section 1: FIELD ACTIONS (continued)

PAGE 114 of 156 INSTRUCTIONS CONTINGENCY ACTIONS

5. (continued)

C.

VERIFY ALL of the following valves CLOSED 0 SC-10-3A, 3A LP Htr Extr Stm Non Return 0 SC-10-3B, 3B LP Htr Extr Stm Non Return 0 SC-10-4A, 4A LP Htr Extr Stm Non Return 0 SC-10-4B, 4B LP Htr Extr Stm Non Return 0 SC-10-5A, 5A HP Htr Extr Stm Non Return 0 SC-1 0-5B, 5B HP Htr Extr Stm Non Return o 6. From the Turbine Deck, VERIFY the Turning Gear is ready for operation.

o 7. When Section 1 Field Actions are

COMPLETE, Then NOTIFY the Control Room.

End of Section 1 42

Appendix D Operator Action Form ES-D-2 I! Op Test No.:

Scenario #

7 Event #

-.;..:7'...;8~,.;.,9 ___ Page ~

of....;;.,;20;"-'-11 II Event

Description:

Loss of Instrument Air pressure. Plant down power, Unit trip. Three CEA's do not fully insert. Stop all RCP's due to CCW unrecoverable.

i~--~~me Position A

licant's Actions or Behavior

~-Bo~-th O~~rator Instructions: Suggested: Trigger Event 10, LOCA when RCP's I

have been stopped.

-I

. Indications Available:

.------------ ----r---------,---------------------------1 Ii RC~ H:a~r~::~::lst one SG has feedwater available (MFW pumps will trip on low flow due to recirc valves failing BOP closed on loss of air)

Verify RCS Tavg is between 525 and 535 0 F Place ADV's in service due to loss of air to SBCS valves.

i--------i------------------------------I I

[ Containment Conditions Verify containment pressure <2 psig Verify NO containment radiation monitors in alarm Verify containment temperature is less than 120 0 F Verify NO secondary plant radiation alarms

-----------------+------1---------------------------1

~ _______ +-.i ___ -+----___________

--1 I

Identifies three CEA's not fully inserted. Initiates emergency

, boration by:

Place the Makeup Mode Selector switch in Manual RO Ensure V2525, Boron Load Control valve closed Start 2A or 2B BA Pump Close V2650 Tank 2A Recirc Valve

Close V2651 Tank 2B Recirc Valve

Open V2514, Emergency Borate I------~---- -+-----+--------------------------\\

1-Performs EOP*01 Safety Functions as directed for Reactivity I

i Control, Inventory Control, Pressure Control, Core Heat

, _________ I _____ -II_r_e_m_o_v_a_I ____________________

--i I

.-- -- ---------1----------+--------------------------1 Critical Task Start RCP oil lift pumps and stop all RCP's when directed.

NOTE: Trigger Event 10, LOCA, when all RCP's are stopped

(

Appendix D Operator Action Form ES-D-2 fi~----.

il

Op Test No.

11 Scenario #

7 Event #

7, 8, 9 Page _15_ of 20 i

Ii Event Description Loss of Instrument Air pressure. Plant down power, Unit trip. Three CEA's I do not fully insert Stop all RCP's due to CCW unrecoverable.

I J=::Eosition JI

.... _ J Ir' Time A plica nt's Actions or Behavior

, Booth Operator Instructions: Suggested: Trigger Event 10, LOCA when RCP's

... ~.'~ __ '

have been stopped.

_~

Indications Available:

i T

I RC~ H:a~r~::t~::lst one SG has feedwater available (:~-- -II pumps will trip on low flow due to recirc valves failing I. Ii' I -

BOP closed on loss of air)

Verify RCS Tavg is between 525 and 535 0 F Place ADV's in service due to loss of air to SBCS valves.

I Containment Conditions I

I Verify containment pressure <2 psig Verify NO containment radiation monitors in alarm 1~._v_e_r_if_y_Containment temperature is less than 120 0

F

-+-

Verify NO secondary plant radiation alarms

.t-, *~-+I ~--~

-~~

I Identifies three CEA's not fully inserted. Initiates emergency

, boration by Place the Makeup Mode Selector switch in Manual RO Ensure V2525, Boron Load Control valve closed Start 2A or 2B BA Pump Close V2650 Tank 2A Recirc Valve Close V2651 Tank 2B Recirc Valve Open V2514, Emergency Borate i

~-~----*I I

I Performs EOP-01 Safety Functions as directed for Reactivity

Control, Inventory Control, Pressure Control, Core Heat I

. I _____ ~-tI~r~e~m~o~v~a~1 ~~

__ ~ _______ ~~_~~_

._~~----<

I

-_.. _.. -- -.. ~~~-+-~~~~-~~~-.... -.~~~.~~~~-

~-------j Critical Task Start RCP oil lift pumps and stop all RCP's when directed.

~~~

L... _____

~_~~_~~~~~~

~~~~_---j NOTE: Trigger Event 10, LOCA, when all RCP's are stopped

~-~~~-

Appendix D Operator Action Form ES-D-2 Ii Op Test No,

" 'I Scenario #

7 Event #

_7;..:"..;.8:...;,9;....-__ Page ~

of _2_0--i1

!I Event

Description:

Loss of Instrument Air pressure. Plant down power, Unit trip, Three CEA's do not fully insert, Stop all RCP's due to CCW unrecoverable, Position A

licant's Actions or Behavior

Booth Operator Instructions:

~-.---.,

i Indications Available:

r---'

~----------------------------------------------~

Reactivity Control Verify Reactor power is lowering.

]

Verify startup rate is negative, I

Verify a maximum of one CEA is not fully inserted.

Inventory Control Verify pressurizer level is between 10 and 68%

I Pressurizer level is trending to 30 - 35%

I

.-,,--,,--,,-"'j.---------+---------------------------------------<

!,,---T i

Pressure Control Verify RCS pressure is between 1800-2300 psia I

\\

Verify RCS pressure is trending 2225-2275 psia (control

'I manually due to loss of air to spray valves)

Verify RCS subcooling is >20 0 F

+------+----------------------1 Core Heat Removal Verify at least one RCO running with CCW (identifies CCW unable to be restored due to loss of air to valves)

Verify loop delta T is <10° F i--"-""------+-------+---------------------------------------

~----'-"-+-----+-------.-------------~

~--_-~~ I SRO I Exits 2-EOP~01 to 2-EOP-_O,_9 _LO_O_P_/L_O_F_C ______ ~

f----

NOTE: If RCS leakage identified while in 2-EOP-01, 2-EOP-09 LOOP/LOFC will probably NOT be entered and 2-EOP-03 LOCA will be entered from 2-EOP-01.

I

.--... ~-

Direct Safety Function Status Check's performed every 15 minutes r-Direct Appendix A EOP-99 Sample SG's (attached page 45,46)

I i

(

Appendix 0 Operator Action Form ES-0-2 i

il Op Test No.

1 Scenario #

7 Event #

7, 8, 9 Page,]L of _20_-11 I: Event Description Loss of Instrument Air pressure. Plant down power, Unit trip. Three CEA's Ii do not fully insert. Stop all RCP's due to CCW unrecoverable.

L:i~~-_-=1~~p~0~s~llio~n~"""-=~==~~=~A=PI~ic~an~t~'s~A~C~tio~n=s~o~r~B~eh~a~v~io~r=~===~~~1

Booth Operator Instructions:

Indications Available:

--.------.---------------,!----------------------------i i Reactivity Control I

Verify Reactor power is lowering, I

. Verify startup rate is negative.

__.. !------L. Verify a maxim~m of one CEA is not fully inserted, 1

I Inventory Control I

Verify pressurizer level is between 10 and 68%

____ -+. __. __

p_r_es_s_u_r_iz_e_r_le_vel is trending to 30 - 35%

.--t---

I Pressure Cantrall i

Verify RCS pressure is between 1800-2300 psia I

I Verify RCS pressure is trending 2225-2275 psia (control II I

manually due to loss of air to spray valves)

Verify RCS subcooling is >20° F I

.. -=--+-+-----~-.------ -

j I Core Heat Removal Verify at least one RCO running with CCW (identifies CCW unable to be restored due to loss of air to valves)

J I

Verify loop delta T is <10° F 1---

- ---------t--- ___ +--__. _____

e.~_

I

==-__

-~~ 1 ___ SRo_~i Exits 2-EOP-01 to 2-ECJP_~_0_9_LO_O_P_/L_O_F_C ______

___j-1 l---------.~

I

JI NOTE: If RCS leakage identified while in 2-EOP-01, 2-EOP-09 LOOP/LOFC will I

praba~~~T-_~-T-be entered and 2-~_O_P_-_03~OCA will be entered from 2-EOP-01.

I Oi,rect Safety Fu~~t-;on Status Check's performed every 15

! minutes n.-_

i

[~~ l==~--n----j.-o-irect Appendix A EOP-99 Sample SG's (attached pag~-45,46) I

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 1 of 2) o 1, 11 a LOOP has occurred, Then PERFORM BOTH of the following:

o A, ENSURE 2AB 480V Load Center is aligned to an energized bus.

o B. DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 2B Instrument Air Compressors.

CAUTION PAGE 3 of 156 Under SIAS conditions the CCW 'N' header should only be aligned to ONE essential header. This will maintain train separation while safeguards slqnals are still present.

NOTE HCV-14-9 (HCV-14-10) will open 5 seconds after HCV-14-8A (HCV-14-8B) starts to open When SIAS is present, placing the control switches in CLOSE and then OyERRIDE will open the CCW 'N' header valves, until SIAS is reset o 2. !f SIAS has closed the 'N' Header valves, Then RESTORE flow from EITHER 'A' or 'B' CCW Header by PLACING the control switches for the deSired train to CLOSE and then to OVERRIDE:

HCV-14-8A HCV-14-9 OR HCV-14-8B HCV-14-10 39 45

(

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 1 of 2) o 1. if a LOOP has occurred, Then PERFORM BOTH of the following:

o A. ENSURE 2AB 480V Load Center is aligned to an energized bus.

o 8. DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 2B Instrument Air Compressors CAUTION PAGE 3 of 156 Under SIAS conditions the CCW 'N' header should only be aligned to ONE essential header. This will maintain train separation while safeguards Signals are still present.

NOTE HCV-14-9 (HCV-14-10) will open 5 seconds after HCV-14-8A (HCV 8B) starts to open When SIAS is present, placing the control switches in CLOSE and then OyERRIDE will open the CCW 'N' heade~ valves, until SillS is reset o 2. !f SIAS has closed the 'N' Header valves, Then RESTORE flow from EITHER 'A' or 'B' CCW Header by PLACING the control switches for the desired train to CLOSE and then to OVERRIDE' HCV-14-8A HCV-14-9 OR HCV-14-8B HCV-14-10 39 45

--~----------------

REVISION NO PROCEDURE TITLE PAGE:

36A PROCEDURE NO.

2*EOP-99 APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 2 of 2) o 3. If CIAS or high radiation has closed the SGBD Sample Valves, Then OPEN FCV-23-7 and FCV-23-9 by PLACING the control switch to CLOSE I OVERRIDE and then to OPEN.

o 4. DIRECT Chemistry to perform SIG samples for activity and boron.

o 5. !.f SIGs cannot be sampled, Then DIRECT Health Physics to conduct secondary plant local area radiation surveys END OF APPENDIX A 40 46 4 of 156

(

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES / FIGURES / TABLES / DATA SHEETS ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 2 of 2) o 3. If CIAS or high radiation has closed the SGBD Sample Valves, PAGE.

4 of 156 Then OPEN FCV-23-7 and FCV-23-9 by PLACING the control switch to CLOSE / OVERRIDE and then to OPEN, o 4, DIRECT Chemistry to perform S/G samples for activity and boron.

o 5, IJ S/Gs cannot be sampled, Then DIRECT Health Physics to conduct secondary plant local area radiation surveys END OF APPENDIX A 40 46

Appendix D r--

II Op Test No.:

1 II

! Event

Description:

II Time Position Operator Action Form ES-D-2 Scenario #

7 Event #

_7~'..;;.8,_9 ___ Page 1L-of _20_..,1 Loss of Instrument Air pressure. Plant down power, Unit trip. Three CEA's do not fully insert. Stop all RCP's due to CCW unrecoverable.

A plicant's Actions or Behavior i Booth Operator Instructions:

~---.---------------------------------------------------~

Indications Available

I I

SRO Verify CCW to the RCP's. If CCW lost to the RCP's for greater than 30 minutes:

Ensure CCW will remain isolated by placing the FOUR Containment CCW To/From RC Pump valves to CLOSE Ensure RCP controlled Bleedoff will remain isolated by placing the TWO RCP Bleedoff valves to close.

Stabilize the secondary plant. Direct Appendix X Section 2

.. _._.. _.. ___. __ I_._.... ____,_Stabilize RCS temperature to <535°F Teold using ADV_'_S ____

--11

. -... ------l-

~... -.

I*

I Direct m_~.nually starting AFW pumps and feeding SG's

=-C--'-

I I

I

~---.. -

I I i I

I I

---t*-**

I I

.1--

RO STA BOP When directed, depressurize the RCS to between 1800 and 1850 psia using auxiliary spray SE*02-3 and SE-02-4.

When directed, stabilize RCS temperature to <535°F Teold using ADV's

--~--

Identify Cavity leakage increasing, RCS pressure and level I dropping.

I When directed perform Safety Function Status Check's performed every 15 minutes When directed start A and B AFW pumps, open discharge valves and throttle AFW flow to A and B SG's.

I i

~

1 When directed perform Appendix X Section 2 (attached I

page _ 48-51_)

I

(

Appendix 0 Operator Action Form ES-O-2

~~~-"------"-"

Scenario #

7 Event #

7, 8, 9 Page 2Z-- of ~.

i Ii Op Test No 1

1 Ii Loss of Instrument Air pressure. Plant down power, Unit trip Three CEA's Event

Description:

do not fully insert. Stop all RCP's due to CCW unrecoverable.

Position A plicant's Actions or Behavior

~--"--"--------------------------------,

Booth Operator Instructions:

i

. Indications Available:

SRO I Verify CCW to the RCP's. If CCW lost to the RCP's for greater I

i. than 30 minutes:

I Ensure CCW will remain isolated by placing the FOUR Containment CCW To/From RC Pump valves to CLOSE

"-. ~~"-+--------- t-Ensure RCP controlled Bleedoff will remain isolated by I

placing the TWO RCP Bleedoff valves to close. ---I

~

i-

_=~=r:SRO I Stabilize the secondary plant Direct Appendix X Section 2

--1-----------+__

I I

! Stabilize RCS temperature to <535°F Tcold using ADV's I

---"-"""-*""-"---"-------r"""-

'i

~-~+--~--I-Direct m~nually starting AFW pump~ and feedi~g-S-G-'S----~

i

*-1

"-- +----~-------~

~

I RO

~--.-------:----

When directed, depressurize the RCS to between 1800 and

'I 1850 psia using auxiliary spray SE-02-3 and SE-02-4.

I When--directed, stabilize RCS temperature to <535°F Tcold using I I

ADV's I

~-~

I

~

---+----!Identify Cavity leakage increasing, RCS pressure and l~v~I-- ----l

, dropping.

-" """-"~--"--+

=J

"_"" _______ ~i -- STA-i When directed perform Safety Function Status Check's i

t---.----

BOP I

.. ---"-.---~

~.-

I performed every 15minutes I

-~!-------------------------~

I When directed start A and B AFW pumps, open discharge I valves and throttle AFW flow to A and B SG's.

When directed perform Appendix X Section 2 (attached page_ 48-51_)

--__ " _______ J

REVISION NO PROCEDURE TITLE PAGE:

36A PROCEDURE NO APPENDICES I FIGURES I TABLES I DATA SHEETS 115 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 5 of 8)

Section 2: CONTROL ROOM ACTIONS INSTRUCTIONS o 1. ENSURE ONLY ONE MFW Pump is RUNNING, with the control switch in RECIRC o 2. ENSURE ONLY ONE Condensate Pump is RUNNING, o 3. !f AFAS has actuated, and use of Main Feedwater is

desired, Thel} PERFORM ALL of the fol/owing:

o A. ENSURE AFAS is RESET, o B. ENSURE BOTH S/G [Main FRVl Block valves CLOSED,

1. MV-09-5

2. MV-09-6 o C. ENSURE BOTH Low Power MIA Stations in MANUAL, o D. For EACH MFW header to be placed in service, ENSURE the associated MFIVs are

OPEN, o E. DEPRESS BOTH pushbuttons to RESET the Low Power Feedwater Valves, 48 CONTINGENCY ACTIONS o 3.1 !f AFAS has NOT actuated and use of Main Feedwater is

desired, Then PERFORM ALL of the following:

o A. ENSURE BOTH S/G [Main FRV] Block valves CLOSED, o B. For EACH MFW header to be placed in service, ENSURE the associated MFIVs are OPEN, o C. ENSURE BOTH Low Power MIA Stations in MANUAL, o D. DEPRESS BOTH pushbuttons to RESET the Low Power Feedwater

Valves, o E. ADJUST the Low Power MIA Stations AS NECESSARY to control SIG levels,

(

REVISION NO PROCEDURE TITLE PAGE 36A PROCEDURE NO APPENDICES I FIGURES I TABLES I DATA SHEETS 115 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 5 of 8)

Section 2: CONTROL ROOM ACTIONS INSTRUCTIONS o 1. ENSURE ONLY ONE MFW Pump is RUNNING, with the control switch in RECIRC o 2. ENSURE ONLY ONE Condensate Pump is RUNNING.

o 3. 11 AF AS has actuated, and use of Main Feedwater is

desired, TheQ PERFORM ALL of the following' o A. ENSURE AFAS is RESET.

o B. ENSURE BOTH S/G [Main FRVl Block valves CLOSED.

1. MV-09-5

2. MV-09-6 o C. ENSURE BOTH Low Power MIA Stations in MANUAL.

o D. For EACH MFW header to be placed in service, ENSURE the associated MFIVs are OPEN.

o E. DEPRESS BOTH pushbuttons to RESET the Low Power Feedwater Valves.

48 CONTINGENCY ACTIONS o 3.1 11 AFAS has NOT actuated and use of Main Feedwater is

desired, Then PERFORM ALL of the following:

o A. ENSURE BOTH S/G [Main FRV) Block valves CLOSED o B. For EACH MFW header to be placed in service, ENSURE the associated MFIVs are OPEN.

o C. ENSURE BOTH Low Power MIA Stations in MANUAL.

o D. DEPRESS BOTH pushbuttons to RESET the Low Power Feedwater Valves.

o E. ADJUST the Low Power MIA Stations AS NECESSARY to control S/G levels.

REVISION NO.

36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE' APPENDICES I FIGURES I TABLES I DATA SHEETS ST, LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 6 of 8)

PAGE, 116 of 156 Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

3. (continued) o F. ADJUST the Low Power MIA Stations AS NECESSARY to control S/G levels, o G. RESTORE AFW to the standby alignment, o 4. ENSURE BOTH Heater Drain Pumps are STOPPED.

o 5. ENSURE BOTH of the following:

o A. Bearing Oil Pump and Seal Oil Backup Pump

RUNNING, o B. When the turbine reaches 600 rpm, Then Bearing Oil Lift Pump RUNNING.

o 6. ENSURE the Turbine Drain Valves are OPEN o 7. ENSURE ONLY ONE Turbine Cooling Water Pump is RUNNING, o B. VERIFY Turbine Generator Bearing Oil temperature between 110 to 120°F 49 o A.1 ENSURE Emergency Bearing Oil Pump RUNNING, o 8,1 DIRECT a field operator to adjust TCW to the in-service TLO Cooler to maintain outlet Oil temperature between 110 to 120°F.

(

(,

REVISION NO 36A PROCEDURE NO 2-EOP-99

.~ ~

PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 6 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

PAGE 116 of 156 INSTRUCTIONS CONTINGENCY ACTIONS

3. (continued) o F. ADJUST the Low Power MIA Stations AS NECESSARY to control S/G levels.

o G. RESTORE AFW to the standby alignment.

o 4. ENSURE BOTH Heater Drain Pumps are STOPPED.

o 5. ENSURE BOTH of the following o A. Bearing Oil Pump and Seal Oil Backup Pump RUNNING.

o B. When the turbine reaches 600 rpm.

Then Bearing Oil Lift Pump RUNNING.

o 6. ENSURE the Turbine Drain Valves are OPEN o 7. ENSURE ONLY ONE Turbine Cooling Water Pump IS RUNNING.

o 8. VERIFY Turbine Generator Bearing Oil temperature between 110 to 120°F 49 o A.1 ENSURE Emergency Bearing Oil Pump RUNNING.

o 8.1 DIRECT a field operator to adjust TCW to the in-service TLO Cooler to maintain outlet Oil temperature between 110 to 120°F.

REVISION NO PROCEDURE TITLE PAGE:

36A PROCEDURE NO APPENDICES / FIGURES / TABLES / DATA SHEETS 117 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 7 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS o 9. When Turbine speed reaches ZERO 09.1 PERFORM ALL of the following:

rpm, Then VERIFY the turning gear automatically ENGAGES.

o 10.11 Reactor power history is low, Then CONSIDER reducing steam generator blowdown now to maintain RCS temperature.

o 11. Place Boron Dilution Alarm System in Operation.

When indicated Reactor power is less than 10'5%,

Then PERFORM BOTH of the following:

o A. ENERGIZE BOTH channels of Startup Nuclear Instrumentation to place the Boron Dilution Alarm System in operation.

o B. VERIFY BOTH Boron Dilution Alarm System Channels are operating.

50 o A. PLACE Turning Gear in MANUAl.

o B. VERIFY the Turning Gear Permissive Light is ON.

o C. locally ENSURE the Turning Gear is ENGAGED.

o D. locally START the Turning Gear.

o 11.1 11 BOTH Boron Dilution Alarm System channels are NOT operating, Then PERFORM applicable actions of ONP-02.01, Boron Concentration Control.

(

REVISION NO PROCEDURE TITLE PAGE 36A PROCEDURE NO APPENDICES I FIGURES / TABLES I DATA SHEETS 117 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 7 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS o 9. When Turbine speed reaches ZERO 09.1 PERFORM ALL of the following

rpm, Then VERIFY the turning gear automatically ENGAGES.

o 10.lf Reactor power history is low, Then CONSIDER reducing steam generator blowdown flow to maintain RCS temperature.

o 11. Place Boron Dilution Alarm System in Operation.

When indicated Reactor power is less than 10.5%,

Then PERFORM BOTH of the following o A. ENERGIZE BOTH channels of Stanup Nuclear Instrumentation to place the Boron Dilution Alarm System in operation.

o B. VERIFY BOTH Boron Dilution Alarm System Channels are operating.

50 o A. PLACE Turning Gear in MANUAL o B. VERIFY the Turning Gear Permissive Light is ON.

o C. Locally ENSURE the Turning Gear is ENGAGED.

o D. Locally START the Turning Gear.

o 11.1 If BOTH Boron Dilution Alarm System channels are NOT operating, Then PERFORM applicable actions of ONP-02.01, Boron Concentration Control.

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES / FIGURES / TABLES / DATA SHEETS ST, LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 8 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

PAGE; 118 of 156 INSTRUCTIONS CONTINGENCY ACTIONS NOTE Excessive moisture can build up in CEDMC's room, and impact equipment reliability if 15 KW heaters are not energized after plant shutdown, o 11.NOTIFY SNPO to energize 15 KW heater located in the CEDMC's room to minimize humidity build-up per 2-NOP-25, 1 0, CEDMCS Air Conditioning System Operation, o 12.CONSIDER contacting the Division Load Dispatcher for a switching order to OPEN the Main Generator disconnects END OF APPENDIX X 51

(

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 8 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

PAGE.

118 of 156 INSTRUCTIONS CONTINGENCY ACTIONS NOTE Excessive moisture can build up in CEDMC's room, and impact equipment reliability If 15 KW heaters are not energized after plant shutdown.

o 11. NOTIFY SNPO to energize 15 KW heater located In the CEDMC's room to minimize humidity build-up per 2-NOP-2510, CEDMCS Air Conditioning System Operation o 12. CONSIDER contacting the DIvision Load Dispatcher for a switching order to OPEN the Main Generator disconnects END OF APPENDIX X 51

Appendix D II Op Test No.

Ii Event

Description:

Operator Action Form ES-D-2 Scenario #

7 Event #

7, 8, 9 Page

_18_ of

...;:;.;20'--~1 Loss of Instrument Air pressure. Plant down power, Unit trip. Three CEA's do not fully insert. Stop all RCP's due to CCW unrecoverable.

Time II Position II Applicant's Actions or Behavior lBO_~!~_ <?~_~rator Instructions:

Indications Available:

.----,----~-- ----

BOP

When directed perform Appendix A EOP-99 Sample SG's

, (attached page_ 45,46_)

- - --**-+1-------+---------------------------1 BOP When directed:

Ensure CCW will remain isolated by placing the FOUR Containment CCW To/From RC Pump valves to CLOSE Ensure RCP controlled Bleedoff will remain isolated by placing the TWO RCP Bleedoff valves to close,

. -----1---*--+-----------

.~---.-----.-.. -.----.-.---_1 i

1 I

,... __.. _-+_.

--.. -.----.--1........ -.---1-------------------------1 i

._----+----+-----_.

f----~-------+------------------------__j L

(

Appendix D Op Test No Event Description' Time _:_'J Position

~

Operator Action Form ES-D-2 Scenario #

7 Event #

7,8,9 Page

_18_ of ~I Loss of Instrument Air pressure. Plant down power, Unit trip. Three CEA's I do not fully insert. Stop all RCP's due to CCW unrecoverable.

I Ap licant's Actions or Behavior i Booth Operator Instructions:

Indications Available:

BOP

When directed perform Appendix A EOP-99 Sample SG's

, (attached page_ 45,46_)

I

---~--

When directed:

Ensure CCW will remain isolated by placing the FOUR BOP Containment CCW To/From RC Pump valves to CLOSE I

fl.. Ensure RCP controlled Bleedoff will remain isolated by placing the TWO RCP Bleedoff valves to close.

-. _______._.----r--~______

-.. ~.~_. ___..

~

i

-- --1--------

I

_____. ________________ um ____

___________ -i i

I

[-

-+---------------------------

~! ---+-

~-..* -=E-+------

J l

i

_... _--+".

+-_*_----------_*_---------_*-----1

.J I

i

'-.----.~---r ----

f-.-.-.------ ------r

__ ~

_________ -L. __

~-------------------

Appendix D Operator Action Form ES*D-2 Op Test No.:

i, ii Scenario #

7 Event #

10 Page 19 of 20

,: Event

Description:

ii 2B2 RCP seal failure results in SBLOCA.

t ___ Jirn~

Position A

licant's Actions or Behavior Booth Operator Instructions: When directed, trigger RCP seal failure. This will result in a 185 gpm LOCA ramping in over 10 minutes.

r- - -------------------------------------~

Indications Available: Annunciator N-46 Reactivity Cavity leakage high.

i Pressurizer pressure and level lowering.

--~~----- I SRO Implement 2-EOP*03, "Loss of Coolant Accident"

~--------+--------+----------------------------,

i II

._---+----+----------------------- ___ _________ ; ________

Directs BOP or ST A to perform SFSC's I

, --~~.. -----------+----------+----------------------------1 Contact SM to classify the event I

1 1

Direct implementation of Appendix A EOP-99 Sampling SG's, if not performed in 2-EOP-09 (attached page 45,46)

Ensure SIAS flow adequate per Figure 2 SI flow Vs. RCS pressure.

I r------------+-I ~-+-----~---------l

,-----------t-I -----------+---D-ir-e-c-ts-B-O-P-t-o-p-I-a-ce-H-yd~r-o-g-e-n-A-n-a-Iy-z-e-r -in-s-e-r-v-ic-e-p-e-r-----------1, I

I Appendix L (attached page_54,55_)

I I

i I

I

---1---- ------+-, -----------------------1 Ensures containment spray actuates if pressure reaches 5.4 psig I' BOP or I Perform Safety Functions for 2-EOP-03, "LOCA" when STA directed.

~--- -----+-------t------~-----------------------i L __ ~

___ +i ----\\----------------------1 I

[.---------.--------+----------------------------1

'--~-- - ---~--.. - -----' -

.----------------------------~--------'

(

Appendix D Operator Action Form ES-D-2 Op Test No..

Scenario #

7 Event #

10 Page 19 Event

Description:

2B2 RCP seal failure results in SBLOCA.

, Booth Operator Instructions: When directed, trigger RCP seal failure. This will result in a 185 gpm LOCA ramping in over 10 minutes.

f--

Indications Available: Annunciator N-46 Reactivity Cavity leakage high.

Pressurizer pressure and level lowering.

H---~- ___ J, __ ~~~~ __ l!mplement 2-EOP-03, "Loss of Coolant Accident': _____

j

"-~_____T_ ~--__+I--- --------,---

Directs BOP or ST A to perform SFSC's

.~

.- _**,1 __.. -------.-_"-

~--------;----

I

~_~~.. ___

"+I __

c_o_n_t_ac_t_S_M_t_o_c,_I_as_S_i_fy_t_h_e_e_v_e_n_t __. ________ ---1 i

I I

Direct implementation of Appendix A EOP-99 Sampling SG's, if not performed in 2-EOP-09 (attached page 45,46)

___ ~_~-~-,~~

__ - *** --_-'_-.:'-:I:I::::~:;-e_s-s_~:ru-e_r:;:.I-A~_*S:f:IO:W: :a:_d-e:q~U-a.-t_e:-p:e:r *F ***. -i g

u:r-e:_2:-S:1 :f_I:OW::V:S-.. :R-C----~--~---j.

Directs BOP to place Hydrogen Analyzer in service per

. __ ~ ______ \\--_A.ppendix L (attached page_54,55_)

I

~ --- ---+.----1.: Direct RO to pertorm ReS cooldown not to exceed 50'F in j anyone hour using ADV's.

-- ~---

I I

Ensures containment spray actuates if pressure reach~~

i 5.4 psig i

t------

~-..,-,----'~----f__--------------.-----------.

~-----

BOP or STA Perform Safety Functions for 2-EOP-03, "LOCA" when directed.

~------~--,~.-----+----- ----------------------j i

(

~~-~~---~-------~----

REVISION NO PROCEDURE TITLE PAGE 36A PROCEDURE NO APPENDICES I FIGURES I TABLES I DATA SHEETS 65 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX L PLACING HYDROGEN ANALYZER IN SERVICE (Page 1 of 2)

1. SELECT ONE sample point by PLACING the sample valve selector switch in the desired position FSE-27-8_ FSE-27*12 (Upper Cntmt. Dome) (Lwr Cntmt)

2. OPEN the Containment Isolation Valves.

3. ENSURE the function selector switch is in the SAMPLE position.

4. PLACE the OFF I STANDBY / ANALYZE switch to ANALYZE.

NOTE FSE-27-9_ FSE-27-13_

(pzr Area)

(262 RCP)

FSE*27-1 0_ FSE-27-14_

(2A1 RCP)

(261 RCP)

FSE-27-11_

(2A2 RCP)

FSE-27.15_ FSE-27-17_

(Sample in to H2 Analyzer)

AND FSE-27-16 FSE-27 -18 (Sample out of H2 Analyzer)

If power is Interrupted and then restored to an in-service Hydrogen Analyzer (such as after an ESFAS or Undervoltage Relay actuation) the remote control selector pushbutton must be depressed to allow for continued operation of the analyzer from the Control Room.

5. DEPRESS the remote control selector pushbutton.

6. VERIFY the red sample light energizes.

54

(

REVISION NO PROCEDURE TITLE PAGE 36A PROCEDURE NO APPENDICES I FIGURES I TABLES I DATA SHEETS 65 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX L PLACING HYDROGEN ANALYZER IN SERVICE (Page 1 of 2)

1. SELECT ONE sample point by PLACING the sample valve selector switch in the desired position.

FSE-27-8 FSE-27*12 -

(Upper Cntmt. Dome)

(Lwr Cntmt.)

2. OPEN the Containment Isolation Valves.

3. ENSURE the function selector switch is in the SAMPLE position.

4. PLACE the OFF I STANDBY I ANALYZE switch to ANALYZE.

NOTE FSE-27-9_ FSE-27-13_

(pzr Area)

(282 RCP)

FSE-27-1 0_ FSE-27-14_

(2A 1 RCP)

(2B1 RCP)

FSE-27 (2A2 RCP)

FSE-27-15 FSE-27-17 (Sample in to H2 Analyzer)

AND FSE-27-16_ FSE-27-18_

(Sample out of H2 Analyzer)

If power is Interrupted and then restored to an in-service Hydrogen Analyzer (such as after an ESFAS or Undervoltage Relay actuation) the remote control selector pushbutton must be depressed to allow for continued operation of the analyzer from the Control Room.

5. DEPRESS the remote control selector pushbutton

6. VERIFY the red sample light energizes.

54

REVISION NO PROCE DURE TITLE PAGE 36A APPENDICES I FIGURES I TABLES I DATA 66 of 156 PROCEDURE NO SHEETS 2-EOP*99 ST. LUCIE UNIT 2 APPENDIX L PLACING HYDROGEN ANALYZER IN SERVICE (Page 2 of 2)

A Train (Y)

B Train C-/)

7, START the Hydrogen Analyzer Recorder. (switch located inside recorder)

8. Allow five to ten minutes for the Hydrogen Analyzer to stabilize as indicated by the (%) indication leveling off.

END OF APPENDIX L

(

55 REVISION NO PROCEDURE TITLE PAGE 36A APPENDICES / FIGURES / TABLES / DATA 66 of 156 PROCEDURE NO SHEETS 2-EOP-99 ST_ LUCIE UNIT 2 APPENDIX L PLACING HYDROGEN ANALYZER IN SERVICE (Page 2 of 2)

A Train (0)

B Train (-:)

7, START the Hydrogen Analyzer Recorder_ (switch located inSide recorder)

~

8, Allow five to ten minutes for the Hydrogen Analyzer to stabilize as indicated by the (%) indication leveling off_

END OF APPENDIX L

(

55

Appendix D Operator Action Form ES-D-2 r---

I Op Test No.:

Scenario #

7 Event #

10 Page 20 of 20

!, Event

Description:

2B2 RCP seal failure results in SBLOCA.

i:~~=Ti~~~;_-='-b __

P~o~s~itl_on __ -b ______ -= _______

A~I~ic~a_nt~'s_A_c_ti~on=s_o=r_B=e_ha=v=io=r===-__ -==--=-=d

, Booth Operator Instructions:

Indications Available:

I RO Perform cooldown using ADV's not to exceed 50°F in anyone hour period.

~-.-'

I I

Monitor subcooling per Figure 1A RCS pressure Temperature (attached page_57_)

I I

~-~---.

-~

_~." -.-.-_O __ -----t-""_

I BOP Places the hydrogen analyzer in service per Appendix L of 2-EOP-99 (attached page_54,55_)

~. _._-_.. --..,-"

i

-_.- - -_. __.--1---- -.----.-

I Compares SI flow to RCS pressure, Figure 2. (attached I

~ ____ -+ ____ --+--I _pa_g_e_-_58_-_) __________________

--1 L.---------i----- -----+-t, ---

~-------_t_I ---j-.

I

f----+------

I

. --+---------l------

Suggested termination point:

Controlled cooldown of :S50°F in anyone hour period.

i SI fI T d ow ven Ie to meet F' Igure 2 I

I AFW flow controlled to both SG's to regain SG levels.

I

t--

I

---.. -~

i

.... ---------i--

.~ --'._".- I I

I I

I Appendix D Operator Action Form ES-D-2

~=.~

II Op Test No Scenario #

7 Event #

10 Page 20 of 20 ii Event Description 2B2 RCP seal failure results in SBLOCA Applicant's Actions or Behavior RO ------rPerform,cooldown using ADV's not to exceed 50°F in anyone i I hour period.

1

(

--=-~-T -

I Monitor subcooling per Figure 1A ReS pressure Temperature I

_____...... ______.. _1 _._.""

I (attached page_57 -)

-<I

... ---.. --------... ----r-.-- ----------------------

i BOP j Places the hydrogen analyzer in service per Appendix L of 2-I'

_._~_.. _._.+ EOP-99 (attached page_54,55_)

__ ~~~~

j.

~.... ---------.. ---iii-----------------------

I Compares SI flow to RCS pressure, Figure 2. (attached I

page_58_)

--=-j-.-I l

.~

1-I

"'-~---r I,

i Controlled cooldown of :::50°F in anyone hour period.

SI flow verified to meet Figure 2

... _____ --_-_-....... i-_.-_-_-___ --_-._

.... =:===-._-~-A-F-W-f-IO-w-c-o-nt_ro_I_le_d_t_o_b_o_t_h_S_G_'_s_t_o_r_eg_a_i_n_S_G_le_v_e_1s-*----i1 i

j

-- -_.--+----------.... _--------

I I

1-------.-.--..........,---------- -------.---------

--~----\\--------------------

i

-..... _._- ---+--_... _..........,-----------------_.. _--

(

REVISION NO PROCEDURE TITLE PAGE*

36A APPENDICES / FIGURES / TABLES / DATA 119 of 156 PROCEDURE NO SHEETS 2*EOP*99 ST. LUCIE UNIT 2 FIGURE 1A RCS PRESSURE TEMPERATURE (Page 1 of 1)

(Containment Temperature Less Than or Equal to 200°F)

CAUTION The RCP NPSH curve assumes one pump is operating in each loop. RCP instrumentation should be monitored for seal and pump performance in accordance with 2*EOP*99, Table 13.

2<00 1:."""~"~'_~''''w<'''''''''''.1 an;. 1"""."._t.o~~!qf'fIItMpt~~\\~'''''V'>f VlIJOtv 01,.. QprllliQ" J..,Q 1"<1

~ CNlVI'\\"" "K *.w,.,. ro<<tr.....

EOPC<I9'II.... ~1 noo Accep'Ab~

Rif1Q\\I 2000

'800 I

MUxlmvm Suoc.oOIW"......

~

'600 if 1400

//

I I

';>00 I

I I

\\

I

\\

I

'000

/

I

\\

I I

M.rllnll,Jrn I

SvPCoQIfH" I

I 600

""~'" 1 '

Reqlllremerw ~

wo

/~--

'00

'\\nc1udn InlllV~l'lt LIn('tnllf\\l,.,

100 Shu,do_ E.'/~ I 0

0

'00 200 300

'00 500 600 700 800 IndICa Ie<) Res Temperalure (.t")

..... '1.01 *....... 1 '~"' ** :..,.

I ReS Pressure Range Required QSPDS Subcooled Margin Reading (Rep CeT) 2250 psia to 1000 psia 40 to 180'F 1000 psia to 500 psis 50 to 170'F Less than 500 pSI a 80 to 160'F 57

(

REVISION NO 36A PROCEDURE NO 2-EOP-99 PROCEDURE TITLE APPENDICES I FIGURES I TABLES I DATA SHEETS ST. LUCIE UNIT 2 F!GURE 1A RCS PRESSURE TEMPERATURE (Page 1 of 1)

(Containment Temperature Less Than or Equal to 200°F)

CAUTION PAGE 119 of 156 The RCP NPSH curve assumes one pump is operating in each loop_ RCP Instrumentation should be monitored for seal and pump performance in accordance with 2-EOP-99, Table 13 100 200 300

'00 1O0 600 700 600

"'-"'V/"

......,,,...... ',r.

___ Required QSPDS SUbCO?l!~ Margin Reading (Rep CET) I 40 to 180'F I

50 to 170°F

-lIt 80 to 160'F RCS Pressure Range I

2250 pSla \\0 1000 pSI a L ____ 1 000 psi a to 500 pSla 1---

Less than 500 pSla 57

\\.

REVISION NO 36A PROCEDURE NO P

R E

S S

U R

I Z

E R

P R

E S

S U

R E

p s

a 2*EOP*99 I

200. ----

PROCEDURE TITLE APPENDICES / FIGURES / TABLES I DATA SHEETS ST. LUCIE UNIT 2 FIGURE 2 SAFETY INJECTION FLOW VS. RCS PRESSURE (Page 1 of 1)

-~~----~--

PAGE 121 of 156 TOTAL SAFETY INJECTION FLOW (gpm)

IP'oPsrzEOP99IF~2JR',0I1'l 58

(

REVISION NO, PROCEDURE TITLE PAGE 36A PROCEDURE NO APPENDICES I FIGURES I TABLES I DATA SHEETS 121 of 156 p

R E

S s u

R I

Z E

R p

R E s s u

R E

p s

cI 2*EOP*99 1300 r*--

1200 ~--

I 1100 1000 '

900.:..,

800 ST. LUCIE UNIT 2 FIGURE 2 SAFETY INJECTION FLOW VS, ReS PRESSURE (Page 1 of 1)

-r-~-~-l-~~'

~--~-~~---r--In-I -+-~-llf~-~iS curve repres~~sT~inimum expected' -j" SI Flow. If measured flow is less than this

....... --;- *-11 figure, Then SI System lineup should be

, : yenned.

I. c-.

1

_.t--+_.: I I rl

,. T~I

! -_._-, - I ---- -.~, ---1-i --l-700 ~

I t

600 ~

500 L.~-

-lI~tl~+ ___ 1 --I I i_ --,.

_-++--+-+-1 ~_:r-11-F~lt~ 1-+ -1 1--1-;-1 in Operation

~

I I

I' I

i r-*r. *iT _._.j I

400'-- --

I 1I1T;;';i--I-*-~--i -.~: --I -*-1 300 ~-. -- --_. ' _. I __ ~;on

-+ --f-1._~

~ __

I

~- I I

I!

I

-+-_J __ +_ ~ __ ~. _+ __ ~.. __ ~ __ \\

I I

~""1-_~=.-

200 '

100 _. - -j ~------t-.-----"l'--=--_+_

! 1 o :**----+--..**1~+-.-.

o 1000 2000 3000 4000 TOTAL SAFETY INJECTION FLOW (gpm)

(PloPsrzEOPS9IF~2t~e,OM) 58

ML100620144

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