ML15141A381

2009302 Draft Simulator Scenario

ML15141A381
Person / Time
Site:	Saint Lucie
Issue date:	05/27/2010
From:	NRC/RGN-II
To:	Florida Power & Light Co
References
Download: ML15141A381 (277)

Text

Appendix D Scenario Outline Form ES-D-1 Facility: St. Lucie Scenario No.: 1 Op Test No.: HLC-19 NRC Examiners: Operators: SRO:

RO:

BOP:

Initial Conditions: IC #3 45% power, Xenon building in, 6 gpm dilution rate. MDL. 2C Charging Pump DOS for repack. 2A AFW Pump DOS to repair oil leak. Both Main Feedwater pumps running.

Turnover: Unit was down powered due to an oil leak on the 2B Main Feedwater Pump. Oil leak has been repaired and the 2B Main Feedwater Pump was just started. 2A AFW pump has been DOS for four hours, expected to be returned to service in one hour. The crew is to perform an up power to 100%.

Critical Tasks:

. Start 2B Emergency Diesel Generator

. Establish Feedwater to 2A or 2B SG Event MaIf. Event Event No. No. Type* Description 1 R / All Power Increase to 100% power N / BOP 2 1 I / BOP DEH swaps to Turbine manual 3 2 C / RD Non Selected Pressurizer level channel LIC-1 1 1 OY fails low.

T.S. SRO 4 3 C / BOP HVS-1C Containment fan cooler trips. HVS-1 D does not start T.S / SRO 5 4 Cl RD Letdown flow controller HIC-1100 goes to at Maximum Flow 6 5 M / All Letdown line leak in Containment SBLOCA 7 6 Cl BOP 2A MFW 15% Bypass valve does not open post trip. A AFW pump does not start manually or on AFAS and MV-09-1 1 2C AFW to 2A SG does not open. MV-09-12 2C AFW to 28 SG opens 30% and trips.

8 7 C / BOP B side electrical does not swap to SU transformers. 2B EDG does not start.

9 - 8 C / BOP Upon AFAS the 2B AFW does not start.

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor

Scenario Event Description NRC Scenario I St. Lucie The Unit will be turned over to the Crew at 45% power. 2C Charging Pump is out of service for repack.

Both Main Feedwater Pumps are running and the Crew is to perform an up power to 100%.

During the up power the DEH system will swap to Turbine manual. No alarm is annunciated with this failure. The up power is to be conducted with the Turbine in manual control.

As the up power progresses, the non-selected Pressurizer level controller LIC-1 11 QY fails low. All heaters will be lost, the B side 4.16 Pressruizer heater breaker tripping open and unable to be re-closed. Key #98 will be required to be taken to the level position to regain only the A side Pressurizer heaters. SRO is to evaluate T.S. on loss of heaters. (T.S. 3.4.3)

Containment Cooler HVS-1C trips and is not recoverable. Containment cooler HVS-1D will not start. The Crew is required to monitor Containment temperature to ensure temperature is maintained less than 120°F. SRO is to evaluate T.S. on loss of one train of Containment cooling. (T.S. 3.6.2.1)

H IC-i 110 Letdown controller fails causing full letdown flow. The RO is to take manual control of the letdown flow controller to re-gain control of letdown flow. When flow control is re-gained, the letdown line in the containment will leak resulting in a SBLOCA. Pressurizer level will not be maintainable and the Crew should manually trip the Unit.

Upon Unit trip the B side will not swap to the SU transformers and the 2B Diesel will not automatically start. The SNPO will be required to locally start the 2B Diesel Generator.

Upon the Unit trip the 2A MFW recirc. valve will not open. This will result in the 2A MFW tripping on low flow. Eventually AFAS will actuate but MV-09-1 1 2C AFW to 2A SG does not open. MV-09-12 2C AFW to 2B SG opens to 70 gpm flow but then the valve motor breaker trips. 28 AFW pump does not start on AFAS but can be manually started. AFAS lockout will occur on the A side due FW pressure when B side pressurizes. Due to the small break LOCA this scenario makes starting the 2B Diesel and restoring feedwater critical.

2-EOP-03, LOCA should be implemented to mitigate the small break (150 gpm) from the letdown line. If the crew has difficultly establishing feedwater they may elect to enter 2-EOP-15, Functional Recovery which is acceptable but may delay the recovery actions. The scenario may be terminated when feedwater is restored to at least one SG, the RCS is being cooled down and depressurized while maintaining subcooling.

Procedures Used

• 2-GOP-201 Reactor Plant Startup Mode 2 to Mode 1

• 2-GOP-lOl, Reactor Operating Guidelines During Steady State and Scheduled Load Changes

• 2-NOP-02.24, Boron Concentration Control

• NOP-1 00.02 Axial Shape Index Control

• 2-ONP-22,03, DEH Turbine Control System

• 2-0120035, Pressurizer Pressure and Level

• 2-ONP-25.01, Loss of RCB Cooling Fans

• 2-ONP-02.03 Charging And Letdown

• 2-0120031, Excessive Reactor Coolant System Leakage

• 2-EOP-01 Standard Post Trip Actions

• 2-EOP-03 Loss of Reactor Coolant Technical Specifications Entered

• 3.4.3 Pressurizer

• 3.6.2.1 Containment Spray and Cooling Systems 2

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # I Event # I Page 3 of 15 Event

Description:

Power increase from 45% to 100%

Time Position Applicants Actions or Behavior Booth Operator Instructions:

• Initiate IC #3 45% power. Xenon building in, 9 gpm dilution rate. MOL. 2C Charging Pump 005 for repack. 2A AFW Pump OOS to repair oil leak (005 for 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. Expected to be returned to service in another 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />) Start 2B MFW pump and leave in recirc. position. Place 2A AFW pump and 2C Charging pump to stop.

Indications Available:

NOTE: Inform the crew 2-GOP-201 step 6.1.30 has been signed off by RE and power ascension is approved. Step 6.1 29.11 is complete. Start at step 6.129.12.

SRO Direct power increase lAW 2-GOP-201 step 6.132 Control Rx power and AS! lAW 2-GOP-i 01 Rx Operating j Guidelines step 6.1 (attached pages 4-5)

Raise dilution rate for power increase lAW 2-NOP-02.24 step RO 6.5.12 (attached page 6)

Withdraw CEAs to control Rx power and AS! lAW 2-GOP-iOl Rx Operating Guidelines step 6.1 (attached page 4)

• CEA Withdrawal, select MS on the CEDMCS Control Switch

• Move the IN/HOLD/OUT Switch to the OUT direction Program DEH for power increase at a rate lAW 2-GOP-i 01 step 6.1.2,D Category 4. (attached page 4)

• Set reference by ensuring REF selected and then BOP depress desired MW endpoint, select ENTER

• Depress LOAD RATE type in desired load rate and select ENTER

• Depress GO pushbutton 3

REVISION NO.. PROCEDURE TITLE: PAGE:

96 REACTOR OPERATING GUIDELINES DURING STEADY 6 115 PROCEDURE NO.: STATE AND SCHEDULED LOAD CHANGES 2-GOP-lOl 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 AS! 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. 1i 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 2 3%/HR above 50% Power .42 MW/MIN 3 20%/HR above 50% Power 2.80 MW/MIN 4 30%/HR above 50% Power 4.2 MW/MIN 4

REVISION NO.: PROCEDURE TITLE: PAGE:

98 REACTOR OPERATING GUIDELINES DURING STEADY 7 f 15 PROCEDURE NO: STATE AND SCHEDULED LOAD CHANGES 2-GOP-lOl 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. IN CREASE 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.

H

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 been maintained for 3 continuous hours or more during the past 8 days.

3. If available, Ib 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 5

REVISION NO,: PROCEDURE TITLE PAGE.

24A BORON CONCENTRATION CONTROL PROCEDURE NO.: 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. C] C] C] C 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. C] C] C] C MAINTAIN VCT pressure less than or equal to 30 psig by opening and closing V2513, VCT Vent, as needed,

14. C] C] C] C] jj necessary to maintain the desired VCT level, DIVERT the letdown flow to the Waste Management System by placing V2500, VCT Divert Valve, in the WMS position:

A. C] C] C] C] ENSURE V2500 VCT Divert Valve indicates OPEN.

B. C] C] U C] When the desired VCT level is reached, PLACE V2500 in AUTO.

C. C] C C] C] ENSURE V2500 indicates CLOSED.

15. C] C] C C] When the desired amount of primary water has been added, Then CLOSE FCV-2210X, Primary Makeup Water,

16. C] C] C C] j V-251 2 Reactor Makeup Water Stop Vlv was opened, Then PLACE V.2512 in CLOSE ENSURE it indicates CLOSED.

17. C] C] C] C] jjV-2525 Boron Load Control Valve was opened, Then PLACE V-2525 in CLOSE and ENSURE it indicates CLOSED.

18. C] C] C] C ENSURE FIC-2210X, PMW Flow controller is in MANUAL and RECUCE output to MINIMUM.

19. C] C] C] C] MONITOR for any abnormal change in Tave.

20. C] C] C] C] §i RECORD on Data Sheet 1, Boration I Dilution Log, the number of gallons of Primary Makeup Water added as indicated on FQI-22 lox, PMW Flow Totalizer.

21. C] C] C] C] 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.

6

Appendix D Operator Action Form ES-D-2 Op Test No.; 1 Scenario # 1 Event # 2 Page 4 of 15 Event

Description:

Power increase from 45% to 1OO%

Time I Position Applicants Actions or Behavior Booth Operator Instructions: Trigger EVENT 2, DEH swap to manual when directed by examiner.

Indications Available: No alarms associated with this failure. DEH panel indicates:

• Turbine manual light is lit

• OP Auto light is off

• Trans Relay 24V monitor light on NOTE: this is not a full loss of DEH computer so CONT RESET light will not be lit on Operator Console B

Recognizes turbine manual light is lit, OP auto light is off.

CHANGE load using the following pushbuttons 2-ONP-22,03)

BOP

. (step 6.2.2.A)

.

• GV Raise NOTE: small pushes (< 1 sec.) of GV Raise will pick up 3-6 megawatts.

, Implements 2-ONP-22.03 DEH Turbine Control System SRO Step 6.2 (attached pages 8-9)

Directs performance of Data Sheet 1 (attached page 10)

Monitors primary plant parameters during DEH manual RO operation. Adjusts dilution rate as needed.

7

EVSION NO.. PROCEDURE TITLE: PAGE:

9 DEH TURBINE CONTROL SYSTEM PROCEDURE NO..

8 of 24 2-ONP-22.03 ST. LUCIE UNIT 2 6.2 Loss Of DEH Computer INSTRUCTIONS CONTINGENCY ACTIONS

1. P RECORD initial conditions on Data Sheet 1, Initial Conditions.

NOTE

• The GV Raise and GV Lower pushbuttons operate on an exponential component. The longer the pushbutton is depressed, the faster the change in load will be made.

• Changing Turbine load will change Reactor power.

2. If load changes are necessary, Itin PERFORM the following:

A. CHANGE load using the following pushbuttons:

• GV Raise

• GV Lower B. PERFORM load changes in accordance with ONE of the following:

• 2-GOP-201, Reactor Plant Startup Mode 2 to Mode 1.

• 2-GOP-123, Turbine Shutdown Full Load to Zero Load.

3. NOTIFY 18CC.

4. CHECK the following indication:

• CONT OFF light NOT LIT on Operator Console A.

• CONT RESET light LIT on Operator Console B.

REVISION NO.: PROCEDURE TITLE: PAGE:

9 DEH TURBINE CONTROL SYSTEM PROCEDURE NO. 9 of 24 2-ONP-22.03 ST. LUCIE UNIT 2 6,2 Loss Of DEH Computer (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

5. DEPRESS the CONT RESET pushbutton on Operator Console B.

6. VERIFY the CONT RESET light NOT LIT.

7. When ready to return to automatic operation, Then GO TO Appendix A, Return To Automatic Operation.

END OF SECTION 6.2 9

REVISION NO.: PROCEDURE TITLE: PAGE:

9 DEH TURBINE CONTROL SYSTEM PROCEDURE NO.: 24 of 24 2-ONP-22.03 ST. LUCIE UNIT 2 DATA SHEET I INITIAL AND FINAL CONDITIONS (Page 1 of 1)

I. P RECORD initial conditions existing prior to transfer to TURBINE MANUAL, as directed.

2. RECORD final conditions prior to initiating transfer to OPER AUTO, as directed.

PARAMETER INITIAL FINAL INITIALS INITIALS CONDITIONS CONDITIONS TURBINE MANUAL (q)

OPER AUTO (q)

SEQ VALVE (s)

SINGLE VALVE ()

MW GV 1 position (%)

GV 2 position (%)

GV 3 position (%)

GV 4 position (%)

Keyboard location 4412 (Flow Demand)

GVC volts (if used) N/A N/A Reviewed by: Date:

US/SM END OF DATA SHEET I 10

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 3 Page 5 of 15 Event

Description:

Non Selected Pressurizer level channel LIC-111OY fails low Time Position Applicants Actions or Behavior Booth Operator Instructions: Trigger EVENT 3, Pressurizer level fails low when directed by examiner (LIC-IIIOY non selected level channel fails low)

Indications Available: Annunciators:

• A-9 Pzr Htr Xfmer 2B3 trouble

• H-18 Pzr Channel V Level High/Low Heaters: P-2, B-4, B-5, B-6 no power available. P-I, B-I, B-2, B-3 power available i but off. Heater transformer breaker B side 2-20403 open.

Recognizes all Pressurizer heaters are de-energized, Monitors RO RCS pressure to ensure spray valves closing in response to loss of heaters.

Recognizes Tech. Spec. entry (3.4.3) due to unable to regain B side pressurizer heaters. 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> action statement to regain B T.S. SRO side. Should also refer to T.S. 3.3.3.5 remote shutdown instrumentation for loss of channel V. 30 day action statement.

(attached page 12)

NOTE: B side heaters will not be available due to breaker 2-20403 unable to be closed on loss of channel Y Implement 2-0120035 Pressurizer Pressure and Level step 7.2.2.G (attached page 13)

Directs backup interlock bypass keyswitch taken to LEVEL position. This will regain only the A side heaters.

When directed, places backup interlock bypass keyswitch to RO the LEVEL position. (step 7.2.2.G.1 .a)

Resets all A side pressurizer heaters. (step 7.2,2.G.1,b)

Monitors RCS pressure. Controls heaters to ensure RCS pressure 2250 psia.

11

REACTOR COOLANT SYSTEM 314.4.3 PRESSURIZER LIMITING CONDITION FOR OPERATION 3.4,3 The pressurizer shall be OPERABLE with a minimum water level of greater than or equal to 27% indicated level and a maximum water level of less than or equal to 68% indicated level and at least two groups of pressurizer heaters capable of being powered from 1 E buses each having a nominal capacity of at least 150 kW.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

a. With one group of the above required pressurizer heaters inoperable, restore at least two groups to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

b. With the pressurizer otherwise inoperable, be in at least HOT STANDBY with the reactor trip breakers open within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.4.3.1 The pressurizer water volume shall be determined to be within its limits at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

4.4.3.2 The capacity of each of the above required groups of pressurizer heaters shall be verified to be at least 150 kW at least once per 92 days.

4.4.3.3 The emergency power supply for the pressurizer heaters shall be demonstrated OPERABLE at least once per 18 months by verifying that on an Engineered Safety Features Actuation test signal concurrent with a loss of offsite power:

a. the pressurizer heaters are automaticafly shed from the emergency power sources, and

b. the pressurizer heaters can be reconnected to their respective buses manually from the control room after resetting of the ESFAS test signal.

ST. LUCIE - UNIT 2 Amendment No. , 11 12

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)

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 G. If pressurizer heaters are controllers (selected and non- deenergized or level indicating selected) are operating properly and controller(s) failed, Then power is available to pressurizer perform the following:

heaters.

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 (RTQB-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 C

13

REVISION NO. PROCEDURE TITLE: PAGE:

3 LOSS OF RCB COOLING FANS PROCEDURE NO.. 13 of 19 2-ON P-25.01 ST. LUCIE UNIT 2 6.4 Loss of Containment Fan Cooler INSTRUCTIONS CONTINGENCY ACTIONS CAUTION

§1,2 Sufficient Containment Fan Coolers (HVS-1A, HVS-1B, HVS-1C or HVE-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 and cooldown to at least Hot Shutdown. The total time from the loss of Containment Fan Coolers to Hot Shutdown is 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />.

1. ATTEMPT one start of the standby 1. L standby fan does NOT start, Containment Fan Cooler. flj) PERFORM the following:

A. PERFORM Appendix D, Containment Cooling Fan Local Breaker Operations.

B. ATTEMPT one start of all available Containment Fan Coolers.

C. If any fan does NOT start,

]Jan the following:

• Maintenance Supervisor

• EM

0. REFER TO Tech Specs 3.6.2.1.

15

REVISION NO: PROCEDURE TITLE. PAGE:

3 LOSS OF RCB COOLING FANS PROCEDURE NO 14 of 19 2-ONP-25.01 ST. LUCIE UNIT 2 6.4 Loss of Containment Fan Cooler (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

2. CHECK Containment air 2. ii Containment air temperature temperature less than or equal to greater than 120°F, Then 120°F. PERFORM the following:

A. INITIATE a rapid shutdown using 2-ONP-22.O1, Rapid Downpower.

B. REFER TO Tech Specs 3.6.1,5.

C. If Containment air temperature is NOT less than 120°F within 45 minutes, Then PERFORM the following:

1. TRIP the reactor.

2. TRIP the turbine.

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

4. COOLDOWNtoat least Hot Shutdown within 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> from the loss of the fan in accordance with 2-GOP305, Reactor Plant Cooldown Hot Standby to Cold Shutdown.

16

CONTAINMENT SYSTEMS 314.6.2 DEPRESSURIZATION AND COOLING SYSTEMS CONTAINMENT SPRAY AND COOLING SYSTEMS LIMITING CONDITION FOR OPERATION 3.6.2.1 Two containment spray trains and two containment cooling trains shall be OPERABLE.

APPLICABILITY: Containment Spray System: MODES 1 2, and MODE 3 with Pressurizer Pressure > 1750 psia, Containment Cooling System: MODES 1 2, and 3.

ACTION:

1. Modes 1, 2, and 3 with Pressurizer Pressure 1750 psia:

a. With one containment spray train inoperable, restore the inoperable spray train to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> and within 10 days from initial discovery of failure to meet the LCO; otherwise be in MODE 3 within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in MODE 4 within the following 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br />.

b. With one containment cooling train inoperable, restore the inoperable cooling train to OPERABLE status within 7 days and within 10 days from initial discovery of failure to meet the LCO; otherwise be in MODE 3 within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in MODE 4 within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

c. WITh one containment spray train and one containment cooling train inoperable, concurrently implement ACTIONS a. and b. The completion intervals for ACTION a. and ACTION b. shall be tracked separately for each train starting from the time each train was discovered inoperable.

d. With two containment cooling trains inoperable, restore one cooling train to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />; otherwise be in MODE 3 within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in MODE 4 within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

e. With two containment spray trains inoperable or any combination of three or more trains inoperable, enter LCO 3.0.3. immediately.

2. Mode 3 with Pressurizer Pressure < 1750 psia:

a. With one containment cooling train inoperable, restore the inoperable cooling train to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />; otherwise be in MODE 4 within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

b. With two containment cooling trains inoperable, enter LCO 3.0.3 immediately ST. LUCIE - UNIT 2 Amendment No. 2, 70 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 5 Page 7 of 15 Event

Description:

Letdown flow controller HIC-liQO goes to maximum flow Tnej Position H Applicants Actions or Behavior Booth Operator Instructions: Trigger EVENT 5, letdown flow controller HIC-1100 when directed by examiner (HIC-1100 goes to maximum flow)

Indications Available: Annunciators:

. M-5 Letdown Press HighlLow

. M-13 Letdown Flow High

. LC-15 Letdown Relief V2345 Disch Temp High Letdown flow increasing to 150 gpm Responds to letdown flow alarm. Recognizes letdown flow is at RO maximum.

..l-.-.______

When directed places HIC-1100 in manual lAW steps 6.0.12.A.1, A.2, A.3, A.4. of 2-ONP-02.03 Charging and Letdown (attached page 19). Manually control letdown flow to

_________ maintain Pressurizer level.

SRO Implements 2-ONP-02.03 Charging and Letdown step 6.0.12 (attached page 19).

.--. Directs HIC-1100 placed in manual. Step 6.0.12.A.1. Directs letdown flow controlled to maintain I regain pressurizer level.

NOTE: crew may elect to isolate letdown if letdown flow is not controlled and letdown relief continues to lift. If letdown is isolated, charging pumps are required to be stopped.

Crew should re-establish charging and letdown when HIC-1100 is placed in manual.

Ion exchanger bypass valve V2520 should be placed in bypass if letdown flow is not recovered in a timely manner. This is lAW annunciator response M-13.

18

REVISION NO PROCEDURE TITLE: PAGE; 158 CHARGING AND LETDOWN PROCEDURE NO.

11 of 26 2-ONP-02.03 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

11. (continued)

U. NOTIFY Health Physics that dose rates near CVCS ion exchangers and piping may change when ion exchanger is placed in service.

V. PLACE the Letdown Ion Exchangers back in service by placing V2520 Ion Exchanger Bypass Valve to the AUTO Position.

12. II Letdown Level control is 12.

malfunctioning Then PERFORM the following:

A. VERIFY the output of A.1 PLACE HIC-lilO in MANUAL by HIC-illO, LEVEL, is performing the following:

responding as expected to current plant 1. BALANCEHIC-1110 conditions. MANUAL to AUTO controller output signals by previewing and using the MANUAL control knob to match the manual and auto controller output signals.

2. PLACE HIC-lilO to MANUAL.

3. ADJUST letdown flow to a value consistent with the current plant conditions.

4. PERFORM a system walkdown observing for leaks or lifting relief valves.

B. VERIFY the selected B.1 PLACE the Alternate Level control level control valve is valve in service in accordance responding as expected with 2-NOP-02.02, Charging and to H IC-i 110 output. Letdown.

19

Appendix D Operator Action Form ES-D-2 Op Test No.: I Scenario # I Event # 6 Page 8 of 15 Event

Description:

Letdown line leak In containment (SBLOCA)

Time Position I Appllcants Actions or 8ehavlor Booth Operator instructions: Trigger EVENT 6, Letdown line break when directed by examiner (SBLOCA in containment, ramping up to 150 gpm in six (6) minutes) indications Available: Annunciator N-46 Rx cavity leakage High Recognizes cavity sump level leakage recorder increasing, RO letdown flow lowering.

Manually adjusts letdown flow in attempt to maintain Pressurizer level.

Closes LCV-07-1 I A or LCV-07-1 I B (to isolate sump from pumping to the EDT) when directed.

Closes letdown isolation valves when V251 5, V251 6, V2524 when directed.

Implements 2-01 20031 ExcessIve Reactor Coolant System SRO leakage. Directs LCV-07-1 I A or LCV-07-1 1 B closed lAW step 7.2.2.K (attached page 21-22).

NOTE: if time permits, may enter T.S. action statement for RCS leakage >1 gpm. (T.S. 3.4.6.2, reduce leakage within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />)

Direct termination of up power If not previously done NOTE: SRO should state DNB T.S. entered when pressurizer pressure reaches 2225 psia.

Directs manual Reactor trip when Pressurizer level cannot be maintained lAW 2-0120031 Excessive Reactor Coolant System leakage step 7.2.2.B.1 RO Trips the reactor when directed

REVISION NO. PROCEDURE TITLE: PAGE:

24A EXCESSIVE REACTOR COOLANT SYSTEM 6 of 26 PROCEDURE NO.: LEAKAGE 2-0120031 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions

1. None 7.2 Subsequent Operator Actions INSTRUCTIONS CONTINGENCY ACTIONS in Modes I thru 3 and SIAS is NOT blocked, Then go to step 2.

If in Modes 3 thru Mode 6 and SIAS is blocked, Then go to step 3,

2. ACTIONS WHEN IN MODES I THRU MODE 3 (SIAS NOT BLOCKED)

A. j RCS leakage is indicated, Then analyze the information available and determine as accurately as possible the magnitude and seriousness of the leak.

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

1. In Modes I and 2, trip the reactor and turbine and perform 2-EOP-01 Standard Post Trip Actions,

2. If in Mode 3 (SIAS is NOT Blocked), Then enter 2-EOP-03, Loss of Coolant Accident.

C. the containment CIS radiation C. Manually actuate CIAS.

monitors exceed the present alarm point level, Then ensure containment isolation signal is actuated.

21

REVISION NO: PROCEDURE TITLE PAGE:

24A EXCESSIVE REACTOR COOLANT SYSTEM 9 of 26 PROCEDURE NO: LEAKAGE 2-01 20031 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

2. (continued) 2. (continued)

NOTE When using the Reactor Cavity Sump Level instrument (LIS-07-6) on RTGB-205, 1 is approximately equal to 46 gallons.

K. If leak appears to be inside containment as indicated by an increase in cavity sump level, Ijj.i close LCV-07-11A or LCV-07-11B to isolate sump from pumping to the EDT.

L. If leak appears to be outside containment, Then consider the following:

1. Local sample valve isolation, refer to Appendix B.

2. Isolating letdown.

3. Isolating RCS sample lines:

V5200 thru V5205.

4. Inspect charging pumps for increased seal leakage.

M. II charging pump seal leakage is the suspected source of leakage, Then perform Appendix C, Charging Pump Local Seal Leakage Determination, while continuing.

N. Monitor secondary radiation levels N. ji secondary radiation levels for increasing trends on the are increasing, Then refer to condenser air ejector, blowdown and ONOP 2-0830030, Steam main steamline monitors. Generator Tube Leak.

22

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 7,8 Page 9 of 15 Event

Description:

Upon trip, 2A MEW trips on low flow due to its recirc valve failing to open. MV-09-1 1 2C AFW to 2A SG does not open. MV-09-12 2C AFW to 2B SG opens 30% and trips. B side electrical does not swap to SU transformers. 2B Diesel does not start.

Tirnej PositioL_j Applicants Actions or Behavior Booth Operator Instructions: When SNPO directed to investigate alarm A-26, state local annunciators 5-2 and 6-1 are energized. If asked to reset lockout, wait one (1) minute and reset lockout relay. NOTE: DIG will start and load when lockout reset.

Indications Available: Annunciator A-26 2B EMERG DIG LOCKOUTISS ISOL.

Localannunciators: 5-2, Overspeed Trip and 6-1, 2B EDO Trip/Lockout SRO Directs BOP to contact SNPO to investigate lockout alarm.

Critical Direct BOP to have SNPO reset lockout when informed no Task apparent problem with DIG.

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

• RO: Reactivity control, Inventory Control, Pressure Control, Core Heat Removal

• GOP: Vital Auxiliaries, RCS Heat removal, Containment Conditions Closes MSR block valves. (Reheat panel reset pushbutton will BOP be required to be depressed due to loss of power to two MSR block valves)

Critical Recognizes 2B Diesel Generator did not start. Recognize lockout relay alarm in. Direct SNPO to reset lockout when SRO Task directed.

Verifies D/G loading when lockout reset Notify NPO to perform Appendix X (NPO Actions) section 1 of EOP-99.

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

23

Appendix D Operator Action Form ES-D-2

Op Test No.. 1 Scenario # 1 Event # 7,8 Page 10 of 15 Event Description, Upon trip, 2A MFW trips on ow flow due to its recirc valve failing to open. MV-09-1 1 2C AFW to 2A SC does not open. MV-09-1 2 2C AFW to 2B SG opens 30% and trips. B side electrical does not swap to SU transformers. 2B Diesel does not start, Time J Position j Applicants Actions or Behavior Booth Operator Instructions:

Indications Available:

Maintenance of Vital Auxiliaries

• Verifies turbine governor and throttle valves closed

• Verify GEN Brk open (East breaker, Mid Breaker and Exciter Breaker)

BOP Verify all vital and non vital AC Buses energized. (2A1, i 2A2, 2A3 2AB, 2B1, 2B2 and 2B3 6,9 and 4.16kv buses) NOTE: 2B1 and 2B2 will not be energized due to SU transformer not swapping on trip.

• All vital and non vital DC Buses energized. -_____

RCS Heat Removal

• Verify at least one SC has feedwater available

. Verify RCS Tavg is between 525 and 535° F

• Verify SBCS valves controls Tavg.

• Close MSIV at 750 psia.

• Close Spillover Bypass valve MV-08814 (unable to be I closed due to loss of power)

: 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 Performs EOP-01 Safety Functions as directed for Reactivity

RO Control, Inventory Control, Pressure Control, Core Heat

. removal 24

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 7,8 Page 11 of 15 Event

Description:

Upon trip, 2A MFW trips on ow flow due to its recirc valve failing to i open. MV-09-1 1 2C AFW to 2A SG does not open. MV-09-1 2 2C AFW to 2B SG opens 30% and trips. B side electrical does not swap to SU transformers. 2B Diesel does not start.

Position Applicant s Actions or Behavior Booth Operator Instructions:

Indications Available:

Examiners note: Due to the small leak SIAS will not actuate until the crew enters 2-EOP-03 and starts a cooldown.

Reactivity Control

• Verify Reactor power is lowering.

RO

• 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% (not trending due to letdown leak)

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° F Core Heat Removal

• Verify at least one RCP running with CCW (if >10 minutes. With no CCW must secure RCPs)

• Verify loop delta T is <10° F 25

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 9 Page 12 of 15 Event

Description:

AFAS actuation. MV-09-12-2C 2C AFW pump to 2B SG partially opens to 70 gpm flow. 2B AFW pump does not start.

TH1iej Position Applicant s Actions or Behavior BoothOperator Instructions:

Indications Available:

Examiners note: Due to the small leak SIAS will not actuate until the crew enters 2-EOP-03 and starts a cooldown.

SRO Implement 2-EOP-03, Loss of Coolant Accident -

• Directs BOP to perform SFSCs

.-.--t----- -

• Contact SM to classify the event

---1-* ___

• Direct implementation of Appendix A EOP-99 Sampling I SGs (attached page 27-28).

• Ensure SIAS flow adequate per Figure 2 SI flow Vs.

RCS pressure. (due to high RCS pressure, ECCS flow will not occur until later in the event) (attached page 29)

• When SIAS. direct CCW restored to RCPs per Appendix J 2-EOP-99 within 10 minutes or stop the running RCPs(attached pages 30-31)

• Direct establishing alternate RCP bleedoff flowpath to the RCPs by opening V2507, RCP Bleedoff Relief Stop

, Vlv.

• Directs BOP to place Hydrogen Analyzer in service per Appendix L (32-33_pages

• Direct RO to perform RCS cooldown not to exceed 100°F in any one hour using SBCS.

26

REVISION NO PROCEDURE TITLE. PAGE.

36A APPENDICES I FIGURES I TABLES I DATA 3 of 156 PROCEDURE NO SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 1 of2)

A Train (1) B Train (J)

U 1. If a LOOP has occurred, Then PERFORM BOTH of the following:

U A. ENSURE 2AB 480V Load Center is aligned to an energized bus.

U B. DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 2B Instrument Air Compressors.

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-1 4-8B) 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 U 2. If 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

• HC V-i 4-9 OR

• HCV-14-8B HGV-i 4-10 27

REVISION NO.: PROCEDURE TITLE: PAGE:

36A APPENDICES / FIGURES I TABLES I DATA of 156 PROCEDURE NO: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 2 of 2) 0 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.

0 4. DIRECT Chemistry to perform S1G samples for activity and boron.

0 5. S/Gs cannot be sampled,

]Jj. DIRECT Health Physics to conduct secondary plant local area radiation surveys.

END OF APPENDIX A 28

REVISION NO.: PROCEDURE TITLE: PACE:

36A APPENDICES I FIGURES I TABLES I DATA 121 of 156 PROCEDURE NO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 FIGURE 2 SAFETY INJECTION FLOW VS. RCS PRESSURE (Page 1 of 1) 1300 1200 p

R 1100 E

S S

U R

E R

P R

E S

S U

R E

p S

TOTAL SAFETY INJECTION FLOW(gpm) (PIQPS.EOP.9!lg2iRevOtfl 29

REVISION NO: PROCEDURE TITLE: PAGE:

36A APPENDICES / FIGURES I TABLES / DATA 62 of 156 PROCEDURE NO SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX J RESTORATION OF CCW AND CBO TO THE RCPs (Page 1 of2)

D 1. ENSURE Instrument Air to Containment is available by PLACING HCV-1 8-1 to CLOSE / 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-14-1O) 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.

0 2. If 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 lsol Suction OR

• HCV-14-8B N Hdr Isol Discharge

• HCV-14-1O N Hdr Isol Suction 0 3. ALIGN CCW to / from the RCPs by OPENING ALL of the following valves:

0 HCV-14-1, CCWTo RC PUMP 0 HCV-14-2, CCW From RC PUMP 0 HCV-1 4-7, CCW To RC PUMP 0 HCV-14-6, CCW From RC PUMP O 4. II CIAS has isolated controlled bleedoff flow to the VCT, Then OPEN V2507, RCP Bleedoff Relief Stop Vlv.

30

REVISION NO PROCEDURE TITLE. PAGE:

36A APPENDICES! FIGURES / TABLES I DATA 63 of 156 PROCEDURE NO: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPEN DIX J RESTORATION OF CCW AND CBO TO THE RCPs (Page 2 of 2)

CAUTION 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:

Li HCV-14-11-A1, CCW From 2A1 RCP Seal Cooler U HCV-1 4-11 -A2, CCW From 2A2 RCP Seal Cooler U HCV-14-11-B1, CCW From 281 RCP Seal Cooler U HCV-14-11-82, CCW From 2B2 RCP Seal Cooler U 6. VERIFY RCP CCW related alarms are CLEAR or have been evaluated and dispositioned.

END OF APPENDIX J 31

REVISION NO: PROCEDURE TITLE: PAG:

36A APPENDICES I FIGURES / TABLES / DATA PROCEDURE NO SHEETS 65 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX L PLACING HYDROGEN ANALYZER IN SERVICE (Page 1 of 2)

A Train (1) B Train (J)

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.)

FSE-27-9 FSE-27-1 3 (Pzr. Area) (2B2 RCP)

FSE-27-1O FSE-27-14 (2A1 RCP) (281 RCP)

FSE-27-1 1 (2A2 RCP)

2. OPEN the Containment Isolation Valves. FSE-27-15_ FSE-27-17_

(Sample in to H2 Analyzer)

AND FSE-27-16 FSE-27-18 (Sample out of H2 Analyzer)

3. ENSURE the function selector switch is in the SAMPLE position.

4. PLACE the OFF / STANDBY / ANALYZE switch to ANALYZE.

NOTE 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.

32

REVISION NO: PROCEDURE TITLE: PAGE:

36A APPENDICES I FIGURES / TABLES / DATA 66 of 156 PROCEDURE NO SHEETS 2-EDP-99 ST. LUCIE UNIT 2 APPENDIX L PLACING HYDROGEN ANALYZER IN SERVICE (Page 2 of 2)

A Train (q) B Train (i)

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 33

Appendix D Operator Action Form ES-D-2

01) Test No.: 1 Scenario # 1 Event # 9 Page 13 of 15 Event

Description:

AFAS actuation. MV-09-12-2C 20 AFW pump to 2B SG partially opens to 70 gprn flow. 28 AFW pump does not start.

m[Position Applicants Actions or Behavior Booth Operator Instructions:

Indications Available:

SRO Critical Direct starting 2B AFW pump when identified no start on AFAS.

Task May elect to feed 2A SG AND 20 SG by cross tying 20 AFW SRO pump. This should be done lAW 2-ONP-09,02 Auxiliary Feedwater Appendix C step 2. (attached page 35-36)

Perform cooldown using SBCS not to exceed 100F in any one RO hour to regain subcooling.

Monitor subcooling per Figure 1A RCS pressure Temperature (attached page 37)

RO/BOP Identifies 25 AFW pump did not start upon AFAS actuation.

Critical Start 2B AFW pump when directed.

Task When SIAS, restore CCW to RCPs per Appendix J 2-EOP-99 BOP within 10 minutes or stop the running RCPs. (attached pages 30-3 1)

When directed establish alternate RCP bleedoff flowpath to the RCPs by opening V2507, RCP Bleedoff Relief Stop Vlv.

Places the hydrogen analyzer in service per Appendix L of 2-

--C EOP-99 (attached_pages_32-33) -

Compares SI flow to RCS press, Figure 2.(attached page 29) 34

REVISION NO* PROCEDURE TITLE. PAGE:

11 AUXILIARY FEEDWATER PROCEDURE NO. 20 of 29 2-ONP-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, fl PERFORM the following:

1. CLOSE MV-09-10, Pump 2B Disch To SG 2B Valve.

2. If 2A S/G is being fed, ]jj. 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/C Vlv Key 83.

5. Locally CLOSE MV-09-1 3, 2A To 2B 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 SO 2A Valve CLOSED MV-09-10, Pump 26 Disch To SG 2B Valve CLOSED SE-09-2, 2A Pump Disch To 2A S/C VIv Key 83 CLOSED MV-09-1 3, 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. II 28 AFW Pump is to feed 2A S/C, ]j PERFORM the following:

A. ENSURE MV-09-9, Pump 2A Disch to 2A SIC Valve, is CLOSED.

B. START Auxiliary Feedwater Pump 28.

C. OPEN SE-09-3, 2B Pump Disch To 2B S/C VIv Key 84.

35

REVISION NO PROCEDURE TITLE: PAGE; 11 AUXILIARY FEEDWATER PROCEDURE NO:

21 of 29 2-ONP-09.02 ST. LUCIE UNIT 2 APPENDIX C CROSS-CONNECTING AFW (Page 3 of 4)

2. (continued) INITIAL CAUTION Opening both MV-09-1 3 and MV-09-1 4 while the unit is in Mode 1 2, 3 could make two independent AFW pump both inoperable.

N OTE Key-switches for MV-09-13 and MV-09-14 are located in 2A/2B AFW Pump Room. Two keys are required since the keys are removable in CLOSE only.

D. Locally OPEN MV-09-1 3, 2A To 2B AFW Hdr Cross-tie.

NPO E. Locally OPEN MV-09-14, 2B To 2A AFW Hdr Cross-tie.

NPO CAUTION Ensure total pump flow does not exceed 425 gpm.

F. THROTTLE MV-09-9, Pump 2A Disch To SG 2A Valve, to establish desired flow rate.

[ NOTE While feeding both S/Cs indicated flow is pump flow to both S/Cs.

0. To feed the 2B S/C, THROTTLE MV-09-1O, Pump 2B Disch To SC 2B Valve, to establish desired flow rate.

H. When the system is to be returned to normal, Then PERFORM the following:

1. CLOSE MV-09-9, Pump 2A Disch To SC 2A Valve.

2. II 2B S/C is being fed, Then CLOSE MV-09-1O, Pump 26 Disch To SC 26 Valve.

3. STOP Auxiliary Feedwater Pump 2B.

4. CLOSE SE-09-3, 26 Pump Disch To 2B S/C Vlv Key 84.

36

REVISION NO.: PROCEDURE TITLE: PAGE:

36A APPENDICES I FIGURES / TABLES / DATA 9o f 156 PROCEDURENO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 FIGURE IA RCS PRESSURE TEMPERATURE (Page 1 of 1)

(Containment Temperature Less Than or Equal to 200° F)

I 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.

2400 4)0 0.0 n 1.4)4 C4)*cl *0*01 OCO

• .$* bar cw00 IC Oct 10*1.000 We P000&0* *00* art, 04) v.erd We 0.aIo. 4,0 ono 4 charçc n,.c.aiy oociy 0.

EOPCac0.r*Io.

2200 2000 1800 Maximum Subcooied cc 1800 a

400 a-4) 1200 4) 0 1000 Minimum Subcoolexr BOO RCP NPSH Requiremenr 000 400 9ncbuci., 10111c11Th0111 bJricerIOInt,01 200 100 200 300 400 500 000 700 800 in0icaIe RCS Tempeature (}

RCS Pressure Range Required QSPDS Subcooled Margin Reading (Rep GET) 2250 psia to 1 000 psia 40 to 1 80°F 1000 psia to 500 psia 50 to 170°F Less than 500 psia 80 to 160°F 37

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 ScenarIo # I Event # 9 Page 14 of 15 Event

Description:

AFAS actuation. MV-ag-I 2-2C 2C AFW pump to 28 SG partially opens to 70 gpm flow. 2B AFW pump does not start.

Time Position Applicants Actions or Behavior BOP Perform Appendix A sampling SGs (attached page 27-28)

When (if) directed contact NPO to open MV-09-1 3 and MV 14 lAW Appendix C of 2-ONP-09.02 Auxiliary Feedwater step 2.D and 2.E (attached 36) to feed 2A AND 2B SG.

Suggested termination point:

. RCS Cooldown progressing 1 00°F per hour

. 2A and / or 2B SG is being fed by 2B AFW pump and level is being restored.

38

OPERATIONS SHIFT TURNOVER REPORT UNIT 2 CONTROL ROOM Day: Today Desk RCO: Board RCO:

Protected Train: A Unit 2 Identified RCS Leakage: 0 Unit 2 Unidentified RCS Leakage: 0 Unit 2 Scheduled Activities per the OSP:

Unit was down powered to 45% due to an oil leak on the 2B Main Feedwater Pump. Oil leak has been repaired and the 2B Main Feedwater Pump was just started. 2A AFW pump has been ODS for four hours, expected to be returned to service in one hour. The crew is to perform an up power to lOO%. The crew is to begin the up power at step 6.132 of 2-GOP-201.

Upcoming ECOs to Hang or Release:

2A AFW pump, clear ECO when work complete.

Tech Spec Action Statement:

None.

OPS 513s:

None Locked in Annunciators:

G-28 - 2A AFW Pump OVRLD/Trip M-24 20 Charging Pump Suct Press Low/OVRLDITrip Current Status:

45% power, Xenon building in, 6 gpm dilution rate. MDL.

Equipment Problems:

2C Charging Pump DOS for repack. 2A AFW Pump OOS to repair oil leak.

39

Appendix D Scenario Outline Form ES-D-1 Facility: St. Lucie Scenario No.: 2 Op Test No.: HLC-19 NRC Examiners: Operators: SRO:

RO:

BOP:

Initial Conditions: 100% power 2C Charging Pump OOS for repack. 2A AFW Pump QOS to repair oil leak.

Turnover: 100% power. 2A Heater Drain Pump has a severe shaft seal leak and must be removed from service. Perform down power to remove 2A Heater Drain Pump from service.

Critical Tasks:

. Close 2B MSIV.

. Stabilize RCS temperature after 2B S/G blows dry.

. Terminate AFW flow to 2B SIG. (Isolate 2B SIG)

Event MaIf. Event Event No. No. Type* Description 1 R I All Unit down power to remove 2A Heater Drain Pump from service.

N / BOP 2 1 C / RO Boric Acid Flow Control Valve FCV-2210Y fails closed 3 2 C / RO 2A Charging Pump trips on low oil pressure T.S. SRO 4 3 C / BOP 2A DEH Pump Failure I 28 does not auto start 5 4 T.S. I SRO Containment Pressure PT-07-2A fails high 6 5 M / All Steam Leak in Containment on 2B S/G 7 6 Cl RO 2B MSIV fails to close on MSIS 8 - 7 C / BOP AFAS lockout fails to stop feeding 28 SG from 2B AFW pump 9 Isolate 2B S/G (N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor

Scenario Event Description NRC Scenario 2 St. Lucie Unit is at 100% power with 2A AFW pump OOS to repair an oil leak. It is expected to be back in service within one hour. The 2C Charging pump is out of service for repack.

The 2A Heater Drain Pump has a severe shaft seal leak and must be removed from service. The crew will perform a down power to approximately 90% to remove the pump from service.

Boric Acid flow control valve FCV-2210Y fails closed and cannot be opened. The crew will implement the Off Normal procedure and use the emergency borate valve to continue the down power.

During the down power the 2A Charging pump will trip on low oil pressure. The SRO will need to make a T.S. 3.1.2.4 & 3.5.2 a2 calls due to one Charging pump operable. If the crew has not started the 2B Charging pump for the down power, procedure requires letdown to be isolated. Charging and Letdown ONP should be implemented and Charging and letdown should be placed back in service if secured. If 2B Charging pump was started prior to the loss of 2A Charging pump, letdown bias will need to be adjusted to maintain Pressurizer level on setpoint.

As the down power progresses the 2A DEH pump trips. The 2B DEH pump does not automatically start and should be manually started.

Containment Pressure PT-07-2B fails high. The SRO should refer to T.S. 3.3.1 and 3.3.2 and implement ONP for loss of Tech. Spec. Instrumentation.

A major steam leak in the Containment will develop. The crew should manually trip the Unit prior to any automatic trip. As the leak progresses and a MSIS is received the 2B MSIV does not close. The MSIV can be closed manually from the Control Room.

AFAS lockout will occur but the 2B AFW pump will continue to feed the faulted S/G through MV-09-10.

The crew should manually terminate AFW flow to the 2B S/G by stopping the 2B AFW pump.

Implementation of 2-EOP-05 Excess Steam Demand should be implemented. Termination of scenario should be when the 2B S/G is isolated lAW 2-EOP-99 Appendix R and RCS temperature and pressure are under control.

Procedures Used

• 2-GOP-123, Turbine Shutdown Full Load to Zero Load

• 2-GOP-lOt Reactor Operating Guidelines During Steady State and Scheduled Load Changes

• NOP-100.02 Axial Shape Index Control

• 2-ONP-22.01, Rapid Down Power

• 2-ONP-02.01, Boron Concentration Control 2-ONP-02.03, Charging and Letdown

• ARP 0-36 DEH PUMP OVLD

• 2-ONP-99.01, Loss of Technical Specification Instrumentation

• 2-ONP-08.01 Steam Leak Off-Normal Operating Procedure

• 2-EOP-01, Standard Post Trip Actions

• 2-EOP-05, Excess Steam Demand

• 2-EOP-99, Appendix R Technical Specifications Entered

• 3.1.2.4 Charging Pump Operation

• 3.5.2 ECCS

• 3.3.1 RPS and 3.3.2 ESFAS 2

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # I Page 3 of 18 Event

Description:

Unit down power to remove 2A Heater Drain Pump from service.

Time j Positio Applicants Actions or Behavior Booth Operator Instructions: If crew chooses 2- GOP-I 23, Turbine Shutdown Full -

load To Zero Load, instead of 2-ONP-22.O1, Rapid Down Power procedure then inform SRO the 2A Heater Drain Pump shaft seal leak is getting worse.

The pump needs to be stopped ASAP Booth Operator Response:

Control Room Indications Available:

Supervise/Coordinates Power reduction in accordance with 2-SRO ONP-22.O1 Rapid Down Power. (attached pages 5-20)

Directs Boration per Appendix C 2-ONP-22.O1 Rapid Down Power.

Directs Lead group CEA insertion of 6 inches step 6.1.2.

Directs DEH programmed for load rate step 6.1 .3.

When T-ave decrease noted directs GO on the turbine step 6.1.4.

May direct additional Charging pump started lAW 2-ONP-22.O1 Rapid_Downpower_Appendix D (attached_page_18)

. May direct Pzr. Placed on recirc lAW 2-ONP-22.O1 Rapid

.______ Downpower Appendix E. (attached page 19)

Begins Boration per Appendix C, ONP-22.O1 (attached page RO 17)

Appendix D Operator Action Form ES-D-2 Op Test No.. 1 Scenario # 2 Event # 1 Page 4 of 18 Event

Description:

Unit down power to remove 2A Heater Drain Pump from service.

Time

=

Position Aoolicants Actions or Behavior 1 BoothOperator Instructions:

Booth Operator Response:

Control Room Indications Available:

Inserts Lead CEA Group 6 inches.

RO . Select MANUAL SEQUENTIAL.

. Insert CEAs by taking IN/HOLD/OUT switch to insert.

If directed starts additional Charging pump lAW 2-ONP-22.O1 Rapid Downpower Appendix D. (attached page 18)

If directed, places Pzr. On recirc. lAW 2-ONP-22.O1 Rapid Downpower Appendix E. (attached page 19)

Programs the DEH per ONP-22.O1 step 6.1.3 for the desired

load reduction rate.

• Set reference by ensuring REF selected and then BOP depress desired MW endpoint, hit ENTER.

• Depress LOAD RATE type in desired load rate and hit ENTER.

. Depress GO pushbutton.

Notifies Plant Dispatcher.

When T-ave decrease is noted, starts Turbine down power per ONP-22.O1 step 6.1.4.

Continues to Supervise/Coordinate Power reduction in SRO accordance with 2-ONP-22.O1 Rapid Down Power Steps 6.2.1 thru 6.2.9.

L

REVISION NO. PROCEDURE TITLE: PAGE:

15 RAPID DOWN POWER PROCEDURE NO 0 0 2-ONP-22.01 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS 6.1 Immediate Operator Actions INSTRUCTIONS CONTINGENCY ACTIONS NOTE This Procedure may contain steps that could adversely affect reactivity.

ENSURE that proper consideration and appropriate briefings occur prior to performance of steps that could challenge reactivity.

1. BEGIN boration per Appendix C.

2, INSERT the Lead CEA Group approximately 6 inches to initially lower RCS temperature.

3. PERFORM the following:

A. PROGRAM the turbine DEH for the desired load reduction rate.

B. SET DEMAND I REF to desired power level.

NOTE While performing power maneuvers during which time Tavg and Tref are closely monitored it may be advantageous to change TR-111111121 chart speed from 30 minutes per division to 1 minute per division.

4. When a Tavg decrease is noted, Then 4. If in turbine MANUAL, Then DEPRESS the GO pushbutton on the DEPRESS and RELEASE the GV turbine DEH control panel. LOWER pushbutton as necessary to reduce / control the load reduction rate.

END OF SECTION 6.1

REVISION NO PROCEDURE TITLE. PAGE:

15 RAPID DOWN POWER 6 of 20 PROCEDURE NO.

2-ONP-22.01 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions INSTRUCTIONS CONTINGENCY ACTIONS

1. NOTIFY plant personnel using Gai-tronics and boost function as follows:

Attention all personnel, Unit 2 has commenced a Rapid Down-power due to (reason)

2. NOTIFY System of the rapid down power load reduction.

3. REFER TO Appendix A, Rapid Down Power Conditional Actions and MONITOR (or potential conditions during the down power.

A. ii any parameter is exceeded, Itin NOTIFY theSM/USand PERFORM the required action.

4. REFER TO Appendix B, Rapid Down Power Parameters and MAINTAIN parameters.

A. If any parameter is exceeded, flj NOTIFY the SM / US EVALUATE the problem.

5. it is desired to place additional charging pumps in service, Then PERFORM Appendix D, CHARGING PUMP GUIDANCE, as time permits.

6. If it is desired to Placethe pressurizer on recirculation, Then PERFORM Appendix E, PRESSURIZER RECIRCULATION GUIDELINES, as time permits.

7. § CONTROL Axial Shape Index with CEAs in accordance with NOP-100.02, Axial Shape Index Control, g as directed by the SM / US.

6

REVISION NO PROCEDURE TITLE PAGE 15 RAPID DOWN POWER 7 of 20 PROCEDURE NO 2-ONP-22.01 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

8. MAINTAIN Tavy within 6.6°F of Trei using 8. jT9 can NOT be maintained the following: within 6.6°F of Trei, IMi NOTIFY

• RCS Boration Rate the SM I US.

• CEA Position

• Turbine Load CAUTION Near the end of core life, it may not be possible to stabilize reactor power due to xenon and boron concentrations.

9. If desired power level is reached, Then 9.

STABILIZE the unit by performing the following:

A. SECURE Boration to the RCS per 2-NOP-02.24, Boron Concentration Control.

B. ENSURE Tave and Tref are matched and PLACE turbine on Hold.

C. MATCH Reference and Demand on Turbine Control Panel.

D. COMMENCE a Dilution to the RCS per 2-NOP-02.24, Boron Concentration Control, that will compensate for transient Xenon effects and maintain Reactor Power as directed by SM / US.

E. ENSURE that at least two charging pumps are operating per Appendix D.

F. BALANCE Charging and Letdown F. ii letdown is isolated, Then flows. OPERATE charging pumps as needed to control Pressurizer level.

G. ENSURE the pressurizer is on recirculation per Appendix E.

H. CONTACT Reactor Engineering for specific guidance on Axial Shape Index Control 7

REVISION NO PROCEDURE TITLE. PAGE:

15 RAPID DOWN POWER 8 of 20 PROCEDURE NO 2..ONP-22.01 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

10. When power level is approximately 45%, 10.

Then PERFORM the following:

A. STOP one Main Feed Pump.

B. ENSURE Steam Generator levels B. If the Steam Generator levels are maintained between 55% and can NOT be maintained 75% narrow range level, between 55% and 75%

narrow range level, Then RESTART the Main Feed Pump and evaluate the problem.

C. ENSURE Main Feed Pump suction pressure is stable at greater than 400 psig.

11. When power level is approximately 11.

40%, Then PERFORM the following:

A. STOP the Condensate Pump on the same electrical train as the secured Main Feed Pump.

B. ENSURE Main Feed Pump suction B. jf the Main Feed Pump pressure is stable at greater than suction pressure can NOT be 400 psig. maintained stable at greater than 400 psig, RESTART the Condensate Pump and evaluate the problem.

12. ENSURE FCV-12-1, Condensate Hdr Recirc to Condsr, operates to maintain greater than 10,000 gpm condensate Ilow.

8

REVISION NO. PROCEDURE TITLE PAQE:

15 RAPID DOWN POWER 9 of 20 PROCEDURE NO 2-ONP-22.01 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

13. When power level is approximately 13.

35%, i.b PERFORM the following:

A. OPEN V38238, Demin Wtr to 2A Htr Drain Pump Gland Quench Seal Isol.

B. STOP 2A Heater Drain Pump.

C. ENSURE Main Feed Pump suction C. j Main Feed Pump suction pressure is stable at greater than pressure can NOT be 400 psig. maintained stable at greater than 400 psig, Ibn RE START 2A Heater Drain Pump and evaluate the problem.

14. When power level is approximately 14.

35%, Then PERFORM the following:

A. OPEN V38239, Demin Wtr to 28 Htr Drain Pump Gland Quench Seal Isol.

B. STOP 2B Heater Drain Pump.

C. ENSURE Main Feed Pump suction C. 1! the Main Feed Pump pressure is stable at greater than suction pressure can NOT be 400 psig. maintained stable at greater than 400 psig, Then RESTART 28 Heater Drain Pump and evaluate the problem.

9

REVISION NO PROCEDURE TITLE PAGE.

15 RAPID DOWN POWER PROCEDURE NO 10 of 20 2-ONP-22.01 ST. L.UCIE UNIT 2 6.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE WHEN using Reheat CONTROL Panel, all four 8 steam valves go closed immediately WHEN Rheostat is moved counterclockwise.

15. When power level is less than 30% and both Heater Drain Pumps are stopped, Then REMOVE the MSRs from service as follows:

A. CLOSE MSR TCVs using the MSR Reheat Control panel.

B. CLOSE MV-08-4 and MV-08-10 (A and C MSR block valves).

C. CLOSE MV-08-8 and MV-08-06 (B and D MSR block valves).

16. When power is approximately 25%,

Then TRANSFER station electrical loads from the Auxiliary Transformers to the Startup Transformer by performing the following:

A. INSERT Sync Plug.

B. ROTATE to appropriate ST position.

C. VERIFY SYN-888 is stationary at the 12 oclock position.

D. VERIFY incoming and running voltages are matched.

E. CLOSE the appropriate start-up transformer.

F. Green FLAG the associated Auxiliary Transformer Breaker.

G. REMOVE Sync Plug.

10

0 REVISION NO 15 PROCEDURE TITLE RAPID DOWN POWER PAGE 11 of 20 PROCEDURE NO.:

2-ON P-22.01 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

17. When power is approximately 25%, 17. j.f the Main Feed Pump suction iian PLACE the running Main Feed pressure is NOT maintained Pump in the RECIRC position and greater than 400 psig Steam ENSURE the following: Generator levels are NOT maintained between 55% and 75% narrow range level, Ibn PLACE the Main Feed Pump control switch in AUTO RECIRC and evaluate the problem.

A. Main Feed Pump suction pressure is maintained greater than 400 psig, B. Steam Generator levels are maintained between 55% and 75%

narrow range.

CAUTION It is NOT desirable to trip the Reactor if Rapid Down Power is due to a Steam Generator Tube Leak.

18. If it is desired to trip the Reactor at this power level (20% to 25%), ]b PERFORM the following:

A. RECORD Main Gen KW Hrs in the chronological log as indicated on WHM/881.

B. Manually TRIP the Reactor.

C. EXIT to 2-EOP-01.

19. When power level is approximately 20%, fl! ENSURE FCV-24-100 through FCV-24-108, Turbine Drain Valves, are OPEN.

11

REVISION NO PROCEDURE TITLE PAGE:

15 RAPID DOWN POWER 12 of 20 PROCEDURE NO 2-ONP-22.01 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

20. If a Linear Range Safety Channel nuclear power detector is out of service, Then before lowering reactor power to less than 15%, PLACE High Startup Rate trip bistable for the affected channel in bypass or trip condition.

21. § When power is less than 15% but greater than 5%, Then PLACE jjjy one ADV per steam generator in automatic control, if desired.

22. When power is less than 15%, flj 22. j.f Reactor Loss of Load trip is ENSURE that the Reactor Loss of Load NOT bypassed, Then NOTIFY the trip is bypassed by the following SM I US and evaluate the indications: problem.

. Three out of four RPS channels Nuclear Pwr indications are less than 11%.

Annunciator L-29, LOSS OF LOAD /

LCL PWR DENS CHNL TRIP BYPASS, is LIT.

23. If the Reactor Loss of Load trip is 23. II the turbine TVs and GVs do bypassed, ].b TRIP the turbine and NOT close, Then NOTIFY the VERIFY: SM / US and PERFORM the following:

A. The Turbine TVs and GVs are A. TRIP the reactor.

CLOSED.

B. The OCBs and Exciter supply B. CLOSE HCV-08-1A, Main breakers are OPEN. Steam Hdr A Isolation Valve.

C. CLOSE HCV..08-1B, Main Steam Hdr B Isolation Valve.

D. ENSURE generator lockout occurs.

E. GO TO 2-EOP-01, Standard Post Trip Actions.

12

REVISION NO PROCEDURE TITLE. PAGE:

15 RAPID DOWN POWER 13 of 20 PROCEDURE NO 2-ONP-22.01 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

24. §2 ADJUST boration rate and CEA position to maintain power as directed by the SM / US.

25. MAINTAIN 2A S/G level between 60% 25. If the Steam Generator level can to 70% narrow range. NOT be maintained between 60%

and 70% narrow range level, iin NOTIFY the SM / US and GO TO Main Feedwater Off-Normal procedure 2-0700030.

26. CLOSE MV-09-05, Stm Gen 2A Reg Block Valve.

27. MAINTAIN 2B SIG level between 60% 27. lIthe Steam Generator level can to 7O% narrow range. NOT be maintained between 60%

and 7O% narrow range level, Then NOTIFY the SM / US and GO TO Main Feedwater Off-Normal Procedure 2-0700030.

28. CLOSE MV-09-06, Stm Gen 28 Reg Block Valve.

29. ENSURE RCS heat removal is 29. II Tavg can NOT be maintained, established and MAINTAIN Tav Then NOTIFY the SM I US and between 531 and 533°F as directed evaluate the problem.

by the SM / US.

30. ESTIMATE Xenon build-in and its effect on reactor power.

31. 1 J VERIFY the reactor is critical. 31. If the reactor is NOT critical, Then NOTIFY the SM I US and evaluate the problem.

32. DILUTE and / or MOVE CEAs as required to maintain reactor power as directed by the SM I US.

13

REVISION NO PROCEDURE TITLE: PAGE 15 RAPID DOWN POWER 14 of 20 PROCEDURE NO:

2-ONP-22.01 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

33. Ji directed by the SM I US, Then GO TO 2-GOP-123, Turbine Shutdown-Full Load to Zero Load.

34. If directed by the SM I US, Then GO TO 2-GOP-203, Reactor Shutdown.

END OF SECTION 6.2 14

REVISION NO PROCEDURE TITLE PAGE.

15 RAPID DOWN POWER PROCEDURE NO.:

15 of 20 2-ONP-22,01 ST. LUC UNIT 2 APPENDIX A RAPID DOWN POWER CONDITIONAL ACTIONS (Page 1 of 1)

1. II at any time parameters associated with automatic reactor or turbine trips are challenged are NOT recovering, ]fl prior to the respective parameters reaching an automatic trip set point, TRIP the reactor and turbine and GO TO 2-EOP-O1, Standard Post Trip Actions.

2. II at any time during power changes, Tavg is NOT within 66°F of Tiet for a given power level and efforts to regain control of temperature are unsuccessful, Then TRIP the reactor and GO TO 2-EOP-O1, Standard Post Trip Actions.

3. If at any time the unit load is greater than 30% power turbine back pressure is greater than 5.5 inches Hg absolute, fli.çj TRIP the unit and GO TO 2-EOP-O1, Standard Post Trip Actions.

4. at any time the unit load is less than or equal to 30% power and turbine back pressure is greater than 3.5 inches Hg absolute, Then TRIP the unit and GO TO 2-EOP-O1, Standard Post Trip Actions.

5. If at any time the differential pressure between the condensers is 2.5 inches of Hg absolute or higher, ]jj TRIP the unit and GO TO 2-EOP-O1, Standard Post Trip Actions.

6. If at any time the rapid down power is terminated, ]jjj ESTIMATE Xenon poison build-in and ADJUST RCS boron concentration and / or CEA position to maintain reactor power as directed by the SM / US.

7. II at any time plant parameters indicates that a steam generator tube leak has occurred, Ijj.j FOLLOW 2-0830030, Steam Generator Tube Leak load rate guidelines.

8. Refer to OPS-530 Pre-Planned Power Change Guidance.

END OF APPENDIX A 15

REVISION NO PROCEDURE TITLE: PAGE:

15 RAPID DOWN POWER PROCEDURE NO 16 of 20 2-ONP-22.01 ST. LUCIE UNIT 2 APPENDIX B RAPID DOWN POWER PARAMETERS (Page 1 of 1)

1. Maximum power reduction rate is 45 MW/minute.

2. Maintain Generator amperes less than or equal to 26 kiloamps per phase.

3. Maintain Generator terminal voltage between 21 KV and 23 Ky.

4. Maintain Exciter field current less than or equal to 310 amps.

5. Maintain 2A3 and 283, 4.16 KV bus voltage between 3.95 KV and 4.35 Ky.

6. Maintain Generator frequency greater than 59.5 HZ.

7. Maintain VCT level between 45% and 65% during power reduction.

8. Turbine bearing maximum bearing metal temperature is 225°F (Turbine Trip Criteria).

9, Turbine bearing maximum oil discharge temperature is 180°F F (Turbine Trip Criteria).

10. Turbine exhaust hood sprays automatic actuation temperature is 160°F.

11. Maintain Steam Generator levels between 55% and 75% narrow range level.

12. ¶2 Maintain Generator cold gas temperature between 45°F (7.2°C) and 114°F (46.1 °C).

13. Monitor Turbine Cooling Water Pump parameters and operate pumps as necessary to ensure adequate component cooling and pump operation,

14. § Maintain pressurizer level between 27% and 68%.

NOTE

§2 Rapid Down power may result in Pressurizer Pressure dropping below DNBR Limit.

15. ¶ Maintain pressurizer pressure between 2225 and 2275 psia.

END OF APPENDIX B 16

REVISION NO PROCEDURE TtTLE: PAGE.

15 RAPID DOWN POWER PROCEDURE NO..

17 of 20 2-ONP-22.01 ST. LUCIE UNIT 2 APPENDIX C RCS BORATION GUIDANCE (Page 1 of 1)

NOTE The steps in this Appendix are applicable when the CVCS is normally aligned, with no RCS boration or dilution in progress. If other than normal alignment, use guidance of 2-NOP-02.24, Boron Concentration Control.

1. BORATE the RCS by the following:

A. START either Boric Acid Pump 2A or 28.

B. PLACE FCV-2210Y control switch in AUTO.

C. If borating to the VCT, fl OPEN V251 2, Reactor Makeup Water Stop Vlv.

D. If borating to the Charging Pump suction, Then OPEN V2525, Boron Load Control Valve.

E. ADJUST FlC2210Y to the desired flowrate.

NOTE Ensure a minimum of 10 gpm of boric acid flow at all times while 8AM pump recirc valve is closed, F. If desired to maximize the boric acid flow rate, CLOSE the running BAM pump recrc valve.

G. MAINTAIN VCT pressure less than or equal to 30 psig by opening and closing V251 3, VCT Vent, as needed.

H. 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.

NOTE An Operator Aid has been placed at RTGB-205. 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 placecard.

END OF APPENDIX C 17

REVISION NO PROCEDURE TITLE PAGE.

15 RAPID DOWN POWER 18 of 20 PROCEDURE NO:

2-ONP-22.01 ST. LUCIE UNIT 2 APPENDIX D CHARGING PUMP GUIDANCE (Page 1 of 1)

.f Charging Pump(s) are to be started, Ii2. PERFORM the following:

A. ENSURE that each Charging pump that is desired to be started is ready to operate by local inspection by the SNPO, if time permits.

B. If associated Charging Pump Recirc Valve is operable, Then ENSURE that it is OPEN prior to starting the Charging Pump.

NOTE Placing a second or third charging pump in service will increase letdown flow which may cause the general area dose rates in the vicinity of the letdown line in the 19.5 Pipe Penetration Room or 19.5 Letdown Cubicle Room to exceed 1000 mr/hr (Locked High Radiation Area limit) due to reduced transport time of short-lived radioactive isotopes.

C. START the Charging pump.

D. NOTIFY Health Physics of the charging pump alignment.

E. ADJUST the bias on HIC-1 110, Level, using the upper knurled knob to control the letdown flow to maintain the actual Pressurizer Level to program RRS Pressurizer Level for current plant conditions, if required.

F. If FIA-2212, Chg Flow to Regen Hx, is in service, Then VERIFY proper Charging Header flow by observing FIA-2212 raise and stabilize for the number of Charging Pumps that are running.

G. If FIA-2212, Charging to Regen Hx, is NOT in service, Then VERIFY proper Charging Header flow by observing Letdown flow and expected changes in Pressurizer level for the number of Charging Pumps that are running.

H. ENSURE the running Charging Pump Reciro Valve is CLOSED.

I. PLACE the Chrg Pump Sel Running-B/U switch in the proper position for current plant conditions per operator aid placard on RTGB-205. (Charging pump combinations vs. selector switch)

END OF APPENDIX 0 18

REVISION NO PROCEDURE TTLE PAGE 15 RAPID DOWN POWER 19 of 20 PROCEDURENO.

2-ONP-22.01 ST. LUCIE UNIT 2 APPEN DIX E PRESSURIZER RECIRCULATION GUIDELINES (Page lofi)

NOTE

• The purpose of placing the Pressurizer on recirculation is to keep the Pressurizer and RCS boron concentration within 25 ppm when changing RCS boron concentration.

• From measured data, the estimated time in minutes to correct a greater than or equal to 25 ppm boron mismatch by operating 6 Backup Heater Banks may be determined as follows:

• Time (in mm.) to correct mismatch = [(Pzr ppm - RCS ppm) -

25ppm]x3

1. To place the Pressurizer on recirculation:

A. PLACE all available Backup Heater Bank control switches to ON.

B. Slowly REDUCE the AUTO setpoint on PlC-i 100X or PlC-i bOY, the selected Pressurizer Pressure controller, to maintain normal operating pressure.

C. OBSERVE HIC-1100, Pressurizer Spray output and PCV-1100E / hOOF, Pressurizer Spray Valve position indication to verify Main Spray flow.

NOTE Normally, the required number of Backup Bank heaters in service is dependent upon:

1. The magnitude of thermal losses from the system, including leakage to the Quench Tank.

2. The number of heater elements out of service.

The normal configuration is to have enough Backup Bank heaters in service to keep the Proportional Bank heaters at approximately 50% output.

END OF APPENDIX E 19

REVISION NO: PROCEDURE TITLE. PAGE:

15 RAPID DOWN POWER 20 of 20 PROCEDURE NO.

2-ONP-22.O1 ST. LUCIE UNIT 2 APPENDIX F AXIAL SHAPE INDEX CONTROL (Page 1 of 1)

Unplanned Load Reductions NOTE Contact Reactor Engineering for additional support in planning for or controlling core xenon oscillations.

1. II ASI cannot be maintained within transient band due to the inoperability of CEA(s), flj.j CONTACT Reactor Engineering to assist in determining the load reduction rate which would minimize the effects of ASI being out of the transient band.

CAUTION The duration and magnitude of operation with ASI in excess of the Steady State Band should be limited to the maximum extent possible.

2. Every effort should be made to maintain ASI within limits (+/- 0.5 of the ESI),

however, under extreme conditions (e.g., rapid downpower) the SM / US may direct temporary operation outside this limit. jj operation outside the limit is unavoidable during a rapid downpower, Then:

A. MAINTAIN ASI within RPS LPD pre-trip limits.

B. RESTORE ASI to within limits as soon as is practical.

C. Contact Reactor Engineering for evaluation and post-stabilization ASI guidance prior to any power increase.

3. REFER to NOP-1 00.02 for additional guidance on Axial Shape Index Control.

END OF APPENDIX F 20

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 1 Page 5 of 18 Event

Description:

Unit down power to remove 2A Heater Drain Pump from service.

Time N Position Aoolicants Actions or Behavior Booth Operator Instructions Booth Operator Response Control Room Indications Available:

Refers to Appendices A and B as directed by the SRO per RO/BOP steps 6.2.3 and 6.2.4.

Controls ASI as directed by SRO with CEAs or per NOP RO 100.02, Axial Shape Index Control Per step 6.2.7.

RO/BOP Maintains T-avg within 6.6°F of T-ref per step 6.2.8.

When desired power level reached stabilizes unit per step RO 6.2.9.

I GOP I When desired power level reached stabilizes unit per step 6.2.9.

-1 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 2 Page 6 of 18 I Event

Description:

Boric Acid Flow Control Valve FCV-221 OY fails closed Timej[Position_J Applicants Actions or Behavior Booth Operator Instructions: Trigger Boric Acid Flow Control Valve FCV-2210Y failure on examiner cue.

Note: Failure should be inserted after downpower is started approx 97-95% power.

Booth Operator Response: When requested by l&C to investigate failure of FCV 2210Y respond will investigate. Response after investigation, valve diaphragm has failed resulting in the valve being unable to open.

Control Room Indications Available: Boric acid flow goes to full scale low, indicating lights for FCV-2210Y goes from

- dual to green. No associated alarms RO Recognizes closed indication on FCV-2210Y and notifies SRO.

Directs RO actions in accordance with 2-ONP-02.01 Boron SRO Concentration Control Off-Normal Operating Procedure steps 6.0.9 A E. (attached page 23)

Ensures either Boric Acid pump is running.

Directs OPENING V2514, Emergency Borate.

- Directs Placing Makeup Mode Selector Switch in MANUAL.

Directs cycling the Boric Acid pump as necessary to control boric acid addition rate and rate of power change.

Directs monitoring for any abnormal change in T-avg.

Directs BOP to go to HOLD on turbine. (if already started)

Notifies shift manager and I&C of event.

RO Starts a Boric Acid pump if none are running.

22

PAGE:

REVISION NO.: PROCEDURE TITLE: .

7B BORON CONCENTRATION CONTROL 15 of 19 PROCEDURE NO.:

2-ONP-02.O1 ST. LUCIE UNIT 2 6 0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS CAUTION Prolonged use of V2514, Emergency Borate, can lead to uncontrolled power reduction rates. Boric Acid flow rate is equal to the charging pump flow rate when using the emergency borate valve.

9. If FCV-2210Y, Boric Acid Valve, fails to OPEN when a power reduction is required, Then PERFORM the following:

A. START either Boric Acid pump.

B. OPEN V2514 C. PLACE Makeup Mode Selector switch in MANUAL.

D. CYCLE the Boric Acid pump as necessary to control boric acid addition rate and the rate of power reduction.

E. MONITOR for any abnormal change in Tave END OF SECTION 6.0 23

Appendix D Operator Action Form ES-D-2

, Op Test No 1 Scenario # 2 Event 2 Page 7 of 18 j Event

Description:

Boric Acid Flow Control Valve FCV-2210Y fails closed j:i!I_Losition I Applicants Actions or Behavior Booth Operator Instructions:

Booth Operator Response:

Control Room Indications Available:

OPENS V2514, Emergency Borate.

o (This will cause annunciator M-42 Emergency Borate V2514 OPEN/OVLD/SS Isol to alarm.)

Places Makeup Mode Selector Switch in MANUAL.

Cycles the Boric Acid pump as necessary to control boric acid addition rate and rate of power change.

Monitors for any abnormal change in T-avg.

Puts turbine on HOLD as directed. (if already started)

, Monitors plant parameters while event in progress. -

Secure 2A HPDP lAW 2-GOP-123 step 6.22.1 (attached page 25) z*:

24

PAGE 3 PROCEDURE TIThE:

REVISION NO.:

30 TURBINESHUTDOWN-FULLLOADTO of 40 PROCEDURE NO ZERO LOAD 2-GOP-i 23 ST LUCIE UNIT 2 JNITIAU 6.21 ENSURE FCV-12-i, Condensate Hdr Recirc to Condsr, operates to maintain approximately 10,000 GPM condensate flow.

NPO NOTE The two substeps in the following step may be performed in any order, and I they may be performed at any time PRIOR to reaching 35% if the Heater LDrain Pump(s) need to be stopped due to plant conditions.

6.22 When power is approximately 35%, Then PERFORM the following:

1. STOP the 2A Heater Drain Pump as follows:

A. OPEN V38238, Demin Wtr to 2A Htr Drain Pump Gland Quench Seal Isol.

NPO B. STOP the 2A Heater Drain Pump.

C. ENSURE LCV-11-18A, 4A LP Htr Alt Drain, OPENS to control the level in the 4A Heater.

NPO D. VERIFY Main Feed Pump suction pressure is being maintained greater than or equal to 400 PSIG as indicated on P1219_A, Feedwater Pumps Header Pressure Suction.

E. H Main Feed Pump suction pressure is NOT being maintained greater than or equal to 400 PSIG, Then RESTART the Heater Drain Pump and evaluate the problem.

25

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 3 Page 8 of 18 Event

Description:

2A Charging Pump trips on ow oil pressure 1

H I1C Positin Applicants Actions or Behavior Booth Operator Instructions: Trigger 2A Charging Pump trip on examiner cue.

Booth Operator Response:

Control Room Indications Available: 2A Charging Pump Red light ON, Green light OFF Annunciator M.14 Charging Pump Flow Low, M.30 2A Charging Pump Trouble if ONLY 2A Charginq pumi was runninci.

RO Recognizes 2A Charging Pump trip, and reports to US.

SRO If only One Charging pump was running:

Directs RO action in accordance with 2-ONP-02.03 Charging and Letdown Off-Normal Procedure section steps 6.0,2 thru 6.0.6, 6.0.9, and 6.0.11 (attached pages 27-29)

SRO Recognizes entry into T.S. 3.1.2.2 and T.S 3.5.2a2 (both are 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> actions to restore a Charging pump).(attached page 30-T.S. 31)

Notifies shift manager of event.

.1 As directed performs 2-ONP-02.03 Charging and Letdown Off-:.

RO Normal Procedure steps 6.0.2 thru 6.0.6, 6.0.9, and 6.0.11.

(attached page 27-29)

SRO If Two Charging pumps were running: ____________

Directs RO to maintain Pressurizer level on program setpoint.

Notifies shift manager of event.

Adjusts Letdown bias to maintain Pressurizer level on program RO setpoint.

26

REVISION NO PROCEDURE TITLE PAGE 15B CHARGING AND LETDOWN PROCEDURE NO 5 of 26 2-ONP-02,03 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS INSTRUCTIONS CONTINGENCY ACTIONS

1. If letdown flow is lost, Ib&!2 STOP the charging pumps.

A. RETURN the charging pump control switches to AUTO.

CAUTION Severe thermal stress and flashing may occur in the Regenerative Heat Exchanger if letdown flow is NOT immediately isolated.

2. charging flow is lost, 2.1 ISOLATE Letdown by the Then ISOLATE letdown. following:

A. CLOSE V2515, Stop Valve-IC B. CLOSE V.2516, Containment Isol Valve-IC.

C. CLOSE V2522, Containment Isol Valve-CC.

NOTE With Charging and Letdown isolated pressurizer level will lower slowly due to RCP controlled bleedoff flow.

3. If charging and letdown flow has been lost, MAINTAIN Reactor power and RCS temperature constant to minimize pressurizer level deviations.

4. VERIFY all applicable automatic actions have occurred.

Appendix A contains a listing of expected automatic actions.

27

REVISION NO PROCEDURE TITLE PAGE:

15B CHARGING AND LETDOWN 6 of 26 PROCEDURE NO.:

2-ONP-02 03 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS CAUTION Prolonged use of Charging without Letdown could result in the Pressurizer exceeding the Technical Specification limit of 68%. Pressurizer level must be closely monitored.

5. § MAINTAIN Pressurizer level 5.1 § If Pressurizer level can NOT between 27% and 68% and be maintained between 27%

within 2% of setpoint as and 68%, ]J2. BE in at follows: least HOT STANDBY with the reactor trip breakers OPEN within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

A. As Pressurizer level reduces to approximately 2% less than setpoint, START one Charging Pump.

B. When Pressurizer level is approximately 2% greater than setpoint, THEN STOP the running Charging Pump.

C. PLACE the previously running Charging Pump Control Switch in AUTO.

6. j charging and letdown flow has been lost, Then DETERMINE the cause.

7. If a charging system leak has occurred, Then ISOLATE the leak and refer to applicable Technical Specifications for guidance.

6. If the normal charging flow path becomes unavailable, flj REFER TO Appendix B, Alternate Charging Flow Path through A HPSI Header.

28

REVISION NO IPROCEDURE TITLE PAGE.

158 I CHARGING AND LETDOWN 7 of 26 PROCEDURE NO 1

2-ONP-02.03 I ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

9. If letdown is unavailable, Then MAINTAIN pressurizer level by temporarily cycling charging pumps.

NOTE

§ If one or more charging pumps have lost pumping ability, gas binding may have occurred. This can result from pumping the VCT dry (hydrogen binding) or rupture of a charging pump suction accumulator (nitrogen binding). If this occurred, the charging pumps must be vented after restoring a source of water to the suction.

10. jjthe charging pumps are gas bound, Then REFER TO Appendix C, Venting a Gas Bound Charging Pump.

11. If charging and letdown has 11.

been lost and can be restored, jbj RE-ESTABLISH charging and letdown flow as follows:

A. ENSURE adequate VCT A.1 RESTORE the VCT level is indicated, to a normal level in accordance with 2-ONP-02 .0 1, Boron Concentration Control.

B. ENSURE the Level Control Valve selector switch and the Pressure Control Valve selector switch are selected to the level and pressure control valves presently in service.

29

REACTIVITY CONTROL SYSTEMS FLOW PATHS - OPERATING LIMfl1NG CONDITION FOR OPERATION 3.1.2.2 At least two of the following three boron injection flow paths shall be OPERABLE:

a. One flow path from the boric acid makeup tank(s) with the tank meeting Specification 3.1.2.8 part a) or b), via a boric acid makeup pump through a charging pump to the Reactor Coolant System.

b. One flow path from the boric acid makeup tank(s) with the tank meeting Specification 3.1.2.8 part a) or b), via a gravity feed valve through a charging pump to the Reactor Coolant System.

c. The flow path from the refueling water storage tank via a charging pump to the Reactor Coolant System.

OR At least two of the following three boron injection flow paths shall be OPERABLE:

a. One flow path from each boric acid makeup tank with the combined tank contents meeting Specification 3.1.2.8 C), via both boric acid makeup pumps through a charging pump to the Reactor Coolant System.

b. One flow path from each boric acid makeup tank with the combined tank contents meeting Specification 3.1.2.8 c), via both gravity feed valves through a charging pump to the Reactor Coolant System.

c. The flow path from the refueling water storage tank, via a charging pump to the Reactor Coolant System.

APPLICABILITY: MODES 1 2, 3 and 4.

ACTION:

With only one of the above required boron injection flow paths to the Reactor Coolant System OPERABLE, restore at least two boron injection flow paths to the Reactor Coolant System to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY and borated to a SHUTDOWN MARGIN equivalent to its COLR limit at 200 °F within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />; restore at least two flow paths to OPERABLE status within the next 7 days or be in COLD SHUTDOWN within the next 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

ST. LUCIE - UNIT 2 Amendment No. 8, 25, 40, 105 30

EMERGENCY CORE COOLING SYSTEMS 314.5.2 ECCS SUBSYSTEMS OPERATING -

LIMITING CONDITION FOR OPERATION 3.5.2 Two independent Emergency Core Cooling System (ECCS) subsystems shall be OPERABLE with each subsystem comprised of:

a. One OPERABLE high pressure safety injection pump,

b. One OPERABLE low pressure safety injection pump, and

c. An independent OPERABLE flow path capable of taking suction from the refueling water tank on a Safety Injection Actuation Signal and automatically transferring suction to the containment sump on a Recirculation Actuation Signal, and

d. One OPERABLE charging pump.

3*

APPLICABILITY: MODES 1 2, and ACTION:

a. 1. With one ECCS subsystem inoperable only because its associated LPSI train is inoperable, restore the inoperable subsystem to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

2. With one ECCS subsystem inoperable for reasons other than condition al., restore the inoperable subsystem to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

b. In the event the ECCS is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within 90 days describing the circumstances of the actuation and the total accumulated actuation-cycles to date. The current value of the usage factor for each affected safety injection nozzle shall be provided in this Special Report whenever its value exceeds 0.70.

With pressurizer pressure greater than or equal to 1750 psia.

ST. LUCIE - UNIT 2 Amendment No. 4-06, 119 31

Appendix D Operator Action Form ES-D-2 Op Test No: 1 Scenario # 2 Event # 4 Page 9 of 18

Event

Description:

2A DEH pump trips I:rni - Position Applicant s Actions or Behavior Booth Operator Instructions: Trigger 2A DEH pump trip on examiner cue.

Booth Operator Response:

• Control Room Indications Available: No light indication on 2A DEH pump, 2B does not start on decreasing DEH header pressure.

Annunciator D-36 DEH pp overload SRO Recognizes the 2A DEH pump tripped.

Recognizes the 2B DEH pump did not start.

-. Directs BOP to manually start 2B DEH pump.

Notifies management of event.

V RO Monitors primary plant parameters during event.

1, BOP Recognizes the 2A DEH pump tripped.

V *VVVV Recognizes the 26 DEH pump did not start. Should have started at 1550 psia.

Refers to Annunciator summary for D-36 DEH pp overload.

(attached page 33)

Manually starts 2B DEH pump as directed.

32

REVISION NO: PROCEDURE TITLE: PANEL; 0 ANNUNCIATOR RESPONSE PROCEDURE D PROCEDURE NO: WiNDOW; 2-ARP-01-D36 ST. LUCIE UNIT 2 36 ANNUNCIATOR PANEL 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 DEH 21 22 23 24 25 26 27 28 29 30 PUMP j 32 33 34 35 37 38 39 40 OVRLD 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 D-36 DEVICE: LOCATION: SETPOINT:

74/720 Bkr 2-40832 on MCC 2A1 De-energized 49/720 Bkr 2-40832 on MCC 2A1 Thermal Overload 74/721 Bkr 2-40610 on MCC 2B1 De-energized 49/721 Bkr 2-40610 on MCC 2B1 Thermal Overload ALARM CONFIRMATION:

1 Green light LIT on the previously running DEH Pump indicates the thermal overload has actuated.

2. Loss of both indicating lights on RTGB-201 for the affected pump indicates loss of control power or breaker open.

OPERATOR ACTIONS:

1. ENSURE the standby DEH Pump is RUNNING.

2. the standby pump did NOT start, Ibn PLACE the control switch to START.

3. P1-22-26, Emergency Trip Header Pressure, is approaching 1000 psig and dropping, PERFORM the following:

A. CHECK status of annunciator L-29, LOSS OF LOAD/ LCL PWR DENS CHNL TRIP BYPASS.

B.If annunciator L-29 is CLEAR, ]JJ.J2 PERFORM the following:

1. TRIP the Reactor and Turbine.

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

4. If the Turbine trips, Then IMPLEMENT 2-EOP-01, Standard Post Trip Actions, if applicable.

5. PLACE the previously running standby DEH Pump control switch to STOP.

6. DISPATCH an operator to the applicable DEH pump breaker:

• Bkr 2-40832, Elect Hydraulic Gov Fluid Pp 2A, on MCC 2A1.

• Bkr 2-40610, Elect Hyd Gov Fluid Pump 2B, on MCC 2B1.

7. PERFORM the following at the applicable breaker:

A. CHECK the breaker CLOSED.

B. PRESS the Thermal Overload RESET button.

ft the breaker is CLOSED and indicating lights are NOT LIT, Then ENSURE the control power fuse is checked and replaced as necessary.

UI the breaker is TRIPPED the thermal overload repeatedly actuates, Then CONTACT EM for troubleshooting and repairs.

CAUSES: This alarm may be caused by either of the following for either DEH Pump:

• Thermal Overload (49) Relay actuating due to motor overload.

• Control power loss due to a blown fuse or the breaker is open.

REFERENCES:

1. CWD 2998-B-327 sheets 720 and 803

2. 2998-31 33

Appendix D Operator Action Form ES-D-2

. Op Test No: 1 Scenario # 2 Event # 5 Page 10 of 18

[ Event Descripton: Containment Pressure PT-07-2A fails high

[Tme Position Applicants Actions or Behavior

[Booth Operator Instructions: Trigger PT-07-2A failure on examiner cue.

Booth Operator Response:

Control Room Indications Available: RTGB-206 PIS-07-2A indicates high Annunciators in alarm:

Q2 ESFAS ATI, Q-3 CNTMT Press SIAS Channel Trip, S-17 CNTMT Press High Channel Trip, P.13 CNTMT Press High CIS Channel Trip, P.23 CNTMT Press High CIS Channel Pre Trip, L-5 CNTMT Press High Channel Trip, L-13 CNTMT Press Hi1 h Channel Pre Trii SRO/BOP Recognize numerous alarms.

!RO Directs implementation of 2-ONP-99.01 Loss Of Tech Spec SRO Instrumentation step 6.3.2.E.1 or 6,3.2.E.2. (attached page 35)

SRO Recognize entry into T.S. 3.3.1 action 2 (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place in trip or bypass) and 3.3.2 action 13, 18a & 18b. (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place in T.S. trip or bypass) (attached pages 36-38)

RO Monitors primary plant parameters during event.

Obtains keys 109,127,128, & 129 and Bypasses, or, Trips Channel A trip units as directed per of 2-ONP-99,01, Loss Of BOP Tech Spec Instrumentation step 6,3.2.E.1 or 6.3.2.E.2.

(attached page 35) 34

REVISION NO PROCEDURE TITLE PAGE 21 LOSS OF TECH SPEC INSTRUMENTATION 17 of 37 NO 2-ONP-99.01 ST. LUCIE UNIT 2 6.3 ESFAS Channel Malfunction (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

2. (continued) 2. (continued)

NOTE Containment pressure monitors are covered by Tech Spec 3.3.1, Table 3.3-1 for RPS and Tech Spec 3.3.2, Table 3.3-3 for ESFAS.

• ESFAS cabinet door key, key 114, is required for bypassing ESFAS.

• Containment Pressure SIAS and MSIS share the same bistable and isolation modules.

E, Containment Pressure E.1 PERFORM ONE of the following:

instrumentation indication PIS-07-2A/B/C/D.

1. BYPASS the following channels effected by the failed Containment Pressure instrument:

• Hi Cntmt Press RPS trip unit (key 109)

• Cont Press SIAS (key 127)

• Cntmt Press CIS (key 129)

• Cntmt Press CSAS (key 128)

OR

2. PLACE the affected RPS and ESFAS trip units in TRIP in accordance with Appendix A, Placing Trip Units in Trip.

35

TABLE 3.3-1 (Continued)

ACTION STATEMENTS ACTION 2 - a. With the number of channels OPERABLE one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may continue provided the inoperable channel is placed in the bypassed or tripped condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. The channel shall be returned to OPERABLE status no later than during the next COLD SHUTDOWN.

b. With the number of channels OPERABLE one less than the Minimum Channels OPERABLE, STARTUP and/or POWER OPERATION may continue provided the following conditions are satisfied:

1. Verify that one of the inoperable channels has been bypassed and place the other inoperable channel in the tripped condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

2. All functional units affected by the bypassed/tripped channel shall also be placed in the bypassed/tripped condition.

With a channel process measurement circuit that affects multiple functional units inoperable or in test, bypass or trip all associated functional units as listed below:

Process Measurement Circuit Functional Unit Bypassed

1. Safety Channel Nuclear Instrumentation Wide Range Rate of Change of Power High (RPS)

Linear Range Variable Power Level High (RPS)

Local Power Density High (RPS)

Thermal Margin/Low Pressure (RPS)

2. Pressurizer Pressure - Pressurizer Pressure High (RPS)

Thermal Margin/Low Pressure (RPS)

Pressurizer Pressure Low (ES F)

3. Containment Pressure - Containment Pressure High (RPS)

Containment Pressure High (ES F)

4. Steam Generator Pressure - Steam Generator Pressure Low (RPS)

Thermal Margin/Low Pressure (RPS)

AFAS-1 and AFAS-2 (AFAS)

Steam Generator Pressure Low (ESF)

5. Steam Generator Level - Steam Generator Level Low (RPS)

If SG-2A, then AFAS-1 (AFAS)

If SG-2B, then AFAS-2 (AFAS)

ST LUCIE - UNIT 2 Amendment No. 48, , 149 36

TABLE 3.3-3 (Continued)

TABLE NOTATION (a) Trip function may be bypassed in this MODE when pressurizer pressure is less than 1836 psia; bypass shall be automatically removed when pressurizer pressure is greater than or equal to 1836 psia.

(b) An SIAS signal is first necessary to enable CSAS logic.

(c) Trip function may be bypassed in this MODE below 700 psia; bypass shall be automatically removed at or above 700 psia.

The provisions of Specification 30.4 are not applicable.

ACTION OF STATEMENTS ACTION 12 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

ACTION 13 - With the number of channels OPERABLE one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may continue provided the inoperable channel is placed in the bypassed or tripped condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. The channel shall be returned to OPERABLE status no later than during the next COLD SHUTDOWN.

With a channel process measurement circuit that affects multiple functional units inoperable or in test, bypass or trip all associated functional units as listed below.

Process Measurement Circuit Functional Unit Bypassed

1. Containment Pressure - Containment Pressure High (SIAS, CIAS, CSAS)

Containment Pressure High (RPS)

2. Steam Generator Pressure - Steam Generator Pressure Low (MS IS)

AFAS-1 and AFAS-2 (AFAS)

Thermal Margin/Low Pressure (RPS)

Steam Generator Pressure Low (RPS)

3. Steam Generator Level - Steam Generator Level Low (RPS)

If SG-2A, then AFAS-1 (AFAS)

If SG-2B, then AFAS-2 (AFAS)

4. Pressurizer Pressure - Pressurizer Pressure High (RPS)

Pressurizer Pressure Low (SIAS)

Thermal Margin/Low Pressure (RPS)

ST. LUCIE - UNIT 2 Amendment No. 2, , 149 37

TABLE 3.3-3 (Continued)

TABLE NOTATION ACTION 18 - With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in either the bypassed or tripped condition and the Minimum Channels OPERABLE requirement is demonstrated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. If the inoperable channel can not be restored to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />, then place the inoperable channel in the tripped condition.

b. With a channel process measurement circuit that affects multiple functional units inoperable or in test, bypass or trip all associated functional units as listed in ACTION 13.

c. With the number of channels OPERABLE one less than the Minimum Channels OPERABLE, operation may proceed provided one of the inoperable channels has been bypassed and the other inoperable channel has been placed in the tripped condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. Restore one of the inoperable channels to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

ACTION 19 - With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the following conditions are satisfied:

a. Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> the inoperable channel is placed in either the bypassed or tripped condition. If OPERABILITY can not be restored within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />, be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

b. The Minimum Channels OPERABLE requirement is met; however, one additional channel may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing per Specification 4.3.2.1.

ST. LUCIE - UNIT 2 Amendment No. 132 38

Appendix D Operator Action Form ES-D-2 O Test No 1 Scenario # 2 Event # 6 7, 8 Page 11 of 18 venl Descr:ption. Steam Leak in Containment on 2B S/G, 2B MSIV fails to close on MSIS, AFAS lockout fails to stop feeding 2B S/G from 2B AFW pump.

PosioJ Applicants Actions or Behavior Booth Operator Instructions: Trigger Steam Leak in Containment on examiner cue. Ensure 2B MSIV failure to close on MSIS is enabled.

Booth Operator Response:

Control Room Indications Available: RTGB- 206 rising Containment Building pressure, lowering S/C pressures RTGB-204 RCS temperatures dropping Recognizes S/G pressure dropping and Containment Building SRO pressure rising.

Directs RO to trip reactor prior to MSIS.

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

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

Directs one RCP stopped when T Id approaches 5000 F.

0 Directs RO to stop 1 RCP in each loop on SIAS on low Pzr Directs Emergency boration due to uncontrolled cooldown at 500°F.

SRO Directs manual closure of 2B MSIV following failure to close on Critical MSIS.

Task 39

Aperidix D Operator Action Form ES-D-2 Op Test No 1 Scenario # 2 Event # 6 7, 8

, Page 12 of 18 Event

Description:

Steam Leak in Containment on 2B S/G, 2B MSIV fails to close on MSIS.

AFAS lockout fails to stop feeding 2B SIG from 2B AFW pump.

Time J Position Applicant s Actions or Behavior Booth Operator Instructions:

Booth Operator Response:

Control Room Indications Available:

I Manually trips reactor as directed. Performs EOP-01 Safety RO Functions as directed for Reactivity Control, inventory Control, Pressure Control, Core Heat removal.

Emergency borates when directed. (from RCS Heat Removal Safety Function)

. Places Makeup Mode Selector Switch in Manual.

. Ensures V2525 Load control valve closed.

. Starts 2A or 2B BAM Pump.

. Closes V2650 Tank 2A Recirc valve.

. Closes V2651 Tank 2B Recirc valve,

.OpensV25l4 Emergency Borate valve.

Pressure Control

• Verifies RCS pressure is between 1800-2300 psia. (at 1736 psia verify S1AS and stop RCP in each loop.)

• Verifies RCS pressure is trending 2225-2275 psia.

(control manually)

• Verifies RCS subcooling is >20°F.

Core Heat Removal

• Verifies at least one RCO running with COW. ( if >10 minutes with no COW must secure)

. Verifies loop delta T is <10°F.

Stops one RCP when directed as TCOid <500°F.

RO Critical Manually closes 2B MSIV as directed.

Task 40

Appendix D Operator Action Form ES-D-2 Op Tcst No. 1 Scenario # 2 Event 6 7, 8 Page 13 of 18 Even Description. Steam Leak in Containment on 2B S/G, 2B MSIV fails to close on MSIS.

AFAS lockout fails to stop feeding 2B S/G from 2B AFW pump.

Tim Position_J[ Applicant s Actions or Behavior Booth Operator Instructions:

Booth Operator Response:

Control Room Indications Available:

Verifies turbine trip on reactor trip. Performs EOP-O1 Safety BOP functions as directed for: Vital Auxiliaries, RCS Heat Removal, Containment Conditions.

Closes MSR reheat Block Valves and Ensures MSR Warmup Valves are CLOSED.

Notifies NPO to perform Appendix X section 1 of EOP.99.

(outside CR actions)

Maintenance of Vital Auxiliaries

• Verifies turbine governor and throttle valves closed.

• Verifies GEN Brk open (East breaker, Mid Breaker and Exciter Breaker.)

• Verifies all vital and non vital AC Buses energized.

• Verifies all vital and non vital DC Buses energized.

Closes Spillover Bypass valve MV-08-814.

41

Appoidx D Operator Action Form ES-D-2 Op Tcsl No 1 Scenario # 2 Event # 6 7, 8 Page 14 of 18 Event

Description:

Steam Leak in Containment on 2B S/G, 2B MSIV fails to close on MSIS, AFAS lockout fails to stop feeding 28 S/G from 28 AFW pump.

Tuii Positionj Applicant s Actions or Behavior Booth Operator Instructions:

Booth Operator Response:

Control Room Indications Available:

Containment Conditions

. Verifies Containment pressure <2 psig. (Pressure is increasing ensures 4 Containment Cooling fans on.)

. Verifies NO Containment radiation monitors in alarm.

. Verifies Containment temperature is less than 120°F.

(Temperature is increasing)

. Verifies NO secondary plant radiation alarms.

Re-establishes CCW to RCPs lAW 2-EOP-99, Appendix J as directed or stop all RCPs if COW lost >10 minutes. (this may be done in 2-EOP-01) (attached pages 49-50)

SRO Evaluates diagnostic flow chart of 2-EOP-01.

Exits EOP-01 to EOP-05 Excess Steam Demand.

Enters 2-EOP-05 ESD after analysis from Diagnostic Flow chart.

Directs BOP perform Safety Function Status Checks.(SFSC)

Directs Appendix A EOP-99 Sampling S/Gs.(attached pages 51-52)

If SIAS present verify SI flow lAW Figure 2.(attached page 48)

Directs one RCP/LOOP stopped when SIAS received. (may 42

Appendix D Operator Action Form ES-D-2

• Op Test No.: Scenario # 2 Event # 6 7, 8 Page 15 of 18 Evcnt

Description:

Steam Leak in Containment on 28 S/G, 2B MSIV fails to close on MSIS, AFAS lockout fails to stop feeding 2B SIG from 2B AFW pump.

-. Position I Applicants Actions or Behavior -

have been directed in 2-EOP-O1)

Booth Operator Instructions:

Booth Operator Response:

Control Room Indications Available:

Directs COW restored to RCPs per Appendix J 2-EOP-99.(may 1-have been completed in 2-EOP-O1) (attached pages 49-50)

Notifies shift manager of event and need to classify.

SRO Directs ROS temperature stabilized within the limits of Figure Critical 1A, using 2A ADVs when 2B S/G blown dry.(attached page 45)

Task 43

Appo:idx D Operator Action Form ES-D-2 Op Ost No 1 Scenario # 2 Event # 6 7, 8

, Page 16 of 18 Description Steam Leak in Containment on 28 SIG, 28 MSIV fails to close on MS IS, AFAS lockout fails to stop feeding 2B S/G from 28 AFW pump.

Time rposition j Applicants Actions or Behavior Booth Operator Instructions:

Booth Operator Response:

Control Room Indications Available:

RO Opens A AD Vs to stabilize RCS temperature within the limits of Figure 1A when 2B SG blown dry. See Ops Policy Critical Task 539. (attached page 45-47)

Stops one RCP/LOOP when directed. (may have been RO completed in 2-EOP-01)

Performs SFSCs EOP-05 when directed.

STA

. Verify SI flow lAW Figure 2 (attached page 48)

Performs EOP-99 Appendix J CCW restoration to RCPs BOP when directed. (may have been completed in 2-EOP-01 (attached pages 49-50)

Performs Appendix A when directed.(attached pages 51-52)

Recognizes that AFAS lockout has failed and 2B S/G is -

SRO/BOP/RO being fed from 2B AFW pump.

SRO Directs RO to stop feeding 2B SIG by stopping 2B AFW Critical Step pump.

RO Takes 2B AFW pump control switch to STOP as directed.

Critical Step 44

REVISION NO.: PROCEDURE TITLE: PAGE:

36A APPENDICES / FIGURES / TABLES / DATA 119 of 156 PROCEDURE NO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 FIGURE IA RCS PRESSURE TEMPERATURE (Page 1 of 1)

(Containment Temperature Less Than or Equal to 200°F)

E 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.

2400 k Opone Ad en LJe CO.* ROV RCO d6$ At.t l.fl.Qfl ID In SaDhon çÉ IP,a p,oC64we $t.I 1 4s#y We 4

vaDy$ I?. Oporep. *4 )nd 4 cDaçn Dt necanJy .Ott4 P.

OP C.DIDnIOI 2200 2000 1800 Maxlrllunl SubC00Ie 1800 S

1400 0

200 0.

1000 V Miremuni Subcooled 800 RCP NPSH 600 400 9nOudes IrsIruInenI UnceIlaInhes 200 0

0 100 200 300 400 500 600 700 800 ndicate RCS Temperalure (F)

RCS Pressure Range Required QSPDS Subcooled Margin Reading (Rep GET) 2250 psia to 1 000 psia 40 to 1 80°F 1000 psia to 500 psia 50 to 170°F Less than 500 psia 80 to 160°F 45

ST. LUCIE PLANT QPS-539 OPERATIONS DEPARTMENT POLICY Rev. I Date 06/02/09 RCS COOLDOWN GUIDANCE Page lof2 THIS POLICY HAS BEEN COMPLETELY REWRITTEN The purpose of this guidance is to precisely control the plant during RCS cooldowns.

The limit, at which the RCS is cooled, is determined by the plant configuration (e.g., RCPs in operation, number of SOs available, status of subcooling, etc). The method of cooldown will be determined by the availability of condenser vacuum, SBCS, ADVs, and Safety Injection flow rate. When cooling down the RCS:

The US will:

1. Direct the RCO to commence a cooldown of the RCS using ADVs or SBCS.

2. Give the RCO a limit (e.g., Do not exceed 100°F in any one hour period).

The RCQ will:

1. Document RCS T-cold (the starting point will always be 532°F post trip). Document and report RCS T-cold and cooldown rate to the US every 10 minutes.

2. Commence a cooldown of the RCS. Ensure that the limits of Figure 1A or 1 B are being restored or maintained.

3. Using SBCS for recovery of subcooling or during a Steam Generator Tube Rupture cooldown to T-hot less than 510°F:

a. Place the SBCS in manual operation.

b. Fully open PCV-8801. If PCV-8801 is unavailable, use the next available SBCS valve.

4. Using ADVs for recovery of subcooling or during a Steam Generator Tube Rupture cooldown to 5 10°F:

a. Place an ADV on each Steam Generator in service, preferably in Auto-Manual (if available) or Manual-Manual.

b. For Unit 1, open the ADV on each Steam Generator to 50% open.

c. For Unit 2, fully open one ADV on each Steam Generator.

46

ST. LUCIE PLANT OPS-539 OPERATIONS DEPARTMENT POLICY Rev. I Date 06/02/09 RCS COOLDOWN GUIDANCE Page 2of2

5. Once subcooling is restored or the cooldown limit is being approached, adjust the position of the ADVs or SBCS to ensure that the cooldown limit-will not be exceeded.

The objective here is not to cool down 100°F in a few minutes and then stop the cool down for the remainder of the hour. After the initial opening, ADVs or SBCS should be adjusted to achieve a rate of 100°F/hour, based on each 10 minute plot. Continued lowering of steam flow may be necessary if ECCS flow is present. If after the first 10 minutes the rate is still >100°F/hour, then adjust ADVs or SBCS to 75% open.

If after the next 10 minute plot it is still >100°F/hour, then adjust ADVs or SBCS to 50%

open and so on until a balance is achieved between steaming and ECCS flow.

If ECCS flow alone in contributing to RCS cool down at >100°F/hour, then steaming should be secured.

6. Once 510°F T-hot is reached for a Steam Generator Tube Rupture cooldown, adjust the position of ADVs or SBCS to ensure that the cooldown limit will not be exceeded.

The RCS temperature will be stabilized when the Excessive Steam Demand has terminated, or the Steam Generator has blown dry.

The US will:

1. Direct the RCO to stabilize RCS temperature using ADVs at the lowest RCS T-cold.

The RCO will:

1. Determine the saturation pressure for the lowest RCS T-cold (if this wasnt performed prior to dry-out, the ADV[s] will be opened first then the saturation pressure will be determined).

a. For Unit 1: open the ADV on the non-faulted Steam Generator to 100% open, in manual, then adjust the auto setpoint to the saturation pressure for the lowest RCS T-cold and place it in auto.

b. For Unit 2: open one ADVs on the non-faulted Steam Generator tolOO% open, in manual, then adjust the auto setpoint to the saturation pressure for the lowest RCS T-cold and place it in auto. Open the second ADV on the non-faulted Steam Generator to 100% open, in manual, then adjust the auto setpoint to the saturation pressure for the lowest RCS T-cold and place it in auto.

Approved: (David Lanyl Signature on File)

Assistant Operations Manager St. Lucie Plant 47

RFVISION NO [ROCEDURE WILE IPAGE 36A APPENDICES / FIGURES / TABLES I DATA 121 of 156 PROCEDURE NO SHEETS 2-EOP-99 ST. LUCIE UNIT 2 I

FIGURE 2 SAFETY INJECTION FLOW VS. RCS PRESSURE (Page 1 of 1) 130O-1200 - _o This curve represents minimum expected I. SI Flow. If measured flow is less than this, 1100 figure Then SI System lineup should be E Ivenfied. -

S S

boo -

900 800 R

P 600- H 1 Full Train 500 E 400 4..

P 200 1001 0 101 4000 5000 6000 TOTAL SAFETY INJECTION FLOW (gpm) (P/OPS*EQP99IFJReVOII 48

REVISION NO PROCEDURE TITLE PAGE 36A APPENDICES I FIGURES / TABLES / DATA 62 of 156

-ROCEDURENO SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX J RESTORATION OF CCW AND CBO TO THE RCPs (Page 1 of 2)

Li 1. ENSURE Instrument Air to Containment is available by PLACING HCV-18-1 to CLOSE / 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-149 (HCV-14-1O) will open 5 seconds after HCV-14-8A (HO V-i 4-8B) 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.

Li 2. If 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

• HC V-I 4-10 N Hdr Isol Suction Li 3. ALIGN CCW to I from the RCPs by OPENING ALL of the folIowng valves:

Li HCV-14-1, CCWT0 RC PUMP Li HCV-14-2, CCW From RC PUMP Li HCV-14-7, CCW To RC PUMP Li HCV-14-6, CCW From RC PUMP Li 4. II CIAS has isolated controlled bleedoff flow to the VCT, Then OPEN V2507, RCP Bleedoff Relief Stop Vlv.

49

EVISION NO PROCEDURE TITLE PAGE.

36A APPENDICES I FIGURES I TABLES / DATA 63 of 156 RDCEDURE NO SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX J RESTORATION OF CCW AND CBO TO THE RCPs (Page 2 of 2)

CAUTION 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.

0 5. ENSURE ALL RCP Seal Cooler Isolation valves are OPEN:

0 HCV-1 4-1 1-Al, CCW From 2Al RCP Seal Cooler 0 HCV-14-1 1-A2, CCW From 2A2 RCP Seal Cooler 0 HCV-l 4-11 -Bi, COW From 2B1 RCP Seal Cooler 0 HCV-14-ll-B2, COW From 2B2 RCP Seal Cooler 0 6. VERIFY RCP COW related alarms are CLEAR or have been evaluated and dispositioned.

END OF APPENDIX J 50

REVISION NO PROCEDURE TITLE: PAGE:

36A APPENDICES / FIGURES / TABLES I DATA PROCEDURE NO SHEETS 3 of 156 2EOP-99 ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 1 of2)

A Train (q) B Train (NJ) 0 1. If a LOOP has occurred, Then PERFORM BOTH of the following:

0 A. ENSURE 2AB 480V Load Center is aligned to an energized bus.

U B. DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 2B Instrument Air Compressors.

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.

N OTE

• HCV-14-9 (HCV-14-1O) 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 0 2. II 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-14-80

• I-ICV-14-1O 51

R[VISION NO PROCEDURE TITLE PAGE 36A APPENDICES / FIGURES I TABLES / DATA PROCEDURE NO of 156 SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 2 of 2)

U 3. If CIAS or high radiation has closed the SGBD Sample Valves, jJ OPEN FCV-23-7 and FCV-23-9 by PLACING the control switch to CLOSE / OVERRIDE and then to OPEN.

U 4. DIRECT Chemistry to perform S/G samples for activity and boron.

Li 5. II S/Gs cannot be sampled, Itin DIRECT Health Physics to conduct secondary plant local area radiation surveys.

END OF APPENDIX A 52

\ppel(t x 0 Operator Action Form ES-D-2 Oe Test No 1 Scenario # 2 Event # 9 Page 17 of 18 E.cii Dcscritjlion

Isolate 2B SIG Tin JPositio_J Applicants Actions or Behavior Booth Operator Instructions:

Booth Operator Response: When directed, initiate Isolate 2BA SG per App R.

Control Room Indications Available:

• SRO Critical Directs isolation of 2B SIG, 2-EOP-99 Appendix R.

Step BOP

• Performs Appendix R to isolate the 26 SIG when directed.

Critical (attached pages 5455)

Step 1**-.**-..-.*

Scenario Termination Cue:

• 2B SIG is isolated lAW 2-EOP-99 Appendix R

• RCS temperature and pressure are stabilized and are under control.

53

REV)SiON NO PROCEDURE liThE PAGE.

36A APPENDICES I FIGURES I TABLES / DATA PROCEDURE NO SHEETS 90 of 156 2.EOP-99 ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 1 of 6)

Section 1: 2A Steam Generator Isolation CAUTION If S/C 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-08-1A, Main Steam Header A Isolation Valve (MSIV), is CLOSED.

O 2. HCV-08-1A did not close remotely, Then PERFORM local closure.

REFER TO Appendix I, MSIV Local Closure.

O 3. ENSURE MV08-1A, MSIV Header A Bypass Valve, is CLOSED.

T 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.

0 4. ENSURE HCV-09-1A, Main Feedwater Header A Isolation Valve, is CLOSED.

El 5. ENSURE HCV-09-1B, Main Feedwater Header A Isolation Valve, is CLOSED.

0 6. If BOTH HCV-09-1A and HCV-09-1B, Main Feedwater Isolation Valves to SIC 2A, are NOT CLOSED or suspected of leaking, Then PERFORM ANY of the following AS NECESSARY; U A. ENSURE ALL of the following valves are CLOSED:

C MV-09-5, Stm Gen 2A Reg Block Valve C LCV-9005, 2A 15% Bypass C MV-09-3, 2A 100% Bypass U B. STOP BOTH Main Feedwater Pumps.

O 7. ENSURE FCV-23-3, 2A SC Blowdown, is CLOSED.

54

REVISION NO PROCEDURE TITLE PAGE.

36A APPENDICES I FIGURES / TABLES / DATA IOCEDURE NO SHEETS 91 of 156 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 2 of 6)

Section 1: 2A Steam Generator Isolation (continued)

LI 8. ENSURE FCV-23-4, 2A SG Blowdown, is CLOSED.

LI 9. ENSURE MV-08-18A, 2A S/G Atmos Dump VIv, is CLOSED.

LI 1O.CLOSE MV-08-14, 2A S/G ADV Isol.

O 11.PLACE the control switch for auxiliary feed, Pump 2A, in STOP.

LI 12.ENSURE MV-09-9, Pump 2A Disch to SG 2A Valve, is CLOSED.

[I 13,ENSURE MV-09-11, Pump 2C to SG 2A, is CLOSED.

LI 14.PLACE MV-08-13, SG 2A Stm to AFW PP 2C, in CLOSE.

LI 15.ENSURE MVO8-19A, 2A S/G Atmos Dump Vlv, is CLOSED.

LI 16.CLOSE MV-08-15, 2A SIG ADV Isol.

LI 17.PERFORM the following LOCAL operations:

LI A. UNLOCK and CLOSE V09152, 2C AFW Pump to 2A S/G Isolation.

LI B. UNLOCK and CLOSE V09120, 2A AFW Pump to 2A SIG Isolation.

LI C. CLOSE SE-08-2, Main Steam to 2C AFW Pump Warm-up Valve Solenoid.

LI D. If SE-08-2, Main Steam to 2C AFW Pump Warm-up Valve Solenoid is NOT CLOSED or suspected of leaking, Then CLOSE V08884, SE-08-2 Inlet Isolation.

(continued on next page) 55

OPERATIONS SHIFT TURNOVER REPORT UNIT 2 CONTROL ROOM Day: Today Desk RC. Board RCO:

Erotected Train: A Unit 2 Identified RCS Leakage: 0 Unit 2 Unidentified RCS Leakage: 0 Unit 2 Scheduled Activities per the OSP:

.A Heater Drain Pump has a severe shaft sea! leak and must be removed from service.

Perform down power to remove 2A Heater Drain Pump from service.

Upcoming ECOs to Hang or Release:

2A AFW -- release ECO when work is complete.

Tech Spec Action Statement:

OPS 513s:

None Locked in Annunciators:

G-28 - 2A AFW Pump OVRLD/Trip M .2Ai 2C Charging Pump Suct Press Low/OVRLD/Trip Current Status:

Unit 2 is at 1000/c power, steady state, MOL g.ciuipment Problems:

20 Charging Pump DOS for repack.

2A AFW Pump OOS to repair oil leak. (is expected to be back in service within one hour) 56

Appendix D Scenario Outline Form ES-D-1 Facility: St. Lucie Scenario No.: 5 Op Test No.: HLC-19 NRC Examiners: Operators: SRO:

RO:

SOP:

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 28 SG Event Malf. Event Event No. No. Type* Description 1 R / RD Power increase to approximately 45%.

C 2 1 N / BOP C / RO Loss of 28 Component Cooling Water Pump T.S. SRO 3 2 I / RD Selected Pressurizer Level Channel LT 11 1 OX fails high 4 3 T.S. SRO PORV 1474 Acoustic Monitor fails 5 4 C / GOP Loss of Sups Vital AC Bus lnverter. Stabilize the plant after alternate source has energized the Vital AC bus.

C / RD 6 5 M / All LOOP / Loss of Feedwater 7 6 C / BOP 28 Diesel does not start. 2A Diesel output breaker does not close 8 7 Cl SOP 2C AFW pump trips and MVO9-9 2A AFW pump to 2A SG fails to open 9 8 C / SOP Crosstie 2A AFW pump to feed 2B Steam Generator (N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor

Scenario Event Description NRC Scenario 5 St. Lucle 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 LT 111 OX fails high requiring the RO to swap level channels.

Acoustic monitor for PORV 1474 wIll annunciate and fall 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 crosstle 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 $6 Is being fed by the 2A AFW pump.

Procedures Used

• 2-GOP-201, Reactor Plant Startup Mode 2 to Mode 1

• 2-GOP-I 01, Reactor Operating Guidelines During Steady State and Scheduled Load Changes

• 2-GOP-502, Data Sheets Required for Heatup

• 2-ONP-49.01, SUPS NON Safety Vital AC ISFSI Security or Fire and Security lnverter Malfunction

• 2-031 0030, 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-ONP-09.02, Auxiliary Feedwater

• 2-EOP-09, LOOP Technical Specifications Entered

• 3.7.3 Component Cooling Water System

• 3.3.3.6 Accident Monitoring

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 1 Page 3 of 19 Event

Description:

Power increase to approximately 45%.

Tim_çJ Position j Applicants Actions or Behavior Booth Operator Instructions: Initiate IC #14 30% power. Xenon building in, 6 8pm dilution rate. MOL. 2C Charging Pump OOS for repack. 2B MFW Pump OOS to repair oil cooler.

Indications NOTE: Inform the crew 2-GOP-201 step 6.1.26 has been signed off by RE and power ascension is approved.

Direct power increase lAW 2-GOP-201 step 6.128 (attached SRO page 4)

Directs Placing MSRs in service 300 MW per 2-GOP-502, Data Sheets Required For Heatup, Appendix AA (attached page 5-8) as directed.

Directs Control of Rx power and ASI lAW 2-GOP-lOl Rx Operating Guidelines step 6,1 (attached, page 9-10)

Commences dilution for power increase lAW 2-NOP-02.24 step RO 6.5 (attached page 11-13)

Withdraws CEAs to control Rx power and ASI lAW 2-GOP-lOl Rx Operating Guidelines step 6.1 (attached page 9-10)

. 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-i 01 step 6.i.2.D Category 4. (attached page 9-10)

. Set reference by ensuring REF selected and then BOP depress desired MW endpoint, select ENTER

. Depress LOAD RATE type in desired load rate and select ENTER

. Depress GO pushbutton r

Places MSRs in service 300 MW per 2-GOP-502, Data Sheets Required For Heatup, Appendix AA as directed.

(attached page 5-8) 3

REVISION NO PROCEDURE TITLE PAGE.

60 REACTOR PLANT STARTUP - MODE 2 TO MODE I 51 of 69 PROCEDURE NO 2.GOP-201 ST. LUCIE UNIT 2 5.125 (continued) INITIAL

6. Exhaust Hood temperatures are less than 150°F (TR-22-6B points 3, 7, 8 and 10), Ig:

A. CLOSE V12396, 2A LP Turb Spray Hdr TCV-22-61A Bypass.

B, CLOSE V12403, 2B LP Turb Spray Hdr TCV-22-618 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 Ott Normal.

CHEM 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 ¶ II required, :[n prior to Reactor Power reaching 3O% 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 Feedwaler Discharge Coefficients Verificalion per 2-NOP-102.01 SCE / I&C

3. PERFORM 2-OSP-69.01, Nuclear / Delta T Power Calibration.

4. ENSURE scheduled iricore 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.

NTE The power ascension may continue while the MSRs are being placed in service.

6.128 Turbine load is approximately 300 MW, Then PERFORM Appendix AA of 2-GOP5Q2, Placing MSRs In Service.

4

DATA SHEETS REQUIRED FOR HEATUP ST, LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 1 of4)

INITIAL Date / I DEPRESS the Reset pushbutton on the Reheater Control System VERIFY locally the MSR TCVs are positioned as loIIows:

COMPONENT DESCRIPTION POSITION INITIAL TCV*08-1 MS to 2A MSR CLOSED TCV-O8-7 MS to 2A MSR CLOSED TCV-08-3 MS to 2B M$R CLOSED TCV-OS-9 MS to 2B MSR CLOSED TCV-08-4 MS to 2C MSR CLOSED TCV-08-1O MSto2CMSR CLOSED TCV-08-2 MS to 2D MSR CLOSED TCV.O6S MS to 2D 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.

POSITION the MSR Block Valves as follows:

[ COMPONENT DESCRIPTION POSITION INITIAL]

E MV-08-4 2A Block TCV OPEN MV-08-6 2D Block TCV OPEN MV-08-8 2B Block TCV OPEN MV-08-1O 2C Block TCV OPEN 5

PEVISION NO PROCEOIJRE TITLE PAGE 51A DATA SHEETS REQUIRED FOR HEATUP PROCEDURE NO 125 of 127 2-GOP-502 ST. LUCIE UNIT 2 APPENDIX AA PLACING MSRs IN SERVICE (Page 2 of 4)

INITIAL NOTE Quench water to the MSRs wilt be supplied immediately upon opening the MSR Block Valves.

4. Stn the MSR Block Valves are open, ]jj THROTTLE 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 Isol to 7 gpm V09319 SE-09-1B 2B MSR, Subcooling F[09-4B 5 Dwnstrm Isol to 7 gpm V09328 SE09-1C 2C MSR, Subcooling FI-094C 5 Dwnstrm Isol to 7 gpm V09325 SE-09-1D 2D MSR, Subcooling Fl-094D = S Dwnstrrn sot 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.

lithe wrong pushbutton is depressed, the controller can be reset by depressing the Reset pushbutton Ramp starts a 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> timed opening of TCV*08-7, 8, 9 and 10 (small TCVs). This is lollowed by a 30 minute time delay and then a 10 minute timed opening of TCV-081 2, 3 and 4 (large TCVs). Total time is 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> and 40 minutes until TCV-08-1, 2, 3 and 4 indicate open.

5. L automatic startup is desired. ]j DEPRESS the Ramp pushbutton.

6

REVISON NO IPROCEDURE TIRE PAGE 1

51A DATA SHEETS REQUIRED FOR HEATUP PROCEDURE NO 126o1127 I

2-GOP-502 ST. LUCIE UNIT 2 I 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. j manual startup is desired, 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

7. j the MSR TCVs are OPEN, Ibn PERFORM the following:

A. POSITION the small TCV isolation valves as follows, COMPONENT DESCRIPTION POSITION INITIAL V05381 TCV-06.7 Isol CLOSED V08370 TCV-08-7 Isol CLOSED V08378 TCVO8S Dwnstm Isol CLOSED V08382 TCVOS8 Upstrm Isol CLOSED V08383 TCV-08-9 Isol CLOSED V08372 TCV-06.9 lsol CLOSED V08375 TCV-O81O Isol CLOSED V08384 TCVC61O Isol CLOSED B. ALIGN the MSR vents to the 5A and 5B Feedwater Heaters as follows COMPONENT DESCRIPTION POSITION INITIAL Vi 1446 2A MSR to Extr Sim Isol OPEN Vi 1451 28 MSR To Extr Stm lsol OPEN Viii 17 2C MSR To Extr Strn Isol OPEN Viii 22 2D MSR To Extr Stm Isol OPEN 7

REVISION NO IPROCEOVRE TITLE IPAGE 51A DATASHEETS REQUIRED FOR HEATUP I 127 of 127 PROCEDUENO I 2-GOP-502 ST. LUCIE UNIT 2 I

APPENDIX AA PLACING M$Rs IN SERVICE (Page 4 of 4)

7. (continued) INITIAL C. ALIGN the MSR vents to the Condenser as follows:

[ COMPONENT Vi 1508 I DESCRIPTION 28 Cndsr Vent From 2A MSR Isol POSITION CLOSED INITIAL Vi 1507 2B Cndsr Vent From 28 MSR Isol CLOSED V11520 28 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 1 MV-08-5 Warmup 2A MSR CLOSED

. MV-08-7 Warmup 20 MSR CLOSED MV-08-9 Warmup 28 MSR CLOSED MV-08-1 1 Warmup 2C MSR CLOSED Reviewed by Date / I SRO END OF APPENDIX AA 8

REVi5ON NO PROCEOIJRE TIfl.E PAGE 98 REACTOR OPERATING GUIDELINES DURING STEADY PROCEOURE NO STATE AND SCHEDULED LOAD CHANGES 6 0 f 15 2-GOP-lOl ST. LUCIE UNIT 2 5.0 INSTRUCTIONS 6.1 Power Level Escalat,ons NOTE CEAs should be above the Long-term Steady State Insertion Limit (102 inches withdrawn on Group 5) before reaching 2O% core power and at a position to begin controlling ASI at the ESI between 20% and 50% power Refer to NOP-100.02, 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 I 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-100,02, Axial Shape Index Control, for speciflc instructions regarding ASI control during power escalations.

0. 1i When raising Reactor power, all power escalation rates should be within the totlowing fuel preconditioning guidelines:

Max Core Power Escalation Rate Max Equivalent Turbine Category Generator Load Rate H 3%/HR at or above 15% Power .42 MWIMIN 2 3%/HR above 50% Power .42 MW/MIN 3 20%/HR above 50°/a Power 2.80 MW/MIN 4 30%/HR above 50% Power 4.2 MW/MIN 9

REVISION NO PROCEDURE TITLE PAGE 98 REACTOR OPERATING GUIDELINES DURING STEADY 15 PROCEOURE NO STATE AND SCHEDULED LOAD CHANGES 2-GOP-lOl ST. LUCIE UNIT 2 6.1 Power Level Escalations (continued)

2. 0. (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 ri 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 toss 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. If available, fl 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

REVISION 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).

• If a Reactivity management issue occurs, refer to procedure ADM-09. 11 Reactivity Management.

• If constant dilution is desired then ensure flow on FlC2210X is observable

• Engineering Assessment of FIC-22 lOX PMW Flow, shows that there could be an error up to +/- 0.5 gpm, and the recommended minimum flow rate is 2 gpm

1. U C U C ENSURE Section 3.0, Prerequisites is completed at least once per shift

2. U U U U ENSURE Section 4.0, Precautions I Limitations, has been reviewed at least once per shift

3. U U U U ¶2 ENSURE calorimetric power is less than 100.00% prior to any dilutions by obtaining a DCS calorimetric power.

4. U U U U DETERMINE the desired volume of primary water to be added

. C U U U PLACE the Makeup Mode Selector switch in MANUAL.

6. U U C U ENSURE FIC-2210X, PMW Flow, is in MANUAL REDUCE the controller output to ZERO

7. U U U U ENSURE FIC-2210Y, Boric Acid Flow is in MANUAL and REDUCE the controller output to ZERO.

8. 0 U U U ENSURE either Primary Makeup Water Pump is running.

9. U U U C PLACE FCV-22 lOX, Primary Makeup Water Control Switch in Auto

10. U U U U II diluting to the VCT, fl OPEN V-2512, Reactor Makeup Water Stop VIv.

11. U U U U diluting to the Charging Pump suction, Then OPEN V-2525, Boron Load Control Valve.

11

FVISION NO PROCEDURE TITLE PAGE 24A BORON CONCENTRATION CONTROL 20 of 75 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. C C C C ADJUST FIC-22 lOX PMW Flow in AUTO or MANUAL to desired flowrate (and if using V.2 525 do NOT exceed the flowrate for the number of running Charging Pumps)

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

14. C C C C 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. C C C C ENSURE V2500 VCT Divert Valve indicates OPEN.

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

C. C C C C ENSURE V2500 indicates CLOSED.

15. C C C C When the desired amount of primary water has been added,

]j CLOSE FCV-22 lOX, Primary Makeup Water.

16. C C C C If V-2512 Reactor Makeup Water Stop Vlv was opened, Then PLACE V.2512 in CLOSE and ENSURE it indicates CLOSED 17, C C DC If V-2525 Boron Load Control Valve was opened, Then PLACE V.2525 in CLOSE and ENSURE it indicates CLOSED.

18. C C C C ENSURE FIC-2210X, PMW Flow controller is in MANUAL and RECUCE output to MINIMUM 19, C C C C MONITOR for any abnormal change in Tave.

20. C C C C § 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. C D C C 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 BORON CONCENTRATION CONTROL PROCEDURE NO 21 o!75 2-NOP-02.24 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution (continued) 22, D C C If 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 4 of 19 Event Description; Loss of 2B Component Cooling Water Pump Time [ Position AppHcants 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.

SNPO reports 28 CCW motor outboard bearing is very hot and discolored.

Indications Available: Increasing amps on 2B CCW pump.

Alarms: 5-2: 28 CCW Hdr Flow HighlLow S-32: 2B CCW PUMP OVRLDI TRIP, alarms and will clear after pump trip.

S-26: 2C CCW PUMP HDR VALVESIAB BUS MISALIGNMENT, while aIignin 2C oumo.

SRO/RO/

Recognize loss of 2B CCW pump.

TS Enters TS. 3.7.3. (72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> action to restore 2 CCW pumps, 2

hours to ensure valve lineup commensurate with electrical SRO lineup)

NOTE SRO May elect to hold power increase.

I.

Enters 2-031 0030, Component Cooling Water Off-Normal-Operation (attached pages 1 5-1 7), and directs lineup of 2C

______ CCW pump to replace 28 CCW pump per step 6.2.3.B 1 & 2 Directs swapping of 2AB bus to the B side per step 6.2.3.B.4 thru 2-NOP-52.02, Alignment Of 2A8 Buses And Components,

step 4.1.4AthruC Directs starting the 2C CCW pump per step 6.2.38.5 Directs placing 2B CCW pump to Pull To Lock positions per step 6,2.3.B.7 14

REVISION NO IPROCEDURE TIILE PAGE.

37 I COMPONENT COOLING WATER.

7 of 23 PROCEDURE NO OFF-NORMAL OPERATION 2-0310030 ST. LUCIE UNIT 2 6.2 Subsequent Action (continued)

3. A. (continued)

CAUTION If 2A8 AC and DC Busses are not alt 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 flows return to normal.

7. PLACE the 2A CCW pump control switch to the PULL TO LOCK position.

8. 1! the 480V Load Center 2A8 and DC bus 2A8 are NOT completely aligned to the A side, Ibti REALIGN the 480V Load Center 2A5 and DC bus 2A8 to the A side per 2-NOP.52.02, Alignment of 2A8 Busses and Components.

B. Loss of the 28 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. SOC is in service and CCW is completely lost to an SDC Heat Exchanger, IJ2 SDC flow must be terminated to the affected heat exchanger prior to restoring CCW flow. REFER to ONOP 2-0440030, Shutdown Cooling Off-Normal.

4. j 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-NDP-5202 PRIOR to starting the 2C CCW Pump on lhe 28 CCW Header.

15

REvISION NO PROCEDURE TITLE P.CE.

37 COMPONENT COOLING WATER -

8 of 23 PROCUURE No OFF-NORMAL OPERATION 2.0310030 ST. LUCIE UNIT 2 6,2 Subsequent Action (continued)

3. 8. (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 28 CCW pump control switch in the PULL TO LOCK position.

6. It the 480V Load Center 2AB arid DC bus 2A8 are NOT completely aligned to the B side, Th REALIGN the 480V Load Center 2A3 and DC bus 2A8 to the B side per 2-NOP-52.02, Alignment ot 2AB Busses and Components.

C. Loss of two (2) CCW Pumps CAUTION REFER to off-normal operating procedure 2-ONP-25.01, Loss of RCB Cooling Fans, for appropriate direction

• §i Sufficient Containment Fan Coolers (HVS.1A, HVS-1B, HVS-1C or 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. b if the health and safety of the public is in jeopardy, Ib ATTEMPT ONLY ONE restart.

16

RvSOi *.i PROCEDURE TITLE 12 ALIGNMENT OF 2A8 BUSES AND COMPONENTS 12 of 37 QE)URE ND 2NOP52 02 ST LUCIE UNIT 2 4.1 Transfer of 2A8 Buses and Components from A Side to B Side (continued)

N OTE 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 2A5 to B side, as follows:

A. At RTGB 201. VERIFY the following tie breakers are OPEN:

61cr 1-20501, lAB 4 16KV BUS SB0 TIE 81cr 2-20501, 2AB4 16 Ky 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 2A8/2A3.

(2) OPEN Bkr 2-20208, 416KV BUS TIE 2A3/2A8.

(3) CLOSE 81cr 2-20409, 4 16KV BUS TIE 283/2AB (4) CLOSE 81cr 2-20504, 4.16KV BUS TIE 2AB12B3.

5. ALIGN 460V Load Center 2AB to 8 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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 2 Page 5 of 19 Event

Description:

Loss of 2B Component Cooling Water Pump Time J Position Applicants Actions or Behavior Booth Operator Instructions:

Indications Available:

Examiners Note: Due to the time needed to swap the 2AB 480V and 2AB DC bus, consider moving on with scenario and initiate Event 3. (Typical time for crews to perform the below is 30-40 minutes)

If time permits directs realignment of 2AB 480 VAC Load Center and DC bus 2AB to B side per 2-NOP-52.02, alignment of 2AB SRO Busses and Components, steps 4.1.1 thru 4.1.3, 4.1.5, 4.1 .6 (attached page 1 99)

T.S. 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 <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> SRO action)

RO Monitors primary plant.

BOP 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 pages 15-17)

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 pages 1 9-29)

Starts the 2C CCW pump as directed per step 6.2.3.8.5 Places 28 CCW pump to Pull To Lock position as directed per step 6,2.3.B.7

- If directed realign the 2A0 48OVAC Load Center and DC bus 2AB to B side as directed 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 18

PROCEDURE TITLE PAOE 12 ALIGNMENT OF 2A8 SUSES AND COMPONENTS 7 of 37 FROCEDUR NO 2.NOP-52 02 ST WCIE UNIT 2 4.0 INSTRUCTIONS 4.1 Transfer of 2A8 Buses and Components from A Side to B Side REMOVE the Vital AC SUPS Rectifier from service by performing the following A. At 125V DC Bus 2D, ENSURE Bkr 2-61303, PLANT VITAL AC SUPS, is ON B. At 480V MCC 2A8, ENSURE Bkr 2-42434, CONST.

VOLTAGE TRANSFORMER, is ON.

C. At Vital AC SUPS Irwerter, 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 VITAL/SECURITY/FIRE INVTR TROUBLE (RTGB 201), alarm.

(3) PLACE C83, 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 VOLTS AC FAILURE FAN FAILURE D. At 480V MCC 2AB, PLACE Bkr 2-42433, INVERTER RECTIFIER. ri OFF E. NOTIFY Control Room the Vital AC SUPS rectifier is removed from service F. VERIFY annunciator 8-33, 120 VAC VITAL/SECURITY/FIRE INVTR TROUBLE (RTGB 201), alarm received 19

flFSIONNO PROCEDURE TITLE PAQE PIOJRC NO 12

_J ALIGNMENT OF 2A8 BUSES AND COMPONENTS 8 of 37 2.NOP52 02 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 125V0C 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 AC. SUPS Inverter, PERFORM the foIIowin (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 VITALJSECURITY 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 450V MCC 2AB, PLACE Bkr 2-42415, INVERTER SEC SUPS RECT., in OFF E. NOTIFY Control Room the Fire arid Security SUPS Rectifier is removed from service F. VERIFY annunciator 6-33, 120 VAC VITALJSECURITh FIRE NVTR TROUBLE (RTGB 201), alarm received 20

(VSlON NO PROCEQIJRE TITLE l2 AUGNMENT OF 2AB BUSES AND COMPONENTS 9 of 37 rPQCEOjE NO 2.NOP*52 02 ST LLJCIE 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 28 by performing the foflowing:

A. VERIFY Battery Charger 2A and/or 2-AA is supplying power to 125V DC Buses 2A and 2M B. VERIFY Battery Charger 28 and/or 2-GB is supplying power to 125V DC Buses 28 and 2BB.

C. At 480V MCC 2A8, ENSURE Bkr 2-42413, BATTERY CHARGER 2AB, is positioned to ON.

D. 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 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 acing the DC output breaker to ON.

1 (3) ENSURE 2A8 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 2A8 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 2A8 in the equalize mode by turning the equalizer timer to HOLD.

21

i vSUN O PROCEOURE TITLE PAGE 2

ALIGNMENT OF 2AB BUSES AND COMPONENTS 10 of 37 fii.CLJURE NO 2NOP-52 02 ST LUCIE UNIT 2 4.1 Transfer of 2A8 Buses and Components from A Side to B Side (continued)

3. (continued)

NOTE The following alarms on RTGB 201 may be recewed 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/288 TROUBLE A50, 125V BATT CHGR 2A3 TROUBLE 620. 125V DC BATT CHGR 2N2M 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, TI-lEN PERFORM the following (1) Immediately PLACE Ski 2-60326. CKT #26 (Battery Charger 2AB), in OFF (2) CONTACT US/NWE for further instructions.

G. NOTIFY Control Room that Battery Charger 2AB is powering 125V DC Bus 2AB.

NOTE When performing Section 4.1 Step 3.H, the following annunciators will ALARM:

S-16, EMERG 125VD0/4.16KV/48OVAB BUSES MISALIGNED (RTGB 206)

B-60. EMERG 125V DC/4.1GKVI48OV AS 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 2N2A8.

22

RE viSON NO PROCEDURE TITLE PD,E:

12 ALJGNMENTOF2A8BUSESANDCOMPONENTS 11 0137 PROCEDURE NO 2.NOP52 02 ST. LUCIE UNIT 2 4.1 Transfer of ZAG Buses and Components from A Side to B SIde (continued)

3. H. (continued)

(3) CLOSE Bkr 2-60243. TIE 2B/2A8.

(4) CLOSE Bkr 2-60333. TIE 2A8/28 I. VERIFY the following annunciators are in ALARM S-16, EMERO 125VDC/4.16KV/4SOVAB 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 2A8), 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 8-20, 125V DC BATT CHGR 2A/2M TROUBLE (RTGB-201)- Reflash Panel RA-RAB-11/B-20 (RAB/49/RA2/RAJ) and Reflash Panel RA-RAB-26/B-20 (RA8148/N-RA4IE-RAK)

A-20, 125V DC BATT CHGR 28/288 TROUBLE (RTGB-201) Reflash Panel RA-RAB-10/A-20 (RA8i48/N-RA3/E-RAK) and Reflash Panel RA-RAB-27/A-20 (RAB/48/S-RA3IW-RAK)

A-50, 125V DC BATT CHOR 2A8 TROUBLE (RTGB-201) Reflash Panel RA-RAB-12/A-5Q (RAB/46/N-RA2/E-RAL) 23

ISIUN PROCEDURE TITLE PAGE 2

ALIGNMENT OF 2A6 BUSES AND COMPONENTS 1 3 f 37 QOCFOUiE NO 2NOP52 02 ST LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B Side INITIAL (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 F NOTE 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 2AB12A2.

(2) OPEN Bkr 2-40220, 4&QV BUS TIE 2A2/2A8.

(3) CLOSE Bkr 2-40504. 40V BUS TIE 232/2AB.

(4) CLOSE Bkr 2-40706, 480V BUS TIE 2AB12B2.

6. VERIFY the following annunciators are CLEAR

• 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)

FI NOTE Section 4 1, Steps 7 through 19, may be completed in any order

7. ENSURE N-45. WASTE MANAGEMENT LOCAL ALARM (RTGB-205) is CLEAR by locally acknowledging alarms on Waste Management Panel, it necessary

8. VERIFY annunciators listed in Attachment 2 are CLEAR

9. RESTORE charging pumps to the desired lineup per 2-NOP-02.02, Charging and Letdown 24

REV$IQNNQ PROCEGURE TITLE PAGE:

AUGNMENT OF 2A6 BUSES AND COMPONENTS 14 of 37 ODURE NO 2.NOP52 02 ST LUCIE UNIT 2 4.1 Transfer or 2AB Buses and Components from A Side to B Side tNAL (continued)

10. At RTGB-205, ALIGN 2C CCW Pump to 28 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 SB21 165, 2C ICW PUMP XTlE DISCH To A TRAIN SQL (INTKJ9/N-4/W-C),

IV

8. LOCK OPEN SB21 211, 2C ICW PUMP X-TIE DISCH To 8 TRAIN SQL (INTKJ9/N-4/W-C)

IV C. IF 2C ICW Pump is required to be running, THEN START 2C 1GW Pump per 2-NOP-21 03. Intake Cooling Water System Operation 25

PROCEDURE TITLE PAGE 12 ALIGNMENT OF 2A8 BUSES AND COMPONENTS 15 of 37 P11OCFDU1E NO 2.NOP52 02 ST LUCIE UNIT 2 4,1 Transfer of 2AB Buses and Components from A Side to B SIde INmAL (continued)

12. ALIGN HVNACC-3C, Control Room Area Supply Air Handling Unit.

CCW supply and return headers to the 28 CCW header as follows:

A. LOCK CLOSED V14510, SUPPLY HDR A TO HVNACC.3C CNTL ROOM NC ISOL (RAB17O/S-RA2/W-RAI).

IV B. LOCK CLOSED Vi 4518, HVNACC-3C CNTL ROOM A/C TO RETURN HDR A SQL (RAB/70/S.RA2IE.RAJ).

lv C. LOCK OPEN V14506, SUPPLY HDR B TO HVNACC-3C CNTL ROOM NC SQL (RABI7O/N-RA2/W-RAI)

D. LOCK OPEN V14514, HVNACC-3C CNTL RM NC TO RETURN HOR B SQL (RAB/70/S-RA2/E-RAJ)

IV

13. IF HVAACC-3C is required for operation, THEN START HVNACC-3C per 2-NOP-2507. 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/24124/E-B)

B. Locally START Radiator Fan (TGB/24/241E-8) 26

rvISON NO PROCEDURE TITLE PAGE 12 AUGNMENT OF 2AB BUSES AND COMPONENTS 16 of 37 OCEOURE NO 2-NOP.52 02 ST. LUCIE UNIT 2 4.1 Transfer of 2AB Buses and Components from A Side to B S;de (continued)

NOTE Verification of proper Plant Vent Stack Radiation Monitor operation includes pump restart when power is restored.

Tech Spec 3 3 3.1 5 applicable.

15. VERIFY proper operation of RC26-9O. PLT 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 PC1 1 Radiation Monitor, VERIFY the following parameters on Grid 4 are GREEN (normal):

ML621 AE624 C. If indications are NOT normal, PRESS the FLOW pushbutton on RC-26-90, PLT 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 performing the following A. At 480V MCC 2AB. PLACE Bkr 2-42433, INVERTER RECTIFIER, in ON 27

WE VISION NO PROCEDURE TITLE PQE 2

ALIGNMENT OF 2AB BUSES AND COMPONENTS 17 of 37 prOLOIJRE NO 2.NOP.52 02 ST LIJCIE UNIT 2 4.1 Transfer of ZAB Buses and Components from A Side to B Side (continued)

15. (continued)

B. At Vital AC SUPS Inverter, PERFORM the following:

(1) VERIFY PRE-CHARGE light is ON.

(2) PLACE C33, 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 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 CS 403. AC INPUT, breaker in ON (3) VERIFY INVERTER SUPPLYING LOAD is ON 28

PROCEDURE T!TE PAGE PEisoN NQ 12 ALIGNMENT OF 2AB BUSES AND COMPONENTS 18 of 37 PROCEOUR NO 7.N0P52 02 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 8-33, 120 VAC VITAL/SECURITY/FIRE INVTR TROUBLE, alarm CLEAR (RTGB 201).

21. VERIFY Sewage Lilt 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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 3 Page 6 of 19 Event

Description:

Selected Pressurizer Level Channel LT 11 1 OX fails high Time Position Applicants Actions or Behavior Booth Operator Instructions: When directed by examiner, trigger LT IIIOX fails high Indications Available: Alarms H-17 Pzr Channel X Level HighlLow

_________ LA-5 Pzr Channel X Level High I SRO / RD Recognizes by numerous alarms that Selected Pressurizer Level Channel LT 111OX failed high.

Enters 2-0120035, Pressurizer Pressure And Level. (attached SRO page 31-33)

_______ Directs verify operable RRS channel selected TS/ SRO Enters T.S 3.3.3.6a Accident Monitoring Action A (7 day action)

Directs verifying proper operation of the Letdown system Directs selecting operable PZR Level Channel LT 1 1 1 OY.

Directs restoring Pressurizer Heaters per 2-01 20035 step I 7.2.2G.

RD Verifies proper operation of the letdown system.

Ensures operable channels selected for RRS and PZR level

(attached pages 31-32).

Restores Pressurizer Heaters as directed per 2-0120035 step 7.2.2G. (attached page 33) t---....

L - - --

BOP Monitors balance of plant.

30

REViSION NO PROCEDURE TITLE PAGE 26 PRESSURIZER PRESSURE AND LEVEL 9o115 PROCEDURENO 2-0120035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

1. (continued)

G. It (LOOP) Loss of Offsite Power has occurred with diesel generators supplying power jj pressurizer level is greater than 27%, Then perform the following to regain pressurizer heaters:

1. Manually close the breakers br pressurizer healer on 4160V buses Bkr 2-20204 on 2A3 bus 81cr 2-20403 on 283 bus.

2. Manually reset the backup healer breakers Bi and 84 only (200 kw each).

2. ABNORMAL PRESSURIZER LEVEL 2.

CONDITION NOTE Appendix B contains a listing of pressurizer levels which are associated with automatic actions.

A. Verify selected RRS channel is A. lithe selected RRS channel operating properly has failed, Then shift to the operable channel.

1. NAVIGATE to the SBCS inputs screen on either FW FPD and reset the TAVE signal, ii required B. Ensure backup charging pump starts B. If automatic actions have NOT and letdown flow is decreasing, or occurred, Ifl manually the backup charging pump stops and control charging and letdown letdown flow is increasing, whichever flow as required.

is applicable. (Appendix B contains expected automatic responses 31

REVISION NO PROCEDURE TITLE PAGE 26 PRESSURIZER PRESSURE AND LEVEL PROCEDURE NO lOot 15 2-0120035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTiONS CONTINGENCY ACTIONS

2. (continued) 2. (continued)

C. Verity level anomaly is NOT caused C, Slow the rate of change of by a large rate of change in T-avg. i-avg or stabilize until level anomaly is controlled.

D. Verily Letdown Isol. Valves, 0. II letdown has isolated, Then V-2515, V-2516. and V.2522 are secure charging and refer to open 2-ONP-02.03. Charging and Letdown.

E. Verify selected pressurizer level E. If selected level control valve is control valve (LCV-2110P I NOT operating properly, Then LCV-2110Q) is operating properly. take manual control of level control valve and refer 10 2-ONP-02.03, Charging and Letdown.

F. Verify selected letdown pressure F. If selected pressure control control valve (PCV-2201 P / valve is NOT operating PCV-2201Q) is operating properly. properly, Then take manual control of pressure control valve and refer to 2-ONP-02.03, Charging and Letdown.

32

U)VNL TITLE 26 PRESSURIZER PRESSURE AND LEVEL 11 of 15 EOURE 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 27D/o level on Channel Y, the B pressurIzer heater transformer feeder breaker (2-20403) trips and the A sIde 460V power supplies deenergize. The backup interlock bypass keyswitch selected to the level position, allows the 450V heater power supplies to be reset.

G. Verity pressurizer level indicating G. If pressurizer heaters are controllers (selected and non* deenergized or level indicating selected) are operating properly and controller(s) failed, Then power is available to pressurizer perform the following:

heaters.

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 33

Appendix D Operator Action Form ES-D-2 r__.

Op Test No.: 1 Scenario # 5 Event # 4 Page 7 of 19 Event

Description:

PORV 1474 Acoustic Monitor fails ime] Position J Applicants Actions 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 VI 477 and Close VI 476 and paker) This will allow T.S. 3.3.3.6 to be exited.

SROIROI Recognize that PORV 1474 Acoustic Monitor is in alarm.

Enters 2-0120036, Pressurizer Relief! Safety Valve (attached SRO

, page 35)

. Evaluates T.S. 3,3,3.6, Accident Monitoring Instrumentation (7 TS day action and monitor alt indicators every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, may refer SRO to 2-OSP-1 00.17, Accident Monitoring Instrumentation Monthly

..________ Channel Check, step 7.1.18 (attached page 36-38)

.4-- Directs checking plant parameters to determine if PORV is open by 2-0120036, steps 7.2.1 by checking PORV 1474 Position indicating light, Discharge line temperature and Quench Tank parameters and documenting using Data Sheet 30.

Determines that only the PORV 1474 Acoustic Monitor has failed.

Observes tailpipe temperatures, pressurizer pressure stable, RO and determines PORV 1474 is not open.

Checks as directed plant parameters to determine if PORV is open by 2-01 20036, steps 7.2.1 by checking PORV1 474 RO Position indicating light, Discharge line temperature and Quench Tank parameters. Documents using Data Sheet 30.

BOP Monitors balance of plant.

34

REVISION NO PROCEDURE TITLE pAGE.

14 PRESSURIZER RELIEF I SAFETY VALVE 5 of 8 PROCEDURE NO 2-01 20036 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions

1. None 7.2 Subsequent Operator Actions INSTRUCTIONS CONTINGENCY ACTIONS RELIEF VALVE FAILURE OR 1.

LEAKAGE; A. Determine which PORV is open or A, If it is NOT known which leaking by observing acoustic how PORV is stuck open, Then monitors or PORV position indicating immediately close both block lights, valves (V.1476 and V-1477).

B. If a PORV has failed OPEN, IJan B. !i the relief valve does NOT place the control switch to close and pressurizer pressure OVERRIDE position and verify valve is less than 2300 psia, Then closure by immediately close the applicable block valve (V.1476 or V-1477).

1. Posilion indicating lights.

2. Acoustic flow monitoring

3. Discharge line temperature

4. Quench tank parameters.

35

INSTRUMENTATION ACCI DENT MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.6 The accident monitoring instrumentation channels shown in Table 3.3-10 shall be OPERABLE.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

a.* With the number of OPERABLE accident monitoring channels less than the Required Number of Channels shown in Table 3.3-10, either restore the inoperable channel to OPERABLE status within 7 days, or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

b.* With the number of OPERABLE accident monitoring channels less than the Minimum Channels OPERABLE requirements of Table 3.3-10, either restore the inoperable channels to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

c. With the number of OPERABLE Channels one less than the Total Number of Channels shown in Table 3.3-10, either restore the inoperable channel to OPERABLE status within 7 days if repairs are feasible without shutting down or prepare and submit a Spedal Report to the Commission pursuant to Specification 6.9.2 within 30 days following the event outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.

d.** With the number of OPERABLE Channels less than the Minimum Channels OPERABLE requirements of Table 3.3-10, either restore the inoperable channel(s) to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> if repairs are feasible without shutting down or:

1. Initiate an alternate method of monitoring the reactor vessel inventory; and

2. Prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within 30 days following the event out lining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status, and

3. Restore the Channel to OPERABLE status at the next scheduled refueling.

e. The provisions of Specification 3.0.4 are not applicable.

Action statements do not apply to Reactor Vessel Level Monitoring System, Containment Sump Water Level (narrow range) and Containment Sump Water Level (wide range) instruments.

Action statements apply only to Reactor Vessel Level Monitoring System, Containment Sump Water Level (narrow range) and Containment Sump Water Level (wide range) instruments.

ST. LUCIE - UNIT 2 Amendment No. 4, 45 36

TABLE 3.3-10 ACCIDENT MONITORING INSTRUMENTATION REQUIRED NUMBER MINIMUM CHANNELS INSTRUMENT OF CHANNELS OPERABLE

1. Containment Pressure 2 1

2. Reactor Coolant Outlet Temperature THOt 2 1 (Wide Range)

3.

Reactor Coolant Inlet Temperature TCOId 2 1 (Wide Range)

4.

Reactor Coolant Pressure Wide Range 2 1

5. Pressurizer Water Level 2 1

6. Steam Generator Pressure 2/steam generator 1/steam generator

7. Steam Generator Water Level Narrow Range 1/steam generator 1/steam generator

8. Steam Generator Water Level Wide Range 1/steam generator* 1/steam generator*

9. Refueling Water Storage Tank Water Level 2 1

10. Auxiliary Feedwater Flow Rate (Each pump) 1/pump* 1/pump*

11. Reactor Cooling System Subcooling Margin Monitor 2 1

12. PORV Position/Flow Indicator 2/valve*** 1/valve**

13. PORV Block Valve Position Indicator 1/valve** 1/valve**

14. Safety Valve Position/Flow Indicator 1/valve*** 1/valve***

15. Containment Sump Water Level (Narrow Range) 1 1

16. Containment Water Level (Wide Range) 2 1

17. Incore Thermocouples 4/core quadrant 2/core quadrant

18. Reactor Vessel Level Monitoring System 2***** 1 These corresponding instruments may be substituted for each other.

Not required if the PORV block valve is shut and power is removed from the operator.

If not available, monitor the quench tank pressure, level and temperature, and each safety valve/PORV discharge piping temperature at least once every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

The non-safety grade containment sump water level instrument may be substituted.

Definition of OPERABLE: A channel consists of eight (8) sensors in a probe of which four (4) sensors must be OPERABLE.

ST. LUCIE UNIT 2 3/4 3-42 Amendment No. 3, 4-9, 109

PROCEDuRE TUlLE PAGE RE VISION NO 4 ACCIDENT MONITORING INSTRUMENTATION 11 17 PROCEOURENO MONTHLY CHANNEL CHECK 2.OSP-10017 ST. LUCIE UNIT 2 7.1 (continued) INITIAL

16. Verify PORV block valve position indicators are illuminated and indicale 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 (Fl-Oil, Fl-O1-2, Fl-O1-3, FI-O1-4 & FI-O1-5):

A. No flow indication Red LEDs is illuminated.

B. Power available Red LEDs are illuminated.

7.2 If it has been evaluated thaI an accident monitoring instrument has failed the channel check, iJa 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 EDOS notebook along with the green PWO tags associated with Ihe 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 I is placed in the review file at the beginning of each fuel cycle and a new Table 11$ initiated (transferring all existing EOOS entries to the new Table 1) 7.4 The Accidenl 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.

38

Appendix D Operator Action Form ES-D-2

Op Test No.: 1 Scenario # 5 Event # 5 Page 8 of 19

1 Event

Description:

Loss of Sups Vital AC Bus Inverter. Stabilize the plant after alternate source has energized the Vital AC bus.

[Time Position Applicants Actions or Behavior 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 Indications Available:

Alarms 8-33, 12OVAC Vital! SecuritylFire lnvtr Trouble SRO/RO/ Recognize numerous alarms related to the Vital AC Bus BOP Inverter failure.

Enters 2-ONP-49.01 SUPS- Non Safety Vital AC, ISFSI SRO Security Or Fire And Security Inverter Malfunction.(attached pages 40-41)

Notifies SM Directs SNPO to perform step 6.1.1A

- --4---.

Directs SNPO to perform step 6.3.1 thru 6.3.5 to place the

, Inverter on alternate source.

F-39

PA13E REVISION NO PROCEDURE lIRE IC SUPS NON-SAFETY VITAL AC, ISFSI SECURITY OR 5 of 28 PROCEDURE NO FIRE AND SECURITY INVERTER MALFUNCTION 2-ONP-4901 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS 6.1 SUPS Non-Safely Vital AC, ISFSI Security or Fire and Security Inverter INSTRUCTIONS CONTINGENCY ACTiONS Diagnostic Actions N OTE SUPS Vital AC lnverter power sources are:

Main bed Bkr 2-42433, Invertor Rectifier, MCC 2A3 Bypass feed Bkr 2-42434, Const Voltage Transformer, MCC 2A8 DC feed- Bkr 2-61303. Plant Vital AC SUPS, 125VDC Bus 2D Fire and Security Inverler power sources are:

Main feed Bkr 2-424 15, lriverter Sec SUPS Rect, MCC 2AB

• Bypass feed Bkr 2-4 2508, 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 ii the alternate source is available (In Sync light LIT).

A. DIRECT an operator to CHECK Rehash Module RA-RAB-4 to determine which SUPS is in alarm and the cause (West wall of the Cable Spreading Room)

Inability to gain access to the Cable Spreading Room would indicate the Fire and Security Inverter is affected.

8. If unable to gain entry to the Cable Spreading Room, Then:

1. CONTACT SecurIty to man Control Room arid Cable Spreading Room access.

2. GO TO SectIon 6.4.

40

PROCEDURE TITLE PAGE REVISON NO 4C SUPS NON*SAFETY VITAL AC, ISFSI SECURITY OR 17 of 26 ROCEOuRE NO FIRE AND SECURITY INVERTER MALFUNCTION 2-ONP-49 01 ST. LUCIE UNIT 2 6.3 Loss of Vital AC SUPS Inverter INSTRUCTIONS CONTINGENCY ACTIONS

1. ENSURE alternate source Bkr 2-42434, Consi Voltage Transformer, on MCC 2AB, is CLOSED.

2. ENSURE the following inverler breakers are positioned as indicated:

COMPONENT ID COMPONENT NAME POSITION CB-4 Alternate Source AC Input ON CB-6 2A Vital lnstr. Bus ON CB-7 28 Vital lnstr. Bus ON C8-8 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 nverler 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. II 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 o 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,Q1, 120 V Vital AC Sups (Non-Class 1E) Operation.

END OF SECTION 6,3 41

Appendix D Operator Action Form ES-D-2

• Op Test No: 1 Scenario # 5 Event # 5 Page 9 of 19 Event

Description:

Loss of Sups Vital AC Bus lnveer. Stabilize the plant after alternate source has energized the Vital AC bus.

TuneJ Position Applicant s Actions or Behavior Booth Operator Instructions:

Indications Available:

Examiners Note: On the DCS, both channels for SG Wide Range level and Steam Pressure will be in bypass as indicated by the Yellow overlay. When SUPS lnverter power restored, FW Reg. valves will have to be placed in manual to remove the above from bypass, then, placed back to automatic.

When SUPS inverter placed on bypass, DCS SG Wide Range -

level and Steam Header pressure channels will require restoring from bypass. Directs transfer of MFW from AUTO to SRO MANUAL, reset channels, then place MFW back to AUTO control per 2-NOP-102.01 DCS Operations per step 6.7.4 and 6.9.4 (attached pages 43-46) step Notifies EM per step 6.3.6 Transfers MFW valves from AUTO to MANUAL, then, restores Wide Range level from bypass. Places MFW back to AUTO BOP control per 2-NOP-1 02.01 DCS Operations, per step 6.7.4 as directed. Restores Steam Header pressure from bypass per step_6.9.4_(attached_page_43-46)

- i--. ...-

42

PAGE REVISION NO PROCEDURE TITLE 8A DISTRIBUTED CONTROL SYSTEM (DOS) - 20 1 81 PROCEDURE 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 the WR level digital indicator that reads HOLDING LAST 000D VALUE RESET REQUIRED.

c. The digital and graphical indicators for WR level on the S/G FW IN PUTS 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 Sf0 FW OVERViEW screens indicate POOR (Black & Cyan),

6. RETURN FPD(s) to the default screen of S/3 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 B. NAVIGATE to the Sf0 FW INPUTS screen on the affected FW Train and SELECT the [BYP) Button on the WR level section of the screen C. On the Overlay, SELECT [BYPASS) for the WR level signal (L9012 or L9022)

0. VERIFY the IBYPASSI Button on Ihe 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 6.74.0 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 SIG FW OVERVIEW screen indicate GOOD (Green & White).

43

PROCEDURE TITLE PAGE EVSION NO 8A DISTRIBUTED CONTROL SYSTEM (DCS) 21 of 81 PNOCDURE NO OPERATIONS 2-NOP-102 01 ST. LUCIE UNIT 2 6.7 DCS Input Signal Removal I Restoration FWCS (continued) INITiAL

4. (continued)

NOTE An Info Tag 2A (28) 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 M/A STATION of the affected FW Train in Manual.

2. ENSURE the HIGH POWER M/A STATION of the affected FW Train is in Manual.

G. From the SIG FW INPUTS screen, PERFORM the following.

1. SELECT the IRESET) Button in the WR level section of the screen to bring up the RESET Overlay for the WR level input 2, SELECT IRESETI 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 5/0 FW INPUTS and SIG FW OVERVIEW screens indicate GOOD (Green & White).

H. CLOSE the RESET Overlay.

NOTE The Info Tag 2A (28) FW REG SYS IN MANUAL will be removed after Both

[!A 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 M/A Station of the affected FW Train is in its required mode of control for current plant conditions.

44

jPRQCUUt TILt:

DISTRIBUTED CONTROL SYSTEM (DCS) 22 of 81 OPERATIONS ST LUCIE UNIT 2 OCS Input Signal Removal / Restoration FWCS (continued) INITIAL 6.7

4. (continued)

J. VERIFY Automatic SC level control has been restored to the affected FW Train.

K. RETURN FPD(s) to the default screen of S/C FW OVERVIEW or as directed by the US/SM.

5. BYPASSING a FWCS Feedwater Flow Input signal (A Side:

F9011, F0903A2, F0903A3; 8 Side: F9021, F0903B2, F090383):

CAUTION The Feedwater Flow signals are Critical System Signals when in the High Power Mode of operation (see Appendix C).

112 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 Oveiview 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 Allhough 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 tRESET] (and a return to 3-Element control) can occur.

• SYPAS SING 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/C FW INPUTS screen on the affected FPD and SELECT any ISYP] Sutton on the Feedwater Flow section of the screen.

45

PAGE REVISION NO IPR0cE0U TITLE 8A PROCEDURE NO J DISTRIBUTED CONTROL SYSTEM (DCS)

OPERATIONS

- 59 of 81 2-NOP-102.O1 ST. LUCIE UNIT 2 6.9 DOS Input SHARED Signal Removal / Restoration SBCS + FWCS (continued) INITIAL

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/C INPUTS and SBCS INPUTS screens.

5. CLOSE the Overlay and VERIFY the following:

a. P0802 indicates it has been Removed from BYPASS by its (GYP) 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 46

Appendix D Operator Action Form ES-D-2 Op Test No.: I Scenario # 5 Event # 6, 7 Page 10 of 19 Event

Description:

LOOP / Loss of Feedwater, 2B Diesel does not start. 2A Diesel output breaker does not close.

Time Position I Applicants Actions or Behavior rBooth Operator Instructions: When directed by examiner, trigger LOOP I Loss of Feedwater, 2B EDG should not auto start and 2A output breaker does not close.

Indications Available:

When SNPO called by Control Room Local 2B EDG alarms in are:

6-1: 2B EDG TRIPILOCKOUT 6-2: START DC FAILUREI SS ISOL If asked, one minute later state, lockout unable to be resetS If requested, SNPO reports breaker 60221 has not tripped.

SRO/ROI Multiple alarms, recognize Reactor /Turbine trip BOP Directs implementation of 2-EOP-O1, Standard Post Trip Actions as follows:

• RO: Reactivity control, Inventory Control, Pressure SRO control, Core Heat Removal

. BOP: Vital Auxiliaries, RCS heat removal, Containment Conditions.(2B EDG does not auto start)

H----

J Recognizes that the 2B EDG did not start and that 2B EDG has alarm A-26, 2B Emerg D/G Lockout/SS Isol.

Critical Recognizes that 2A EDG breaker did not close.

Task Directs BOP to close the 2A EDG breaker.

SRO Recognizes that the 2B EDG did not start and that 2B EDG has BOP L. -.

alarm A-26, 2B Emerg DIG LockoutlSS lsol.

Critical Recognizes that 2A EDG breaker did not close.

Task Close the 2A EDG breaker when directed.

BOP 47

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 6, 7 Page 11 of 19 Event Description. LOOP I Loss of Feedwater, 28 Diesel does not start. 2A Diesel output

breaker does not close.

i Time - Posion L Applicant s Actions or Behavior Booth Operator Instructions:

Indications Available:

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

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° F Core Heat Removal

. Verify at least one RCP running with CCW. (LOOP, no RCPs running)

Verify loop delta T is <10° F J

• Verifies turbine trip on reactor trip. Performs EOP-01 Safety functions as directed for: Vital Auxiliaries, RCS Heat Removal, Containment Conditions.

BOP 48

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 6, 7 Page 12 of 19 Event

Description:

LOOP I Loss of Feedwater, 26 Diesel does not start. 2A Diesel output breaker does not close.

Time] Position ] Applicant s Actions or Behavior Booth Operator Instructions:

Indications Available:

Ensures MSR Warmup Valves are CLOSED. Calls NPO to BOP manually_close_due_to_loss_of_power.

Notifies NPO to perform Appendix X section 1 of EOP-99.

I.

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.

49

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 8, 9 Page 13 of 19 j 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 TirneL Position Applicant s Actions or Behavior Booth Operator Instructions: Trigger Restore Instrument Air when contacted by Control Room Indications Available:

SRO Performs Diagnostic Flow Chart Exits EOP-01 to EOP-09, LOOP (attached pages 51-55)

Directs STA SFSCs for EOP-09 performed every 15 minutes.

Directs Appendix A of EOP-99, to Sample Steam Generators. (attached page 56-57). Directs HP to perform secondary surveys.

Directs Ensure EDG Loading

-_________ Directs Appendix H of EOP-99, Restore Instrument Air Examiners Note: If Instrument air is restored after 30 minutes with RCP CCW valves in auto, the COW valves will re-open, which is in violation of above step.

Ensure RCP Seal; Cooling Examiners note: If not completed within 30 minutes of loss of CCW, ensure CCW NOT restored to RCPs.

Directs RCS depressurized to 1800 to 1850 psia using auxiliary sprays. (key 76 and 77 to operate SE-02-3 and SE-02-4)

Directs closing of MSIVs Directs closing of S/C blowdown and sample valves 50

REVISION NO.: PROCEDURE TITLE: PAGE:

15 LOSS OF OFFSITE POWER/LOSS OF FORCED 6of27 PROCEDURENO.: CIRCULATION 2-EOP-09 ST. LUCIE UNIT 2 4O OPERATOR ACTIONS INSTRUCTIONS CONTINGENCY ACTIONS NOTE

• Instruments should be channel checked when one or more confirmatory indications are available.

• Steps designated with an

• may be performed non-sequentially or are to be performed continuously.

Eli. Confirm Diagnosis VERIFY LOOP/LOFC Safety 1.1 REDIAGNOSE the event using Function Status Check acceptance 2-EOP-O1 Chart 1, Diagnostic criteria are satisfied every Flow Chart, 15 minutes. and GO TO ONE of the following:

The appropriate Optimal Recovery Procedure 2-EOP-15, Functional Recovery Ei2. Classify Event EVALUATE EPIP Classification criteria for present plant conditions and Emergency Plan Actions.

REFER TO EPIP-Ol Classification of Emergencies.

[13. Implement Placekeeping OPEN the Placekeeper jjç. NOTE the time of EOP entry.

[14. Sample Steam Generators Sample S/Gs.

REFER TO Appendix A, Sampling Steam Generators.

51

REVISION NO.: PROCEDURE TITLE: PAGE:

15 LOSS OF OFFSITE POWER/LOSS OF FORCED of 27 PROCEDURE NO.: CIRCULATION 2-EOP-09 ST. LUCIE UNIT 2 4.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS Ensure EDG Loading If a LOOP has occurred, Then ENSURE the following for EACH Vital 4.16 KV Bus:

A. EDG has STARTED. A.1 Locally START the EDG.

REFER TO Appendix C, Diesel B. EDG Output Breaker is CLOSED. Generator Local Start.

C. LOOP Loads are ENERGIZED. C.1 Manually ALIGN EDG loads, REF ER TO Table 8, Emerg. Diesel Generator Loading (LOOP).

El 6. Restore Instrument Air If a LOOP has occurred, Then PERFORM BOTH of the following:

A. ENSURE 2AB 480V Load Center is aligned to an energized bus.

B. DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 2B Instrument Air Compressors.

52

REVISION NO.: PROCEDURE TITLE: PAGE:

15 LOSS OF OFFSITE POWER/LOSS OF FORCED 8o f 27 PROCEDURENO.: CIRCULATION 2-EOP-09 ST. LUCIE UNIT 2 4.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

7. Ensure RCP Seal Cooling A. VERIFY CCW to the RCPs. A.1 an SIAS or CIAS has isolated CCW to the RCPs, Then RESTORE CCW.

REFER TO Appendix J, Restoration of CCW and CBO to the RCPs.

A.2 If CCW is lost for greater than 30 minutes, Then PERFORM BOTH of the following:

A. ENSURE CCW to the RCPs will remain isolated by PLACING the FOUR Containment CCW To/From RC Pump valves to CLOSE.

B. ENSURE RCP controlled bleedoff will remain isolated by PLACING the TWO RCP Bleedoff valves to CLOSE.

B. BOTH of the following conditions exist,

• RCPs have CCW flow

• CIAS has isolated the normal RCP bleedoff flowpath to the VCT Then ESTABLISH the alternate RCP bleedoff flowpath to the Quench Tank by OPENING V2507, RCP Bleedoff Relief Stop Vlv.

53

REVISION NO.: PROCEDURE TITLE: PAGE:

15 LOSS OF OFFSITE POWER/LOSS OF FORCED 9 of 27 PROCEDURE NO.: CIRCULATION 2-EOP-09 ST. LUCIE UNIT 2 4.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE Annunciator R-8 SIAS Channel NB Actuation Block Permissive, alarms at a setpoint of 1836 psia.

8. Depressurize the RCS A. COMMENCE depressurizing the RCS to between 1800 and 1850 psia.

B. MAINTAIN pressurizer level between 10 and 68%.

9. Protect Main Condenser A. If a LOOP has occurred, Then PERFORM BOTH of the following to protect the Secondary Plant:

1. ENSUREMSIVsare CLOSED.

2. ENSURE SGBD is ISOLATED.

B. STABILIZE the Secondary Plant.

REFER TO Appendix X, Secondary Plant Post Trip Actions, Section 2.

10. Stabilize RCS Temperature 10.1 j RCS TCOLD is greater than 535°F, Then VERIFY MSSVs are ENSURE RCS TCOLD is less than controlling RCS temperature.

535°F and controlled by operation of ANY of the following: 10.2 If ADVs are unavailable, Then use alternate steaming

• SBCS paths.

REFER TO Table 12, Alternate

• ADVs S/G Heat Removal Paths.

54

REVISION NO.: PROCEDURE TITLE: PAGE:

15 LOSS OF OFFSITE POWER/LOSS OF FORCED 10 f 27 PROCEDURE NO.: CIRCULATION 2-EOP-09 ST. LUCIE UNIT 2 4.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS El ii. EnsureSIGLeveI6Oto7O%NR ENSURE at least ONE S/G has level being maintained or restored to between 60 and 70% NR.

12. VerifyPzrLevel 12.1 OPERATE charging pumps and letdown as necessary to restore VERIFY Pressurizer level meets level.

BOTH of the following conditions:

A. Within 10 to 68%.

B. Trending to between 30 to 35%.

El 13. Maintain RCS Within Figure IA Lim its 13.1 lIthe RCS is over-subcooled, or RCS pressure exceeds the upper limits of Figure 1A, RCS MAINTAIN the RCS less than the Pressure Temperature, upper limits of Figure 1A, RCS Then RESTORE subcooling or Pressure Temperature, by performing pressure to within the appropriate ANY of the following: limit:

A. OPERATE Auxiliary Pressurizer A. STABILIZE RCS sprays. temperature.

B. OPERATE Pressurizer heaters. B. DEPRESSURIZE the RCS using Auxiliary Pressurizer spray.

55

REVISION NO.: PROCEDURE TITLE: PAGE:

36A APPENDICES / FIGURES I TABLES I DATA of 156 PROCEDURE NO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 1 of 2)

A Train (q) B Train (I)

C 1. If a LOOP has occurred, Then PERFORM BOTH of the following:

U A. ENSURE 2AB 480V Load Center is aligned to an energized bus.

U B. DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 2B Instrument Air Compressors.

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-14-1O) 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 U 2. If 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-14-6A

• HCV-14-9 OR

• HCV-14-8B

• HCV14-1O 56

REVISION NO.: PROCEDURE TITLE: PAGE:

36A APPENDICES I FIGURES I TABLES / DATA of 156 PROCEDURE NO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 2 of 2)

D 3. 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.

4. DIRECT Chemistry to perform S/G samples for activity and boron.

5. S/Gs cannot be sampled, Then DIRECT Health Physics to conduct secondary plant local area radiation surveys.

END OF APPENDIX A 57

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario 1* 5 Event # 8, 9 Page 14 of 19 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 Time Position Applicant s Actions or Behavior Booth Operator Instructions: When contacted by Control Room perform 2-ON P.

09.02, Auxiliary Feedwater Appendix C steps IA thru IH as directed.

Indications Available: Alarm: G-46, 2C AFW PUMP TURBINE FAILURE/Trip/OVRLD/SS ISOL SRO Directs Stabilize RCS Temperature.

Directs Ensure S/G Level 60 to 70%

If AFAS NOT actuated, direct AFW restored by manual starting of pumps and opening of valves lAW 2-NOP-09.02 (attached page 59-67)

If Appendix H, Restore Instrument Air not completed within 30 RO minutes of loss of CCW, ensures CCW is NOT restored to RCPs.

RCS depressurized to 1800 to 1850 psia using auxiliary sprays as directed.

Stabilizes RCS Temperature as directed.

Ensures SIG Level 60 to 70% as directed Informs NPO to perform Appendix H, 2-EOP-99 restore BOP Instrument Air, as directed Resets Instrument Air Compressors when notified by NPO Aligns and initiates AFW flow to 2A and 2B SG lAW 2-NOP-09.02 (attached page 59-67) 58

REVISION NO PROCEDURE TITLE PAGE 2A AUXILIARY FEEDWATER SYSTEM OPERATION 7 of 34 PROCEDURE NO 2NOP-09,02 ST. LUCIE UNIT 2 4.0 INSTRUCTIONS INITIAL 4.1 2A AFW PUMP to 2A SIC

1. STARTPUMP2A.

2. OPEN SE-09-2, 2A PUMP DISCH TO 2A S/C 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 SC 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/C VLV, is CLOSED.

D. STOP PUMP 2A.

E. RETURN PUMP 2A switch to AUTO.

IV Performed By:

PnntlSign Initials Date Verified By:

Print/Sign Initials Date 59

RI VISION NO PROCEDURE TITLE PAGE 2A AUXILIARY FEEDWATER SYSTEM OPERATION 8 Of 34 POCE)JRE NO 2-NOP-09 02 ST. LUCIE UNIT 2 4,2 28 AFW PUMP to 28 SIG INITIAL I. STARTPUMP2B.

2. OPEN SE-09-3, 28 PUMP DISCH TO 28 Sf0 VLV. (KEY 84)

3. THROTTLE MV-09-1D, PUMP 2B DISCH TO SO 2B VALVE, as necessary to establish and maintain desired AFW flow to 28 5/0.

4. WHEN desired level is achieved AND the 2B AFW PUMP is no longer needed, THEN PERFORM the following:

A. CLOSE MV-0910, PUMP 28 DISCH TO SG 2B VALVE.

8. PLACE key switch for SE-09-3, 28 PUMP DISCH TO 2B S/C VLV, to AUTO.

IV C. VERIFY SE-O93, 28 PUMP DISCH TO 2B Sf0 VLV, is CLOSED.

0. STOP PUMP 2B.

E. RETURN PUMP 28 switch to AUTO.

IV Performed By:

PnnliSign Initials Date Verified By:

PrinllSign Initials Date 60

RE VISION NO PROCEDURE TITLE PAGE 2A AUXILIARY FEEDWATER SYSTEM OPERATION 9 f 34 PROCEDURE NO 2-NOP-09 02 ST. LUCIE UNIT 2 4.3 2C AFW PUMP to 2A I 28 SIG INITIAL NOTE If the 20 AFW PUMP has tripped, 2-ONP-09.02, Auxiliary Feedwater, provides instructions for restarting.

CAUTION When steam is isolated from the 20 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, 20 PUMP, by placing the key switch on RTGB 202 in the CLOSE position, (KEY 78)

B. OPEN MV-08-12, SG 28 STM TO AFW PP 20.

C. OPEN MV-OS-i 3, SG 2A STM TO AFW PP 2C.

D. AFTER 5 minutes, CLOSE MV-08-i2, SG 28 STM TO AFW PP 20.

E. CLOSE MV-08-13, SG 2A STM TO AFW PP 20.

F. OPEN MV-08-3, 20 PUMP, by placing the key switch on RTGB-202 in the OPEN position.

IV

2. IF the 20 AFW PUMP turbine is rotating, THEN PERFORM the following A. UNLOCK AND CLOSE V08884, SE-08-2 INLET ISOL.

B. WHEN the 20 AFW PUMP stops rotating, THEN SLOWLY OPEN V08884, SE-O8-2 INLET SO.

C. IF the 20 AFW PUMP does NOT STOP rotating, THEN PERFORM Section 5.4.2.

61

PROCEDURE TITLE PAGE:

REVISIDN NO 2A AUXILIARY FEEDWATER SYSTEM OPERATION 10 of 34 PROCEDURE NO 2.NOP-09.02 ST. LUCIE UNIT 2 4.3 2C AFW PUMP to 2A I 28 Sf0 (continued) INITIAL 2, (continued)

0. LOCK OPEN V08884, SE-082 INLET ISOL.

N OTE 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 QOS.

4. ENSURE the governor oil level is visible between the level mark and top of sighiglass.

62

.VSION NO PROCEDURE TITLE PAGE.

2A AUXILIARY FEEDWATER SYSTEM OPERATION 11 or 34 INC,CEOJRE NO 2*NOP09.02 ST. LUCIE UNIT 2 4,3 2C AFW PUMP to 2A 1 28 SIC (continued) INITIAL CAUTION If the oil in the 20 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 20 AFW PUMP Turbine is NOT rotating.

A, VERIFY 3 minutes have passed since pump rotation stopped.

OR

8. CYCLE the manual speed control knob on the side of the governor fully counter-clockwise, then fully clockwise.

6. START 20 AFW PUMP by performing the following:

• OPEN MV-08-12, SG 26 STM TO AFW PP 2C.

AND I OR

• OPEN MV-OS-i 3, SG 2A STM TO AFW PP 20.

7. VERIFY turbine speed is stable between 3700 and 3800 rpm AND the governor valve is NOT hunting I oscillating.

8. OPEN the solenoid valve(s) in the header(s) to the S/Gs requiring feed:

• SE-09-4, 20 PUMP DISCH TO 2A SIG VLV (KEY 85)

• SE-09-5, 2C PUMP DISCH TO 2B SIC VLV (KEY 86)

9. THROTTLE MV-09-11, PUMP 20 TO SC 2A, as necessary to establish and maintain desired flow to 2A S/C.

10. THROTTLE MV-09-12, PUMP 20 TO SC 26, as necessary to establish and maintain desired flow to 28 S/C.

63

RI \SIDS1 NO PROCEDURE TITLE PAGE:

2A AUXILIARY FEEDWATER SYSTEM OPERATION 12 of 34 I ROCE DUNE 2NDP09 02 ST. LUCIE UNIT 2 4.3 2C AFW PUMP to 2A I 28 SIG (continued) INITIAL

11. WHEN the 20 AFW PUMP is no longer being used for feed and it is desired to secure, THEN PERFORM the following:

A. ENSURE MV-09-1 1, PUMP 20 TO SC 2A, is CLOSED.

B. ENSURE MV-09-12, PUMP 20 TO SC 2B, is CLOSED.

C. PLACE key switch for SE-09-4, 2C PUMP DISCH TO 2A S/C VLV, to AUTO IV D. VERIFY SE-09-4, 20 PUMP DISCH TO 2A SIC VLV, s CLOSED.

E. PLACE key switch for SE-09-5, 2C PUMP DISCH TO 2B S/C VLV, to AUTO.

F. VERIFY SEO9-5, 2C PUMP DISCH TO 28 S/C VLV, is CLOSED.

C, 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 20 AFW PUMP TURBINE CONTROL PANEL.

Locally STOP the 2C AFW PUMP by tripping the mechanical overspeed trip lever.

H. VERIFY 20 AFW PUMP turbine is slowing by observing reduction of speed on 20 AFW PUMP TURBINE CONTROL PANEL.

64

R[VSION NO PROCEDURE TITLE 2A AUXILIARY FEEDWATER SYSTEM OPERATION 13 of 34 i4IDCDURE NO 2-NOP-09.02 ST. LUCIE UNIT 2 INITIAL 4.3 2C AFW PUMP to 2A I 2B SIG (continued)

11. (continued)

NOTE An electrical overspeed trip results in closed indication for MV-08-3, and alarm and reset for annunciator 0-46.

A mechanical overspeed trip results in closed indication for MV-08-3, and locked in alarm for Annunciator 0-46.

Closing MV-08-3 alone will result in closed indication for MV-08-3 with no alarm for Annunciator 0-46.

I. IF applicable, THEN VERIFY annunciator 0-46, 2C AFW PUMP TURBINE FAILURE I 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.

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 2B STM TO AFW PP 2C, is CLOSED.

65

PROCEDURE TITLE PAGE cEVSON NO 2A AUXILIARY FEEDWATER SYSTEM OPERATION 14 of 34 PROCEDUI* NO 2-NOP-09.02 ST. LUCIE UNIT 2 4.3 2C AFW PUMP to 2A / 28 SIG (continued) NIT1AL

11. (continued)

N. ENSURE MV-08-13, SG 2A STM TO AFW PP 2C, is CLOSED.

0. 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 RTGB2O2 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 SQL.

(3) IF the 2C AFW PUMP does NOT stop rotating, THEN PERFORM Section 5.4.2.

(4) LOCK OPEN V08884, SE-03-2 INLET SQL.

IV

12. ENSURE MV-08-12, SG 2B STM TO AFW PP 20, switch is in AUTO position.

IV 66

RFVISION NO PROCEDURE flTLE PAGE 2A AUXILIARY FEEDWATER SYSTEM OPERATION 15 or 34 PRQCED)RE NO 2*NOP-09 02 ST. LUCIE UNIT 2 4.3 2C AFW PUMP to 2A 1 2B SIG (continued) INITIAL

13. ENSURE MV-08-13, SG 2A STM TO AFW PP 2C, switch is in AUTO position.

Iv Performed By:

PrinUSign Initials Dale Verified By:

Print/Sign Initials Dale 67

Appendix D Operator Action Form ES-D-2 Op Test No: 1 Scenario # 5 Event # 8, 9 Page 15 of 19 j

Event

Description:

20 AFW pump trips and MV-09-9 2A AFW pump to 2A SC fails to open, Crosstie 2A AFW pump to feed 2B Steam Generator Timej Position Applicant s Actions or Behavior Booth Operator Instructions: 2C AFW overspeed trip linkage will not reset. MV 09-9 manual operator will not engage allowing opening the valve.

Indications Available:

SOP Closes the MSI Vs as directed.

Closes the S/G blowdown and sample valves as directed.

Performs EOP-99 Appendix X section 2 (attached page 69-72) as directed Recognizes 20 AFW pump trips when started. 2B AFW pump discharge valve solenoid fails to open. -

.-t- --.

.L___

68

REVISION NO. IPROCEDURE TITLE: PAGE:

36A I APPENDICES / FIGURES I TABLES / DATA ll5of 156 PROCEDURE NO. SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 5 of 8)

Section 2: CONTROL ROOM ACTIONS INSTRUCTIONS CONTINGENCY ACTIONS U 1. ENSURE ONLY ONE MFW Pump is -

RUNNING, with the control switch in RECIRC.

U 2. ENSURE ONLY ONE Condensate Pump is RUNNING.

U 3. If AFAS has actuated, U 3.1 If AFAS has NOT actuated and use of Main Feedwater is and use of Main Feedwater is desired, desired, Then PERFORM ALL of the Then PERFORM ALL of the following: V following:

U A. ENSURE AFAS is RESET. U A. ENSURE BOTH SIG [Main FRV] Block valves CLOSED.

U B. ENSURE BOTH S/G [Main U B. For EACH MFW header to FRV] Block valves CLOSED. be placed in service, ENSURE the associated MFIVs are OPEN.

1. MV-09--5

2. MV-O96 U C. ENSURE BOTH Low Power U C. ENSURE BOTH Low Power M/A Stations in MANUAL, M/A Stations in MANUAL.

U D. For EACH MFW header to be U 0. DEPRESS BOTH placed in service, ENSURE pushbuttons to RESET the the associated MFIVs are Low Power Feedwater OPEN. Valves.

U E. DEPRESS BOTH pushbuttons U E. ADJUST the Low Power M/A to RESET the Low Power Stations AS NECESSARY to Feedwater Valves, control S/G levels.

69

REVISION NO. PROCEDURE TITLE: PAGE:

36A APPENDICES I FIGURES / TABLES / DATA 116 of 156 PROCEDURE NO SHEETS 2EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 6 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

3. (continued)

U F. ADJUST the Low Power M/A Stations AS NECESSARY to control S/G levels.

U G. RESTORE AFW to the standby alignment.

U 4. ENSURE BOTH Heater Drain Pumps are STOPPED, O 5. ENSURE BOTH of the following:

U A. Bearing Oil Pump U A.1 ENSURE Emergency Bearing Oil Seal Oil Backup Pump Pump RUNNING.

RUNNING.

U B. When the turbine reaches 600 rpm, Ifl Bearing Oil Lift Pump RUNNING.

U 6. ENSURE the Turbine Drain Valves are OPEN.

U 7. ENSURE ONLY ONE Turbine Cooling Water Pump is RUNNING.

U 8. VERIFY Turbine Generator Bearing U 8.1 DIRECT a field operator to adjust Oil temperature between 110 to TCW to the in-service TLO Cooler 120°F, to maintain outlet Oil temperature between 110 to 120°F.

70

REVISION NO PROCEDURE TITLE: PAGE:

36A APPENDICES / FIGURES I TABLES / DATA 117 of 156 PROCEDURE NO SHEETS 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 0 9. When Turbine speed reaches ZERO O 9.1 PERFORM ALL of the following:

rpm, Then VERIFY the turning gear automatically ENGAGES.

Li A. PLACE Turning Gear in MANUAL.

O 8. VERIFY the Turning Gear Permissive Light is ON.

O C. Locally ENSURE the Turning Gear is ENGAGED.

Li D. Locally START the Turning Gear.

Li 1O.lf Reactor power history is low, CONSIDER reducing steam generator blowdown flow to maintain RCS temperature.

Li 11.Place Boron Dilution Alarm 0 11.1 If BOTH Boron Dilution Alarm System in Operation. System channels are NOT operating When indicated Reactor power is Then PERFORM applicable less than 1O%, actions of ONP-02.O1 Boron Then PERFORM BOTH of the Concentration Control.

following:

Li A. ENERGIZE BOTH channels of Startup Nuclear Instrumentation to place the Boron Dilution Alarm System in operation.

Li B. VERIFY BOTH Boron Dilution Alarm System Channels are operating.

71

REVISION NO PROCEDURE TITLE: PAGE:

36A I APPENDICES / FIGURES / TABLES I DATA 118 of 156 PROCEDURE NO SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX X SECONDARY POST TRIP ACTIONS (Page 8 of 8)

Section 2: CONTROL ROOM ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE Excessive moisture can build up in CEDMCs room, and impact equipment reliability if 15 KW heaters are not ener9ized after plant shutdown.

0 11.NOTIFY SNPO to energize 15 KW heater located in the CEDMCs room to minimize humidity build-up per 2-NOP-25.1O, 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 72

Appendix D Operator Action Form ES-D-2 Op Test No 1 Scenario # 5 Event # 8,9 Page 16 ol 19 Event

Description:

20 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 i Position JL Applicant s Actions or Behavior Booth Operator lnstructions:

Indications Available: No AFW flow available Re diagnose using diagnostic flow chart and exit to EOP-06 SRO Total Loss of Feedwater Direct STA perform SFSCs for EOP-06 performed every 1 5 minutes.

Direct HP to perform secondary surveys if not already

-. rmed._____

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 COW, ensure COW NOT restored to ROPs if not already performed.

NOTE:

When AB Bus is swapped in App-H AFW flow indication on RTGB will be restored.

Direct closing of S/G blowdown and sample valves if not already performed.

Direct closing of MSIVs if not already performed.

Direct EOP-99 Appendix X section 2 if not already performed.

73

Appendix D Operator Action Form ES-D-2 Op Test No 1 Scenario 5 Event # 8, 9 Page 17 of 19 E,en!

Description:

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 TiinePosition Applicants Actions or Behavior Booth Operator Instructions:

Indications Available:

SRO Critical Direct Replenishing S/G Inventory by using 2-ONP-0902, Auxiliary Feedwater Appendix C steps 1A thru 1H (attached pages Task 76-77) if not already performed.

___BOP_- Performs as directed SFSCs for EOP-06 every 1 5 minutes.:

RCS depressurized to 1600 to 1850 psia using auxiliary sprays RO

- SE-02-3 and SE-0204, as directed if not already performed.

If Appendix H, Restore Instrument Air not completed within 30 minutes of loss of COW, ensures COW is NOT restored to RCPs.

Contacts NPO to perform local steps in Appendix H, restore BOP Instrument Air, of EOP-99 if not already performed.

.-L Resets Instrument Air Compressors when notified by NPO if not already performed.

Closes the MSIVs as directed if not already performed, 74

Appendix D Operator Action Form ES-D2 Op Test No S 1 Scenario # 5 Event # 8, 9 Page 18 of 19 Event

Description:

20 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]LPosIon_J Applicant s Actions or Behavior Booth Operator Instructions: When directed by NPO (after appropriate time delay),

trigger MV-09-13 and 14 open, and throttle MV-09-1O as directed.

Indications Available:

. Closes the S/G blowdown and sample valves as directed if not already performed.

I Performs EOP-99 Appendix X section 2 as directed if not already performed.

• BOP Critical Replenishes SIG Inventory by using 2-ON P-09,02, Auxiliary Feedwater Appendix C steps 1A thru 1H as directed. Contacts Task NPO to perform steps (attached pages 76-77)

NOTE: When NPO locally opens MV-09-1O this may cause an AFAS-1 lockout so 1-SE-09-2 will need to be opened.

H Suggested termination point:

. 2A Diesel output breaker has been closed and

• 28 SIG is being fed by the 2A AFW pump, 75

REVSON NO PROCEDURE TITi.E PAGE 11 AUXILIARY FEEDWATER 19 Of 29 POCUURE NO 2-ONP-09.02 ST. LUCIE UNIT 2 APPENDIX C CROSS-CONNECTING AFW (Page 1 of 4)

INITIAL NOTE II cross-tying AFW in Modes 1 3, Then the motor driven pump not being Used to supply SOs must be declared out-of-service per the applicable Tech. Spec.

If 2A AFW Pump is to feed 28 S/G, Then PERFORM the following:

A. ENSURE MV-09-1O, Pump 28 Disch To S/G 2B Valve, is CLOSED.

B, START Auxiliary Feedwater Pump 2A.

C. OPEN SE.09-2, 2A Pump Disch To 2A S/C Vlv Key 83.

CAUTION Opening both MV.09-13 and MV-09-14 while in Modes 1, 2, 3 could make Iwo independent AFW flow path inoperable.

NOTE Key-switches for MV-09-13 and MV-0914 are located in 2N28 AFW Pump Room Two keys are required since the keys are removable in CLOSE D. Locally OPEN MV-09-13, 2A To 28 AFW Hdr Cross-tie.

NPO E. Locally OPEN MV-09-l4, 2B To 2A AFW Hdr Cross-tie.

NPO CAUTION Ensure total pump flow does not exceed 425 gpm.

F. THROTTLE MV-09-1O, Pump 28 Disch To SG 28 Valve, to establish desired flow rate.

NOTE While feeding both SIGs indicated flow is pump flow to both S/Os.

G. To feed the 2A S/C, THROTTLE MV-09-9, Pump 2A Disch To SC 2A Valve, to establish desired flow rate.

76

iEvSION O PROCEDURE TITI.E PAGE 11 AUXILIARY FEEDWATER PROCEDURE NO 20 of 29 2-ONP-09.02 ST. LUCIE UNIT 2 APPENDIX C CROSS-CONNECTING AFW (Page 2 of 4)

(continued) INITIAL H. the system is to be returned to normal, Then PERFORM the following:

1. CLOSE MV-09-10, Pump 28 Disch To SG 28 Valve.

2. 2A SIG is being fed, Then CLOSE MV-09-9, Pump 2A Disch To SO 2A Valve.

3. STOP Auxiliary Feedwater Pump 2A.

4, CLOSE SE-09-2, 2A Pump Disch To 2A SIG 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 IIV INITIAL MV-09-9. Pump 2A Disch To SG 2A Valve CLOSED MV-09-10. Pump 28 Disch To SC 28 Valve CLOSED SE-092, 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. 28 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 SOs must be declared out-of-service per the applicable Tech. Spec.

2. 28 AFW Pump is to feed 2A S/C, ]j PERFORM the following A. ENSURE MV-09-9, Pump 2A Disch to 2A S/C Valve, is CLOSED.

8. START Auxiliary Feedwater Pump 28 C. OPEN SE-09-3, 23 Pump Disch To 23 S/C Vlv Key 84.

77

OPERATIONS SHIFT TURNOVER REPORT UNIT 2 CONTROL ROOM Day: Today Desk RCO: Board RCO:

Protected Train: A Unit 2 Identified RCS Leakage: 0 Unit 2 Unidentified RCS Leakage: .03 Unit 2 Scheduled Activities per the OSP:

2B MFW pump OOS for cooler replacement, Not expected back this shift. .2C Charging pump out for repack Chemistry limits have been cleared to perform an up power within the capacity of the operating Main Feedwater pump.

Upcoming ECOs to Hang or Release:

None.

Tech Spec Action Statement:

None.

OPS 513s:

None Locked in Annunciators:

P-38, 2A/2B MEW Pump Disch MV-09-1/2 OVLD M-48, 2C Charging Pump SS (sol V2553 OVLD G-1 1, 2B FW Pump Trouble Current Status:

29% power, MOL, 6gpm dilution, Chemistry limits checked OK to raise power per step 6.126 of 2-GOP-201.

Longstanding Problems: -

None.

78

Appendix D Scenario Outline Form ES-D-1 Facility: St. Lucie Scenario No: 8 Op Test No.: NRC HLC-19A Examiners: Operators: SRO:

RO:

BOP:

Initial Conditions: 2-3 % power, BOC. 2C Charging pump COS for repack.

Turnover: 2-3% power. 8CC, 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. Directions for the shift: Raise power and place the Turbine on line.

Critical Tasks:

• Manually Initiate MSIS

• Start2AHPSlpump Event Malf. Event Event No. No. Type* Description 1

R/RO Performuppowertolo%

2 1 T.S. SRO CIS RM RIS-26-4-2 (B Channel) falls high. Bypass ESFAS bistable 3 2 C I RO Individual CEA does not move out with group 4 3 C I RO 2A2-2A3 Spurious Opening resulting momentary doenergizatlon of CIBOP 2A34.l6KVbus T.S. i SRO MCC 2A8 Fails to energize after bus re-energized 5 4 C I BOP CCW 8 header rupture. HCV-14-1O falls to close 6 5 C I ALL SGTL 2B Steam Generator 6 6 M I All SGTR 2B Steam Generator 7 7 M I All 2A Steam Generator MSSV opens. Closes at 500 psia 8 8 C / RO Failure of MSIS requires manual actuation 9 9 C / BOP On SIAS 2A HPSI pump falls to start 10 C I BOP Isolate the 2A SG per Appdx R (N)ormal, (R)eactivity, (l)nstrurnent, (C)omponent, (M)ajor I-

Scenario Event Description NRC Scenario 8 St. Lucle UnIt 2 The crew assumes the shift at 2-3% power. The 2C Charging pump is out of service to replace shaft seals. The crew will be instructed to raise power and place the unit on line.

Shortly after turnover, CIS RM-26-4-2 fails high. This is a T.S. SRO call and the channel must be bypassed lAW 2-ONP-99.01.

As the RO is withdrawing CEAs one CEA In the group will not move. I/C should be notified to investigate.

The individual CEA movement issue will be resolved and that CEA will be realigned with its group. If the CEA movement issue is not noticed prior to misaligned greater than 7 inches this should be a T.S. call.

A spurious opening of the 2A2-2A3 Tie Breaker will cause the 2A3 4.16KV bus to de-energize. As designed, the bus will be de-onergtzed for about 10 seconds and then the 2A Diesel Generator closes onto the bus. The spurious opening of the tie breaker will be resolved and the breaker will be manipulated to parallel with the gild. When the 2A3 bus is tied back to the grid, the 2A Diesel Generator will be shut down. When 2A3 bus Is reenergized, MCC 2A8 will fail to energize (not required for scenario). This will require a Tech Spec call by the SRO. MCC 2A8 can be re-energized after the Tech Spec call. Pressurizer heaters, charging and letdown will have to be restored. Additional manipulations of the SBVS, CR ventilation and SBCS DCS input will also have to be manipulated (not necessary to continue).

CCW header B will rupture causing the surge tank to lower. The N header should Isolate, however HCV 14-10 falls to close. The Operator should recognize this and manually close HCV-14-10. CCW can then be restored to the RCPs via the A header.

A SGTL occurs on the 2B Steam Generator followed by a SGTR. This will require a Reactor shutdown.

When the unit is tripped a Main Steam Safety valve on the 2A Steam Generator opens and fails to close until 500 psia steam pressure on the generator. MSIS fails to actuate at 700 psia and must be manually actuated. The crew should exit EOP-01 to EOP-15 due to a dual event (ESD and SGTR). NOTE:

Operations management written guidelines state if a MSSV falls to reseat when designed the Steam Generator Is considered faulted until the MSSV is gagged.

Upon SIAS the 2A HPSI pump fails to start. It can be manually started. This is a critical step due to the rupture of the B CCW header, the 2B HPSI pump is considered inoperable.

The exercise can be terminated when the 2A Steam Generator is isolated. A cool down is in progress using the 26 Steam Generator.

Procedures used

• 2-GOP-201, Reactor Plant Startup Mode 2 to Mode 1

• 2-NOP-25.07, Control Room Ventilation System

• 2-ONP-25.02, Ventilation Systems

• 2-ONP-99.01, Loss of Technical Specification Instrumentation

• 2-0120035, Pressurizer Pressure and Level

• 2-0110030, CEA Off-Normal Operation and Realignment

• 2-0310030, Component Cooling WaterOff- Normal Operation

• 2-ONP-47.01. Loss of A Safety Related AC Bus

• 2-ONP-02.03, Charging and Letdown

• 2-ONP-26.02, Area Radiation Monitors

• 2-0830030, Steam Generator Tube Leak

• 2-EOP-01, Standard Post Trip Actions

• 2-EOP-1 5, Functional Recovery

Scenario Event Description NRC Scenario 8 Technical Specifications entered

• 3.3.2 ESFAS Table 3.3-3

• 3.8.3.1 Onsite Power Distribution 3

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 1 Page 4 of 22 1 9A Event

Description:

Raise Reactor power Time J Position Applicants Actions or Behavior 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.

Direct power increase to 10-12% lAW 2-GOP-201 step 6.10 in SRO preparation to roll the Turbine. (attached pages 5-8) 2-GOP-201 step 6.11, When Reactor is in Mode 1 direct maximize SG blowdown lAW 2-NOP-23.02 Steam Generator Blowdown System Operations, (attached pages 9-10)

Direct CEA Group 5 withdrawn to raise Reactor power (may direct dilution)

If directed commence Dilution for power increase lAW 2-NOP-RO 02.24 step 6.5.12, 13, 14 (attached pages 11-12)

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

NOTE: Power should be raised initially by CEAs. CEAs should be withdrawn to at least 102 prior to 20% power to meet LTSSIL BOP Monitor SBCS for proper operation during power increase.

When directed call Unit I to determine SG blowdown flow rate.

Adjust SC blowdown to no more than 100 gpm per SG. lAW 2-NOP-23.02 Steam Generator Blowdown System Operations step 6.5.1.C (2A SG). Step 6,5.2.C (28 SC) (attached pages 9-10) 4

REVISION NO.: PROCEDURE TITLE: PAGE:

60 REACTOR PLANT STARTUP MODE 2 TO MODE 1 25 f 69 PROCEDURE NO.:

2-GOP-201 ST. LUCIE UNIT 2 6.8 (continued) INITIAL

2. P. (continued)

6. Using the Single Down Arrow, CONTINUOUSLY and FULLY CLOSE LCV-9006, 28 15% BYPASS Valve while VERIFYING FCV-9021 SG 2B FEED REG Valve OPENING 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 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%.

5

REVISION NO.: PROCEDURE TITLE: PAGE:

60 REACTOR PLANT STARTUP MODE 2 TO MODE 1 26 of 69 PROCEDURE NO.:

2-GOP-201 ST. LUCIE UNIT 2 INITIAL 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.

SRO Date I Time /

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

SRO 6.14 ENSURE that Steam Generators are being maintained between 60%

and 70% narrow range level.

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

SRO 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.

Switchman

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

Switchman 6

REVISION NO.: PROCEDURE TITLE: PAGE:

60 REACTOR PLANT STARTUP MODE 2 TO MODE 1 27 0 f 69 PROCEDURE NO.:

2-GOP-201 ST. LUCIE UNIT 2 IflAL NOTE The following indicating lights are located inside the lower cubicle, south side, center panel of the Excitation Switchgear.

6.17 ENSURE the excitation switchgear power supply is properly aligned to the 2C DC Bus as follows:

1. VERIFY the Normal Available light is LIT.

2. it the Normal Available light is NOT LIT, Then ENSURE bkr 2-60601 Ckt#1 on the 125V DC Bus Power Panel 2C is ON.

3. VERIFY the Emergency Available light is LIT.

4. if the Emergency Available light is NOT LIT, Then ENSURE bkr 2-61310 Ckt#10 on the 125V DC bus 2D is ON.

5. VERIFY the Load Connected to Normal light is LIT.

6. j.f the Load Connected to Normal light is NOT LIT and the Load Connected To Emergency light is LIT, Then HOLD the Reset toggle switch to the RESET position.

7. When the Load Connected To Normal light LIGHTS and the Load Connected to Emergency light is NO longer LIT, Then RELEASE the Reset toggle switch.

6.18 ENSURE alarms in the voltage regulator cubicle are acknowledged and reset.

6.19 ENSURE the Hydrogen Control Panel is in service as follows:

1. ENSURE bkr2-60201 Ckt#1 on the 125V DC Bus Power Panel 2B is ON.

2. ENSURE all unexplained alarms are reset.

3. ENSURE the Purity Meter Blower switch located in the lower back half of the Hydrogen Control Panel is On.

6.20 ENSURE one Isophase Bus Cooling Fan is in operation.

7

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EVIS ION NO.: PROCEDURE TITLE: PAGE:

13C STEAM GENERATOR BLOWDOWN SYSTEM 1 9 of 3 PROCEDURE NO.: OPERATION 2-NOP-23.02 ST. LUCIE UNIT 2 5.5 Adjusting Steam Generator Blowdown Flow CHECK NOTE

• If the respective Steam Generator Pressure Control Valve is Bypassed or in Manual, monitor and adjust as required.

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

2. PERFORM the following to adjust 26 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.

9

REVISION NO.: PROCEDURE TITLE: PAGE; 13C STEAM GENERATOR BLOWDOWN SYSTEM 20 o f 39 PROCEDURE NO.: OPERATION 2-NOP-23.02 ST. LUCIE UNIT 2 6.5 Adjusting Steam Generator Blowdown Flow (continued) CHECK

2. (continued)

D. If FCV-23-14 is in MANUAL, SLOWLY depress the raise /

lower pushbuttons on FIC-23-14 to obtain the desired flow.

E. 1! FCV-23-14 is bypassed, Then THROTTLE V23 149, FCV-23-14 Bypass, as necessary to adjust flow.

END OF SECTION 6.5 10

REVISION NO.: PROCEDURE TITLE: PAGE:

24A BORON CONCENTRATION CONTROL 19 of 75 PROCEDURE NO.:

2-NOP-02.24 ST. LUCIE UNIT 2 6.5 Aligning for MANUAL Dilution NOTE

• An Operator Aid has been placed at RTGB-205 PNL RN. 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. C C C C ENSURE Section 3.0, Prerequisites is completed at least once per shift,

2. C C C C ENSURE Section 4.0, Precautions I Limitations, has been reviewed at least once per shift.

3. CC CC ¶2 ENSURE calorimetric power is less than 100.00% prior to any dilutions by obtaining a DCS calorimetric power.

4. C C C C DETERMINE the desired volume of primary water to be added.

5. C C C C PLACE the Makeup Mode Selector switch in MANUAL.

6. C C C C ENSURE FIC-2210X, PMW Flow, is in MANUAL and REDUCE the controller output to ZERO.

7. C C C C ENSURE FIC-2210Y, Boric Acid Flow is in MANUAL and REDUCE the controller output to ZERO.

8. C C C C ENSURE either Primary Makeup Water Pump is running.

9. C C C C PLACE FCV-2210X, Primary Makeup Water Control Switch in Auto.

10. CC C C ft diluting to the VCT, Then OPEN V-2512, Reactor Makeup Water Stop VIv.

11. C C CC ft diluting to the Charging Pump suction, Then OPEN V-2525, Boron Load Control Valve.

11

REVISION NO.: PROCEDURE TITLE: PAGE:.

24A BORON CONCENTRATION CONTROL 20 f 75 PROCEDURE NO.:

2-NOP-02.24 ST. LUCIE UNIT 2 6.5 Alignng 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. D D D D 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 V251 3, 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. 00 00 ENSURE V2500 VCT Divert Valve indicates OPEN.

B. 00 0 0 When the desired VCT level is reached, PLACE V2500 in AUTO.

C. 000 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. 0 0 0 0 If V2512 Reactor Makeup Water Stop Vlv was opened, Then PLACE V-2512 in CLOSE ENSURE it indicates CLOSED.

17. 0 0 0 0 If V-2525 Boron Load Control Valve was opened, Then PLACE V-2525 in CLOSE 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 § 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 II 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

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 1 Page 5 of 22 19A Event

Description:

Raise Reactor power Time Position I Applicants Actions or Behavior Booth Operator Instructions:

If 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 PCVs are in auto.

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

If directed depress RESET pushbutton on Reheat Control BOP Panel. Step 6.21.1. Notify NPO to verify locally TCVs closed.

When Reactor power reaches 5%, make plant announcement BOP/RO Reactor is in Mode 1 13

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 2 Page 6 of 22 1 9A Event

Description:

CIS RM RIS-26-4-2 (8 Channel) fails high Time I Position I Applicants Actions or Behavior Booth Operator Instructions:

. When in Mode I trigger E2-CIS RM RIS-26-4-2 fails high.

Control Room Indications:

. Channel B Containment Radition instrument failed high

. Annunciator o P.5 CNTMT Rad High CIS Channel Trip o P.15 CNTMT Rad High CIS Channel Pre Trip o Q-2 Engineered Safeguards ATI Fault

. Containment evacuation alarm Direct actions lAW 2-ONP-99.O, Loss of Tech Spec SRO Instrumentation section 6.3.2.D. Refer to TS 3.3.2 (Table 3.3-3)

T.S.

(attached pages 15-19) Action 13 and 14 May enter 2-ONP-26.02, Area Radiation Monitors (including Appendix A), to verify validity of the alarm. (attached pages 20-22)

Notifies shift manager of event.

RO Recognize Channel B ESFAS CIS rad monitor failed high Verify PC-I 1 channel indications and that only one channel is in alarm.

GOP Make plant announcement to disregard Cont. Evac alarm When directed Bypass ESFAS channel MB instrument RIS 4-2 14

REVtSION NO.: PAGE:

21 LOSS OF TECH SPEC INSTRUMENTATION 16 of 37 PROCEDURE NO.:

2-ONP-99.01 ST. LUCIE UNIT 2 6.3 ESFAS Channel Malfunction (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

2. (continued) 2. (continued)

NOTE

• Containment radiation monitors are covered by Tech Spec 3.3.2, Table 3.3-3.

• ESFAS cabinet door key, key 114, is required for bypassing ESFAS.

D. Containment radiation D.1 PERFORM ONE of the following:

instrumentation indication:

• RIS-26-3-2 (MA) 1. BYPASS the CIS channel affected by the failed radiation

• RIS-26-4-2 (MB) monitor using key 130.

• RlS-26-52 (MC) OR

• RIS-26-6-2 (MD) 2. PLACE the affected ESFAS trip unit in TRIP in accordance with Appendix A, Placing Trip Units in Trip 15

INSTRUMENTATION 314.3.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2 The Engineered Safety Features Actuation System (ESFAS) instrumentation channels arid bypasses shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3-4.

APPLICABILITY: As shown in Table 3.3-3.

ACTION:

a. With an ESFAS instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3-4, declare the channel inoperable and apply the applicable ACTION requirement of Table 3.3-3 until the channel is restored to OPERABLE status with the trip setpoint adjusted consistent with the Trip Setpoint value.

b. With an ESFAS instrumentation channel inoperable, take the ACTION shown in Table 3.3-3.

SURVEILLANCE REQUIREMENTS 4.3.2.1 Each ESFAS instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations during the MODES and at the frequencies shown in Table 4.3-2.

4.3.2.2 The logic for the bypasses shall be demonstrated OPERABLE during the at power CHANNEL FUNCTIONAL TEST of channels affected by bypass operation.

The total bypass function shall be demonstrated OPERABLE at least once per 18 months during CHANNEL CALIBRATION testing of each channel affected by bypass operation.

4.3.2.3 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS function shall be demonstrated to be within the limit at least once per 18 months.

Each test shall include at least one channel per function such that all channels are tested at least once every N times 18 months where N is the total number of redundant channels in a specific ESFAS function as shown in the Total No.

of Channels column of Table 3.3-3.

ST. LUCIE - UNIT 2 3/4 3-11 Amendment No. 67 16

TABLE 3.3-3 (Continued)

TABLE NOTATION (a) Trip function may be bypassed in this MODE when pressurizer pressure is less than 1836 psia; bypass shall be automatically removed when pressurizer pressure is greater than or equal to 1836 psia.

(b) An SIAS signal is first necessary to enable CSAS logic.

(c) Trip function may be bypassed in this MODE below 700 psia; bypass shall be automatically removed at or above 700 psia.

The provisions of Specification 3.0.4 are not applicable.

ACTION OF STATEMENTS ACTION 12 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

ACTION 13 - With the number of channels OPERABLE one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may continue provided the inoperable channel is placed in the bypassed or tripped condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. The channel shall be returned to OPERABLE status no later than during the next COLD SHUTDOWN.

With a channel process measurement circuit that affects multiple functional units inoperable or in test, bypass or trip all associated functional units as listed below.

Process Measurement Circuit Functional Unit Bypassed

1. Containment Pressure - Containment Pressure High (SIAS, CIAS, CSAS)

Containment Pressure High (RPS)

2. Steam Generator Pressure - Steam Generator Pressure Low (MSIS)

AFAS-1 and AFAS-2 (AFAS)

Thermal Margin/Low Pressure (RPS)

Steam Generator Pressure Low (RPS)

3. Steam Generator Level - Steam Generator Level Low (RPS)

If SG-2A, then AFAS-1 (AFAS)

If SG-2B, then AFAS-2 (AFAS)

4. Pressurizer Pressure - Pressurizer Pressure High (RPS)

Pressurizer Pressure Low (SIAS)

Thermal Margin/Low Pressure (RPS)

ST. LUCIE - UNIT 2 3/4 3-15 Amendment No. 28, 3, 149 17

TABLE 3.3-3 (ContInued)

TABLE NOTATION ACTION 14 - With the number of channels OPERABLE one less than the Minimum Channels OPERABLE, STARTUP and/or POWER OPERATION may continue provided the following conditions are satisfied:

a. Verify that one of the inoperable channels has been bypassed and place the other inoperable channel in the tripped condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

b. All functional units affected by the bypassed/tripped channel shall also be placed in the bypassed/tripped condition as listed below.

Process Measurement Circuit Functional Unit BypassedlTripped

1. Containment Pressure - Containment Pressure High (SIAS, CIAS, CSAS)

Containment Pressure High (RPS)

2. Steam Generator Pressure - Steam Generator Pressure Low (MSIS)

AFAS-1 and AFAS-2 (AFAS)

Thermal Margin/Low Pressure (RPS)

Steam Generator Pressure Low (RPS)

3. Steam Generator Level -. Steam Generator Level Low (RPS)

If SG-2A, then AFAS-1 (AFAS)

If SG-2B, then AFAS-2 (AFAS)

4. Pressurizer Pressure - Pressurizer Pressure High (RPS)

Pressurizer Pressure Low (SIAS)

Thermal Margin/Low Pressure (RPS)

ACTION 15 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channels to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

ACTION 16 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or declare the associated valve inoperable and take the ACTION required by Specification 3.7.1.5.

ACTION 17 - With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or place the inoperable channel in the tripped condition and verify that the Minimum Channels OPERABLE requirement is demonstrated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />; one additional channel may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing per Specification 4.3.2.1.

ST. LUCIE UNIT 2

- 3/4 3-16 Amendment No. 28, 73 18

TABLE 3.3-3 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE OF CHANNELS TO TRIP OPERABLE MODES ACTION FUNCTIONAL UNIT SAFETY INJECTION (SIAS) 2 1 2 1,2,3,4 12

a. Manual (Trip Buttons) 2 3 1,2,3 13*14

b. Containment Pressure 4 High 2 3 1,2,3(a) 13*, 14

c. Pressurizer Pressure 4 Low 2 1 2 1,2,3,4 12 ci. Automatic Actuation Logic

2. CONTAINMENT SPRAY (CSAS) 2 1 2 1,2,3,4 12

a. Manual (Trip Buttons) 3 1(b), 2(b), 3(b) 18a*, 18b*, 18c

b. Containment Pressure 4 2 (0

High-High 2 1 2 1,2,3,4 12

c. Automatic Actuation Logic

3. CONTAINMENT ISOLATION (CIAS) 2 1 2 1,2,3,4 12

a. Manual CIAS (Trip Buttons)

b. Safety Injection (SIAS) See Functional Unit 1 for all Safety Injection Initiating Functions and Requirements 3 1,2,3 13*,14

c. Containment Pressure 4 2 High 3 1,2,3 13*,14

d. Containment Radiation 4 2 High 2 1 2 1,2,3,4 12

e. Automatic Actuation Logic

- UNIT 2 314 3-12 Amendment No. 132 ST. LUCIE

REVISION NO.: PROCEDURE TITLE: PAGE:

6 AREA RADIATION MONITORS 4 0 f 18 PROCEDURE NO.:

2-ON P-26.02 ST. LUCIE UNJT 2 4.0 OPERATOR ACTIONS 4.1 Containment Isolation Radiation Monitors INSTRUCTIONS CONTINGENCY ACTIONS NOTE If a containment evacuation alarm sounds with personnel inside containment, the Radiation Protection Manager or on-site designee must approve re-entry into the containment.

1. If a containment evacuation alarm has actuated and personnel are in the containment, Then:

A. ANNOUNCE over the Gaitronics for all personnel to leave their work in a safe condition and evacuate the containment.

B. NOTIFY HP to commence an evaluation of the containment radiological conditions.

C. CONTACT Security to perform personnel accountability for the evacuation.

D. ANNOUNCE over Gaitronics restoration of containment access when advised by Radiation Protection Manager that radiological conditions are safe for return to work.

20

EVISION NO.: PROCEDURE TITLE: PAGE:

6 AREA RADIATION MONITORS 5 of 18 PROCEDURE NO.:

2-ONP-26.02 ST. LUCIE UNIT 2 4.1 Containment Isolation Radiation Monitors (continued)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE A Containment Isolation signal is generated when at least two of the following monitors exceed the HIGH alarm setpoint:

RC-26-3 I RC-26-4 I RC-26-5 I RC-26-6

2. DETERMINE alarm validity: 2.1 II the alarm is NOT valid, Then GO TO Appendix A, Inoperable A. VERIFY PC-li channel display Monitor.

for the affected channel is NOT blue (indicating system or 2.2 If PC-i I Driver hang alarm equipment failure) magenta appears refer to Appendix C.

(indicating PC-I 1 communications failure).

B. VERIFY PC-il channel indication agrees with indication on the Control Room monitor for the affected channel (i.e., alert or high alarm):

• RC-26-3, CIS

• RC-26-4, CIS

• RC-26-5, CIS

• RC-26-6, CIS C. VERIFY increased or increasing trend for the affected channel:

• RR-26-3, CIS

• RR-26-4, CIS

• RR-26-5, CIS

• RR-26-6, CIS D. it only one CIS monitor is alarmed, Then CHECK the other CIS monitors for increasing radiation level trends.

21

REVISION NO.: PROCEDURE TITLE: PAGE:

6 AREA RADIATION MONITORS 15 of 18 PROCEDURE NO.:

2-ONP-26.02 ST. LUCIE UNIT 2 APPENDIX A INOPERABLE MONITOR (Page 1 of 1)

INITIAL

1. § NOTIFY Health Physics to PERFORM surveys of the affected area as required (if accessible).

2. CHECK local operation of the affected area as required (if accessible).

3; j. required, Then NOTIFY l&C to check the affected Monitor.

4. if monitor is inoperable, Then PERFORM the following:

A. REFER to 2-NOP-26.01, Radiation Monitors, for operating instructions.

B. INITIATE a NPWO in accordance with ADM-1 0.02, Plant Work Request / Order Origination. Identify on Work Request if Monitor is in continuous alarm.

C. NOTIFY Health Physics to perform surveys of the affected area in accordance with HPP-4, Scheduling of Health Physics Activities.

D. j.f the inoperable monitor is any of the following:

• Fuel Storage Pool Area

• Containment Isolation (CIS)

• Control Room Isolation

• Containment Area (High Range)

Then REFER TO Technical Specification 3.3.3.1, Radiation Monitoring, for required actions.

END OF APPENDIX A 22

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 3 Page 7 of 22 1 9A Event

Description:

CEA does not move with group Time Position L Apphcants Actions or Behavior Booth Operator Instructions:

• Trigger CEA #57 fails to withdraw.(soon after passing through 7% power)

When I/C called wait 5 minutes and report the ACTM card toggle switch has been reset and recommend attempt to move CEA Control Room Indications: Deviation will be first picked up on CEA Display Monitor

• Annunciators: K-Il CEA Motion Inhibit (if not picked up before 4)

K-SO CEA Position DeviatIon Motion Block (ADS)

EXAMINERS NOTE: RO should recognize CEA failure prior to CEA deviation alarm.

RO Recognize CEA #57 failure to move with group Place CEDMCS panel in OFF Implement 2-0110030, CEA Off-Normal Operation and Realignment. If CEA misaligned >7 inches direct SRO implementation of Appendix C, Appendix A, and/or Appendix H to realign. (attached pages 25-34)

Informs Shift Manager & Reactor Engineering If CEA misaligned by >7 inches implement T,S, 3.1.3.1 Realign to within 7 inches of CEAs within group within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Appendix C.

Directs I/C to trouble shoot lAW Appendix A of 2-0110030, CEA Off-Normal Operation and Realignment.

When called by I/C on request to move CEA #57 direct RO to perform Appendix A 2-0110030, CEA Off-Normal Operation and Realignment.

23

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 3 Page 8 of 22 1 9A Event

Description:

CEA does not move with group Time Position Applicants Actions or Behavior Booth Operator Instructions: When directed trigger step to allow CEA to move.

When I/C called wait 5 minutes and report the ACTM card toggle switch has been reset and recommend attempt to move CEA When Appendix A complete, direct realignment lAW Appendix SRO H

RO When directed perform Appendix C (attached pages 28-29)

When directed perform Appendix A (attached pages 30-32)

When directed to realign perform Appendix H (attached pages 33-34) 24

REVISION NO.: PROCEDURE TITLE: PAGE:

57A CEA OFF-NORMAL OPERATION AND 6 of 33 PROCEDURE NO.: REALIGNMENT 2-0110030 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions:

INSTRUCTIONS CONTINGENCY ACTIONS

1. Place CEDMCS panel in OFF.

2. II continuous CEA withdrawal is indicated, while CEDMCS panel is OFF, Then trip the reactor and turbine and carry out 2-EOP-01, Standard Post Trip Actions.

3. jf a mismatch between reactor power and turbine power (T-avg and T-ref) exists, Then adjust turbine power to equal reactor power.

NOTE If two CEAs are misaligned, with one misaligned greater than or equal to 15 inches and the other misaligned greater than 7.0 inches, then actions of two CEAs misaligned from any other CEA in its group by greater than or equal to 15 inches would apply.

4. If 2 or more CEA5 are misaligned from any other CEA in their group by greater than 15 inches and I or dropped, while in Mode 1 or 2, Then manually trip the reactor and turbine and carry out 2-EOP-01, Standard Post Trip Actions.

25

REVISION NO.: PROCEDURE TITLE: PAGE:

57A CEA OFF-NORMAL OPERATION AND of 33 PROCEDURE NO.: REALIGNMENT 2-0110030 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions:

INSTRUCTIONS CONTINGENCY ACTIONS NOTE This Procedure may contain steps that could adversely affect reactivity.

ENSURE that proper consideration and appropriate briefings occur prior to performance of steps that could challenge reactivity.

1. If continuous CEA insertion is indicated, while the CEDMCS panel is OFF, Then locally open the disconnect for the affected CEA(s) at the CEDM coil power supply panels in the cable spreading room.

2. Notify Reactor Engineering, Operations Supervisor and Operations Manager of time of CEA misalignment.

NOT required if in Mode 3.

• If unable to reach the Operations Manager, NOTIFY the Plant General Manager or any of his direct reports.

3. Refer to the appropriate appendix listed below and apply the instructions as required.

26

REVISION NO.: PROCEDURE TITLE: PAGE:

57A CEA OFF-NORMAL OPERATION AND 8 of 33 PROCEDURE NO.: REALIGNMENT 2-0110030 ST. LUCIEUNIT2 7.2 Subsequent Operator Actions: (continued)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE

• Guidance for realigning misaligned CEAs during performance of Preop 3200091, Reload Startup Physics Testing is provided in Appendix I of Preop 3200091, Reload Startup Physics Testing.

• CEAs on the hold bus will still de-energize on a reactor trip.

• Respond to all CEA alarms by use of the appropriate appendix in this procedure.

• More than one appendix may be required.

• If two CEAs are misaligned, with one misaligned greater than or equal to 15 inches and the other misahgned greater than 7.0 inches, the actions of Appendix E will apply.

CEA MALFUNCTION APPENDIX CEA investigation for operability A One or more CEAs inoperable B One or more CEAs misaligned greater than 7 inches but less than or equal to C 15 inches.

One CEA misaligned greater than 15 inches. D Two CEAs dropped or misaligned greater than 15 inches. E One dropped CEA F CEA position indication malfunction G CEA realignment (Modes 1, 2 and 3) H Realignment of one dropped CEA (Mode 1)

Hi gripper voltage alarm J CEDMCS Trouble Alarm K

4. If conditions require a unit shutdown (per Tech Spec), Then implement the E-Plan as required.

27

REVISION NO.: PROCEDURE TITLE: PAGE:

57A CEA OFF-NORMAL OPERATION AND 14 of 33 PROCEDURE NO.: REALIGNMENT 2-0110030 ST. LUCIE UNIT 2 APPENDIX C ONE OR MORE CEA(S) MISALIGNED FROM ANY OTHER CEA IN ITS GROUP BY GREATER THAN 7 INCHES BUT LESS THAN OR EQUAL TO 15 INCHES (Page 1 of 2)

NOTE Refer to T.S. 3.1.3.1.f

1. Ensure the following:

A. CEDMCS panel in OFF.

B. Turbine power adjusted to equal reactor power.

C. CEA motion inhibit.

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

3. 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.

4. CEA(s) determined to be inoperable due to excessive friction or mechanical interference, refer to Appendix B and continue with the steps of this appendix as applicable.

NOTE If this procedure is employed while in Mode 3, the one hour time restriction does NOT apply.

5. §i II CEA(s) are operable, Then realign the CEA(s) within one hour from the initial misalignment in accordance with Appendix H.

6. §i If CEA inoperable:

A. Within one hour from the initial misalignment, realign the remainder of operable CEA5 in the group within 7 inches of inoperable CEA while maintaining the allowable CEA sequence and insertion limits shown in Fig. I (COLR Fig. 3.1-2). The thermal power level shall be restricted pursuant to specification 3.1 .3.6 during subsequent operation.

7. § fl unable to perform Step 5 or Step 6, Then be in at least Hot Standby within six hours.

8. If a CEA becomes misaligned greater than 15 inches, but does NOT drop while performing the above section, Then proceed to Appendix D.

28

REVISION NO.: IPROCEDURE TITLE: PAGE:

57A PROCEDURENO.:

J CEA OFF-NORMAL OPERATION AND REALIGNMENT 15 of 33 2-0110030 ST. LUCIE UNIT 2 APPENDIX C ONE OR MORE CEA(S) MISALIGNED FROM ANY OTHER CEA IN ITS GROUP BY GREATER THAN 7 INCHES BUT LESS THAN OR EQUAL TO 15 INCHES (Page 2 of 2)

9. jf the CEA drops while performing the above section, Then proceed to Appendix F.

10. Upon ascertaining that plant conditions are normal, continue with the reactor startup or return to the desired operating power level in accordance with 2-GOP-lOl, Reactor Operating Guidelines During Steady State and Scheduled Load Change. The guidelines for ASI oscillation control should be implemented appropriately.

END OF APPENDIX C 29

REVISION NO.: PROCEDURE TITLE: PAGE:

57A CEA OFF-NORMAL OPERATION AND 90 f 33 PROCEDURE NO.: REALIGNMENT 2-0110030 ST. LUCIE UNIT 2 APPENDIX A CEA INVESTIGATION FOR OPERABILITY (Page 1 of 3)

CAUTION

• 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.

0. j[ 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. ] 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.

30

REVISION NO.: PROCEDURE TITLE: PAGE:

57A CEA OFF-NORMAL OPERATION AND 10 f 3 PROCEDURE NO.: REALIGNMENT 2-0110030 ST. LUCIE UNIT 2 APPENDIX A CEA INVESTIGATION FOR OPERABILITY (Page 2 of 3)

NOTE Tripped CEA disconnect and I or loss of CEA subgroup logic function will cause dropped CEAs.

2. fl the CEA(s) does NOT operate (move), Then check the status of the CEDM coil power supply panels in the cable spreading room:

A. Symptoms:

1. CEA disconnect in OFF; red light off, green light on.

2. CEA disable lights are red for the affected CEA.

3. Timer failure lights are red for the affected CEA.

B. Trouble Shooting:

1. If CEA disconnect is off, Then:

a. Turn ON disconnect switch.

b. Reset ACTM card toggle switch. (located inside cabinet, top switch, UG ENGD light should remain on).

2. If CEA disconnect is not off, Then:

a. Reset ACTM card toggle switch.

C. Check the air conditioning system for proper operation.

0. Check the cooling fans for proper operation.

E. Contact the I&C Dept. for assistance and notify them of the problem and any abnormalities found.

1. Check the CEDMCS and CEA drive system for alarms that might indicate the CEA problem.

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

2. Withdraw and insert the CEA(s) in manual individual or manual group at the direction of I&C to support troubleshooting.

31

REVISION NO.: PROCEDURE TITLE: PAGE; 57A CEA OFF-NORMAL OPERATION AND 11 of 33 PROCEDURENO.: REALIGNMENT 2-0110030 ST. LUCIE UNIT 2 APPENDIX A CEA INVESTIGATION FOR OPERABILITY (Page 3 of 3)

2. (continued)

F. Have I & C perform the following as necessary.

1. Check associated power supplies and fuses.

2. Obtain coil current traces and voltage measurements to determine the location of trouble.

NOTE Two or more CEAs simultaneously transferring to the lower gripper could indicate CEDMCS noise caused by system grounds.

3. j two or more CEAs simultaneously transfer to the lower gripper, Then perform the following:

a. Direct l&C to troubleshoot for possible system grounds.

b. Minimize movement of CEAs.

G. Proceed to the applicable Appendix for CEA realignment or to Appendix B if CEA is determined to be inoperable.

END OF APPENDIX A 32

REVISION NO.: PROCEDURE TITLE: PAGE:

57A CEA OFF-NORMAL OPERATION AND 24 ° f 3 PROCEDURE NO.: REALIGNMENT 2-0110030 ST. LUCIE UNIT 2 APPENDIX H CEA REALIGNMENT (MODES 1, 2 AND 3)

(Page 1 of 2)

1. While realigning CEAs, observe the following:

A. Regulating CEA5 shall be withdrawn in sequence and overlap between groups shall JQI 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 CEA5.

E. While CEA is misaligned, individual CEA positions within the group shall be determined at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 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. II CEA motion inhibit is present jj:

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).

33

REVISION NO.: PROCEDURE TITLE: PAGE:

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

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

E. 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 34

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 4 Page 9 of 22 1 9A Event

Description:

2A2-2A3 Spurious Opening resulting momentary deenergization of 2A3 4.16 KV bus Time f Position f Applicants Actions or Behavior Booth Operator Instructions: When directed, trigger OPEN 2A2- 2A3 Tie Breaker de-energizing the 2A3 4.16KV bus. The 2A EDG will start and load onto the 2A3 4.16KV Bus.

Booth Operator Instructions: When NPO directed to Investigate loss of bus, wait three minutes and state maintenance person was walking down an ECO and bumped the door tie-breaker cubicle door and the breaker opened. There is no apparent damage to the breaker.

Booth Operator Instructions:.

Control Room Indications:

Key Annunciator: B-9 PZR HTR XFMR 2A3 Trouble B-29 480V LC 2A312AB Load Shed RLY Failure Recognize 2A3 4.16KV bus is momentarily de-energized and SRO 2A Diesel Generator has started and closed onto the bus.

Implements 2-ONP-47.01, Loss of Safety Related A.C. Bus (attached pages 36-43)

Recognizes loss of letdown, direct charging pumps to be stopped and control switches place in AUTO Implements 2-ONP-47.01, Loss of Safety Related A.C. Bus Appendix A (attached pages 38-43)

May implement 2-01 20035, Pressurizer Pressure and Level, due to the need to select an operable pressure control channel and RRS channel and to reset heaters. (attached pages 44-50)

If up power in progress, directs stopping power ascension places turbine on HOLD 35

REVISION NO.: PROCEDURE TITLE: PAGE:

7 LOSS OF A SAFETY RELATED A.C. BUS 7 of 54 PROCEDURE NO.:

2-ON P-47.01 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions CAUTION Various instruments and equipment that are normally used for the assessment of critical safety functions may QI be operable. Use all available indications.

INSTRUCTIONS CONTINGENCY ACTIONS

1. If letdown flow is lost, Then:

A. SECURE charging.

B. ENSURE all operable charging pump control switches are returned to AUTO.

2. INVESTIGATE DETERMINE which electrical bus was lost.

3. VERIFY RCP CCW Flow Low 10 Minute 3. jf RCP 10 Minute Time Delay Trip Timing annunciator is NOT in alarm. is in alarm, Then:

A. ISOLATE N Header supply RETURN valves from the inoperable CCW train OR B. ISOLATE CCW to the Fuel Pool Heat Exchanger.

4. plant is in mode 3 through 6 (SIAS Blocked), Then PERFORM safety function status check of Low Mode Off-Normal Procedure for the current plant condition.

36

tEVISION NO.: PROCEDURE TITLE: PAGE:

7 LOSS OF A SAFETY RELATED A.C. BUS 8 0 f 54 PROCEDURE NO.:

2-ONP-47.O1 ST. LUCIE UNIT 2 6.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS NOTE If more than one electrical bus has been lost, several appendices may be required to restore electrical lineup to normal. Figure 1 contains a diagram of the main power distribution system to aid in the performance of this procedure.

5. RESTORE power to the deenergized bus per the appropriate Appendix below:

VOLTAGE DEENERGIZED BUS APPENDIX 4160 2A3 A 4160 2B3 B 4160 2AB C 480 L.C. 2AB D 480L.C. 2A2 E 480 L.C. 2B2 F 460..C. 2A5 G 480 L.C. 2B5 H 480 M.C.C. 2A5 480 M.C.C. 2B5 J 480 M.C.C. 2A6 K 480 M.C.C. 2B6 L 480 M.C.C. 2A7 M 480 M.C.C. 2B7 N 480 M.C.C. 2A8 0 480 M.C.C. 2B8 P 480 M.C.C. 2A9 Q 480 M.C.C. 2B9 R 480 M.C.C. 2AB S

6. If RAB electrical equipment room ventilation has been lost, Then RESTORE per 2-NOP-25.06, RAB Ventilation System.

7. EVALUATE Technical Specifications for lost electrical busses and equipment.

37

REVISION NO,; PROCEDURE TITLE: PAGE:

7 LOSS OF A SAFETY RELATED A.C. BUS 10 of 54 PROCEDURE NO.:

2-ONP-47.01 ST. LUCIE UNIT 2 APPENDIX A RESTORATION OF 2A3 4160V BUS (Page 1 of 6)

INITIAL If the deenergized bus is the 2A3 4160V bus, Then PROCEED as follows:

CAUTION Various instruments and equipment that are normally used for the assessment of critical safety functions may not be operable. Use all available indications.

NOTE Table 1 contains a listing of the major loads that have been lost.

A. With less than two CCW pumps running, MONITOR RCP bearing and seal temperatures closely.

B. ISOLATE N header supply and return valves from the CCW Train, if necessary, to increase cooling to the RCPs.

• HCV-14-8A

• HCV-14-9 C. ENSURE ICW pump does NOT start on a depressurized header.

PERFORM the following if required:

1. PLACE the 2A ICW pump (or 2C, if aligned to the A train) switch in the PULL to LOCK position.

AND

2. Locally THROTTLE 2A ICW pump (or 2C, if aligned to the A train) discharge valve approximately 10 turns open.

D. If a differential current lockout has occurred, (Annunciators B-14),

Then DISPATCH an operator to the switchgear to check for any relay indications or other apparent problems. (Current Relay located on 2A CCW pump breaker cubicle).

38

IPROCEDURE TITLE:

ST. LUCIE UNIT 2 APPENDIX A RESTORATION OF 2A3 4160V BUS (Page 2 of 6>

(continued) INITIAL CAUTION Resetting the differential current lockout relay will immediately result in the diesel output breaker closing and the diesel loading onto the bus.

E. If no apparent damage exists, Qfj attempt may be made to reset the lockout.

F. ATTEMPT to energize the bus from the 2A diesel generator, as follows:

1. VERIFY the 2A diesel generator is up to full speed and voltage. ATTEMPT a manual start of the engine if necessary.

2. When the diesel generator is ready to synchronize, INSERT the synchronize plug and make only one attempt to close in the 2A diesel output breaker 2-2021 1.

3. If the diesel generator did NOT start or is NOT running correctly, SEND an operator to the diesel building to investigate.

G. REFER to applicable appendices to re-power load centers.

H. if the bus has NOT been reenergized, Then ATTEMPT to cross tie the bus to the 2A2 4160V bus as follows:

1. ENSURE breakers to be closed are first green flagged.

2. ENSURE the 2A2 4160V bus is energized, if deenergized, perform the following as necessary:

a. If a differential current lockout has occurred, (Annunciator B-13), Then DISPATCH an operator to the switchgear to check for any relay indications or other apparent problems. (tCurrent Relay located on 2-20110 breaker cubicle).

b. If no apparent damage exists, one attempt may be made to reset the lockout.

39

REVISION NO.: PROCEDURE TITLE: PAGE:

7 LOSS OF A SAFETY RELATED A.C. BUS 12 of 54 PROCEDURE NO.:

2-ONP-47.01 ST. LUCIE UNIT 2 APPENDIX A RESTORATION OF 2A3 4160V BUS (Page 3 of 6)

1. H. 2. (continued) INITIAL

c. INSERT sync plug and turn to position ST-2A2 MAKE only one attempt to Close Startup Transformer breaker 2A 2-20102.

OR INSERT sync plug and turn to position AT-2A2 MAKE only one attempt to Close Aux Transformer breaker 2A 2-201 01.

d. j. the 2A2 4160V bus can NOT be energized, Then PROCEED with Step 1 .H.

3. MAKE one attempt to close the 2A2/2A3 tiebreaker 2-20109.

4. INSERT the sync plug and turn to position TIE-2A3 MAKE only one attempt to close the 2A3!2A2 tiebreaker 2-20209.

I. CALL the Electrical Department for assistance, if breaker(s) will NOT close.

J. If NOT done previously, DISPATCH an operator to the switchgear to check for relay indications and any other possible problems.

K. If the diesel generator is loaded on the bus and the bus can be powered from an auxiliary I startup transformer, PERFORM the following if desired:

1. ENSURE breakers to be closed are first green flagged.

2. CLOSE breaker 2-20 109 2A2 to 2A3 tie breaker.

NOTE The EDO Governor Control Amber light must be lit to ensure the EDG governor motor operated potentiometer is set to 60 cycles PRIOR to selecting the sync plug to position TIE-2A3.

3. ENSURE amber light is lit on the diesel generator governor control.

40

REVISION NO.: PROCEDURE TITLE: PAGE:

7 LOSS OF A SAFETY RELATED A.C. BUS 13 0 f 54 PROCEDURE NO.:

2-ONP-47.01 ST. LUCIE UNIT 2 APPENDIX A RESTORATION OF 2A3 4160V BUS (Page 4 of 6)

K. (continued) INITIAL CAUTION Potential for diesel generator trip exists. Prior to closing the bus tie breaker, verify there are no diesel generator trips locked in (Annunciators B-26).

4. PLACE the synchronize plug in the TIE 2A3 position MATCH voltages using the DG voltage control.

5. With the DG governor control, MAKE the synchroscope go slow in the counter-clockwise direction.

6. CLOSE breaker 2-20209 2A3/2A2 just before the needle on the synchroscope passes through the 12 oclock position. Immediately GO TO raise on the diesel governor control and HOLD it there until the Diesel has stabilized (to prevent reverse power trip).

7. UNLOAD 2A diesel generator to 100KW and open 2A diesel generator output breaker.

8. STOP 2A diesel generator VERIFY proper restart conditions by amber light indications on voltage regulator and governor controls.

a. COMPLETE all of the activities associated with shutdown of the Emergency Diesel Generators lAW normal operating procedures, including draining the accumulated water from the day tanks.

9. REMOVE the sync plug.

41

REVISION NO.: PROCEDURE TITLE: PAGE:

7 LOSS OF A SAFETY RELATED A.C. BUS 14 of 54 PROCEDURE NO.:

2-ONP-47.01 ST. LUCIE UNIT 2 APPENDIX A RESTORATION OF 2A3 4160V BUS (Page 5 of 6)

1. (continued) INITIAL L. j the bus can NOT be reenergized quickly, Then PERFORM the following:

TThe HVE-21 B CEDM Cooling Fan breaker NOTE may have to be RECLOSED manually due to an undervoltage trip condition on the A side bus.

1. ENSURE the following are running:

a. HVE-21B CEDM cooling fan

b. HVS-2B Rx cavity cooling fan

c. HVE-3B Rx support cooling fan

d. HVS-1C & 10 containment coolers

2. REFER to 2-ONP-25.01, Loss of RCB Cooling Fans, due to the loss of two containment coolers.

3. ENSURE that Pressurizer level and pressure controllers are selected to the unaffected Y channel, then REFER to ONOP 2-01 20035, Pressurizer Pressure and Level, to restore the PZR heaters as necessary.

4. If the 2AB 480V load center was aligned to the A bus, REALIGN it to the energized B bus as follows:

a. OPEN 2-40702 2A2 Tie Breaker to 2AB 480V LC.

b. OPEN 2-40220, 2A2 Tie Breaker to 2AB 480V load center.

c. CLOSE 2-40504 2B2 Tie breaker to 2AB 480V load center.

5. CLOSE 2-40706, 2B2 Tie breaker to 2AB 480V load center.

42

REVISION NO.: PROCEDURE TITLE: PAGE:

7 LOSS OF A SAFETY RELATED A.C. BUS 15 of 54 PROCEDURE NO.:

2-ON P-47.01 ST. LUCIE UNIT 2 APPENDIX A RESTORATION OF 2A3 4160V BUS (Page 6 of 6)

1. L. (continued) INITIAL

6. If the 2AB 41 60V bus was aligned to the deenergized A bus, REALIGN it to the energized B bus as follows:

a. OPEN 2-20505, 2A3 tie breaker to 2AB 4160V bus.

b. OPEN 2-20208, 2A3 tie breaker to 2AB 4160V bus.

c. CLOSE 2-20409 2B3 tie breaker to the 2AB 4160V bus.

d. CLOSE 2-20504 2B3 tie breaker to the 2AB 4160V bus.

7. START the 2C ICW pump on the depressurized header per 2-NOP-21 .03C, 2C Intake Cooling Water System Operation.

8. START 2C CCW pump per ONOP 2-0310030, Component Cooling Water Off Normal Operation.

9. If shutdown cooling has been lost, Then RESTORE SDC per ONOP 2-0440030, Shutdown Cooling Off-Normal.

10. RESTORE charging and letdown, if necessary, per 2-ON P-02 .03, Charging and Letdown.

11. ALIGN the 2AB battery charger to the 2A DC bus per 2-NOP-50.OIA, 125V DC Bus 2A (Class IE) Normal Operation.

12. MONITOR the 2A diesel fuel oil day tank levels, as they will NOT automatically refill.

END OF APPENDIX A 43

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 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 enerçized.

1. ABNORMAL PRESSURIZER 1.

PRESSURE CONDITION NOTE Appendix A contains a listing of pressurizer pressures which are associated with automatic actions.

A. Verify pressurizer spray, proportional A. f system is NOT operating and back-up heaters are operating properly in automatic, Then properly in automatic. Refer to perform the following as Appendix A for expected automatic necessary:

responses.

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

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

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

44

REVISION NO.: PROCEDURE TITLE: PAGE:

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

2-01 20035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

1. A. (continued) 1. A. (continued)

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

NOTE 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 I 100E, Spray Valve 2B2, B. j either spray valve is OPEN, and PCV 11 OOF, Spray Valve 2B1, Then perform the following:

CLOSED by observing BOTH of the following:

1. CLOSED valve position 1. it PCV 11 OOE, Spray Valve indication. 2B2, is OPEN, Then PLACE the spray valve selector switch in PCV hOOF.

2. TIA-1103, Spray Line 2B1 2. PCV 11 OOF, Spray Valve Temperature, and TIA-1104, 2B1, is OPEN, Then Spray Line 2B2 Temperature, PLACE the spray valve approximately equal. selector switch in PCV 1100E.

45

REVISION NO.: PROCEDURE TITLE: PAGE:

26 PRESSURIZER PRESSURE AND LEVEL 7 0 f 15 PROCEDURE NO.:

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

INSTRUCTIONS CONTINGENCY ACTIONS (continued) 1. B. (continued)

3. jf pressure continues to decrease due to a failed open main spray valve, Then consider performing the following:

• Trip the reactor and turbine

• Stop the RCP in the affected loop.

PCV IIOOE-2B2 RCP PCVIIOOF-2B1 RCP

4. if the RCP in the affected loop has been secured and pressure continues to decrease, Then consider securing both 2B1 and 2B2 RCPs.

C. Verify SE-02-03, and SE-02-04, C. jf auxiliary spray valve(s) is Auxiliary Spray Valve(s), CLOSED. OPEN, Then:

1. Attempt to close using key switch.

2. if auxiliary spray valves will NOT close, Then stop all charging and isolate letdown. Refer to 2-ONP-02.03, Charging and Letdown.

3. ReviewAP 0010134, Component Cycles and Transients, for applicability when plant is stabilized.

46

REVISION NO.: PROCEDURE TITLE: PAGE:

26 PRESSURIZER PRESSURE AND LEVEL 8 of 15 PROCEDURE NO.:

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

INSTRUCTIONS CONTINGENCY ACTIONS

1. (continued) 1. (continued)

I NOTE

[ Normally one PORV is isolated at power.

D. Verify power operated relief valves D. jf PORV is OPEN and are closed, pressure is less than 2300 psia, Then close PORV block valve(s) V-I 476 and I or V-1477. Refer to 2-0120036, Pressurizer Relief! Safety Valve Off-Normal Operating Procedure.

E. Ensure that PORVs V-1474 and V-1475 hand switches are in the proper position for existing plant conditions; see below:

Switch in NORMAL RANGE: Switch in LTOP:

1. (Lift Setpoint 2370 psia) 1. (Lift Setpoint 490 psia)

RCS temperature greater than RCS temperature less than 255°F during heatup or greater 255°F during heatup or less than 240°F during a cooldown. than 240°F during cooldown.

F. Verify pressure anomaly is NOT F. Slow the rate of change of caused by a large rate of change of T-avg or stabilize until T-avg. pressure anomaly is controlled.

0) 47

REVISION NO.: PROCEDURE TITLE: PAGE:

26 PRESSURIZER PRESSURE AND LEVEL f 15 PROCEDURE NO.:

2-01 20035 ST. LUCIE UNIT 2 7.2 Subsequent Operator Actions (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

1. (continued)

G. If (LOOP) Loss of Offsite Power has occurred with diesel generators supplying power 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 81 and B4 only (200 kw each).

2. ABNORMAL PRESSURIZER LEVEL 2.

CONDITION NOTE Appendix B contains a listing of pressurizer levels which are associated with automatic actions.

A. Verify selected RRS channel is A. j the selected RRS channel operating properly. has failed, Then shift to the operable channel.

1. NAVIGATE to the SBCS inputs screen on either FWFPD and resetthe TAVE signal, if required.

B. Ensure backup charging pump starts B. jf automatic actions have NOT and letdown flow is decreasing, or occurred, Then manually the backup charging pump stops and control charging and letdown letdown flow is increasing, whichever flow as required.

is applicable. (Appendix B contains expected automatic responses.)

48

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.

0. 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-02.03, Charging and Letdown.

E. Verify selected pressurizer level E. 11 selected level control valve is control valve (LCV-21 lOP / NOT operating properly, Then LCV-2110Q) is operating properly. take manual control of level control valve and refer to 2-ONP-02.03, Charging and Letdown.

F. Verify selected letdown pressure F. j selected pressure control control valve (PCV-2201P I valve is NOT operating PCV-2201Q) is operating properly. properly, Then take manual control of pressure control valve and refer to 2-ONP-02.03, Charging and Letdown.

49

REVISION NO.: IPROCEDURE TITLE: PAGE:

26 1 PRESSURIZER PRESSURE AND LEVEL 11 of 15 PROCEDURENO.: 1 2-0120035 f 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 G. pressurizer heaters are controllers (selected and non- deenergized or level indicating selected) are operating properly and controller(s) failed, Then power is available to pressurizer perform the following:

heaters.

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 50

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 4 Page 10 of 22 1 9A Event

Description:

2A2-2A3 Spurious Opening resulting momentary deenergization of 2A3 4.16 KV bus Time I Position I Applicants Actions or Behavior Booth Operator Instructions: If requested, the Shift Manager and/or Electrical Maintenance Supervisor give OK to reclose the 2A2-2A3 Tie Breaker.

When directed to reset non-essentials, call and state the 2A8 MCC non-essentials will not reset. Appears MCC still de-energized.

EXAMINERS NOTE:

Direct restoration of CR ventilation and SBVS/Fuel Pool ventilation systems. Recognize must reenergize MCC 2A8 before restoring Fuel Pool ventilation.

From Appendix A step K direct the 2A3 KV bus powered from SRO the Startup transformer and the 2A Diesel unloaded and stopped. (attached pages 40-41)

Direct non-essential loads reset.

Resets DCS TAVE signal on SBCS or FW FPD input screens if required. Using 2-0120035, Pressurizer Pressure and Level (attached page 48)

EXAMINERS NOTE: When 2A3 4.16 KV bus re-energized 2A8 MCC load center breaker tripped deenergizing the bus.

SRO Recognize T.S. 3.8.3.1 Action a re-energize within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

TS. NOTE: Also applied when the bus was initially de-energized.

51 I,

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 4 Page 1 1 of 22 19A Event

Description:

2A2-2A3 Spurious Opening resulting momentary deenergization of 2A3 4.16 KV bus Time I Position I

. Applicants Actions or Behavior Booth Operator Instructions: None Recognize loss of letdown, stops Charging pumps and places RO control switches in AUTO Recognizes toss of power to the LIC 1100 X and PlC 11 OOX RO requiring selection of the Y controllers to regain PZR heaters.

Selects operable Pressurizer pressure control and RRS channels and resets Pressurizer heaters lAW 2-01 20035, Pressurizer Pressure and Level. Obtains key 98 for backup interlock bypass keyswitch. Places key in LEVEL position and reset B side heaters. (attached pages 44-50)

Monitors adequate CCW flow to the RCPs. Monitors RCP RO bearing and seal temperatures.

When directed restore Charging and letdown JAW 2-ONP-02.03, Charging and Letdown step 6.0.11 (attached pages 53-57) 52

REVISION NO.: PROCEDURE TITLE: PAGE:

15B CHARGING AND LETDOWN PROCEDURE NO.: 7 of 26 2-ON P-02.03 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

9. j letdown is unavailable, Then MAINTAIN pressurizer level by temporarily cycling charging pumps.

NOTE

§ If one or more charging pumps have lost pumping ability, gas binding may have occurred. This can result from pumping the VCT dry (hydrogen binding) or rupture of a charging pump suction accumulator (nitrogen binding). If this occurred, the charging pumps must be vented after restoring a source of water to the suction. -

10. the charging pumps are gas bound, Then REFER TO Appendix C, Venting a Gas Bound Charging Pump.

11. jchargingandletdownhas 11.

been lost and can be restored, Then RE-ESTABLISH charging and letdown flow as follows:

A. ENSURE adequate VCT A.1 RESTORE the VCT level is indicated, to a normal level in accordance with 2-ON P-02.O 1, Boron Concentration Control.

B. ENSURE the Level Control Valve selector switch and the Pressure Control Valve selector switch are selected to the level and pressure control valves presently in service.

53

REViSION NO.: PROCEDURE TITLE: PAGE -

15B CHARGING AND LETDOWN 8of26 PROCEDURE NO.:

2-ONP-02.03 ST. LUCIE UNIT 2 5.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

11. (continued)

C. PLACE HIC-lilO, Level, controller in MANUAL.

D. ENSURE PIC-2201 Pressure controller is in AUTO and set to maintain 150 psig.

E. PLACE the Position Limiter Bypass key switch in the BYPASS position.

F. ENSURE the Level Control Valves are CLOSED.

G. BYPASS Letdown Ion Exchangers by placing V2520 Ion Exchanger Bypass Valve to the BYPASS RESET POSITION.

H. START one charging pump I. VERIFY charging flow is indicated.

NOTE If V251 5 closed due to Regenerative Heat Exchanger Outlet Temp High, it may be necessary to cycle V2515 while opening the PZR Level control valve until flow is adequate to clear the high temperature alarm.

J. VERIFY the regenerative heat exchanger high temperature alarm M-28, SIAS R-6 or CIS P-3 alarms are NOT present.

cyi 54

REVISION NO.: PROCEDURE TITLE: PAGE:

158 CHARGING AND LETDOWN of 26 PROCEDURE NO.:

2-ONP-02.03 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

11. (continued)

K. OPEN V2515, Stop Valve-IC.

L. OPEN V2516, Containment IsoI Valve-IC.

M. OPEN V2522, Containment Isol Valve OC N. SLOWLY OPEN the Level Control Valve and ESTABLISH approximately 5 gpm letdown flow.

CAUTION Prolonged use of charging without letdown could result in the pressurizer going solid. Pressurizer level must be closely monitored.

NOTE TI-2229, Charging Temp Outlet Regen HX should NOT be allowed to increase more than 60°F per minute.

0. WHEN Letdown 0.1 it letdown cannot be temperature stabilizes on restored, TIC-2221, Temp Regen Then INITIATE charging Hx Tube Out, as required for restoring Then RAISE letdown pressurizer level, or flow at a rate NOT to boration.

exceed 5 to 10 gpm over at least a 4 minute period.

P. ENSURE PIC-2201, Pressure controller is maintaining letdown pressure at 150 psig.

55

FEVISION NO.: PROCEDURE TITLE: PAGE:

158 CHARGING AND LETDOWN PROCEDURE NO.:

10 of 26 2-ONP-02.03 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

11. (continued)

Q. When PZR level is at its setpoint, Then PERFORM the following:

1. BALANCE HIC-IllO, LEVEL, controller AUTO to MANUAL output signals, using the BIAS control knob while previewing the AUTO signal.

2. PLACE HIC-1110, LEVEL, controller to AUTO.

3. MONITOR pressurizer level for abnormal trends.

R. PLACE the Position Limiter Bypass key switch to the NORM position.

CAUTION I V2345, LTDN CNTL VLV STATION SAFETY RELIEF, will open at 600 psig.

S. SLOWLY RAISE PIC-2201, Pressure, setpoint to 430 psig.

T. ENSURE letdown pressure is being maintained at 430 psig.

56

REVISION NO.: PROCEDURE TITLE: PAGE; 158 CHARGING AND LETDOWN 0f 26 PROCEDURE NO.:

2-ON P-02.03 ST. LUCIE UNIT 2 6.0 OPERATOR ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

11. (continued)

U. NOTIFY Health Physics that dose rates near CVCS ion exchangers and piping may change when ion exchanger is placed in service.

V. PLACE the Letdown Ion Exchangers back in service by placing V2520 Ion Exchanger Bypass Valve to the AUTO Position.

12. If Letdown Level control is 12.

malfunctioning, Then PERFORM the following:

A. VERIFY the output of A.1 PLACE HIC-IllO in MANUAL by HIC-IllO, LEVEL, is performing the following:

responding as expected to current plant 1. BALANCE HIC-IllO conditions. MANUAL to AUTO controller output signals by previewing and using the MANUAL control knob to match the manual and auto controller output signals.

2. PLACE HIC-IllO to MANUAL.

3. ADJUST letdown flow to a value consistent with the current plant conditions.

4. PERFORM a system walkdown observing for leaks or lifting relief valves.

B. VERIFY the selected B.1 PLACE the Alternate Level control level control valve is valve in service in accordance responding as expected with 2-NOP-02.02, Charging and to HIC-111O output. Letdown.

57

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 4 Page 12 of 22 1 9A Event

Description:

2A2-2A3 Spurious Opening resulting momentary deenergization of 2A3 4.16KV bus Time Position T Applicants Actions or Behavior Booth Operator Instructions: None Recognize key annunciator B-22 4.16KV SWGR 2A2-2A3 TIE BOP BKR OVRLD TRIP. Verify breaker 2-20109 and 20209 are open.

Verifies 2A EDG has started and loaded onto 2A3 Bus.

When directed, calls NPO and SNPO to checkout breakers 2-201 09 and 20209 respectively.

When directed energize the 2A3 4.16 KV bus from the Startup.

transformer lAW Appendix A step K (attached pages 40-41)

Restore shield building/fuel pool ventilation system using 2-ONP-26.02 Area Radiation Monitors. (attached pages 59-60)

Resets DOS TAVE signal on SBCS or FW FPD input screens if required. (attached pages 48) 58

REVISION NO.: PROCEDURE TITLE: PAGE:

6 AREA RADIATION MONITORS 16 0 f 18 PROCEDURE NO.:

2-ON P-26.02 ST. LUCIE UNIT 2 APPENDIX B FUEL POOL VENTILATION RESTORATION (Page 1 of 2)

1. RESET the Fuel Pool High Radiation interlocks as follows (HVAC Panel):

A. PRESS the Fuel Pool HVAC HI RAD A Reset pushbutton.

B. PRESS the Fuel Pool HVAC HI RAD B Reset pushbutton.

2. STOP the operating Shield Building Exhaust Fan(s):

• HVE-6A, SBVS Exhaust Fan

• HVE-6B, SBVS Exhaust Fan

3. ENSURE the following components are positioned as indicated:

COMPONENT ID COMPONENT NAME POSITION FCV-25-32 SBVS Isolation Valve OPEN FCV-25-30 Fuel Handling Emerg Vent Vlv CLOSED FCV-25-1 1 Outside Cooling Air to SBVS CLOSED D-29 Fuel Pool Inlet Damper OPEN D-31 Fuel Pool Outlet Damper OPEN D-33 Fuel Hdlg Bldg Inlet Damper OPEN D-35 Fuel Hdlg Bldg Outlet Damper OPEN FCV-25-33 SBVS Isolation Valve OPEN FCV-25-31 Fuel Handling Emerg Vent Vlv CLOSED FCV-25-12 Outside Cooling Air to SBVS CLOSED D-30 Fuel Pool Inlet Damper OPEN 0-32 Fuel Pool Outlet Damper OPEN D-34 Fuel Hdlg Bldg Inlet Damper OPEN D-36 Fuel Hdlg Bldg Outlet Damper OPEN

4. PLACE Fuel Pool Ventilation in service as follows:

A. START a Fuel Pool Exhaust Fan:

• HVE-16A, Fuel Pool Exhaust Fan

• HVE-16B, Fuel Pool Exhaust Fan B. VERIFY HVS-6, Fuel Pool Supply Fan, starts.

59

REVISION NO.: PROCEDURE TITLE: PAGE:

6 AREA RADIATION MONITORS 0

PROCEDURE NO.:

2-ONP-26.02 ST. LUCIE UNIT 2 APPENDIX B FUEL POOL VENTILATION RESTORATION (Page 2 of 2)

5. NOTIFY the SNPO to place Fuel Handling Building Ventilation in service as follows:

A. START HVE-15, Fuel Handling Bldg Exhaust Fan.

B. VERIFY HVS-7, Fuel Handling Bldg Supply Fan, starts.

C. START HVE-17, Fuel Handling Bldg Swgr Area Exhaust Fan.

END OF APPENDIX B 60

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 5 Page 13 of 22 1 9A Event

Description:

CCW Header B rupture HCV-14-1O fails open Timçj Position I Applicants Actions or Behavior Booth Operator Instructions: When directed trigger CCW header B rupture Control Room Indication available:

Annunciators LA-lO, CCW Surge Tank Compartment A Level Low and LB-b, CCW Surge Tank Compartment B Level Low Examiners Note: If crew manually trips the reactor due to failure of restoring the N header within 10 minutes, insert SGTL I SGTR SRO Recognizes low CCW surge tank alarms Implements 2-0310030, Component Cooling Water Off-Normal Operation step 6.2.5 (attached pages 63-67)

Directs verification of N header valves closing Direct closing HCV-14-10 when informed failed to close Directs stopping 2B CCW pump Directs restoring N header from A side by performing step 6.2.5.C.2 NOTE: CCW N header must be restored within 10 minutes or the Reactor should be tripped and the RCPs should be turned off.

Direct placing 2B HPSI and Containment Spray Pumps to SRO STOP. Step 6.2 5.C.3.

° T.S. 3.7.3 Action statement 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to restore 2 trains NOTE: SRO may direct securing Charging and Letdown 61

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 5 Page 14 of 22 1 9A Event

Description:

CCW Header B rupture HCV-14-1O fails open Time Fosition L Applicants Actions or Behavior Booth Operator Instructions: None Recognizes low CCW surge tank alarms and recognizes HCV BOP 14-10 failure to close and notifies US When HCV-14-10 closed, recognizes annunciator LA-b, CCW Surge Tank Compartment A Level Low clears indicating rupture is on B header BOP Stops 2B CCW pump when directed When directed perform step 6.2.5,C.2 to restore N header from A side. (attached pages 64-65 Places the 2B HPSI and 2B Containment Spray Pump in STOP.

RO Monitors RCP bearing and seal temperatures Sets CCW Makeup valve to .85 If directed, secures Charging and Letdown 62

REVISION NO.: PROCEDURE TITLE: PAGE:

37 COMPONENT COOLING WATER -

14 of 23 PROCEDURE NO.: OFF-NORMAL OPERATION 2-0310030 ST. LUCIE UNIT 2 6.2 Subsequent Action (continued)

4. B. 8. (continued)

c. Non-running Containment Cooler (approx. 1300 GPM)

COMPONENT ID COMPONENT NAME POSITION INITIAL MV-14-9 CCW Supply to HVS-1A CLOSED MV-14-11 CCW Supply to HVS-1B CLOSED MV-I 4-13 CCW Supply to HVS-IC CLOSED MV-14-15 CCWSupplyto HVS-ID CLOSED

9. PLACE the following pump control switches in STOP on

-.4 RTGB-206:

. 2BHPSIPump w

-4

. 2B Containment Spray Pump -.4

10. CONSULT Tech Spec 3.7.3 due to loss of a Heat Exchanger.

5. jf a CCW Header is ruptured, Then PERFORM the following:

NOTE Annunciators LA-lO, CCW Surge Tank Compartment A Level Low, and LB-10, CCW Surge Tank Level High I Compartment B Level Low, will alarm on a rupture of either the A, B, or N CCW Header, or failure of the makeup system.

A. VERIFY that the N Header automatically isolates from the A and B Headers due to low levels in both compartments of the CCW Surge Tank by closure of the following:

. HCV-14-BA

. HCV-14-8B

. HCV-14-9

. HCV-14-10 63

REVISION NO.: PROCEDURE TITLE: PAGE:

37 COMPONENT COOLING WATER

- 1 of 2 3 PROCEDURE NO.: OFF-NORMAL OPERATION 2-0310030 ST. LUCIE UNIT 2 6.2 Subsequent Action (continued)

5. (continued)

NOTE CCW has been isolated to the following B Essential Header Components:

28 HPSI Pump 2B CS Pump 2C and 20 Containment Fan Coolers 2B SDC Heat Exchanger 2B Control Room NC Unit Fuel Pool Heat Exchanger CAUTION Loss of component cooling water flow through any of the heat exchangers listed below can result in severe thermal stress and flashing upon re-admittance of cooling flow:

2B HPSI Pump 2B CS Pump 2C and 20 Containment Fan Coolers 28 SDC Heat Exchanger 3B Control Room NC Unit 3C Control Room A/C Unit, if aligned to B Essential Header Fuel Pool Heat Exchanger, if aligned to B Essential Header C. If Annunciator LA-i 0, CCW Surge Tank Compartment A Level Low, alarm clears, indicating that the rupture is in the B Essential CCW Header, Then PERFORM the following:

1. STOP the CCW Pump currently supplying the B Header:

28 CCW Pump OR 2CCCWPump

2. RESTORE CCW to the N Header from the A Essential Header by performing the following:

a. CLOSE HCV-14-8A.

b. CLOSE HCV-14-9.

c. OPEN HCV-14-8A.

d. OPEN HCV-i4-9 (5 second time delay to open).

64

EVIS ION NO.: PROCEDURE TITLE: PAGE:

37 COMPONENT COOLING WATER -

18 of 23 PROCEDURE NO.: OFF-NORMAL OPERATION 2-0310030 ST. LUCIE UNIT 2 6.2 Subsequent Action (continued)

5. C. (continued)

3. PLACE the following pump control switches in STOP on RTGB-206:

• 2B HPSI Pump

• 2B Containment Spray Pump

4. lithe plant is on Shutdown Cooling, Then the primary side of the 2B SDC Heat Exchanger must be isolated by closing V3658, 2B SDC HX Inlet From LPSI Pump.

5. DISPATCH an operator to verify local CCW Surge Tank level indications that the A Surge Tank level has been restored.

6. LOCATE and ISOLATE the leak, if possible.

7. ft it is deemed necessary to restore CCW to the Fuel Pool Heat Exchanger from the A Essential Header prior to determining the source of the leak on the B Header, Then PERFORM the following:

a. CLOSE MV-14-17 and MV-14-19.

b. OPEN MV-14-18 and MV-14-20.

c. ft the A Essential Header begins to depressurize or Annunciator LA-lO, CCW Surge Tank Compartment A Level Low, alarms indicating that the rupture is in the header to or from the Fuel Pool Heat Exchanger, Then CLOSE MV-14-18 and MV-14-20.

65

REVISION NO.: PROCEDURE TITLE: PAGE; 37 COMPONENT COOLING WATER -

19 of 23 PROCEDURE NO.: OFF-NORMAL OPERATION 2-0310030 ST. LUCIE UNIT 2 6.2 Subsequent Action (continued)

5. (continued)

NOTE CCW has been lost to the following:

Reactor Coolant Pumps CEDM Coolers Letdown HX Sample HXs 2A and 2B Waste Gas Compressors CAUTION Loss of component cooling water flow through any of the heat exchangers listed below can result in severe thermal stress and flashing upon re-admittance of cooling flow:

Reactor Coolant Pumps CEDM Coolers Letdown Heat Exchanger Sample Heat Exchangers 2A and 2B Waste Gas Compressors D. If Annunciators LA-i 0, CCW Surge Tank Compartment A Level Low, and LB-b, CCW Surge Tank Level High I Compartment B Level Low, both clear, indicating that the rupture is in the N Header, Then PERFORM the following:

1. TRIP the Reactor and the Turbine.

2. TRIP all four RCPs.

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

4. LOCATE and ISOLATE the leak, if possible.

E. If Annunciators LA-b, CCW Surge Tank Compartment A Level Low, and LB-b, CCW Surge Tank Level High I Compartment B Level Low, do not clear, Then GO TO Step 6.2.6.B, Low Level in the CCW Surge Tank.

66

REVISION NO.: PROCEDURE TITLE: PAGE; 37 COMPONENT COOLING WATER -

20 of 23 PROCEDURE NO.: OFF-NORMAL OPERATION 2-0310030 ST. LUCIE UNIT 2 6.2 Subsequent Action (continued)

NOTE CCW Surge Tank vent (RCV-14-1) diverts from atmosphere to the Chemical Drain Tank on high radioactivity in the CCW system.

6. II abnormal level conditions exist in the CCW surge tank, Then PERFORM the following:

A. High Level in the CCW Surge Tank.

1. CHECK the CCW Radiation Monitors (RM-26-1 and RM-26-2) for abnormal trends. If high radiation is indicated, REFER to 2-ON P-14.02, Component Cooling Water Excessive Activity.

2. CHECK the CCW Surge Tank Makeup Flow meter (FQ-14-14) for flow. If makeup flow is indicated, CLOSE V14100, Makeup lsoI, and VERIFY V14101, Alternate Makeup Supply, is closed.

3. EVALUATE S/G Blowdown Sample Heat Exchangers as a source of in leakage.

B. Low Level in the CCW Surge Tank

1. CHECK the CCW Surge Tank Makeup Flow Meter (FQ-14-14) for flow:

a. If no flow is indicated:

1. VERIFY LCV-14-1, CCW Surge Tank Fill Valve, and V14100, Makeup Isol, are open.

2. VERIFY a Demin Water Pump is running.

I CAUTION I Use the fire system as a makeup source only as a last resort.

b. If flow is indicated:

1. COMMENCE a visual search of the CCW System for evidence of leakage.

2. REFER to Appendix A to aid in the leak search.

3. ISOLATE the leak, if possible.

67

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 6 Page 15 of 22 1 9A Event

Description:

SGTL I SGTR lime Position Applicants Actions or Behavior Booth Operator Instructions: When directed by examiner trigger SGTL, This will result in a 20 gpm SGTL Control Room Indications available:

Lowering Pressurizer pressure and level PC-Il SJAE and Blowdown alarms SRO Recognize Steam generator tube leak occurring on 2B SG

. SJAE alarm on PC-li 28 SG Blowdown radiation trending up

. Mismatch Chg / Letdown

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

Implement 2-0830030, Steam Generator Tube Leak (attached pages 69-82)

. Implement Appendix A and refer to Figure 2

. 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 1 1, Consider isolating U-i Vacuum drag

. Step 12 Verify SGBD not aligned to Discharge Canal e Direct field operators to perform step 13, 17, 18, 19 and 20 of Appendix A (attached pages 84-86)

SRO

• Determine T.S. 3.4.6.2. c (Action a) HSB within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Ts e Contact Chemistry for secondary sampling 68

REVISION NO.: PROCEDURE TITLE: PAGE:

36B STEAM GENERATOR TUBE LEAK 5 of 35 PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 7.0 OPERATOR ACTIONS 7.1 Immediate Operator Actions

1. None 7.2 Subsequent Operator Actions INSTRUCTIONS CONTINGENCY ACTIONS

1. in Mode I through Mode 3 (SIAS NOT Blocked), Then PERFORM Appendix A and refer to Figure 2 as needed.

2. j in Mode 3 through Mode 6 (SIAS is blocked), Then PERFORM Appendix B and refer to Figure 3 as needed.

3. ii continued use of SBCS is desired, Then block automatic initiation of MSIS at 700 psia (annunciators P-18, P-20), as follows:

A. Block MSIS by turning MSIS block key switches (21 and 22) on RTGB 206 to the block position.

B. Ensure annunciators P-8 and (P-b),

MSIS Actuation Channel A (B)

Blocked, alarm when blocked.

4. Maintain steam generator level in the operating band (60% 70% narrow range) using main or auxiliary feedwater system.

69

REVISION NO.: PROCEDURE TITLE: PAGE:

36B STEAM GENERATOR TUBE LEAK PROCEDURE NO.:

of 35 2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE I THROUGH MODE 3 (SIAS NOT BLOCKED)

(Page 1 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

1. j 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. j in Mode 3 (SIAS NOT Blocked),

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

NOTE lii 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 2. jf pressurizer level is NOT being operating and maintaining pressurizer maintained, Then isolate letdown to level, assist in maintaining pressurizer level.

3. ft the steam generator blowdown rad 3. Manually close the S/G blowdown monitor is in High Alarm, Then ensure and sample valves from the affected steam generator blowdown and sample steam generator.

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.

70

REVISION NO.: tROCEDURE TITLE: PAGE:

36B STEAM GENERATOR TUBE LEAK 10 of 35 PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE I 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 Blowdown monitor readings.

• Steam Generator Blowdown sample isolates on Steam Generator Blowdown orocess 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 guidehnes and Technical Specifications.

5. CHECK Air Ejector and I or Steam 5. 1! Steam Generator sample flow is Generator Blowdown monitor reading. isolated due to CIAS or high radiation, Then perform the

• Log radiation monitor readings every following, to regain sample flow only:

15 minutes. (Data Sheet 2)

• PLACE control switch for FCV-23-7/9 to CLOSE I OVERRIDE position

• OPEN FCV-23-7/9

6. j Air Ejector and / or Steam Generator Blowdown 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 B. If it is not possible to estimate leakage by comparing Air Ejector primary to secondary leakage or monitor (preferred) and I or Steam the radiation monitors are out-of-Generator Blowdown monitor reading service, Then determine leak rate with Daily Chemistry Report. by Chemistry sample.

71

REVISION NO.: PROCEDURE TITLE: PAGE:

36B STEAM GENERATOR TUBE LEAK 11 0 f 35 PROCEDURE NO.:

2-0830030 ST. LUCIE UNIT 2 APPENDIX A ACTIONS IN MODE I 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 / hr.

• Data Sheet 1 is available to facilitate monitoring leakage.

C. I! 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 / 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/mm to 50% in 1 hr and be in Mode 3 in the next 2 hrs, in accordance with 2-ONP-22.01, Rapid Downpower.

2. Go to Step 16 of Appendix A.

72

REVISION NO.: rROCEDURE TITLE: PAGE:

36B STEAM GENERATOR TUBE LEAK 12 f 35 PROCEDURE NO.:

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

(Page 4 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6. (continued) 6. (continued)

NOTE 150 gpd = 0.1 gpm D. if RCS inventory balance or plant 0. Go TO Step 6.E of Appendix A.

indications confirm primary to secondary leakage exceeds Tech Spec limits.

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

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

• 2-GOP-i 23, Turbine Shutdown

- Full Load to Zero Load

• 2-ONP-22.01, Rapid Down power

2. GO TO Step 16 of Appendix A.

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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 downpower will minimize possible plant perturbation.

E. jf BOTH the following conditions exist, E. Go TO Step 6.F of Appendix A.

• §, Estimated primary to secondary leakage is 75 gpd.

• There is no operable SJAE or affected S/C Blowdown radiaUon monitor, Then PERFORM the following:

I. REDUCE power ata rate of 3 mw/mm and be in Mode 3 in the next 6 hrs, in accordance with 2-ONP-22.01, Rapid Downpower.

2. Go to Step 16 of Appendix A.

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(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. il either of the following condition F. Go TO Step 6.G of Appendix A.

exists:

• 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/mm and be in Mode 3 in less than or equal to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, in accordance with one of the following:

• 2-GOP-I 23, Turbine Shutdown Full Load to Zero Load

• 2-ONP-22.01, Rapid Downpower

2. Go to Step 16 of Appendix A.

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(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. 11 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/C 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

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

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

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(Page 8 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

6. G. (continued) 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 H. GO TO Step 7 of Appendix A.

leakage is less than 30 gpd but greater than or equal to 5 gpd, Then PERFORM the following:

I. 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 l&C to adjust process monitor alarm setpoints.

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(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. j 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> time requirement of Data Sheet 1.

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

NOTE

• i! total tube leakage is greater than .1 GPM, Then the reactor must be in Hot Standby within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and Cold Shutdown within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />. 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.

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(Page 10 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

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

II. 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-IOA or HVS-1OB

• Exhaust Fans HVE-41A or HVE-41B

• SGBTF Ventilation Process Monitor

14. VERIFY RCS water inventory balance 14. RETURN TO Step 6.B of and I or Chemistry samples indicate Appendix A.

primary to secondary leak rate is less than or equal to 30 gpd.

15. j RCS Inventory balance and I or 15. RETURN to Step 6.B of Chemistry samples indicate primary to Appendix A.

secondary leak rate is less than 5 gpd, Then EXIT this procedure and continue with the normal monitoring program.

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(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:

• ff 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-IOA or HVS-1OB

• Exhaust Fans HVE-41A or HVE-41B

• SGBTF Ventilation Process Monitor 80

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(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.

21. When the turbine is tripped the reactor 21. j the reactor is shutdown, Then go is NOT shutdown, Then shutdown the to Step 22 of Appendix A.

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.

81

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(Page 13 of 13)

INSTRUCTIONS CONTINGENCY ACTIONS

22. When the reactor is shutdown, Then 22.

PERFORM BOTH of the following:

A. COMMENCE an RCS cooldown until A. Ji the SBCS is NOT available, hot leg temperature is less than 510°F Then PERFORM both of the using the SBCS. following:

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

2. Reevaluate the E-Plan classification.

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

Temperature.

23. j 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.

END OF APPENDIX A 82

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 6 Page 16 of 22 1 9A Event

Description:

SGTL / SGTR Time Position I Applicants Actions or Behavior Booth 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.

PC-li SJAE trending up and eventual alarm PC-li Blowdown trending up (10-15 mInutes after SJAE)

BOP/RO Recognize Steam generator tube leak occurring

. SJAE radiation alarms

. Blowdown radiation trending up

. Mismatch Chg. I Letdown Determines approximate leak rate of 20 gpm based on RO Charging I Letdown mismatch.

Communicate with NPO I SNPO to perform Appendix A steps BOP 13, 17, 18, 19 and 20 when directed by SRO,(attached pages 79-81) 83

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 6 Page 17 of 22 1 9A Event

Description:

SGTL / SGTR Time I Position Applicants Actions or Behavior Booth Operator Instructions: Trigger SGTR when directed by examiner Direct RO to isolate Letdown (Close V2515, V2516, V2522) as SRO 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 80)

Directs Reactor tripped when notified Pressurizer level cannot be maintained.

BOP Monitors and maintains SC 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 RO Isolate letdown when directed as leak increases Recognize Pressuirzer level lowering with letdown isolated and both Charging pumps running.

Inserts CEAs in Manual Sequential when directed, to place the plant in Mode 3 Trips the Reactor when directed by SRO 84

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 7, 8, 9 Page 18 of 22 1 9A Event

Description:

Reactor trip 2A MSSV fails open. Failure of MSIS to actuate. Failure of 2A HPSI pump to start.

Tirne_] Position 1 Applicants Actions or Behavior Booth Operator Instructions: When directed by Control Room to perform Appendix X of EOP-99 wait one minute and report back stating there is a MSSV stuck open the 2A SG.

Examiners Note: The MSSV will reset at 500 psia SG pressure Directs implementation of 2-EOP-01, Standard Post Trip Actions as follows:

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

Performs EOP-01 Safety Functions as directed for Reactivity RD 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)

Pressure Control

. Verify RCS pressure is between 1 800-2300 psia (at 1736 psia verify SIAS and stop RCP in each loop) e Verify RCS pressure is trending 2225-2275 psia (control manually)

• Verify RCS subcooling is >200 F 85

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 7, 8, 9 Page 19 of 22 19A Event

Description:

Reactor trip 2A MSSV fails open. Failure of MSIS to actuate. Failure of 2A HPSlpumptostart.

Time I Position j Applicants Actions or Behavior Booth Operator Instructions: If asked to gag the SG safety, report back In three minutes, the gag, normally on the steam trestle is missing.

CRITICAL Upon SIAS (1736 psia) recognize 2A HPSI failed to start.

TASK Request SRO permissive to start 2A HPSI pump. Starts 2A RO HPSI pump.

RO Stops one RCP I LOOP when SIAS on low Pzr. Pressure CRITICAL TASK Direct 2A HPSI pump started SRO Direct CCW restored to RCPs per Appendix J (attached pages SRO 92-93) when isolated by SIAS. If not restored within 10 minutes, direct stopping RCPs 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 BOP 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. (2A1, 2A2, 2A3 2AB, 2B1, 2B2 and 2B3 6.9 and 4.16kv buses)

• All vital and non vital DC Buses energized.

86

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 7, 8, 9 Page 20 of 22 1 9A Event

Description:

Reactor trip 2A MSSV fails open. Failure of MSIS to actuate. Failure of 2A HPSI pump to start.

Time I Position I Applicants Actions or Behavior Booth Operator Instructions: Approximately 2 minutes after being directed to perform Appdx. X section 1, NPO reports the 2A MSSV is lifting.

RCS Heat Removal

. Verify at least one SG has feedwater available (AFW or MFW)

BOP . 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 CRITICAL Recognizes MSIS fails to actuate at 700 psia. Recommends to TASK SRO to manually actuate MSIS. Manually actuates MSIS when BOP directed.

CRITICAL TASK Concurs I Gives direction to manually actuate MSIS.

SRO Containment Conditions

. Verify containment pressure <2 psig

. Verify NO containment radiation monitors in alarm.

BOP

. 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.

Restore CCW to RCPs per AppendixJ (attached pages 88-89)

Evaluate diagnostic flow chart of 2-EOP-01 Determines SGTR SRO and ESDE. Directs entry to 2-EOP-15, Functional Recovery 87

REVISION NO.: PROCEDURE TITLE: PAGE:

36A APPENDICES / FIGURES I TABLES I DATA 62 of 156 PROCEDURE NO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX J RESTORATION OF CCW AND CBO TO THE RCPS (Page 1 of 2)

Ei 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-14-1O ) 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.

Li 2. If 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-14-8B N Hdr lsol Discharge

• HCV-14-1O N Hdr lsol Suction Li 3. ALIGN CCWt0 I from the RCPs by OPENING ALL of the following valves:

Li HCV-14-1, CCWTo RC PUMP Li HCV-14-2, CCW From RC PUMP Li HCV-14-7, CCWTo RC PUMP Li HCV-14-6, CCW From RC PUMP Li 4. II CIAS has isolated controlled bleedoff flow to the VCT, Then OPEN V2507, RCP Bleedoff Relief Stop VIv.

88

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36A APPENDICES I FIGURES I TABLES I DATA 63 of 156 PROCEDURE NO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX J RESTORATION OF CCW AND CBO TO THE RCPs (Page 2 of 2)

CAUTION 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:

O HCV-14-11-A1, CCW From 2A1 RCP Seal Cooler 0 HCV-14-1 1-A2, CCW From 2A2 RCP Seal Cooler O HCV-14-11-B1, CCW From 281 RCP Seal Cooler O HCV-14-1 1-B2, CCW From 2B2 RCP Seal Cooler 0 6. VERIFY RCP CCW related alarms are CLEAR or have been evaluated and dispositioned.

END OF APPENDIX J 89

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: HLC Scenario # 8 Event # 10 Page 21 of 22 19A Event

Description:

Enter 2-EOP-15 Functional Recovery. Isolate 2A SC per Appendix R Time Position ( Applicants Actions or Behavior Booth Operator Instructions:

Implements 2-EOP-15 Functional Recovery:

SRO Implement Stepsl-9 (attached page 91-99)

Direct SFSCS to be performed every 15 minutes.

Identify Success Paths (Attachment 3 )(attached page 98)

Perform success path step 12 A-C (attached page 96)

Determines Containment Isolation Safety function NOT met (most affected SG not yet isolated). (attached page 98)

Directs isolation of the 2A SG using Appendix R of EOP-99, per RCS and Core Heat Removal HR-2 (attached pages 100-1 02)

When Appendix R complete determines Containment Isolation Safety Function met per Success Path Cl-i Perform 2-EOP-99 Appendix A, Sampling SGs (attached BOP pages 103-1 04)

BOP Perform Appendix R to isolate 2A SG (attach pages 100-102)

RD Monitor RCP operating limits.

Suggested termination point:

. 2A SG isolated

. All safety functions met e Controlled cooldown being performed 90

PAGE; REVISION NO,: PROCEDURE TITLE:

30 FUNCTIONAL RECOVERY 6 of 207 PROCEDURE NO.:

2-EOP-15 ST. LUCIE UNIT 2 4.0 OPERATOR INITIAL ACTIONS INSTRUCTIONS CONTINGENCY ACTIONS CAUTION A harsh containment condit ion exists if containment temperature is greater than 200° F. Figure IA should be used for determination of saturation margin when indicated containment temperature is less than or equal to ature 200°F. Figure 1 B should be used when indicated containment temper is greater than 200°F. Figure 1A should also be used if containment temperature had exceeded 200°F during event progression but was lowered to 200°F or less by containment cooling systems.

NOTE

• Instruments should be channe l checke d when one or more confirmatory indications are availab le. Reg Guide 1.97 designated instruments should be used for diagno sis of events and confirmation of safety functions.

are to Steps designated with an may be performed non-sequentially or be performed continuously.

1. Classify Event EVALUATE EPIP Classification criteria for present plant conditions and Emergency Plan Actions.

REFER TO EPIP-01, Classification of Emergencies.

EJ 2. Implement Placekeeping OPEN the Placekeeper NOTE the time of EOP entry.

91

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2-EOP-15 ST. LUCIE UNIT 2 4.0 OPERATOR INITIAL ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS j 3. RCP Trip Strategy A. If ANY of the following conditions exist,

• 2A or 2B AFW Pump is the ONLY source of Feedwater

• RCS pressure is less than 1736 psia

• RCS Temperature is less than 500°F Then STOP ONE RCP in EACH loop.

B. jf ANY of the following conditions exist,

• Main or Auxiliary Feedwater flow can NOT be re-established

• RCS subcooling is less than minimum subcooling

• CCW is LOST to the RCPs for greater than 10 minutes Then STOP ALL RCPs.

92

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30 FUNCTIONAL RECOVERY 8 of 207 PROCEDURE NO.:

2-EOP-15 ST. LUCIE UNIT 2 4.0 OPERATOR INITIAL ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS Ensure RCP Seal Cooling A. VERIFY CCW to the RCPs. A.1 j SIAS has isolated CCW to the RCPs, Then RESTORE CCW.

REFER TO Appendix J, Restoration of CCW and CBO to the RCPs.

A.2 CCW is lost for greater than 30 minutes, Then PERFORM BOTH of the following:

A. ENSURE CCW to the RCPs will remain isolated by PLACING the FOUR Containment CCW To/From RC Pump valves to CLOSE.

B. ENSURE RCP controlled bleedoff will remain isolated by PLACING the TWO RCP Bleedoff valves to CLOSE.

B. f BOTH of the following conditions exist,

• RCPs have CCW flow

• CIAS has isolated the normal RCP bleedoff flowpath to the VCT Then ESTABLISH the alternate RCP bleedoff flowpath to the Quench Tank by OPENING V2507, RCP Bleedoff Relief Stop Vlv.

93

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30 FUNCTIONAL RECOVERY PROCEDURE NO.:

9 of 207 2-EOP-15 ST. LUCIE UNIT 2 4.0 OPERATOR INITIAL ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

5. Verify RCP Operating Limits 5.1 STOP RCPs that do NOT satisfy operating limits.

if RCPs are RUNNiNG, Then VERIFY RCP operating limits are satisfied.

REFER TO Table 13, RCP Operating Limits.

LI 6. Sample SIGs Sample BOTH SIGs for activity and boron.

REFER TO Appendix A, Sampling Steam Generators.

LI 7. Place Hydrogen Analyzers in Service PLACE BOTH Hydrogen Analyzers in service.

REFER TO Appendix L, Placing Hydrogen Analyzer in Service.

8. Protect Main Condenser PERFORM BOTH of the following:

A. If a LOOP has occurred, Then PERFORM BOTH of the following to protect the Secondary Plant:

1. ENSURE MSIVs are CLOSED.

2. ENSURE SGBD is ISOLATED.

B. STABILIZE the Secondary Plant AS NECESSARY.

REFER TO Appendix X, Secondary Plant Post Trip Actions, Section 2.

94

rEVIS ION NO.: ,ROCEDURE TITLE: PAGE:

30 FUNCTIONAL RECOVERY PROCEDURE NO.:

10 of 207 2-EOP-15 ST. LUCIE UNIT 2 4.0 OPERATOR INITIAL ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS Restore Instrument Air jt a LOOP has occurred, Then PERFORM BOTH of the following:

A. ENSURE 2A8 480V Load Center is aligned to an energized bus.

B, DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 28 Instrument Air Compressors.

El 10. Perform Safety Function Status Checks PERFORM the Safety Function Status Checks every 15 minutes.

REFER TO Attachment 1, Safety Function Status Check Sheet.

El 11. Identify Success Paths IDENTIFY the success paths to be used to satisfy each safety function.

REFER TO Attachment 3, Functional Recovery Success Paths.

95

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30 FUNCTIONAL RECOVERY PROCEDURE NO.:

11 of 207 2EOP-15 ST. LUCIE UNIT 2 4.0 OPERATOR INITIAL ACTIONS (continued)

INSTRUCTIONS CONTINGENCY ACTIONS

12. Perform Success Path Instructions PERFORM ALL of the following IN THE ORDER LISTED.

A. Instructions for a success path MOST LIKELY to be met for safety functions that are NOT met by ANY success path.

B. Instructions for success paths for safety functions that are NOT met by Success Path 1.

C. Instructions for ALL other success paths for safety functions met by Success Path 1.

j 13. Perform Long Term Actions When ALL Safety Function Status Check acceptance criteria are being satisfied Then PERFORM Long Term Actions.

REFER TO Section 4.10, Long Term Actions.

END OF INITIAL ACTIONS 96

REVISION NO.: PROCEDURE TITLE: PAGE:

30 FUNCTIONAL RECOVERY PROCEDURE NO.: 147 of 207 2-EOP-15 ST. LUCIE UNIT 2 4.7 CONTAINMENT ISOLATION Cl-I - Success Path I AutomaticiManual (continued) Isolation (continued)

INSTRUCTIONS CONTINGENCY ACTIONS CAUTION If there is a conflict between isolating a S/G with indications of SIG tube leakage or isolating a S/G with an unisolable steam leak, Then the S/G with the ESD should be isolated. At least ONE S/G must remain available for heat removal.

El 2. Determine If SGTR Present If a SGTR has occurred as indicated by ANY of the following,

• SIG activity

• Main steam piping radiation

• SIG level change when NOT feeding

• SIG blowdown activity

• ONE SIG level rising faster than the other with feed and steaming rates being essentially the same for BOTH o Feedflow mismatch between S/Gs

• Steam flow vs. feed flow mismatch in a S/G PRIOR to the trip Then IDENTIFY and ISOLATE the MOST affected SIG.

REFER TO Heat Removal Success Path HR-i or HR-2, RETURN TO this success path when the MOST affected S/G is ISOLATED.

97

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30 FUNCTIONAL RECOVERY PROCEDURE NO.:

207 of 207 2-EOP-15 ST. LUCIE UNIT 2 ATTACHMENT 3 FUNCTIONAL RECOVERY SUCCESS PATHS (Page 1 of I)

Safety Functions Success Paths 123456 Reactivity Control RC-1, CEA Insertion RC-2, Boration via CVCS RC-3, Boration via SIAS Maint of Vital Aux DC MVA-DC-1, Batteries/Chargers Maint of Vital Aux AC MVA-AC-1, Startup Transformers MVA-AC-2, EDGs MVA-AC-3, Unit Crosstie RCS Inventory Control IC-I, CVCS lC-2, Safety Injection RCS Pressure Control PC-I, Subcooled Control PC-2, PORVs/Pzr Vent PC-3, Saturated Control RCS & Core Heat HR-I, SIG Without SIAS HR-2, S/C With SIAS HR-3, Once Through Cooling Containment Isol Cl-I, Automatic/Manual Isol Cntmt Press & Temp CTPC-I, Normal Cntmt Fans CTPC-2, Cntmt Coolers CTCP-3, Cntmt Spray Cntmt Comb Gas CCGC-I, Hydrogen <35%

CCGC-2, Hydrogen >3.5%

END OF ATTACHMENT 3 98

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30 PROCEDURE NO.:

I I

FUNCTIONAL RECOVERY I 176 of 207 2-EOP-15 ST. LUCIE UNIT 2 ATTACHMENT I SAFETY FUNCTION STATUS CHECK SHEET (Page 12 of 16)

6. CONTAINMENT ISOLATION AutomaticlManual Isolation, Cl-I SAFETY ACCEPTANCE FUNCTION CRITERIA CHECK CIS Radiation Monitors No valid alarms unexplained rising trends OR CIAS Actuated I I I I AND Containment Pressure Less than 3.5 psig I I I I OR CIAS Actuated 111111 F AND Secondary Plant No valid alarms IIIlII Activity j unexplained rising (Condenser Air Ejector, trends Blowdown OR Main Steamline Radiation Monitors)

If a SGTR exists The MOST affected I I I I S/G is ISOLATED AND The MOST affected I I I S/G pressure is less than 915 psig (930 psia)

AND No Steam Release from I I I I I I I the MOST affected S/C END OF SAFETY FUNCTION 6 99

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36A APPENDICES I FIGURES I TABLES / DATA 90 of 156 PROCEDURE NO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 1 of 6)

Section 1: 2A Steam Generator Isolation CAUTION I 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. ENSURE HCV-08-1A, Main Steam Header A Isolation Valve (MSIV), is CLOSED.

D 2. u HCV-08-1A did not close remotely, Then PERFORM local closure.

REFER TO Appendix I, MSIV Local Closure.

D 3. ENSURE MV-08-IA, MSIV Header A 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-09-1A, Main Feedwater Header A Isolation Valve, is CLOSED.

0 5. ENSURE HCV-09-1 B, Main Feedwater Header A Isolation Valve, is CLOSED.

0 6. 1! BOTH HCV-09-IA HCV-09-1B, Main Feedwater Isolation Valves to SIG 2A, are NOT CLOSED or suspected of leaking, Then PERFORM ANY of the following AS NECESSARY:

0 A. ENSURE ALL of the following valves are CLOSED:

O MV-09-5, Stm Gen 2A Reg Block Valve O LCV-9005, 2A 15% Bypass O MV-09-3, 2A 100% Bypass O B. STOP BOTH Main Feedwater Pumps.

O 7. ENSURE FCV-23-3, 2A SG Blowdown, is CLOSED.

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36A APPENDICES I FIGURES / TABLES / DATA i ° f 156 PROCEDURENO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 2 of 6)

Section 1: 2A Steam Generator Isolation (continued)

O 8. ENSURE FCV-23-4, 2A SG Blowdown, is CLOSED.

0 9. ENSURE MV-08-18A, 2A SIG Atmos Dump VIv, is CLOSED.

O 1O.CLOSE MV-06-14, 2A S/G ADV Isol.

0 11.PLACE the control switch for auxiliary feed, Pump 2A, in STOP.

0 12.ENSURE MV-09-9, Pump 2A Disch to SG 2A Valve, is CLOSED.

O 13.ENSURE MV-09-11, Pump 2C to SG 2A, is CLOSED.

0 14.PLACE MV-06-13, SG 2A Stm to AFW PP 2C, in CLOSE.

0 15.ENSURE MV-08-19A, 2A S/C Atmos Dump VIv, is CLOSED.

0 16.CLOSE MV-08-15, 2A S/G ADV Isol.

0 17PERFORM the following LOCAL operations:

0 A. UNLOCK and CLOSE V09152, 2C AFW Pump to 2A SIC Isolation.

O B. UNLOCK and CLOSE V09120, 2A AFW Pump to 2A S/C Isolation.

0 C. CLOSE SE-08-2, Main Steam to 2C AFW Pump Warm-up Valve Solenoid.

0 D. If SE-08-2, Main Steam to 2C AFW Pump Warm-up Valve Solenoid is NOT CLOSED or suspected of leaking, Then CLOSE V08884, SE-08-2 Inlet Isolation.

(continued on next page) 101

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36A APPENDICES I FIGURES I TABLES I DATA 92 of 156 PROCEDURE NO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX R STEAM GENERATOR ISOLATION (Page 3 of 6)

Section 1: 2A Steam Generator Isolation (continued)

17. (continued)

D E. If MV-08-13, SIG 2A 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-08-13 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 1 102

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36A APPENDICES / FIGURES / TABLES I DATA of 156 PROCEDURE NO.: SHEETS 2-EOP-99 ST. LUCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 1 of 2)

A Train (q) B Train (SI)

U 1. ia LOOP has occurred, Then PERFORM BOTH of the following:

U A. ENSURE 2AB 480V Load Center is aligned to an energized bus.

U B. DISPATCH an operator to restore Instrument Air.

REFER TO Appendix H, Operation of the 2A and 2B Instrument Air Compressors.

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-14-1O) 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 U 2. ji 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-1 4-8B HCV-I 4-10 103

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36A APPENDICES I FIGURES I TABLES I DATA PROCEDURE NO.: SHEETS of 156 2-EOP-99 ST. LLJCIE UNIT 2 APPENDIX A SAMPLING STEAM GENERATORS (Page 2of2)

D 3. II CIAS or high radiation has closed the SGBD Sample Valves, Then OPEN FCV-23-7 and FCV23-.9 by PLACING the control switch to CLOSE / OVERRIDE and then to OPEN.

D 4. DIRECT Chemistry to perform S/G samples for activity and boron.

0 5. If S/Cs cannot be sampled, Then DIRECT Health Physics to conduct secondary plant local area radiation surveys.

END OF APPENDIX A 104

OPERATIONS SHIFT TURNOVER REPORT UNIT 2 CONTROL ROOM Day: Today Desk RCO: Board RCO:

Protected Train: A Unit 2 Identified RCS Leakage: 0 Unit 2 Unidentified RCS Leakage: 0 Unit 2 Scheduled Activities per the OSP:

Raise power and place the Turbine on line starting with step 6.10 of 2-GOP-201, Reactor Plant Startup Mode 2 to Mode 1.

Upcoming ECOs to Hang or Release:

None, Tech Spec Action Statement:

None.

OPS 513s:

None Locked in Annunciators:

D-19 DEH DC Supply Trouble.

D-59 Generator Condition Monitor Alarm.

K-6 CEA Auto Motion Low Power Prohibit.

K-iS Auto Withdrawal Prohibit.

L-12 Steam Bypass Demand AWP.

L-23 CEA Long Term Steady State Insertion Limit.

L-29 Loss of Load/LCL PWR DENS Channel Trip Bypassed.

L-41 Start-Up Rate Trip in Service.

M-48 20 Charging Pump SS ISOL/V2553 OVRLD.

Current Status:

2-3% power. BOC, 1622 PPM boron, MTC approximately 0. MFW and SBCS are in service. Vacuum has been drawn in the Condenser.

All Surveillances are completed and approvals given to go to Mode 1.

Reactor Engineering Guidance recommends Gp 5 at 102 at 20% Power.

Equipment Problems:

2C Charging pump QOS for repack.

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