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Initial Exam 2009-301 Final Simulator Scenarios
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Appendix D Scenario Outline Form ES-D-1 2009 NRC EXAMINATION Facility:

Catawba Nuclear Station Scenario No.: 1 Op-Test No.: 2009 D-1 --SNAP 141 Examiners:

Operators:

Unit 1 is recovering from a reactor trip 2 days ago

Conditioned power level is 100%

EFPD is 2-5 days

Boron Concentration is 1929 ppm

Your crew has stabilized the plant in Mode 2 at 1 x 10-8 amps and critical data gathering has been completed

OP/1 IA/61 00 001 (Controlling Procedure for Unit Startup), Enclosure 4.1, Unit Startup is in progress and has been completed through step 2.166

Increase power to 1 % per OP/1/A/61 001001 Event Malf. No. Event Event No. Type* Description 1 RO R Increase power to 1 % 2 RO I IIR N35 Loss of high voltage failure/re-zero SUR SRO TS 3 BOP C KC pump 1 B2 trips, 1 B1 will not start SRO TS 4 BOP C Loss of offsite power to 1 B essential trainl 1 RN-292B fails to open SRO TS 5 BOP C NC system leak (DeS) SRO TS 6 RO C Loss of normal feed to S/Gs I 1A CA pump fails to autostart 7 ALL M Steam line break on 1A S/G Additional Failures 1 BB-56A fails to auto close 1A ND pump fails to autostart

(N)ormal, (R)eactivity, (I)nstrument, (C)om ponent, (M)ajor Appendix 0 Scenario Outline Form ES-D-1 2009 NRC EXAMINATION Facility:

Catawba Nuclear Station Scenario No.: 1 Op-Test No.: 20090-1 --SNAP 141 Examiners:

Operators:

Unit 1 is recovering from a reactor trip 2 days ago

Conditioned power level is 100%

EFPD is 25 days

Boron Concentration is 1929 ppm

Your crew has stabilized the plant in Mode 2 at 1 x 10-8 amps and critical data gathering has been completed

OP/1 IN61 00 001 (Controlling Procedure for Unit Startup), Enclosure 4.1, Unit Startup is in progress and has been completed through step 2.166

Increase power to 1 % per OP/1/N61 001001 Event Malf. No. Event Event No. Type* Description 1 RO R Increase power to 1 % 2 RO I IIR N35 Loss of high voltage failurelre-zero SUR SRO TS 3 BOP C KC pump 1 B2 trips, 1 B1 will not start SRO TS 4 BOP C Loss of offsite power to 1 B essential trainl 1 RN-292B fails to open SRO TS 5 BOP C NC system leak (DeS) SRO TS 6 RO C Loss of normal feed to S/Gs I 1A CA pump fails to autostart 7 ALL M Steam line break on 1A S/G Additional Failures 1 BB-56A fails to auto close 1A NO pump fails to autostart

(N)ormal, (R )eactivity, (I)nstrument, (C)omponent, (M)ajor SIMULATOR SETUP Reset to 10-8 amps BOL snap Roll Charts Clear EHC alarm and any OACI 1.47 bypass alarms Sign off OP/1/A/61 001001 enclosure 4.1 thru step 2.166 (students start at 2.167) MALFUNCTIONS, REMOTES, and OVERRIDES Malfunction

Description Value ANN-AD11-B03 TRANSFORMER A TROUBLE ON ANN-AD11-E03 TRANSFORMER B TROUBLE ON LOA-CA015 CA66B -CA PMP #1 DISCH TO S/G A 0 ISOL VLV LOA-NV078 SEAL WATER LOW FLOW LCL ACKN REFLASH ACK (AD7,C4) MAL-CA004A FAILURE OF CA PUMP A TO START AUTO MAL-DG007B DIG 1 B OUTPUT BREAKER FAILURE OPEN MAL-ENB009A LOSS OF IIR CH 35 HI VOL T MAL-NC013B NC COLD LEG BLEAK 0.22 MAL-ND001A ND PUMP A FAILURE AUTO MAL-SM008A STM LINE BRK OUTSIDE 4.125E6 CONTAINMENT LOOP A OVR-EP051D ETB NORM FDR FRM ATD TRIP PB ON OVR-FWP018C CFPT 1A MOP 1A1 AUTO PB OFF OVR-FWP019C CFPT 1A MOP 1A2 AUTO PB OFF OVR-KC016C PMP B1 ON PB OFF OVR-KC018D PMP B2 OFF PB ON VLV-RN033A RN292B DSL GEN B HTX INLET ISOL VLV FAIL AUTO ACTIONS VLV-SG007A BB56A S/G 1 A BLDN CO NT ISOL INSIDE FAIL AUTO ACTIONS Event Ramp Delay Trigger 22 120 300 21 180 2 5 7 4 6 3 SIMULATOR SETUP Reset to 10-8 amps BOL snap Roll Charts Clear EHC alarm and any OACI 1.47 bypass alarms Sign off OP/1 IA/61 001001 enclosure 4.1 thru step 2.166 (students start at 2.167) MALFUNCTIONS, REMOTES, and OVERRIDES Malfunction

Description Value ANN-AD11-B03 TRANSFORMER A TROUBLE ON ANN-AD11-E03 TRANSFORMER B TROUBLE ON LOA-CA015 CA66B -CA PMP #1 DISCH TO S/G A 0 ISOL VLV LOA-NV078 SEAL WATER LOW FLOW LCL ACKN REFLASH ACK (AD7,C4) MAL-CA004A FAILURE OF CA PUMP A TO START AUTO MAL-DG007B DIG 1 B OUTPUT BREAKER FAILURE OPEN MAL-ENB009A LOSS OF IIR CH 35 HI VOL T MAL-NC013B NC COLD LEG BLEAK 0.22 MAL-ND001A ND PUMP A FAILURE AUTO MAL-SM008A STM LINE BRK OUTSIDE 4.125E6 CO NT AINMENT LOOP A OVR-EP051D ETB NORM FDR FRM ATD TRIP PB ON OVR-FWP018C CFPT 1A MOP 1A1 AUTO PB OFF OVR-FWP019C CFPT 1A MOP 1A2 AUTO PB OFF OVR-KC016C PMP B1 ON PB OFF OVR-KC018D PMP B2 OFF PB ON VLV-RN033A RN292B DSL GEN B HTX INLET ISOL VLV FAIL AUTO ACTIONS VLV-SG007A BB56A S/G 1A BLDN CONT ISOL INSIDE FAIL AUTO ACTIONS Event Ramp Delay Trigger 22 120 300 21 180 2 5 7 4 6 3 EVENT TRIGGERS (other than manual) Event Trigger NONE I Description CRITICAL TASKS (See attached documentation)

E-O H -Manually start at least one low-head ECCS pump before transition out of E-O. E-O 0 -Close containment isolation valves such that at least one valve is closed on each critical phase A penetration before the end of the scenario.

E-2 A -Isolate the faulted S/G before transition out of E-2. QUALITATIVE ATTRIBUTES Required Actual Total malfunctions 5-8 8 Malfunctions after EOP entry 1 -2 2 Abnormal events 2-4 5 Major transients 1 -2 1 EOPs enteredlrequiring substantive actions 1 -2 2 EOP contingencies requiring substantive actions 0-2 0 Critical tasks 2-3 3 REFERENCES OP/1/A/6100/001 (Controlling Procedure for Unit Startup), Enclosure

4.1 revision

217DCS AP/1/A/5500/016 (Malfunction of Nuclear Instrumentation System) revision 024DCS AP/1/A/5500/021 (Loss of Component Cooling) revision 036DCS AP/1/A/5500/007 (Loss of Normal Power) revision 057 AP/1/A/5500/010 (Reactor Coolant Leak) revision 051 DCS AP/1/A/5500/006 (Loss of S/G Feedwater) revision 039 EP/1/A/5000/E-0 (Reactor Trip or Safety Injection) revision 036 EP/1/A/5000/E-2 (Faulted Steam Generator Isolation) revision 012 EP/1/A/5000/ES-1.1 (Safety Injection Termination) revision 025 OTHER NOTES AND INSTRUCTIONS NOTE: The following steps are GUIDELINES.

The NRC lead examiner will direct timing of events unless otherwise noted. NOTE: Any groups or individuals (IAE, Rx Grp, RP, SOC, SWM) that are called to IIR a problem or for simple notification of a problem, repeat back the information they provide unless otherwise noted. NOTE: Any operators dispatched should repeat back information provided.

Call back items are listed below when necessary for the scenario.

EVENT TRIGGERS (other than manual) Event Trigger NONE I Description CRITICAL TASKS (See attached documentation)

E-O H -Manually start at least one low-head ECCS pump before transition out of E-O. E-O 0 -Close containment isolation valves such that at least one valve is closed on each critical phase A penetration before the end of the scenario.

E-2 A -Isolate the faulted S/G before transition out of E-2. QUALITATIVE ATTRIBUTES Required Actual Total malfunctions 5-8 8 Malfunctions after EOP entry 1 -2 2 Abnormal events 2-4 5 Major transients 1 -2 1 EOPs entered/requiring substantive actions 1 -2 2 EOP contingencies requiring substantive actions 0-2 0 Critical tasks 2-3 3 REFERENCES OP/1/A/6100/001 (Controlling Procedure for Unit Startup), Enclosure

4.1 revision

217DCS AP/1/A/5500/016 (Malfunction of Nuclear Instrumentation System) revision 024DCS AP/1/A/5500/021 (Loss of Component Cooling) revision 036DCS AP/1/A/5500/007 (Loss of Normal Power) revision 057 AP/1 /A/5500/01 0 (Reactor Coolant Leak) revision 051 DCS AP/1/A/5500/006 (Loss of S/G Feedwater) revision 039 EP/1/A/5000/E-0 (Reactor Trip or Safety Injection) revision 036 EP/1/A/5000/E-2 (Faulted Steam Generator Isolation) revision 012 EP/1/A/5000/ES-1.1 (Safety Injection Termination) revision 025 OTHER NOTES AND INSTRUCTIONS NOTE: The following steps are GUIDELINES.

The NRC lead examiner will direct timing of events unless otherwise noted. NOTE: Any groups or individuals (IAE, Rx Grp, RP, SOC, SWM) that are called to IIR a problem or for simple notification of a problem, repeat back the information they provide unless otherwise noted. NOTE: Any operators dispatched should repeat back information provided.

Call back items are listed below when necessary for the scenario.

Event 1 -Increase power to 1% This event will be entered once the crew has taken turnover and evaluated plant conditions.

Anytime after a stable positive startup rate is achieved, the next event can be started. Event 2 -IIR N35 Loss of high voltage failure. SRO Technical Specification Initiating Cue: 1AD-2, C/1, N35 failed to bottom of scale When AP/1/A/5500/016 is completed, and the SRO has completed consulting Technical Specifications, the next event can be inserted TS -3.3.1 Item 4 Condition F Event 3 -KC pump 1B2 trips. 1B1 will not start. SRO Technical Specification Initiating Cues:

1 AD-6, C/1 -C/4, D/1 -D/4, E/1 -E/4 and others When AP/1/A/5500/021 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

If an operator is dispatched to checkout 1A2 KC pump and breaker, after a few minutes state "nothing abnormal was noted". TS -3.7.7 Condition A Event 4 -Loss of offsite power to 1 B essential train/1 RN-292B fails to open. SRO Technical Specification Initiating Cue: Multiple electrical alarms on 1AD-11, UV status lights for 1 ETB on 1SI-14 When operator is dispatched to manually open 1 RN-292B, after 3 minutes call back and state "1RN-292B cannot be opened". When called by the crew to open 1 EDF-F01 F and load shed 1 ETB, RUN SCHEDULE Load_Shed_1 ETB.sch (under Operations folder). Call back when schedule is complete and state: "1 B DIG Load sequencer has been de-energized and 1 ETB has been load shed per Enclosure

9. No lockout relay targets are picked up." When step 22 of AP/1/A/5500/007 case 2 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

TS -3.4.9 Condition B 3.8.1 Conditions A, B, D, F 3.8.9 Condition A 3.7.8 Condition A Event 1 -Increase power to 1 % This event will be entered once the crew has taken turnover and evaluated plant conditions.

Anytime after a stable positive startup rate is achieved, the next event can be started. Event 2 -IfR N35 Loss of high voltage failure. SRO Technical Specification Initiating Cue: 1 AD-2, C/1, N35 failed to bottom of scale When AP/1/A155001016 is completed, and the SRO has completed consulting Technical Specifications, the next event can be inserted TS -3.3.1 Item 4 Condition F Event 3 -KC pump 1B2 trips. 1B1 will not start. SRO Technical Specification Initiating Cues:

1 AD-6, C/1 -C/4, D/1 -D/4, E/1 -E/4 and others When AP/1/A155001021 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

If an operator is dispatched to checkout 1A2 KC pump and breaker, after a few minutes state "nothing abnormal was noted". TS -3.7.7 Condition A Event 4 -Loss of offsite power to 1 B essential train/1 RN-292B fails to open. SRO Technical Specification Initiating Cue: Multiple electrical alarms on 1AD-11, UV status lights for 1 ETB on 1SI-14 When operator is dispatched to manually open 1 RN-292B, after 3 minutes call back and state "1RN-292B cannot be opened". When called by the crew to open 1 EDF-F01 F and load shed 1 ETB, RUN SCHEDULE Load_Shed_1 ETB.sch (under Operations folder). Call back when schedule is complete and state: "1 B DIG Load sequencer has been de-energized and 1 ETB has been load shed per Enclosure

9. No lockout relay targets are picked up." When step 22 of AP/1/A155001007 case 2 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

TS -3.4.9 Condition B 3.8.1 Conditions A, B, D, F 3.8.9 Condition A 3.7.8 Condition A

Event S -NC system leak. SRO Technical Specification Initiating Cue: 1AD-13, Al7, F/5 When a leakage rate has been determined, and step 11 of AP/1/Al5500/010 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

If annunciator for seal water low flow comes in and directed by the crew, insert EVENT 21. Call back when alarm is cleared and state "Seal water low flow has been locally acknowledged." TS -3.4.13 Condition A, 3.6.4 Condition A, SLC 16.7-9 Condition A,B Event 6 -Loss of normal feed to S/Gs/1A CA pump fails to autostart Initiating cue: 1AD-1 Al6 and 1AD-5 Al1, Al4 When step 5 of AP/1/Al5500/006 is read, the next event should be inserted.

This will begin the major event. Event 7 -Steam line break on 1A S/G Initiating cue: 1AD-3, Al1 This is the major event. Additional failures

1 BB-56A fails to auto close

1A ND pump fails to autostart In E-2 Step 7.c.3) RNO, when dispatched to close 1CA-66B, insert EVENT 22. Call back when 1CA-668 is closed and state "1CA-668 is closed." In E-2, Step1 O.c if asked to sample S/Gs for activity state "I will sample Unit 1 S/Gs for activity and report the results back in about an hour." In E-2, Step 1 O.c if asked to frisk cation columns for activity state "I will frisk Unit 1 cation columns for activity and report back the results in a few minutes. Call back in S minutes and state "Unit 1 cation columns indicate no abnormal activity." Scenario End Point ANYTIME AFTER NV SII FLOWPATH IS ISOLATED PER STEP 9 of EP/1/S000/ES-1.1.

Event S -NC system leak. SRO Technical Specification Initiating Cue: 1AD-13, Al7, F/5 When a leakage rate has been determined, and step 11 of AP/1/Al5500/010 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

If annunciator for seal water low flow comes in and directed by the crew, insert EVENT 21. Call back when alarm is cleared and state "Seal water low flow has been locally acknowledged." TS -3.4.13 Condition A, 3.6.4 Condition A, SLC 16.7-9 Condition A,B Event 6 -Loss of normal feed to S/Gs/1A CA pump fails to autostart Initiating cue: 1AD-1 Al6 and 1AD-5 Al1, Al4 When step 5 of AP/11A15500/006 is read, the next event should be inserted.

This will begin the major event. Event 7 -Steam line break on 1A S/G Initiating cue: 1 AD-3, Al1 This is the major event. Additional failures

1 BB-56A fails to auto close

1A ND pump fails to autostart In E-2 Step 7.c.3) RNO, when dispatched to close 1 CA-66B, insert EVENT 22. Call back when 1CA-668 is closed and state "1CA-668 is closed." In E-2, Step10.c if asked to sample S/Gs for activity state "I will sample Unit 1 S/Gs for activity and report the results back in about an hour." In E-2, Step 1 O.c if asked to frisk cation columns for activity state "I will frisk Unit 1 cation columns for activity and report back the results in a few minutes. Call back in S minutes and state "Unit 1 cation columns indicate no abnormal activity." Scenario End Point ANYTIME AFTER NV SII FLOWPATH IS ISOLATED PER STEP 9 of EP/1/S000/ES-1.1.

CREW INFORMATION

Unit 1 is recovering from a reactor trip 2 days ago

Conditioned power level is 100%

EFPD is 25 days

Boron Concentration is 1929 ppm

Your crew has stabilized the plant in Mode 2 at 1 x 10-8 amps and critical data gathering has been completed

OP/1/Al6100 001 (Controlling Procedure for Unit Startup), Enclosure 4.1, Unit Startup is in progress and has been completed through step 2.166

Increase power to 1 % per OP/1/Al61 00/001 CREW INFORMATION

Unit 1 is recovering from a reactor trip 2 days ago

Conditioned power level is 100%

EFPD is 25 days

Boron Concentration is 1929 ppm

Your crew has stabilized the plant in Mode 2 at 1 x 10-8 amps and critical data gathering has been completed

OP/1/A/61 00 001 (Controlling Procedure for Unit Startup), Enclosure 4.1, Unit Startup is in progress and has been completed through step 2.166

Increase power to 1 % per OP/1/A/61 001001

, ' Duke Energy Procedure No. Catawba Nuclear Station OP/I/N6 1 00100 1 Revision No. Controlling Procedure For Unit Startup 217 Des Continuous Use Electronic Reference No. CN005FK3 CD Duke Energy Procedure No. Catawba Nuclear Station OP/I/A/61001001 Revision No. Controlling Procedure For Unit Startup 217 Des Continuous Use Electronic Reference No. CNOO5FK3 CD Controlling Procedure For Unit Startup 1. Purpose OP!l/A/6100/001 Page 2 of7 1.1 To outline the steps necessary to take the plant from cold shutdown to 15% full power. 1.2 To provide a procedure for startup from any shutdown condition.

2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing boron concentration, temperature, steam flow, and power level. (R.M.) 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 2.2.2 Overlap between the source and intermediate ranges and between intermediate and the power ranges shall NOT be less than 1 decade. 2.2.3 During Modes 1 & 2 and prior to diluting for ECB, the PZR boron concentration shall be within +/- 50 ppm of the NC System boron concentration.

During Modes 3, 4,5,6, or No Mode, PZR boron concentration is NOT required to be maintained relative to the NC System provided the following conditions are met:

PZR outflow can be verified

NC System boron concentration>

100 ppm over the r-equired SDM 2.2.4 With the reactor critical at low power, steam withdrawal from the S/Gs may be used only for auxiliary uses (i.e., warm steam lines, operate air ejectors, supply gland steam, some turbine warming) or for controlling heatup rate via the steam dumping system. Use caution to ensure the steam drain is slow. 2.2.5 Ensure reactivity management guidance outlined in SOMP 01-02 (Reactivity Management) is followed during reactor startup and power operation.

Controlling Procedure For Unit Startup 1. Purpose OP!l/A/6100/001 Page 2 of7 1.1 To outline the steps necessary to take the plant from cold shutdown to 15% full power. 1.2 To provide a procedure for startup from any shutdown condition.

2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing boron concentration, temperature, steam flow, and power level. (R.M.) 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.2 Overlap between the source and intermediate ranges and between intermediate and the power ranges shall NOT be less than 1 decade. 2.2.3 During Modes 1 & 2 and prior to diluting for ECB, the PZR boron concentration shall be within +/- 50 ppm of the NC System boron concentration.

During Modes 3, 4, 5, 6, or No Mode, PZR boron concentration is NOT required to be maintained relative to the NC System provided the following conditions are met:

PZR outflow can be verified

NC System boron concentration>

100 ppm over the required SDM 2.2.4 With the reactor critical at low power, steam withdrawal from the S/Gs may be used only for auxiliary uses (i.e., warm steam lines, operate air ejectors, supply gland steam, some turbine warming) or for controlling heatup rate via the steam dumping system. Use caution to ensure the steam drain is slow. 2.2.5 Ensure reactivity management guidance outlined in SOMP 01-02 (Reactivity Management) is followed during reactor startup and power operation.

BE SIGNED OFF AND ARE NOT INCLUDED HERE. Enclosure 4.1 Unit Startup OP/IIA161 001001 Page 50 of66 2.166 Ensure Steps 2.137 -2.139 have been completed to ensure automatic steam dump control has been established.

--2.167 Will pull rods to have a positive stable S/U rate Per L&P 0.5 is limit. See L&P. __ 2.168 Begin reviewing the items listed in Step 2.176 so that Unit 1 will NOT enter Mode 1 until all substeps of2.176 are signed off. --2.169 IF necessary, continue heatup to no load T-AVG (S57°F). --2.170 Increase S/G blowdown flowrate as recommended by Secondary Chemistry for S/G chemistry control and within guidelines ofOPIlIAl62501008 (Steam Generator Blowdown). (R.M.) Person making recommendation'---

________ _ __ 2.171 Coordinate with Chemistry to determine when blowdown flowrate can be subsequently reduced. * ........ _ .. _ ...........................................................................

_....... . ...... _ ...... _ .............

_ .... _. ALL PREVIOUS STEPS WILL BE SIGNED OFF AND ARE NOT INCLUDED HERE. Enclosure 4.1 Unit Startup OP/I/A/61001001 Page 50 of66 2.166 Ensure Steps 2.137 -2.139 have been completed to ensure automatic steam dump control has been established.

N e);rE: 1.

3. ]he",thrQ:J]lijJ,g .as .. the .

QJ Will pull rods to have a positive stable S/U raTel --(R*M*) Per L&P 0.5 is limit. See L&P. I __ 2.168 Begin reviewing the items listed in Step 2.176 so that Unit 1 will NOT enter Mode 1 until all substeps of2.176 are signed off. --2.169 IF necessary, continue heatup to no load T -A VG (557°F). --2.170 Increase S/G b10wdown flowrate as recommended by Secondary Chemistry for S/G chemistry control and within guidelines ofOP/l/A/62501008 (Steam Generator Blowdown). (R.M.) Person making recommendation

_________

_ __ 2.171 Coordinate with Chemistry to determine when b10wdown flowrate can be subsequently reduced.

Initiating Cue: 1AD-2, C/1, N35 failed to bottom of scale Initiating Cue: 1AD-2, C/1, N35 failed to bottom of scale CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A155001016 1 of 14 Rev 24 A. Purpose

To verify the proper response in the event of a nuclear instrumentation malfunction.

B. Symptoms Case I. Source Range Malfunction

Indication lost or erratic

1AD-2, D/1 "SIR HI VOLTAGE FAILURE" -LIT

1AD-2, D/3 "SIR HI FLUX LEVEL AT SHUTDOWN" -LIT

1AD-2, D/4 "SIR HI FLUX LEVEL AT SHUTDOWN" -LIT. Case II. Audio Count Rate Malfunction

Audible count rate lost. Case III. Intermediate Range Malfunction

1AD-2, C/2 "I/R COMPENSATING VOLTAGE FAILURE" -LIT

1AD-2, C/3 "IIR HI FLUX LEVEL ROD STOP" -LIT

SIR failure to re-energize during shutdown.

Case IV. Power Range Malfunction

Indication lost or erratic

1AD-2, Al1 "P/R HI NEUTRON FLUX RATE ALERT" -LIT

1AD-2, Al2 "P/R HI NEUTRON FLUX LO SETPOINT ALERT" -LIT

1AD-2, Al3 "P/R HI NEUTRON FLUX HI SETPOINT ALERT" -LIT

1AD-2, 8/3 "COMPARATOR P/R CHANNEL DEVIATION" -LIT

1AD-2, 8/5 "P/R HI VOLTAGE FAILURE" -LIT

1AD-2, E/8 "OVER POWER ROD STOP" -LIT CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A155001016 1 of 14 Rev 24 A. Purpose

To verify the proper response in the event of a nuclear instrumentation malfunction.

B. Symptoms Case I. Source Range Malfunction

Indication lost or erratic

1AD-2, D/1 "SIR HI VOLTAGE FAILURE" -LIT

1AD-2, D/3 "SIR HI FLUX LEVEL AT SHUTDOWN" -LIT

1AD-2, D/4 "SIR HI FLUX LEVEL AT SHUTDOWN" -LIT. Case II. Audio Count Rate Malfunction

Audible count rate lost. Case III. Intermediate Range Malfunction

Indi¢c}tion IRS! or ett.3'tic 1AR"2,G/1"IlRhIJWOL TI-iGE lIlJ

1AD-2, C/2 "I/R COMPENSATING VOLTAGE FAILURE" -LIT

1AD-2, C/3 "I/R HI FLUX LEVEL ROD STOP" -LIT

SIR failure to re-energize during shutdown.

Case IV. Power Range Malfunction

Indication lost or erratic

1AD-2, Al1 "P/R HI NEUTRON FLUX RATE ALERT" -LIT

1AD-2, Al2 "P/R HI NEUTRON FLUX LO SETPOINT ALERT" -LIT

1AD-2, Al3 "P/R HI NEUTRON FLUX HI SETPOINT ALERT" -LIT

1AD-2, 8/3 "COMPARATOR P/R CHANNEL DEVIATION" -LIT

1AD-2, 8/5 "P/R HI VOLTAGE FAILURE" -LIT

1AD-2, E/8 "OVER POWER ROD STOP" -LIT CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/5500/016 Case III 8 of 14 Intermediate Range Malfunction Rev 24 OCt ACTION/EXPECTED RESPONSE c. Operator Actions 1. 3. .'iliII'i\lg:35' OR

N-36. 4.

RESPONSE NOT OBTAINED Will insert rods to achieve a SUR of 0 _ Adjust turbine load to maintain T-Avg at T-Ref. CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/5500/016 Case III 8 of 14 Intermediate Range Malfunction Rev 24 ACTION/EXPECTED RESPONSE C. Operator Actions 1.

10%. 3.

I R 0 RO OR

N-36. 4 f6l1QWing: , _

i\1BYRASS" f I Hgpt Q:D ..

_ 0.

-:LIJ. I RESPONSE NOT OBTAINED Will insert rods to achieve a SUR of 0 _ Adjust turbine load to maintain T-Avg at T-Ref.

CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM AP/1/N55001016 Case III Intermediate Range Malfunction ACTION/EXPECTED RESPONSE 8. 10. 11.

_*fI:!IIB

..

13. RESPONSE NOT OBTAINED ITEM 4 Condition F INone PAGE NO. 9 of 14 Rev 24 CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM AP/1/A/SSOOI016 Case III Intermediate Range Malfunction ACTION/EXPECTED RESPONSE 9 malfUnclion;'

1 O.§jh,sure 3.3;1 (Reactor (RI§)

_ It;'REFER TOij.!i:(Q/AlSOOQ/001, ( Classificatidb'91Emer:9?ncy)

_ REFER

). 12.

RESPONSE NOT OBTAINED ITEM 4 Condition F one in 'a.lrippe(f; a 'reactor!trip

13.

to ENe!: PAGE NO. 9 of 14 Rev 24 Initiating Cues: 1AO-6, C/1 -C/4, 0/1 -0/4, E/1 -E/4 1AO-20, Al1 and 1AO-21, Al1 and others Initiating Cues: 1AO-6, C/1 -C/4, 0/1 -0/4, E/1 -E/4 1AO-20, Al1 and 1AO-21, Al1 and others CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/N55001021 1 of 39 Rev 36 A. Purpose

To verify proper response in the event of a loss of Component Cooling. B. Symptoms

1AD-10, Al1 "KC SURGE TANK A LO-LO LEVEL" -LIT

1AD-10, Al2 "KC SURGE TANK B LO-LO LEVEL" -LIT

1AD-9, F/5 "KC TRAIN A SINGLE PUMP RUNOUT" -LIT

1AD-9, F/6 "KC TRAIN B SINGLE PUMP RUNOUT" -LIT

1AD-9, F/7 "KC TRAIN A TWO PUMP RUNOUT" -LIT

1AD-9, F/8 "KC TRAIN B TWO PUMP RUNOUT" -LIT

High temperature alarms on components supplied by KC System. CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/5500/021 1 of 39 Rev 36 A. Purpose

To verify proper response in the event of a loss of Component Cooling. B. Symptoms

1AD-10, Al1 "KC SURGE TANK A LO-LO LEVEL" -LIT

1AD-10, Al2 "KC SURGE TANK B LO-LO LEVEL" -LIT

1AD-9, FI5 "KC TRAIN A SINGLE PUMP RUNOUT" -LIT

1AD-9, F/6 "KC TRAIN B SINGLE PUMP RUNOUT" -LIT

1AD-9, F/7 "KC TRAIN A TWO PUMP RUNOUT" -LIT

1AD-9, FIB "KC TRAIN B TWO PUMP RUNOUT" -LIT

High temperature alarms on components supplied by KC System.

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/N55001021 2 of 39 Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions BOP DOES THIS PROCEDURE 1 B 1 KC pump will not start and the crew will have to start an A train pump. This will require action in Step 14. b. IF no KC pump can be started, THEN perform the following:

_ 1) IF SII has actuated on either unit, THEN GO TO Step 4. CAUTION YO can only supply one Unit's NV pump at a time. _ 2) Determine which unit will receive alternate NV pump cooling from YD. _ 3) IF Unit 2 selected to receive YD cooling to 2A NV pump, THEN GO TO Step 4. (RNO continued on next page) CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/N55001021 2 of 39 Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions BOP DOES THIS PROCEDURE to. re§lQre tiQ;putDP

..

6'r::NV pIlJii'tp**seals

resultiijg;jn. 1 B 1 KC pump will not start and the crew will have to start an A train pump. This will require action in Step 14.

_

Stattfiit.!e""sl

b. IF no KC pump can be started, THEN perform the following:

_ 1) IF SII has actuated on either unit, THEN GO TO Step 4. CAUTION YO can only supply one Unit's NV pump at a time. _ 2) Determine which unit will receive alternate NV pump cooling from YD. _ 3) IF Unit 2 selected to receive YD cooling to 2A NV pump, THEN GO TO Step 4. (RNO continued on next page)

CNS LOSS OF COMPONENT COOLING PAGE NO. APf1fAl5500f021 ACTION/EXPECTED RESPONSE 2. (Continued) 3 of 39 Rev 36 DCE RESPONSE NOT OBTAINED

NV pumps may be started without regard to cooling water alignment.

Operating NV Pump will reach high temperature conditions in approximately 15 minutes with no cooling water. _ 4) Dispatch operator to align YD cooling to NV pump 1A. REFER TO Enclosure 4 (Alternate Cooling To NV Pump 1A). _ 5) Maximize NV pump run time. REFER TO Enclosure 7 (Maximize NV Pump Run Time). _ 6) IF AT ANY TIME an Sfl occurs on either unit, THEN notify dispatched operator to realign NV Pump 1 A cooling to normal. REFER TO Enclosure 4 (Alternate Cooling To NV Pump 1A). _ 7) GO TO Step 4. CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A155001021 ACTION/EXPECTED RESPONSE 2. (Continued) 3 of 39 Rev 36 DCS RESPONSE NOT OBTAINED

NV pumps may be started without regard to cooling water alignment.

Operating NV Pump will reach high temperature conditions in approximately 15 minutes with no cooling water. _ 4) Dispatch operator to align YD cooling to NV pump 1A. REFER TO Enclosure 4 (Alternate Cooling To NV Pump 1A). _ 5) Maximize NV pump run time. REFER TO Enclosure 7 (Maximize NV Pump Run Time). _ 6) IF AT ANY TIME an SII occurs on either unit, THEN notify dispatched operator to realign NV Pump 1A cooling to normal. REFER TO Enclosure 4 (Alternate Cooling To NV Pump 1A). _ 7) GO TO Step 4.

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/Al5500/021 ACTION/EXPECTED RESPONSE If LIT, will go to RNa, But will NOT do actions because one KC pump will be on already. 4 of 39 Rev 36 RESPONSE NOT OBTAINED IF KC flow unavailable to letdown HX, THEN isolate letdown as follows: a. Ensure the following valves -CLOSED:

1 NV -1 OA (Letdn Orif 1 B Otlt Cant Isol)

1 NV-11A (Letdn Orif 1 C Otlt Cant Isol)

1 NV-13A (Letdn Orif 1A Otlt Cant Isol). b. Control charging to stabilize Pzr level at program level while maintaining seal injection flow. c. Ensure 1 NV-153A (Letdn Hx Otlt 3-Way VI v) -ALIGNED TO VCT. d. Ensure 1 NV-172A (3-Way Divert To VCT-RHT) -ALIGNED TO RHT. e. Ensure VCT makeup -IN AUTOMATIC

f. WHEN time and manpower permit, THEN REFER TO AP/1/Al5500/012 (Loss Of Charging Or Letdown).

g. IF AT ANY TIME the following conditions exist:

VCT level -LESS THAN 23%

PZR level -GREATER THAN 85% AND INCREASING.

_ THEN GO TO Enclosure 8 (Rx Trip Sequence).

h. GO TO Step 6. CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/55001021 ACTION/EXPECTED RESPONSE _ *. ,1AQ;1,F/3 "lil='POl)!

HX019T;L!=T'}:I1 If LIT, will go to RNa, But will NOT do actions because one KC pump will be on already. 4 of39 Rev 36 DCt RESPONSE NOT OBTAINED IF KC flow unavailable to letdown HX, THEN isolate letdown as follows: a. Ensure the following valves -CLOSED:

1 NV-1 OA (Letdn Orif 1 B Otlt Cant Isol)

1NV-11A (Letdn Orif 1C Otlt Cant 1501)

1 NV -13A (Letd n Orif 1 A Otlt Cant Isol). b. Control charging to stabilize Pzr level at program level while maintaining seal injection flow. c. Ensure 1 NV-153A (Letdn Hx Otlt 3-Way Vlv) -ALIGNED TO VCT. d. Ensure 1 NV-172A (3-Way Divert To VCT-RHT) -ALIGNED TO RHT. e. Ensure VCT makeup -IN AUTOMATIC

f. WHEN time and manpower permit, THEN REFER TO AP/1/A/55001012 (Loss Of Charging Or Letdown).

g. IF AT ANY TIME the following conditions exist:

VCT level -LESS THAN 23%

PZR level -GREATER THAN 85% AND INCREASING.

_ THEN GO TO Enclosure 8 (Rx Trip Sequence).

h. GO TO Step 6.

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/11A155001021 ACTION/EXPECTED RESPONSE 7.

50f39 Rev 36 DCS RESPONSE NOT OBTAINED _ GO TO Step 8. _ IF KC pump(s) damaged by fire, THEN notify IAE to repair cables to pumps needed for recovery.

REFER TO IP/11A13890/027A (Fire Damage Control Procedure).

Perform the following:

a. Ensure the following valves -OPEN:

1 KC-425A (NC Pumps Ret Hdr Cont Isol)

1 KC-3388 (NC Pumps Sup Hdr Cont Isol)

1 KC-4248 (NC Pumps Ret Hdr Cont Isol). (RNO continued on next page) CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/Al5500/021 ACTION/EXPECTED RESPONSE 5.

Ql.HL:;E[

HI TI;MP"

7.

_

Al1jflKC

-DJ¥F.K _

HQg::FLOWi fO 5 of 39 Rev 36 RESPONSE NOT OBTAINED _ GO TO Step 8. _ IF KC pump(s) damaged by fire, THEN notify IAE to repair cables to pumps needed for recovery.

REFER TO IP/1/A13890/027A (Fire Damage Control Procedure).

Perform the following:

a. Ensure the following valves -OPEN:

1 KC-425A (NC Pumps Ret Hdr Cont Isol)

1 KC-3388 (NC Pumps Sup Hdr Cont 1501)

1 KC-4248 (NC Pumps Ret Hdr Cont Isol). (RNO continued on next page)

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A155001021 ACTION/EXPECTED RESPONSE 8. (Continued) 60f39 Rev 36 RESPONSE NOT OBTAINED b. IF AT ANY TIME any of the following conditions are met:

Time since loss of KC -GREATER THAN 10 MINUTES OR _

Any NC pump trip criteria from Enclosure 1 (Foldout Page) is met THEN perform the following:

1) IF letdown is isolated, THEN: a) Ensure NV pump suction aligned to FWST as follows: _ (1) 1 NV-252A (NV Pumps Suct From FWST) -OPEN _ (2) 1 NV-2538 (NV Pumps Suct From FWST) -OPEN _ (3) 1 NV-188A (VCT Otlt CLOSED _ (4) 1NV-1898 (VCT Otlt CLOSED. _ b) WHEN Reactor is tripped, THEN attempt to establish and maintain a slow cooldown as required to maintain PZR level. _ 2) Ensure steam dumps -IN PRESSURE MODE. _ 3) Ensure the Reactor -TRIPPED. (RNO continued on next page) CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/55001021 ACTION/EXPECTED RESPONSE 8. (Continued) 60f39 Rev 36 RESPONSE NOT OBTAINED b. IF AT ANY TIME any of the following conditions are met:

Time since loss of KC -GREATER THAN 10 MINUTES _

Any NC pump trip criteria from Enclosure 1 (Foldout Page) is met THEN perform the following:

1) IF letdown is isolated, THEN: a) Ensure NV pump suction aligned to FWST as follows: _ (1) 1 NV-252A (NV Pumps Suct From FWST) -OPEN _ (2) 1 NV-2538 (NV Pumps Suct From FWST) -OPEN _ (3) 1 NV-188A (VCT Otlt CLOSED _ (4) 1NV-1898 (VCT Otlt CLOSED. _ b) WHEN Reactor is tripped, THEN attempt to establish and maintain a slow cooldown as required to maintain PZR level. _ 2) Ensure steam dumps -IN PRESSURE MODE. _ 3) Ensure the Reactor -TRIPPED. (RNO continued on next page)

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/5500/021 ACTION/EXPECTED RESPONSE 8. (Continued) 7 of 39 Rev 36 RESPONSE NOT OBTAINED 4) WHEN reactor power less than 5%, THEN perform the following:

_ a) Trip all NC pumps. _ b) Ensure the normal spray valve associated with the tripped NC pump(s) -IN MANUAL AND CLOSED. _ 5) Secure any dilutions in progress.

6) IF the reactor trip breakers were closed, THEN perform one of the following while continuing with this procedure as time and conditions allow: _. IF above P-11, THEN GO TO EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).

OR

IF below P-11, THEN GO TO AP/1/A/5500/005 (Reactor Trip Or Inadvertent S/I Below P-11). CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/55001021 ACTION/EXPECTED RESPONSE 8. (Continued) 7 of 39 Rev 36 RESPONSE NOT OBTAINED 4) WHEN reactor power less than 5%, THEN perform the following:

_ a) Trip all NC pumps. _ b) Ensure the normal spray valve associated with the tripped NC pump(s) -IN MANUAL AND CLOSED. _ 5) Secure any dilutions in progress.

6) IF the reactor trip breakers were closed, THEN perform one of the following while continuing with this procedure as time and conditions allow:

IF above P-11, THEN GO TO EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).

OR

IF below P-11, THEN GO TO AP/1/A/55001005 (Reactor Trip Or Inadvertent S/I Below P-11).

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/N55001021 8 of39 Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED a.

b. c. The KC non-essential header valves can be reopened when the appropriate train's level switch is reset. This should occur between 40% and 48% KC surge tank level. a. WHEN OAC alarm C1 D2215 (KC Train A Low-Low Level Surge Tank Isol) is "NOT ACTUATED", THEN ensure the affected valve(s) are open. The KC non-essential header valves can be reopened when the appropriate train's level switch is reset. This should occur between 40% and 48% KC surge tank level. b. WHEN OAC alarm C1D2214 (KC Train B Low-Low Level Surge Tank Isol) is "NOT ACTUATED", THEN ensure the affected valve(s) are open. c. IF KC pump(s) damaged by fire, THEN notify IAE to repair cables to pumps needed for recovery.

REFER TO IP/1/N38901027A (Fire Damage Control none will be needed Procedure).

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/N55001021 ACTION/EXPECTED RESPONSE 9.

a.

<@I1!RNf I§'QJ)

Isol}

IsgJ) 1 K* 1""2'1'/\

'/1V U' x*'*BI""*g*'*

.. *:* .. o*n** I::;,,'s'" R"e" t :erd'" r'" * "u <

.. ,.<ttJ, <:

b.

.. .I.son

1.KC-'18B B f:RX>BUir;"Nbrl-:l2:Ss Ret;fldt:: ) ...... *d\' ....... ", ** Qt... , .... ;,", '", ..... ,'" ,,'

Hdt

_

1591). c. ,KQjQJ;td$'

none will be needed RESPONSE NOT OBTAINED The KC non-essential header valves can be reopened when the appropriate train's level switch is reset. This should occur between 40% and 48% KC surge tank level. 8 of39 Rev 36 a. WHEN OAC alarm C1 D2215 (KC Train A Low-Low Level Surge Tank Isol) is "NOT ACTUATED", THEN ensure the affected valve(s) are open. The KC non-essential header valves can be reopened when the appropriate train's level switch is reset. This should occur between 40% and 48% KC surge tank level. b. WHEN OAC alarm C1D2214 (KC Train B Low-Low Level Surge Tank Isol) is "NOT ACTUATED", THEN ensure the affected valve(s) are open. c. IF KC pump(s) damaged by fire, THEN notify IAE to repair cables to pumps needed for recovery.

REFER TO IP/1/N38901027A (Fire Damage Control Procedure).

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/N55001021 ACTION/EXPECTED RESPONSE 10.

11. Verify at least one KC surge tank above 10-10 level as follows: _. 1AD-10, N1 "KC SURGE TANK A LO-LO LEVEL" -DARK OR

1AD-10, N2 "KC SURGE TANK B LO-LO LEVEL" -DARK. 90f39 Rev 36 DC!: RESPONSE NOT OBTAINED a. Perform the following:

1) Dispatch operator to initiate makeup to surge tank(s) by opening the appropriate valve(s):

_. 1KC-107 (1A KC Surge Tank YM M/U) (AB-601, PP-59, Rm 500) OR _. 1KC-111 (1B KC Surge Tank YM M/U) (AB-601, PP-59, Rm 500). _ 2) Dispatch operators to locate and isolate KC System leakage. _ 3) WHEN the affected KC surge tank(s) level is greater than or equal to 90%, THEN notify dispatched operator to secure makeup. _ 4) GO TO Step 11. Perform the following:

a. Verify the following:

_ 1) Both Unit 1 RN Essential Headers -PRESSURIZED.

_ 2) IF only one RN Essential Header is pressurized, THEN use it for surge tank makeup. _ 3) IF AT ANY TIME the RN Essential Header being used for makeup becomes depressurized, THEN notify dispatched operator to secure makeup from RN. (RNO continued on next page) CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/N55001021 ACTION/EXPECTED RESPONSE 1 O.

_ at

11. Verify at least one KC surge tank above 10-10 level as follows: _. 1AD-10, N1 "KC SURGE TANK A LO-LO LEVEL" -DARK OR

1AD-10, N2 "KC SURGE TANK B LO-LO LEVEL" -DARK. 9 of 39 Rev 36 DC!: RESPONSE NOT OBTAINED a. Perform the following:

1) Dispatch operator to initiate makeup to surge tank(s) by opening the appropriate valve( s): _. 1KC-107 (1A KC Surge Tank YM M/U) (AB-601, PP-59, Rm 500) OR _. 1 KC-111 (1 B KC Surge Tank YM M/U) (AB-601, PP-59, Rm 500). _ 2) Dispatch operators to locate and isolate KC System leakage. _ 3) WHEN the affected KC surge tank(s) level is greater than or equal to 90%, THEN notify dispatched operator to secure makeup. _ 4) GO TO Step 11. Perform the following:

a. Verify the following:

_ 1) Both Unit 1 RN Essential Headers -PRESSURIZED.

_ 2) IF only one RN Essential Header is pressurized, THEN use it for surge tank makeup. _ 3) IF AT ANY TIME the RN Essential Header being used for makeup becomes depressurized, THEN notify dispatched operator to secure makeup from RN. (RNO continued on next page)

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/11A155001021 ACTION/EXPECTED RESPONSE 11. (Continued) 10 of 39 Rev 36 RESPONSE NOT OBTAINED Preference should be given to the surge tank with the highest stable level and available pumps. b. Dispatch operator to makeup to available train of KC from YM and RN. REFER TO Enclosure 5 (Surge Tank Makeup). c. Dispatch operators to locate and isolate KC System leakage. d. Notify Chemistry of RN makeup to KC System. e. WHEN the KC surge tank level is above the 10-10 level setpoint, THEN: _ 1) Ensure the KC pumps on the affected train -ON. (RNO continued on next page) CNS LOSS OF COMPONENT COOLING PAGE NO. AP/11 Al55001021 ACTION/EXPECTED RESPONSE 11. (Continued) 10 of 39 Rev 36 RESPONSE NOT OBTAINED Preference should be given to the surge tank with the highest stable level and available pumps. b. Dispatch operator to makeup to available train of KC from YM and RN. REFER TO Enclosure 5 (Surge Tank Makeup). c. Dispatch operators to locate and isolate KC System leakage. d. Notify Chemistry of RN makeup to KC System. e. WHEN the KC surge tank level is above the 10-10 level setpoint, THEN: _ 1) Ensure the KC pumps on the affected train -ON. (RNO continued on next page)

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/55001021 ACTION/EXPECTED RESPONSE 11. (Continued)

RESPONSE NOT OBTAINED The KC non-essential header valves can be reopened when the appropriate train's level switch is reset. This should occur between 40% and 48% KC surge tank level. 11 of 39 Rev 36 2) Open the non-essential header isolation valves for the affected train as follows:

Train A:

1 KC-230A (Rx Bldg Non-Ess Hdr Isol)

1 KC-3A (Rx Bldg Non-Ess Ret Hdr Isol)

1 KC-50A (Aux Bldg Non-Ess Hdr Isol)

1KC-1A (Aux Bldg Non-Ess Ret Hdr Isol). OR

Train B:

1 KC-228B (Rx Bldg Non-Ess Hdr Isol)

1 KC-18B (Rx Bldg Non-Ess Ret Hdr Isol)

1 KC-53B (Au x Bldg Non-Ess Hdr Isol)

1 KC-2B (Au x Bldg Non-Ess Ret Hdr Isol). f. WHEN one train's non-essential header isolation valves are opened, THEN perform Steps 12 through 13. (RNO continued on next page) CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/5500/021 ACTION/EXPECTED RESPONSE 11. (Continued)

RESPONSE NOT OBTAINED The KC non-essential header valves can be reopened when the appropriate train's level switch is reset. This should occur between 40% and 48% KC surge tank level. 11 of 39 Rev 36 2) Open the non-essential header isolation valves for the affected train as follows:

Train A:

1 KC-230A (Rx Bldg Non-Ess Hdr Isol)

1 KC-3A (Rx Bldg Non-Ess Ret Hdr Isol)

1 KC-50A (Aux Bldg Non-Ess Hdr Isol)

1KC-1A (Aux Bldg Non-Ess Ret Hdr Isol). OR

Train B:

1 KC-228B (Rx Bldg Non-Ess Hdr Isol)

1 KC-18B (Rx Bldg Non-Ess Ret Hdr Isol)

1 KC-53B (Aux Bldg Non-Ess Hdr Isol)

1 KC-2B (Aux Bldg Non-Ess Ret Hdr Isol). f. WHEN one train's non-essential header isolation valves are opened, THEN perform Steps 12 through 13. (RNO continued on next page)

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/N5500/021 12 of 39 Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 11. (Continued)

_ g. GO TO Step 14. CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/55001021 12 of 39 Rev 36 DCE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 11. (Continued)

_ g. GO TO Step 14.

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A1SS00/021 ACTION/EXPECTED RESPONSE 12. Verify 1AD-10, Al1 "Ke SURGE TANK A LO-LO LEVEL" -DARK. 13 of 39 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Ensure the following valves -CLOSED:

1 KC-230A (Rx Bldg Non-Ess Hdr 1501)

1 KC-3A (Rx Bldg Non-Ess Ret Hdr Isol)

1 KC-SOA (Aux Bldg Non-Ess Hdr 1501)

1KC-1A (Aux Bldg Non-Ess Ret Hdr Isol). b. Ensure both Train B KC pumps -ON. c. IF KC Surge Tank 1A level continues to decrease OR is empty. THEN: 1) Ensure the following Train B essential equipment

-IN SERVICE AS NEEDED:

NV Pump 1B

NI Pump 1B

ND Pump 1B

ND Hx 1B

CA Pump 1B

NS Pump 1B

KF Pump 1B. 2) Ensure the following Train A essential equipment

-OFF:

NV Pump 1A

NI Pump 1A

ND Pump 1A

CA Pump 1A

NS Pump 1A

KF Pump 1A. _ 3) Ensure both Train A KC pumps -OFF. _ 4) Locate and isolate leak on Train A essential header. CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/55001021 ACTION/EXPECTED RESPONSE 12. Verify 1AD-10, Al1 "Ke SURGE TANK A LO-LO LEVEL" -DARK. 13 of 39 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Ensure the following valves -CLOSED:

1 KC-230A (Rx Bldg Non-Ess Hdr Isol)

1 KC-3A (Rx Bldg Non-Ess Ret Hdr Isol)

1 KC-50A (Aux Bldg Non-Ess Hdr Isol)

1 KC-1A (Aux Bldg Non-Ess Ret Hdr Isol). b. Ensure both Train B KC pumps -ON. c. IF KC Surge Tank 1A level continues to decrease OR is empty, THEN: 1) Ensure the following Train B essential equipment

-IN SERVICE AS NEEDED:

NV Pump 1B

NI Pump 1B

NO Pump 1B

NO Hx 1B

CA Pump 1B

NS Pump 1B

KF Pump 1B. 2) Ensure the following Train A essential equipment

-OFF:

NV Pump 1A

NI Pump 1A

NO Pump 1A

CA Pump 1A

NS Pump 1A

KF Pump 1A. _ 3) Ensure both Train A KC OFF. _ 4) Locate and isolate leak on Train A essential header.

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/55001021 ACTION/EXPECTED RESPONSE 13. Verify 1AD-10, Al2 "KC SURGE TANK B LO-LO LEVEL" -DARK. 14 of 39 Rev 36 DCS RESPONSE NOT OBTAINED Perform the following:

a. Ensure the following valves -CLOSED:

1 KC-228B (Rx Bldg Non-Ess Hdr Isol)

1 KC-18B (Rx Bldg Non-Ess Ret Hdr Isol)

1 KC-53B (Aux Bldg Non-Ess Hdr Isol)

1 KC-2B (Aux Bldg Non-Ess Ret Hdr Isol). b. Ensure both Train A KC pumps -ON. c. IF KC Surge Tank 1 B level continues to decrease OR is empty, THEN: 1) Ensure the following Train A essential equipment

-IN SERVICE AS NEEDED:

NV Pump 1A

NI Pump 1A

NO Pump 1A

NO Hx 1A

CA Pump 1A

NS Pump 1A

KF Pump 1A. 2) Ensure the following Train B essential equipment

-OFF:

NV Pump 1B

NI Pump 1B

NO Pump 1B

CA Pump 1B

NS Pump 1B

KF Pump 1B. _ 3) Ensure both Train B KC pumps -OFF. _ 4) Locate and isolate leak on Train B essential header. CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/5500/021 ACTION/EXPECTED RESPONSE 13. Verify 1AD-10, Al2 "Ke SURGE TANK B LO-LO LEVEL" -DARK. 14 of 39 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Ensure the following valves -CLOSED:

1 KC-228B (Rx Bldg Non-Ess Hdr Isol)

1 KC-18B (Rx Bldg Non-Ess Ret Hdr Isol)

1 KC-53B (Aux Bldg Non-Ess Hdr Isol)

1 KC-2B (Aux Bldg Non-Ess Ret Hdr 1501). b. Ensure both Train A KC pumps -ON. c. IF KC Surge Tank 1 B level continues to decrease OR is empty, THEN: 1) Ensure the following Train A essential equipment

-IN SERVICE AS NEEDED:

NV Pump 1A

NI Pump 1A

NO Pump 1A

NO Hx 1A

CA Pump 1A

NS Pump 1A

KF Pump 1A. 2) Ensure the following Train B essential equipment

-OFF:

NV Pump 1B

NIPump1B

NO Pump 1B

CA Pump 1B

NS Pump 1B

KF Pump 1B. _ 3) Ensure both Train B KC pumps -OFF. _ 4) Locate and isolate leak on Train B essential header.

CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/5500/021 ACTION/EXPECTED RESPONSE 15. 16

irst§tifi<mtlf: )tfl'meCilrerneo'fs 1! 1 .. III&IIWI.II

. III.III'#IgilL,I"'.,Q"IIIII.,.,.'., .*.. " *. ,.11:1"1,, 15 of 39 Rev 36 RESPONSE NOT OBTAINED This will require a swap of the switches so A train is in TEMP mode and B train is in MINIFLOW mode TS 3.7.7 Condition A CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/5500/021 ACTION/EXPECTED RESPONSE 15.

6fjoss'!(if 16

- SL;Q;16.9-9{J:?QratiQ!iltl'Sysf&Xf1s:

SqJl!gowp}, _ ::' ,Q

C ... fI. ".a:rin'lililm S)O ) "",9 .!;Lv"",P

....... P . ",' .9

"",." ... "." " ,.,.91 . * :,

_:,0 Spray System) _ ii ;;3,;(;5 (System)'

_ ,Ss*e'ln).;; . . _

tREFERTa'R,f'I.Q1A1:§QQO/OlIm (Cla$,slfit!atiq)JPf.EOie'rIje(;;cy)'

_

15 of 39 Rev 36 RESPONSE NOT OBTAINED This will require a swap of the switches so A train is in TEMP mode and B train is in MINIFLOW mode TS 3.7.7 Condition A None CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/N5500/021 ACTION/EXPECTED RESPONSE _. Notify Radiation Protection that a potential unmonitored release may have occurred.

Notify Station Management to evaluate a KC Hx to RN leak. _ * '1IIM ** lllla _ ...... ... 20. trJilillllfl'lMgW'GlIIIII'IRiIl?'firl

_*_ ...... lilillill.J

- - IIBlltrU

Return NV Pump 1A to normal cooling as applicable.

REFER TO Enclosure 4 (Alternate Cooling To NV Pump 1A). _* ...........

ma' ..... _ * .."IIB _ * ..... WMllllllltI.1BlI 16 of 39 Rev 36 DCt RESPONSE NOT OBTAINED _ RETURN TO Step 9. Perform the following:

a. IF letdown isolated, THEN refer to AP/1/N5500/012 (Loss Of Charging Or Letdown).

b. Do not continue in this procedure until Step 21 conditions are met. CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/5500/021 ACTION/EXPECTED RESPONSE

Notify Radiation Protection that a potential unmonitored release may have occurred.

Notify Station Management to evaluate a KC Hx to RN leak. 19.

Great' ':'i11/1ari

_ <><>'", .

.... '.' .. ,,1'.

Return KC puOOps' operi,mfJfl.

REFER TOPPl1

Return NV Pump 1A to normal cooling as applicable.

REFER TO Enclosure 4 (Alternate Cooling To NV Pump 1A). .1 A!j):

H,X 0WiiltSTHI T;EMF1i:1i it 1AD-7, 16 of 39 Rev 36 RESPONSE NOT OBTAINED _ RETURN TO Step 9. Perform the following:

a. IF letdown isolated, THEN refer to AP/1/A/5500/012 (Loss Of Charging Or Letdown).

b. Do not continue in this procedure until Step 21 conditions are met.

CNS LOSS OF COMPONENT COOLING AP/1/Al5500/021

22. 23. ACTION/EXPECTED RESPONSE _ ...........

_._' ....... 2) .... a"'lm* ....

...

RESPONSE NOT OBTAINED PAGE NO. 17 of 39 Rev 36 CNS LOSS OF COMPONENT COOLING AP/1/A/5500/021 ACTION/EXPECTED RESPONSE 22.

pat,b a$

p.

to 1 )Oper;rt[le;if6UowiI19

0JIUspl) .1 t\iV-9;:89l3(1(M9TOtltlls9i).

2)

_ .'h From, tfWSJl: b,:

tQVQjjf, THEN

23.

RETURN TOp.tQcedurg in RESPONSE NOT OBTAINED PAGE NO. 17 of 39 Rev 36 DC::

Duke Energy Procedure No. Catawba Nuclear Station API 1 IAl5500/007 Loss of Normal Power Revision No. 057 Electronic Reference No. Continuous Use CN005CEB PERFORMANCE I * * * * * * * * *

UNCONTROLLED FOR PRINT * * * * * * * * * * (ISSUED) -PDF Format Initiating Cue: Multiple electrical alarms on 1AD-11, UV status lights for 1ETB on 1 SI-14 Duke Energy Procedure No. Catawba Nuclear Station AP/I/A/5500/007 Loss of Normal Power Revision No. 057 Electronic Reference No. Continuous Use CN005CEB PERFORMANCE I * * * * * * * * *

UNCONTROLLED FOR PRINT * * * * * * * * * * (ISSUED) -PDF Format Initiating Cue: Multiple electrical alarms on 1AO-11, UV status lights for 1ETB on 1SI-14 CNS LOSS OF NORMAL POWER AP/1/A155001007 Case II. Loss of All Power to an Essential Train:

1 ETA de-energized

*

Affected DIG -OFF

Affected sequencer not loading essential loads. Case III is normally entered from Case I or II. If both 1 ETA and 1ETB are powered from Unit 2 and Unit 1 offsite power only is lost then Case III may be entered directly.

Case III. Loss Of All 6.9KV Busses

Case I (Loss of Normal Power to an Essential Train), Step 12

Case II (Loss of All Power to an Essential Train), Step 22

1AD-11, F/4 "ZONE G LOCKOUT TRIP" -LIT

Loss Of Switchyard

Swgr Tie Bkrs Closed status lights (1 SI-14) -LIT

Emergency lighting -LIT

Numerous transformer trouble annunciators 1AD-11 -LIT * "DRPI BON EMERG POWER" (1SI-3) -LIT

DRPI indication

-DARK

1 SA-5 failed open. PAGE NO. 2 of 154 Revision 57 CNS LOSS OF NORMAL POWER AP/1/N55001007 Case II. Loss of All Power to an Essential Train:

1 ETA de-energized

com.poneQts

Affected DIG -OFF

Affected sequencer not loading essential loads. Case III is normally entered from Case I or II. If both 1 ETA and 1 ETB are powered from Unit 2 and Unit 1 offsite power only is lost then Case III may be entered directly.

Case III. Loss Of All 6.9KV Busses

Case I (Loss of Normal Power to an Essential Train), Step 12

Case II (Loss of All Power to an Essential Train), Step 22

1AD-11, F/4 "ZONE G LOCKOUT TRIP" -LIT

Loss Of Switchyard

Swgr Tie Bkrs Closed status lights (1 SI-14) -LIT

Emergency lighting -LIT

Numerous transformer trouble annunciators 1AD-11 -LIT * "DRPI B ON EMERG POWER" (1 SI-3) -LIT

DRPI indication

-DARK

1 SA-5 failed open. PAGE NO. 2 of 154 Revision 57 CNS AP/1/A/5500/007 C. Operator Actions 1. 2. a. b. c. 3. 4. 5. LOSS OF NORMAL POWER a. Manually start pump(s). b. Perform the following:

_ 1) Manually start pump(s). PAGE NO. 20 of 154 Revision 57 _ 2) Ensure KC Hx outlet mode switches -PROPERLY ALIGNED. c. REFER TO AP/1/A/5500/012 (Loss of Charging or Letdown).

d. e. REFER TO OP/0/A/6450/011 (Control Room Area Ventilation/Chilled Water System). _ IF CA Pump #1 is required to maintain S/G levels, THEN start CA Pump #1. The crew should not RESET CA to secure the CAPT. The CAPT will secure automatically when CA is RESET in step 12. Otherwise an _ overspeed condition could result if it is started later due to steam trapped in the line The DIG IS running, but the output breaker will not close. Also the cooling water valve will not open and the DIG will be secured eventually.

CNS AP/1/A/5500/007 C. Operator Actions LOSS OF NORMAL POWER Case II PAGE NO. 20 of 154 Revision 57 2.

as'/19I1owsJ

a. . uniri{p) -

EE>/ a. Manually start pump(s). b.

b. Perform the following:

_ 1) Manually start pump(s). _ 2) Ensure KC Hx outlet mode switches -PROPERLY ALIGNED. c. REFER TO AP/1/A/5500/012 (Loss of Charging or Letdown).

d. Apump'is .malJ,tam'*S/G

e. REFER TO OP/0/A/6450/011 (Control Room Area Ventilation/Chilled Water System). _ IF CA Pump #1 is required to maintain S/G levels, THEN start CA Pump #1. The crew should not RESET CA to secure the CAPT. The CAPT will secure automatically when CA is RESET in step 12. Otherwise an overspeed condition could result if it is started later due to steam trapped in the line The D/G IS running, but the output breaker will not close. Also the cooling water valve will not open and the D/G will be secured eventually.

CNS LOSS OF NORMAL POWER PAGE NO. AP/1/AJ55001007 Case II 21 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE 6. 7. _. REFER TO Enclosure 8 (Manual Load Shed Of 1 ETA) OR

RESPONSE NOT OBTAINED

DIG 1A: a. Depress and hold the DIG "OFF" pushbutton.

b. Dispatch operator to open 1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496). c. WHEN 1 EDE-F01 F (Diesel Generator Load Sequencer Panel OR 1 DGLSA) is open, THEN release the DIG "OFF" pushbutton.

CNS LOSS OF NORMAL POWER PAGE NO. AP/1 I Al55001007 Case II 21 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE _. REFER TO Enclosure 8 (Manual Load Shed Of 1 ETA) OR (fi§HualCfj,:dad' RESPDNSE NOT OBTAINED

DIG 1A: a. Depress and hold the DIG "OFF" pushbutton.

b. Dispatch operator to open 1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496). c. WHEN 1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) is open, THEN release the DIG "OFF" pushbutton.

OR tj:' ,Dispatch to 1EQF-F01F . S¢quel) 1DGl,(SB}{i,B-560, CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A15500/007 Case II 22 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE 8. 9. 10. a. b. GO TO Step 12. RESPONSE NOT OBTAINED _ REFER TO AP/OIAl5500/020 (Loss of Nuclear Service Water). a. CNS LOSS OF NORMAL POWER PAGE NO. AP/1/AJ5500/007 Case II 22 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE 1 0

a.

' .. , ,'"< ">" c "\""""-',

b. GO TO Step 12. RESPONSE NOT OBTAINED _ REFER TO AP/O/AlS500/020 (Loss of Nuclear Service Water).

CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A155001007 Case II 23 of 154 11. Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE a. b. At least one NO pump -ON. c. 1 AO-11, K/3 "4KV BIO BUS FTA VOLTAGE LO" -DARK. RESPONSE NOT OBTAINED _,*i ..... b. REFER TO AP/1/A155001019 (Loss of Residual Heat Removal System). c. Perform the following:

Both NO Hx Bypass valves fail closed on loss of 1 LXI (1FTA). 1} IF NO Pump 1A is operating in Residual Heat Removal Mode, THEN perform the following:

_ a} Place the "PWR OISCON fOR 1 NI173A" in "THROT". _ b} Throttle 1NI-173A (NO Hdr 1A To Cold Legs C&O) to stabilize NC temperature.

_ c} WHEN 1AO-11, K/3 "4KV BIO BUS FTA VOLTAGE LO" dark, THEN return 1 NI-173A to normal alignment.

2} IF NO Pump 1 B is operating in Residual Heat Removal Mode, THEN perform the following:

_ a} Place the "PWR OISCON fOR 1N1178B" in "THROT". _ b} Throttle 1NI-178B (NO Hdr 1B To Cold Legs A&B) to stabilize NC temperature.

_ c} WHEN 1AO-11, K/3"4KVB/O BUS FTA VOLTAGE LO" dark, THEN return 1 NI-178B to normal alignment.

CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A/55001007 Case II 23 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE b. At least one NO pump -ON. c. 1AD-11, Kl3 "4KV BIO BUS FTA VOLTAGE LO" -DARK. RESPONSE NOT OBTAINED b. REFER TO AP/1/A/55001019 (Loss of Residual Heat Removal System). c. Perform the following:

Both NO Hx Bypass valves fail closed on loss of 1 LXI (1 FTA). 1} IF NO Pump 1A is operating in Residual Heat Removal Mode, THEN perform the following:

_ a} Place the "PWR DISCON FOR 1N1173A" in "THROT". _ b} Throttle 1NI-173A (NO Hdr 1A To Cold Legs C&D) to stabilize NC temperature.

_ c} WHEN 1AD-11, Kl3 "4KV BIO BUS FTA VOLTAGE LO" dark, THEN return 1 NI-173A to normal alignment.

2} IF NO Pump 1 B is operating in Residual Heat Removal Mode, THEN perform the following:

_ a} Place the "PWR DISCON FOR 1 N1178B" in "THROT". _ b} Throttle 1NI-178B (NO Hdr 1B To Cold Legs A&B) to stabilize NC temperature.

_ c} WHEN 1AD-11, Kl3 "4KV BIO BUS FTA VOLTAGE LO" dark, THEN return 1 NI-178B to normal alignment.

CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A155001007 Case II 24 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE 12. 13. b. c. RESPONSE NOT OBTAINED a. Perform the following:

_ 1) REFER TO Enclosure 16 (S/G Level Control).

_ 2) GO TO Step 14. CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A/5500/007 Case II 24 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE VEirl!ygFftgw

c. RESPONSE NOT OBTAINED a. Perform the following:

_ 1} REFER TO Enclosure 16 (S/G Level Control).

_ 2} GO TO Step 14. pl¢lion tcftake iQ,ipfG:

CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A155001007 Case II 25 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE 14. RESPONSE NOT OBTAINED To prevent overpressurizing the condenser perform the following:

a. Dispatch operator to close the following valves:

1SA-22 (Main Steam To CSAE) (TB 1-594, 1 M-32)

1SA-27 (Aux Steam To CSAE) (TB-594, 1 M-27). b. WHEN notified by dispatched operator that the SA supplies are closed, THEN perform the following:

_ 1) Open "COND A-B-C VAC BKR VLVS". 2) IF power not available to operate "COND A-B-C VAC BKRVLVS", THEN dispatch operator to open the following valves:

1CM-368 (1A Main Cond Shell Vacuum Bkr) (TB-600,1 F-26) (Ladder needed)

1CM-369 (1B Main Cond Shell Vacuum Bkr) (TB-603, 1 F-24) (Ladder needed)

1 CM-370 (1 C Main Cond Shell Vacuum Bkr) (TB-605, 1 F-22) (Ladder needed). _ 3) WHEN time permits, THEN dispatch operator to complete breaking condenser vacuum. REFER TO OP/1/B/63001006 (Main Vacuum). _ 4) Shutdown steam seals. REFER TO OP/1/B/63001005 (Steam Seal System). CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A/5500/007 Case II 25 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED To prevent overpressurizing the condenser perform the following:

a. Dispatch operator to close the following valves:

1 SA-22 (Main Steam To CSAE) (TB 1-594, 1 M-32)

1SA-27 (Aux Steam To CSAE) (TB-594, 1 M-27). b. WHEN notified by dispatched operator that the SA supplies are closed, THEN perform the following:

1) Open "COND A-B-C VAC BKR VLVS". 2) IF power not available to operate "COND A-B-C VAC BKR VLVS", THEN dispatch operator to open the following valves:

1CM-368 (1A Main Cond Shell Vacuum Bkr) (TB-600,1 F-26) (Ladder needed)

1 CM-369 (1 B Main Cond Shell Vacuum Bkr) (TB-603, 1 F-24) (Ladder needed)

1 CM-370 (1 C Main Cond Shell Vacuum Bkr) (TB-605, 1 F-22) (Ladder needed). _ 3) WHEN time permits, THEN dispatch operator to complete breaking condenser vacuum. REFER TO OP/1/B/6300/006 (Main Vacuum). _ 4) Shutdown steam seals. REFER TO OP/1/B/6300/005 (Steam Seal System).

. CNS LOSS OF NORMAL POWER PAGE NO. AP/1/AJ55001007 Case" 26 of 154 Loss of All Power to an Essential Train Revision 57 15. 16. a. b. 17. 18. 19. ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Attempt to restore letdown. REFER TO AP/1/AJ55001012 (Loss of Charging or Letdown).

_ 2) WHEN normal letdown has been established, THEN place additional letdown orifice in service as necessary to control Pzr level. _ 3) GO TO Step 17. _ REFER TO AP/OIAl5500/022 (Loss of Instrument Air). * . CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A/55001007 Case" 26 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE 15.

_

..

tg\ mcmllamzt:

.. . rp9I§J:naQ . 16. 19. b. place! ao!f/tlQU/a'i'net(lowri 6nific RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Attempt to restore letdown. REFER TO AP/1/A/55001012 (Loss of Charging or Letdown).

_ 2) WHEN normal letdown has been established, THEN place additional letdown orifice in service as necessary to control Pzr level. _ 3) GO TO Step 17. _ REFER TO AP/OIAl5500/022 (Loss of Instrument Air).

.... ' t CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A155001007 Case" 27 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE 20. _.II:tIIIBI" .... _ _ .... fR, __ II. _._ .. Wili5ijMl)

_._I.iil .. ** .. _._ ** ' .. IM_81 23. _

The status of all lockout targets have been determined

Station management has approved power restoration to the affected bus. RESPONSE NOT OBTAINED T8 3.4.9 Condition B T8 3.8.1 Condition A, B, D, and F T8 3.8.9 Condition A T8 3.7.8 Condition A _ WHEN time and manpower permit, THEN perform applicable portions of Case III. REFER TO Case'" (Loss Of All 6.9KV Busses). rEXTEVENT CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A/5500/007 Case" 27 of 154 Loss of All Power to an Essential Train Revision 57 ACTION/EXPECTED RESPONSE _ _ * -Operatiog)

_

-ShutdoWD)

Slh'38 4 {bC'S1 f)f: *>': 0 t@ili,)CC

_ . . .;

perq.

_ l.3.S:P'*

,; ... 3.6.7

_ Gl)3.8.8

_

21.

...... c.' c* '.: q .:.:.* ..

.* U' ...... << ... " ........ c .UN.*.

_TO_c (

,!!j'e

The status of all lockout targets have been determined

Station management has approved power restoration to the affected bus. RESPONSE NOT OBTAINED . T8 3.4.9 Condition B T8 3.8.1 Condition A, B, 0, and F T8 3.8.9 Condition A T8 3.7.8 Condition A _ WHEN time and manpower permit, THEN perform applicable portions of Case III. REFER TO Case III (Loss Of All 6.9KV Busses). INEXTEVENT Initiating Cue: 1AD-13, All, F/5 LEAK IS approximately 30 gpm Initiating Cue: 1AD-13, All, F/5 LEAK IS approximately 30 gpm CNS REACTOR COOLANT LEAK PAGE NO. AP/1/Al5500/010 2 of 154 Rev 51 Case II. NC System Leak:

Pzr pressure -DECREASING

Any of the following EMF indications

-INCREASING OR IN ALARM:

EMF-41 (Aux Bldg Ventilation)

1 EMF-38 (Containment Particulate)

1 EMF-39 (Containment Gas)

1 EMF-46A (Component Cooling Train A)

1 EMF-46B (Component Cooling Train B).

Containment floor and equipment sump level(s) -INCREASING.

CNS REACTOR COOLANT LEAK PAGE NO. AP/1/Al5500/010 2 of 154 Rev 51 Case II. NC System Leak:

inCl[catioo;iINCREASlfi],c.;

1I:zrlevel

Pzr pressure -DECREASING

Any of the following EMF indications

-INCREASING OR IN ALARM:

EMF-41 (Aux Bldg Ventilation)

1 EMF-38 (Containment Particulate)

1 EMF-39 (Containment Gas)

1 EMF-46A (Component Cooling Train A)

1 EMF-46B (Component Cooling Train B).

Containment floor and equipment sump level(s) -INCREASING.

CNS REACTOR COOLANT LEAK AP/1/N55001010 Case II NC System Leak ACTION/EXPECTED RESPONSE C. Operator Actions P DOES THESE ACTIONS 3. Ensure containment integrity as required:

a. IF leak known to be in Auxiliary Building, THEN GO TO Step 4. b. Initiate Containment Closure. c. Initiate additional action as required to ensure Containment Equipment Hatch -CLOSED. d. Initiate additional action as required to ensure Containment Air Locks -CLOSED. a. RESPDNSE NOT OBTAINED PAGE NO. 54 of 154 Rev 51 PZR level wi" still be decreasing and the crew wi" have to reduce letdown. _ c. IF Pzr level is stable OR increasing, THEN GO TO Step 5. (RNO continued on next page) CNS REACTOR COOLANT LEAK PAGE NO. AP/1/N5500/010 Case II 54 of 154 NC System Leak Rev 51 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions IBOP DOES THESE ACTIONS

3. Ensure containment integrity as required:

a. IF leak known to be in Auxiliary Building, THEN GO TO Step 4. b. Initiate Containment Closure. c. Initiate additional action as required to ensure Containment Equipment Hatch -CLOSED. d. Initiate additional action as required to ensure Containment Air Locks -CLOSED. PZR level will still be decreasing and the crew will have to reduce letdown. a .rv1aintcI!tJ,,!chC!(gihg

.{lpW b M.*ahuall . s ,. . .. ,Y,,,SHJ(

,m'* ., .. P

c. IF Pzr level is stable OR increasing, THEN GO TO Step 5. (RNO continued on next page)

CNS REACTOR COOLANT LEAK PAGE NO. AP/1/N55001010 Case II 55 of 154 NC System Leak Rev 51 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 4. (Continued) a) =.I.I.I, .. !I.III _ (1) s *1 ... 7

..

' ___ -("i ** L (RNO continued on next page) CNS AP/1 /A/5500/01 0 ACTION/EXPECTED RESPONSE 4. (Continued)

REACTOR COOLANT LEAK PAGE NO. Case II 55 of 154 NC System Leak Rev 51 DCS RESPONSE NOT OBTAINED d.

THEN: 1) as follows::

a) IF 1 r;;J}/:JOA (Letdo Orif;,S Otlt CooIIspJ}open.

THEN Jperform the . _ (1) M!=ll1lJ§lly

..

NVt-:'t;48 y,gQtr()l)t2 beNileeg';375 RS:JB'l\ _ (2) 1hr9tt1e1 NV-81f9 {letdo' GpM ;letdoWnJfI9w.

_ (3) WHEN 45GPMletQ'1Wn TBEN Press Q9:htftol);;fQ}!)1ainJ§,{f;!,

3!5QPSIG.

_ (4) ,WHENIe,td6w,n pre§:§,bfe is place J:.:>tess (RNO continued on next page)

CNS AP/1/A/5500/010 ACTION/EXPECTED RESPONSE 4. (Continued)

REACTOR COOLANT LEAK PAGE NO. Case II 56 of 154 NC System Leak Rev 51 RESPONSE NOT OBTAINED b) IF 1 NV-13A (Letdn Orif 1A Otlt Cant Isol) open, THEN perform the following:

_ (1) Manually control 1 NV-148 (Letdn Press Control) to establish letdown pressure between 150 -200 PSIG. _ (2) Open 1 NV-11A (Letdn Orif 1 C Otlt Cant Isol). _ (3) Adjust 1 NV-148 (Letdn Press Control) to establish letdown pressure between 375 -400 PSIG. _ (4) Close 1 NV-13A (Letdn Orif 1A Otlt Cant Isol). _ (5) Adjust 1NV-148 (Letdn Press Control) to maintain letdown pressure at 350 PSIG. _ (6) WHEN letdown pressure is stable at 350 PSIG, THEN place 1NV-148 (Letdn Press Control) in auto. 2) IF Pzr level continues to decrease, THEN ensure the following valves closed:

1NV-10A (Letdn Orif 1B Otlt Cant Isol)

1 NV-11A (Letdn Orif 1C Otlt Cant Isol)

1NV-13A (Letdn Orif 1A Otlt Cant Isol). (RNO continued on next page) CNS AP/1/A15500/010 ACTION/EXPECTED RESPONSE 4. (Continued)

REACTOR COOLANT LEAK PAGE NO. Case II 56 of 154 NC System Leak Rev 51 OCt RESPONSE NOT OBTAINED b) IF 1 NV-13A (Letdn Orif 1A Otlt Cont Isol) open, THEN perform the following:

_ (1) Manually control 1 NV-148 (Letdn Press Control) to establish letdown pressure between 150 -200 PSIG. _ (2) Open 1 NV-11A (Letdn Orif 1 C Otlt Cont Isol). _ (3) Adjust 1 NV-148 (Letdn Press Control) to establish letdown pressure between 375 -400 PSIG. _ (4) Close 1 NV-13A (Letdn Orif 1A Otlt Cont Isol). _ (5) Adjust 1 NV-148 (Letdn Press Control) to maintain letdown pressure at 350 PSIG. _ (6) WHEN letdown pressure is stable at 350 PSIG, THEN place 1 NV-148 (Letdn Press Control) in auto. 2) IF Pzr level continues to decrease, THEN ensure the following valves closed:

1NV-10A (Letdn Orif 18 Otlt Cont Isol)

1NV-11A (Letdn Orif 1C Otlt Cont Isol)

1NV-13A (Letdn Orif 1A Otlt Cont Isol). (RNO continued on next page)

CNS AP/11A155001010 ACTION/EXPECTED RESPONSE 4. (Continued)

REACTOR COOLANT LEAK PAGE NO. Case II 57 of 154 NC System Leak Rev 51 DC:: RESPONSE NOT OBTAINED 4) IF Pzr level continues to decrease OR cannot be maintained greater than 4%, THEN: a) IF in Modes 1, 2, or 3 with CLAs in service, THEN perform the following:

_ (1) Manually trip the reactor. _ (2) WHEN reactor trip verified, THEN manually initiate S/I. _ (3) GO TO EP/11A15000/E-O (Reactor Trip Or Safety Injection).

_ b) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/11A155001027 (Shutdown LOCA). _ c) IF in Mode 5, THEN GO TO AP/11A155001019 (Loss of Residual Heat Removal System). CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A155001010 Case II 57 of 154 NC System Leak Rev 51 DC:: ACTION/EXPECTED RESPONSE 4. (Continued)

5. If in*

RESPONSE NOT OBTAINED 4) IF Pzr level continues to decrease OR cannot be maintained greater than 4%, THEN: a) IF in Modes 1, 2, or 3 with CLAs in service, THEN perform the following:

_ (1) Manually trip the reactor. _ (2) WHEN reactor trip verified, THEN manually initiate S/I. _ (3) GO TO EP/1/A15000/E-O (Reactor Trip Or Safety Injection).

_ b) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/A155001027 (Shutdown LOCA). _ c) IF in Mode 5, THEN GO TO AP/1/A155001019 (Loss of Residual Heat Removal System).

CNS REACTOR COOLANT LEAK PAGE NO. AP/1/N55001010 Case II 58 of 154 NC System Leak Rev 51 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Perform the following:

a. IF Pzr level is greater than 17%, THEN ensure Pzr heaters on as required.

b. Ensure Pzr spray valves -CLOSED. c. Ensure all Pzr PORVs -CLOSED. d. IF any Pzr PORV is leaking or has not reseated, THEN close its associated Pzr PORV isolation valve. e. IF Pzr/NC pressure is decreasing in an uncontrolled manner, THEN: 1) IF in Mode 1, 2 or 3 with CLAs in service, THEN: _ a) Manually initiate S/I. _ b) GO TO EP/1/N5000/E-O (Reactor Trip Or Safety Injection).

_ 2) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/N55001027 (Shutdown LOCA). _ 3) IF in Mode 5, THEN GO TO AP/1/N55001019 (Loss of Residual Heat Removal System). CNS REACTOR COOLANT LEAK PAGE NO. AP/1/N55001010 Case II 58 of 154 NC System Leak Rev 51 DeE ACTION/EXPECTED RESPONSE PRESSVRpi 7

8.

REf.ERTO

'Er@osllrJf14 (Qoritrg);

RESPONSE NOT OBTAINED Perform the following:

a. IF Pzr level is greater than 17%, THEN ensure Pzr heaters on as required.

b. Ensure Pzr spray valves -CLOSED. c. Ensure all Pzr PORVs -CLOSED. d. IF any Pzr PORV is leaking or has not reseated, THEN close its associated Pzr PORV isolation valve. e. IF Pzr/NC pressure is decreasing in an uncontrolled manner, THEN: 1) IF in Mode 1, 2 or 3 with CLAs in service, THEN: _ a) Manually initiate S/I. _ b) GO TO EP/1/N5000/E-O (Reactor Trip Or Safety Injection).

_ 2) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/N55001027 (Shutdown LOCA). _ 3) IF in Mode 5, THEN GO TO AP/1/N55001019 (Loss of Residual Heat Removal System).

CNS REACTOR COOLANT LEAK AP/1/N55001010 Case II NC System Leak ACTION/EXPECTED RESPONSE 9.

a. Open 1 NV-2S2A (NV Pumps Suct From FWST). b. Open 1 NV-253B (NV Pumps Suet From FWST). c. Close 1 NV-188A (VCT Otlt Isol). d. Close 1 NV-189B (VCT Otlt Isol). e. IF Reactor trip breakers are closed, THBN perform the following:

_ 1) Continue concurrent use of this procedure for the NC leak. _ 2) Manually trip the reactor. _ 3) IF Unit was in Mode 3 below 1955 PSIG, THBN GO TO AP/1/N55001005 (Reactor Trip or Inadvertent S/I Below P-11). _ 4) GO TO EP/1/N5000/E-O (Reactor Trip Or Safety Injection).

RESPONSE NOT OBTAINED This wont happen. PAGE NO. 59 of 154 Rev 51 DCl: CNS REACTOR COOLANT LEAK AP/1/N55001010 Case II NC System Leak ACTION/EXPECTED RESPONSE 9. ifF E 1AQ7?, ..

TflEN*

tQ

a. Open 1 NV-252A (NV Pumps Suct From FWST). b. Open 1 NV-253B (NV Pumps Suet From FWST). c. Close 1 NV-188A (VCT Otlt Isol). d. Close 1 NV-189B (VCTOtlt Isol). e. IF Reactor trip breakers are closed, THEN perform the following:

_ 1) Continue concurrent use of this procedure for the NC leak. _ 2) Manually trip the reactor. _ 3) IF Unit was in Mode 3 below 1955 PSIG, THEN GO TO AP/1/N5500/005 (Reactor Trip or Inadvertent S/I Below P-11). _ 4) GO TO EP/1/N5000/E-O (Reactor Trip Or Safety Injection).

RESPONSE NOT OBTAINED This wont happen. PAGE NO. 59 of 154 Rev 51 DCl:

CNS REACTOR COOLANT LEAK AP/1/A155001010 llIIr.'P 10. _ * ** IIII1IIID-Wi&l.

.. _ ..........

aM aM

11.

.... JEIfIR .. ' _ ....... "4' ........ _ .............. . _

_ ** ...,! ..........

J Leak size is approximately 30 gpm TS 3.4.13 Condition A TS 3.6.4 Condition A SLC 16.7-9 Condition A, B EVENT 6 can begin here. PAGE NO. 60 of 154 Rev 51 CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A155001010 Qase'111 ih 60 of 154 Utgk Rev 51 ACHON/EXPECTED*RES'PONSE

RESPONSE NOT o BlA: I NED;

1 O.

f611Q:W.jt;i§

_.

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System Le$RI,Rl;lte, Ten Mih Run A,{9):f 11 .

3.4A RCSL<):6ps-Mod El s.;l and 2 3.4,5.;RCSf'l3oo s::'Mode13i

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,(LTOP) Sys;tElDl

'Q. **:erati A nafil2eaKcf*

i):: _ <.,I **.*....* w\' hi *....*.... .I;>.,,,,,, .. """':*"'*

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,**Sh'e'ific*:Piefivrr 7:' .. ',,+'.'. *h,* \ .;;"; "" . J]f ,."".t' {l(. ....., ,,,.,, Y/.l .' SI!@'?"*6.7:1'97 lf StriCJ5'Y Snutc1([Wf:l.fS

'stem};: , ' " >,' .h' a, <<:::Xi' Y /'" ;fflEf-!-

'." Y .,' Leak size is approximately 30 gpm TS 3.4.13 Condition A TS 3.6.4 Condition A SLC 16.7-9 Condition A, B EVENT 6 can begin here .

CNS REACTOR COOLANT LEAK PAGE NO. AP/1/N5500/010 Enclosure 14 -Page 1 of 3 143 of 154 Control Room Ventilation System Verification Rev 51 ACTION/EXPECTED RESPONSE

RESPONSE NOT OBTAINED Perform the following:

a. Shift operating VCIYC trains. REFER TO Enclosure 15 (Shifting Operating VCIYC Train). b. IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:

_. OP/OIN6450/011 (Control Room Area Ventiiation/Chilled Water System) _. EM/OIN5200/001 (Troubleshooting Cause For Improper Operation of VCIYC System). IF chlorine odor is detected in the Control Room, THEN perform the following based on the status of given alarms: a. IF detectors on both unit intakes are in alarm, THEN: 1) Ensure the following VC intake dampers -CLOSED:

1VC-58 (CRA Filt Inlet)

1VC-6A (CRA Filt Inlet)

2VC-58 (CRA Filt Inlet)

2VC-6A (CRA Filt Inlet). _ 2) GO TO Step 4. (RNO continued on next page) CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A155001010 Enclosure 14 -Page 1 of 3 143 of 154 Rev 51 Control Room Ventilation System Verification ACTION/EXPECTED RESPONSE 1.

' _ _ * 'CR,

.. OW\AIiW::1

2. Verity _ *

.tJNTAKE;HI B"

11'11\41.

8 1J 7 8mllNIT*2

'INPUfiE HI' l'f}"'G'0d.-. ' ,

',.,V , CIj[I!f§)RI N1=iZA".

1AD-113; C/dLQR1 N§,;,2B", RESPONSE NOT OBTAINED Perform the following:

a. Shift operating VCIYC trains. REFER TO Enclosure 15 (Shifting Operating VCIYC Train). b. IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:

OP/OIAl64501011 (Control Room Area Ventiiation/Chilied Water System)

EM/OIAl52001001 (Troubleshooting Cause For Improper Operation of VCIYC System). IF chlorine odor is detected in the Control Room, THEN perform the following based on the status of given alarms: a. IF detectors on both unit intakes are in alarm, THEN: 1) Ensure the following VC intake dampers -CLOSED:

1VC-58 (CRA Filt Inlet)

1VC-6A (CRA Filt Inlet)

2VC-58 (CRA Filt Inlet)

2VC-6A (CRA Filt Inlet). _ 2) GO TO Step 4. (RNO continued on next page)

CNS REACTOR COOLANT LEAK PAGE NO. AP/1/Al5500/010 Enclosure 14 -Page 2 of 3 144 of 154 Control Room Ventilation System Verification Rev 51 ACTION/EXPECTED RESPONSE 2. {Continued)

RESPONSE NOT OBTAINED b. IF Unit 1 intake HI chlorine detector(s) in alarm, THEN: 1) Ensure the following VC dampers -CLOSED: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). 2) Ensure the following dampers -OPEN: _. 2VC-58 (CRA Filt Inlet) _

2VC-6A (CRA Filt Inlet). _ 3) GO TO Step 4. c. IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN: 1 ) Ensure the following VC dampers -CLOSED: _

2VC-58 (CRA Filt Inlet) _

2VC-6A (CRA Filt Inlet). 2) Ensure the following OPEN: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). _ 3) GO TO Step 4. CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A/5500/010 Enclosure 14 -Page 2 of 3 144 of 154 Control Room Ventilation System Verification Rev 51 ACTION/EXPECTED RESPONSE 2. (Continued)

_e 1

_

_ .'g'lQi6A{ORi::Eilt Inlet). RESPONSE NOT OBTAINED b. IF Unit 1 intake HI chlorine detector(s) in alarm, THEN: 1) Ensure the following VC dampers -CLOSED: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). 2) Ensure the following dampers -OPEN: _

2VC-58 (CRA Filt Inlet) _

2VC-6A (CRA Filt Inlet). _ 3) GO TO Step 4. c. IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN: 1) Ensure the following VC dampers -CLOSED: _. 2VC-58 (CRA Filt Inlet) _

2VC-6A (CRA Filt Inlet).

2) Ensure the following dampers -OPEN: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). _ 3) GO TO Step 4.

CNS REACTOR COOLANT LEAK PAGE NO. AP/1/N55001010 Enclosure 14 -Page 3 of 3 145 of 154 Control Room Ventilation System Verification Rev 51 ACTION/EXPECTED RESPONSE R£SPONSENOT OBTAINED 4. -. CNS REACTOR COOLANT LEAK AP/1/N55001010 Enclosure 14 -Page 3 of 3 Control Room Ventilation System Verification ACTION/EXPECTED RESPONSE notifiedljpy as follQws: °li _ il:

oe;: 1 AO':18act:qale.

RESPONSE NOT OBTAINED PAGE NO. 145 of 154 Rev 51 Initiating cue: 1AD-1 Al6 and 1AD-5 Al1, Al4 Initiating cue: 1AO-1 A/6 and 1AO-5 A/1, A/4 CNS LOSS OF S/G FEEDWATER AP/1/N55001006 A. Purpose

To verify proper response to a loss of feedwater supply to the S/Gs.

To verify proper response to a loss of normal supply of auxiliary feedwater.

B. Symptoms

1AD-3, C/6 "CF ISOL TRN A" -LIT

1AD-3, D/6 "CF ISOL TRN B" -LIT

Any S/G 10 level alert alarm on 1AD-4 -LIT

Any S/G flow mismatch 10 CF flow alarm on 1AD-4 -LIT. Case II. Loss Of Normal CA Supply:

Any CA Auto Start

1AD-5, H/4 "CACST LO LEVEL" -LIT

1AD-8, B/1 "UST LO LEVEL" -LIT. PAGE NO. 1 of 20 Rev 40 CNS LOSS OF S/G FEEDWATER AP/11 N55001006 A. Purpose

To verify proper response to a loss of feedwater supply to the S/Gs.

To verify proper response to a loss of normal supply of auxiliary feedwater.

B.

CasEf"I.Lq§gPf:;q=

Su

,cfBT

1AD-3, C/6 "CF ISOL TRN A" -LIT

1AD-3, D/6 "CF ISOL TRN B" -LIT

Any S/G 10 level alert alarm on 1AD-4 -LIT

Any S/G flow mismatch 10 CF flow alarm on 1AD-4 -LIT. Case II. Loss Of Normal CA Supply:

Any CA Auto Start

1AD-5, H/4 "CACST LO LEVEL" -LIT

1AD-8, B/1 "UST LO LEVEL" -LIT. PAGE NO. 1 of 20 Rev 40 CNS LOSS OF S/G FEEDWATER PAGE NO. AP/11A155001006 Case I 2of20 Loss of CF Supply To S/Gs Rev 40 DCl: ACTION/EXPECTED RESPONSE C. QQerator Actions CAPT #1 should have been secured already and since B train has no power and A CA pump autostart is failed, they will start A CA manually.

RESPONSE NOT OBTAINED IF AT ANY TIME all CF supply to S/G(s) lost, THEN perform the following:

a. Manually trip reactor. b. GO TO EP/11A15000/E-0 (Reactor Trip Or Safety Injection).

IF 214 S/G N/R levels on anyone S/G are greater than 83%, THEN: a. Verify all Feedwater Isolation status lights (1SI-5) -LIT. b. IF any Feedwater Isolation status light is not lit, THEN: _ 1) Manually initiate Feedwater Isolation.

_ 2) IF proper status light indication is not obtained, THEN manually close affected valve(s).

1A CA pump feeds AlB S/Gs 1 B CA pump feeds C/D S/Gs CAPT feeds all S/Gs CNS LOSS OF S/G FEEDWATER PAGE NO. AP/1/A/55001006 Case I 2 of20 Loss of CF Supply To S/Gs Rev 40 ACTION/EXPECTED RESPONSE C. QRerator Actions -0 IRO IRO J

3.

fIQ"",,¥GREATER .ItlAN CAPT #1 should have been secured already and since B train has no power and A CA pump autostart is failed, they will start A CA manually.

RESPONSE NOT OBTAINED IF AT ANY TIME all CF supply to S/G(s) lost, THEN perform the following:

a. Manually trip reactor. b. GO TO EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).

IF 214 S/G N/R levels on anyone S/G are greater than 83%, THEN: a. Verify all Feedwater Isolation status lights (1SI-5) -LIT. b. IF any Feedwater Isolation status light is not lit, THEN: _ 1) Manually initiate Feedwater Isolation.

_ 2) IF proper status light indication is not obtained, THEN manually close affected valve(s).

,{5,';:'

1A CA pump feeds AlB S/Gs 1 B CA pump feeds C/D S/Gs CAPT feeds all S/Gs CNS LOSS OF S/G FEEDWATER PAGE NO. AP/1/A155001006 Case I 30f20 Loss of CF Supply To S/Gs Rev 40 ACTION/EXPECTED RESPONSE 4. II1II ........ ,1 _ _ B

_fL ** 6. Ensure compliance with appropriate Tech Specs and SLCs:

3.3.2 (ESFAS Instrumentation)

3.7.5 (Auxiliary Feedwater System)

SLC 16-7.1 (AMSAC). 7. Determine required notifications:

REFER TO RP/0IAl50001001 (Classification Of Emergency)

REFER TO RP/0/B/50001013 (NRC Notification Requirements).

8. Determine and correct cause of loss of CF supply. 9. Verify at least one CF Pump* ON. RESPONSE NOT OBTAINED a. Maintain total feed flow greater than 450 GPM to intact S/Gs until at least one S/G N/R level greater than 11 %. MAJOR EVENT WILL BE INSERTED WHEN THIS STEP IS READ _ Perform a hot restart of one CF Pump. REFER TO OP/1/A16250/001 (Condensate and Feedwater System). CNS LOSS OF S/G FEEDWATER PAGE NO. AP/1/A/55001006 Case I 3 of 20 Loss of CF Supply To S/Gs Rev 40 ACTION/EXPECTED RESPONSE _ fa';;

11;1;%'* _ b.1 ,WHEN at gteqter ,flbW tQetwee:[]

5. 6. Ensure compliance with appropriate Tech Specs and SLCs:

3.3.2 (ESFAS Instrumentation)

3.7.5 (Auxiliary Feedwater System)

SLC 16-7.1 (AMSAC). 7. Determine required notifications:

REFER TO RP/O/A/50001001 (Classification Of Emergency)

REFER TO RP/O/S/50001013 (NRC Notification Requirements).

8. Determine and correct cause of loss of CF supply. 9. Verify at least one CF Pump -ON. RESPONSE NOT OBTAINED a. Maintain total feed flow greater than 450 GPM to intact S/Gs until at least one S/G N/R level greater than 11 %. MAJOR EVENT WILL BE INSERTED WHEN THIS STEP IS READ _ Perform a hot restart of one CF Pump. REFER TO OP/lIAl6250/001 (Condensate and Feedwater System).

MAJOR EVENT START Initiating cue: 1AD-3, AJ1 MAJOR EVENT START Initiating cue: 1AD-3, AJ1 CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 1 of 61 Rev 36 A. Purpose This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of all Reactor Trips and 5/1 above P-11, valid 5/1 below P-11 and to assess plant conditions, and to identify the appropriate recovery procedure.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1 I A/SOOO/E-O 1 of 61 Rev 36 DCE A. Purpose This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of all Reactor Trips and 5/1 above P-11, valid 5/1 below P-11 and to assess plant conditions, and to identify the appropriate recovery procedure.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 2 of61 Rev 36 B. Symptoms or Entry Conditions

1. The following conditions are symptoms that require a Reactor Trip:

1 of 2 SIR channels -GREATER THAN 10 5 CPS WHILE BELOW P-6

1 of 2 IIR channels -GREATER THAN 25% FULL POWER AMPS EQUIVALENT WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 25% FULL POWER WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 109% FULL POWER

2 of 4 P/R channels -+5% FULL POWER IN 2 SECONDS

2 of 4 loop LlTs -GREATER THAN THE OPLlT SETPOINT

2 of 4 loop LlTs -GREATER THAN THE OTLlT SETPOINT

2 of 4 Pzr pressure channels -GREATER THAN 2385 PSIG

2 of 4 Pzr pressure channels -LESS THAN 1945 PSIG WHILE ABOVE P-7

2 of 3 Pzr level channels -GREATER THAN 92% WHILE ABOVE P-7

2 of 4 S/G N/R level channels on 1 of 4 S/Gs -LESS THAN LO-LO SETPOINT

2 of 4 NC pump buses -LESS THAN 77% OF NORMAL VOLTAGE (5082 VOLTS) WHILE ABOVE P-7

2 of 4 NC pump buses -LESS THAN 56 HERTZ WHILE ABOVE P-7

2 of 3 NC flow channels on 2 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-7 AND BELOW P-8

2 of 3 NC flow channels on 1 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-8

4 of 4 turbine stop valves -CLOSED WHILE ABOVE P-9

2 of 4 turbine stop valves EHC pressure -LESS THAN 550 PSIG WHILE ABOVE P-9

1 of 2 SII trains -ACTUATED

2 of 2 SSPS trains -GENERAL WARNING ALARM. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 2 of 61 Rev 36 DeE B. Symptoms or Entry Conditions

1. The following conditions are symptoms that require a Reactor Trip:

1 of 2 SIR channels -GREATER THAN 10 5 CPS WHILE BELOW P-6

1 of 2 IIR channels -GREATER THAN 25% FULL POWER AMPS EQUIVALENT WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 25% FULL POWER WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 109% FULL POWER

2 of 4 P/R channels -+5% FULL POWER IN 2 SECONDS

2 of 4 loop ilTs -GREATER THAN THE OPilT SETPOINT

2 of 4 loop ilTs -GREATER THAN THE OTilT SETPOINT

2 of 4 Pzr pressure channels -GREATER THAN 2385 PSIG

2 of 4 Pzr pressure channels -LESS THAN 1945 PSIG WHILE ABOVE P-7

2 of 3 Pzr level channels -GREATER THAN 92% WHILE ABOVE P-7

2 of 4 S/G N/R level channels on 1 of 4 S/Gs -LESS THAN LO-LO SETPOINT

2 of 4 NC pump buses -LESS THAN 77% OF NORMAL VOLTAGE (5082 VOLTS) WHILE ABOVE P-7

2 of 4 NC pump buses -LESS THAN 56 HERTZ WHILE ABOVE P-7

2 of 3 NC flow channels on 2 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-7 AND BELOW P-8

2 of 3 NC flow channels on 1 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-8

4 of 4 turbine stop valves -CLOSED WHILE ABOVE P-9

2 of 4 turbine stop valves EHC pressure -LESS THAN 550 PSIG WHILE ABOVE P-9

1 of 2 SII trains -ACTUATED

2 of 2 SSPS trains -GENERAL WARNING ALARM.

CNS REACTOR TRIP OR SAFETY INJECTION EP/1/A15000/E-O

2. The following are symptoms of a Reactor Trip:

Any Reactor Trip annunciator

-LIT

Neutron level -RAPIDLY DECREASING

Rod bottom lights -LIT. 3. The following are symptoms that require a Reactor Trip and SII:

2 of 4 Pzr pressure channels -LESS THAN 1845 PSIG

2 of 3 containment pressure channels -GREATER THAN 1.2 PSIG. 4. The following are symptoms of a Reactor Trip and S/I:

Any SII Reactor Trip annunciator

-LIT

NV, NI, and ND pumps -ON * "SAFETY INJECTION ACTUATED" status light (1SI-13) -LIT

E/S Load Sequencer Actuated status lights (1SI-14) -LIT. PAGE NO. 30f61 Rev 36 DeS CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 3 of 61 Rev 36 DC!: 2. The following are symptoms of a Reactor Trip:

Any Reactor Trip annunciator

-LIT

Neutron level -RAPIDLY DECREASING

Rod bottom lights -LIT. 3. The following are symptoms that require a Reactor Trip and 5":

2 of 4 Pzr pressure channels -LESS THAN 1845 PSIG

2 of 3 containment pressure channels -GREATER THAN 1.2 PSIG. 4. The following are symptoms of a Reactor Trip and 5/1:

Any SII Reactor Trip annunciator

-LIT

NV, NI, and ND pumps -ON * "SAFETY INJECTION ACTUATED" status light (1SI-13) -LIT

EIS Load Sequencer Actuated status lights (1SI-14) -LIT.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE C. Operator Actions RO DOES THIS PAGE RESPONSE NOT OBTAINED Perform the following:

a. Manually trip r.eactor.

b. IF reactor will not trip, THEN concu rrently: 40f61 Rev 36

Implement EP/1/A/5000/F-O (Critical Safety Function Status Trees) .

GO TO EP/1/A/5000/FR-S.1 (Response To Nuclear Power Generation/ATWS).

Perform the following:

a. Manually trip the turbine. b. IF turbine will not trip, THEN: _ 1) Depress the "MANUAL" pushbutton on the turbine control panel. _ 2) Rapidly unload turbine by simultaneously depressing the "CONTROL VALVE LOWER" and "FAST RATE" pushbuttons.

3) IF turbine will not runback, THEN close:

All MSIVs

All MSIV bypass valves. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE c. Operator Actions RO DOES THIS PAGE All

_ .t\J1

QPEN" _

fLR o

_

RESPONSE NOT OBTAINED Perform the following:

a. Manually trip reactor. b. IF reactor will not trip, THEN concurrently:

40f61 Rev 36

Implement EP/1/A/SOOO/F-O (Critical Safety Function Status Trees) .

GO TO EP/1/A/SOOO/FR-S.1 (Response To Nuclear Power Generation/ATWS).

Perform the following:

a. Manually trip the turbine. b. IF turbine will not trip, THEN: _ 1) Depress the "MANUAL" pushbutton on the turbine control panel. _ 2) Rapidly unload turbine by simultaneously depressing the "CONTROL VALVE LOWER" and "FAST RATE" pushbuttons.

3) IF turbine will not runback, THEN close:

All MSIVs _

All MSIV bypass valves.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE BOP DOES THIS PAGE 1ETB is NOT energized

a.

b. 50f61 Rev 36 DC:: RESPONSE NOT OBTAINED

a. IF 1 ETA AND 1 ETB are de-energized, THEN GO TO EP/1/A15000/ECA-O.O (Loss Of All AC Power). b. a. Perform the following:

1) Verify conditions requiring S/I: _. Pzr pressure -LESS THAN 1845 PSIG OR _

Containment pressure -GREATER THAN 1.2 PSIG. _ 2) IF S/I is required, THEN manually initiate S/I. 3) IF S/I is not required, THEN concu rrently:

Implement EP/1/A15000/F-O (Critical Safety Function Status Trees) .

GO TO EP/1/A15000/ES-O.1 (Reactor Trip Response).

b. Manually initiate S/I. They may choose to manually initiate S/I but the B sequencer breaker was opened previously and this step will not accomplish anything.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O I ACTION/EXPECTED RESPONSE -0 Verify ILlV" LI,V'ES THIS PAGE o Verify 1ETB is NOT energized

a.

b.

50f61 Rev 36 DC:: RESPONSE NOT OBTAINED i?eriorm

a. IF 1 ETA AND 1 ETB are de-energized, THEN GO TO EP/1/A/5000/ECA-O.O (Loss Of All AC Power). b. WHEN to;

p(ocedt.lt@: REF:ER{:!fo.

P ""XX " ",ower)\;:'

a. Perform the following:

1} Verify conditions requiring S/I: _. Pzr pressure -LESS THAN 1845 PSIG OR _

Containment pressure -GREATER THAN 1.2 PSIG. _ 2} IF S/I is required, THEN manually initiate S/I. 3} IF S/I is not required, THEN concurrently:

Implement EP/1/A/5000/F-O (Critical Safety Function Status Trees) .

GO TO EP/1/A/5000/ES-O.1 (Reactor Trip Response).

b. Manually initiate S/I. They may choose to manually initiate S/I but the B sequencer breaker was opened previously and this step will not accomplish anything.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O ACTION/EXPECTED RESPONSE 7 .

IBOP 1 9.

b.

60f61 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Manually initiate Feedwater Isolation.

b. IF proper status light indication is not obtained, THEN manually close valves. a. Manually initiate Phase A Isolation.

1 BB-56A has failed to close and B train BB valve is not closed due to loss of power, so there is a direct path from containment.

a. Perform the following:

This time may be used later to determine when to align ND Aux spray. _ 1) Record approximate time of reactor trip. _ 2) Verify NS pumps -INDICATING FLOW. _ 3) IF flow is not indicated, lIiHEN manually initiate Phase B Isolation for affected train(s). (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 ACTION/EXPECTED RESPONSE 7 IBOP 1 9. 10. IBOP I

a.

b.

LII.; ICRITICAL TASK folloWs: a;c RI:?MAI 6 of 61 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Manually initiate Feedwater Isolation.

b. IF proper status light indication is not obtained, THEN manually close valves. _ a. Manually initiate Phase A Isolation.

'pi' I 1 BB-56A has failed to close and B train BB valve is not closed due to loss of power, so there is a direct path from containment.

a. Perform the following:

This time may be used later to determine when to align ND Aux spray. _ 1) Record approximate time of reactor trip. _ 2) Verify NS pumps -INDICATING FLOW. _ 3) IF flow is not indicated, THEN manually initiate Phase B Isolation for affected train(s). (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTIONIEXPECTED RESPONSE 10. (Continued) 7 of 61 Rev 36 RESPONSE NOT OBTAINED 4) Verify Phase B Isolation has actuated as follows: _ a) Phase B Isolation "RESET" lights -DARK. _ b) IF Phase B Isolation "RESET" lights are lit, THEN manually initiate Phase B Isolation.

c) Verify following monitor light panel lights -LIT:

Group 1 Sp lights

Group 5 Sp lights

Group 5 St lights Ll11 and Ll12. _ d) IF monitor light panel not in correct alignment, THEN ensure correct alignment.

e) IF NS pump(s) did not start, THEN perform the following for the affected train(s):

_ (1) Reset ECCS. _ (2) Reset DIG load sequencer.

_ (3) Manually start affected NS pump. _ (4) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on. _ 5) Stop all NC pumps. _ 6) Maintain seal injection flow. _ 7) Energize H2 igniters. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE 10. (Continued) 7 of 61 Rev 36 RESPONSE NOT OBTAINED 4) Verify Phase 8 Isolation has actuated as follows: _ a) Phase 8 Isolation "RESET" lights -DARK. _ b) IF Phase 8 Isolation "RESET" lights are lit, THEN manually initiate Phase 8 Isolation.

c) Verify following monitor light panel lights -LIT:

Group 1 Sp lights

Group 5 Sp lights

Group 5 St lights Ll11 and Ll12. _ d) IF monitor light panel not in correct alignment, THEN ensure correct alignment.

e) IF NS pump(s) did not start, THEN perform the following for the affected train(s):

_ (1) Reset ECCS. _ (2) Reset DIG load sequencer.

_ (3) Manually start affected NS pump. _ (4) IF AT ANY TIME a 8/0 occurs, THEN restart SII equipment previously on. _ 5) Stop all NC pumps. _ 6) Maintain seal injection flow. _ 7) Energize H2 igniters. (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 ACTION/EXPECTED RESPONSE 10. (Continued)

b. a. b. No B train power so should not go to RNO. 8of61 Rev 36 RESPONSE NOT OBTAINED 8) Dispatch operator to perform the following:

_ a) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ b) Place containment H2 analyzers in service. REFER TO OP/1/N6450101 0 (Containment Hydrogen Control Systems).

_ 9) WHEN 9 minutes has elapsed, THEN verify proper VX system operation.

REFER TO Enclosure 7 (VX System Operation).

_10) GO TO Step 11. a. Perform the following for the affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected motor driven CA pump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 ACTION/EXPECTED RESPONSE 10. (Continued) b .IF A ll;ANYtffIME ih}tl}is THEN 11 .

f()(Igws:.

a.

No B train power so should not go to RNO. b.

11%/; 8 of 61 Rev 36 DC:: RESPONSE NOT OBTAINED 8) Dispatch operator to perform the following:

_ a) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ b) Place containment H2 analyzers in service. REFER TO OP/1/N6450/01 0 (Containment Hydrogen Control Systems).

_ 9) WHEN 9 minutes has elapsed, THEN verify proper VX system operation.

REFER TO Enclosure 7 (VX System Operation).

_10) GO TO Step 11. a. Perform the following for the affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected motor driven CA pump. _ 4) IF AT ANY TIME a B/O occurs, THEN restart S/I equipment previously on.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O

14. ACTION/EXPECTED RESPONSE 1A NO pump must be manually started. CRITICAL TASK!

No 8 train power so should not go to RNO. No 8 train power so should not go to RNO. 18 RN has no power, but 28 is running.

pgi¥fttili'gl!ii;I§11§IJI!!I:'

9 of 61 Rev 36 RESPONSE NOT OBTAINED Perform the following for affected train(s):

a. Reset ECCS. b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. Perform the following:

a. IF any Unit 2 RN pump is off, THEN manually start affected pump(s). b. IF any Unit 1 RN pump is off, THEN perform the following for affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected pump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O IBOP 15. ACTIONIEXPECTED RESPONSE 1A ND pump must be manually started. CRITICAL TASK! No B train power so should not go to RNO. No B train power so should not go to RNO. 1 B RN has no power, but 2B is running.

_ .

$9;$t¢ITfVerif\@§ti6n)J _ * .

9 of 61 Rev 36 RESPONSE NOT OBTAINED a; ResetfGCS;;" b.

dv:

fe$1l;lI:r$I!!9vl'l1 i ptl"ie,hfp'reviously

.. q"8. Perform the following for affected train(s):

a. Reset ECCS. b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a 8/0 occurs, THEN restart SII equipment previously on. Perform the following:

a. IF any Unit 2 RN pump is off, THEN manually start affected pump(s). b. IF any Unit 1 RN pump is off, THEN perform the following for affected train(s ): _ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected pump. _ 4) IF AT ANY TIME a 8/0 occurs, THEN restart SII equipment previously on.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-0 ACTION/EXPECTED RESPONSE 17. EWMt'MflilJlllbilWiiflWlJ r::::'IB-=-O=-p-'1

_ a. ' ............

IJIIIItl7IJ 10 of 61 Rev 36 RESPONSE NOT OBTAINED II __

_ ...... _ : ** b. IF any valve is open, THEN: _ 1) Manually initiate Main Steam Isolation.

_ 2) IF any valve is still open, THEN manually close valve. a. Manually start NV pump(s) and align valves. b. Perform the following:

_ 1) Ensure ND pump miniflow valve on operating ND pump(s) -OPEN. 2) IF ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop ND pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. _ 3) GO TO Step 18. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-0 ACTION/EXPECTED RESPONSE IRO 16.

17. r:::-::-:::::--, IBOP I 10 of 61 Rev 36 DC:: RESPONSE NOT OBTAINED PerfpIfll thelfgUdWil1g:

a., Ve'tifylb,e f()J1owing Valve'$': " IAIF:MSIWs

-_ ' . ",A:, ,,' : yp "'" ..... ,,",,.,.:

...

AIIl§LG PORVs> b. IF any valve is open, THEN: _ 1) Manually initiate Main Steam Isolation.

_ 2) IF any valve is still open, THEN manually close valve. a. Manually start NV pump(s) and align valves. b. Perform the following:

_ 1) Ensure ND pump miniflow valve on operating ND pump(s) -OPEN. 2) IF ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop ND pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart S/I equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. _ 3) GO TO Step 18.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE 17. (Continued)

e. NO pumps -INDICATING FLOW TO C-LEGS. 11 of 61 Rev 36 RESPONSE NOT OBTAINED _ c. Manually start NI pump(s) and align valves.

_ 1) _lmlllllllllltJllttlJ..-_

IRIlYMlJlfJD1IGIIIJIBI

2) IF the NO pump miniflow valve(s) cannot be opened. THEN perform the following for affected train(s):

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop NO pump. _ d) IF AT ANY TIME a BIO occurs. THEN restart SII equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner. THEN restart the NO pump. e. Manually start NO pump(s) and align valves. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O IBOP I ACTION/EXPECTED RESPONSE 17. (Continued)

d. NC 28qPSIGr e. ND pumps -INDICATING FLOW TO C-LEGS. 11 of 61 Rev 36 RESPONSE NOT OBTAINED c. Manually start NI pump(s) and align valves. _ 1) op&[aiing NO pl(rT),R{

Q1ill=N;e

2) IF the ND pump miniflow valve{s) cannot be opened, THEN perform the following for affected train(s):

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop ND pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. e. Manually start ND pump(s) and align valves.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0

20. ACTION/EXPECTED RESPONSE Flow may be less than 450 gpm due to operator action. IBOP I .. _IEID IRO I 12of61 Rev 36 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF N/R level in all S/Gs is less than 11 % (29% ACC), THEN manually start CA pumps and ensure correct valve alignment.

2) IF N/R level in all S/Gs is less than 11 % (29% ACC) AND feed flow greater than 450 GPM cannot be established, THEN concurrently:

_. Implement EP/1/A1S000/F-0 (Critical Safety Function Status Trees).

GO TO EP/1/A15000/FR-H.1 (Response To Loss Of Secondary Heat Sink). _ Manually open valve(s).

_ Manually align equipment.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 ACTION/EXPECTED RESPONSE 18. (;ontrgl foll§ws: 20. IBOP a.'

GRi::!\TJ=RTHAN

.4QO Flow may be less than 450 gpm due to operator action. b.

S/G:N/RleveL;i§'

greater than')1 % {29%ACC),THBNr th rqttleJee,g yalves:-OPEN. 120f61 Rev 36 DC:: RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF N/R level in all S/Gs is less than 11 % (29% ACC), THEN manually start CA pumps and ensure correct valve alignment.

2) IF N/R level in all S/Gs is less than 11 % (29% ACC) AND feed flow greater than 450 GPM cannot be established, THEN concurrently:

Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees) .

GO TO EP/1/A/5000/FR-H.1 (Response To Loss Of Secondary Heat Sink). _ Manually open valve(s).

_ Manually align equipment.

NOTE*

_ . REIi:ERTO CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE 1§!llY§11 11§,J(gllg:!l§lli 13 of 61 Rev 36 RESPONSE NOT OBTAINED a. IF Pzr pressure is less than 2315 PSIG, THEN: _ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve. 3) IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:

_ a) Energize H2 igniters.

b) Dispatch operator to perform the following:

_ (1) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ (2) Place containment H2 analyzers in service. REFER TO OP/1/A164501010 (Containment Hydrogen Control Systems). (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O

22. IBOP I ACTION/EXPECTED RESPONSE ari.d ;pzr foHC)W$: 13 of 61 Rev 36 RESPONSE NOT OBTAINED a. IF Pzr pressure is less than 2315 PSIG, THEN: _ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve. 3) IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:

_ a) Energize H2 igniters.

b) Dispatch operator to perform the following:

_ (1) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ (2) Place containment H2 analyzers in service. REFER TO OP/1/A/6450/010 (Containment Hydrogen Control Systems). (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 ACTION/EXPECTED RESPONSE 22. (Continued) 14 of 61 Rev 36 DCS RESPONSE NOT OBTAINED c} IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). d} Concurrently:

Implement EP/1/A15000/F-0 (Critical Safety Function Status Trees).

GO TO EP/1/A15000/E-1 (Loss Of Reactor Or Secondary Coolant).

b. IF Pzr pressure is less than 2260 PSIG, THEN: _ 1} Manually close spray valve(s}.

2} IF spray valve(s} cannot be closed, THEN: _ a} Stop NC pumps 1A and 1 B. _ b} IF NC pressure continues to decrease, THEN stop third NC pump as required.

c. IF power is available, THEN open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV. IF any NV OR NI pump is on, THEN: a. Ensure all NC pumps -OFF. b. Maintain seal injection flow. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE 22. (Continued)

_ \g3.

14 of 61 Rev 36 RESPONSE NOT OBTAINED c) IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). d) Concurrently:

Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).

GO TO EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant).

b. IF Pzr pressure is less than 2260 PSIG, THEN: _ 1) Manually close spray valve(s).

2) IF spray valve(s) cannot be closed, THEN: _ a) Stop NC pumps 1Aand 1B. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required.

c. IF power is available, THEN open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV. IF any NV OR NI pump is on, THEN: a. Ensure all NC pumps -OFF. b. Maintain seal injection flow.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O ACTION/EXPECTED RESPONSE 24.

- *** II'II'

25. Verify S/G tubes are intact as follows:

Verify the following EMF trip 1 DARK:

1 EMF-33 (Condenser Air Ejector Exhaust)

1 EMF-26 (Steamline 1A)

1EMF-27 (Steamline 1B)

1 EMF-28 (Steamline 1 C)

1 EMF-29 (Steamline 1 D).

All S/G levels -STABLE OR INCREASING IN A CONTROLLED MANNER. 15 of 61 Rev 36 RESPONSE NOT OBTAINED a. IF both the following conditions exist, _. Containment pressure -GREATER THAN 1 PSIG _. Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). b. _1MIIfD * ..I."'.t ",',

<, IF any EMF trip 1 light is lit OR any S/G level is increasing in an uncontrolled manner, THEN concurrently:

_. Implement EP/1/N5000/F-O (Critical Safety Function Status Trees). _. GO TO EP/1/N5000/E-3 (Steam Generator Tube Rupture).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11 Al5000/E-O ACTION/EXPECTED RESPONSE 24.

fQUQ,Vis: :,l\lIlliS/Gi1:

r ssiJf',:'R,'ST:ABLEOR

_ '" """"v'

",'

'8,'_ ' ,v '

11, ALL

25. Verify S/G tubes are intact as follows:

Verify the following EMF trip 1 DARK:

1 EMF-33 (Condenser Air Ejector Exhaust)

1 EMF-26 (Steamline 1A)

1 EMF-27 (Steamline 1 B)

1 EMF-28 (Steamline 1 C)

1 EMF-29 (Steamline 1 D) .

All S/G levels -STABLE OR INCREASING IN A CONTROLLED MANNER. 15 of 61 Rev 36 RESPONSE NOT OBTAINED IF press tire ir'l'TaUY OR;<;JDY SIG;,is!

following:

a. IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). b.

_

EPWIN50aO/F-O (QritR:al IF any EMF trip 1 light is lit OR any S/G level is increasing in an uncontrolled manner, THEN concurrently:

_. Implement EP/1/A15000/F-O (Critical Safety Function Status Trees). _. GO TO EP/1/A15000/E-3 (Steam Generator Tube Rupture).

CNS REACTOR TRIP OR SAFETY INJECTION EP/1/N5000/E-0 -Page 1 of 1 Foldout Page 1. IF any S/G(s) suspected ruptured, THEN perform the following:

WHEN the following conditions met:

Total CA flow -GREATER THAN 450 GPM AND

All intact S/G(s) N/R level -GREATER THAN 11 %(29% ACC) PAGE NO. 320f61 Rev 36 THEN throttle feed flow to ruptured S/G(s) to maintain ruptured S/G(s) N/R level between 11 %(29% ACC) and 39%. 2. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NVor NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO OaF. 3. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO AP/1/N55001006 (Loss of S/G Feedwater):

1AD-5, H/4 "CACST LO LEVEL" OR

1AD-8, B/1 "UST LO LEVEL". 4. Position Criteria for 1 NV*2028 and 1 NV*203A (NV Pumps A&8 Recirc Isol):

IF NC pressure is less than 1500 PSIG AND NV SII flowpath is aligned, THEN close 1 NV-202B and 1 NV-203A.

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-202B and 1 NV-203A. 5. Cold Leg Recirc Switchover Criterion:

IF FWST level decreases to 37% (1AD-9, 0/8 "FWST 2/4 LO LEVEL" lit), AND an S/I has occurred, THEN GO TO EP/1/N5000/ES-1.3 (Transfer To Cold Leg Recirculation).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 -Page 1 of 1 32 of 61 Foldout Page Rev 36 1. IF any S/G(s) suspected ruptured, THEN perform the following:

WHEN the following conditions met:

Total CA flow -GREATER THAN 450 GPM

All intact S/G(s) N/R level -GREATER THAN 11 %(29% ACC) THEN throttle feed flow to ruptured S/G(s) to maintain ruptured S/G(s) N/R level between 11 %(29% ACC) and 39%. 2. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NV or NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO O°F. 3. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO AP/1/N55001006 (Loss of S/G Feedwater):

1AD-5, H/4 "CACST LO LEVEL" OR

1 AD-8, 8/1 "UST LO LEVEL". 4. Position Criteria for 1 NV-202B and 1 NV-203A (NV Pumps A&B Recirc 1501):

IF NC pressure is less than 1500 PSIG AND NV SII flowpath is aligned, THEN close 1 NV-2028 and 1 NV-203A.

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-2028 and 1 NV-203A. 5. Cold Leg Recirc Switchover Criterion:

IF FWST level decreases to 37% (1AD-9, 0/8 "FWST 2/4 LO LEVEL" lit), AND an SII has occurred, THEN GO TO EP/1/N5000/ES-1.3 (Transfer To Cold Leg Recirculation).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-O -Page 1 of 7 33 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1. II BOP DOES THIS ENCLOSURE

a. Perform the following:

_ 1) Shift operating VCIYC trains. REFER TO Enclosure 6 (Shifting Operating VCIYC Train). 2) IF no train can be properly aligned. THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:

_. OP/O/AI6450/011 (Control Room Area Ventilation/Chilled Water System)

EM/O/Al5200/001 (Troubleshooting Cause For Improper Operation of VCIYC System). CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 1 of 7 33 of 61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE 18. Verify one tr,?ipof thelolloWiQg; equipmenti§,:;m}qperatiop:

RESPONSE NOT OBTAINED BOP DOES THIS ENCLOSURE

a. Perform the following:

_ 1} Shift operating VCIYC trains. REFER TO Enclosure 6 (Shifting Operating VCIYC Train). 2} IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:

OP/O/A/64501011 (Control Room Area Ventiiation/Chilied Water System)

EM/O/A/52001001 (Troubleshooting Cause For Improper Operation of VCIYC System).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-O -Page 2 of 7 34 of 61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1. (Continued)

b. b. IF chlorine odor is detected in the Control Room, THEN perform the following based on the status of given alarms: 1) IF detectors on both unit intakes are in alarm, THEN: a) Ensure the following VC intake dampers -CLOSED:

1VC-S8 (CRA Filt Inlet)

1VC-6A (CRA Filt Inlet)

2VC-S8 (CRA Filt Inlet)

2VC-6A (CRA Filt Inlet). _ b) GO TO Step 1.d. 2) IF Unit 1 intake HI chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 1VC-S8 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). b) Ensure the following dampers -OPEN: _

2VC-S8 (CRA Filt Inlet) _

2VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-O -Page 2 of 7 34 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 1. (Continued)

b.

theTQIJQwing

.;1A@,,18,

_ _ * . RESPONSE NOT OBTAINED b. IF chlorine odor is detected in the Control Room, THEN perform the following based on the status of given alarms: 1) IF detectors on both unit intakes are in alarm, THEN: a) Ensure the following VC intake dampers -CLOSED:

1 VC-S8 (CRA Filt Inlet)

1VC-6A (CRA Filt Inlet)

2VC-S8 (CRA Filt Inlet)

2VC-6A (CRA Filt Inlet). _ b) GO TO Step 1.d. 2) IF Unit 1 intake HI chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 1VC-S8 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). b) Ensure the following dampers -OPEN: _

2VC-S8 (CRA Filt Inlet) _

2VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d. (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 3 of 7 35 of 61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1. (Continued)

c. 3) IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _

2VC-58 (CRA Filt Inlet) _

2VC-6A (CRA Filt Inlet). b) Ensure the following dampers -OPEN: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 3 of 7 35 of 61 Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE 1. (Continued)

c. !;Dsgfe the fPII9wijjQI,IC

-\QflpN:

_

_.

d tbis:enctq:SureY!,lj11il, o'Qtified

_-

QB ;.Lt;tX.tl;lime VC/YC relatea annl.lnCiatots

_ "., .. ,.Y ...*..... , .......... u. . .*.*.** , ... <....... . .... u.

RESPONSE NOT OBTAINED 3) IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _

2VC-58 (CRA Filt Inlet) _

2VC-6A (CRA Filt Inlet). b) Ensure the following dampers -OPEN: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-O -Page 4 of 7 36 of 61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED B train VA is powered from Unit 2 and therefore is unaffected by the 1 B train blackout.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 4 of 7 36 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 2. .

fQU9VfS:)

JanS't"'OFf;j

"A:ElUXF '1B\

iSli ll setyiceas

;t 1 ABF:":":[DL12

&.1 g'V,Vlf,.'

FHter. A.8 ass . ... " .............

'.... '\ .... " ....,yp, Darf:j:tt§[s,)

.. 1 Bypass' Da* .. *;ers).

.*.* rQJ? .,., d, ,

A§PXF-1A

RESPONSE NOT OBTAINED B train VA is powered from Unit 2 and therefore is unaffected by the 1 B train blackout.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 -Page 5 of 7 37 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 3.

a. b. This will be correct for A train, no power to B train. RESPONSE NOT OBTAINED a. Manually start fan{s). b. Perform the following: 1 ) IF annulus pressure is more positive than -1.4 in. WC, THEN: a) Verify flow indicated on the following indications:

"VE 1A FLOW TO STACK" * "VE 1 B FLOW TO STACK". b) IF flow is not indicated, THEN dispatch operator to verify status of the following dampers based on their local indication or their operating piston rods being extended 4" to 6":

1AVS-D-2 (VE A Trn Recirc Damp) (AB-603, JJ-51, Rm 500) -CLOSED

1AVS-D-7 (VE B Trn Recirc Damp) (AB-603, HH-52, Rm 500) -CLOSED

1AVS-D-3 (VE A Trn Exh Damp) (AB-603, JJ-52, Rm 500) -OPEN

1 AVS-D-8 (VE B Trn Exh Damp) (AB-603, HH-52, Rm 500) -OPEN. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A152001002 (Troubleshooting Cause For VE System Hi/lo Pressure).

_ d) GO TO Step 3.c. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 -Page 5 of 7 37 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 3.

b.Afll'\ulus

-1:,4;;IN.

This will be correct for A train, no power to B train. RESPONSE NOT OBTAINED a. Manually start fan{s). b. Perform the following: 1 ) IF annulus pressure is more positive than -1.4 in. WC, THEN: a) Verify flow indicated on the following indications:

"VE 1 A FLOW TO STACK" * "VE 1 B FLOW TO STACK". b) IF flow is not indicated, THEN dispatch operator to verify status of the following dampers based on their local indication or their operating piston rods being extended 4" to 6":

1 AVS-D-2 (VE A Trn Recirc Damp) (AB-603, JJ-51, Rm 500) -CLOSED

1AVS-D-7 (VE B Trn Recirc Damp) (AB-603, HH-52, Rm 500) -CLOSED

1AVS-D-3 (VE A Trn Exh Damp) (AB-603, JJ-52, Rm 500) -OPEN

1 AVS-D-8 (VE B Trn Exh Damp) (AB-603, HH-52, Rm 500) -OPEN. _ c) Consult plant engineering staff and notify IAEIMaintenance to troubleshoot and repair. REFER TO EM/1/A152001002 (Troubleshooting Cause For VE System Hi/lo Pressure).

_ d) GO TO Step 3.c. (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 6 of 7 38 of 61 Ventilation System Verification Rev 36 DC::: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3. (Continued)

2) IF annulus pressure is more negative than -1.8 in. WC, THEN: _ a) Determine which VE train indicates highest discharge flow to stack. _ b) Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , ensure VE train that indicates highest discharge flow to stack is secured. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A152001002 (Troubleshooting Cause For VE System Hillo Pressure).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 6 of 7 38 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 3. (Continued)

c.

iIliltI!:'

RESPONSE NOT OBTAINED 2) IF annulus pressure is more negative than -1.8 in. WC, THEN: _ a) Determine which VE train indicates highest discharge flow to stack. _ b) Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , ensure VE train that indicates highest discharge flow to stack is secured. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A/5200/002 (Troubleshooting Cause For VE System HilLa Pressure).

CNS REACTOR TRIP OR SAFETY INJECTION EP/1/Al5000/E-O -Page 7 of 7 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 4. Record time ventilation systems are verified on following table: TIME SYSTEM (VC. VE) INITIALS PAGE NO. 39 of 61 Rev 36 CNS REACTOR TRIP OR SAFETY INJECTION EP/1/ NSOOO/E-O -Page 7 of 7 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 4. Record time ventilation systems are verified on following table: TIME SYSTEM (VC, VE) INITIALS PAGE NO. 39 of 61 Rev 36 CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 1 of 4 41 of61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE IRO DOES THIS

2.

J§tgB.§1 4

NC temperature

-STABLE AT LESS THAN OR EQUAL TO 55rF. OR

NC temperature

-TRENDING TO 55rF. 5. Continue to monitor NC temperature.

RESPONSE NOT OBTAINED Perform the following:

a. Use NC T -Colds to determine NC temperature as required in subsequent steps. b. GO TO Step 4. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 1 of 4 41 of61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE IRO DOES THIS ENCLOSURE 2 .lJ§:el:Jj,i,T-Avator;:lg}errtlifje Nq rec:nUredl(}

slElA§'f;

,31, ,THENspse NeT-Colas Net

NC temperature

-STABLE AT LESS THAN OR EQUAL TO 55rF. OR

NC temperature

-TRENDING TO 55rF. 5. Continue to monitor NC temperature.

I RESPONSE NOT OBTAINED Perform the following:

a. Use NC T -Colds to determine NC temperature as required in subsequent steps. b. GO TO Step 4.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 2 of 4 42 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE 6. Do not continue in this enclosure until one of the following occurs:

NC temperature

-GREATER THAN 557°F AND INCREASING IN AN UNCONTROLLED MANNER. OR

NC temperature

-GREATER THAN 557°F AND STABLE. OR

NC temperature

-LESS THAN 55rF AND DECREASING IN AN UNCONTROLLED MANNER. RESPONSE NOT OBTAINED Perform the following:

a. IF NC temperature is greater than 55rF AND increasing, THEN stabilize NC temperature at 55rF as follows: 1) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use S/G PORVs. b. IF the following conditions exist:

NC temperature is greater than 55rF and stable

Time and manpower is available, THEN stabilize NC temperature at 55rF as follows: 1) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use S/G PORVs. c. GO TO Step 9. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 2 of 4 42 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE 6. Do not continue in this enclosure until one of the following occurs:

NC temperature

-GREATER THAN 55]oF AND INCREASING IN AN UNCONTROLLED MANNER. OR

NC temperature

-GREATER THAN 55]oF AND STABLE. OR

NC temperature

-LESS THAN 55]oF AND DECREASING IN AN UNCONTROLLED MANNER. 7. -LESSIJ:;IAN RESPONSE NOT OBTAINED Perform the following:

a. IF NC temperature is greater than 55]oF AND increasing, THEN stabilize NC temperature at 55]oF as follows: 1) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use S/G PORVs. b. IF the following conditions exist:

NC temperature is greater than 55]oF and stable

Time and manpower is available, THEN stabilize NC temperature at 55]oF as follows: 1) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use S/G PORVs. c. GO TO Step 9.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 3 of 4 430f61 NC Temperature Control Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 8.Bs

b. IF any S/G PORV cannot be closed, THEN close its isolation valve . CNS REACTOR TRIP OR SAFETY INJECTION EP/1/A/5000/E-O -Page 3 of 4 NC Temperature Control ACTION/EXPECTED RESPONSE 8.

tostoplbg,;;NC coqUiQwn as fgllows: a.EnsureT

.. u s . . .........

'. '. jl '£. ....I11,Y.!IlP .

.. . RESPONSE NOT OBTAINED PAGE NO. 43 of 61 Rev 36 DC:: b. IF any S/G PORV cannot be closed, THEN close its isolation valve. c.

fqUowing .

1AOtitHdr BldWn fPYJ.;} .. *"1SM 2 7El8;RS/G

1 BOtltHdr BldWn. CIY) ;1;SMFl{9A Hdrl?!(;!WD:

PlY>>) }":I; '1 SAil -n" "Oflt i'B'I'l'I"'*ww

c "::: .. C c Pir" . /:,;

c"i" " ,ywn: eN}; lie. "SIYBEFORE$,EAT PuS.llPutton (1 MG ..

t9 ii1'SMf4:1.($top Drn} (Stop VlytJ,2, ,l3efore

'O,rn);

Dm) * .. '

.. at Om}.

CNS REACTOR TRIP OR SAFETY INJECTION EP/1/A15000/E-O -Page 4 of 4 NC Temperature Control ACTION/EXPECTED RESPONSE 8. (Continued)

9. f*r.* ... _ ....

NC temperature

-STABLE AT LESS THAN OR EQUAL TO 557°F. OR

NC temperature

-TRENDING TO 557°F. f . RESPONSE NOT OBTAINED . .-PAGE NO. 44 of 61 Rev 36 CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 4 of 4 44 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE 8. (Continued)

f. Verify NO'cq<;>190wn fJ,:ST088Et;>":!';

9 the .

this.,

the following:

NC temperature

-STABLE AT LESS THAN OR EQUAL TO 557°F. OR

NC temperature

-TRENDING TO 55rF. RESPONSE NOT OBTAINED f. . n::*. cooldowncontiriues,THEN

>:throttle follows:' .

.. " ... 1) i.s (29°(o folloWing::

Maiolah tota.lf§g.o .tlowli9reates; GPM.' 2) 11 % {29%

THEN JIC5W;rurther to.

..

cqQ:,lQ9wr1

Maintain:

at least oneS/QiIN/R' level 11% (29% ACC). .. (3) 1Fc9.olgqwncoQUm:Qes, THEN MSIVs . .. AII*MSIY.

bypassyalves.

Duke Power Company Procedure No. Catawba Nuclear Station EP/I/A/sooo/E-2 Faulted Steam Generator Isolation Revision No. 012 Electronic Reference No. Continuous Use CP0094CZ PERFORMANCE I * * * * * * * * *

UNCONTROLLED FOR PRINT * * * * * * * * * * (ISSUED) -PDF Format 16 Duke Power Company Procedure No. Catawba Nuclear Station EP/I/A/sooo/E-2 Faulted Steam Generator Isolation Revision No. 012 Electronic Reference No. Continuous Use CP0094CZ PERFORMANCE I * * * * * * * * *

UNCONTROLLED FOR PRINT * * * * * * * * * * (ISSUED) -PDF Format 16 CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 1 of 21 Revision 12 A. Purpose This procedure provides actions to identify and isolate a faulted S/G. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/A15000/E-O (Reactor Trip Or Safety Injection), Step 24, with the following symptoms:

1) Any S/G pressure decreasing in an uncontrolled manner. 2) Any S/G completely depressurized.

b. EP/1/A15000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 2, EP/1/A15000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired), Step 11, EP/1/A15000/ECA-3.2 (SGTR With Loss Of Reactor Coolant -Saturated Recovery Desired), Step 5 with the following symptoms and/or conditions:

1) Any S/G pressure decreasing in an uncontrolled manner. 2) Any S/G completely depressurized.

3) Faulted S/G isolation not verified.

c. EP/1/A15000/FR-H.5 (Response To Steam Generator Low Level), Step 4, when the affected S/G is identified as faulted. d. Foldout page of other procedures whenever a faulted S/G is identified.

e. EP/1/A15000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Enclosure 1 (Foldout Page), if any S/G pressure increases.

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/N5000/E-2 1 of 21 Revision 12 A. Purpose This procedure provides actions to identify and isolate a faulted S/G. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/N5000/E-O (Reactor Trip Or Safety Injection), Step 24, with the following symptoms:

1) Any S/G pressure decreasing in an uncontrolled manner. 2) Any S/G completely depressurized.

b. EP/1/N5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 2, EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired), Step 11, EP/1/N5000/ECA-3.2 (SGTR With Loss Of Reactor Coolant -Saturated Recovery Desired), Step 5 with the following symptoms and/or conditions:

1) Any S/G pressure decreasing in an uncontrolled manner. 2) Any S/G completely depressurized.

3) Faulted S/G isolation not verified.

c. EP/1/N5000/FR-H.5 (Response To Steam Generator Low Level), Step 4, when the affected S/G is identified as faulted. d. Foldout page of other procedures whenever a faulted S/G is identified.

e. EP/1/N5000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Enclosure 1 (Foldout Page), if any S/G pressure increases.

eNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE C. Operator Actions 1. 2. 1RQl3. 4. EJ 5.

6. 20f21 Revision 12 RESPONSE NOT OBTAINED _ Manually close valve(s).

_ IF all S/Gs are faulted, THEN GO TO EP/1/A15000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators).

Perform the following:

a. Dispatch operators to search for initiating break at the following locations:

Main steamlines

Main feedlines

_

Other secondary piping. _ b. GO TO Step 8. Maintain one S/G available for NC System cool down in subsequent steps. eNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE C. Operator Actions 1. 2. 3.

=:

5.

IRQ I . .tit *Y. 'k 'h ". \.7"....... " " , _

2 of 21 Revision 12 RESPONSE NOT OBTAINED _ Manually close valve(s).

_ IF all S/Gs are faulted, THEN GO TO EP/1/A15000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators).

Perform the following:

a. Dispatch operators to search for initiating break at the following locations:

Main steamlines

Main feedlines _

Other secondary piping. _ b. GO TO Step 8. Maintain one S/G available for NC System cooldown in subsequent steps.

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/N5000/E-2 ACTION/EXPECTED RESPONSE 7. EJ-b. 30f21 Revision 12 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually close valve(s).

2) IF 1CA-185 (S/G 1A CA Nozz Tempering Isol) cannot be closed, THEN: a) Manually close the following valves:

1CF-100 (S/G CA Nozz Tempering Ctrl)

1 CF-156 (8yp Valve For 1CF-100).

b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):

1CF-100 (S/G CA Nozz Tempering Ctrl) (T8-580, 1 H-33) (Ladder needed)

1 CF-156 (8yp Valve For 1CF-100) (T8-577, 1 H-33) (Ladder needed). b. Perform the following:

_ 1) Manually close S/G PORV. 2) IF S/G PORV cannot be closed, THEN: _ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve. CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7 3 of 21 Revision 12 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually close valve(s).

2) IF 1CA-185 (S/G 1A CA Nozz Tempering Isol) cannot be closed, THEN: a) Manually close the following valves:

1 CF-1 00 (S/G CA Nozz Tempering Ctrl)

1 CF-156 (8yp Valve For 1CF-100).

b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):

1CF-100 (S/G CA Nozz Tempering Ctrl) (T8-580, 1 H-33) (Ladder needed)

1CF-156 (8yp Valve For 1 CF-1 00) (T8-577, 1 H-33) (Ladder needed). b. Perform the following:

_ 1) Manually close S/G PORV. 2) IF S/G PORV cannot be closed, THEN: _ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve.

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/N5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

c. Close the following valves: _1) _ 2) _ 3) d. 40f21 Revision 12 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1SM-77A (S/G 1A Otlt Hdr Bldwn CN) (DH-583, FF-GG, 43-44, Rm 591). 2) Perform the following:

_ a) Close 1CA-60 (CA Pump 1A Flow To S/G 1A). _ b) Dispatch operator to close 1 CA-62A (CA Pmp A Disch To S/G 1A Isol) (DH-587, DD-EE, 44-45, Rm 591). This should already have been done in E-O but will be done here if not. CRITICAL TASK!!! CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/N5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

c. Close the following valves: d. 4 of 21 Revision 12 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1SM-77A (S/G 1A Otlt Hdr Bldwn CN) (DH-583, FF-GG, 43-44, Rm 591). 2) Perform the following:

_ a) Close 1CA-60 (CA Pump 1A Flow To S/G 1A). _ b) Dispatch operator to close 1 CA-62A (CA Pmp A Disch To S/G 1A Isol) (DH-587, DD-EE, 44-45, Rm 591).

j8nowing:

_ Cl.ose1C;A-64(CA Pumpfjt1 Flgw IQi3fG.1A) . _

'SI 44-.* . ..

to.close .

Pmp1 This should already have been done in E-O but will be done here if not. CRITICAL TASK!!!

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

IRQ I -2) No power last known position was closed 50f21 Revision 12 RESPONSE NOT OBTAINED 2) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1BB-56A is open, THEN perform the following:

_ (1) Ensure "S/G A BLDWN CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED: _. 1 BB-148B (S/G 1A Bldwn Cont Isol Byp) (DH-580, EE-FF, 44-45, Rm 591) _. 1 BB-81 (1A S/G Blowdown Penetration Valve Test Isol) (DH-583, EE-FF, 44, Rm 591). CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

IRQ I -2)

No power last known position was closed 5 of 21 Revision 12 RESPONSE NOT OBTAINED 2) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1BB-56A is open, THEN perform the following:

_ (1) Ensure "S/G A BLOWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1BB-148B (S/G 1A Bldwn Cont Isol Byp) (DH-580, EE-FF, 44-45, Rm 591)

1BB-81 (1A S/G Blowdown Penetration Valve Test Isol) (DH-583, EE-FF, 44, Rm 591).

CNS FAULTED STEAM GENERATOR ISOLATION EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

_ 3) 3) -No power last known position was OPEN 1 BB-56A should already be closed but if not this RNO will be done. Skip to page 18, steps in between are for isolating other S/Gs that may be faulted, but none are in this case. RESPONSE NOT OBTAINED PAGE NO. 6of21 Revision 12 CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 6 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 7. (Continued)

_ 3)

3) ) -No power last known position was OPEN 1 BB-56A should already be closed but if not this RNO will be done. Skip to page 18, steps in between are for isolating other S/Gs that may be faulted, but none are in this case. b 5 tlii:\yalv6 will notclose,AND\

1IBB:-5()Ats per;!'orm' th$ following:

_ (1) ,Ensdre i"S/G?'!l('S8bWlx,f'

_i . .i .. ;d . (2).

to' .

1138-57

_ . . SIQwdown

..... . (DJ"h:583,iEI;-'PF.

44 iji Rm591).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

S/G 1B: a. Verify S/G 1 B Feedwater Isolation status light (1 SI-5) -LIT. b. Verify S/G 1 B PORV -CLOSED. 70f21 Revision 12 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually close valve(s).

2) IF 1CA-186 (S/G 1B CA Nozz Tempering Isol) cannot be closed, THEN: a) Manually close the following valves:

1CF-100 (S/G CA Nozz Tempering Ctrl)

1 CF-156 (Byp Valve For 1CF-100).

b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):

1CF-100 (S/G CA Nozz Tempering Ctrl) (TB-580, 1 H-33) (Ladder needed)

1 CF-156 (Byp Valve For 1CF-100) (TB-577, 1H-33) (Ladder needed). b. Perform the following:

_ 1) Manually close S/G PORV. 2) IF S/G PORV cannot be closed, THEN: _ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve. CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

S/G 1B: a. Verify S/G 1 B Feedwater Isolation status light (1 SI-5) -LIT. b. Verify S/G 1 B PORV -CLOSED. 7 of 21 Revision 12 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually close valve(s).

2) IF 1CA-186 (S/G 1 B CA Nozz Tempering Isol) cannot be closed, THEN: a) Manually close the following valves:

1 CF-1 00 (S/G CA Nozz Tempering Ctrl)

1 CF-156 (Byp Valve For 1CF-100).

b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):

1CF-100 (S/G CA Nozz Tempering Ctrl) (TB-580, 1 H-33) (Ladder needed)

1 CF-156 (Byp Valve For 1CF-100) (TB-577, 1 H-33) (Ladder needed). b. Perform the following:

_ 1) Manually close S/G PORV. 2) IF S/G PORV cannot be closed, THEN: _ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve.

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

c. Close the following valves: _ 1) 1 SM-76B (S/G 1 B Otlt Hdr Bldwn CN). _ 2) 1CA-58A (CA Pmp A Disch To S/G 1 B Isol). _ 3) 1CA-54B (CA Pmp 1 Disch To S/G 1 B Isol). d. Verify CA Pump 1A or AVAILABLE.

e. Dispatch operator to unlock and close 1SA-1 (1B S/G Main Steam to CAPT Maintenance Isol) (DH-624, FF-53, Rm 572) (Breakaway lock installed).

8 of 21 Revision 12 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1 SM-76B (S/G 1 B Otlt Hdr Bldwn CN) (DH-583, FF-53, Rm 572). 2) Perform the following:

_ a) Close 1CA-56 (CA Pump 1A Flow To S/G 1 B). _ b) Dispatch operator to close 1 CA-58A (CA Pmp A Disch To S/G 1 B Isol) (DH-586, DD-EE, 52-53, Rm 572). 3) Perform the following:

_ a) Close 1 CA-52 (CA Pump #1 Flow To S/G 1 B). _ b) Dispatch operator to close 1CA-54B (CA Pmp 1 Disch To S/G 1 B Isol) (DH-584, DD-EE, 52-53, Rm 572). d. IF CA Pump #1 is the only source of feedwater, THEN perform the following:

_ 1) Maintain steam flow to the CAPT from at least one S/G. _ 2) IF desired to isolate steam supply to CA Pump #1 from 1 B S/G, THEN GO TO Step 7.e. _ 3) GO TO Step 7.f. e. Dispatch operator to unlock and close 1 SA-3 (1 B S/G Mai n Steam to CAPT Stop Check) (AB-551, DD-53, Rm 217) (Breakaway lock installed).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

c. Close the following valves: _ 1) 1 SM-76B (S/G 1 B Otlt Hdr Bldwn CN). _ 2) 1CA-58A (CA Pmp A Disch To S/G 1 B Isol). _ 3) 1CA-54B (CA Pmp 1 Disch To S/G 1 B Isol). d. Verify CA Pump 1A or 1 B -AVAILABLE.

e. Dispatch operator to unlock and close 1 SA-1 (1 B S/G Main Steam to CAPT Maintenance Isol) (DH-624, FF-53, Rm 572) (Breakaway lock installed).

80f21 Revision 12 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1 SM-76B (S/G 1 B Otlt Hdr Bldwn CN) (DH-583, FF-53, Rm 572). 2) Perform the following:

_ a) Close 1CA-56 (CA Pump 1A Flow To S/G 1B). _ b) Dispatch operator to close 1 CA-58A (CA Pmp A Disch To S/G 1 B Isol) (DH-586, DD-EE, 52-53, Rm 572). 3) Perform the following:

_ a) Close 1CA-52 (CA Pump #1 Flow To S/G 1B). _ b) Dispatch operator to close 1 CA-54B (CA Pmp 1 Disch To S/G 1 B Isol) (DH-584, DD-EE, 52-53, Rm 572). d. IF CA Pump #1 is the only source of feedwater, THEN perform the following:

_ 1) Maintain steam flow to the CAPT from at least one S/G. _ 2) IF desired to isolate steam supply to CA Pump #1 from 1 B S/G, THEN GO TO Step 7.e. _ 3) GO TO Step 7.f. e. Dispatch operator to unlock and close 1 SA-3 (1 B S/G Mai n Steam to CAPT Stop Check) (AB-551, DD-53, Rm 217) (Breakaway lock installed).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

f. Verify the following blowdown isolation valves -CLOSED: _ 1) 1 BB-19A (S/G 1 B Bldwn Cont Isol Insd). _ 2) 1 BB-150B (S/G 1 B Bldwn Cont Isol Byp). 90f21 Revision 12 RESPONSE NOT OBTAINED _ 1) Manually close valve. 2) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1BB-19A is open, THEN perform the following:

_ (1) Ensure "S/G B BLDWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1BB-150B (S/G 1B Bldwn Cont Isol Byp) (DH-580, FF, 52-53, Rm 572)

1 BB-83 (1 B S/G Blowdown Penetration Valve Test Isol) (DH-580, FF-53, Rm 572). CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

f. Verify the following blowdown isolation valves -CLOSED: _ 1) 1 BB-19A (S/G 1 B Bldwn Cont Isol Insd). _ 2) 1BB-150B (S/G 1B Bldwn Cont Isol Byp). 9 of 21 Revision 12 RESPONSE NOT OBTAINED _ 1) Manually close valve. 2) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1BB-19A is open, THEN perform the following:

_ (1) Ensure "S/G B BLDWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1 BB-150B (S/G 1 B Bldwn Cont Isol Byp) (DH-580, FF, 52-53, Rm 572)

1 BB-83 (1 B S/G Blowdown Penetration Valve Test Isol) (DH-580, FF-53, Rm 572).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

_ 3) 1 BB-21 B {S/G 1 B Bldwn Cont Isol Otsd). 10 of 21 Revision 12 RESPONSE NOT OBTAINED 3) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1BB-19A is open, THEN perform the following:

_ (1) Ensure "S/G B BLDWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1BB-21B (S/G 1B Bldwn Cont Isol Otsd) (DH-580, FF, 52-53, Rm 572)

1 BB-83 (1 B S/G Blowdown Penetration Valve Test Isol) (DH-580, FF-53, Rm 572). CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/11 A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

_ 3} 1 BB-21 B {S/G 1 B Bldwn Cont Isol Otsd}. 10 of 21 Revision 12 RESPONSE NOT OBTAINED 3} Perform the following:

_ a} Manually close valve. b} IF valve will not close AND 1BB-19A is open, THEN perform the following:

_ (1) Ensure "S/G B BLDWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1BB-21B (S/G 1B Bldwn Cont Isol Otsd) (DH-580, FF, 52-53, Rm 572)

1 BB-83 (1 B S/G Blowdown Penetration Valve Test Isol) (DH-580, FF-53, Rm 572).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

S/G 1C: a. Verify S/G 1 C Feedwater Isolation status light (1SI-5) -LIT. b. Verify S/G 1 C PORV -CLOSED. 11 of 21 Revision 12 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually close valve(s).

2) IF 1CA-187 (S/G 1C CA Nozz Tempering Isol) cannot be closed, THEN: a) Manually close the following valves: _. 1 CF-1 00 (S/G CA Nozz Tempering Ctrl) _. 1CF-156 (Byp Valve For 1CF-100).

b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):

_. 1CF-100 (S/G CA Nozz Tempering Ctrl) (TB-580, 1 H-33) (Ladder needed)

1CF-156 (Byp Valve For 1CF-100)(TB-577, 1 H-33) (Ladder needed). b. Perform the following:

_ 1) Manually close S/G PORV. 2) IF S/G PORV cannot be closed, THEN: _ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve. CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

S/G 1C: a. Verify S/G 1 C Feedwater Isolation status light (1SI-5) -LIT. b. Verify S/G 1 C PORV -CLOSED. 11 of 21 Revision 12 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually close valve(s).

2) IF 1 CA-187 (S/G 1 C CA Nozz Tempering Isol) cannot be closed, THEN: a) Manually close the following valves:

1 CF-1 00 (S/G CA Nozz Tempering Ctrl)

1 CF-156 (Byp Valve For 1CF-100).

b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):

1CF-100 (S/G CA Nozz Tempering Ctrl) (TB-580, 1 H-33) (Ladder needed)

1 CF-156 (Byp Valve For 1CF-100) (TB-577, 1H-33) (Ladder needed). b. Perform the following:

_ 1) Manually close S/G PORV. 2) IF S/G PORV cannot be closed, THEN: _ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve.

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

c. Close the following valves: _ 1) 1SM-75A (S/G 1C Otlt Hdr Bldwn CN). _ 2) 1 CA-46B (CA Pmp B Disch To S/G 1 C Isol). _ 3) 1CA-50A (CA Pmp 1 Disch To S/G 1 C Isol). d. Verify CA Pump 1A or 1 B -AVAILABLE.

e. Dispatch operator to unlock and close 1SA-4 (1C S/G Main Steam to CAPT Maintenance Isol) (DH-624, FF-53, Rm 572) (Breakaway lock installed).

12 of 21 Revision 12 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1SM-75A (S/G 1C Otlt Hdr Bldwn CN) (DH-580, GG, 52-53, Rm 572). 2) Perform the following:

_ a) Close 1CA-44 (CA Pump 1B Flow To S/G 1C). _ b) Dispatch operator to close 1 CA-46B (CA Pmp B Disch To S/G 1C Isol) (DH-586, DD, 53-54, Rm 572). 3) Perform the following:

_ a) Close 1 CA-48 (CA Pump #1 Flow To S/G 1C). _ b) Dispatch operator to close 1CA-50A (CA Pmp 1 Disch To S/G 1 C Isol) (DH-584, EE-53, Rm 572). d. IF CA Pump #1 is the only source of feedwater, THEN perform the following:

_ 1) Maintain steam flow to the CAPT from at least one S/G. _ 2) IF desired to isolate steam supply to CA Pump #1 from 1 C S/G, THEN GO TO Step 7.e. _ 3) GO TO Step 7.f. e. Dispatch operator to unlock and close 1SA-6 (1C S/G Main Steam to CAPT Stop Check) (AB-551, DD-53, Rm 217) (Breakaway lock installed) (Ladder needed). CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

c. Close the following valves: _ 1) 1SM-75A (S/G 1C Otlt Hdr Bldwn CN). _ 2) 1 CA-46B (CA Pmp B Disch To S/G 1 C Isol). _ 3) 1CA-50A (CA Pmp 1 Disch To S/G 1 C Isol). d. Verify CA Pump 1A or 1 B -AVAILABLE.

e. Dispatch operator to unlock and close 1SA-4 (1C S/G Main Steam to CAPT Maintenance Isol) (DH-624, FF-53, Rm 572) (Breakaway lock installed).

12 of 21 Revision 12 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1SM-75A (S/G 1C Otlt Hdr Bldwn CN) (DH-580, GG, 52-53, Rm 572). 2) Perform the following:

_ a) Close 1CA-44 (CA Pump 1B Flow To S/G 1 C). _ b) Dispatch operator to close 1 CA-46B (CA Pmp B Disch To S/G 1C Isol) (DH-586, DO, 53-54, Rm 572). 3) Perform the following:

_ a) Close 1 CA-48 (CA Pump #1 Flow To S/G 1 C). _ b) Dispatch operator to close 1 CA-50A (CA Pmp 1 Disch To S/G 1 C Isol) (DH-584, EE-53, Rm 572). d. IF CA Pump #1 is the only source of feed water, THEN perform the following:

_ 1) Maintain steam flow to the CAPT from at least one S/G. _ 2) IF desired to isolate steam supply to CA Pump #1 from 1C S/G, THEN GO TO Step 7.e. _ 3) GO TO Step 7.f. e. Dispatch operator to unlock and close 1SA-6 (1C S/G Main Steam to CAPT Stop Check) (AB-551, DO-53, Rm 217) (Breakaway lock installed) (Ladder needed).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

f. Verify the following blowdown isolation valves -CLOSED: _ 1) 1 BB-60A (S/G 1 C Bldwn Cont Isol Insd). _ 2) 1BB-149B (S/G 1C Bldwn Cont IsoI8yp).

13 of 21 Revision 12 RESPONSE NOT OBTAINED _ 1) Manually close valve. 2) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1 BB-60A is open, THEN perform the following:

_ (1) Ensure "S/G C BLDWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1BB-1498 (S/G 1C Bldwn Cont Isol Byp) (DH-578, FF-GG, 52, Rm 572)

1 BB-82' (1 C S/G Blowdown Penetration Valve Test Isol) (DH-583, FF-53, Rm 572). CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

f. Verify the following blowdown isolation valves -CLOSED: _ 1) 1 BB-60A (S/G 1 C Bldwn Cont Isol Insd). _ 2) 1 BB-149B (S/G 1C Bldwn Cont Isol Byp). 13 of 21 Revision 12 RESPONSE NOT OBTAINED _ 1) Manually close valve. 2) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1 BB-60A is open, THEN perform the following:

_ (1) Ensure "S/G C BLDWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1BB-149B (S/G 1C Bldwn Cont Isol Byp) (DH-578, FF-GG, 52, Rm 572)

1 BB-82' (1 C S/G Blowdown Penetration Valve Test Isol) (DH-583, FF-53, Rm 572).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/Al5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

_ 3) 1 B8-61 8 (S/G 1 C Bldwn Cont 1501 Otsd). 14 of 21 Revision 12 RESPONSE NOT OBTAINED 3) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1BB-60A is open, THEN perform the following:

_ (1) Ensure "S/G C BLDWN CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1BB-61B (S/G 1C Bldwn Cont 1501 Otsd) (DH-578, FF-GG, 52, Rm 572)

188-82 (1 C S/G Blowdown Penetration Valve Test 1501) (DH-583, FF-53, Rm 572). CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

_ 3} 1BB-u1B (S/G 1C Bldwn Cont Isol Otsd). 14 of 21 Revision 12 RESPONSE NOT OBTAINED 3} Perform the following:

_ a} Manually close valve. b} IF valve will not close AND 1 BB-60A is open, THEN perform the following:

_ (1) Ensure "S/G C BLOWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1 BB-61 B (S/G 1C Bldwn Cont Isol Otsd) (DH-578, FF-GG, 52, Rm 572)

1 BB-82 (1 C S/G Blowdown Penetration Valve Test Isol} (DH-583, FF-53, Rm 572).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

S/G 1D: a. Verify S/G 1 D Feedwater Isolation status light (1SI-5) -LIT. b. Verify S/G 1 D PORV -CLOSED. 15 of 21 Revision 12 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually close valve(s).

2) IF 1CA-188 (S/G 1D CA Nozz Tempering Isol) cannot be closed, THEN: a) Manually close the following valves:

1 CF-1 00 (S/G CA Nozz Tempering Ctrl) _. 1 CF-156 (Byp Valve For 1CF-100).

b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):

1CF-100 (S/G CA Nozz Tempering Ctrl) (TB-580, 1 H-33) (Ladder needed)

1 CF-156 (Byp Valve For 1CF-100) (TB-577, 1H-33) (Ladder needed). b. Perform the following:

_ 1) Manually close S/G PORV. 2) IF S/G PORV cannot be closed, THEN: _ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve. CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

S/G 1 D: a. Verify S/G 1 D Feedwater Isolation status light (1SI-5) -LIT. b. Verify S/G 1 D PORV -CLOSED. 15 of 21 Revision 12 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually close valve(s).

2) IF 1CA-188 (S/G 1D CA Nozz Tempering Isol) cannot be closed, THEN: a) Manually close the following valves:

1 CF-1 00 (S/G CA Nozz Tempering Ctrl)

1 CF-156 (Syp Valve For 1CF-100).

b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):

1 CF-1 00 (S/G CA Nozz Tempering Ctrl) (TS-580, 1 H-33) (Ladder needed)

1CF-156 (Syp Valve For 1 CF-1 00) (TS-577, 1 H-33) (Ladder needed). b. Perform the following:

_ 1) Manually close S/G PORV. 2) IF S/G PORV cannot be closed, THEN: _ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve.

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/N5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

c. Close the following valves: _ 1) 1 SM-74B (S/G 1 D Otlt Hdr Bldwn CN). _ 2) 1CA-42B (CA Pmp B Disch To S/G 1 D Isol). _ 3) 1 CA-38A (CA Pmp 1 Disch To S/G 1 D Isol). d. Verify the following blowdown isolation valves -CLOSED: _ 1) 1 BB-8A (S/G 1 D Bldwn Cont Isol Insd). 16 of 21 Revision 12 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1SM-74B (S/G 1D Otlt Hdr Bldwn CN) (DH-583, FF-GG, 44-45, Rm 591 ). 2) Perform the following:

_ a) Close 1CA-40 (CA Pump 1B Flow To S/G 1D). _ b) Dispatch operator to close 1 CA-42B (CA Pmp B Disch To S/G 1 D Isol) (DH-586, DD-EE, 43-44, Rm 591). 3) Perform the following:

_ a) Close 1 CA-36 (CA Pump #1 Flow To S/G 1 D). _ b) Dispatch operator to close 1CA-38A (CA Pmp 1 Disch To S/G 1 D Isol) (DH-584, DD-EE, 43-44, Rm 591). _ 1) Manually close valve. CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

c. Close the following valves: _ 1) 1SM-74B (S/G 1D Otlt Hdr Bldwn CN). _ 2) 1CA-42B (CA Pmp B Disch To S/G 1 D Isol). _ 3) 1 CA-38A (CA Pmp 1 Disch To S/G 1 D Isol). d. Verify the following blowdown isolation valves -CLOSED: _ 1) 1 BB-8A (S/G 1 D Bldwn Cont Isol Insd). 16 of 21 Revision 12 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1 SM-74B (S/G 1 D Otlt Hdr Bldwn CN) (DH-583, FF-GG, 44-45, Rm 591 ). 2) Perform the following:

_ a) Close 1 CA-40 (CA Pump 1 B Flow To S/G 1D). _ b) Dispatch operator to close 1 CA-42B (CA Pmp B Disch To S/G 1 D Isol) (DH-586, DD-EE, 43-44, Rm 591). 3) Perform the following:

_ a) Close 1 CA-36 (CA Pump #1 Flow To S/G 1 D). _ b) Dispatch operator to close 1 CA-38A (CA Pmp 1 Disch To S/G 1 D Isol) (DH-584, DD-EE, 43-44, Rm 591). _ 1) Manually close valve.

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/11A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

_ 2) 188-1478 (S/G 1D 81dwn Cont Isol8yp).

17 of 21 Revision 12 RESPONSE NOT OBTAINED 2) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 188-8A is open, THEN perform the following:

_ (1) Ensure "S/G D 8LDWN CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

188-1478 (S/G 1 D 81dwn Cont Isol 8yp) (DH-582, EE-FF, 44, Rm 591)

188-80 (1 D S/G 810wdown Penetration Valve Test Isol) (DH-583,EE-FF,44, Rm 591). CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

_ 2) 1BB-147B (S/G 1D Bldwn Cont Isol Byp). 17 of 21 Revision 12 RESPONSE NOT OBTAINED 2) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1 BB-8A is open, THEN perform the following:

_ (1) Ensure "S/G D BLDWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1 BB-147B (S/G 1 D Bldwn Cont Isol Byp) (DH-582, EE-FF, 44, Rm 591)

1 BB-80 (1 D S/G Blowdown Penetration Valve Test Isol) (DH-583,EE-FF,44, Rm 591).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/Al5000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

9. _ 3) 1 BB-1 OB (S/G 1 D Bldwn Cont Isol Otsd). -1 ...... '--18 of 21 Revision 12 RESPONSE NOT OBTAINED 3) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1 BB-8A is open, THEN perform the following:

_ (1) Ensure "S/G D BLDWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED: _. 1BB-10B (S/G 1D Bldwn Cont Isol Otsd) (DH-582, EE-FF, 44, Rm 591) _. 1BB-80 (1D S/G Blowdown Penetration Valve Test Isol) (DH-583,EE-FF,44, Rm 591). _ REFER TO AP/1/A15500/006 (Loss of S/G Feedwater).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 7. (Continued)

8. IRO I _ 3) 1 BB-1 OB (S/G 1 D Bldwn Cont 1501 Otsd). 18 of 21 Revision 12 RESPONSE NOT OBTAINED 3) Perform the following:

_ a) Manually close valve. b) IF valve will not close AND 1 BB-8A is open, THEN perform the following:

_ (1) Ensure "S/G D BLDWN FLOW CLOSED. (2) Dispatch operators to ensure the following valves -CLOSED:

1BB-10B (S/G 1D Bldwn Cont Isol Otsd) (DH-582, EE-FF, 44, Rm 591)

1 BB-80 (1 D S/G Blowdown Penetration Valve Test 1501) (DH-583,EE-FF,44, Rm 591). _ REFER TO AP/1/A15500/006 (Loss of S/G Feedwater).

eNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 ACTION/EXPECTED RESPONSE 10. ,BOP I _.&11_,1&1

_ __ I' -........ -e. f. 19 of 21 Revision 12 RESPONSE NOT OBTAINED d. GO TO EP/1/A15000/E-3 (Steam Generator Tube Rupture).

_1) f. Perform the following:

_ 1) Notify station management to evaluate S/G(s) activity results. _ 2) IF S/G(s) activity indicate a SGTR, THEN GO TO EP/1/A15000/E-3 (Steam Generator Tube Rupture).

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2

10. EJ ACTION/EXPECTED RESPONSE

..

silg

_

_ 2):

_ 3) KG NCiNI Ni\.1 St

_ *bB?;.:l\lignall SIG:$ forchernistry at of.thefollowing':i'

_ '*,.Notjfy . sample T§/Gs for aqlivity.

OR .{NdJi{Y JRR to . :¢?tLdh:

d

IJARK.: >

_ 4; 1 1 C)*.1 _ *. ; ***..**..*

,';' i" . .... _.

19 of 21 Revision 12 RESPONSE NOT OBTAINED d. GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).

RP

_ 1) the

. , f. Perform the following:

_ 1) Notify station management to evaluate S/G(s) activity results. _ 2) IF S/G(s) activity indicate a SGTR, THEN GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).

eNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/N5000/E-2 ACTION/EXPECTED RESPONSE 11. . RO/BOP c. d. e. 12. GO TO EP/11A15000/E-1 (Loss Of Reactor Or Secondary Coolant).

20 of 21 Revision 12 RESPONSE NOT OBTAINED a. GO TO Step 12 . b. GO TO Step 12. c. GO TO Step 12. d. GO TO Step 12. Termination criteria should be met and the crew should transition to ES-1.1. eNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 RO/SOP a ACTION/EXPECTED RESPONSE

b. .secongafY:lhefitgir1!<

agfg!Jpws:, _

,.'NW:"JG';;i1

%{29%/"J OR

c.

&R' d. (gPO(crACC);

1 e. 12. GO TO EP/1/Al5000/E-1 (Loss Of Reactor Or Secondary Coolant).

20 of 21 Revision 12 RESPONSE NOT OBTAINED a. GO TO Step 12. b. GO TO Step 12. c. GO TO Step 12. d. GO TO Step 12. Termination criteria should be met and the crew should transition to ES-1.1.

CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 -Page 1 of 1 21 of 21 Foldout Page Revision 12 1. Cold Leg Recirc Switchover Criterion:

_. IF FWST level decreases to 37% (1AO-9, 0/8 "FWST 2/4 LO LEVEL" lit), THEN GO TO EP/1/A15000/ES-1.3 (Transfer To Cold Leg Recirculation).

2. Position Criteria for 1 NV-202B and 1 NV-203A (NV Pumps A&B Recirc Isol): _. IF NC pressure is less than 1500 PSIG AND NV SII flowpath is aligned, THEN close 1 NV-202B and 1 NV-203A.

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-202B and 1 NV-203A. CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 -Page 1 of 1 21 of 21 Foldout Page Revision 12 1. Cold Leg Recirc Switchover Criterion:

IF FWST level decreases to 37% (1AD-9, 0/8 "FWST 2/4 LO LEVEL" lit), THEN GO TO EP/1/A/5000/ES-1.3 (Transfer To Cold Leg Recirculation).

2. Position Criteria for 1 NV-202B and 1 NV-203A (NV Pumps A&B Recirc 1501):

IF NC pressure is less than 1500 PSIG AND NV SII flowpath is aligned, THEN close 1 NV-202B and 1 NV-203A.

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-202B and 1 NV-203A.

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/NSOOO/ES-1.1 1 of 76 Rev2SDCS A. Purpose This procedure provides the necessary instructions to terminate Safety Injection and stabilize plant conditions.

B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/NSOOO/E-O (Reactor Trip Or Safety Injection), Step 27, EP/1/NSOOO/E-1 (Loss Of Reactor Or Secondary Coolant), Step 7, and EP/1/NSOOO/E-2 (Faulted Steam Generator Isolation), Step 11 when specified termination criteria are satisfied.

b. EP/1/NSOOO/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 48, after secondary heat sink has been re-established and S/I has been terminated.

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/NSOOO/ES-1.1 1 of76 Rev 2SDCS A. Purpose This procedure provides the necessary instructions to terminate Safety Injection and stabilize plant conditions.

B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/NSOOO/E-O (Reactor Trip Or Safety Injection), Step 27, EP/1/NSOOO/E-1 (Loss Of Reactor Or Secondary Coolant), Step 7, and EP/1/NSOOO/E-2 (Faulted Steam Generator Isolation), Step 11 when specified termination criteria are satisfied.

b. EP/1/NSOOO/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 48, after secondary heat sink has been re-established and SII has been terminated.

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE c. Operator Actions IIRT.DDlllliiJWllllmmu

... 1J&iJllill

__ * -. 2 of 76 Rev 25DCS RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ 2) Concurrently implement Enclosure 6 (ECCS Master Reset) while continuing in this procedure.

b. Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372). CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 ACTION/EXPECTED RESPONSE C. Operator Actions Z"ErislJre B. EGCS;' c.

TIME a B/Q,:sg:curs, THEN; restarfS!1 eqqjpment . .

Phase A .; *Phase.B.

20f76 Rev 25DGS RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ 2) Concurrently implement Enclosure 6 (ECGS Master Reset) while continuing in this procedure.

b. Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372).

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Perform the following:

a. Align N2 to the Pzr PORVs by opening the following valves: 3 of 76 Rev 25DCS

1 NI-438A (Emer N2 From CLA A To 1 NC-34A)

1 NI-439B (Emer N2 From CLA B To 1 NC-32B). b. IF VI pressure is less than 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE 4 ISOpl *cv 1VI 7 7B'Y'l:/I'r7' t I" 'I')' OPC'N _ * \*"$liIC e ',,":, -dli.' RESPONSE NOT OBTAINED Perform the following:

a. Align N2 to the Pzr PORVs by opening the following valves: 30f76 Rev 25DCS

1 NI-438A (Emer N2 From CLA A To 1 NC-34A)

1 NI-439B (Emer N2 From CLA B To 1 NC-32B). b. IF VI pressure is less than 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE b. Verify the following valves -OPEN:

1 FW-27A (NO Pump 1A Suct From FWST)

1 FW-558 (NO Pump 18 Suct From FWST). c. Containment pressure -LESS THAN 2.4 PSIG. d. Reset NS. e. Stop NS pumps. f. Close the following valves:

1 NS-29A (NS Spray Hdr 1A Cont Isol)

1 NS-32A (NS Spray Hdr 1 A Cont Isol)

1 NS-15B (NS Spray Hdr 1 B Cont Isol)

1 NS-12B (NS Spray Hdr 18 Cont Isol). 40f76 Rev 250CS RESPONSE NOT OBTAINED b. Perform the following:

_ 1) WHEN containment pressure is less than 1 PSIG, THEN perform Steps 5.d through 5.f. _ 2) GO TO Step 6. c. Perform the following:

_ 1) WHEN containment pressure is less than 2.4 PSIG, THEN perform Step 5. _ 2) GO TO Step 6. CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ISOp/5. ACTION/EXPECTED RESPONSE a.

b. Verify the following valves -OPEN:

1 FW-27A (NO Pump 1A Suct From FWST)

1 FW-55B (NO Pump 1 B Suct From FWST). c. Containment pressure -LESS THAN 2.4 PSIG. d. Reset NS. e. Stop NS pumps. f. Close the following valves:

1 NS-29A (NS Spray Hdr 1A Cant Isol)

1 NS-32A (NS Spray Hdr 1 A Cant Isol)

1 NS-15B (NS Spray Hdr 1 B Cant Isol)

1NS-12B (NS Spray Hdr 1B Cant Isol). 4 of76 Rev 250CS RESPONSE NOT OBTAINED b. Perform the following:

_ 1) WHEN containment pressure is less than 1 PSIG, THEN perform Steps 5.d through 5.f. _ 2) GO TO Step 6. c. Perform the following:

_ 1) WHEN containment pressure is less than 2.4 PSIG, THEN perform Step 5. _ 2) GO TO Step 6.

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 ACTION/EXPECTED RESPONSE 5 of 76 Rev 25DCS RESPONSE NOT OBTAINED Perform the following:

a. Ensure Pzr spray valves -CLOSED. b. IF NC pressure continues to decrease, THEN GO TO EP/1/A15000/ES-1.2 (Post LOCA Cooldown And Depressurization

). In subsequent steps, control room control is lost for the following valves and local operation will be required:

1 NV-294 (NV Pmps A&B Disch Flow Ctrl)

1 NV-309 (Seal Water Injection Flow). a. IF NV pump suctions are aligned for Cold Leg Recirc, THEN: _ 1) Close 1 NV-309 (Seal Water Injection Flow). 2) IF control of 1 NV-309 is lost from the control room, THEN dispatch operator with radio to perform the following:

_ a) Close 1 NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ b) Throttle 1 NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to control seal injection flow as required in subsequent steps. 3) Open the following valves:

1 NV-312A (Chrg Line Cant Isol)

1 NV-314B (Chrg Line Cant Isol). (RNO continued on next page) CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1

7. B. ISOpl ACTION/EXPECTED RESPONSE yerifY'NC

9.

=-:::-=-1 a:

_ ;;1 FWS;;F) _ ***

IJrqfft f't!$]}s 50f76 Rev 25DCS RESPONSE NOT OBTAINED Perform the following:

a. Ensure Pzr spray valves -CLOSED. b. IF NC pressure continues to decrease, THEN GO TO EP/1/A/5000/ES-1.2 (Post LOCA Cooldown And Depressurization

). In subsequent steps, control room control is lost for the following valves and local operation will be required:

1 NV-294 (NV Pmps A&B Disch Flow Ctrl)

1 NV-309 (Seal Water Injection Flow). a. IF NV pump suctions are aligned for Cold Leg Recirc, THEN: _ 1) Close 1 NV-309 (Seal Water Injection Flow). 2) IF control of 1 NV-309 is lost from the control room, THEN dispatch operator with radio to perform the following:

_ a) Close 1 NV-30B (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ b) Throttle 1 NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to control seal injection flow as required in subsequent steps. 3) Open the following valves:

1 NV-312A (Chrg Line Cont Isol)

1 NV-314B (Chrg Line Cont Isol). (RNO continued on next page)

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/11A15000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued) 60f76 Rev 25DCS RESPONSE NOT OBTAINED 4) IF 1 NV-312AOR 1 NV-314B cannot be opened. THEN dispatch operator to open affected valve{s).

REFER TO the following enclosure{s) for affected valve(s):

Enclosure 8 (locally Open 1 NV-312A)

Enclosure 10 (locally Open 1 NV-314B).

_ 5) Do not continue in this procedure until 1 NV-312A and 1 NV-314B are open. _ 6) IF NC pressure is greater than 1950 PSIG. THEN throttle 1NV-309 or 1 NV-311 to 50% open. _7) Open 1 NV-294 (NV Pmps A&B Disch Flow Ctrl). 8) IF control of 1 NV-294 is lost from the control room. THEN: _ a) Place the controller for 1 NV-294 in the 100% demand position.

_ b) Dispatch operator with a radio to throttle 1 NV-295 (NV Pmps A & B Disch Ctrl Isol) (AB-551. JJ-55. Rm 231) to control charging flow as required in subsequent steps. 9) Close the following valves: _. 1 NI-9A (NV Pmp C/l Inj Isol) _. 1NI-10B (NV Pmp C/l Inj Isol). (RNO continued on next page) CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued) 60f76 Rev 25DCS RESPONSE NOT OBTAINED 4) IF 1 NV-312A OR 1 NV-314B cannot be opened, THEN dispatch operator to open affected valve(s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 8 (locally Open 1 NV -312A)

Enclosure 10 (locally Open 1 NV-314B).

_ 5) Do not continue in this procedure until 1 NV-312A and 1 NV-314B are open. _ 6) IF NC pressure is greater than 1950 PSIG, THEN throttle 1 NV-309 or 1 NV-311 to 50% open. _ 7) Open 1 NV-294 (NV Pmps A&B Disch Flow Ctrl). 8) IF control of 1 NV-294 is lost from the control room, THEN: _ a) Place the controller for 1 NV-294 in the 100% demand position.

_ b) Dispatch operator with a radio to throttle 1 NV-295 (NV Pmps A & B Disch Ctrllsol) (AB-551, JJ-55, Rm 231) to control charging flow as required in subsequent steps. 9) Close the following valves: _. 1 NI-9A (NV Pmp C/l Inj Isol) _. 1 NI-1 OB (NV Pmp C/l Inj Isol). (RNO continued on next page)

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued) 7 of 76 Rev 25DCS RESPONSE NOT OBTAINED 10) IF 1 NI-9A OR 1 NI-1 OB cannot be closed, THEN dispatch operator to close affected valve{s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 7 (Locally Close 1 NI-9A)

Enclosure 9 (Locally Close 1NI-10B).

11) Throttle charging and seal injection to maintain the following:

Charging line flow between 60 GPM and 180 GPM

NC pump seal injection flow. _ 12) GO TO Step 11. CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued) 70f76 Rev 25DCS RESPONSE NOT OBTAINED 10) IF 1 NI-9A OR 1 NI-1 OB cannot be closed, THEN dispatch operator to close affected valve{s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 7 (Locally Close 1 NI-9A)

Enclosure 9 (Locally Close 1NI-10B).

11) Throttle charging and seal injection to maintain the following:

Charging line flow between 60 GPM and 180 GPM

NC pump seal injection flow. _ 12) GO TO Step 11.

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/11A15000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued)

b. IF 1 NV-203A was closed earlier due to low NC system pressure per enclosure 1 of E-O, or E-2 they will go to the RNO and open it. 80f76 Rev 25DCS RESPONSE NOT OBTAINED b. Perform the following:

_ 1) Open affected valve{s).

_ 2) IF 1 NV-203A AND 1 NV-2Q2B are open, THEN GO TO Step 9.c. 3) Dispatch operator to open affected valve(s):

_. 1 NV-203A (NV Pumps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed)

1 NV-202B (NV Pmps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed). _ 4) Close 1 NV-309 (Seal Water Injection Flow). 5) IF control of 1 NV-309 is lost from the control room, THEN dispatch operator with radio to perform the following:

_ a) Close 1 NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ b) Throttle 1 NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to control seal injection flow as required in subsequent steps. 6) Open the following valves:

1 NV-312A (Chrg Line Cont Isol)

1NV-314B (Chrg Line Cont Isol). (RNO continued on next page) CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued)

" ,JY, I " ' * (N)Z*PumpJ A&Bigecirc

!§Pl) .1 IsQD* IF 1 NV-203A was closed earlier due to low NC system pressure per enclosure 1 of E-O, or E-2 they will go to the RNO and open it. 80f76 Rev 25DCS RESPONSE NOT OBTAINED b. Perform the following:

_ 1) Open affected valve{s) . _ 2) IF 1 NV-203A AND 1 NV-2Q2B are open, THEN GO TO Step 9.c. 3) Dispatch operator to open affected valve(s):

1 NV-203A (NV Pumps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed)

1 NV-202B (NV Pmps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed). _ 4) Close 1 NV-309 (Seal Water Injection Flow). 5) IF control of 1 NV-309 is lost from the control room, THEN dispatch operator with radio to perform the following:

_ a) Close 1 NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ b) Throttle 1 NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to control seal injection flow as required in subsequent steps. 6) Open the following valves:

1 NV-312A (Chrg Line Cont Isol)

1 NV-314B (Chrg Line Cont Isol). (RNO continued on next page)

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued) 90f76 Rev 25DCS RESPONSE NOT OBTAINED 7) IF 1 NV-312AOR 1 NV-314B cannot be opened, THEN dispatch operator to open affected valve(s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 8 (locally Open 1 NV-312A)

Enclosure 10 (locally Open 1 NV-314B).

_ 8) Do not continue in this procedure until 1 NV-312A and 1 NV-314B are open. _ 9) IF NC pressure is greater than 1950 PSIG, THEN throttle 1 NV-309 or 1 NV-311 to 50% open. _ 10) Open 1 NV-294 (NV Pmps A&B Disch Flow Ctrl). 11) IF control of 1 NV-294 is lost from the control room, THEN: _ a) Place the controller for 1 NV-294 in the 100% demand position.

_ b) Dispatch operator with a radio to throttle 1 NV-295 (NV Pmps A & B Disch Ctrllsol) (AB-551, JJ-55, Rm 231 ) to control charging flow as required in subsequent steps. 12) Close the following valves:

1 NI-9A (NV Pmp C/l Inj 1501)

1 NI-1 OB (NV Pmp C/l Inj 1501). (RNO continued on next page) CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued) 90f76 Rev 25DCS RESPONSE NOT OBTAINED 7) IF 1 NV-312A OR 1 NV-3148 cannot be opened, THEN dispatch operator to open affected valve{s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 8 (locally Open 1 NV -312A)

Enclosure 10 (locally Open 1 NV-3148).

_ 8) Do not continue in this procedure until 1 NV-312A and 1 NV-3148 are open. _ 9) IF NC pressure is greater than 1950 PSIG, THEN throttle 1 NV-309 or 1 NV-311 to 50% open. _ 10) Open 1 NV-294 (NV Pmps A&8 Disch Flow Ctrl). 11) IF control of 1 NV-294 is lost from the control room, THEN: _ a) Place the controller for 1 NV-294 in the 100% demand position.

_ b) Dispatch operator with a radio to throttle 1 NV-295 (NV Pmps A & 8 Disch Ctrl Isol) (A8-551 , JJ-55, Rm 231) to control charging flow as required in subsequent steps. 12) Close the following valves:

1 NI-9A (NV Pmp C/l Inj Isol)

1 NI-1 08 (NV Pmp C/l Inj Isol). (RNO continued on next page)

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued)

c. SCENARIO MAY BE TERMINATED ANYTIME AFTER THIS STEP 10 of 76 Rev 25DCS RESPONSE NOT OBTAINED 13) IF 1 NI-9A OR 1 NI-1 OB cannot be closed, THEN dispatch operator to close affected valve(s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 7 (Locally Close 1 NI-9A)

Enclosure 9 (Locally Close 1NI-10B).

14) Throttle charging and seal injection to maintain the following:

Charging line flow between 60 GPM and 180 GPM

NC pump seal injection flow. _ 15) WHEN 1 NV-203A AND 1 NV-202B are opened, THEN charging flow may be reduced below 60 GPM. _ 16) GO TO Step 11. c. Dispatch operator to close affected valve(s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 7 (Locally Close 1 NI-9A)

Enclosure 9 (Locally Close 1 NI-10B). CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE 9. (Continued) vaIV§s: SCENARIO MAY BE TERMINATED ANYTIME AFTER THIS STEP 10 of 76 Rev 25DCS RESPONSE NOT OBTAINED 13) IF 1 NI-9A OR 1 NI-1 OB cannot be closed, THEN dispatch operator to close affected valve(s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 7 (Locally Close 1 NI-9A)

Enclosure 9 (Locally Close 1 NI-1 OB). 14) Throttle charging and seal injection to maintain the following:

Charging line flow between 60 GPM and 180 GPM

NC pump seal injection flow. _ 15) WHEN 1 NV-203A AND 1 NV-202B are opened, THEN charging flow may be reduced below 60 GPM. _ 16) GO TO Step 11. c. Dispatch operator to close affected valve(s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 7 (Locally Close 1 NI-9A)

Enclosure 9 (Locally Close 1 NI-10B).

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE 11 of 76 Rev 25DCS RESPONSE NOT OBTAINED a. IF all the valves are closed, THEN perform the following:

_ 1) Open 1 NV-309 (Seal Water Injection Flow). _ 2) IF control of 1 NV-309 (Seal Water Injection Flow) is lost from the control room, THEN dispatch operator with radio to open 1 NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233). 3) Open the following valves: _. 1 NV-312A (Chrg Line Cont Isol) _. 1 NV-314B (Chrg Line Cont Isol). 4) IF 1 NV-312AOR 1 NV-314B cannot be opened, THEN dispatch operator to open affected valve(s).

REFER TO the following enclosure(s) for affected valve{s):

Enclosure 8 (Locally Open 1 NV -312A)

Enclosure 10 (Locally Open 1 NV-314B).

_ 5) Throttle 1 NV-294 (NV Pmps A&B Disch Flow Ctrl) to maintain charging flow less than 180 GPM. 6) IF 1 NV-294 cannot be operated from the control room, THEN: _ a) Place the controller for 1 NV-294 in the 100% demand position.

_ b) Dispatch operator with a radio to throttle 1 NV-295 {NV Pmps A & B Disch Ctrl Isol) (AB-551, JJ-55, Rm 231) to maintain charging line flow less than 180 GPM. (RNO continued on next page) CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE 1 O.

Valves"'l%

a., ':1, /'" "

""',

'" ,9", "'" J"" "',

"""" _ * " ","\,'0"';"1>

,"",:(,;mp;:,,,£"

JIPP "t; C(1rT'{sol,). """"[l,","",,,,

NGIBm mSeal'B.u" 'I""" _ ."'"5""",,,,'",,", ( ""," p" ,",", "" "',,, pp,y _

G$eal p"l.1pply

Dpeal§l.1pply

IsQ!j: 11 of 76 Rev 25DCS RESPONSE NOT OBTAINED a. IF all the valves are closed, THEN perform the following:

_ 1) Open 1 NV-309 (Seal Water Injection Flow). _ 2) IF control of 1 NV-309 (Seal Water Injection Flow) is lost from the control room, THEN dispatch operator with radio to open 1 NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233). 3) Open the following valves: _. 1 NV-312A (Chrg Line Cont 1501) _. 1 NV-314B (Chrg Line Cont 1501). 4) IF 1 NV-312A OR 1 NV-314B cannot be opened, THEN dispatch operator to open affected valve(s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 8 (Locally Open 1 NV-312A)

Enclosure 10 (Locally Open 1 NV-314B).

_ 5) Throttle 1 NV-294 (NV Pmps A&B Disch Flow Ctrl) to maintain charging flow less than 180 GPM. 6) IF 1 NV-294 cannot be operated from the control room, THEN: _ a) Place the controller for 1 NV-294 in the 100% demand position.

_ b) Dispatch operator with a radio to throttle 1 NV-295 (NV Pmps A & B Disch Ctrllsol) (AB-551, JJ-55, Rm 231) to maintain charging line flow less than 180 GPM. (RNO continued on next page)

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/Al5000/ES-1.1 ACTION/EXPECTED RESPONSE 10. (Continued)

c. d. e. f. 12 of 76 Rev 25DCS RESPONSE NOT OBTAINED _ 7) GO TO Step 11. b. Perform the following:

_ 1) Place the controller for 1 NV-294 in the 100% demand position.

_ 2) Dispatch operator with a radio to throttle 1 NV-295 (NV Pmps A & B Disch Ctrl Isol) (AB-551, JJ-55, Rm 231) for 32 GPM charging line flow. _ 3) Throttle 1 NV-295 to control charging flow as required in subsequent steps. c. Dispatch operator with radio to perform the following:

_ 1) Close 1 NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ 2) Throttle 1 NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps. d. Dispatch operator to open affected valve(s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 8 (Locally Open 1 NV-312A)

Enclosure 10 (Locally Open 1 NV-314B).

e. GO TO Step 10.g. CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 ACTION/EXPECTED RESPONSE 10. (Continued)

b.

FIQwCm5'f: pr

c. c:;lq$e1 1?19l¥)* * (QmJ@ l;iq¢<CQnt;lgol):

e.

OPf;RA aQ.QMi f.

12 of 76 Rev 25DCS RESPONSE NOT OBTAINED _ 7) GO TO Step 11. b. Perform the following:

_ 1) Place the controller for 1 NV-294 in the 100% demand position.

_ 2) Dispatch operator with a radio to throttle 1 NV-295 (NV Pmps A & B Disch Ctrllsol) (AB-551, JJ-55, Rm 231) for 32 GPM charging line flow. _ 3) Throttle 1 NV-295 to control charging flow as required in subsequent steps. c. Dispatch operator with radio to perform the following:

_ 1) Close 1 NV-308 (Seal Wtr Inj Flow Ctrllsol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ 2) Throttle 1 NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps. d. Dispatch operator to open affected valve(s).

REFER TO the following enclosure(s) for affected valve(s):

Enclosure 8 (Locally Open 1 NV-312A)

Enclosure 10 (Locally Open 1 NV-314B).

e. GO TO Step 10.g.

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 ACTION/EXPECTED RESPONSE a. b. 13 of 76 Rev 25DCS RESPONSE NOT OBTAINED b. Perform the following:

_ 1) IF any S/G is faulted, THEN do not continue until faulted S/G depressurization stops OR Pzr level can be maintained stable or increasing.

2) IF no S/G is faulted OR Pzr level continues to decrease after faulted S/G depressurization stops, THEN perform the following:

a) Open the following valves:

1 NI-9A (NV Pmp C/l Inj Isol) _. 1NI-10B (NV Pmp C/l Inj Isol). b) Close the following valves:

1 NV-312A (Chrg Line Cont Isol)

1 NV-314B (Chrg Line Cont Isol). _ c) GO TO EP/1/A15000/ES-1.2 (Post lOCA Cooldown And Oepressu rization).

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/SOOO/ES-1.1 ACTION/EXPECTED RESPONSE 1 O.

ftl;;l,Ji\l

.. , , .'"., > ,

a.

..

b 13 of 76 Rev 2SDCS RESPONSE NOT OBTAINED b. Perform the following:

_ 1) IF any S/G is faulted, THEN do not continue until faulted S/G depressurization stops OR Pzr level can be maintained stable or increasing.

2) IF no S/G is faulted OR Pzr level continues to decrease after faulted S/G depressurization stops, THEN perform the following:

a) Open the following valves:

1 NI-9A (NV Pmp C/l Inj Isol) _. 1NI-10B (NV Pmp C/l Inj Isol). b) Close the following valves:

1 NV-312A (Chrg Line Cont Isol)

1 NV-314B (Chrg Line Cont Isol). _ c) GO TO EP/1/A/SOOO/ES-1.2 (Post lOCA Cooldown And Depressurization).

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/SOOO/ES-1.1 ACTION/EXPECTED RESPONSE

a. b. 14 of 76 Rev 25DCS RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF any S/G is faulted, THEN do not continue until faulted S/G depressurization stops OR criteria for stopping NI pumps is met. _ 2) IF no S/G is faulted OR conditions for stopping NI pumps cannot be satisfied after faulted S/G depressurization stops, THEN GO TO EP/1/A/5000/ES-1.2 (Post LOCA Cooldown And Depressurization).

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/SOOO/ES-1.1 ACTION/EXPECTED RESPONSE 12.

a. Vgrity

13.

14 of 76 Rev 2SDCS RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF any S/G is faulted, THEN do not continue until faulted S/G depressurization stops OR criteria for stopping NI pumps is met. _ 2) IF no S/G is faulted OR conditions for stopping NI pumps cannot be satisfied after faulted S/G depressurization stops, THEN GO TO EP/1/A/SOOO/ES-1.2 (Post LOCA Cooldown And Depressurization).

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/N5000/ES-1.1 ACTION/EXPECTED RESPONSE a. 15 of 76 Rev 25DCS RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually start S/I pumps and align valves as necessary to restore NC subcooling.

_ 2) GO TO EP/1/N5000/E-1 (Loss Of Reactor Or Secondary Coolant).

b. Perform the following:

_ 1) Control charging flow to restore Pzr level to greater than 11 % (20% ACC). 2) IF Pzr level cannot be maintained greater than 11 % (20% ACC), THEN: _ a) Manually start S/I pumps and align valves as necessary to restore Pzr level. _ b) GO TO EP/1/N5000/E-1 (Loss Of Reactor Or Secondary Coolant).

CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/N5000/ES-1.1 ACTION/EXPECTED RESPONSE a.

b.

(20o;4'ACC

)}: 15 of 76 Rev 25DCS RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually start S/I pumps and align valves as necessary to restore NC subcooling.

_ 2) GO TO EP/1/N5000/E-1 (Loss Of Reactor Or Secondary Coolant).

b. Perform the following:

_ 1) Control charging flow to restore Pzr level to greater than 11 % (20% ACC). 2) IF Pzr level cannot be maintained greater than 11 % (20% ACC), THEN: _ a) Manually start SII pumps and align valves as necessary to restore Pzr level. _ b) GO TO EP/1/N5000/E-1 (Loss Of Reactor Or Secondary Coolant).

Appendix D Scenario Outline Form ES-D-1 2009 NRC EXAMINATION Facility:

Catawba Nuclear Station Scenario No.: 2a Op-Test No.: 2009 D-1 --SNAP 142 Examiners:

Operators:

Initial Conditions:

100% power

EFPD = 25 days

Boron Concentration is 1348 ppm Turnover:

1 CFP5600 (1 D S/G Narrow Range Level Ch #2) failed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago. IAE repairs are in progress and estimated to take 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . All TSAIL entries have been made.

Reduce power to 87% for control valve movement test to be done by the next shift per OP/1/A/61 001003 (Controlling Procedure for Unit Operation), Enclosure 4.3, Unit Operation Between 85% and 100% Power. Event Malf. No. Event Event No. Type* Description 1 BOP N Borate for power decrease (DCS) 2 RO R Power reduction using turbine in auto lrods as necessary 3 SRO TS 1 B S/G WR level fails low (TS call only) 4 BOP C RN Strainer 1A high DIP, backflush does not operate SRO TS 5 RO C Generator voltage regulator fails voltage low 6 RO C Loss of condenser vacuuml reduce load with turbine in manual 7 BOP C PZR Spray valve 1 NC-27 fails open with no manual control SRO TS 8 ALL M Tube rupture on 1 A S/G Additional Failures Failure of automatic feedwater (OF) isolation Failure of 1NI-9 and 1NI-10 to automatically position S/G PORV 1SV-19 fails open *(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Scenario Outline Form ES-D-1 2009 NRC EXAMINATION Facility:

Catawba Nuclear Station Scenario No.: 2a Op-Test No.: 2009 D-1 --SNAP 142 Examiners:

Operators:

Initial Conditions:

100% power

EFPD = 25 days

Boron Concentration is 1348 ppm Turnover:

1 CFP5600 (1 D S/G Narrow Range Level Ch #2) failed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago. IAE repairs are in progress and estimated to take 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . All TSAIL entries have been made.

Reduce power to 87% for control valve movement test to be done by the next shift per OP/1/A/61 001003 (Controlling Procedure for Unit Operation), Enclosure 4.3, Unit Operation Between 85% and 100% Power. Event Malf. No. Event Event No. Type* Description 1 BOP N Borate for power decrease (DCS) 2 RO R Power reduction using turbine in auto !rods as necessary 3 SRO TS 1 B S/G WR level fails low (TS call only) 4 BOP C RN Strainer 1A high DIP, backflush does not operate SRO TS 5 RO C Generator voltage regulator fails voltage low 6 RO C Loss of condenser vacuuml reduce load with turbine in manual 7 BOP C PZR Spray valve 1 NC-27 fails open with no manual control SRO TS 8 ALL M Tube rupture on 1 A S/G Additional Failures Failure of automatic feedwater (CF) isolation Failure of 1 NI-9 and 1 NI-1 0 to automatically position S/G PORV 1SV-19 fails open *(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor SIMULATOR SETUP Reset to 100% BOL snap Roll Charts Provide a boration/dilution plan Clear EHC alarm and any OACI 1.47 bypass alarms Sign off OP/1/A/61 001003 enclosure 4.3 thru step 2.13 (students start at 2.14) MALFUNCTIONS.

REMOTES. and OVERRIDES Malfunction

Description Value Event Trigger MAL-IPE003B PZR SPRAY VLV NC-27 FAIL, NO 100 7 MAN CTRL MAL-ISE007 A AUTO CF ISOL SIGNAL TRN A BLOCK MAL-ISE007B AUTO CF ISOL SIGNAL TRN B BLOCK MAL-MT003 LOSS OF CONDENSER VACUUM 0 11 (VLV LEAK) MAL-MT003 LOSS OF CONDENSER VACUUM 25 6 (VLV LEAK) MAL-MT010 GLAND STEAM REGULATOR 0 15 FAILURE (TL3) MAL-MT012 EXTRACTION STEAM SEAL 0 15 REGULATOR FAILURE (TL 10) MAL-RN002A RN STRNER 1A HI DIP 0 12 MAL-RN002A RN STRNER 1A HI DIP 100 4 MAL-RN002A RN STRNER 1A HI DIP 0 14 MAL-RN002A RN STRNER 1A HI DIP 100 10 MAL-SG001A S/G A TUBE LEAK 650 8 MAL-SM002A S/G PORV SV19 FAILURE 100 9 OVR-EGB004C VOLTAGE ADJUST RAISE PB OFF 5 OVR-EBG004C VOLTAGE ADJUST RAISE PB OFF 13 OVR-EGB004D VOLTAGE ADJUST LOWER PB ON 5 VLV-NI001A NI9A B.I.T. DISCHARGE ISOL VLV FAIL AUTO ACTIONS VLV-NI002A NI10B B.I.T. DISCHARGE ISOL VLV FAIL AUTO ACTIONS VLV-RN061F RN30A RN STRAINER A BCKWASH 0 ISOL FAIL TO POSITION XMT-SG016 LCF _5600 S/G 1 D N/R LVL CH2 TO 0 DCS/MCB/OAC (CFAA5600)

XMT-SG094 XCF _5620 S/G B W/R LVL CH 2 TO 0 3 DCS/OAC (CFAA5620)

Ramp Delay 60 300 15 15 5 60 5 Del in 1 60 5 Del in 1 Del in 8 I \ SIMULATOR SETUP Reset to 100% BOL snap Roll Charts Provide a boration/dilution plan Clear EHC alarm and any OACI 1.47 bypass alarms Sign off OP/1/A/61 001003 enclosure 4.3 thru step 2.13 (students start at 2.14) MALFUNCTIONS.

REMOTES. and OVERRIDES Malfunction

Description Value Event Trigger MAL-IPE003B PZR SPRAY VLV NC-27 FAIL, NO 100 7 MAN CTRL MAL-ISE007 A AUTO CF ISOL SIGNAL TRN A BLOCK MAL-ISE007B AUTO CF ISOL SIGNAL TRN B BLOCK MAL-MT003 LOSS OF CONDENSER VACUUM 0 11 (VLV LEAK) MAL-MT003 LOSS OF CONDENSER VACUUM 25 6 (VLV LEAK) MAL-MT010 GLAND STEAM REGULATOR 0 15 FAILURE (TL3) MAL-MT012 EXTRACTION STEAM SEAL 0 15 REGULATOR FAILURE (TL 10) MAL-RN002A RN STRNER 1A HI DIP 0 12 MAL-RN002A RN STRNER 1A HI DIP 100 4 MAL-RN002A RN STRNER 1A HI DIP 0 14 MAL-RN002A RN STRNER 1A HI DIP 100 10 MAL-SG001A S/G A TUBE LEAK 650 8 MAL-SM002A S/G PORV SV19 FAILURE 100 9 OVR-EGB004C VOLTAGE ADJUST RAISE PB OFF 5 OVR-EBG004C VOLTAGE ADJUST RAISE PB OFF 13 OVR-EGB004D VOLTAGE ADJUST LOWER PB ON 5 VLV-NI001A NI9A B.I.T. DISCHARGE ISOL VLV FAIL AUTO ACTIONS VLV-NI002A NI10B B.I.T. DISCHARGE ISOL VLV FAIL AUTO ACTIONS VLV-RN061 F RN30A RN STRAINER A BCKWASH 0 ISOL FAIL TO POSITION XMT-SG016 LCF _5600 S/G 1 D N/R LVL CH2 TO 0 DCS/MCB/OAC (CFAA5600)

XMT-SG094 XCF _5620 S/G B W/R LVL CH 2 TO 0 3 DCS/OAC (CFAA5620)

Ramp Delay 60 300 15 15 5 60 5 Del in 1 60 5 Del in 1 Del in 8 XMT-MT011 PTL_5000 TURBINE SEAL STEAM 3.2 HEADER PRESS MTR XMT-MT011 PTL_5000 TURBINE SEAL STEAM 0 15 15 HEADER PRESS MTR EVENT TRIGGERS (other than manual) Event Description Trigger 9 jpplp4(1)

I jpplp4(2) (Reactor Trip either train) 10 jpplsia I jpplsib (Safety Injection either train) 11 rtlh004>0.035

& x01 d047m>1.1 (TL4 not closed and Steam Seal Header Pressure>

1.1 psig) 12 X11i038f (1A RN pump off button depressed) 13 X01i135m (Voltage Regulator in manual) 14 X11 i038f & jpplsib & !jpplsia (1A RN pump off button depressed and B SI and no A SI) 15 SMSS < 1165 (MW less than 1165) CRITICAL TASKS (See attached documentation)

E-O 1-Establish flow from at least one high-head ECCS pump before transition out of E-O. E-3 A -Isolate feed water flow into and steam flow from the ruptured S/G before a transition to ECA-3.1 occurs. QUALITATIVE ATTRIBUTES Required Actual Total malfunctions 5-8 8 Malfunctions after EOP entry 1 -2 3 Abnormal events 2-4 4 Major transients 1 -2 1 EOPs enteredlrequiring substantive actions 1 -2 1 EOP contingencies requiring substantive actions 0-2 0 Critical tasks 2-3 2 REFERENCES Del in 2 ( XMT-MT011 PTL_5000 TURBINE SEAL STEAM 3.2 HEADER PRESS MTR XMT-MT011 PTL_5000 TURBINE SEAL STEAM 0 15 15 HEADER PRESS MTR EVENT TRIGGERS (other than manual) Event Description Trigger 9 jpplp4(1)

I jpplp4(2)

-<Reactor Trip either train) 10 jpplsia I jpplsib (Safety Injection either train) 11 rtlh004>0.035

& x01 d047m>1.1 (TL4 not closed and Steam Seal Header Pressure>

1.1 psig) 12 X11 i038f (1A RN pump off button depressed) 13 X01i135m (Voltage Regulator in manual) 14 X11 i038f & jpplsib & !jpplsia (1A RN pump off button depressed and B SI and no A SI) 15 SMSS < 1165 (MW less than 1165) CRITICAL TASKS (See attached documentation)

E-O 1-Establish flow from at least one high-head ECCS pump before transition out of E-O. E-3 A -Isolate feedwater flow into and steam flow from the ruptured S/G before a transition to ECA-3.1 occurs. QUALITATIVE ATTRIBUTES Required Actual Total malfunctions 5-8 8 Malfunctions after EOP entry 1 -2 3 Abnormal events 2-4 4 Major transients 1 -2 1 EOPs entered/requiring substantive actions 1 -2 1 EOP contingencies requiring substantive actions 0-2 0 Critical tasks 2-3 2 REFERENCES Del in 2 OP/11A161501009 (Boron Concentration Control) revision 068DCS OP/11A161 001003 (Controlling Procedure for Unit Operation), Enclosure

4.3 revision

106DCS OP/1/B/63001001 (Turbine Generator) revision 091 AP/0IAl55001020 (Loss of Nuclear Service Water) revision 037DCS AP/11A155001037 (Generator Voltage and Electric Grid Disturbances) revision 000 AP/11A155001011 (Pressurizer Pressure Anomalies) revision 022DCS AP/11A155001023 (Loss of Condenser Vacuum) revision 018 EP/11A15000/E-0 (Reactor Trip or Safety Injection) revision 036DCS EP/11A15000/E-3 (Steam Generator Tube Rupture) revision 034DCS OP/0IAl64001006C (Nuclear Service Water) revision 266 NOTES AND INSTRUCTIONS NOTE: The following steps are GUIDELINES.

The NRC lead examiner will direct timing of events unless otherwise noted. NOTE: Any groups or individuals (IAE, RxGrp, RP, SOC, SWM) that are called to I/R a problem or for simple notification of a problem, repeat back the information they provide unless otherwise noted. NOTE: Any operators dispatched should repeat back information provided.

Call back items are listed below when necessary for the scenario.

Event 1 -Borate for power decrease This event will be entered once the crew has taken turnover and evaluated plant conditions.

When the first boration batch has been completed, the next event can be started. Event 2 -Power reduction using turbine/rods as necessary When turbine power has been reduced by 3-5 MW, the next event can be inserted.

Event 3 -1B S/G WR level fails low, SRO Technical Specification Initiating Cues:

1AD-2 alarms F/10 (DCS alarm screen shows actual alarm) TS 3.3.3 Item 21, Conditions A, C Event 4 -RN Strainer 1A high D/P, backflush does not operate, SRO Technical Specification Initiating Cues:

1AD-12 alarms Al1, Al2, Al5, C/2 When AP/0/Al55001020 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

TS 3.7.8 Condition A If asked to check out RN pump 1A and/or breaker state, after 10 minutes state "Nothing ( OP/11A161501009 (Boron Concentration Control) revision 068DCS OP/11A161 001003 (Controlling Procedure for Unit Operation), Enclosure

4.3 revision

106DCS OP/1/B/63001001 (Turbine Generator) revision 091 AP/OIAl55001020 (Loss of Nuclear Service Water) revision 037DCS AP/11A155001037 (Generator Voltage and Electric Grid Disturbances) revision 000 AP/11A155001011 (Pressurizer Pressure Anomalies) revision 022DCS AP/11A155001023 (Loss of Condenser Vacuum) revision 018 EP/11A15000/E-0 (Reactor Trip or Safety Injection) revision 036DCS EP/11A15000/E-3 (Steam Generator Tube Rupture) revision 034DCS OP/OIAl64001006C (Nuclear Service Water) revision 266 NOTES AND INSTRUCTIONS NOTE: The following steps are GUIDELINES.

The NRC lead examiner will direct timing of events unless otherwise noted. NOTE: Any groups or individuals (IAE, RxGrp, RP, SOC, SWM) that are called to IIR a problem or for simple notification of a problem, repeat back the information they provide unless otherwise noted. NOTE: Any operators dispatched should repeat back information provided.

Call back items are listed below when necessary for the scenario.

Event 1 -Borate for power decrease This event will be entered once the crew has taken turnover and evaluated plant conditions.

When the first boration batch has been completed, the next event can be started. Event 2 -Power reduction using turbine/rods as necessary When turbine power has been reduced by 3-5 MW, the next event can be inserted.

Event 3 -1 B S/G WR level fails low, SRO Technical Specification Initiating Cues:

1AD-2 alarms F/10 (DCS alarm screen shows actual alarm) TS 3.3.3 Item 21, Conditions A, C Event 4 -RN Strainer 1A high DIP, backflush does not operate, SRO Technical Specification Initiating Cues:

1 AD-12 alarms Al1 , Al2, Al5, C/2 When AP/OIAl55001020 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

TS 3.7.8 Condition A If asked to check out RN pump 1 A and/or breaker state, after 10 minutes state "Nothing unusual was noted." If asked to check on RN pump 1 B following the state, state "It appears to be operating normally." Event 5 -Generator voltage regulator fails voltage low Initiating Cues:

OAC alarm C1A0567 (Unit 1 Generator Volts) -LO At Step 17, when the SOC is contacted for guidance on adjusting generator voltage state "Adjust voltage per the Voltage Schedule".

When step 18 of AP/1/A/55001037 is reached, the next event can be entered. Event 6 -Loss of condenser vacuum Initiating Cues:

1AD1, F/7

OAC alarm C1A0734 (Condenser C absolute backpressure)

Turbine MW decreasing When load has been reduced to -1165 per AP/1/A/55001023, TL pressure will fail to 0 per EVENT 15. Once the crew begins adjusting 1 TL-4, EVENT 11 will trigger which will make the leak smaller and go away completely after a few minutes so that vacuum recovers.

Event 7 -PZR Spray valve 1NC-27 fails intermediate with no manual control NOTE: If the spray valve failure is not dealt with quickly, the reactor will trip and in that case, EVENT 8 should be immediately triggered.

Initiating Cues:

1AD-6, FIB

OAC alarm C1 L4455 (Normal Pressurizer Spray Flow Activated)

When AP/1/A/55001011 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

This will begin the major event. TS -3.4.1 Condition A (based on NC pressure at the time) ( unusual was noted." If asked to check on RN pump 1 B following the state, state "It appears to be operating normally." Event 5 -Generator voltage regulator fails voltage low Initiating Cues:

OAC alarm C1A0567 (Unit 1 Generator Volts) -LO At Step 17, when the SOC is contacted for guidance on adjusting generator voltage state "Adjust voltage per the Voltage Schedule".

When step 18 of AP/1/A15500/037 is reached, the next event can be entered. Event 6 -Loss of condenser vacuum Initiating Cues:

1AD1, F/7

OAC alarm C1A0734 (Condenser C absolute backpressure)

Turbine MW decreasing When load has been reduced to -1165 per AP/1 I A15500/023, TL pressure will fail to 0 per EVENT 15. Once the crew begins adjusting 1 TL -4, EVENT 11 will trigger which will make the leak smaller and go away completely after a few minutes so that vacuum recovers.

Event 7 -PZR Spray valve 1NC-27 fails intermediate with no manual control NOTE: If the spray valve failure is not dealt with quickly, the reactor will trip and in that case, EVENT 8 should be immediately triggered.

Initiating Cues:

1AD-6, F/8

OAC alarm C1 L4455 (Normal Pressurizer Spray Flow Activated)

When AP/1/A15500/011 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.

This will begin the major event. TS -3.4.1 Condition A (based on NC pressure at the time)

Event 8 -Tube rupture on 1A S/G Initiating Cues:

1 RAD-1, 8/1, 8/4, E/5

1 RAD-3, E/5 This is the major event. Additional failures

Failure of automatic feedwater (CF) isolation

Failure of 1 NI-9 and 1 NI-1 0 to automatically position

S/G PORV 1SV-19 fails open Scenario End Point ANYTIME AFTER SAFETY INJECTION IS TERMINATED PER EP/1/A1S000/E*3 Step 2S.c. Event 8 -Tube rupture on 1A S/G Initiating Cues:

1 RAD-1, 8/1, 8/4, E/5

1 RAD-3, E/5 This is the major event. Additional failures

Failure of automatic feedwater (CF) isolation

Failure of 1 NI-9 and 1 NI-1 0 to automatically position

S/G PORV 1SV-19 fails open Scenario End Point ANYTIME AFTER SAFETY INJECTION IS TERMINATED PER EP/1/A1SOOO/E*3 Step 2S.c. j ,

CREW TURNOVER INFORMATION Initial Conditions:

100% power

EFPD = 25 days

Boron Concentration is 1348 ppm Turnover:

1CFP5600 (10 S/G Narrow Range Level Ch #2) failed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago. IAE repairs are in progress and estimated to take 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . All TSAIL entries have been made.

Reduce power to 87% for control valve movement test to be done by the next shift per OP/1/A/61 001003 (Controlling Procedure for Unit Operation), Enclosure 4.3, Unit Operation Between 85% and 100% Power. ( CREW TURNOVER INFORMATION Initial Conditions:

100% power

EFPD = 25 days

Boron Concentration is 1348 ppm Turnover:

1CFP5600 (1 D S/G Narrow Range Level Ch #2) failed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago. IAE repairs are in progress and estimated to take 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . All TSAIL entries have been made.

Reduce power to 87% for control valve movement test to be done by the next shift per OP/1/A/61 00/003 (Controlling Procedure for Unit Operation), Enclosure 4.3, Unit Operation Between 85% and 1 00% Power.

Boron Concentration Control 1. Purpose To describe the operation of the Boron Concentration Control System. 2. Limits and Precautions OP/l!A/6150/009 Page 2 of4 2.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing boron concentration. (R.M.) 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 When changing the boron concentration of the NC System, closely monitor the following for expected indication:

Rodmotion

T-AVG

Nuclear instrumentation 2.2.2 When performing dilutions at or near 100% power, batch additions to the VCT (instead of continuous dilution at low flow rates) are the preferred method. {PIP C99-0587}

2.2.3 If the NC System is filled and vented and the boron concentration is being reduced in the NC System, at least one NC pump shall be in operation, recirculating the NC System. {PIP C99-2510}

2.2.4 If the boron concentration is being increased in the NC System, at least one NC pump or one ND pump shall be in operation, recirculating the NC System. 2.2.5 Following an increase or decrease of the NC System boron concentration of 50 ppm, pressurizer spray shall be operated to equalize the boron concentration throughout the system. 2.2.6 When the reactor is subcritical and dilution is in progress, if the Nuclear Instrumentation increases by a factor of two, secure the operation immediately and evaluate the cause. 2.2.7 If the unit has operated continuously for several months, significant Boron 10 depletion may have occurred.

The effective boron concentration of the NC System may be lower than indicated by Chemistry samples. NC temperature shall be carefully monitored following VCT makeup. 2.3 During continuous dilution operations, sample the NC System H2 concentration every eight hours. Boron Concentration Control 1. Purpose To describe the operation of the Boron Concentration Control System. 2. Limits and Precautions OP!l/A/6150/009 Page 2 of4 2.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing boron concentration. (R.M.) 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 When changing the boron concentration of the NC System, closely monitor the following for expected indication:

Rod motion

T-AVG

Nuclear instrumentation 2.2.2 When performing dilutions at or near 100% power, batch additions to the VCT (instead of continuous dilution at low flow rates) are the preferred method. {PIP C99-0587}

2.2.3 If the NC System is filled and vented and the boron concentration is being reduced in the NC System, at least one NC pump shall be in operation, recirculating the NC System. {PIP C99-2510}

2.2.4 If the boron concentration is being increased in the NC System, at least one NC pump or one ND pump shall be in operation, recirculating the NC System. 2.2.5 Following an increase or decrease of the NC System boron concentration of 50 ppm, pressurizer spray shall be operated to equalize the boron concentration throughout the system. 2.2.6 When the reactor is subcritica1 and dilution is in progress, if the Nuclear Instrumentation increases by a factor of two, secure the operation immediately and evaluate the cause. 2.2.7 If the unit has operated continuously for several months, significant Boron 10 depletion may have occurred.

The effective boron concentration of the NC System may be lower than indicated by Chemistry samples. NC temperature shall be carefully monitored following VCT makeup. 2.3 During continuous dilution operations, sample the NC System H2 concentration evelY eight hours.

OP/l!A/61501009 Page 3 of4 2.4 When manually operating any motor operated valve, minimize the torque applied to the handwheel.

2.5 After

manual operation, maintenance or packing adjustment of any motor operated safety related valve, it shall be cycled electrically to ensure reliable automatic operation.

2.6 With the "NC MAKEUP MODE SELECT" switch in the "DILUTE" position, the makeup flow rate is limited by letdown flow, the VCT spray nozzle, and VCT pressure.

The maximum expected makeup flow rate is approximately 95 gpm. 2.7 With the "NC MAKEUP MODE SELECT" switch in the "ALTERNATE DILUTE" position, the maximum expected makeup flow rate is approximately 130 gpm. 2.8 With BAT boron concentration greater than or equal to 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is ppm. Automatic or manual makeup can be used when NC System boron concentration is < 1300 ppm. {PIP 03-7305} 2.9 With BAT boron concentration less than 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is::: 1250 ppm. Automatic or manual makeup can be used when NC System boron concentration is < 1250 ppm. {PIP 03-7305} 3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Automatic

Makeup 4.2 4.3 Dilution 4.4 Alternate Dilution 4.5 Manual Operation Of The Makeup Controls 4.6 Operation Of The Boric Acid Transfer Pumps In Miniflow 4.7 Placing Boric Acid Tank #2 In Service For Unit #1 4.8 Valve Checklist

4.9 Rapid

Boration OP/l!A/6150/009 Page 3 of4 2.4 When manually operating any motor operated valve, minimize the torque applied to the handwheel.

2.5 After

manual operation, maintenance or packing adjustment of any motor operated safety related valve, it shall be cycled electrically to ensure reliable automatic operation.

2.6 With the "NC MAKEUP MODE SELECT" switch in the "DILUTE" position, the makeup flow rate is limited by letdown flow, the VCT spray nozzle, and VCT pressure.

The maximum expected makeup flow rate is approximately 95 gpm. 2.7 With the "NC MAKEUP MODE SELECT" switch in the "ALTERNATE DILUTE" position, the maximum expected makeup flow rate is approximately 130 gpm. 2.8 With BAT boron concentration greater than or equal to 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is ppm. Automatic or manual makeup can be used when NC System boron concentration is < 1300 ppm. {PIP 03-7305} 2.9 With BAT boron concentration less than 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is:::: 1250 ppm. Automatic or manual makeup can be used when NC System boron concentration is < 1250 ppm. {PIP 03-7305} 3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Automatic

Makeup 4.2 4.3 Dilution 4.4 Alternate Dilution 4.5 Manual Operation Of The Makeup Controls 4.6 Operation Of The Boric Acid Transfer Pumps In Miniflow 4.7 Placing Boric Acid Tank #2 In Service For Unit #1 4.8 Valve Checklist

4.9 Rapid

Boration BOP DOES THIS 1. Initial Conditions o 1.1 11: .* 1) o 2. Procedure o 2:1 2.2 o 2.3 o 2.4 o 2.5 2.6 o 2.7 o 2.8 o 2.9 Enclosure

4.2 Boration

OP;1/A/6150/009 Page 1 of3 BOP DOES THIS 1. Initial Conditions Enclosure

4.2 Boration

OP;1/A/6150/009 Page 1 of3 1.2l V

duringtJ;te

2. Procedure lB' B-¢acgIrit£ ,IR.MJ o eml\XiferPmfiToijI6h<.let;yCtrl) 01 NY ";.'tS6A(I31 Aijlenc1¢t O tlt1;pVCl1>Otlt) 2.6 4H (AlltQmati!{,:t¥al<eqp), recqrd , .* ,1gplJl' o 2.8 o 2.9 2.10 D 2.12 2.13 2.14 Enclosure

4.2 Boration

IF desired, flush the makeup line as follows: 2.14.1 Open the following valves: D INV-242A (RMWST To BfA Blender Ctrl) D 1NV-186A (BfA Blender Otlt To VCT Otlt) OP;1fAf6150/o09 Page 2 of3 Flushing should not be desired at this time. D 2.14.2 Ensure one reactor makeup water pump is in "ON". 2.14.3 WHEN 20 gallons of makeup water have been flushed through the makeup line, close the following valves: D INV-242A (RMWST To BfA Blender Ctrl) D INV-186A (BfA Blender Otlt To VCT Otlt) 2.14.4 Place the following valve control switches in "AUTO": D INV-242A (RMWST To BfA Blender Ctrl) D INV-186A (BfA Blender Otlt To VCT Otlt) 2.14.5 IF NOT required for current plant operation, place the reactor makeup water pump started in Step 2.14.2 in "AUTO". Enclosure

4.2 Boration

D D

OP!lfAf6150f009 Page 2 of3 2.13 the1({I!QwjiIg D

P:w D

vCrOtIt)l 2.14 line IF desired, flush the makeup line as follows: 2.14.1 Open the following valves: D INV-242A (RMWST To BfA Blender Ctrl) D INV-186A (BfA Blender Otlt To VCT Otlt) Flushing should not be desired at this time. D 2.14.2 Ensure one reactor makeup water pump is in "ON". 2.14.3 WHEN 20 gallons of makeup water have been flushed through the makeup line, close the following valves: D INV-242A (RMWST To BfA Blender Ctrl) D INV-186A (BfA Blender Otlt To VCT Otlt) 2.14.4 Place the following valve control switches in "AUTO": D INV-242A (RMWST To BfA Blender Ctrl) D INV-186A (BfA Blender Otlt To VCT Otlt) 2.14.5 IF NOT required for current plant operation, place the reactor makeup water pump started in Step 2.14.2 in "AUTO".

2.15 2.15.1 2.15.2 Enclosure

4.2 Boration

OP/l!A/6150/009 Page 3 of3 IF it is desired to change the blender outlet boron concentration, refer to Enclosure 4.1 (Automatic Makeup). OR o 2.15.2.1 o 2.15.2.2 o 2.15.2.3 2.16 Do NOT file this enclosure in the Control Copy folder of this procedure.

2.15.1 Enclosure

4.2 Boration

OP;l/A/6150/009 Page30f3 IF it is desired to change the blender outlet boron concentration, refer to Enclosure 4.1 (Automatic Makeup). OR D 2.15.2.1 D 2.15.2.2 D 2.15.2.3 I\9;{TII 2.16 Do NOT file this enclosure in the Control Copy folder of this procedure.

Controlling Procedure For Unit Operation

1. Purpose OP/l!A/6100/003 PageZ of4 To describe the operation of the unit between approximately 15% and 100% tull power. 2. Limits and Precautions 2.1 This procedure is Reactivity Management relared because it controls activities that can effect core reactivity by the following: (R.M.)

Control rod movement

Turbine load changes

Feedwater manipulations

Reactor power changes 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 Before returning reactor control to automatic, T -A VG shall be within +/- 1°F of T-REF. 2.2.2 Do NOT exceed rod insertion limits or temporary rod withdrawal limits. 2.2.3 Automatic control rod withdrawal is blocked when Control Bank D 200 steps withdrawn.

2.2.4 The difference in boron concentration between the PZR and NC System is desired to be maintained within +/- 50 ppm. 2.2.5 Axial Flux Difference (AFD) shall be maintained within the allowable limits as defined in the ROD manual at all power levels above 50% reactor power. (Tech Spec 3.2.3) 2.2.6 During a power change, other indications of reactor power shall be observed along with power range and secondary thermal power indications to aid in determining the reactor power level. Using indications like turbine impulse pressure, CF flow rate, NC loop Ts, and others may help in detecting the miscalibration of a nuclear instrument.

2.3 In the event of an inadvertent power reduction, it is recommended that the power level NOT be increased until an investigation has been conducted and corrective action taken. Controlling Procedure For Unit Operation

1. Purpose OPll/A/61 001003 Page 2 of4 To describe the operation of the unit between approximately 15% and 100% tull power. 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can effect core reactivity by the following: (R.M.)

Control rod movement

Turbine load changes

Feedwater manipulations

Reactor power changes 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 Before returning reactor control to automatic, T -A VG shall be within +/- 1°F of T-REF. 2.2.2 Do NOT exceed rod insertion limits or temporary rod withdrawal limits. 2.2.3 Automatic control rod withdrawal is blocked when Control Bank D 200 steps withdrawn.

2.2.4 The difference in boron concentration between the PZR and NC System is desired to be maintained within +/- 50 ppm. 2.2.5 Axial Flux Difference (AFD) shall be maintained within the allowable limits as defined in the ROD manual at all power levels above 50% reactor power. (Tech Spec 3.2.3) 2.2.6 During a power change, other indications of reactor power shall be observed along with power range and secondary thermal power indications to aid in determining the reactor power level. Using indications like turbine impulse pressure, CF flow rate, NC loop and others may help in detecting the miscalibration of a nuclear instrument.

2.3 In the event of an inadvertent power reduction, it is recommended that the power level NOT be increased until an investigation has been conducted and corrective action taken.

OP/l!Al61 00/003 Page 3 of4 2.4 If reactor control is in manual, maintain T-AVG within +/- 2°F ofT-REF to prevent receiving "T-REF/T-AUCT HIILO" alarm. 2.5 Whenever there is a thermal power change greater than or equal to 15% rated thermal power within a one hour period: (OAC point CIL4790 in alarm)

Notify Chemistry to take an isotopic analysis for iodine within 2 to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months following the last power change that is greater than or equal to 15% rated thermal power within a one hour period. (T.S. SR 3.4.16.2)

When thermal power has stabilized, notify Radiation Protection to sample and analyze gaseous effluents. (S.L.C. 16.11-6) 2.6 S/G blowdown flowrate shall NOT exceed a maximum of200 GPM per S/G. 2.7 After a thermal power change when plant conditions stabilize, lEMF-39 setpointsshall be adjusted so the Trip 2 setpoint is set at three times the containment activity and Trip 1 setpoint is set at 70% of Trip 2 setpoint.

2.8 If the RC System condenser inlet temperature drops to less than or equal to 60°F when the Rx is shutdown or less than or equal to 5SOF when the Rx is critical, the system shall be configured as follows:

One RC pump running (throttled).

One tower inlet isolated.

All three riser bypasses open. 2.9 OAC point CIK0628 (CF Flow Venturi Correction Factor) shall be reset to 1.0 when either of the following conditions are met:

A step load change such as a load rejection greater than 10% rated thermal power,

A ramp load change of greater than 15% rated thermal power in a one hour period. 2.10 When the unit is engaged in a power maneuver resulting in a mismatch between OAC point CIP1385 (Reactor Thermal Power, Best) and any excore power channel in excess of2% refer to Tech Spec Basis for SR 3.3.1.2. 2.11 The insertion of Control Bank D will affect mismatch between OAC point CIP1385 (Reactor Thermal Power, Best) and the excore power range channels.

This is due to shielding of the power range detectors by Control Bank D. Therefore, refer to Tech Spec Basis for SR 3.3.1.2 when mismatch between Reactor Thermal Power (Best Estimate) and the excore power range channels shall be observed to be exceeding 2%. 2.12 The Reactor Engineering Group normally provides information for planned power maneuvers.

The OAC xenon predict program can be used to help anticipate dilution and boration requirements.

{PIP C99-0587}

OP!l/A/61 00/003 Page 3 of4 2.4 If reactor control is in manual, maintain T-AVG within +/- 2°F ofT-REF to prevent receiving "T-REF/T-AUCT HIILO" alarm. 2.5 Whenever there is a thermal power change greater than or equal to 15% rated thermal power within a one hour period: (OAC point C1L4790 in alarm)

Notify Chemistry to take an isotopic analysis for iodine within 2 to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months following the last power change that is greater than or equal to 15% rated thermal power within a one hour period. (T.S. SR 3.4.16.2)

When thermal power has stabilized, notify Radiation Protection to sample and analyze gaseous effluents. (S.L.C. 16.11-6) 2.6 S/G blowdown flowrate shall NOT exceed a maximum of200 GPM per S/G. 2.7 After a thermal power change when plant conditions stabilize, 1EMF-39 setpoints shall be adjusted so the Trip 2 setpoint is set at three times the containment activity and Trip 1 setpoint is set at 70% of Trip 2 setpoint.

2.8 If the RC System condenser inlet temperature drops to less than or equal to 60°F when the Rx is shutdown or less than or equal to 55°F when the Rx is critical, the system shall be configured as follows:

One RC pump running (throttled).

One tower inlet isolated.

All three riser bypasses open. 2.9 OAC point C1K0628 (CF Flow Venturi Correction Factor) shall be reset to 1.0 when either of the following conditions are met:

A step load change such as a load rejection greater than 10% rated thermal power,

A ramp load change of greater than 15% rated thermal power in a one hour period. 2.10 When the unit is engaged in a power maneuver resulting in a mismatch between OAC point C1P138S (Reactor Thermal Power, Best) and any excore power channel in excess of2% refer to Tech Spec Basis for SR 3.3.1.2. 2.11 The insertion of Control Bank D will affect mismatch between OAC point C1P1385 (Reactor Thermal Power, Best) and the excore power range channels.

This is due to shielding of the power range detectors by Control Bank D. Therefore, refer to Tech Spec Basis for SR 3.3.1.2 when mismatch between Reactor Thermal Power (Best Estimate) and the excore power range channels shall be observed to be exceeding 2%. 2.12 The Reactor Engineering Group normally provides information for planned power maneuvers.

The OAC xenon predict program can be used to help anticipate dilution and boration requirements.

{PIP C99-0587}

OP/l!Al6100/003 Page 4 of4 2.13 The Steamline N-16 Radiation Monitors (EMF-71, 72, 73, 74) become inaccurate at power levels below 40% due to inaccuracies in the algorithm used to calculate the output of these monitors.

{PIP 99-3980} 2.14 It is recommended that Primary Chemistry be notified prior to all significant boric acid additions or dilutions to the NC System such that proper pH control may be maintained.

Normal boric acid additions and dilutions should be communicated at the Control Room shift briefing.

{PIP C-01-66S}

2.15 In accordance with INPO best practices when personnel are accessing areas that could experience significant dose rate changes resulting from increasing power, Operations shall maintain Reactor power steady or decreasing.

3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Power

Increase 4.2 Power Decrease 4.4 T-AVG Coastdown 4.4.1 T -A VG Coastdown Data 4.4.2 Adjustment OfDCS ACCEPTED VALUE For T AVG 4.4.3 T-AVG Coastdown Tracking Data (Phase 1 and Phase 2) 4.5 Power Escalation Guideline OP/l!A/61 00/003 Page 4 of4 2.13 The Steamline N-16 Radiation Monitors (EMF-71, 72, 73, 74) become inaccurate at power levels below 40% due to inaccuracies in the algorithm used to calculate the output of these monitors.

{PIP 99-3980} 2.14 It is recommended that Primary Chemistry be notified prior to all significant boric acid additions or dilutions to the NC System such that proper pH control may be maintained.

Normal boric acid additions and dilutions should be communicated at the Control Room shift briefing.

{PIP C-01-665}

2.15 In accordance with INPO best practices when personnel are accessing areas that could experience significant dose rate changes resulting from increasing power, Operations shall maintain Reactor power steady or decreasing.

3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Power

Increase 4.2 Power Decrease 4.4 T -A VG Coastdown 4.4.1 T-AVG Coastdown Data 4.4.2 Adjustment Of DeS ACCEPTED VALUE For T A VG 4.4.3 T -A VG Coastdown Tracking Data (Phase 1 and Phase 2) 4.5 Power Escalation Guideline Enclosure 4.3 Unit Operation Between 85% and 100% Power OPIl!A/61 001003 Page 3 of6 NOTE: The intent of the following step is to have a more controlled final approach to 100% power. 2.9 WHEN at 99.5% reactor power on CIP1385 (Ul Reactor Thermal Power Best), perform the following:

2.9.1 HOLD power escalation for at least 10 minutes to allow for Xenon and AFD oscillations to be seen. 2.9.2 WHEN at least 10 minutes have elapsed,continue the power increase.

CAUTION: Alternate indications of reactor power shall be monitored to verify reactor power level and help prevent NI miscalibration.

--2.10 At 100% thermal power (3411 MWt), compare OAC heat balance point CIP1385 (Reactor Thermal Power, Best) with nuclear instrumentation.

2.11 IF this power increase is from Mode 3, notify Secondary Chemistry to perform a primary to secondary leak rate calculation per PT/l/B/46001028 (Determination of Steam Generator Tube Leak Rate for Unit 1) within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of reaching 100% power. (NSD 513) Person notified -----------------------------

--2.12 IF required, notify IAE to adjust nuclear instrumentation per Model W 10 #00874628.

-START Person notified HERE lTl'llmIC." 2.13 SRO ill " " ' N/A these 2 steps Enclosure 4.3 Unit Operation Between 85% and 100% Power OPIl!A/61 001003 Page 3 of6 NOTE: The intent of the following step is to have a more controlled final approach to 100% power. 2.9 WHEN at 99.5% reactor power on C1P1385 CUI Reactor Thermal Power Best), perform the following:

2.9.1 HOLD power escalation for at least 10 minutes to allow for Xenon and AFD oscillations to be seen. 2.9.2 WHEN at least 10 minutes have elapsed, continue the power increase.

CAUTION: Alternate indications of reactor power shall be monitored to verify reactor power level and help prevent NI miscalibration.

--2.10 2.11 At 100% thermal power (3411 MWt), compare OAC heat balance point C1P1385 (Reactor Thermal Power, Best) with nuclear instrumentation.

IF this power increase is from Mode 3, notify Secondary Chemistry to perform a primary to secondary leak rate calculation per PTIl/B/46001028 (Determination of Steam Generator Tube Leak Rate for Unit 1) within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of reaching 100% power. (NSD 513) Person notified ----------------------------

--2.12 IF required, notify IAE to adjust nuclear instrumentation per Model W 10 #00874628.

Person notified HERE ----------------------------

IJ6wer. 2.13 2

.4;1::

SRO 2i!:14'IF l}otiti'e4per

); N/A these 2 steps 1 2.15 is 1 __ 2.15.1 N/A 2.15.2 2.15.3 2.16 CAUTION: Enclosure 4.3 Unit Operation Between 85% and 100% Power Declare lEMF-48 inoperable.

Close INM-26B (Hot Leg Smpl Heir Cont Isol). Record time ------------------

OP/l!Al6100/003 Page 4 of6 NotifY Primary Chemistry and RP Shift that lEMF-48 has been isolated:

RP Shift person notified.

____________________

_ Primary Chemistry person notified.

___________________

__ ** * .. ' ... "!I.IIIII.II.IEl'1lIllJL

.... *'I' ..... 1IIIJIIII

_.Will*!*,MWlllll

--2.18 Enclosure 4.3 Unit Operation Between 85% and 100% Power OP/liAl61 001003 Page 4 of6 The conti1.1lle whHeperfonning 1 2.15 is 1 __ 2.15.1 N/A 2.15.2 Declare 1EMF-48 inoperable.

Close 1NM-26B (Hot Leg Smp1 Hdr Cont Iso1). Record time -----------------

2.15.3 Notify Primary Chemistry and RP Shift that 1EMF-48 has been isolated:

RP Shift person notified __________

_ Primary Chemistry person notified'----

_________

_ ,NOTE::.! .QUring a Coast4pwn valve testmg,);;is requesf¢d wide:open,.the 10g\i!j <lycrease

",nUNOT belilIea.r withtKa!tve 1:his is4ue toJlj:e .flow the turbine "1@;deman\:!

increase!

sh;bultl be expeCted.

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--2.18 2.18 is N/A 2t Alternate be

'IF gQ% *.

prevent theiml§ma!sh C IP 2%J; NOTE: 2.19 No failed fuel 2.20 25 EFPD so >120 days to refueling 2.21 NOTE: Enclosure 4.3 Unit Operation Between 85% and 100% Power OP/l!A/61 001003 Page 5 of6 2.22 IF shutting down for an outage where condenser vacuum will be broken, at approximately 85% turbine power 003 MWe) complete the Heater Vent Orifice Return to Service Valve Alignment enclosure ofOPIlIB162501004 (Feedwater Heaters, Vents, Drains and Bleed System). Enclosure 4.3 Unit Operation Between 85% and 100% Power OPIl!A161001003 Page 5 of6 NOTE:

followU!g ntilig(;l1eiliist]:y

Jhis,

will%fllloW.

vendQ! support to'lJe

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2.20

.1 Q%is Refueling) fq,f iodine 25 EFPD so

>120 days to refueling

'*if' f, 2.22 IF shutting down for an outage where condenser vacuum will be broken, at approximately 85% turbine power MWe) complete the Heater Vent Orifice Return to Service Valve Alignment enclosure of OP/l/B/62501004 (Feedwater Heaters, Vents, Drains and Bleed System).

Turbine Generator

1. Purpose To describe the proper method for operating the Turbine-Generator.

2. Limits and Precautions OP!l/B/63 00/00 1 Page 2 of5 2.1 This procedure is Reactivity Management related because it controls activities that can effect reactivity. (R.M.) 2.2 Low load operation limits: 2.2.1 The unit can be operated continuously at low loads when exhaust hood temperature is < 175°F. The load shall, however, be increased slowly until the temperature decreases below 125°F before increasing load at normal rate (Multipoint Recorder on 1MC3). 2.2.2 Limit turbine/generator operation below 5% load to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to prevent moisture erosion unless directed by the Turbine Engineer for testing 2.2.3 Motoring of the unit is to be avoided. 2.2.4 Excessive use of the exhaust hood sprays shall be avoided to prevent accelerated blade erosion. 2.3 Journal bearings shall NOT be operated with metal temperatures above 250°F (OAC Turbine Bearings graphic (TGBRG)).

2.4 Lube oil cooler discharge temperatures shall be lOO°F to 120°F when at rated speed. 2.5 The lube oil temperature rise shall NOT exceed SO°F on the main bearings and 45°F on the thrust bearing. 2.6 Under no conditions shall the thrust bearing be operated above 190 0 P metal temperature (OAC Turbine Bearings graphic (TGBRG)).

2.7 Never

allow a hot rotor to stand without rolling. If and when a hot rotor was allowed to stand still, when possible rotate the shaft 180° and allow to stand still again for one-half the time it first stood still, and then put the turbine on turning gear. 2.8 The minimum allowed cold gas temperature is 86°P for operation.

The maximum cold gas temperature is 122°F. (OAC points C1AOS22 (Cold Gas from Hydrogen Cooler Turbine End) and C1A0528 (Cold Gas from Hydrogen Cooler Exciter End), Main Generator graphic (MAINGEN)).

Turbine Generator

1. Purpose To describe the proper method for operating the Turbine-Generator.

2. Limits and Precautions OP/l!B/6300/001 Page 2 of5 2.1 This procedure is Reactivity Management related because it controls activities that can effect reactivity. (R.M.) 2.2 Low load operation limits: 2.2.1 The unit can be operated continuously at low loads when exhaust hood temperature is < 175°F. The load shall, however, be increased slowly until the temperature decreases below 125°F before increasing load at normal rate (Multipoint Recorder on IMC3). 2.2.2 Limit turbine/generator operation below 5% load to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to prevent moisture erosion unless directed by the Turbine Engineer for testing 2.2.3 Motoring of the unit is to be avoided. 2.2.4 Excessive use of the exhaust hood sprays shall be avoided to prevent accelerated blade erosion. 2.3 Journal bearings shall NOT be operated with metal temperatures above 250°F (OAC Turbine Bearings graphic (TGBRG)).

2.4 Lube oil cooler discharge temperatures shall be lOO°F to 120°F when at rated speed. 2.5 The lube oil temperature rise shall NOT exceed 50°F on the main bearings and 45°F on the thrust bearing. 2.6 Under no conditions shall the thrust bearing be operated above 190°F metal temperature (OAC Turbine Bearings graphic (TGBRG)).

2.7 Never

allow a hot rotor to stand without rolling. If and when a hot rotor was allowed to stand still, when possible rotate the shaft 180° and allow to stand still again for one-half the time it first stood still, and then put the turbine on turning gear. 2.8 The minimum allowed cold gas temperature is 86°F for operation.

The maximum cold gas temperature is 122°F. (OAC points CIA0522 (Cold Gas from Hydrogen Cooler Turbine End) and CIA0528 (Cold Gas from Hydrogen Cooler Exciter End), Main Generator graphic (MAINGEN)).

OPI l!B/63 00100 1 Page 3 of5 2.9 Do NOT exceed the load, hydrogen pressure, and power factor limits per the Unit One Revised Data Book Figure 43. 2.10 If the limits of the Unit One Revised Data Book Figure 43 (Generator Capability Curves) are exceeded, the Turbine Generator shall be tripped. 2.11 The generator shall NOT be operated without excitation.

If the generator is operated without field, the unit shall be immediately tripped off the line and shutdown for inspection.

2.12 Following a trip-out due to differential phase relays, both the armature and field windings shall be meggered and inspected before attempting to resynchronize.

2.13 Do NOT allow turbine generator speed to exceed 2000 rpm on overspeed tests. 2.14 The turbine shall NOT be operated with condenser vacuum less than 24.3 inches Hg. 2.15 The maximum differential pressure between adjacent LP shell pressures shall NOT exceed 2.0 inches Hg. (main condenser vacuum gauges on IMC13, OAC points C1P1669 (DIP between A & B Condensers) and C1P1670 (DIP between B & C Condensers) or Main Condenser graphic (CMCOND)).

2.16 Do NOT hold the turbine at speeds < 800 rpm for more than 5 minutes. 2.17 When steam seals are on the turbine, the steam packing exhauster shall be operating, and the turbine shall be on turning gear. The turbine may be taken off gear with steam seals established with concurrence from the Turbine Engineer.

2.18 When a condition arises that is serious enough to make a reduction in speed necessary, it shall be initiated by selecting "MANUAL" and "CONTROL VALVE LOWER" or by tripping the turbine. 2.19 Temperature ofthe LH System reservoir shall be 2: 90°F prior to turbine start (OAC point C1A0188 (LH TEMP)). 2.20 A sudden downward trend on an LP turbine's lower extraction temperature shall be investigated as a possible indication of water induction into the turbine. This is indicated on the recorder on the rear of 1MC8 labeled "TURBINE WATER DETECTION", using any of the LP 8th stage lower temperatures.

2.21 The time the turbine generator is on turning gear shall be kept to a minimum to prevent the buildup of copper dust in the generator coil slots. 2.22 When system is in "EMERG MANUAL" runbacks and limit circuits may NOT be available.

2.23 Control rods shall NOT exceed rod withdrawal limits. Prior to changing power, refer to Reactor Operating Data Book, Temporary Control Rod Withdrawal Limits. OPI l!B/63 00/00 1 Page 3 of5 2.9 Do NOT exceed the load, hydrogen pressure, and power factor limits per the Unit One Revised Data Book Figure 43. 2.10 If the limits of the Unit One Revised Data Book Figure 43 (Generator Capability Curves) are exceeded, the Turbine Generator shall be tripped. 2.11 The generator shall NOT be operated without excitation.

If the generator is operated without field, the unit shall be immediately tripped off the line and shutdown for inspection.

2.12 Following a trip-out due to differential phase relays, both the armature and field windings shall be meggered and inspected before attempting to resynchronize.

2.13 Do NOT allow turbine generator speed to exceed 2000 rpm on overspeed tests. 2.14 The turbine shall NOT be operated with condenser vacuum less than 24.3 inches Hg. 2.15 The maximum differential pressure between adjacent LP shell pressures shall NOT exceed 2.0 inches Hg. (main condenser vacuum gauges on 1MC13, OAC points C1P1669 (DIP between A & B Condensers) and C1P1670 (DIP between B & C Condensers) or Main Condenser graphic (CMCOND)).

2.16 Do NOT hold the turbine at speeds < 800 rpm for more than 5 minutes. 2.17 When steam seals are on the turbine, the steam packing exhauster shall be operating, and the turbine shall be on turning gear. The turbine may be taken off gear with steam seals established with concurrence from the Turbine Engineer.

2.18 When a condition arises that is serious enough to make a reduction in speed necessary, it shall be initiated by selecting "MANUAL" and "CONTROL VALVE LOWER" or by tripping the turbine. 2.19 Temperature of the LH System reservoir shall be 2: 90°F prior to turbine start (OAC point C1A0188 (LH TEMP)). 2.20 A sudden downward trend on an LP turbine's lower extraction temperature shall be investigated as a possible indication of water induction into the turbine. This is indicated on the recorder on the rear of 1MC8 labeled "TURBINE WATER DETECTION", using any of the LP 8th stage lower temperatures.

2.21 The time the turbine generator is on turning gear shall be kept to a minimum to prevent the buildup of copper dust in the generator coil slots. 2.22 When system is in "EMERG MANUAL" runbacks and limit circuits may NOT be available.

2.23 Control rods shall NOT exceed rod withdrawal limits. Prior to changing power, refer to Reactor Operating Data Book, Temporary Control Rod Withdrawal Limits.

OP!l/B/63 00/00 1 Page 4 of5 2.24 A "LOAD RATE" > "6.2 MWIMIN" shall NOT be used during normal load changes. 2.25 The main turbine oil temperature limit of 80 to 90°F shall be maintained when the turbine is on the turning gear. 2.26 Differential temperature between adjacent exhaust hoods shall NOT exceed 30°F unless evaluated and approved by the responsible engineer (Turbine Generator System Expert). (OAC points C1P1667 (A & B Exhaust Hoods Metal Delta Temp) and C1P1668 (B & C Exhaust Hoods Metal Delta Temp) or Main Condenser graphic (CMCOND)).

2.27 During turbine acceleration, the heat up rate of the first stage bowl inner surface (OAC Point C1P1283 (First Stage Metal Temp Rate)) shall be < 150°FIhr.

2.28 During turbine acceleration, the rate of change of the reheat steam temperature (OAC points C1P1287 to C1P1292 (CIV No.1 (to 6) Inlet Temp Rate) or Turbine Generator graphic (TG)) shall be < 125°Flhr.

2.29 Any deviations from this procedure that could affect steam admission rates shall require an engineering evaluation to be performed which specifically addresses partial arc admission.

2.30 The 6.9KV Switchgear Automatic Fast Transfer Switches are placed in the ENABLE position whenever the generator breakers are closed and in the DEFEAT position whenever the generator breakers are open. If an auto swap of the tie breaker occurs when in the DEFEAT position, equipment being supplied by the 6.9KV Switchgear is more likely to trip than when the switch in ENABLE. {PIP 98-4093, PIP 98-3589} 2.31 Feedback loops shall NOT be taken in/out of service during turbine control valve movement. Following turbine control valve movement, DEHC shall be allowed to stabilize prior to placing feedback loops in/out of service to prevent unexpected load changes. (PIP 03-5660) 2.32 The Main Turbine OIU Work Station has the capability to perform control functions for the Main Turbine, including tripping and resetting of the turbine. If a control function window is inadvertently selected while manipulating the Main Turbine OIU Work Station, the window shall be closed to prevent actuation of the control function.

2.33 The Main Turbine shall NOT be run more than 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months at 1800 RPM, no load, unless directed by the Turbine Engineer for testing. 2.34 The Excitation System can affect the functioning of heart pacemakers.

Personnel with pacemaker devices shall NOT enter the AVR enclosure/building during operation or testing. If the A VR enclosurelbuilding is NOT installed, personnel with pacemaker devices shall remain at least 20 feet away from the A VR during operation or testing. 2.35 Failure to confirm steam isolation to the turbine prior to opening the generator breaker may result in destructive overspeed of the steam turbine power train. {PIP C-08-50l8}

OP/I/B/63001001 Page 4 of5 2.24 A "LOAD RATE" > "6.2 MWIMIN" shall NOT be used during nonnalload changes. 2.25 The main turbine oil temperature limit of 80 to 90°F shall be maintained when the turbine is on the turning gear. 2.26 Differential temperature between adjacent exhaust hoods shall NOT exceed 30°F unless evaluated and approved by the responsible engineer (Turbine Generator System Expert). (OAC points C1P1667 (A & B Exhaust Hoods Metal Delta Temp) and C1P1668 (B & C Exhaust Hoods Metal Delta Temp) or Main Condenser graphic (CMCOND)).

2.27 During turbine acceleration, the heat up rate of the first stage bowl inner surface (OAC Point ClP1283 (First Stage Metal Temp Rate)) shall be < 150°FIhr.

2.28 During turbine acceleration, the rate of change of the reheat steam temperature (OAC points C1P1287 to C1P1292 (CIV No.1 (to 6) Inlet Temp Rate) or Turbine Generator graphic (TG)) shall be < 125°Flhr.

2.29 Any deviations from this procedure that could affect steam admission rates shall require an engineering evaluation to be perfonned which specifically addresses partial arc admission.

2.30 The 6.9KV Switchgear Automatic Fast Transfer Switches are placed in the ENABLE position whenever the generator breakers are closed and in the DEFEAT position whenever the generator breakers are open. If an autoswap of the tie breaker occurs when in the DEFEAT position, equipment being supplied by the 6.9KV Switchgear is more likely to trip than when the switch in ENABLE. {PIP 98-4093, PIP 9S-3589} 2.31 Feedback loops shall NOT be taken in/out of service during turbine control valve movement.

Following turbine control valve movement, DEHC shall be allowed to stabilize prior to placing feedback loops in/out of service to prevent unexpected load changes. (PIP 03-5660) 2.32 The Main Turbine OIU Work Station has the capability to perfonn control functions for the Main Turbine, including tripping and resetting of the turbine. If a control function window is inadvertently selected while manipulating the Main Turbine OIU Work Station, the window shall be closed to prevent actuation of the control function.

2.33 The Main Turbine shall NOT be run more than 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months at lSOO RPM, no load, unless directed by the Turbine Engineer for testing. 2.34 The Excitation System can affect the functioning of heart pacemakers.

Personnel with pacemaker devices shall NOT enter the AVR enclosurelbuilding during operation or testing. If the AVR enclosurelbuilding is NOT installed, personnel with pacemaker devices shall remain at least 20 feet away from the A VR during operation or testing. 2.35 Failure to confinn steam isolation to the turbine prior to opening the generator breaker may result in destructive overspeed of the steam turbine power train. {PIP C-08-501S}

3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Turbine

Generator Startup 4.2 opil IB/63 00100 1 Page 5 of5 4.3 Transfer Turbine From Auto Control To Manual Control And Transfer Turbine From Manual Control To Auto Control 4.4 Turbine Generator Shutdown 4.5 Placing (Removing)

Core Monitor And Pyrolysate Collector In (From) Service 4.6 Valve Checklist

4.7 Generator

Operating Limits 4.8 Turbine Generator Roll Computer Points 4.9 Lamp Verification 4.10 Operation of Turbine TSI Panel 4.11 Reboot of the Main Turbine OIU Computer 4.12 Transfer of the Main Turbine OIU Computer Alarm Switch That Drives the "EHC Fault Annunciator" 4.13 Voltage Regulator Operation From Control Room 4.14 Voltage Regulator Operation From UI Gen Voltage Reg Local Control Panel 3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Turbine

Generator Startup 4.2J"gad OP/1/B/63001001 Page:; of5 4.3 Transfer Turbine From Auto Control To Manual Control And Transfer Turbine From Manual Control To Auto Control 4.4 Turbine Generator Shutdown 4.5 Placing (Removing) Core Monitor And Pyrolysate Collector In (From) Service 4.6 Valve Checklist

4.7 Generator

Operating Limits 4.8 Turbine Generator Roll Computer Points 4.9 Lamp Verification 4.10 Operation of Turbine TSI Panel 4.11 Reboot of the Main Turbine OIV Computer 4.12 Transfer of the Main Turbine OIV Computer Alarm Switch That Drives the "EHC Fault Annunciator" 4.13 Voltage Regulator Operation From Control Room 4.14 Voltage Regulator Operation From VI Gen Voltage Reg Local Control Panel 2.2.1 D 2.1.2.7 D 2.1.2.8 D 2.1.2.9 D 2.2.1.1 D D D Enclosure 4.2 Load Changing OP/l!B/6300/001 Page 3 of4 Verify new load target appears on Target Display. Select "GO" and verify it illuminates to start load increase.

S/G blowdown changes shall be coordinated with Secondary Chemistry.

D 2.1.2.7 D 2.1.2.8 START HERE D 2.1.2.9 D 2.2.1.1 Enclosure 4.2 Load Changing OP/liB/63001001 Page 3 of4 Verify new load target appears on Target Display. Select "GO" and verify it illuminates to start load increase.

S/G blowdown changes shall be coordinated with Secondary Chemistry.

..

.....

t 2.2.2 D D D D D D D D D Enclosure 4.2 Load Changing OP/l!B/6300100 1 Page 4 of4 2.3 Do NOT file this enclosure in the Control Copy folder of this procedure.

Enclosure 4.2 Load Changing OP/l!B/63 00100 1 Page 4 of4 2'. l!fnit o 2.2.t!f o 2.2.2;g. D'i:2.t!3>

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VYuft*neW:lb'ad . . ' .*

2.3 Do NOT file this enclosure in the Control Copy folder of this procedure.

SCENARIO 2 EVENT 3 DATA -1 B SIG W/R level fails low INITIATING CUE: 1AD-2 alarms F/10 (DCS alarm screen shows actual alarm) There is no procedural action for this event; it is a TS call for the SRO only. TS 3.3.3 Item 21, Conditions A, C SCENARIO 2 EVENT 3 DATA -1 B SIG W/R level fails low INITIATING CUE: 1AD-2 alarms F/10 (DCS alarm screen shows actual alarm) There is no procedural action for this event; it is a TS call for the SRO only. TS 3.3.3 Item 21, Conditions A, C Initiating Cues: e1AD-12 alarms Al1, Al2, Al5, C/2 ALL STEPS PERFORMED BY BOP Initiating Cues:

1AD-12 alarms Al1, Al2, Al5, C/2 ALL STEPS PERfORMED BY BOP CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/OIN55001020 1 of 52 Rev 37 A. Purpose

To verify proper response in the event of a loss of RN train or normal suction. CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP 101 Al55001020 1 of 52 Rev 37 A. Purpose

To verify proper response in the event of a 1055 of RN train or normal suction.

CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/OIAl55001020 2 of 52 Rev 37 B. Symptoms

Case I. Loss of RN Train:

1AD-12, Al4 or 2AD-12, Al4 "RN PUMP B FLOW HI/LO" -LIT

1AD-12, C/5 or 2AD-12, C/5 "RN PMP B STRAINER HI DIP" -LIT

RN PUMP 1A or 1B -TRIPPED

RN PUMP 2A or 2B -TRIPPED.

Case II. Loss of RN Pit Level:

1AD-12, B/2 "RN PIT A SCREEN HI DIP" -LIT

1AD-12, B/5 "RN PIT B SCREEN HI DIP" -LIT

1AD-12, B/1 or 2AD-12, B/1 "RN PUMP INTAKE PIT A LEVEL -LO" -LIT

1AD-12, B/4 or 2AD-12, B/4 "RN PUMP INTAKE PIT B LEVEL -LO" -LIT

1AD-12, E/2 or 2AD-12, E/2 "RN PIT A SWAP TO SNSWP" -LIT

1AD-12, E/5 or 2AD-12, E/5 "RN PIT B SWAP TO SNSWP" -LIT. CNS LOSS OF NUCLEAR SERVICE WATER AP 101 N55001020 B. Symptoms e Case I. Loss of RN Train:

PU.MIi.

e "RN:

e 1AD-12, N4 or 2AD-12, N4 "RN PUMP B FLOW HI/LO" -LIT e 11.JV.r::\So12 N'5'wRN:!if'1c"SSENTIALlI:4DR B::oRES*S.:1z1DPfj:...

L"O*H':31 1.iIT' .. . J :" fut ... .

", .. '"

.' 1,." .. , : ... )Jf. .

c : . : ... :"",'d/",E},'"-#:R

.. :.,.,: .'.C o c en e 1AD-12, C/5 or 2AD-12, C/5 "RN PMP B STRAINER HI DIP" -LIT e RN PUMP 1A or 1B -TRIPPED e RN PUMP 2A or 2B -TRIPPED. e Case II. Loss of RN Pit Level: e 1AD-12, B/2 "RN PIT A SCREEN HI DIP" -LIT e 1AD-12, B/5 "RN PIT B SCREEN HI DIP" -LIT e 1AD-12, B/1 or 2AD-12, B/1 "RN PUMP INTAKE PIT A LEVEL -LO" -LIT e 1AD-12, B/4 or 2AD-12, B/4 "RN PUMP INTAKE PIT B LEVEL -LO" -LIT e 1AD-12, E/2 or 2AD-12, E/2 "RN PIT A SWAP TO SNSWP" -LIT e 1AD-12, E/5 or 2AD-12, E/5 "RN PIT B SWAP TO SNSWP" -LIT. PAGE NO. 2of52 Rev 37 CNS LOSS OF NUCLEAR SERVICE WATER AP/O/A/55001020 Case I Loss of RN Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c. Operator Actions 2. Any alternate RN Pump can be started. Should secure 1A RN pump due to another pump running. a. b. (RNO continued on next page) PAGE NO. 3 of 52 Rev 37 DeS CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/A/55001020 Case I 3 of 52 Loss of RN Train Rev 37 DC:: ACTION/EXPECTED RESPONSE c. Operator Actions 3 ratil}gRNilPUr11P GR:I;ATER:

Any alternate RN Pump can be started. Should secure 1A RN pump due to another pump running. RESPONSE NOT OBTAINED ti!et{§rmlllg:::t91IoWitig:, a t9:

b.

{i; 1 IHIE'JfA I.§o I, Frq@;i'

.

P{ffi{ PIt J;3:":tsol, i?roDi Lak¢l FrQoi L'k'lt a

_ .. .* ,

_

A (B'NHd'iJ2A

_ (RNO continued on next page)

CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/OIAJ55001020 Case I 4 of 52 Loss of RN Train Rev 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3. (Continued) (RNO continued on next page) CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/ Al5500/020 ACTION/EXPECTED RESPONSE 3. (Continued)

Case I Loss of RN Train RESPONSE NOT OBTAINED fOIJowing};RN 4 of 52 Rev 37 _ e111t-J-849.e

$Ys); ei.

onijQf RL va.lves -;,QPENil OR _e .1R!2::62{ij.N Sy$fDisch'To RCTFfqC;:B)F RN RNDisQIDbjdr

_

RNJ;)isclj:;.ijId( (RNO continued on next page)

CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/ Al5500/020 Case I 5 of 52 Loss of RN Train Rev 37 DeS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3. (Continued)

Conditions do not require these jsteps. This alarm was in , but should be off if 1 A RN pump was secured earlier. Backwash will not operate in any case. _. RN cannot be aligned to the lake _. No flow indicated on operating RN pump(s). THEN align RN to SNSWP as follows: _ 1) Align valves for RN swap to SNSWP. REFER TO Enclosure 2 (RN Valve Alignment for RN Swap to SNSWP). _ 2) IF WL discharge in progress, THEN coordinate with Radwaste Chemistry to secure all controlled WL discharges.

_ 3) IF any RN chemical addition is in progress, THEN have Chemistry secure it. _ 4) WHEN corrective action has been taken, THEN restore RN to normal alignment.

REFER TO Enclosure 3 (Returning RN alignment To Normal After Transfer To SNSWP). _

i.

1AD-12, C/5 "RN PMP B STRAINER HI D/P"

2AD-12, C/2 "RN PMP A STRAINER HI DIP"

2AD-12, CI5 "RN PMP B STRAINER HI DIP". CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/OI AJ55001020 Case I 5 of 52 Loss of RN Train Rev 37 DeE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3. (Continued)

Conditions do not require these lsteps. This alarm was in , but should be off if 1 A RN pump was secured earlier. Backwash will not operate in any case. g. I ittl§t;l*

_. RN cannot be aligned to the lake _. No flow indicated on operating RN pump(s). THEN align RN to SNSWP as follows: _ 1) Align valves for RN swap to SNSWP. REFER TO Enclosure 2 (RN Valve Alignment for RN Swap to SNSWP). _ 2) IF WL discharge in progress, THEN coordinate with Radwaste Chemistry to secure all controlled WL discharges.

_ 3) IF any RN chemical addition is in progress, THEN have Chemistry secure it. _ 4) WHEN corrective action has been taken, THEN restore RN to normal alignment.

REFER TO Enclosure 3 (Returning RN alignment To Normal After Transfer To SNSWP). _ * '1

1AD-12, C/5 "RN PMP B STRAINER HI DIP"

2AD-12, C/2 "RN PMP A STRAINER HI DIP"

2AD-12, CIS "RN PMP B STRAINER HI DIP". LI Farly alsltmslit, TItiEN man UGI,l,ly )J CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/OIAl55001020 ACTION/EXPECTED RESPONSE 6 of 52 Case I Loss of RN Train Rev 37 RESPONSE NOT OBTAINED Perform the following:

CAUTION Closing of the RN supply x-over isolation valves may result in the momentary isolation of an essential header. NOTE Isolating the Unit 1 or 2 non-essential header will result in loss of cooling supply to the following unit related equipment:

VA Supply Vent Units

VF Supply Vent Unit. a. Ensure the following RN supply X-Over isolation valves -CLOSED:

1 RN-4 7 A (RN Supply X-Over Isol)

1 RN-48B (RN Supply X-Over Isol)

2RN-47A (RN Supply X-Over Isol)

2RN-48B (RN Supply X-Over Isol). b. IF flow is returning to normal, THEN GO TO Step 5. c. IF flow is still excessive, THEN: _ 1) Ensure both RN pump(s) on the affected train -OFF. _ 2) Dispatch operators to locate any piping leaks. REFER TO AP/OIAl5500/030 (Plant Flooding).

CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/A/55001020 ACTION/EXPECTED RESPONSE 4.

t:'I;§S' THAI'1,23,QPO 6 of 52 Case I Loss of RN Train Rev 37 DC:: RESPONSE NOT OBTAINED Perform the following:

CAUTION Closing of the RN supply x-over isolation valves may result in the momentary isolation of an essential header. NOTE Isolating the Unit 1 or 2 non-essential header will result in loss of cooling supply to the following unit related equipment:

VA Supply Vent Units

VF Supply Vent Unit. a. Ensure the following RN supply X-Over isolation valves -CLOSED:

1RN-47A (RN Supply X-Over Isol)

1 RN-48B (RN Supply X-Over Isol)

2RN-47A (RN Supply X-Over Isol)

2RN-48B (RN Supply X-Over Isol). b. IF flow is returning to normal, THEN GO TO Step 5. c. IF flow is still excessive, THEN: _ 1) Ensure both RN pump(s) on the affected train -OFF. _ 2) Dispatch operators to locate any piping leaks. REFER TO AP/O/A/55001030 (Plant Flooding).

CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/A/5500/020 ACTION/EXPECTED RESPONSE

b. 8. Case I 7 of 52 Loss of RN Train Rev 37 RESPONSE NOT OBTAINED a. Shift KC train in service as needed. REFER TO:

OP/1/A/6400/005 (Component Cooling Water System)

OP/2/A/6400/005 (Component Cooling Water System). Perform the following:

a. Do not exceed 4650 GPM through an NS Hx. b. Align RN flow through NS Hx(s) as needed to increase each operating RN pump's discharge flow to greater than 8,600 GPM. REFER TO OP/0/A/64001006F (Nuclear Service Water System Flush Procedure).

Dispatch operator to locally remove any D/G(s) without a cooling water supply from standby readiness.

REFER TO:

OP/1/AI6350/002 (Diesel Generator Operation)

OP/2/A/6350/002 (Diesel Generator Operation).

_ Align VCIYC to operating RN train. REFER TO OP/O/Al6450/011 (Control Room Area Ventilation/Chilled Water System). CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/A/55001020 ACTION/EXPECTED RESPONSE

8.

J"9:'ALL,:;UNIT l' 2\,N D, _

_

Case I 7 of 52 Loss of RN Train Rev 37 RESPONSE NOT OBTAINED a. Shift KC train in service as needed. REFER TO:

OP/1/A/64001005 (Component Cooling Water System)

OP/2/A/64001005 (Component Cooling Water System). Perform the following:

a. Do not exceed 4650 GPM through an NS Hx. b. Align RN flow through NS Hx(s) as needed to increase each operating RN pump's discharge flow to greater than 8,600 GPM. REFER TO OP/O/A/64001006F (Nuclear Service Water System Flush Procedure).

Dispatch operator to locally remove any D/G(s) without a cooling water supply from standby readiness.

REFER TO:

OP/1/A163501002 (Diesel Generator Operation)

OP/2/A/63501002 (Diesel Generator Operation

). _ Align VCNC to operating RN train. REFER TO OP/O/Al6450/011 (Control Room Area Ventilation/Chilled Water System).

CNS LOSS OF NUCLEAR SERVICE WATER AP/0/AJ5500/020 ACTION/EXPECTED RESPONSE 10. 11 .

Case I Loss of RN Train RESPONSE NOT OBTAINED TS 3.7.8 Condition A PAGE NO. 8 of 52 Rev 37 CNS LOSS OF NUCLEAR SERVICE WATER AP/O/A/55001020 Case I Loss of RN Train ACTION/EXPECTED RESPONSE 1 O.

R.NlJrai 11,;1 11.

Cotnm'itnlents,Mariu.c:l I: .' SLCJ 6.7-6 (BN*Di§;9harge

.... '. "."" ., ... W.

.... " ... j:> ... ' .... ,e*

3 ..

.*(CQritain1:Yi'eriPS'ta:iS;'stem)*;

... . .... ,., ... ' ..... ,.,. ..... .... Y". 'il* "w.* _ *.*

.' 3.7

.'

.* 3, lnp {ConJrqll3qorn

{c8AVS)1 .. .

_-;' . * ;; ,'REFE'°irO np/f:iIAl' , . .

.,,?, (Cla$$ification:l9>f

..

RESPONSE NOT OBTAINED TS 3.7.8 Condition A PAGE NO. 8 of 52 Rev 37 DCS CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/A/55001020 Case I 9 of 52 Loss of RN Train Rev 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED CNS LOSS OF NUCLEAR SERVICE WATER AP/O/A/55001020 ACTION/EXPECTED RESPONSE 14.

Case I Loss of RN Train RESPONSE NOT OBTAINED PAGE NO. 9 of 52 Rev 37 Duke Energy Procedure No. Catawba Nuclear Station API 1 IA/5500/037 Generator Voltage and Electric Grid Disturbances Revision No. 000 Electronic Reference No. Continuous Use CP00965X PERFORMANCE I **********UNCONTROLLEDFORPRrnT********** (ISSUED) -PDF Format Duke Energy Procedure No. Catawba Nuclear Station AP/I/A/5500/037 Generator Voltage and Electric Grid Disturbances Revision No. 000 Electronic Reference No. Continuous Use CP00965X PERFORMANCE I **********UNCONTROLLEDFORPRrnT********** (ISSUED) -PDF Format CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/A/5500/037 DISTURBANCES 2of20 Revision 0 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED B. Symptoms *

1AD-11, Kl6 "230 KV Switchyard Voltage LO" -LIT

1AD-1, C/4 "GEN Excitation Limiter Active" -LIT

OAC point C1 E1795 (230KV Y BUS VOLTS) -IN ALARM LO

OAC point C1E1797 (230KV R BUS VOLTS) -IN ALARM LO

OAC point C1A0567 (Unit 1 Generator Volts) -IN ALARM HI

OAC point C1A1631 (Unit 1 Generator MEGAVARS)

-IN ALARM HI

OAC point C1A1631 (Unit 1 Generator MEGAVARS)

-IN ALARM LO

Generator voltage and MVARs fluctuating

Generator Capability Curve Exceeded

TCC notification that "Real Time Contingency Analysis" (RTCA) indicates Switchyard voltage would NOT be adequate if the unit should trip.

Case II Abnormal Generator or Grid Frequency:

OAC point C1A0561 (Generator Frequency)

-IN ALARM LO

OAC point C1 E1794 (230KV Y BUS Frequency)

-Indicated Frequency less than 59.8 Hz

OAC point C1 E1796 (230KV R BUS Frequency)

-Indicated Frequency less than 59.8 Hz

SOC or TCC notification of Grid frequency disturbances

1AD-1, D/6 "EHC System Fault" (EHC Alarm Panel input indicates Generator Frequency Correction activated)

-LIT. CNS GENERATOR VOLTAGE AND ELECTRIC GRID AP/1/N5500/037 DISTURBANCES ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED B. Symptoms *

1AD-11, Kl6 "230 KV Switchyard Voltage LO" -LIT

1AD-1, C/4 "GEN Excitation Limiter Active" -LIT

OAC point C1 E1795 (230KV Y BUS VOLTS) -IN ALARM LO

OAC point C1E1797 (230KV R BUS VOLTS) -IN ALARM LO

OAC point C1A0567 (Unit 1 Generator Volts) -IN ALARM HI

OAC point C1A1631 (Unit 1 Generator MEGAVARS)

-IN ALARM HI

OAC point C1A1631 (Unit 1 Generator MEGAVARS)

-IN ALARM LO

Generator voltage and MVARs fluctuating

Generator Capability Curve Exceeded PAGE NO. 2of20 Revision 0

TCC notification that "Real Time Contingency Analysis" (RTCA) indicates Switchyard voltage would NOT be adequate if the unit should trip.

Case II Abnormal Generator or Grid Frequency:

OAC point C1A0561 (Generator Frequency)

-IN ALARM LO

OAC point C1 E1794 (230KV Y BUS Frequency)

-Indicated Frequency less than 59.8 Hz

OAC point C1 E1796 (230KV R BUS Frequency)

-Indicated Frequency less than 59.8 Hz

SOC or TCC notification of Grid frequency disturbances

1AD-1, D/6 "EHC System Fault" (EHC Alarm Panel input indicates Generator Frequency Correction activated)

-LIT.

CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/A155001037 DISTURBANCES 40f20 Case I Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c. Operator Actions 1. 2. RO GENCAP will not be exceeded.

Perform the following:

Shared systems (RN, VC, YC, VA) require an operable normal power source to be operable.

a. IF notified by TCC that degraded switch yard (grid) voltage conditions exist, THEN ensure compliance with the following Tech Specs. REFER TO PT/1/A143501002C (Available Power Source Operability Check).

3.8.1 (AC Sources -Operating)

3.7.8 (Nuclear Service Water System (NSWS)

3.7.10 (Control Room Area Ventilation System (CRAVS))

3.7.11 (Control Room Area Chilled Water System (CRACWS))

3.7.12 (Auxiliary Building Filtered Ventilation System ABFVS)). b. RETURN TO procedure and step in effect. CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. DISTURBANCES AP/1/A/55001037 Case I 4of20 Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions D 2. D GENCAP will not be exceeded.

Perform the following:

Shared systems (RN, VC, YC, VA) require an operable normal power source to be operable.

a. IF notified by TCC that degraded switch yard (grid) voltage conditions exist, THEN ensure compliance with the following Tech Specs. REFER TO PT/1/A/43501002C (Available Power Source Operability Check).

3.8.1 (AC Sources -Operating)

3.7.8 (Nuclear Service Water System (NSWS)

3.7.10 (Control Room Area Ventilation System (CRA VS))

3.7.11 (Control Room Area Chilled Water System (CRACWS))

3.7.12 (Auxiliary Building Filtered Ventilation System ABFVS)). b. RETURN TO procedure and step in effect.

CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/A/5500/037 DISTURBANCES 50f20 Case I Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE 3. Adjust Generator MVARs to operate within Generator Capability Curve limits as follows: _. Depress "LOWER" on the VOLTAGE ADJUST to reduce lagging MVARs

Depress "RAISE" on the VOLTAGE ADJUST to reduce leading MVARs. 4. Notify RES Engineer to evaluate generator abnormal operating conditions.

RESPONSE NOT OBTAINED Perform the following:

a. IF voltage regulator in "AUTO", THEN perform the following:

_ 1) Place voltage regulator in MANUAL. _ 2) Adjust MVARs to within the GENERATOR CAPABILITY CURVE limits. b. IF unable to maintain MVARs within Generator Capability Curve limits, THEN remove generator from service as follows: 1 ) IF reactor power greater than or equal to 69%, THEN perform the following:

_ a) Trip reactor. _ b) GO TO EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).

2) IF reactor power less than 69%, THEN perform the following:

_ a) Trip turbine. _ b) GO TO AP/1/A/5500/002 (Turbine Generator Trip). CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/A/5500/037 DISTURBANCES 50f20 Case I Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE 3. Adjust Generator MVARs to operate within Generator Capability Curve limits as follows: _. Depress "LOWER" on the VOLTAGE ADJUST to reduce lagging MVARs

Depress "RAISE" on the VOLTAGE ADJUST to reduce leading MVARs. 4. Notify RES Engineer to evaluate generator abnormal operating conditions.

RESPONSE NOT OBTAINED Perform the following:

a. IF voltage regulator in "AUTO", THEN perform the following:

_ 1) Place voltage regulator in MANUAL. _ 2) Adjust MVARs to within the GENERATOR CAPABILITY CURVE limits. b. IF unable to maintain MVARs within Generator Capability Curve limits, THEN remove generator from service as follows: 1) IF reactor power greater than or equal to 69%, THEN perform the following:

_ a) Trip reactor. _ b) GO TO EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).

2) IF reactor power less than 69%, THEN perform the following:

_ a) Trip turbine. _ b) GO TO AP/1/A/5500/002 (Turbine Generator Trip).

CNS GENERATOR VOLTAGE AND ELECTRIC GRID DISTURBANCES AP/1/A155001037 Case I Abnormal Generator or Grid Voltage 5. ACTION/EXPECTED RESPONSE No info received from TCC 6. Record time TCC "RTCA" indicated CNS switchyard (grid) voltage NOT adequate.

7. Start 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months timer from time TCC "RTCA" indicated CNS switchyard (grid) voltage NOT adequate.

RESPONSE NOT OBTAINED PAGE NO. 6of20 Revision 0 CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/A155001037 DISTURBANCES 60f20 Case I Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

,<!bhting' .

prQgram if the

5. .lJnIt Tnp Wlth,SafetYi:JDJectlon a ,'N'." t,pn. RO No info received from TCC 6. Record time TCC "RTCA" indicated CNS switchyard (grid) voltage NOT adequate.

7. Start 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months timer from time TCC "RTCA" indicated CNS switchyard (grid) voltage NOT adequate.

_ a.',J:TCC l1asnot report($ 'ii,'dications,THEN notit CJo .. :rnOnitor "RICA" and *teport resu <,i toCQQtrol

Room Supe'fvI$or.

b. :IF!:ATANYTIMETCCrepOrtstffla't indi ',siCNS'

,'ge would';'T be.

it should trip; THEN GO 6} _ TO Step'17;'

CNS GENERATOR VOLTAGE AND ELECTRIC GRID AP/1/N55001037 DISTURBANCES Case I 8. 9. Abnormal Generator or Grid Voltage ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED When TCC "RTCA" indicates switchyard voltage would NOT be adequate if the unit trips, the following conditions exist:

Both trains of offsite (normal) power are inoperable.

Both ECCS trains are in an unanalyzed condition and inoperable.

Shared systems (RN, VC, YC, VA) that require an operable normal power source, are inoperable.

Perform Tech Spec assessment as follows: a. Ensure compliance with the following Tech Specs due to both trains of the following systems inoperable:

3.8.1 (AC Sources -Operating)

3.5.2 (ECCS -Operating)

3.7.8 (Nuclear Service Water System (NSWS>>

3.7.10 (Control Room Area Ventilation System (CRAVS>>

3.7.11 (Control Room Area Chilled Water System (CRACWS>>

3.7.12 (Auxiliary Building Filtered Ventilation System ABFVS>>. b. Ensure compliance with Tech Spec 3.0.3 due to both trains of ECCS, RN, VC, YC, VA inoperable.

Notify Regulatory Compliance to pursue licensing options due to loss of normal power source operability to shared systems. PAGE NO. 70f20 Revision 0 CNS GENERATOR VOLTAGE AND ELECTRICGRID DISTURBANCES AP/1/A/5500/037 Case I 8. 9. Abnormal Generator or Grid Voltage ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED When TCC "RTCA" indicates switchyard voltage would NOT be adequate if the unit trips, the following conditions exist:

Both trains of offsite (normal) power are inoperable.

Both ECCS trains are in an unanalyzed condition and inoperable.

Shared systems (RN, VC, YC, VA) that require an operable normal power source, are inoperable.

Perform Tech Spec assessment as follows: a. Ensure compliance with the following Tech Specs due to both trains of the following systems inoperable:

3.8.1 (AC Sources -Operating)

3.5.2 (ECCS -Operating)

3.7.8 (Nuclear Service Water System (NSWS))

3.7.10 (Control Room Area Ventilation System (CRA VS))

3.7.11 (Control Room Area Chilled Water System (CRACWS))

3.7.12 (Auxiliary Building Filtered Ventilation System ABFVS)). b. Ensure compliance with Tech Spec 3.0.3 due to both trains of ECCS, RN, VC, YC, VA inoperable.

Notify Regulatory Compliance to pursue licensing options due to loss of normal power source operability to shared systems. PAGE NO. 7of20 Revision 0 CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/ Al5500/037 DISTURBANCES 80f20 Case I Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED The TCC/SOC response to a degraded grid voltage condition may restore voltage to adequate status within one hour. 10. Activate the TSC as follows: a. Verify TCC expects switchyard (grid) voltage restoration to adeq uate status in less than one hour. b. Evaluate activating the TSC. REFER TO RP/0/B/5000/027 (Augmentation of Shift Utilizing the Emergency Response Organization without Emergency Declaration)

a. Perform the following:

_ 1) Activate the TSC. REFER TO RP/0/B/5000/027 (Augmentation of Shift Utilizing the Emergency Response Organization without Emergency Declaration)

_ 2) Observe Note prior to Step 11 and GO TO Step 11. NOTE The degraded switchyard (grid) voltage condition places ECCS in an unanalyzed condition reportable per 1 OCFR50. 72(b )(3)(ii).

11. Determine required notifications:

REFER TO RP/0/Al5000/001 (Classification Of Emergency)

REFER TO RP/0/B/5000/013 (NRC Notification Requirements).

12. Evaluate the following:

Stopping in progress surveillance testing.

Stopping in progress maintenance activities.

Returning systems to normal/functional status. CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/ Al5500/037 DISTURBANCES 80f20 Case I Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED The TCC/SOC response to a degraded grid voltage condition may restore voltage to adequate status within one hour. 10. Activate the TSC as follows: a. Verify TCC expects switchyard (grid) voltage restoration to adeq uate status in less than one hour. b. Evaluate activating the TSC. REFER TO RP/0/B/5000/027 (Augmentation of Shift Utilizing the Emergency Response Organization without Emergency Declaration)

a. Perform the following:

_ 1) Activate the TSC. REFER TO RP/0/B/5000/027 (Augmentation of Shift Utilizing the Emergency Response Organization without Emergency Declaration)

_ 2) Observe Note prior to Step 11 and GO TO Step 11. NOTE The degraded switchyard (grid) voltage condition places ECCS in an unanalyzed condition reportable per 1 OCFR50. 72(b)(3)(ii).

11. Determine required notifications:

REFER TO RP/0/Al5000/001 (Classification Of Emergency)

REFER TO RP/0/B/5000/013 (NRC Notification Requirements).

12. Evaluate the following:

Stopping in progress surveillance testing.

Stopping in progress maintenance activities.

Returning systems to normal/functional status.

CNS GENERATOR VOLTAGE AND ELECTRIC GRID AP/1/N55001037 DISTURBANCES Case I Abnormal Generator or Grid Voltage ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED The SOCITCC is allowed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to restore switchyard (grid) voltage to adequate.

The 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months time limit may be adjusted based on OSM assessment of plant or grid conditions.

13. Do not continue in this procedure until one of the following conditions exist:

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months have elapsed since TCC "RTCA" indicated switchyard voltage NOT adequate.

OR

Notification from TCC that "RTCA" indicates switchyard voltage would be adequate should the unit trip. OR

OSM adjust 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months time limit based on assessment of plant conditions PAGE NO. 9 of 20 Revision 0 CNS GENERATOR VOLTAGE AND ELECTRIC GRID AP 111 AJ55001037 DISTURBANCES Case I Abnormal Generator or Grid Voltage ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED The SOCITCC is allowed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to restore switchyard (grid) voltage to adequate.

The 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months time limit may be adjusted based on OSM assessment of plant or grid conditions.

13. Do not continue in this procedure until one of the following conditions exist:

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months have elapsed since TCC "RTCA" indicated switchyard voltage NOT adequate.

OR

Notification from TCC that "RTCA" indicates switchyard voltage would be adequate should the unit trip. OR

OSM adjust 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months time limit based on assessment of plant conditions PAGE NO. 9 of 20 Revision 0 CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/N55001037 DISTURBANCES 10 of 20 Case I Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE 14. Verify TCC reported that "RTCA" indicates switchyard voltage would be adequate should the unit trip. 15. Do not continue in this procedure until TCC reports that "RTCA" indicates switchyard voltage would be adequate should the unit trip. RESPONSE NOT OBTAINED Perform the following:

The jumpers bypass the 4160 degraded voltage 5 second time delay relay.

If an S/I occurs with the jumpers installed, the 4160V incoming breakers trip open when LOCA Sequencer actuates.

The DIGs will supply power. a. Notify to install jumpers per AM/1/N51 001008 (4Kv Essential Power (EPC) System Degraded Voltage Logic. When jumpers are installed offsite power and shared systems remain inoperable until "RTCA" indicates switchyard voltage is adequate should the unit trip. b. WHEN jumpers installed per AM/1/N51 001008 (4Kv Essential Power (EPC) System Degraded Voltage Logic, THEN Unit 1 exits L.C.O. 3.0.3 due to both trains of ECCS inoperable Tech Spec 3.5.2. CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/A/5500/037 DISTURBANCES 10 of 20 Case I Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE 14. Verify TCC reported that "RTCA" indicates switchyard voltage would be adequate should the unit trip. 15. Do not continue in this procedure until TCC reports that "RTCA" indicates switchyard voltage would be adequate should the unit trip. RESPONSE NOT OBTAINED Perform the following:

The jumpers bypass the 4160 degraded voltage 5 second time delay relay.

If an S/I occurs with the jumpers installed, the 4160V incoming breakers trip open when LOCA Sequencer actuates.

The D/Gs will supply power. a. Notify SPOC to install jumpers per AM/1/A/51 00/008 (4Kv Essential Power (EPC) System Degraded Voltage Logic. When jumpers are installed offsite power and shared systems remain inoperable until "RTCA" indicates switchyard voltage is adequate should the unit trip. b. WHEN jumpers installed per AM/1/A/51 00/008 (4Kv Essential Power (EPC) System Degraded Voltage Logic, THEN Unit 1 exits L.C.O. 3.0.3 due to both trains of ECCS inoperable Tech Spec 3.5.2.

CNS GENERATOR VOLTAGE AND ELECTRIC GRID DISTURBANCES AP/1/AJ55001037 Case I Abnormal Generator or Grid Voltage ACTION/EXPECTED RESPONSE 16. WHEN TCC reports "RTCA" indicates switchyard voltage has been returned to adequate should the unit trip, THEN perform the following:

a. IF jumpers installed, THEN notify SPOC to rem'ove jumpers per, AM/1/AJ5100100B (4Kv Essential Power (EPC) System Degraded Voltage Logic. b. Evaluate exiting the following Tech Spec LCO actions:

3.B.1.(AC Sources -Operating)

3.5.2 (ECCS -Operating)

3.7.B (Nuclear Service Water System (NSWS>>

3.7.10 (Control Room Area Ventilation System (CRAVS>>

3.7.11.(Control Room Area Chilled Water System (CRACWS>>

3.7.12 (Auxiliary Building Filtered Ventilation System ABFVS>>. _

Tech Spec LCO 3.0.3. c. Notify Regulatory Compliance of Tech Spec LCO action status. RESPONSE NOT OBTAINED PAGE NO. 11 of 20 Revision 0 CNS GENERATOR VOLTAGE AND ELECTRIC GRID PAGE NO. AP/1/A155001037 DISTURBANCES 11 of 20 Case I Abnormal Generator or Grid Voltage Revision 0 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 16. WHEN Tee reports "RTeA" indicates switchyard voltage has been returned to adequate should the unit trip, THEN petiorm the following:

a. IF jumpers installed, THEN notify SPOC to rem'ove jumpers per, AM/1/A15100100B (4Kv Essential Power (EPC) System Degraded Voltage Logic. b. Evaluate exiting the following Tech Spec LCO actions:

3.B.1.(AC Sources -Operating)

3.5.2 (ECCS -Operating)

3.7.B (Nuclear Service Water System (NSWS))

3.7.10 (Control Room Area Ventilation System (CRAVS))

3.7 .11.(Control Room Area Chilled Water System (CRACWS))

3.7.12 (Auxiliary Building Filtered Ventilation System ABFVS)).

Tech Spec LCO 3.0.3. c. Notify Regulatory Compliance of Tech Spec LCO action status.

CNS GENERA TOR VOLTAGE AND ELECTRIC GRID DISTURBANCES AP/11A155001037 Case I Abnormal Generator or Grid Voltage ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED .B. 18. When the SOC is called, The crew will be told to adjust generator voltage aocording to the voltage schedule.

PAGE NO. 12 of 20 Revision 0 CNS GENERATOR VOLTAGE AND ELECTRICGRID AP/1/AJ5500/037 DISTURBANCES Case I Abnormal Generator or Grid Voltage ACTION/EXPECTED RESPONSE 17. '-R:-::O:--'

'foIlQWs;:j OR 18.

reliable, THEN' RETURN.

in RESPONSE NOT OBTAINED When the SOC is called, The crew will be told to adjust generator voltage according to the voltage schedule.

PAGE NO. 12 of 20 Revision 0 Duke Energy Procedure No. Catawba Nuclear Station API 1 IA/5500/023 Loss of Condenser Vacuum Revision No. 018 Electronic Reference No. Continuous Use CN005CER PERFORMANCE I **********UNCONTROLLEDFORPruNT********** (ISSUED) -PDF Format Initiating Cues:

1AD1, F/7

OAC alarm C1A0734 (Condenser C absolute backpressure)

Turbine MW decreasing Duke Energy Procedure No. Catawba Nuclear Station API 1 IA/SSOO/023 Loss of Condenser Vacuum Revision No. 018 Electronic Reference No. Continuous Use CNOOSCER PERFORMANCE I **********UNCONTROLLEDFORPruNT********** (ISSUED) -PDF Format Initiating Cues:

1AD1, F/7

OAC alarm C1A0734 (Condenser C absolute backpressure)

Turbine MW decreasing CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1 I Al55001023 1 of 15 Revision 18 A. Purpose

To verify proper response in the event of a loss of condenser vacuum. B. Symptoms

Condenser vacuum indication

-DECREASING

Hotwell temperature

-INCREASING

1AD-1, F/7 "CONDENSER LO VACUUM" -LIT

1AD-1, F/8 "EXH HOOD HI TEMP (PRE-TRIP)" -LIT

1AD-5, Al4 "CFPT A LO EXHAUST VACUUM" -LIT

1AD-5, C/4 "CFPT B LO EXHAUST VACUUM" -LIT

OAC point C1P1493 (Unit 1 C1&C2 Average RC Inlet Temp) -IN ALARM HI. CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/11 Al55001023 1 of 15 Revision 18 A. Purpose

To verify proper response in the event of a loss of condenser vacuum. B. Symptoms

Condenser vacuum indication

-DECREASING

Hotwell temperature

-INCREASING

1AD-1, F/7 "CONDENSER LO VACUUM" -LIT

1AD-1, FIB "EXH HOOD HI TEMP (PRE-TRIP)" -LIT

1AD-5, Al4 "CFPT A LO EXHAUST VACUUM" -LIT

1AD-5, C/4 "CFPT B LO EXHAUST VACUUM" -LIT

OAC point C1P1493 (Unit 1 C1&C2 Average RC Inlet Temp) -IN ALARM HI.

CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/11A155001023 ACTION/EXPECTED RESPONSE c. Operator Actions 1. 2. to _ 2) b. Perform the appropriate controlling procedure to reduce power: _. OP/11A161 001003 (Controlling Procedure For Unit Operation)

OR

OP/11A161 001002 (Controlling Procedure For Unit Shutdown).

2 of 15 Revision 18 RESPONSE NOT OBTAINED Crew should stay in this AP at this time. CNS LOSS OF CONDENSER VACUUM AP/1/A155001023 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions 1. 2. Decrease turbine load as required to *. .' d','W* .. ** ... , .* .".' <stabilize vaculiQ!lf's .aJj:i;LIFWPid tHEN perfcWnJlie, NOTE 3

PAGE NO. 2 of 15 Revision 18 _ 1>>'3;Select toteduce turpine load asirequired.

Crew should stay in this AP at this Itime. _ 2) REFER TO AP/flNS500lhbg* . _

b. Perform the appropriate controlling procedure to reduce power: _. OP/1/Al61 001003 (Controlling Procedure For Unit Operation)

OR

OP/1/A161 001002 (Controlling Procedure For Unit Shutdown).

CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/AJ55001023 ACTION/EXPECTED RESPONSE 3. a. b. 3 of 15 Revision 18 RESPONSE NOT OBTAINED a. Perform the following:

_ 1} Start additional cooling tower fans as necessary to maintain condenser inlet temperature less than gO°F. REFER TO OP/1/B/64001001A (Condenser Circulating Water System). _ 2} Start additional RC pump(s} as necessary to maintain condenser inlet temperature less than gO°F. REFER TO OP/1/B/64001001A (Condenser Circulating Water System). b. IF cooling tower level is low, THEN perform the following:

_ 1} Ensure 1RL-853 (Train A RL To RC Makeup Control) RESTORING NORMAL COOLING TOWER LEVEL. 2} IF 1 RL-853 is not maintaining cooling tower level, THEN perform the following:

_ a} Contact Environmental Chemistry to secure cooling tower blowdown.

_ b} Throttle open 1 RL-855 (Train A RL To RC MlU Valve Bypass) (1MC-13) to maintain cooling tower level. _ c} Start additional RL pumps as needed. REFER TO OP/O/B/64001003 (Low Pressure Service Water System). CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/AJ55001023 ACTION/EXPECTED RESPONSE 3.

fQU,c>\Vs:

3 of 15 Revision 18 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Start additional cooling tower fans as necessary to maintain condenser inlet temperature less than gO°F. REFER TO OP/1/B/64001001A (Condenser Circulating Water System). _ 2) Start additional RC pump(s) as necessary to maintain condenser inlet temperature less than gO°F. REFER TO OP/1/B/64001001A (Condenser Circulating Water System). b. IF cooling tower level is low, THEN perform the following:

_ 1) Ensure 1 RL-853 (Train A RL To RC Makeup Control) (1 MC-13) -RESTORING NORMAL COOLING TOWER LEVEL. 2) IF 1 RL-853 is not maintaining cooling tower level, THEN perform the following:

_ a) Contact Environmental Chemistry to secure cooling tower blowdown.

_ b) Throttle open 1 RL-855 (Train A RL To RC M/U Valve Bypass) (1 MC-13) to maintain cooling tower level. _ c) Start additional RL pumps as needed. REFER TO OP/O/B/64001003 (Low Pressure Service Water System).

CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/N55001023 ACTION/EXPECTED RESPONSE 4. 4 of 15 Revision 18 RESPONSE NOT OBTAINED Perform the following:

a. Adjust 1AS-2 (Main Stm To Aux Steam) setpoint to maintain AS header pressure 165 PSIG. b. IF 1AS-2 will not control in automatic, THEN manually adjust 1AS-2 to maintain AS header pressure 165 PSIG. c. IF 1AS-2 is functional, THEN GO TO Step 5. CAUTION Aligning the Unit 2 AS system to supply Unit 1 AS headers may cause small reactivity changes on Unit 2. d. IF Unit 2 available to supply Unit 1 AS header, THEN perform the following:

_ 1) Adjust 2AS-2 (Main Stm To Aux Stm) to maintain AS header pressure 165 PSIG. 2) Dispatch operator to align Unit 2 AS as follows: _ a) Ensure 1AS-33 (Unit 1 AS Hdr Isol) (TB-590, 1 M-26) -OPEN. _ b) Open 1AS-59 (Unit 2 AS Hdr Isol) (TB-584, 2N-26). _ 3) WHEN 1AS-59 is open, THEN slowly close 1AS-2 (Main Stm To Aux Steam). CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/A/55001023 ACTION/EXPECTED RESPONSE 4 of 15 Revision 18 RESPONSE NOT OBTAINED Perform the following:

a. Adjust 1AS-2 (Main Stm To Aux Steam) setpoint to maintain AS header pressure 165 PSIG. b. IF 1AS-2 will not control in automatic, THEN manually adjust 1AS-2 to maintain AS header pressure 165 PSIG. c. IF 1AS-2 is functional, THEN GO TO Step 5. CAUTION Aligning the Unit 2 AS system to supply Unit 1 AS headers may cause small reactivity changes on Unit 2. d. IF Unit 2 available to supply Unit 1 AS header, THEN perform the following:

_ 1) Adjust 2AS-2 (Main Stm To Aux Stm) to maintain AS header pressure 165 PSIG. 2) Dispatch operator to align Unit 2 AS as follows: _ a) Ensure 1AS-33 (Unit 1 AS Hdr Isol) (TB-590, 1 M-26) -OPEN. _ b) Open 1AS-59 (Unit 2 AS Hdr Isol) (TB-584, 2N-26). _ 3) WHEN 1AS-59 is open, THEN slowly close 1AS-2 (Main Stm To Aux Steam).

CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/AJ55001023 5 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 5. a. a. GO TO Step 7. =

b. c. c. GO TO Step 6 RNO. CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/A/5500/023 5 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED EJ5. a. a. GO TO Step 7. b. c. GO TO Step 6 RNO.

CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/A/55001023 6 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 6. _. Verify 1TL-3 (Steam Seal Reg Valve) -* NOT CLOSED OR

Verify both the following:

Unit 1 -ON LINE.

1TL-10 (E Bleed Steam Seal Reg Valve) -NOT CLOSED.

Coordinate local observation of 1TL-9 position as follows: a. Dispatch operator to locally observe 1TL-9 (Steam Seal Packing Unloader Reg Valve) (TB-594, 1G-31). b. Throttle open 1TL-4 (Stm Seal Reg Byp) until one of the following conditions are met: _. Steam seal pressure -GREATER THAN 6 PSIG. OR

Dispatched operator reports 1TL-9 -NOT CLOSED. CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1 I Al55001023 ACTION/EXPECTED RESPONSE , _. Verify 1TL-3 (Steam Seal Reg NOT CLOSED OR

Verify both the following:

Unit 1 -ON LINE.

1TL-10 (E Bleed Steam Seal Reg Valve) -NOT CLOSED. 6 of 15 Revision 18 RESPONSE NOT OBTAINED

.. .' qri'loade( .. .byi oQlof t6e tC-91 ,

c '.

c _ . i{§'#S1lSeaJ

">c'"

,:g!1 _ *

@m

Coordinate local observation of 1TL-9 position as follows: a. Dispatch operator to locally observe 1TL-9 (Steam Seal Packing Unloader Reg Valve) (TB-594, 1G-31). b. Throttle open 1TL-4 (Stm Seal Reg Byp) until one of the following conditions are met: _. Steam seal pressure -GREATER THAN 6 PSIG. OR

Dispatched operator reports 1TL-9 -NOT CLOSED.

CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/N55001023

7. ,BOP 1_ a. b. 8. ACTION/EXPECTED RESPONSE Depending on how closely they monitor vacuum, they may dispatch operators here becasuse the trend doesnt immediately reverse on TL restoration 7 of 15 Revision 18 RESPONSE NOT OBTAINED a. Perform the following: 1 ) IF additional air removal will increase vacuum, THEN perform the following:

a) Dispatch operators to perform the following:

_. Align main vacuum pump(s) for service. REFER TO Enclosure 4 (Placing Main Vacuum Pumps in Service) .

Align idle set of CSAE jet(s) for service. REFER TO OP/1/B/63001006 (Main Vacuum). _ b) WHEN condenser vacuum decreases to less than 24 in. Hg., THEN align main vacuum pump(s) to the condenser.

REFER TO Enclosure 4 (Placing Main Vacuum Pumps in Service).

_ 2) GO TO Step 8. CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/A/55001023 7 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NOTE When. bl9fi By 105A,tQ[

Depending on how closely they monitor vacuum, they may dispatch operators here becasuse the trend doesnt immediately reverse on TL restoration .

Dbserye

.'

7.;' .. 8.

REFERTO oPllO/i3/6250J011

.. '{Vacoum:

Pri l11 irig " a. Perform the following:

1) IF additional air removal will increase vacuum, THEN perform the following:

a) Dispatch operators to perform the following:

Align main vacuum pump(s) for service. REFER TO Enclosure 4 (Placing Main Vacuum Pumps in Service) .

Align idle set of CSAE jet(s) for service. REFER TO OP/1/S/63001006 (Main Vacuum). _ b) WHEN condenser vacuum decreases to less than 24 in. Hg., THEN align main vacuum pump{s) to the condenser.

REFER TO Enclosure 4 (Placing Main Vacuum Pumps in Service).

_ 2) GO TO Step 8.

CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/11A15500/023 8 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 9. 10. 11. 13. 14. The crew may not dispatch operators if they are confident they know that they understand where the issue is and have aken actions to mitigate it. CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/A/55001023 ACTION/EXPECTED RESPONSE 9.

flows.: (Verification . . ... 10. .

Emerg'ency)

-

13. 8 of 15 Revision 18 RESPONSE NOT OBTAINED The crew may not dispatch operators if they are confident they know that they understand where the issue is and have taken actions to mitigate it. NONE Initiating Cues:

1AO-6, FIB

OAC alarm C1 L4455 (Normal Pressurizer Spray Flow Activated)

Initiating Cues:

1AD-6, F/8

OAC alarm C1 L4455 (Normal Pressurizer Spray Flow Activated)

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 1 of 9 Rev 22 A. Purpose To ensure proper response in the event of abnormal Pressurizer pressure, assess plant conditions, and identify the appropriate steps for the following cases: Case I Pressurizer Pressure Decreasing Case II Pressurizer Pressure Increasing.

B. Symptoms Case I. Pressurizer Pressure Decreasing:

1AD-6, E/10 "PZR PORV DISCH HI TEMP" -LIT

1AD-6, E/11 "PZR SAFETY DISCHARGE HI TEMP" -LIT

1AD-6, F/8 "PZR LO PRESS CONTROL" -LIT

1AD-6, Al8 "PZR HI PRESS ALERT" -LIT

All Pzr heaters -ENERGIZED

1AD-6, D/11 "PZR LO PRESS PORV NC34 BLOCKED" -LIT

1AD-6, D/10 "PZR LO PRESS PORV NC32 & 36 BLOCKED" -LIT

Pressurizer pressure less than 2235 PSIG and decreasing Case II. Pressurizer Pressure Increasing:

1AD-6, D/8 "PZR LO PRESS ALERT" -LIT

1AD-6, C/8 "PZR HI PRESS DEV CONTROL" -LIT

1AD-6, B/8 "PZR HI PRESS" -LIT

Pressurizer pressure greater than 2235 PSIG and increasing

All Pzr heaters -ENERGIZED.

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/Al55001011 1 of 9 Rev 22 A. Purpose To ensure proper response in the event of abnormal Pressurizer pressure, assess plant conditions, and identify the appropriate steps for the following cases: Case I Pressurizer Pressure Decreasing Case II Pressurizer Pressure Increasing.

B. Symptoms Case I. Pressurizer Pressure Decreasing:

1AD-6, E/10 "PZR PORV DISCH HI TEMP" -LIT

1AD-6, E/11 "PZR SAFETY DISCHARGE HI TEMP" -LIT

1AD-6, F/8 "PZR LO PRESS CONTROL" -LIT

1AD-6, Al8 "PZR HI PRESS ALERT" -LIT

All Pzr heaters -ENERGIZED

1AD-6, D/11 "PZR LO PRESS PORV NC34 BLOCKED" -LIT

1AD-6, D/10 "PZR LO PRESS PORV NC32 & 36 BLOCKED" -LIT

Pressurizer pressure less than 2235 PSIG and decreasing Case II. Pressurizer Pressure Increasing:

1AD-6, D/8 "PZR LO PRESS ALERT" -LIT

1AD-6, C/8 "PZR HI PRESS DEV CONTROL" -LIT

1AD-6, B/8 "PZR HI PRESS" -LIT

Pressurizer pressure greater than 2235 PSIG and increasing

All Pzr heaters -ENERGIZED.

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A15500/011 Case I 2of9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions BOP DOES THIS PAGE Perform the following:

a. Manually close Pzr PORV(s). b. IF any Pzr PORV cannot be closed, THEN: _ 1) Close the affected PORV(s) isolation valve. 2) IF the Pzr PORV isolation valve cannot be closed, THEN perform the following:

_ a) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/A15500/027 (Shutdown LOCA). _ b) Trip reactor. _ c) WHEN reactor tripped OR SII setpoint reached, THEN ensure SII initiated.

_ d) GO TO EP/1/A15000/E-O (Reactor Trip Or Safety Injection).

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/55001011 Case I 2of9 Pressurizer Pressure Decreasing Rev 22 DCt ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions BOP DOES THIS PAGE Perform the following:

a. Manually close Pzr PORV(s). b. IF any Pzr PORV cannot be closed, THEN: _ 1) Close the affected PORV(s) isolation valve. 2) IF the Pzr PORV isolation valve cannot be closed, THEN perform the following:

_ a) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/A/55001027 (Shutdown LOCA). _ b) Trip reactor. _ c) WHEN reactor tripped OR SII setpoint reached, THEN ensure SII initiated.

_ d) GO TO EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/5500/011 Case I 30f9 Pressurizer Pressure Decreasing Rev 22 DeS ACTION/EXPECTED RESPONSE BOP DOES THIS PAGE It is possible that the crew may feel a need to trip the reactor and SI or it may occur automatically if the crew is slow to respond. In any event, the SGTR will occur on Rx trip, whether the trip is manual or an automatic trip occurs. RESPONSE NOT OBTAINED

"1 NC-29 PZR SPRAY VLV MODE SELECT". (RNO continued on next page) CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/5500/011 Case I 3 of 9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE IBOP DOES THIS PAGE It is possible that the crew may feel a need to trip the reactor and SI or it may occur automatically if the crew is slow to respond. In any event, the SGTR will occur on Rx trip, whether the trip is manual or an automatic trip occurs. RESPONSE NOT OBTAINED Pet!9,fm r b JmraYv'§lyg(s)

Will nOtqlose,t i13¥)1f;jATljl.NYIINlE*

Room

_

9.%;:

NmHylnps1A

aog,J§t, _ c};.GOTOEP/1YN50QQt1?'-O (ReClC?torTrip!fQr St;lfe,'ty Injection).

2) fo(aff?pted _ *

'\ILY* ;MODQi§J;rCEGJ8

"1 NC-29 PZR SPRAYVLV MODE SELECT". _

3; (RNO continued on next page)

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/55001011 Case I 40f9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 2. {Continued)

BOP DOES THIS PAGE 4) IF NC pressure continues to decrease, THEN: a) IF in Modes 1 or 2, THEN: _ (1) Trip reactor. _ (2) WHEN reactor power less than 5%, THEN stop NC Pumps 1A and 1 B. _ (3) GO TO EP/1/A/5000/E-O (Reactor Trip or Safety Injection).

_ b) Stop NC Pumps 1Aand 1B. _ c) IF NC pressure continues to decrease, THEN stop additional NC pumps as required. _ d) REFER TO AP/1/A/55001004 (Loss of Reactor Coolant Pump). _ IF Pzr pressure is less than 2220 PSIG, THEN ensure all Pzr heaters are energized.

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 Case I 4 of 9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 2. (Continued)

IBOP DOES THIS PAGE 4) IF NC pressure continues to decrease, THEN: a) IF in Modes 1 or 2, THEN: _ (1) Trip reactor. _ (2) WHEN reactor power less than 5%, THEN stop NC Pumps 1 A and 1 B. _ (3) GO TO EP/1/A15000/E-O (Reactor Trip or Safety Injection).

_ b) Stop NC Pumps 1A and 1 B. _ c) IF NC pressure continues to decrease, THEN stop additional NC pumps as required.

_ d) REFER TO AP/1/A155001004 (Loss of Reactor Coolant Pump). _ IF Pzr pressure is less than 2220 PSIG, THEN ensure all Pzr heaters are energized.

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/55001011 Case I 50f9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE RO DOES THIS PAGE 7 .

perform following:

a. Verify "P-11 PZR SII BLOCK PERMISSIVE" status light (1SI-18) in required state for unit conditions.

b. Notify IAE to fail following bistables for affected channel per Model WIO #00874531.

Bistables shall be tripped within 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s:

Pzr low pressure S/I

OT Delta T

Pzr high pressure Reactor Trip

Pzr low pressure Reactor Trip. RESPONSE NOT OBTAINED _ IF pressure continues to decrease, THEN REFER TO AP/11A15500/010 (Reactor Coolant Leak). a. Ensure compliance with Tech Spec 3.3.2 (Engineered Safety Features Actuation System (ESFAS) Instrumentation).

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 Case I 50f9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED IRO DOES THIS PAGE

5.

OR

6. ,WHEN

theJqJJ5winga,sleqLHted

\q witt;)jri'1

°pitqf T -Ret'

7.

IlPHEN perform following:

a. Verify "P-11 PZR S/I BLOCK PERMISSIVE" status light (1SI-18) in required state for unit conditions.

b. Notify IAE to fail following bistables for affected channel per Model WIO #00874531.

Bistables shall be tripped within 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s:

Pzr low pressure SII

OT Delta T

Pzr high pressure Reactor Trip

Pzr low pressure Reactor Trip. _ IF pressure continues to decrease, THEN REFER TO AP/11A15500/010 (Reactor Coolant Leak). a. Ensure compliance with Tech Spec 3.3.2 (Engineered Safety Features Actuation System (ESFAS) Instrumentation) .

CNS PRESSURIZER PRESSURE ANOMALIES AP/1/A/55001011 Case I Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE 8.

RESPONSE NOT OBTAINED TS -3.4.1 Condition A (based on NC pressure at the time) PAGE NO. 6of9 Rev 22 CNS PRESSURIZER PRESSURE ANOMALIES AP/1/A/55001011 Case I Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE _

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REWURN in RESPONSE NOT OBTAINED TS -3.4.1 Condition A (based on NC pressure at the time) PAGE NO. 6of9 Rev 22 DCS CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O 1 of 61 Rev 36 A. Purpose This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of all Reactor Trips and 8/1 above P-11, valid 8/1 below P-11 and to assess plant conditions, and to identify the appropriate recovery procedure.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O 1 of 61 Rev 36 A. Purpose This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of all Reactor Trips and 5/1 above P*11, valid 5/1 below P*11 and to assess plant conditions, and to identify the appropriate recovery procedure.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-0 20f61 Rev 36 B. Symptoms or Entry Conditions

1. The following conditions are symptoms that require a Reactor Trip:

1 of 2 SIR channels -GREATER THAN 10 5 CPS WHILE BELOW P-6

1 of 2 I/R channels -GREATER THAN 25% FULL POWER AMPS EQUIVALENT WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 25% FULL POWER WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 109% FULL POWER

2 of 4 P/R channels -+5% FULL POWER IN 2 SECONDS

2 of 4 loop -GREATER THAN THE SETPOINT

2 of 4 loop -GREATER THAN THE SETPOINT

2 of 4 Pzr pressure channels -GREATER THAN 2385 PSIG

2 of 4 Pzr pressure channels -LESS THAN 1945 PSIG WHILE ABOVE P-7

2 of 3 Pzr level channels -GREATER THAN 92% WHILE ABOVE P-7

2 of 4 S/G N/R level channels on 1 of 4 S/Gs -LESS THAN LO-LO SETPOINT

2 of 4 NC pump buses -LESS THAN 77% OF NORMAL VOLTAGE (5082 VOLTS) WHILE ABOVE P-7

2 of 4 NC pump buses -LESS THAN 56 HERTZ WHILE ABOVE P-7

2 of 3 NC flow channels on 2 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-7 AND BELOW P-8

2 of 3 NC flow channels on 1 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-8

4 of 4 turbine stop valves -CLOSED WHILE ABOVE P-9

2 of 4 turbine stop valves EHC pressure -LESS THAN 550 PSIG WHILE ABOVE P-9

1 of 2 S/I trains -ACTUATED

2 of 2 SSPS trains -GENERAL WARNING ALARM. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 2 of 61 Rev 36 B. Symptoms or Entry Conditions

1. The following conditions are symptoms that require a Reactor Trip:

1 of 2 SIR channels -GREATER THAN 10 5 CPS WHILE BELOW P-6

1 of 2 IIR channels -GREATER THAN 25% FULL POWER AMPS EQUIVALENT WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 25% FULL POWER WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 109% FULL POWER

2 of 4 P/R channels -+5% FULL POWER IN 2 SECONDS

2 of 4 loop ilTs -GREATER THAN THE OPilT SETPOINT

2 of 4 loop ilTs -GREATER THAN THE OTilT SETPOINT

2 of 4 Pzr pressure channels -GREATER THAN 2385 PSIG

2 of 4 Pzr pressure channels -LESS THAN 1945 PSIG WHILE ABOVE P-7

2 of 3 Pzr level channels -GREATER THAN 92% WHILE ABOVE P-7

2 of 4 S/G N/R level channels on 1 of 4 S/Gs -LESS THAN LO-LO SETPOINT

2 of 4 NC pump buses -LESS THAN 77% OF NORMAL VOLTAGE (5082 VOLTS) WHILE ABOVE P-7

2 of 4 NC pump buses -LESS THAN 56 HERTZ WHILE ABOVE P-7

2 of 3 NC flow channels on 2 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-7 AND BELOW P-8

2 of 3 NC flow channels on 1 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-8

4 of 4 turbine stop valves -CLOSED WHILE ABOVE P-9

2 of 4 turbine stop valves EHC pressure -LESS THAN 550 PSIG WHILE ABOVE P-9

1 of 2 S/I trains -ACTUATED

2 of 2 SSPS trains -GENERAL WARNING ALARM.

CNS REACTOR TRIP OR SAFETY INJECTION EP/1/A15000/E-O

2. The following are symptoms of a Reactor Trip:

Any Reactor Trip annunciator

-LIT

Neutron level -RAPIDLY DECREASING

Rod bottom lig hts -LIT. 3. The following are symptoms that require a Reactor Trip and 5/1:

2 of 4 Pzr pressure channels -LESS THAN 1845 PSIG

2 of 3 containment pressure channels -GREATER THAN 1.2 PSIG. 4. The following are symptoms of a Reactor Trip and 5/1:

Any S/I Reactor Trip annunciator

-LIT

NV, NI, and NO pumps -ON * "SAFETY INJECTION ACTUATED" status light (1SI-13) -LIT

E/S Load Sequencer Actuated status lights (1SI-14) -LIT. PAGE NO. 30f61 Rev 36 CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 3 of 61 Rev 36 2. The following are symptoms of a Reactor Trip:

Any Reactor Trip annunciator

-LIT

Neutron level -RAPIDLY DECREASING

Rod bottom lights -LIT. 3. The following are symptoms that require a Reactor Trip and 811:

2 of 4 Pzr pressure channels -LESS THAN 1845 PSIG

2 of 3 containment pressure channels -GREATER THAN 1.2 PSIG. 4. The following are symptoms of a Reactor Trip and 8/1:

Any SII Reactor Trip annunciator

-LIT

NV, NI, and ND pumps -ON * "SAFETY INJECTION ACTUATED" status light (1SI-13) -LIT

EIS Load Sequencer Actuated status lights (1SI-14) -LIT.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/AlSOOO/E-O ACTION/EXPECTED RESPONSE c. Operator Actions IRO DOES THIS PAGE 1. .W, *

I .-----._------40f61 Rev 36 DCE RESPONSE NOT OBTAINED Perform the following:

a. Manually trip reactor. b. IF reactor will not trip, THEN concurrently:

Implement EP/1/AlSOOO/F-O (Critical Safety Function Status Trees) .

GO TO EP/1/AlSOOO/FR-S.1 (Response To Nuclear Power Generation/ATWS).

Perform the following:

a. Manually trip the turbine. b. IF turbine will not trip, THEN: _ 1) Depress the "MANUAL" pushbutton on the turbine control panel. _ 2) Rapidly unload turbine by simultaneously depressing the "CONTROL VALVE LOWER" and "FAST RATE" pushbuttons.

3) IF turbine will not runback, THEN close:

All MSIVs _. All MSIV bypass valves. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE C. Operator Actions IRO DOES THIS PAGE

_

_ .'

RESPONSE NOT OBTAINED Perform the following:

a. Manually trip reactor. b. IF reactor will not trip, THEN concurrently:

4 of 61 Rev 36

Implement EP/1/A15000/F-O (Critical Safety Function Status Trees) .

GO TO EP/1/A15000/FR-S.1 (Response To Nuclear Power Generation/ATWS).

Perform the following:

a. Manually trip the turbine. b. IF turbine will not trip, THEN: _ 1) Depress the "MANUAL" pushbutton on the turbine control panel. _ 2) Rapidly unload turbine by simultaneously depressing the "CONTROL VALVE LOWER" and "FAST RATE" push buttons. 3) IF turbine will not runback, THEN close:

All MSIVs _

All MSIV bypass valves.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE -0 IBOP DOES THIS PAGE a. b. WI 6. S/I should have already been actuated, but if not, it will be done here, per RNa. PI ,. 50f61 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. IF 1 ETA AND 1 ETB are de-energized, THEN GO TO EP/1/A15000/ECA-O.O (Loss Of All AC Power). b. WHEN time allows, THEN attempt to restore power to de-energized switchgear while continuing with this procedure.

REFER TO AP/1/A15500/007 (Loss of Normal Power). a. Perform the following:

1) Verify conditions requiring S/I: _ *. Pzr pressure -LESS THAN 1845 PSIG OR _. Containment pressure -GREATER THAN 1.2 PSIG. _ 2) IF S/I is required, THEN manually initiate SIlo 3) IF S/I is not required, THEN concurrently:

Implement EP/1/A15000/F-O (Critical Safety Function Status Trees).

GO TO EP/1/A15000/ES-O.1 (Reactor Trip Response).

b. Manually initiate SIlo CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O I ACTION/EXPECTED RESPONSE -0 :, ..

IBOP DOES THIS PAGE S/I should have already been actuated, but if not, it will be done here, per RNa. 5 of 61 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. IF 1 ETA AND 1 ETB are de-energized, THEN GO TO EP/1/A15000/ECA-O.O (Loss Of All AC Power). b. WHEN time allows, THEN attempt to restore power to de-energized switchgear while continuing with this procedure.

REFER TO AP/1/A155001007 (Loss of Normal Power). a. Perform the following:

1) Verify conditions requiring S/I: _. Pzr pressure -LESS THAN 1845 PSIG OR _. Containment pressure -GREATER THAN 1.2 PSIG.

_ 2) IF S/I is required, THEN manually initiate S/I. 3) IF S/I is not required, THEN concurrently:

Implement EP/1/A15000/F-O (Critical Safety Function Status Trees) .

GO TO EP/1/A15000/ES-O.1 (Reactor Trip Response).

b. Manually initiate S/I.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O 60f61 Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 7. -,.,. ==== -====--8. ICRITICAL TASK ====== IBOP I 9. --------b. --a. Manually initiate Phase A Isolation.

b. Manually align valves. a. Perform the following:

NOTE This time may be used later to determine when to align ND Aux spray. _ 1) Record approximate time of reactor trip. _ 2) Verify NS pumps -INDICATING FLOW. _ 3) IF flow is not indicated, THEN manually initiate Phase B Isolation for affected train(s). (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 6 of 61 IBOP I ACTION/EXPECTED RESPONSE 7

_. iIllFeRGtmfHPII.tlIO/llJ§<'

_

<'W JtS:)<.: q ....

.. :t1 Rev 36 RESPONSE NOT OBTAINED I CRITICAL TASK ,lI1

'--______ --'

... 9. a. Manually initiate Phase A Isolation.

b. Manually align valves. a. Perform the following:

NOTE This time may be used later to determine when to align ND Aux spray. _ 1) Record approximate time of reactor trip. _ 2) Verify NS pumps -INDICATING FLOW. _ 3) IF flow is not indicated, THEN manually initiate Phase B Isolation for affected train(s). (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE 10. (Continued) 70f61 Rev 36 RESPONSE NOT OBTAINED 4) Verify Phase B Isolation has actuated as follows: _a) Phase B Isolation "RESET" lights -DARK. _ b) IF Phase B Isolation "RESET" lights are lit, THEN manually initiate Phase B Isolation.

c) Verify following monitor light panel lights -LIT:

Group 1 Sp lights

Group 5 Sp lights

Group 5 St lights U11 and U12. _d) IF monitor light panel not in correct alignment, THEN ensure correct alignment.

e) IF NS pump(s) did not start, THEN perform the following for the affected train(s):

_ (1) Reset ECCS. _ (2) Reset DIG load sequencer.

_ (3) Manually start affected NS pump. _ (4) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on. _ 5) Stop all NC pumps. _ 6) Maintain seal injection flow. _ 7) Energize H2 igniters. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE 10. (Continued) 7 of 61 Rev 36 DC!: RESPONSE NOT OBTAINED 4) Verify Phase B Isolation has actuated as follows: _ a) Phase B Isolation "RESET" lights -DARK. _ b) IF Phase B Isolation "RESET" lights are lit, THEN manually initiate Phase B Isolation.

c) Verify following monitor light panel lights -LIT:

Group 1 Sp lights

Group 5 Sp lights

Group 5 St lights U11 and U12. _ d) IF monitor light panel not in correct alignment, THEN ensure correct alignment.

e) IF NS pump(s) did not start, THEN perform the following for the affected train(s):

_ (1) Reset ECCS. _ (2) Reset DIG load sequencer.

_ (3) Manually start affected NS pump. _ (4) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on. _ 5) Stop all NC pumps. _ 6) Maintain seal injection flow. _ 7) Energize H2 igniters. (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EPI1IA15000/E-0 ACTION/EXPECTED RESPONSE 10. (Continued)

b. a. ______ _ b.,, ______ _ -80f61 Rev 36 DC:: RESPONSE NOT OBTAINED 8) Dispatch operator to perform the following:

_ a) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ b) Place containment H2 analyzers in service. REFER TO OP/1/A164501010 (Containment Hydrogen Control Systems).

_ 9) WHEN 9 minutes has elapsed, THEN verify proper VX system operation.

REFER TO Enclosure 7 (VX System Operation).

_10) GO TO Step 11. a. Perform the following for the affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected motor driven CApump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart S/I equipment previously on. b. Ensure CA Pump #1 -RUNNING. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 ACTION/EXPECTED RESPONSE 10. (Continued)

IBOP I 1.

8 of 61 Rev 36 RESPONSE NOT OBTAINED 8) Dispatch operator to perform the following:

_ a) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ b) Place containment H2 analyzers in service. REFER TO OP/1IA/6450101 0 (Containment Hydrogen Control Systems).

_ 9) WHEN 9 minutes has elapsed, THEN verify proper VX system operation.

REFER TO Enclosure 7 (VX System Operation).

_10) GO TO Step 11. a. Perform the following for the affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected motor driven CA pump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. b. Ensure CA Pump #1 -RUNNING.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE 12. IBOP I -:

IBOP I 13. 14. J] I P II,' .. IBOP I 15 . *

m 'I' Grew may reset EGGS and DIG sequencers to secure RN pump 1 A since it restarts on the S/I and it still has Hi DIP. 90f61 Rev 36 RESPONSE NOT OBTAINED Perform the following for affected train(s):

a. Reset ECCS . b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a 8/0 occurs, THEN restart 5/1 equipment previously on. Perform the following for affected train(s):

a. Reset ECCS. b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a 8/0 occurs, THEN restart 5/1 equipment previously on. Perform the following:

a. IF any Unit 2 RN pump is off, THEN manually start affected pump(s). b. IF any Unit 1 RN pump is off, THEN perform the following for affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected pump. _ 4) IF AT ANY TIME a 8/0 occurs, THEN restart 5/1 equipment previously on. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTIONIEXPECTED RESPONSE :-iEEE <I.

IBOP I 13.

IBOP I Grew may reset EGGS and DIG sequencers to secure RN pump 1A since it restarts on the SII and it still has Hi DIP. 9 of 61 Rev 36 RESPONSE NOT OBTAINED Perform the following for affected train(s):

a. Reset ECCS . b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. Perform the following for affected train(s):

a. Reset ECCS. b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. Perform the following:

a. IF any Unit 2 RN pump is off, THEN manually start affected pump(s). b. IF any Unit 1 RN pump is off, THEN perform the following for affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected pump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 ACTION/EXPECTED RESPONSE 16. EJ IBOP I 17. ___

___ _ a ................. . b. ________ _ 1NI-9A and 1NI-10B do not automatically position and the BOP should note and manually open these valves. CRITICAL TASK to open at least one of these valves! 10 of 61 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Verify the following valves -CLOSED:

All MSIVs =. All MSIV bypass valves

All SIG PORVs. b. IF any valve is open, THEN: _ 1) Manually initiate Main Steam Isolation.

_ 2) IF any valve is still open, THEN manually close valve. a. Manually start NV pump(s) and align valves. b. ____ _

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop ND pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the NO pump.

__ _ CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 10 of 61 ACTION/EXPECTED RESPONSE 16. EJ Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Verify the following valves -CLOSED:

All MSIVs _. All MSIV bypass valves

All SIG PORVs. b. IF any valve is open, THEN: _ 1) Manually initiate Main Steam Isolation.

IBOP I _ 2) IF any valve is still open, THEN manually close valve. 17.

_ a. Manually start NV pump(s) and align valves. b.

b. "lllll<2\tmilt11ll1l1_i 1NI-9A and 1NI-10B do not automatically position and the BOP should note and manually open these valves. CRITICAL TASK to open at least one of these valves! _ 1l 2,

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop NO pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the NO pump.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O ACTION/EXPECTED RESPONSE 17. (Continued)

IBOpr c .* _ .. ___ _ _d ............... . e. NO pumps -INDICATING FLOW TO C-LEGS. 11 of 61 Rev 36 RESPONSE NOT OBTAINED c. Manually start NI pump(s) and align valves. d. ____ _ _ 1)=====_ 2) IF the NO pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop NO pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the NO pump. _ 3).11 II , e. Manually start NO pump(s) and align valves. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE 17. (Continued)

e. ND pumps -INDICATING FLOW TO C-LEGS. 11 of 61 Rev 36 RESPONSE NOT OBTAINED _ c. Manually start NI pump(s) and align valves. 2) IF the ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop ND pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. e. Manually start ND pump(s) and align valves.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 ACTION/EXPECTED RESPONSE 18. a. b. 19. IBOP I 12 of 61 Rev 36 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF N/R level in all S/Gs is less than 11 % (29% ACC), THEN manually start CA pumps and ensure correct valve alignment.

2) IF N/R level in all S/Gs is less than 11 % (29% ACC) AND feed flow greater than 450 GPM cannot be established, THEN concurrently:

_. Implement EP/1/A15000/F-0 (Critical Safety Function Status Trees).

GO TO EP/1/A15000/FR-H.1 (Response To Loss Of Secondary Heat Sink). _ Manually open valve(s).

20

_ Manually align equipment.

I BOP '1 i be opened based on this RNO . * " 1111 iiil 'I II iii EM

111111 21. EJ CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 ACTION/EXPECTED RESPONSE 18.

19. \BOP I 20. a.

12 of 61 Rev 36 DCE RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF N/R level in all S/Gs is less than 11 % (29% ACC), THEN manually start CA pumps and ensure correct valve alignment.

2) IF N/R level in all S/Gs is less than 11 % (29% ACC) AND feed flow greater than 450 GPM cannot be established, THEN concurrently:

_. Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees) .

GO TO EP/1/A/5000/FR-H.1 (Response To Loss Of Secondary Heat Sink). _ Manually open valve(s}.

_ Manually align equipment.

IBOP I If 1 NI-9A and 1 NI-1 OB are still closed, they will be opened based on this RNO. 21. B_ E]

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O ACTION/EXPECTED RESPONSE 22. _ .... IBOP I 13 of 61 Rev 36 RESPONSE NOT OBTAINED a. IF Pzr pressure is less than 2315 PSIG, THEN: _ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve. 3) IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:

_ a) Energize H2 igniters.

b) Dispatch operator to perform the following:

_ (1) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ (2) Place containment H2 analyzers in service. REFER TO OP/1IAl6450/0 1 0 (Containment Hydrogen Control Systems). (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE 22. illlitWIlr IBOP 1-** 13 of 61 Rev 36 RESPONSE NOT OBTAINED a. IF Pzr pressure is less than 2315 PSIG, THEN: _ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve. 3) IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:

_ a) Energize H2 igniters.

b) Dispatch operator to perform the following:

_ (1) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ (2) Place containment H2 analyzers in service. REFER TO OP/1/A/6450/010 (Containment Hydrogen Control Systems). (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 ACTION/EXPECTED RESPONSE 22. (Continued)

IBOPJ. I'IIIIIIII"II"""II'I"IIII'I'!III'.".

c. 14 of 61 Rev 36 RESPONSE NOT OBTAINED c) IF both the following conditions exist, _. Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). d) Concurrently:

Implement EP/1/A15000/F-0 (Critical Safety Function Status Trees).

GO TO EP/1/A15000/E-1 (Loss Of Reactor Or Secondary Coolant).

b. IF Pzr pressure is less than 2260 PSIG, THEN: _ 1) Manually close spray valve(s).

2) IF spray valve(s) cannot be closed, THEN: _ a) Stop NC pumps 1A and 1 B. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required.

c. IF power is available, THEN open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV. IF any NV OR NI pump is on, THEN: a. Ensure all NC pumps -OFF. b. Maintain seal injection flow. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 ACTION/EXPECTED RESPONSE 22. (Continued)

IBOP I 23. 14 of 61 Rev 36 RESPONSE NOT OBTAINED c) IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). d) Concurrently:

Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).

GO TO EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant).

b. IF Pzr pressure is less than 2260 PSIG, THEN: _ 1) Manually close spray valve(s).

2) IF spray valve(s) cannot be closed, THEN: _ a) Stop NC pumps 1A and 1 B. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required.

c. IF power is available, THEN open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV. IF any NV OR NI pump is on, THEN: a. Ensure all NC pumps -OFF. b. Maintain seal injection flow.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O

24. IBOP I ACTION/EXPECTED RESPONSEII

.-----If the crew does not note the 1A S/G PORVopen, they may transition to E-2 to isolate the PORV and THEN go to E-3. If they note it, they will likely have closed the block valve by this point and will continue in E-O.

I.I.I,IIIJ,.IIIIIIIIIIIIIIII" ___ I I

ii. _-lla'lill

1 EMF-27 (Steamline 1 B)

1 EMF-28 (Steam line 1 C)

1 EMF-29 (Steamline 1 D). 15 of 61 Rev 36 RESPONSE NOT OBTAINED IF pressure in any S/G is decreasing in an uncontrolled manner OR any S/G is depressurized, THEN perform the following:

a. IF both the following conditions exist, _. Containment pressure -GREATER THAN 1 PSIG _. Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN manually start one VX fan. REFER TO Enclosure 5 (YX Fan Manual Start). b. Concurrently:

_. Implement EPI1IA15000/F-O (Critical Safety Function Status Trees). _. GO TO EP/1/A15000/E-2 (Faulted Steam Generator Isolation).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1 I A/5000/E-O ACTION/EXPECTED RESPONSF,;

If the crew does not note the 1A S/G PORV open, they may transition to E-2 to isolate the PORV and THEN go to E-3. If they note it, they will likely have closed the block valve by this point and will continue in E-O. BOP "',":"" "",,,,,1,,,,,,,, ",'",",' Vlri,fl#S/D ,

_

'lllil!JlUltl "it ifiJ\iY, _ -

..

1 EMF-27 (Steamline

18)

1 EMF-28 (Steamline 1 C)

1 EMF-29 (Steamline 1 D). 15 of 61 Rev 36 RESPONSE NOT OBTAINED IF pressure in any S/G is decreasing in an uncontrolled manner OR any S/G is depressurized, THEN perform the following:

a. IF both the following conditions exist, _. Containment pressure -GREATER THAN 1 PSIG _. Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). b. Concurrently:

_. Implement EP/1/A/5000/F-O (Critical Safety Function Status Trees). _. GO TO EP/1/A/5000/E-2 (Faulted Steam Generator Isolation).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 -Page 1 of 1 32 of 61 1 . Foldout Page ....... __ .... .. ........................

Rev 36 2. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NV or NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO O°F. 3. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO AP/1/A15500/006 (Loss of S/G Feedwater):

1AD-5, H/4 "CACST LO LEVEL" OR

1AD-8, B/1 "UST LO LEVEL". 4. Position Criteria for 1 NV-202B and 1 NV-203A (NV Pumps A&B Recirc Isol):

IF NC pressure is less than 1500 PSIG AND NV S/I flowpath is aligned, THEN close 1 NV-202B and 1 NV-203A.

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-202B and 1 NV-203A. 5. Cold Leg Recirc Switch over Criterion:

IF FWST level decreases to 37% (1AD-9, D/8 "FWST 2/4 LO LEVEL" lit), AND an S/I has occurred, THEN GO TO EP/1/A15000/ES-1.3 (Transfer To Cold Leg Recirculation).

CNS REACTOR TRIP OR SAFETY INJECTION EP/1/NSOOO/E-0 -Page 1 of 1 Foldout Page 1 .

__

j.,

.AD it x;*

__ .,, ..... , .....

,1J!ii!I\tF' If .1 ,AtIlt PAGE NO. 32 of 61 Rev 36 .)

.

' ). to

' .*... " ... "M!fil.,

'" ,

.....

1:1

2. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NV or NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO OaF. 3. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO AP/1/NSSOOI006 (Loss of S/G Feedwater):

1AD-S, H/4 "CACST LO LEVEL" OR

1AD-8, B/1 "UST LO LEVEL". 4. Position Criteria for 1 NV-202B and 1 NV-203A (NV Pumps A&B Recirc Isol):

IF NC pressure is less than 1S00 PSIG AND NV SII flowpath is aligned, THEN close 1 NV-202B and 1 NV-203A.

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-202B and 1 NV-203A. S. Cold Leg Recirc Switchover Criterion:

IF FWST level decreases to 37% (1AD-9, D/8 "FWST 2/4 LO LEVEL" lit), AND an SII has occurred, THEN GO TO EP/1/NSOOO/ES-1.3 (Transfer To Cold Leg Recirculation).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O -Page 1 of 7 33 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1.

j -iiii ---=-1 1 I BOP DOES THIS ENCLOSURE I a. Perform the following:

_ 1) Shift operating VCIYC trains. REFER TO Enclosure 6 (Shifting Operating VCIYC Train). 2) IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:

_ -OP/OIAl6450/011 (Control Room Area Ventiiation/Chilied Water System) -EM/OIAl5200/001 (Troubleshooting Cause For Improper Operation of VCIYC System). CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-O -Page 1 of 7 33 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1. -,,'",;:, .v a. Perform the following:

_ 1) Shift operating VCIYC trains. REFER TO Enclosure 6 (Shifting Operating VCIYC Train). 2) IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:

_. OP/O/Al6450/011 (Control Room Area Ventilation/Chilled Water System)

EM/O/Al5200/001 (Troubleshooting Cause For Improper Operation of VCIYC System).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O -Page 2 of 7 34 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 1. (Continued)

b. ilili ,. .== ._=-.... .=. == .... -I. RESPONSE NOT OBTAINED b. IF chlorine odor is detected in the Control Room, THEN perform the following based on the status of given alarms: 1 ) IF detectors on both unit intakes are in alarm, THEN: a) Ensure the following VC intake dampers -CLOSED: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet) _. 2VC-58 (CRA Filt Inlet) _. 2VC-6A (CRA Filt Inlet). _ b) GO TO Step 1.d. 2) IF Unit 1 intake HI chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). b) Ensure the following dampers -OPEN: _. 2VC-58 (CRA Filt Inlet) _. 2VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-O -Page 2 of 7 34 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 1. (Continued)

b.

_

_.

CtlL,<lRllHIEI'g

_.

RESPONSE NOT OBTAINED b. IF chlorine odor is detected in the Control Room, THEN perform the following based on the status of given alarms: 1) IF detectors on both unit intakes are in alarm, THEN: a) Ensure the following VC intake dampers -CLOSED:

1VC-S8 (CRA Filt Inlet)

1VC-6A (CRA Filt Inlet)

2VC-S8 (CRA Filt Inlet)

2VC-6A (CRA Filt Inlet). _ b) GO TO Step 1.d. 2) IF Unit 1 intake HI chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 1VC-S8 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). b) Ensure the following dampers -OPEN: _. 2VC-S8 (CRA Filt Inlet) _. 2VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d. (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A1S000/E-O -Page 3 of 7 3S of 61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1. (Continued) c . * -. -. -.... --IF _*"1 1111 lIB -*1111 * 'II !!i iii 9 11111111 111.111111

3) IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 2VC-S8 (CRA Filt Inlet) _. 2VC-6A (CRA Filt Inlet). b) Ensure the following OPEN: _. 1VC-S8 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 3 of 7 35 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 1. (Continued) d; iRDn&atiSte1li'<1)t)ff K ls .. h.,.', jOi;\. ftl

..

_ ilv RESPONSE NOT OBTAINED 3) IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 2VC-58 (CRA Filt Inlet) _. 2VC-6A (CRA Filt Inlet). b) Ensure the following dampers -OPEN: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 4 of 7 36 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 2. --------" I -'I *

-===------==---... _----CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 4 of 7 36 of 61 Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 2.

Jl""gJ ... ll''k

...

=

Glj

... " .,,,, ..*.. , .. ,'Y,,, *. IrUV1M!i'f'_lYQ?".

_

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A1S000/E-0 -Page S of 7 37 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3. 2 _ ... _-a. Manually start fan(s). b. b. Perform the following:

1) IF annulus pressure is more positive than -1.4 in. WC, THEN: a) Verify flow indicated on the following indications:

JIVE 1A FLOW TO STACK"

JIVE 1 B FLOW TO STACK". b) IF flow is not indicated, THEN dispatch operator to verify status of the following dampers based on their local indication or their operating piston rods being extended 4" to 6":

1AVS-D-2 (VE A Trn Recirc Damp) (AB-603, JJ-S1, Rm SOO) -CLOSED

1AVS-D-7 (VE B Trn Recirc Damp) (AB-603, HH-S2, Rm SOO) -CLOSED

1AVS-D-3 (VE A Trn Exh Damp) (AB-603, JJ-S2, Rm SOO) -OPEN

1 AVS-D-8 (VE B Trn Exh Damp) (AB-603, HH-S2, Rm SOO) -OPEN. _c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A1S2001002 (Troubleshooting Cause For VE System HilLo Pressure).

_d) GO TO Step 3.c. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-0 -Page S of 7 37 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE

..et .** "",.iPH'!'"

.. .. " *. " ..

...... "" ..... fQ:IIQM;}

_ ,ifJ;*lt.llllDlNl

b.

WIll RESPONSE NOT OBTAINED a. Manually start fan(s). b. Perform the following:

1) IF annulus pressure is more positive than -1.4 in. WC, THEN: a) Verify flow indicated on the following indications:

"VE 1 A FLOW TO STACK" * "VE 1 B FLOW TO STACK". b) IF flow is not indicated, THEN dispatch operator to verify status of the following dampers based on their local indication or their operating piston rods being extended 4" to 6":

1 AVS-D-2 (VE A Trn Recirc Damp) (AB-603, JJ-S1, Rm SOO) -CLOSED

1 AVS-D-7 (VE B Trn Recirc Damp) (AB-603, HH-S2, Rm SOO) -CLOSED

1 AVS-D-3 (VE A Trn Exh Damp) (AB-603, JJ-S2, Rm SOO) -OPEN

1AVS-D-8 (VE B Trn Exh Damp) (AB-603, HH-S2, Rm SOO) -OPEN. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A/S2001002 (Troubleshooting Cause For VE System Hillo Pressure).

_d) GO TO Step 3.c. (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 6 of 7 38 of 61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3. (Continued)

c. 2) IF annulus pressure is more negative than -1.8 in. WC, THEN: _ a) Determine which VE train indicates highest discharge flow to stack. _ b) Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , ensure VE train that indicates highest discharge flow to stack is secured. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A152001002 (Troubleshooting Cause For VE System Hi/lo Pressure).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O -Page 6 of 7 38 of 61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3. (Continued)

2) IF annulus pressure is more negative than -1.8 in. WC, THEN: _ a) Determine which VE train indicates highest discharge flow to stack. _ b) Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , ensure VE train that indicates highest discharge flow to stack is secured. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/11A152001002 (Troubleshooting Cause For VE System Hillo Pressure).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-0 -Page 1 of 1 40 of 61 Rev 36 Opposite Unit Ventilation Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1. Ensure proper Unit 2 VA System operation as follows:

Ensure the following fans -OFF:

ABUXF-2A

ABUXF-2B.

Ensure VA System filter is in service as follows: _. 2ABF-D-12

& 19 (VA Filter A Bypass Dampers) -CLOSED _. 2ABF-D-5 & 20 (VA Filter B Bypass Dampers) -CLOSED.

Ensure the following fans -ON:

ABFXF-2A

ABFXF-2B.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/ A/SOOO/E-O -Page 1 of 1 40 of 61 Opposite Unit Ventilation Verification Rev 36 DC!: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1. Ensure proper Unit 2 VA System operation as follows:

Ensure the following fans -OFF:

ABUXF-2A

ABUXF-2B.

Ensure VA System filter is in service as follows: _. 2ABF-D-12

& 19 (VA Filter A Bypass Dampers) -CLOSED _. 2ABF-D-S & 20 (VA Filter B Bypass Dampers) -CLOSED.

Ensure the following fans -ON:

ABFXF-2A

ABFXF-2B.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-O -Page 1 of 4 41 of 61 1. 2 . 3. 4 . 5. NC Temperature Control Rev 36 ACTION/EXPECTED RESPONSE

IRO DOES THIS ENCLOSURE I

I .. -=====--* "PII ,,!! Ii II RESPONSE NOT OBTAINED Perform the following:

a. Use NC T -Colds to determine NC temperature as required in subsequent steps. b. GO TO Step 4. GO TO Step 7. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11 A/SOOO/E-O -Page 1 of 4 41 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE IRO DOES THIS ENCLOSURE I

all RESPONSE NOT OBTAINED Perform the following:

a. Use NC T -Colds to determine NC temperature as required in subsequent steps. b. GO TO Step 4. GO TO Step 7 .

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 2 of 4 42 of 61 Rev 36 NC Temperature Control 6. ACTION/EXPECTED RESPONSE

NC temperature

-GREATER THAN 55rF AND INCREASING IN AN UNCONTROLLED MANNER. OR

NC temperature

-GREATER THAN 557°F AND STABLE. OR

NC temperature

-LESS THAN 55rF AND DECREASING IN AN UNCONTROLLED MANNER. 7. Verify NC temperature*

LESS THAN 557°F AND DECREASING.

RESPONSE NOT OBTAINED Perform the following:

a. IF NC temperature is greater than 55rF AND increasing, THEN stabilize NC temperature at 557°F as follows: 1) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use SIG PORVs. b. IF the following conditions exist:

NC temperature is greater than 55rF and stable

Time and manpower is available, THEN stabilize NC temperature at 557°F as follows: 1 ) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use SIG PORVs. c. GO TO Step 9. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1 I A/5000/E-O -Page 2 of 4 42 of 61 Rev 36 DCS NC Temperature Control ACTION/EXPECTED RESPONSE

NC temperature

-GREATER THAN 55rF AND INCREASING IN AN UNCONTROLLED MANNER. OR

NC temperature

-GREATER THAN 557°F AND STABLE. OR

NC temperature

-LESS THAN 55rF AND DECREASING IN AN UNCONTROLLED MANNER. 7. Verify NC temperature

-LESS THAN 557°F AND DECREASING.

RESPONSE NOT OBTAINED Perform the following:

a. IF NC temperature is greater than 55rF AND increasing, THEN stabilize NC temperature at 55rF as follows: 1) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use SIG PORVs. b. IF the following conditions exist:

NC temperature is greater than 55rF and stable

Time and manpower is available, THEN stabilize NC temperature at 55rF as follows: 1 ) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use SIG PORVs. c. GO TO Step 9.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 3 of 4 43 of 61 Rev 36 NC Temperature Control ACTIONIEXPECTED RESPONSE 8. Attempt to stop the NC cooldown as follows: a. Ensure all steam dumps -CLOSED. b. Ensure all S/G PORVs -CLOSED. c. Ensure S/G blowdown is isolated.

d. Close the following valves:

1SM-77A (S/G 1A Otlt Hdr Bldwn CN)

1 SM-76B (S/G 1 B Otlt Hdr Bldwn CN)

1SM-75A (S/G 1C Otlt Hdr Bldwn CN)

1SM-74B (S/G 1D Otlt Hdr Bldwn CN). e. Depress and hold "SN BEFORE SEAT DRN" "CLOSE" pushbutton (1 MC-3) to close the following valves:

1 SM-41 (Stop Vlv #1 Before Seat Drn)

1 SM-44 (Stop Vlv #2 Before Seat Drn)

1 SM-43 (Stop Vlv #3 Before Seat Drn)

1 SM-42 (Stop Vlv #4 Before Seat Drn). RESPONSE NOT OBTAINED b. IF any S/G PORV cannot be closed, THEN close its isolation valve. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O -Page 3 of 4 43 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE 8. Attempt to stop the NC cooldown as follows: a. Ensure all steam dumps -CLOSED. b. Ensure all S/G PORVs -CLOSED. c. Ensure S/G blowdown is isolated.

d. Close the following valves:

1SM-77A (S/G 1A Otlt Hdr Bldwn CN)

1SM-76B (S/G 1B Otlt Hdr Bldwn CN)

1SM-75A (S/G 1C Otlt Hdr Bldwn CN)

1SM-74B (S/G 1 D Otlt Hdr Bldwn CN). e. Depress and hold "SN BEFORE SEAT DRN" "CLOSE" pushbutton (1 MC-3) to close the following valves:

1 SM-41 (Stop Vlv #1 Before Seat Drn)

1SM-44 (Stop Vlv #2 Before Seat Drn)

1SM-43 (Stop Vlv #3 Before Seat Drn)

1 SM-42 (Stop Vlv #4 Before Seat Drn). RESPONSE NOT OBTAINED b. IF any S/G PORV cannot be closed, THEN close its isolation valve.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 4 of 4 44 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE 8. (Continued)

f. Verify NC cooldown -STOPPED. 9. Continue to perform the actions of this enclosure as required to ensure one of the following:

NC temperature

-STABLE AT LESS THAN OR EQUAL TO 55rF. OR

NC temperature

-TRENDING TO 55rF. f. RESPONSE NOT OBTAINED IF cooldown continues, THEN throttle feed flow as follows: 1) IF S/G N/R level is less than 11 % (29% ACC) in all S/G's, THEN throttle feed flow to achieve the following:

Minimize cooldown

Maintain total feed flow greater than 450 GPM. 2) WHEN N/R level is greater than 11 % (29% ACC) in at least one S/G, THEN throttle feed flow further to achieve the following:

Minimize cooldown

Maintain at least one S/G N/R level greater than 11 % (29% ACC). 3) IF cooldown continues, THEN close the following valves:

All MSIVs

All MSIV bypass valves. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11 A/5000/E-O -Page 4 of 4 44 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE 8. (Continued)

f. Verify NC cooldown -STOPPED. 9. Continue to perform the actions of this enclosure as required to ensure one of the following:

NC temperature

-STABLE AT LESS THAN OR EQUAL TO 55rF. OR

NC temperature

-TRENDING TO 55rF. f. RESPONSE NOT OBTAINED IF cooldown continues, THEN throttle feed flow as follows: 1) IF S/G N/R level is less than 11 % (29% ACC) in all S/G's, THEN throttle feed flow to achieve the following:

Minimize cooldown

Maintain total feed flow greater than 450 GPM. 2) WHEN N/R level is greater than 11 % (29% ACC) in at least one S/G, THEN throttle feed flow further to achieve the following:

Minimize cooldown

Maintain at least one S/G N/R level greater than 11 % (29% ACC). 3) IF cooldown continues, THEN close the following valves:

All MSIVs

All MSIV bypass valves.

({j;) "" ---CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/N5000/E-3 1 of 110 Rev 34 A. Purpose This procedure provides actions to terminate leakage of reactor coolant into the secondary system following a steam generator tube rupture. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/N5000/E-0 (Reactor Trip Or Safety Injection), Step 25, when condenser air ejector radiation, S/G blowdown radiation or steamline radiation is abnormal.

b. EP/1/N5000/E-0 (Reactor Trip Or Safety Injection), Step 30, EP/1/N5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 5, EP/1/N5000/E-2 (Faulted Steam Generator Isolation), Step 10, EP/1/N5000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 7, and EP/1/N5000/FR-H.3 (Response To Steam Generator High Level), Step 8, when secondary radiation is abnormal.

c. EP/1/N5000/E-0 (Reactor Trip Or Safety Injection), Step 29, EP/1/N5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 4, EP/1/N5000/ES-1.2 (Post LOCA Cooldown And Depressurization), Step 10, EP/1/N5000/ES-3.1 (Post -SGTR Cooldown Using Backfill), Step 6, EP/1/N5000/ES-3.2 (Post -SGTR Cooldown Using Blowdown), Step 6, EP/1/N5000/ES-3.3 (Post -SGTR Cooldown Using Steam Dump), Step 8, EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired), Step 12, and EP/1/N5000/ECA-3.2 (SGTR With Loss Of Reactor Saturated Recovery Desired), Step 6, when a S/G N/R level increases in an uncontrolled manner. d. Any foldout page that has E-3 transition criteria whenever any S/G level increases in an uncontrolled manner or any S/G has abnormal radiation.

rfj;) \, --CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000IE-3 1 of 110 Rev 34 A. Purpose This procedure provides actions to terminate leakage of reactor coolant into the secondary system following a steam generator tube rupture. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection), Step 25, when condenser air ejector radiation, S/G blowdown radiation or steamline radiation is abnormal.

b. EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection), Step 30, EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 5, EP/1/A/5000/E-2 (Faulted Steam Generator Isolation), Step 10, EP/1/A/5000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 7, and EP/1/A/5000/FR-H.3 (Response To Steam Generator High Level), Step 8, when secondary radiation is abnormal.

c. EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection), Step 29, EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 4, EP/1/A/5000/ES-1.2 (Post LOCA Cooldown And Depressurization), Step 10, EP/1/A/5000/ES-3.1 (Post -SGTR Cooldown Using Backfill), Step 6, EP/1/A/5000/ES-3.2 (Post -SGTR Cooldown Using Blowdown), Step 6, EP/1/A/5000/ES-3.3 (Post -SGTR Cooldown Using Steam Dump), Step 8, EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired), Step 12, and EP/1/A/5000/ECA-3.2 (SGTR With Loss Of Reactor Coolant -Saturated Recovery Desired), Step 6, when a S/G N/R level increases in an uncontrolled manner. d. Any foldout page that has E-3 transition criteria whenever any S/G level increases in an uncontrolled manner or any S/G has abnormal radiation.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE c. Operator Actions '------'_

..... ,IffIPII'IJJJ

... ... Jl** .. *BIllllll OR _. RP determines ruptured S/G by frisking the cation columns in the CT lab. OR

1 EMF-27 (Steamline 1 B)

1 EMF-28 (Steamline 1 C)

1 EMF-29 (Steamline 1 D). OR

IF S/G Sampling is required to identify ruptured S/G(s), THEN: a. Ensure the following signals -RESET: _ 1) Phase A Containment Isolations.

_ 2) CA System valve control. _ 3) KC NC NI NM St signals. b. Align all S/Gs for Chemistry sampling.

c. Notify Chemistry to sample all S/Gs for activity.

2 of 110 Rev 34 RESPONSE NOT OBTAINED Perform the following:

a. WHEN ruptured S/G(s) is identified, THEN perform Steps 3 through 9. b. GO TO Step 10. Crew may ask RP to frisk CAT COLUMNS to get confirmation of leak. This takes about 5 minutes. Sampling takes about 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE c. Operator Actions 2.

IRO

UNCONIR.OJ.LED OR _. RP determines ruptured S/G by frisking the cation columns in the CT lab. OR

The foUowi .E,:1::ljf:1

1 i3MP-g6 :(qtearTIline

1 EMP-27 (Steamline 1 B)

1 EMP-28 (Steamline 1 C)

1 EMP-29 (Steamline 1 D). OR

IF S/G Sampling is required to identify ruptured S/G(s), THEN: a. Ensure the following signals -RESET: _ 1) Phase A Containment Isolations.

_ 2) CA System valve control. _ 3) KC NC NI NM St signals. b. Align all S/Gs for Chemistry sampling.

c. Notify Chemistry to sample all S/Gs for activity.

2 of 110 Rev 34 RESPONSE NOT OBTAINED Perform the following:

a. WHEN ruptured S/G(s) is identified, THEN perform Steps 3 through 9. b. GO TO Step 10. Crew may ask RP to frisk CAT COLUMNS to get confirmation of leak. This takes about 5 minutes. Sampling takes about 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/Al5000/E-3 3 of 110 3. 4. EJ ACTION/EXPECTED RESPONSE Rev 34 RESPONSE NOT OBTAINED Maintain one S/G available for NC System cooldown in subsequent steps. The PORV block valve may already have been isolated -2)

If not it will be closed here. CRITICAL TASK! _ 3) IF ruptured S/G(s) PORV isolation valve will not manually close, THEN dispatch operator to close ruptured S/G(s) PORV isolation valve. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3

3. ACTION/EXPECTED RESPONSE VifrifY'!iilleqst'oneiQtacfS1G'.f' POOLDOWN.

The PORV block valve may already have been isolated If not it will be closed here. CRITICAL TASK! 3 of 110 Rev 34 DC:: RESPONSE NOT OBTAINED Maintain one S/G available for NC System cooldown in subsequent steps. _ 1)

_ 2)

fi*Q;>RV::liMlation

_ 3) IF ruptured S/G(s) PORV isolation valve will not manually close, THEN dispatch operator to close ruptured S/G(s) PORV isolation valve.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued) 4 of 110 Rev 34 RESPONSE NOT OBTAINED b. Perform the following:

_ 1) IF both motor driven CA pumps available, THEN close the "CAPT TRIP TN CTRL". _ 2) IF CA Pump #1 is the only source of feedwater, THEN maintain steam flow to the CAPT from at least one S/G. 3) IF S/G 1 B is ruptured, THEN: _ a) Dispatch two operators to unlock and close 1SA-1 (1B S/G Main Steam to CAPT Maintenance Isol) (DH-624, FF-53, Rm 572) (Breakaway lock installed).

_ b) IF 1SA-1 cannot be closed, THEN dispatch two operators to unlock and close 1 SA-3 (1 B S/G Main Steam to CAPT Stop Check) (AB-551, DO-53, Rm 217) (Breakaway lock installed).

4) IF S/G 1C is ruptured, THEN: _ a) Dispatch two operators to unlock and close 1SA-4 (1C S/G Main Steam to CAPT Maintenance Isol) (DH-624, FF-53, Rm 572) (Breakaway lock installed).

_ b) IF 1SA-4 cannot be closed, THEN dispatch two operators to unlock and close 1 SA-6 (1 C S/G Main Steam to CAPT Stop Check) (AB-551, DO-53, Rm 217) (Breakaway lock installed) (Ladder needed). _ 5) WHEN the ruptured S/G steam supply to CA Pump #1 is isolated, THEN open the "CAPT TRIP TN CTRL". CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

b. Verify SIG(s>>)1 B

-JNTACT .. 4 of 110 Rev 34 OCl: RESPONSE NOT OBTAINED b. Perform the following:

_ 1} IF both motor driven CA pumps available, THEN close the "CAPT TRIP TN CTRL". _ 2} IF CA Pump #1 is the only source of feedwater, THEN maintain steam flow to the CAPT from at least one S/G. 3} IF S/G 1 B is ruptured, THEN: _ a} Dispatch two operators to unlock and close 1 SA-1 (1 B S/G Main Steam to CAPT Maintenance Isol) (OH-624, FF-53, Rm 572) (Breakaway lock installed).

_ b} IF 1SA-1 cannot be closed, THEN dispatch two operators to unlock and close 1SA-3 (1 B S/G Main Steam to CAPT Stop Check) (AB-551, Rm 217) (Breakaway lock installed).

4} IF S/G 1 C is ruptured, THEN: _ a} Dispatch two operators to unlock and close 1 SA-4 (1 C S/G Main Steam to CAPT Maintenance Isol) (OH-624, FF-53, Rm 572) (Breakaway lock installed).

_ b} IF 1SA-4 cannot be closed, THEN dispatch two operators to unlock and close 1 SA-6 (1 C S/G Main Steam to CAPT Stop Check) (AB-551, DO-53, Rm 217) (Breakaway lock installed) (Ladder needed). _ 5} WHEN the ruptured S/G steam supply to CA Pump #1 is isolated, THEN open the "CAPT TRIP TN CTRL".

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

EJ c. CRITICAL TASK 5 of 110 Rev 34 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1SM-77A (S/G 1A Otlt Hdr Bldwn CN) (DH-583, FF-GG, 43-44, Rm 591). _ a) Manually close valve. b) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-56A is open, THEN perform the following:

1. Ensure "S/G A BLOWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-148B (S/G 1A Bldwn Cont Isol Byp) (DH-580, EE-FF, 44-45, Rm 591)

1 BB-81 (1A S/G Blowdown Penetration Valve Test Isol) (DH-583, EE-FF, 44, Rm 591). CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

EJ c. I§QJ;ate bloV(d9W n rUP1!J r ed

_ 1 TASK 2)

ED: _

.** _ b C c:****f'fl**** .

_ 1) J 5 of 110 Rev 34 DC!: RESPONSE NOT OBTAINED Dispatch operator to close 1SM-77A (S/G 1A Otlt Hdr Bldwn CN) (DH-583, FF-GG, 43-44, Rm 591 ). _ a) Manually close valve. b) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AN D 1 BB-56A is open, THEN perform the following:

1. Ensure "SfG A BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-148B (SfG 1A Bldwn Cont Isol Byp) (DH-580, EE-FF, 44-45, Rm 591 )

1 BB-81 (1A SfG Blowdown Penetration Valve Test Isol) (DH-583, EE-FF, 44, Rm 591 ).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/11A15000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued) 6 of 110 Rev 34 DeS RESPONSE NOT OBTAINED c) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1BB-56A is open, THEN perform the following:

1. Ensure "S/G A BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1 BB-57B (S/G 1A Bldwn Cont Isol Otsd) (DH-580, EE-FF, 44-45, Rm 591)

1 BB-81 (1A S/G Blowdown Penetration Valve Test Isol) (DH-583, EE-FF, 44, Rm 591). CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/11A15000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

_

qi?:Qt 6 of 110 Rev 34 RESPONSE NOT OBTAINED c) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-56A is open, THEN perform the following:

1. Ensure "S/G A BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1 BB-57B (S/G 1 A Bldwn Cont Isol Otsd) (DH-580, EE-FF, 44-45, Rm 591)

1BB-81 (1A S/G Blowdown Penetration Valve Test Isol) (DH-583, EE-FF, 44, Rm 591).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/ A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

S/G 1B: _ 1) Close 1SM-76B (S/G 1B Otlt Hdr Bldwn CN). 2) Verify the following blowdown isolation valves -CLOSED: _ a) 1BB-19A(S/G 1B Bldwn Cont Isollnsd).

_ b) 1BB-150B (S/G 1B Bldwn Cont Isol Byp). 7 of 110 Rev 34 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1 SM-76B (S/G 1 B Otlt Hdr Bldwn CN) (DH-583, FF-53, Rm 572). _ a) Manually close valve. b) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-19A is open, THEN perform the following:

1. Ensure "S/G B BLOWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1 BB-150B (S/G 1 B Bldwn Cont Isol Byp) (DH-580, FF, 52-53, Rm 572)

1 BB-83 (1 B S/G Blowdown Penetration Valve Test Isol) (DH-580, FF-53, Rm 572). CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1 / A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

S/G 1B: _ 1) Close 1 SM-76B (S/G 1 B Otlt Hdr Bldwn CN). 2) Verify the following blowdown isolation valves -CLOSED: _ a) 1 BB-19A (S/G 1 B Bldwn Cont Isollnsd).

_ b) 1BB-150B (S/G 1B Bldwn Cont Isol Byp). 7 of 110 Rev 34 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1 SM-76B (S/G 1 B Otlt Hdr Bldwn CN) (DH-583, FF-53, Rm 572). _ a) Manually close valve. b) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-19A is open, THEN perform the following:

1. Ensure "S/G B BLOWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1 BB-150B (S/G 1 B Bldwn Cont Isol Byp) (DH-580, FF, 52-53, Rm 572)

1 BB-83 (1 B S/G Blowdown Penetration Valve Test Isol) (DH-580, FF-53, Rm 572).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

_ c) 1 BB-21 B (S/G 1 B Bldwn Cont IsoIOtsd).

8 of 110 Rev 34 RESPONSE NOT OBTAINED c) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1BB-19A is open, THEN perform the following:

1. Ensure "S/G B BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-21B(S/G1B Bldwn Cont Isol Otsd) (DH-580, FF, 52-53, Rm 572)

1 BB-83 (1 B S/G Blowdown Penetration Valve Test 1501) (DH-580, FF-53, Rm 572). CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

_ c) 1 BB-21 B (S/G 1 B Bldwn Cont IsoIOtsd).

8 of 110 Rev 34 RESPONSE NOT OBTAINED c) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-19A is open, THEN perform the following:

1. Ensure "S/G B BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-21B (S/G 1B Bldwn Cont Isol Otsd) (DH-580, FF, 52-53, Rm 572)

1 BB-83 (1 B S/G Blowdown Penetration Valve Test Isol) (DH-580, FF-53, Rm 572).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

S/G 1C: _ 1) Close 1SM-75A (S/G 1C Otlt Hdr Bldwn CN). 2) Verify the following blowdown isolation valves -CLOSED: _ a) 1 BB-60A (S/G 1 C Bldwn Cont Isollnsd).

_ b) 1BB-149B (S/G 1C Bldwn Cont Isol Byp). 9 of 110 Rev 34 RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1SM-75A (S/G 1C Otlt Hdr Bldwn CN) (DH-580, GG, 52-53, Rm 572). _ a) Manually close valve. b) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-60A is open, THEN perform the following:

1. Ensure "S/G C BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-149B (S/G 1C Bldwn Cont Iso I Byp) (DH-578, FF-GG, 52, Rm 572)

1 BB-82 (1 C S/G Blowdown Penetration Valve Test Isol) (DH-583, FF-53, Rm 572). CNS STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

S/G 1C: _ 1) Close 1SM-75A (S/G 1C Otlt Hdr Bldwn CN). 2) Verify the following blowdown isolation valves -CLOSED: _ a) 1 BB-60A (S/G 1 C Bldwn Cont Isollnsd).

_ b) 1BB-149B (S/G 1C Bldwn Cont Isol Byp). 9 of 110 Rev 34 DCS RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1 SM-75A (S/G 1 C Otlt Hdr Bldwn CN) (DH-580, GG, 52-53, Rm 572). _ a) Manually close valve. b) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-60A is open, THEN perform the following:

1. Ensure "S/G C BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-149B (S/G 1C Bldwn Cont Isol Byp) (DH-578, FF-GG, 52, Rm 572) .1BB-82(1CS/G Blowdown Penetration Valve Test Isol) (DH-583, FF-53, Rm 572).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/N5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

_ c) 1BB-61B (S/G 1C Bldwn Cont IsoIOtsd).

10 of 110 Rev 34 RESPONSE NOT OBTAINED c) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-60A is open, THEN perform the following:

1. Ensure "S/G C BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-61B (S/G 1C Bldwn Cont Isol Otsd) (DH-578, FF-GG, 52, Rm 572)

1BB-82 (1C S/G Blowdown Penetration Valve Test Isol) (DH-583, FF-53, Rm 572). CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

_ c} 1BB-61B (S/G 1C Bldwn Cont IsoIOtsd).

10 of 110 Rev 34 RESPONSE NOT OBTAINED c} Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-60A is open, THEN perform the following:

1. Ensure "S/G C BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-61B(S/G1C Bldwn Cont Isol Otsd} (DH-578, FF-GG, 52, Rm 572)

1BB-82 (1C S/G Blowdown Penetration Valve Test Isol) (DH-583, FF-53, Rm 572).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/N5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

S/G 1D: _ 1) Close 1SM-74B (S/G 1D Otlt Hdr Bldwn CN). 2) Verify the following blowdown isolation valves -CLOSED: _ a) 1 BB-8A (S/G 1 D Bldwn Cont Isollnsd).

_ b) 1 BB-147B (S/G 1 D Bldwn Cont Isol Byp). 11 of 110 Rev 34 DC!:: RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1SM-74B (S/G 1D Otlt Hdr Bldwn CN) (DH-583, FF-GG, 44-45, Rm 591 ). _ a) Manually close valve. b) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-8A is open, THEN perform the following:

1. Ensure "S/G D BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-147B (S/G 1D Bldwn Cont Isol Byp) (DH-582, EE-FF, 44, Rm 591)

1 BB-80 (1 D S/G Blowdown Penetration Valve Test Isol) (DH-583,EE-FF, 44, Rm 591). CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/N5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

S/G 10: _ 1) Close 1 SM-74B (S/G 10 Otlt Hdr Bldwn CN). 2) Verify the following blowdown isolation valves -CLOSED: _ a) 1 BB-8A (S/G 10 Bldwn Cont Isollnsd).

_ b) 1 BB-147B (S/G 10 Bldwn Cont Isol Byp). 11 of 110 Rev 34 OCt RESPONSE NOT OBTAINED _ 1) Dispatch operator to close 1 SM-74B (S/G 10 Otlt Hdr Bldwn CN) (DH-583, FF-GG, 44-45, Rm 591 ). _ a) Manually close valve. b) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-8A is open, THEN perform the following:

1. Ensure "S/G 0 BLOWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-147B (S/G 1D Bldwn Cont Isol Byp) (DH-582, EE-FF, 44, Rm 591)

1 BB-80 (1 D S/G Blowdown Penetration Valve Test Isol) (DH-583,EE-FF, 44, Rm 591).

CNS STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

_ c) 1 BB-1 OB (S/G 1 D Bldwn Cont IsoIOtsd).

120f110 Rev 34 RESPONSE NOT OBTAINED c) Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1BB-8A is open, THEN perform the following:

1. Ensure "S/G D BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1 BB-10B (S/G 1 D Bldwn Cont 1501 Otsd) (DH-582, EE-FF, 44, Rm 591) _. 1BB-80 (1D S/G Blowdown Penetration Valve Test 1501) (DH-583,EE-FF, 44, Rm 591). CNS STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 4. (Continued)

_ c} 1BB-10B (S/G 1D Bldwn Cont IsoIOtsd).

12 of 110 Rev 34 RESPONSE NOT OBTAINED c} Perform the following:

_ (1) Manually close valve. (2) IF valve will not close AND 1 BB-8A is open, THEN perform the following:

1. Ensure "S/G D BLDWN FLOW CTRL" -CLOSED. 2. Dispatch operators to ensure the following valves -CLOSED:

1BB-10B(S/G1D Bldwn Cont Isol Otsd} (DH-582, EE-FF, 44, Rm 591)

1 BB-80 (1 D S/G Blowdown Penetration Valve Test Isol} (DH-583,EE-FF, 44, Rm 591).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3

5. ACTION/EXPECTED RESPONSE CLOSING 1SM-7 is a CRITICAL TASK 130f110 Rev 34 RESPONSE NOT OBTAINED Perform the following:

a. Close the following valves on remaining S/Gs:

MSIV =. MSIV bypass valve. b. Place steam dump control in manual and lower controller output to 0%. c. Place "STEAM DUMP SELECT" switch in pressure mode. d. Transfer turbine steam seal supply to AS as follows: _ 1) Open 1TL-8 (Aux Stm To Stm Seal Reg). _ 2) Close 1TL-2 (Main Stm To Stm Seal Reg). e. Ensure the following turbine SN before seat drain valves -CLOSED:

1 SM-41 (Stop Vlv #1 Before Seat Dm)

1 SM-44 (Stop Vlv #2 Before Seat Dm)

1 SM-43 (Stop Vlv #3 Before Seat Dm)

1 SM-42 (Stop Vlv #4 Before Seat Dm). f. Close 1AS-1 (SM To AS Inlet). g. Ensure the following valves -CLOSED:

1 HM-1 (MSRH 1A&1 B SSRH Stm Source)

1HM-2 (MSRH 1C&1D SSRH Stm Source). (RNO continued on next page) CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/N5000/E-3 ACTION/EXPECTED RESPONSE !CLOSING 1SM-7 is a !,..,.n,T'CAL TASK I 13 of 110 Rev 34 RESPONSE NOT OBTAINED Perform the following:

a. Close the following valves on remaining S/Gs:

MSIV _. MSIV bypass valve. b. Place steam dump control in manual and lower controller output to 0%. c. Place "STEAM DUMP SELECT" switch in pressure mode. d. Transfer turbine steam seal supply to AS as follows: _ 1) Open 1TL-8 (Aux Stm To Stm Seal Reg). _ 2) Close 1TL-2 (Main Stm To Stm Seal Reg). e. Ensure the following turbine SN before seat drain valves -CLOSED:

1 SM-41 (Stop Vlv #1 Before Seat Drn)

1 SM-44 (Stop Vlv #2 Before Seat Drn)

1 SM-43 (Stop Vlv #3 Before Seat Drn)

1 SM-42 (Stop Vlv #4 Before Seat Drn). f. Close 1AS-1 (SM To AS Inlet). g. Ensure the following valves -CLOSED:

1 HM-1 (MSRH 1A&1 B SSRH Stm Source)

1HM-2 (MSRH 1C&1D SSRH Stm Source). (RNO continued on next page)

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A1S000/E-3 ACTION/EXPECTED RESPONSE S. (Continued) a._ 140f110 Rev 34 RESPONSE NOT OBTAINED h. Dispatch operator to isolate steam flow from all ruptured S/G(s). REFER TO Enclosure 2 (Locally Isolating Steam Flow From Ruptured S/G(s>>. i. WHEN cool down is initiated in subsequent steps, THEN use intact S/G(s) PORV for steam dump. _ j. IF at least one intact S/G cannot be isolated from all ruptured S/G(s), THEN GO TO EP/1/A1S000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

a. Perform the following:

_ 1) IF any ruptured S/G is also faulted, THEN do not establish feed flow to the ruptured S/G unless needed for NC System cooldown.

2) IF any ruptured S/G(s) is not faulted OR is required for cooldown, THEN: _ a) Establish and maintain feed flow to affected S/G(s). _ b) WHEN affected S/G(s) N/R level greater than 11 % (29% ACC), THEN perform Steps 6.b and 6.c. _ 3) GO TO Step 7. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/SOOO/E-3 ACTION/EXPECTED RESPONSE S. (Continued)

6.

a. Verify S/G(s) NfR;;!¢v$J

,-'

TER)GJjAN11 ACC)., 14of110 Rev 34 DCS RESPONSE NOT OBTAINED h. Dispatch operator to isolate steam flow from all ruptured S/G(s). REFER TO Enclosure 2 (Locally Isolating Steam Flow From Ruptured S/G(s>>. i. WHEN cooldown is initiated in subsequent steps. THEN use intact S/G(s) PORV for steam dump. _ j. IF at least one intact S/G cannot be isolated from all ruptured S/G(s). THEN GO TO EP/1/A/SOOO/ECA-3.1 (SGTR With Loss Of Reactor Subcooled Recovery Desired).

a. Perform the following:

_ 1) IF any ruptured S/G is also faulted. THEN do not establish feed flow to the ruptured S/G unless needed for NC System cooldown.

2) IF any ruptured S/G(s) is not faulted OR is required for cooldown.

THEN: _ a) Establish and maintain feed flow to affected S/G(s). _ b) WHEN affected S/G(s) N/R level greater than 11 % (29% ACC). THEN perform Steps 6.b and 6.c. _ 3) GO TO Step 7.

CNS STEAM GENERATOR TU8E RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 6. (Continued)

_8 CLOSING BOTH THESE VALVES IS CRITICAL _ 2)

S/G 18: _ 1) Close 1 CA-58A (CA Pmp A Disch To S/G 18 Isol). 150f110 Rev 34 RESPONSE NOT OBTAINED 1) Perform the following:

_ a) Close 1CA-60 (CA Pump 1A Flow To S/G 1A). _ b) Dispatch operator with 14" valve wrench to close 1 CA-62A (CA Pmp A Disch To S/G 1A Isol) (DH-587, DD-EE, 44-45, Rm 591). 2) Perform the following:

_ a) Close 1 CA-64 (CA Pump #1 Flow To S/G 1A). _ b) Dispatch operator with 14" valve wrench to close 1CA-668 (CA Pmp 1 Disch To S/G 1A Isol) (DH-584, DD-EE, 44-45, Rm 591) . 1) Perform the following:

_ a) Close 1CA-56 (CA Pump 1A Flow To S/G 18). _ b) Dispatch operator with 14" valve wrench to close 1 CA-58A (CA Pmp A Disch To S/G 18 Isol) (DH-586, DD-EE, 52-53, Rm 572). CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 6. (Continued)

b.

feep ,flQw *10 S;;g3{§)}

asSlfQ'Ui[>ws;;

CLOSING BOTH THESE VALVES IS CRITICAL _ 2) 1GA-6.6B(CAPr;tip1.

...

To S/G ;1.¥\

S/G 1B: _ 1) Close 1 CA-58A (CA Pmp A Disch To S/G 1 B Isol). 15 of 110 Rev 34 RESPONSE NOT OBTAINED 1) Perform the following:

_ a) Close 1 CA-60 (CA Pump 1A Flow To S/G 1A). _ b) Dispatch operator with 14" valve wrench to close 1 CA-62A (CA Pmp A Disch To S/G 1A Isol) (DH-587, DD-EE, 44-45, Rm 591). 2) Perform the following:

_ a) Close 1 CA-64 (CA Pump #1 Flow To S/G 1A). _ b) Dispatch operator with 14" valve wrench to close 1CA-66B (CA Pmp 1 Disch To S/G 1A Isol) (DH-584, DD-EE, 44-45, Rm 591) . 1) Perform the following:

_ a) Close 1CA-56 (CA Pump 1A Flow To S/G 1 B). _ b) Dispatch operator with 14" valve wrench to close 1 CA-58A (CA Pmp A Disch To S/G 1 B Isol) (DH-586, DD-EE, 52-53, Rm 572).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 6. (Continued)

_ 2) Close 1 CA-54B (CA Pmp 1 Disch To S/G 1 B Isol).

S/G 1C: _ 1) Close 1 CA-46B (CA Pmp B Disch To S/G 1 C Isol). _ 2) Close 1 CA-50A (CA Pmp 1 Disch To S/G 1C Isol).

S/G 1D: _ 1) Close 1 CA-42B (CA Pmp B Disch To S/G 1 D Isol). 16 of 110 Rev 34 RESPONSE NOT OBTAINED 2) Perform the following:

_ a) Close 1 CA-52 (CA Pump #1 Flow To S/G 1 B). _ b) Dispatch operator with 14" valve wrench to close 1CA-54B (CA Pmp 1 Disch To S/G 1 B Isol) (DH-584, DD-EE, 52-53, Rm 572) . 1) Perform the following:

_ a) Close 1CA-44 (CA Pump 1B Flow To S/G 1C). _ b) Dispatch operator with 14" valve wrench to close 1 CA-46B (CA Pmp B Disch To S/G 1C Isol) (DH-586, DD, 53-54, Rm 572). 2) Perform the following:

_ a) Close 1 CA-48 (CA Pump #1 Flow To S/G 1C). _ b) Dispatch operator with 14" valve wrench to close 1CA-50A (CA Pmp 1 Disch To S/G 1 C Isol) (DH-584, EE-53, Rm 572) . 1) Perform the following:

_ a) Close 1 CA-40 (CA Pump 1 B Flow To S/G 1 D). _ b) Dispatch operator with 14" valve wrench to close 1 CA-42B (CA Pmp B Disch To S/G 1 D Isol) (DH-586, DD-EE, 43-44, Rm 591). CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 6. (Continued)

_ 2) Close 1 CA-54B (CA Pmp 1 Disch To S/G 1 B Isol).

S/G 1C: _ 1) Close 1 CA-46B (CA Pmp B Disch To S/G 1 C Isol). _ 2) Close 1 CA-50A (CA Pmp 1 Disch To S/G 1C Isol).

S/G 1D: _ 1) Close 1 CA-42B (CA Pmp B Disch To S/G 1 D Isol). 16 of 110 Rev 34 DC:: RESPONSE NOT OBTAINED 2) Perform the following:

_ a) Close 1 CA-52 (CA Pump #1 Flow To S/G 1 B). _ b) Dispatch operator with 14" valve wrench to close 1CA-54B (CA Pmp 1 Disch To S/G 1 B Isol) (DH-584, DD-EE, 52-53, Rm 572) . 1) Perform the following:

_ a) Close 1 CA-44 (CA Pump 1 B Flow To S/G 1 C). _ b) Dispatch operator with 14" valve wrench to close 1 CA-46B (CA Pmp B Disch To S/G 1C Isol) (DH-586, DD, 53-54, Rm 572). 2) Perform the following:

_ a) Close 1 CA-48 (CA Pump #1 Flow To S/G 1 C). _ b) Dispatch operator with 14" valve wrench to close 1CA-50A (CA Pmp 1 Disch To S/G 1C Isol) (DH-584, EE-53, Rm 572) . 1) Perform the following:

_ a) Close 1CA-40 (CA Pump 1B Flow To S/G 1 D). _ b) Dispatch operator with 14" valve wrench to close 1 CA-42B (CA Pmp B Disch To S/G 1 D Isol) (DH-586, DD-EE, 43-44, Rm 591).

BOP CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 6. (Continued)

c. _ 2) Close 1 CA-38A (CA Pmp 1 Disch To S/G 1 D Isol). OR

Pzr PORV. 17 of 110 Rev 34 RESPONSE NOT OBTAINED 2) Perform the following:

_ a) Close 1 CA-36 (CA Pump #1 Flow To S/G 1 D). _ b) Dispatch operator with 14" valve wrench to close 1CA-38A (CA Pmp 1 Disch To S/G 1 D Isol) (DH-584, DD-EE, 43-44, Rm 591). CAUTION NC T -Cold indication in the ruptured loop may cause an invalid Integrity Status Tree condition.

_ Disregard NC T-Cold indication in the ruptured loop, until directed by this EP or until this EP is exited. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 6. (Continued)

IBOP 1 8. _ 2) Close 1 CA-38A (CA Pmp 1 Disch To S/G 1 D Isol). _8.,

EGGS .$t¢'am.

c.r 1955 R$lGli!-I§Illg gbe.bf

_

OR

Pzr PORV. CAUTION 170f110 Rev 34 RESPONSE NOT OBTAINED 2) Perform the following:

_ a) Close 1 CA-36 (CA Pump #1 Flow To S/G 1 D). _ b) Dispatch operator with 14" valve wrench to close 1 CA-38A (CA Pmp 1 Disch To S/G 1 D Isol) (DH-584, DD-EE, 43-44, Rm 591). NC T-Cold indication in the ruptured loop may cause an invalid Integrity Status Tree condition.

_ Disregard NC T-Cold indication in the ruptured loop, until directed by this EP or until this EP is exited.

CNS STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/1/Al5000/E-3 ACTION/EXPECTED RESPONSE

II gIlJar'iDlI_llIl&fIIIIJmI LOWEST RUPTURED S/G PRESSURE (PSIG) EQUAL TO OR GREATER THAN 1200 1 1000 -1099 900 -999 800 -899 700 -799 600 -699 500 -599 400 -499 320 -399 180f110 Rev 34 RESPONSE NOT OBTAINED a. GO TO EP/1/Al5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

CORE EXIT TICs Target temperature could be lower depending on speed going through the procedure and when 1A S/G PORV is isolated. (OF) 532 (512 ACC) 507 (489 ACC) 494 (476 ACC) 479 (461 ACC) 462 (445 ACC) 442 (426 ACC) 420 (405 ACe) 392 (379 ACe) 364 (352 ACC) CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 18 of 110 Rev 34 DC!: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

NC . pu(riRltcipcriteiia.

base<f i 9liHNC subcooling1:qoes

<;i Affel';'lhEmbWlstear'nline'i "ressure mai/'i1steam is6r"tion si hal isblocKed;N'!aln

@"".,Jt ,. ....... .. "'." '. .,.xQ.. . . . . ... ..... .",,,. , , '. .R, ..... , g. " '... ..... ,,' .,

oC'?b!f.if;the high setp9intis exceeded .. b.

eXit from LOWEST RUPTURED S/G PRESSURE (PSIG) EQUAL TO OR GREATER THAN 1200 1'100 gil' 119'9 1000 -1099 900 -999 800 -899 700 -799 600 -699 500 -599 400 -499 320 -399 a. GO TO EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

CORE EX IT TICs Target temperature could be lower depending on speed going through the procedure and when 1A S/G PORV is isolated . (OF) 532 (512 ACC) :520 . ( 50?F:'ACC ) 507 (489 ACC) 494 (476 ACC) 479 (461 ACC) 462 (445 ACC) 442 (426 ACC) 420 (405 ACC) 392 (379 ACC) 364 (352 ACC)

CNS STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 9. (Continued)

c. These valves should already . previously have been closed. 19 of 110 Rev 34 RESPONSE NOT OBTAINED 1) Ensure the following valves on at least one intact S/G -CLOSED:

MSIV

MSIV bypass valve. 2) IF ruptured S/G(s) pressure is less than 1090 PSIG, THEN perform the following:

_ a) Ensure S/G PORV on ruptured S/G(s) -CLOSED OR ISOLATED.

b) IF S/G PORV on ruptured S/G(s) not closed or isolated, THEN: _ (1) Ensure operator dispatched to close ruptured S/G(s) PORV isolation valve. (2) Do not continue until affected S/G PORV(s):

Isolated OR

Determined to be unisolable.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/Al5000/E-3 ACTION/EXPECTED RESPONSE 9. (Continued)

c.

i§plated li§/ to!lo)1s:

1)

'ii MtSI\1

_

These valves should already previously have been closed. 19 of 110 Rev 34 RESPONSE NOT OBTAINED 1) Ensure the following valves on at least one intact S/G -CLOSED:

MSIV

MSIV bypass valve. 2) IF ruptured S/G(s) pressure is less than 1090 PSIG, THEN perform the following:

_ a) Ensure S/G PORV on ruptured S/G(s) -CLOSED OR ISOLATED.

b) IF S/G PORV on ruptured S/G(s) not closed or isolated, THEN: _ (1) Ensure operator dispatched to close ruptured S/G(s) PORV isolation valve. (2) Do not continue until affected S/G PORV(s):

Isolated OR

Determined to be unisolable.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 9. (Continued)

3) IF S/G 1 B OR 1 C ruptured, THEN verify one of the following CAPT steam supply valves -CLOSED: * "CAPT TRIP TN CTRL" OR

Manual isolation valve on the affected S/G.

_ .-...m ..... _ .......

_

l1""'lIl'BimllllllllD

e. f. 20 of 110 Rev 34 RESPONSE NOT OBTAINED 3) Perform the following:

_ a) Ensure operator dispatched to isolate CAPT steam supply from the ruptured S/G. b) Do not continue until affected CAPT steam supply:

Isolated OR

Determined to be unisolable.

d. GO TO Step 9.g RNO. * . ! : _ 3) CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/11 A/SOOO/E-3 ACTION/EXPECTED RESPONSE 9. (Continued)

3) IF S/G 1 B OR 1 C ruptured, THEN verify one of the following CAPT steam supply valves -CLOSED: * "CAPT TRIP TN CTRL" OR

Manual isolation valve on the affected S/G. d.

follpWsy * "C-9 AVAILABI£i:2' FOR SIM DLJMP" status light (1pl-18) -LIT *

e.

I

'M,()pB Iigt1il; (1SI-18)18 lit,lfHEN PlaCe the steClJ11 dump int§rIQck' 20 of 110 Rev 34 DCS RESPONSE NOT OBTAINED 3) Perform the following:

_ a) Ensure operator dispatched to isolate CAPT steam supply from the ruptured S/G. b) Do not continue until affected CAPT steam supply:

Isolated OR

Determined to be unisolable.

d. GO TO Step 9.g RNO. e.

a,s"fbllowS:

_ \1)

_

MIA station outpt.ittEfl:Q1atch

'STM DUMP t _

DLJMBf:

is egllmtothe

/.,j

'la'l)8t1he

\'' .',,' ,}4"h._. __ P ,,_,b'jy .

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 9. (Continued) -g. IF a Main Steam Isolation occurs, the PORVS on intact S/Gs will be used per the RNO. 21 of 110 Rev 34 NOT OBTAINED EJ g. Perform the following:

_ 1) Dump steam from all intact S/G(s) at maximum rate with S/G PORV(-s).

_ 2) IF any intact S/G PORV cannot be opened from the control room, THEN dispatch operator(s) to dump steam at maximum rate from intact S/G(s) PORV. REFER TO Enclosure 3 (Local Operation of S/G PORV-s). 3) IF operator(s) were dispatched to S/G PORV(s), THEN: _ a) Obtain sound powered phone from storage box on rear wall of control room. _ b) Connect sound powered phone to jack on 1 MC-11. _ c) Monitor sound powered phone for communication from the Doghouse{s).

4) IF no intact S/G is available for NC System cooldown, THEN contact station management to determine which of the following to perform:

Use faulted S/G OR

GO TO EP/1/A15000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

_ 5) GO TO Step 9.h. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 9. (Continued)

IDEiff(:1i;Steam1lti ffomintact

_ g. N'", " ,w' ' (;)","" ,',,', '" '""

'kbJle' avgjg, a Isol?tioh;, IF a Main Steam Isolation occurs, the PORVS on intact S/Gs will be used per the RNO. 21 of 110 Rev 34 RESPONSE NOT OBTAINED IRO I g. Perform the following:

_ 1) Dump steam from all intact S/G(s) at maximum rate with S/G PORV(s). _ 2) IF any intact S/G PORV cannot be opened from the control room, THEN dispatch operator(s) to dump steam at maximum rate from intact S/G(s) PORV. REFER TO Enclosure 3 (Local Operation of S/G PORVs). 3) IF operator(s) were dispatched to S/G PORV(s), THEN: _ a) Obtain sound powered phone from storage box on rear wall of control room. _ b) Connect sound powered phone to jack on 1 MC-11. _ c) Monitor sound powered phone for communication from the Doghouse(s).

4) IF no intact S/G is available for NC System cooldown, THEN contact station management to determine which of the following to perform:

Use faulted S/G OR

GO TO EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

_ 5) GO TO Step 9.h.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/Al5000/E-3 ACTION/EXPECTED RESPONSE 9. (Continued)

IBOP I h.

22 of 110 Rev 34 RESPONSE NOT OBTAINED h. Perform the following:

1) Depressurize NC System to less than 1955 PSIG using one of the following:

_. Pzr spray OR

Pzr PORV. 2) WHEN "P-11 PZR S/I BLOCK PERMISSIVE" status light (1SI-18) is lit, THEN: _ a) Depress ECCS steam pressure "BLOCK" push buttons. _ b) Verify main steam isolation blocked status lights LIT. _ 3) Maintain NC pressure less than 1955 PSIG. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 9. (Continued)

h.

i.

22 of 110 Rev 34 DC:: RESPONSE NOT OBTAINED h. Perform the following:

1) Depressurize NC System to less than 1955 PSIG using one of the following:

_. Pzr spray OR

Pzr PORV. 2) WHEN "P-11 PZR SII BLOCK PERMISSIVE" status light (1SI-18) is lit, THEN: _ a) Depress ECCS steam pressure "BLOCK" push buttons. _ b) Verify main steam isolation blocked status lights LIT. _ 3) Maintain NC pressure less than 1955 PSIG.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 10.

__

IBOP I 23 of 110 Rev 34 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Maintain total feed flow greater than 450 GPM to intact S/Gs until at least one intact S/G N/R level greater than 11 % (29% ACC). 2) IF total 'feed flow greater than 450 GPM cannot be established, THEN contact station management for guidance to establish feed flow from one of the following alternate sources:

CF

CM _

Alternate low pressure water source. b. IF N/R level in any intact S/G continues to increase in an uncontrolled manner, THEN: _ 1) Stop NC system cooldown.

_ 2) RETURN TO Step 1. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/N5000/E-3 ACTION/EXPECTED RESPONSE 1 O.

a.

b. '1,OY6ttJ§,

all intaGt:: 8lG between 16% (290/0 ACC)tand50%.;*

23 of 110 Rev 34 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Maintain total feed flow greater than 450 GPM to intact S/Gs until at least one intact S/G N/R level greater than 11 % (29% ACC). 2) IF total feed flow greater than 450 GPM cannot be established, THEN contact station management for guidance to establish feed flow from one of the following alternate sources:

CF

CM

Alternate low pressure water source. b. IF N/R level in any intact S/G continues to increase in an uncontrolled manner, THEN: _ 1) Stop NC system cooldown.

_ 2) RETURN TO Step 1.

CNS STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE b. c. d. __ !:h!!!! 24 of 110 Rev 34 DC!: RESPONSE NOT OBTAINED a. Dispatch operator to restore power to affected Pzr PORV isolation valve(s):

1 EMXD-F02C (PORV Isol Motor (1NC31B)) (AB-560, BB-50, Rm 372)

1 EMXC-F03C (Pressurizer Power Operated Relief Isol. Valve 1 NC33A) (AB-577, BB-50, Rm 496)

1 EMXD-F05A (PORV Isol Motor (1 NC35B)) (AB-560, BB-50, Rm 372). b. IF Pzr pressure is less than 2315 PSIG, THEN: _ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve. _ 3) IF Pzr PORV cannot be closed OR isolated, THEN GO TO EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

c. Open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV. CNS STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE d iI11t![I?

lProp¢Plg:C#!;

_In EN4gJ'jSQre' i'§dlat$.d:

24 of 110 Rev 34 DC!: RESPONSE NOT OBTAINED a. Dispatch operator to restore power to affected Pzr PORV isolation valve(s):

1 EMXD-F02C (PORV Isol Motor (1 NC31 B)) (AB-560, BB-50, Rm 372)

1 EMXC-F03C (Pressurizer Power Operated Relief Isol. Valve 1 NC33A) (AB-577, BB-50, Rm 496)

1 EMXD-F05A (PORV Isol Motor (1 NC35B)) (AB-560, BB-50, Rm 372). b. IF Pzr pressure is less than 2315 PSIG, THEN: _ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve. _ 3) IF Pzr PORV cannot be closed OR isolated, THEN GO TO EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

c. Open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 12. a. b. c. 25 of 110 Rev 34 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ 2) Concurrently implement Enclosure 12 (ECCS Master Reset) while continuing in this procedure.

b. Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372). Perform the following:

a. Align N2 to the Pzr PORVs by opening the following valves:

1 NI-438A (Emer N2 From CLA A To 1 NC-34A)

1 NI-439B (Emer N2 From CLA B To 1 NC-32B). b. IF VI pressure is less than 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 12

a.

iiii

_ *. ' Pt;ta,§EfB:

i BOP I _.*

85 RSle;'i 25 of 110 Rev 34 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ 2) Concurrently implement Enclosure 12 (ECCS Master Reset) while continuing in this procedure.

b. Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372). Perform the following:

a. Align N2 to the Pzr PORVs by opening the following valves:

1 NI-438A (Emer N2 From CLA A To 1 NC-34A)

1 NI-439B (Emer N2 From CLA B To 1 NC-32B). b. IF VI pressure is less than 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/N5000/E-3 ACTION/EXPECTED RESPONSE c. d. e. 26 of 110 Rev 34 RESPONSE NOT OBTAINED a. GO TO Step 15.e. b. GO TO Step 16. c. GO TO Step 16. _ Do not continue in this procedure until ruptured S/G(s) identified.

Crew will hold here until they meet temperature requirements from the Table on page 18. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE pYinps.

_all

.. b.

p'uXtlP(

d.

e. IF.

.* ;!g*§:@

17 ¥. "s ... *.te.'m**'I]!.c.66.iJ

.*. Cl6w. * ... T .* sh6u*IA%he . '.. .y .. .... ,., .. Yc ...... M, d *. * .*.***........ U% *.*

a*%)l$fify . 26 of 110 Rev 34 RESPONSE NOT OBTAINED a. GO TO Step 15.e. b. GO TO Step 16. c. GO TO Step 16. _ Do not continue in this procedure until ruptured SIG(s) identified.

a, :po core e*itT Crew will hold here until they meet temperature requirements from the Table on page 18.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 18.

I 27 of 110 Rev 34 RESPONSE NOT OBTAINED a. Perform the following:

_1) _ 2) Ensure ruptured S/G(s) isolated.

,

i: less than intact S/G{s) used for cooldown, THEN GO TO EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

3) IF AT ANY TIME DIP between ruptured S/G(s) and intact S/G(s) used for cooldown is less than 250 PSIG, THEN:

Maintain total NC System cooldown less than 100°F in an hour

Dump steam from intact S/Gs to maintain intact S/G pressures 250 PSIG below ruptured S/G(s) pressure.

_ 4) IF intact S/G(s) used for cooldown can not be maintained at least 250 PSIG below the pressure of the ruptured S/G(s), THEN GO TO EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

_ 5) GO TO Step 19. _ IF NC subcooling cannot be promptly restored to greater than 20°F, THEN GO TO EP/1/A15000/ECA*3.1 (SGTR With Loss Of Reactor Coolant* Subcooled Recovery Desired).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/N5000/E-3

18. EJ ACTION/EXPECTED RESPONSE 'rl;erify'f:4.Rlure,Q:§t,G'(ll*

operatQr

.'

INQ.REASING, b.

ur&,iTH ENEp'eITorJiijjSte.p:','8.

27 of 110 Rev 34 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) _ 2) Ensure ruptured S/G(s) isolated.

REFER TO Steps 3 through 6. IF ru ..

is less than intact S/G{s) used for cooldown, THEN GO TO EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

3) IF AT ANY TIME DIP between ruptured S/G(s) and intact S/G(s) used for cooldown is less than 250 PSIG, THEN:

Maintain total NC System cooldown less than 100°F in an hour

Dump steam from intact S/Gs to maintain intact S/G pressures 250 PSIG below ruptured S/G(s) pressure.

_ 4) IF intact S/G(s) used for cooldown can not be maintained at least 250 PSIG below the pressure of the ruptured S/G(s), THEN GO TO EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

_ 5) GO TO Step 19. _ IF NC subcooling cannot be promptly restored to greater than 20°F, THEN GO TO EP/1/A15000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 20.

b. c. 28 of 110 Rev 34 RESPONSE NOT OBTAINED a. GO TO Step 21. b. Observe Caution prior to Step 23 and GO TO Step 23. This is a judgement call about going to step 21 based on whether the SRO thinks sprays are "effective" and what he feels is "approaching 83%". CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 20.

_ a)

b.

,.,('7;3 0.)Z .' AC.r)) ... 1 ** :fO .....

qyl;;.tem\With sp@y; ANYtirlME tbe'

_ .* ; :Spray (PRJ 'HtiloJieti S/G{"') N RleveUisi

_ .. P ......................

.§ ...........

.. ....... ****;*:achir(7B3%

,'(82% ACC}.

..........

9""d.......

..... '. '.", _

.* ,j e*Q,g1(liot cpntiriUe u.(;1J1Iat

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G8.l;lKTER

rRAN7!5%

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ANDl .* , .. :,.

r' le'e*f,.tl.'.14(3'*

[;:U;;1\\.-r;;crRF'1i.t,J A N* +tldf OZ c!i!, ' v

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j " .jjJ ...

28 of 110 Rev 34 RESPONSE NOT OBTAINED a. GO TO Step 21. b. Observe Caution prior to Step 23 and GO TO Step 23. This is a judgement call about going to step 21 based on whether the SRO thinks sprays are "effective" and what he feels is "approaching 83%".

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 20. (Continued)

f. 21. Depressurize NC System using Pzr PORV as follows: a. Verify at least one Pzr AVAilABLE.

This step will be used if the crew determines that a PORV will be used to reduce NC pressure in addition to a spray valve. 29 of 110 Rev 34 RESPONSE NOT OBTAINED 1) IF spray valve(s) will not close, THEN: _ a) Stop NC pumps 1Aand 1B. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required.

2) Ensure one of the following valves -CLOSED: _. 1 NV-312A (Chrg Line Cant Isol) OR

1 NV-314B (Chrg Line Cant Isol). a. Establish NV aux spray as follows: _ 1) Ensure at least one NI pump -ON. _ 2) Ensure at least one NV pump -ON. 3) Ensure the following NV pump miniflow valves -OPEN:

1 NV-203A (NV Pumps A&B Recirc Isol)

1 NV-202B (NV Pmps A&B Recirc Isol). 4) Close the following valves: _. 1 NI-9A (NV Pmp C/l Inj Isol) _. 1NI-10B (NV Pmp C/l Inj Isol). (RNO continued on next page) CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 20. (Continued)

_ 2)

21. Depressurize NC System using Pzr PORV as follows: a. Verify at least one Pzr PORV -AVAilABLE.

This step will be used if the crew determines that a PORV will be used to reduce NC pressure in addition to a spray valve. 29 of 110 Rev 34 RESPONSE NOT OBTAINED 1) IF spray valve(s) will not close, THEN: _ a) Stop NC pumps 1Aand 1B. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required.

2) Ensure one of the following valves -CLOSED: _. 1 NV-312A (Chrg Line Cant Isol) OR

1 NV-314B (Chrg Line Cant Isol). a. Establish NV aux spray as follows: _ 1) Ensure at least one NI pump -ON. _ 2) Ensure at least one NV pump -ON. 3) Ensure the following NV pump miniflow valves -OPEN:

1 NV-203A (NV Pumps A&B Recirc Isol)

1 NV-202B (NV Pmps A&B Recirc Isol). 4) Close the following valves: _. 1 NI-9A (NV Pmp C/l Inj Isol) _. 1 NI-1 OB (NV Pmp C/l Inj Isol). (RNO continued on next page)

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1 I A/5000/E-3 ACTION/EXPECTED RESPONSE 21. (Continued)

b. Verify Pzr level -LESS THAN 76% (73% ACC). 30 of 110 Rev 34 RESPONSE NOT OBTAINED _ 5) Manually throttle 1 NV-294 (NV Pmps A&B Disch Flow Ctrl) for 32 GPM charging line flow. _ 6) Manually close 1 NV-309 (Seal Water Injection Flow). 7) Open the following valves:

1 NV-312A(Chrg Line Cont lsol)

1 NV-314B (Chrg Line Cont Isol). _ 8) Place 1 NV-309 in auto. 9) Ensure the following valves -CLOSED: _. 1 NC-27 (pzr Spray Ctrl Frm Loop A)

1 NC-29 (pzr Spray Ctrl Frm Loop B)

1 NV-39A (NV Supply To Loop D Isol)

1 NV-32B (NV Supply To Loop A Isol). _ 10) Maintain charging flow less than 180 GPM. _ 11) Throttle 1 NV-37 A (NV Supply To Pzr Aux Spray) and charging flow as required.

_ 12) RETURN TO Step 20.e. b. Observe Caution prior to Step 23 and GO TO Step 23. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 21. (Continued)

b. Verify Pzr level -LESS THAN 76% (73% ACC). 30 of 110 Rev 34 RESPONSE NOT OBTAINED _ 5) Manually throttle 1 NV-294 (NV Pmps A&B Disch Flow Ctrl) for 32 GPM charging line flow. _ 6) Manually close 1 NV-309 (Seal Water Injection Flow). 7) Open the following valves:

1 NV-312A (Chrg Line Cont lsol)

1 NV-314B (Chrg Line Cont Isol). _ 8) Place 1 NV-309 in auto. 9) Ensure the following valves -CLOSED:

1 NC-27 (pzr Spray Ctrl Frm Loop A)

1 NC-29 (pzr Spray Ctrl Frm Loop B)

1 NV-39A (NV Supply To Loop D Isol)

1 NV-32B (NV Supply To Loop A Isol). _ 10) Maintain charging flow less than 180 GPM. _ 11) Throttle 1 NV-37 A (NV Supply To Pzr Aux Spray) and charging flow as required.

_ 12) RETURN TO Step 20.e. b. Observe Caution prior to Step 23 and GO TO Step 23.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 21. (Continued)

c. Open one Pzr PORV. d. Do not continue until at least one of the following conditions satisfied:

_. NC subcooling based on core exit TICs -LESS THAN OaF OR

Pzr level -GREATER THAN 76% (73% ACC) OR

Both of the following:

_. NC pressure -LESS THAN RUPTURED S/G(s) PRESSURE AND

Pzr level -GREATER THAN 11 % (20% ACC). e. Close Pzr PORV. f. Close Pzr spray valve(s).

310f110 Rev 34 DCS RESPONSE NOT OBTAINED c. Perform the following:

1) Align N2 to the Pzr PORVs by opening the following valves:

1 NI-438A (Emer N2 From CLA A To 1 NC-34A)

1 NI-439B (Emer N2 From CLA B To 1 NC-32B). _ 2) Open one Pzr PORV. e. Close Pzr PORV isolation valve. f. IF spray valve(s) will not close, THEN: _ 1) Stop NC pumps 1Aand 1B. _ 2) IF NC pressure continues to decrease, THEN stop third NC pump as required.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 21. (Continued)

c. Open one Pzr PORV. d. Do not continue until at least one of the following conditions satisfied:

_. NC subcooling based on core exit TICs -LESS THAN OaF OR

Pzr level -GREATER THAN 76% (73% ACC) OR

Both of the following:

_. NC pressure -LESS THAN RUPTURED S/G(s) PRESSURE AND

Pzr level-GREATER THAN 11% (20% ACC). e. Close Pzr PORV. f. Close Pzr spray valve(s).

31 of 110 Rev 34 DC:: RESPONSE NOT OBTAINED c. Perform the following:

1) Align N2 to the Pzr PORVs by opening the following valves:

1 NI-438A (Emer N2 From CLA A To 1 NC-34A)

1 NI-439B (Emer N2 From CLA B To 1 NC-32B). _ 2) Open one Pzr PORV. e. Close Pzr PORV isolation valve. f. IF spray valve{s) will not close, THEN: _ 1) Stop NC pumps 1Aand 1B. _ 2) IF NC pressure continues to decrease, THEN stop third NC pump as required.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/N5000/E-3 ACTION/EXPECTED RESPONSE 22. Verify NC pressure -INCREASING.

32 of 110 Rev 34 RESPONSE NOT OBTAINED Perform the following:

a. Close Pzr PORV isolation valve. b. IF pressure continues to decrease, THEN perform the following:

1) Monitor the following conditions for indication of leakage from the Pzr PORV:

PRT pressure

Pzr Relief Valve Temp. _ 2) GO TO EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

b. c. d. a. GO TO EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

b. GO TO EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

c. GO TO EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

d. RETURN TO Step 7. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/SOOO/E-3 ACTION/EXPECTED RESPONSE 22. Verify NC pressure -INCREASING.

b.

$J.bk as JdUows: _.

_

d.

rr:WAN . 11;9& 32 of 110 Rev 34 RESPONSE NOT OBTAINED Perform the following:

a. Close Pzr PORV isolation valve. b. IF pressure continues to decrease, THEN perform the following:

1) Monitor the following conditions for indication of leakage from the Pzr PORV:

PRT pressure

Pzr Relief Valve Temp. _ 2) GO TO EP/1/A/SOOO/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

a. GO TO EP/1/A/SOOO/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

b. GO TO EP/1/A/SOOO/ECA-3.1 (SGTR With Loss Of Reactor Subcooled Recovery Desired).

c. GO TO EP/1/A/SOOO/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

d. RETURN TO Step 7.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 33 of 110 Rev 34 DeE RESPONSE NOT OBTAINED a. Perform the following:

1) IF NI Pump 1A failed to trip, THEN perform the following:

a) Ensure the following OPEN:

1 NI-115A (NI Pump 1A Miniflow 1501)

1 NI-147B (NI Pump Miniflow Hdr To FWST 1501). b) WHEN miniflow path aligned, THEN ensure the following valves -CLOSED:

1NI-121A(NI Pump 1A To H-Legs B&C)

1NI-118A(NI Pump 1AC-Leg Inj Isol). _ c) Dispatch operator to locally trip 1ETA#11 (1A NI Pump Motor) (AB-577, AA-49, Rm 496). (RNO continued on next page) CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE

a.

33 of 110 Rev 34 RESPONSE NOT OBTAINED a. Perform the following:

1) IF NI Pump 1A failed to trip, THEN perform the following:

a) Ensure the following valves -OPEN:

1 NI-115A (NI Pump 1A Miniflow Isol)

1 NI-147B (NI Pump Miniflow Hdr To FWST Isol). b) WHEN miniflow path aligned, THEN ensure the following valves -CLOSED:

1 NI-121A (NI Pump 1A To H-Legs B&C)

1 NI-118A (NI Pump 1A C-Leg Inj Isol). _ c) Dispatch operator to locally trip 1 ETA#11 (1A NI Pump Motor) (AB-577, AA-49, Rm 496). (RNO continued on next page)

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/11A15000/E-3 ACTION/EXPECTED RESPONSE 24. (Continued)

b. 34 of 110 Rev 34 DCS RESPONSE NOT OBTAINED 2) IF NI Pump 1 B failed to trip, THEN perform the following:

a) Ensure the following valves -OPEN:

1NI-144A(NI Pump 1B Miniflow Isol)

1 NI-147B (NI Pump Miniflow Hdr To FWST Isol). b) WHEN miniflow path aligned, THEN ensure the following valves -CLOSED:

1 NI-150B (NI Pump 1 B C-Leg Inj Isol)

1 NI-152B (NI Pump 1 B To H-Legs A&D). _ c) Dispatch operator to locally trip 1 ETB#11 (1 B NI Pump Motor) (AB-560, AA-49, Rm 372). CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 24. (Continued) 340f110 Rev 34 RESPONSE NOT OBTAINED 2) IF NI Pump 1 B failed to trip, THEN perform the following:

a) Ensure the following valves -OPEN:

1NI-144A (NI Pump 1B Miniflow 1501)

1 NI-147B (NI Pump Miniflow Hdr To FWST Isol). b) WHEN miniflow path aligned, THEN ensure the following valves -CLOSED:

1 NI-150B (NI Pump 1 B C-Leg Inj 1501)

1 NI-152B (NI Pump 1 B To H-Legs A&D). _ c) Dispatch operator to locally trip 1 ETB#11 (1 B NI Pump Motor) (AB-560, AA-49, Rm 372).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 ACTION/EXPECTED RESPONSE 35 of 110 Rev 34 DCE RESPONSE NOT OBTAINED a. IF NV pump suctions are aligned for Cold Leg Recirc, THEN perform the following:

_ 1} GO TO Enclosure 10 (Establish Charging With NV Miniflow Isolated).

_ 2} GO TO Step 27. b. Perform the following:

1} Dispatch operator to open affected valve(s}:

1 NV-203A (NV Pumps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed)

1 NV-202B (NV Pmps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed). _ 2} GO TO Enclosure 10 (Establish Charging With NV Miniflow Isolated).

_ 3} WHEN 1 NV-203A AND 1 NV-202B are opened, THEN charging flow may be reduced below 60 GPM. _ 4} GO TO Step 27. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 25.

IBOP I a. -OR-EN:

R;W$T) 15<51]\ 1 N* w)'2' '02'BSlMYT.'P*'T'*W"'Pl\o"swR" *'*c':* "'. * . ..*,¥ ....

,"

35 of 110 Rev 34 RESPONSE NOT OBTAINED a. IF NV pump suctions are aligned for Cold Leg Recirc, THEN perform the following:

_ 1) GO TO Enclosure 10 (Establish Charging With NV Miniflow Isolated).

_ 2) GO TO Step 27. b. Perform the following:

1) Dispatch operator to open affected valve(s):

1 NV-203A (NV Pumps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed)

1 NV-202B (NV Pmps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed). _ 2) GO TO Enclosure 10 (Establish Charging With NV Miniflow Isolated).

_ 3) WHEN 1 NV-203A AND 1 NV-202B are opened, THEN charging flow may be reduced below 60 GPM. _ 4) GO TO Step 27.

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 25. (Continued)

IBOP I c. SCENARIO MAY BE TERMINATED HERER 36 of 110 Rev 34 RESPONSE NOT OBTAINED c. Perform the following:

1) Dispatch operator to close the affected valve(s).

REFER TO the following enclosure(s) for the affected valve(s):

Enclosure 13 (Locally Close 1 Nl-9A)

Enclosure 15 (Locally Close 1 NI-10B). 2) IF NC pump seal cooling is established from KC flow to thermal barrier, THEN perform the following:

_ a) Ensure all NC pumps -OFF. _ b) Stop NV Pumps. _ c) WHEN 1 NI-9A AND 1NI-10B are closed, THEN restore NV pump to service. REFER TO Enclosure 9 (NV Pump Restart).

d) Ensure the following valves -OPEN:

1 NI-115A (NI Pump 1A Miniflow Isol)

1NI-144A(NI Pump 1B Miniflow Isol)

1 NI-147B (NI Pump Miniflow Hdr To FWST Isol). (RNO continued on next page) CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 ACTION/EXPECTED RESPONSE 25. (Continued)

SCENARIO MAY BE TERMINATED HERER 36 of 110 Rev 34 RESPONSE NOT OBTAINED c. Perform the following:

1) Dispatch operator to close the affected valve(s).

REFER TO the following enclosure(s) for the affected valve(s):

Enclosure 13 (Locally Close 1 Nl-9A)

Enclosure 15 (Locally Close 1 NI-1 OB). 2) IF NC pump seal cooling is established from KC flow to thermal barrier, THEN perform the following:

_ a) Ensure all NC pumps -OFF. _ b) Stop NV Pumps. _ c) WHEN 1NI-9AAND 1NI-10B are closed, THEN restore NV pump to service. REFER TO Enclosure 9 (NV Pump Restart).

d) Ensure the following valves -OPEN:

1 NI-115A (NI Pump 1A Miniflow Isol)

1 NI-144A (NI Pump 1 B Miniflow Isol)

1 NI-147B (NI Pump Miniflow Hdr To FWST Isol). (RNO continued on next page)

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/SOOO/E-3 -Page 1 of 2 62 of 110 Foldout Page Rev 34 1. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NV or NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO OaF. 2. Position Criteria for 1 NV-202B and 1 NV-203A (NV Pumps A&B Recirc 1501):

IF NC pressure is less than 1S00 PSIG AND NV S/I flowpath is aligned, THEN close 1 NV-202B and 1 NV-203A.

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-202B and 1 NV-203A. 3. 5/1 Reinitiation Criteria:

IF NC subcooling based on core exit TICs is less than OaF OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN: a. Manually start S/I pumps and align valves as necessary to restore subcooling and Pzr level. b. IF S/I reinitiation occurs after Section C. (Operator Actions), Step 24, THEN GO TO EP/1/A/SOOO/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

4. Secondary Integrity Criteria:

IF pressure in any unisolated S/G is decreasing in an uncontrolled manner OR any unisolated S/G has completely depressurized, THEN GO TO EP/1/A/SOOO/E-2 (Faulted Steam Generator Isolation) unless needed for NC System cooldown.

S. Cold Leg Recirc Switchover Criterion:

IF FWST level decreases to 37% (1AD-9, 0/8 "FWST 2/4 LO LEVEL" lit), THEN GO TO EP/1/A/SOOO/ES-1.3 (Transfer To Cold Leg Recirculation).

CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/SOOO/E-3 -Page 1 of 2 62 of 110 Foldout Page Rev 34 1. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NV or NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO OaF. 2. Position Criteria for 1 NV-202B and 1 NV-203A (NV Pumps A&B Recirc Isol):

IF NC pressure is less than 1S00 PSIG AND NV S/I flowpath is aligned, THEN close 1 NV-202B and 1 NV-203A.

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-202B and 1 NV-203A. 3. S/I Reinitiation Criteria:

IF NC subcooling based on core exit TICs is less than OaF OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN: a. Manually start S/I pumps and align valves as necessary to restore subcooling and Pzr level. b. IF S/I reinitiation occurs after Section C. (Operator Actions), Step 24, THEN GO TO EP/1/A/SOOO/ECA-3.1 (SGTR With Loss Of Reactor Coolant -Subcooled Recovery Desired).

4. Secondary Integrity Criteria:

IF pressure in any unisolated S/G is decreasing in an uncontrolled manner OR any unisolated S/G has completely depressurized, THEN GO TO EP/1/A/SOOO/E-2 (Faulted Steam Generator Isolation) unless needed for NC System cooldown.

S. Cold Leg Recirc Switchover Criterion:

IF FWST level decreases to 37% (1AD-9, 0/8 "FWST 2/4 LO LEVEL" lit), THEN GO TO EP/1/A/SOOO/ES-1.3 (Transfer To Cold Leg Recirculation).

CNS STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/11A15000/E-3 -Page 2 of 2 63 of 110 Foldout Page Rev 34 6. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO API1/A15500/006 (Loss of S/G Feedwater):

_. 1AD-5, H/4 "CACST LO LEVEL" OR _. 1AD-8, B/1 "UST LO LEVEL". 7. Multiple Tube Rupture Criteria:

IF level in any intact S/G increases in an uncontrolled manner OR any intact S/G indicates abnormal radiation, THEN: a. Stop any operator controlled cooldown and depressurization in progress.

b. RETURN TO EP/11A15000/E-3 (Steam Generator Tube Rupture), Step 1. CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 -Page 2 of 2 63 of 110 Foldout Page Rev 34 DC:: 6. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO AP/1/A/5500/006 (Loss of S/G Feedwater):

1AD-5, H/4 "CACST LO LEVEL" OR

1AD-8, B/1 "UST LO LEVEL". 7. Multiple Tube Rupture Criteria:

IF level in any intact S/G increases in an uncontrolled manner OR any intact S/G indicates abnormal radiation, THEN: a. Stop any operator controlled cooldown and depressurization in progress.

b. RETURN TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture), Step 1.

Appendix 0 Scenario Outline Form ES-D-1 2009 NRC EXAMINATION Facility:

Catawba Nuclear Station Scenario No.: 3 Op-Test No.: 20090-1 --SNAP 143 Examiners:

Operators:

Initial Conditions:

75% power

EFPD = 450 days

Boron Concentration is 208 ppm Turnover:

1 A D/G was placed in Maintenance Mode and red tagged 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago for PMs and is expected back in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

1 CFP5600 (10 S/G Narrow Range Level Ch #2) failed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago. IAE repairs are in progress and estimated to take 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . All TSAIL entries have been made.

Increase power to 100% at 5% an hour per OP/1/Al61 00/003 (Controlling Procedure for Unit Operation), Enclosure 4.1, Power Increase.

Event Malf. No. Event Event No. Type* Description 1 BOP N Dilute for power increase (DCS) 2 RO R Increase power to 100% 3 BOP I P/R N44A failure SRO TS 4 RO C Loss of 1A CF pump/ no auto rod motion 5 BOP C PORV open does not fully reclose, can be blocked SRO TS 6 RO C 1 CF-55 (0 CF Reg Valve) auto control fails/manual control available SRO TS 7 ALL M Large Break LOCAl Loss of emergency coolant recirculation Additional Failures Auto S/I train A & B fails to auto actuate 1NI-184B fails closed 1 A essential train loss of power *(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Scenario Outline Form ES-D-1 2009 NRC EXAMINATION Facility:

Catawba Nuclear Station Scenario No.: 3 Op-Test No.: 2009 D-1 --SNAP 143 Examiners:

Operators:

Initial Conditions:

75% power

EFPD = 450 days

Boron Concentration is 208 ppm Turnover:

1 A D/G was placed in Maintenance Mode and red tagged 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago for PMs and is expected back in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

1 CFP5600 (1 D S/G Narrow Range Level Ch #2) failed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago. IAE repairs are in progress and estimated to take 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . All TSAIL entries have been made.

Increase power to 100% at 5% an hour per OP/1/Al61 00/003 (Controlling Procedure for Unit Operation), Enclosure 4.1, Power Increase.

Event Malf. No. Event Event No. Type* Description 1 BOP N Dilute for power increase (DCS) 2 RO R Increase power to 100% 3 BOP I P/R N44A failure SRO TS 4 RO C Loss of 1A CF pump/ no auto rod motion 5 BOP C PORV open does not fully reclose, can be blocked SRO TS 6 RO C 1 CF-55 (D CF Reg Valve) auto control fails/manual control available SRO TS 7 ALL M Large Break LOCAl Loss of emergency coolant recirculation Additional Failures Auto S/I train A & B fails to auto actuate 1 N 1-184B fails closed 1 A essential train loss of power *(N)ormal, (R)eactivity, (I)nstrument, (C)om ponent, (M)ajor SIMULATOR SETUP Reset to a 75% power EOL snap Roll Charts Provide a boration/dilution plan Clear EHC alarm and any OACI 1.47 bypass alarms Sign off OP/1/A/61 001003 enclosure 4.1 thru step 2.52 (students start at 2.53) MALFUNCTIONS.

REMOTES. and OVERRIDES Malfunction

Description Value Event Trigger LOA-CNT002 H2 ANALYZERS BOTH 24 MAL-ENB011G P/R DETECTOR 44A FAILURE 100 3 MAL-EQB003A LOSS OF DIG 1 A SEQUENCER 21 CTRLPWR MAL-IRX009 RODS FAIL TO MOVE AUTO 4 MAL-ISE002A AUTO SI TRN A FAILS TO ACTUATE MAL-ISE002B AUTO SI TRN B FAILS TO ACTUATE MAL-NC013C NC COLD LEG C LEAK 27.5 8 MAL-OV0691 B NCDJ5167 NC-34A DEMAND ALARM 5 OPEN fail to NORMAUALARM MAL-SLlM22_04 1 CFSS5060:

CF55 FCV 0 Raise Button 6 Output Pushbutton fail to position Depressed OVR-DG015B DIG 1 B MAINT MODE PB (11/378) ON INITIATE PB OVR-DG047

DG-PNL* MAINTENANCE MODE ON PB BLACK PB OVR-DG048A

DG-PNL* MODE SEL 2 POS ON LOCKOUT RELAY SW TRIP POS OVR-EP029D ETA NORM FOR FRM ATC TRIP ON 9 PB OVR-FWP012C CFPT 1A TRIP & RESET TRIP PB ON 4 OVR-FWP015C CFPT 1 B TRIP & RESET TRIP PB ON 7 VLV-NC006C NC33A PZR PORV ISOL VLV 23 FAILPWR VLV-NC007F NC34A PZR PORV FAIL TO 0.25 12 POSITION VLV-NC007F NC34A PZR PORV FAIL TO 1 5 POSITION VLV-NI037F NI184B CNMT SUMP LINE 1B 0 ISOL (STEM) FAIL TO POSITION VLV-NI037F NI184B CNMT SUMP LINE 1B 1 22 ISOL (STEM) FAIL TO POSITION XMT-SG013 LCF _5580 S/G 10 N/R LVL CH4 100 6 TO DCS/MCB/OAC (CFAA5580)

XMT-SG016 LCF _5600 S/G 10 N/R LVL CH2 0 TO DCS/MCB/OAC (CFAA5600)

Ramp Delay 600 300 1 Del in 6 10 300 1 1 300 300 SIMULATOR SETUP Reset to a 75% power EOL snap Roll Charts Provide a borationldilution plan Clear EHC alarm and any OACI 1.47 bypass alarms Sign off OP/1/A/61 001003 enclosure 4.1 thru step 2.52 (students start at 2.53) MALFUNCTIONS.

REMOTES. and OVERRIDES Malfunction

Description Value Event Trigger LOA-CNT002 H2 ANALYZERS BOTH 24 MAL -ENB011 G P/R DETECTOR 44A FAILURE 100 3 MAL-EQB003A LOSS OF DIG 1A SEQUENCER 21 CTRL PWR MAL-IRX009 RODS FAIL TO MOVE AUTO 4 MAL-ISE002A AUTO SI TRN A FAILS TO ACTUATE MAL -ISE002B AUTO SI TRN B FAILS TO ACTUATE MAL-NC013C NC COLD LEG C LEAK 27.5 8 MAL-OV0691 B NCDJ5167 NC-34A DEMAND ALARM 5 OPEN fail to NORMAUALARM MAL-SLlM22_04 1 CFSS5060:

CF55 FCV D Raise Button 6 Output Pushbutton fail to position Depressed OVR-DG015B DIG 1 B MAINT MODE PB (11/378) ON INITIATE PB OVR-DG047

DG-PNL

MAINTENANCE MODE ON PB BLACK PB OVR-DG048A

DG-PNL

MODE SEL 2 POS ON LOCKOUT RELAY SW TRIP POS OVR-EP029D ETA NORM FDR FRM ATC TRIP ON 9 PB OVR-FWP012C CFPT 1A TRIP & RESET TRIP PB ON 4 OVR-FWP015C CFPT 1 B TRIP & RESET TRIP PB ON 7 VLV-NC006C NC33A PZR PORV ISOL VLV 23 FAILPWR VLV-NC007F NC34A PZR PORV FAIL TO 0.25 12 POSITION VLV-NC007F NC34A PZR PORV FAIL TO 1 5 POSITION VLV-NI037F NI184B CNMT SUMP LINE 1B 0 ISOL (STEM) FAIL TO POSITION VLV-NI037F NI184B CNMT SUMP LINE 1B 1 22 ISOL (STEM) FAIL TO POSITION XMT-SG013 LCF _5580 S/G 1 D N/R LVL CH4 100 6 TO DCS/MCB/OAC (CFAA5580)

XMT-SG016 LCF _5600 S/G 1 D N/R LVL CH2 0 TO DCS/MCB/OAC (CFAA5600)

Ramp Delay 600 300 1 Del in 6 10 300 1 1 300 300 EVENT TRIGGERS (other than manual) Event Description Trigger 8 Reactor trip either train [ jpplp4(1)

I jpplp4(2)

] 9 x11 i357F (TRUE when 1 B NO pump is secured) 12 X1 Oi1 03c (TRUE when 1 NC-34A is taken to the close position)

CRITICAL TASKS (See attached documentation)

E-O 0 -Manually actuate at least one train of SIS-actuated safeguards before any of the following:

Transition to any E-1 series, E-2 series, or E-3 series procedure or transition to any FRG

Completion of Step 5.a of ES-0.1 ES-1.3 A -Transfer to cold leg recirculation and establish ECCS recirculation flow that at least meets the assumptions of plant specific LOCA analyses.*

Per Technical Specification

3.5.2 basis

background section: The EGGS consists of three separate subsystems:

centrifugal charging (high head), safety injection (SI) (intermediate head), and residual heat removal (RHR) (low head). Each subsystem consists of two redundant, 100% capacity trains. The EGGS accumulators and the RWST are also part of the EGGS, but are not considered part of an EGGS flow path as described by this LGO. The EGGS flow paths consist of piping, valves, heat exchangers, and pumps such that water from the RWST can be injected into the RGS following the accidents described in this LGO. The major components of each subsystem are the centrifugal charging pumps, the RHR pumps, heat exchangers, and the SI pumps. Each of the three subsystems consists of two 100% capacity trains that are interconnected and redundant such that either train is capable of supplying 100% of the flow required to mitigate the accident consequences.

This interconnecting and redundant subsystem design provides the operators with the ability to utilize components from opposite trains to achieve the required 100% flow to the core. Critical steps are denoted on the Instructor guide. QUALITATIVE ATTRIBUTES Required Actual Total malfunctions 5-8 8 Malfunctions after EOP entry 1 -2 3 Abnormal events 2-4 4 Major transients 1 -2 1 EOPs entered/requirinQ substantive actions 1 -2 2 EOP continQencies reQuirinQ substantive actions 0-2 1 Critical tasks 2-3 2 EVENT TRIGGERS (other than manual) Event Description TriQQer 8 Reactor trip either train [ jpplp4(1)

I jpplp4(2)

] 9 x11 i357F (TRUE when 1 B NO pump is secured) 12 X1 Oi1 03c (TRUE when 1 NC-34A is taken to the close position)

CRITICAL TASKS (See attached documentation)

E-O 0 -Manually actuate at least one train of SIS-actuated safeguards before any of the following:

Transition to any E-1 series, E-2 series, or E-3 series procedure or transition to any FRG

Completion of Step 5.a of ES-0.1 ES-1.3 A -Transfer to cold leg recirculation and establish ECCS recirculation flow that at least meets the assumptions of plant specific LOCA analyses.* "Per Technical Specification

3.5.2 basis

background section: The EGGS consists of three separate subsystems:

centrifugal charging (high head), safety injection (SI) (intermediate head), and residual heat removal (RHR) (low head). Each subsystem consists of two redundant, 100% capacity trains. The EGGS accumulators and the RWST are also part of the EGGS, but are not considered part of an EGGS flow path as described by this LGO. The EGGS flow paths consist of piping, valves, heat exchangers, and pumps such that water from the RWST can be injected into the RGS following the accidents described in this LGO. The major components of each subsystem are the centrifugal charging pumps, the RHR pumps, heat exchangers, and the SI pumps. Each of the three subsystems consists of two 100% capacity trains that are interconnected and redundant such that either train is capable of supplying 100% of the flow required to mitigate the accident consequences.

This interconnecting and redundant subsystem design provides the operators with the ability to utilize components from oppOSite trains to achieve the required 100% flow to the core. Critical steps are denoted on the Instructor guide. QUALITATIVE ATTRIBUTES Re_quired Actual Total malfunctions 5-8 8 Malfunctions after EOP entry 1 -2 3 Abnormal events 2-4 4 Major transients 1 -2 1 EOPs entered/requiring substantive actions 1 -2 2 EOP contingencies requiring substantive actions 0-2 1 Critical tasks 2-3 2 REFERENCES OP/1/A/61501009 (Boron Concentration Control) revision 068DCS OP/1/A/61 001003 (Controlling Procedure for Unit Operation), Enclosure

4.1 revision

106DCS OP/1/B/63001001 (Turbine Generator) revision 091 AP/1/A/55001016 (Malfunction of Nuclear Instrumentation System) revision 023 AP/1/A/55001011 (Pressurizer Pressure Anomalies) revision 022DCS AP/1/A/55001003 (Load Rejection) revision 036 EP/1/A/5000/E-0 (Reactor Trip or Safety Injection) revision 036DCS EP/1/A/5000/E-1 (Loss of Reactor or Secondary Coolant) revision 023 EP/1/A/5000/ES-1.3 (Transfer to Cold Leg Recirculation) revision 021 EP/1/A/5000/ECA-1.1 (Loss of Emergency Coolant Recirculation) revision 31 DCS OTHER NOTES AND INSTRUCTIONS NOTE: The following steps are GUIDELINES.

The NRC lead examiner will direct timing of events unless otherwise noted. NOTE: Any groups or Individuals (IAE, RxGrp, RP, SOC, SWM) that are called to IIR a problem or for simple notification of a problem, repeat back the Information they provide unless otherwise noted. NOTE: Any operators dispatched should repeat back Information provided.

Call back Items are listed below when necessary for the scenario.

Event 1 -Dilute for power Increase This event will be entered once the crew has taken turnover and evaluated plant conditions.

When the first dilution batch has been completed, the next event can be started. Event 2 -Increase power to 100% This event will be entered once the crew has taken turnover and evaluated plant conditions.

When turbine power has increased by 3-5 MW, the next event can be started. Event 3 -P/R N44A failure. SRO Technical Specification Initiating Cues:

1 AD-2, A/3, A/8, B/8, C/8 Et8 and others When SPOC is notified to place OTDT IOPDT channel in trip per Step 5, reply: "Place Channel 4 of OPDT and OTDT In trip condition per Model W/O 00874531." When AP/1/A/55001016 is completed, and the SRO has completed consulting Technical Specifications, the next event can be inserted.

TS -3.3.1 Items 2a, 2b, 3, 6, 7, 16b, 16c, 16d, 16e Conditions D, E, R, S REFERENCES OP/1/A/6150/009 (Boron Concentration Control) revision 068DCS OP/1/A/61 00/003 (Controlling Procedure for Unit Operation), Enclosure

4.1 revision

106DCS OP/1/B/6300/001 (Turbine Generator) revision 091 AP/1/A/5500/016 (Malfunction of Nuclear Instrumentation System) revision 023 AP/1/A/5500/011 (Pressurizer Pressure Anomalies) revision 022DCS AP/1/A/5500/003 (Load Rejection) revision 036 EP/1/A/5000/E-0 (Reactor Trip or Safety Injection) revision 036DCS EP/1/A/5000/E-1 (Loss of Reactor or Secondary Coolant) revision 023 EP/1/A/5000/ES-1.3 (Transfer to Cold Leg Recirculation) revision 021 EP/1/A/5000/ECA-1.1 (Loss of Emergency Coolant Recirculation) revision 31 DCS OTHER NOTES AND INSTRUCTIONS NOTE: The following steps are GUIDELINES.

The NRC lead examiner will direct timing of events unless otherwise noted. NOTE: Any groups or Individuals (IAE, RxGrp, RP, SOC, SWM) that are called to IIR a problem or for simple notification of a problem, repeat back the Information they provide unless otherwise noted. NOTE: Any operators dispatched should repeat back Information provided.

Call back Items are listed below when necessary for the scenario.

Event 1 -Dilute for power Increase This event will be entered once the crew has taken turnover and evaluated plant conditions.

When the first dilution batch has been completed, the next event can be started. Event 2 -Increase power to 100% This event will be entered once the crew has taken turnover and evaluated plant conditions.

When turbine power has increased by 3-5 MW, the next event can be started. Event 3 -P/R N44A failure. SRO Technical Specification Initiating Cues:

1 AD-2, A/3, A/8, B/8, C/8 El8 and others When SPOC is notified to place OTDT/OPDT channel in trip per Step 5, reply: "Place Channel 4 of OPDT and OTDT In trip condition per Model W/O 00874531." When AP/1/A/5500/016 is completed, and the SRO has completed consulting Technical Specifications, the next event can be inserted.

TS -3.3.1 Items 2a, 2b, 3, 6, 7, 16b, 16c, 16d, 16e Conditions D, E, R, S Event 4 -Loss of 1 A CF pumpl no auto rod motion Initiating Cues:

1 AD-5, A/1, A/4

1AD-1,F/4 When AP/1/A/55001003 is completed, the next event can be inserted.

TS -3.1.6 Condition A (IF Control Rods are at Lo-Lo insertion limit) Event 5 -PORV open does not fully reclose. can be blocked. SRO Technical Specification Initiating Cue:

1 AD-6 C/12, El10, F-8 When AP/1/A/55001011 is complete and the SRO has completed consulting Technical Specifications, the next event can be inserted.

If an operator is dispatched to remove power from 1 NC-33A, Insert EVENT 23. When EVENT 23 Is activated, state "Power has been removed from 1 NC-33A". TS -3.4.11 Condition B TS -3.4.1 Condition A (based on NC pressure at the time) Event 6 -1 CF-55 (D CF Reg Valve) auto control falls/manual control available Initiating Cues:

1AD-4 D/4, 1AD-2 F/9 When 1 D S/G level has been stabilized in manual and the SRO has completed consulting Technical Specifications, the next event can be inserted.

This will begin the major event. TS -3.3.1 Item 13 Condition E TS -3.3.2 Item 5.a.(2) Condition J, Item S.b.(2) Condition D, Item 6.b Condition D TS -3.0.3 (due to two channels OOS) TS -3.3.3 Item 10 Condition B Event 7 -Large Break LOCAl Loss of emergency coolant recirculation When the second feed pump is tripped, the T/G will trip on AMSAC, but because they reactor is <69% power, it will not trip automatically.

The crew will manually trip the reactor based on the immediate actions of AP/06 (trip when >5% power and loss of all feedwater)

This begins the major event. NOTE: Depending on student reading speed, they could enter EP/1/A15000/ES-1.3 without ever going to EP/1/A15000/E-1.

Additional failures

Auto S/I train A & B fails to auto actuate

1 NI-184B fails closed

1 A essential train loss of power Event 4 -Loss of 1 A CF pumpl no auto rod motion Initiating Cues:

1 AD-5, Al1, Al4

1AD-1,F/4 When AP/11A155001003 is completed, the next event can be inserted.

TS -3.1.6 Condition A (IF Control Rods are at Lo-Lo insertion limit) Event 5 -PORV open does not fully reclose. can be blocked. SRO Technical Specification Initiating Cue:

1 AD-6 C/12, El10, F-8 When AP/11A155001011 is complete and the SRO has completed consulting Technical Specifications, the next event can be inserted.

If an operator is dispatched to remove power from 1 NC-33A, Insert EVENT 23. When EVENT 23 Is activated, state "Power has been removed from 1 NC-33A". TS -3.4.11 Condition B TS -3.4.1 Condition A (based on NC pressure at the time) Event 6 -1 CF-55 (D CF Reg Valve) auto control falls/manual control available Initiating Cues:

1AD-4 D/4, 1AD-2 F/9 When 1 D S/G level has been stabilized in manual and the SRO has completed consulting Technical Specifications, the next event can be inserted.

This will begin the major event. TS -3.3.1 Item 13 Condition E TS -3.3.2 Item 5.a.(2) Condition J, Item 5.b.(2) Condition D, Item 6.b Condition D TS -3.0.3 (due to two channels OOS) TS -3.3.3 Item 10 Condition B Event 7 -Large Break LOCAl Loss of emergency coolant recirculation When the second feed pump is tripped, the T/G will trip on AMSAC, but because they reactor is <69% power, it will not trip automatically.

The crew will manually trip the reactor based on the immediate actions of AP/06 (trip when >5% power and loss of all feedwater)

This begins the major event. NOTE: Depending on student reading speed, they could enter EP/1/A150001E5-1.3 without ever going to EPI1IA15000/E-1.

Additional failures

Auto S/I train A & B fails to auto actuate

1 NI-184B fails closed

1 A essential train loss of power In E-O, RNO Step 10.a.8).a) and b) when an operator is dispatched to secure ice condenser air handling units and place H2 analyzers in service, Insert EVENT 24. Call back when the analyzers are In service and state: "Both Unit 1 H2 Analyzers are in service." NOTE: At kickout from E-O, SUBCRITICALITY is RED due to N44 failure. NC INTEGRITY is RED or ORANGE due to cooldown of loops during a LB LOCA. NC INTEGRITY is VALID and the crew should transition briefly to EP/1/NSOOO/FR-P.1 but kick back out to E-1 due to flow to the NC cold legs. HEAT SINK could also be in RED due to operator action but should not be entered on that basis. In E-1 Step 4, if asked to sample S/Gs for activity state "I will sample Unit 1 SlGs for activity and report the results back in about an hour." In E-1 Step 4, if asked to frisk cation columns for activity state "I will frisk Unit 1 cation columns for activity and report back the results In a few minutes. Call back In 5 minutes and state "Unit 1 cation columns Indicate no abnormal activity." In ES-1.3 Step 4.b RNO, when dispatched to remove power from 1 EDE-F01 F, Insert EVENT 21. Call back when the breaker Is open and state "1 EDE-F01 F Is open." In ES-1.3 Step S.a.2).c).(2), RNO when dispatched to manually open 1NI-184B, Insert EVENT 22. Call back when the valve reaches full open and state "1 NI-184B Is open." Scenario End Point AFTER VERIFICATION OF PROPER sn FLOW PER STEP 5.1 of EP/1/5000lES-1.3.

In E-O, RNO Step 10.a.8).a) and b) when an operator is dispatched to secure ice condenser air handling units and place H2 analyzers in service, Insert EVENT 24. Call back when the analyzers are in service and state: "Both Unit 1 H2 Analyzers are In service." NOTE: At kickout from E-O, SUBCRITICALITY is RED due to N44 failure. NC INTEGRITY is RED or ORANGE due to cooldown of loops during a LB LOCA. NC INTEGRITY is VALID and the crew should transition briefly to EP/1/A/5000/FR-P.1 but kick back out to E-1 due to flow to the NC cold legs. HEAT SINK could also be in RED due to operator action but should not be entered on that basis. In E-1 Step 4, if asked to sample S/Gs for activity state "I will sample Unit 1 S/Gs for activity and report the results back In about an hour." In E-1 Step 4, if asked to frisk cation columns for activity state "I will frisk Unit 1 cation columns for activity and report back the results In a few minutes. Call back In 5 minutes and state "Unit 1 cation columns indicate no abnormal activity." In ES-1.3 Step 4.b RNO, when dispatched to remove power from 1 EDE-F01 F, Insert EVENT 21. Call back when the breaker Is open and state "1 EDE-F01 F Is open." In ES-1.3 Step 5.a.2).c).(2), RNO when dispatched to manually open 1 NI-184B, Insert EVENT 22. Call back when the valve reaches full open and state "1 NI-184B Is open." Scenario End Point AFTER VERIFICATION OF PROPER S/I FLOW PER STEP 5.1 of EP/1/5000/ES-1.3.

CREW TURNOVER INFORMATION Initial Conditions:

75% power

EFPD = 450 days

Boron Concentration is 208 ppm Turnover:

1 A DIG was placed in Maintenance Mode and red tagged 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago for PMs and is expected back in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

1 CFP5600 (1 D S/G Narrow Range Level Ch #2) failed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago. IAE repairs are in progress and estimated to take 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . All TSAIL entries have been made.

Increase power to 100% at 5% an hour per OP/1/A/61 00/003 (ContrOlling Procedure for Unit Operation), Enclosure 4.1, Power Increase.

CREW TURNOVER INFORMATION Initial Conditions:

75% power

EFPD = 450 days

Boron Concentration is 208 ppm Turnover:

1 A DIG was placed in Maintenance Mode and red tagged 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago for PMs and is expected back in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

1 CFP5600 (1 D S/G Narrow Range Level Ch #2) failed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago. IAE repairs are in progress and estimated to take 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . All TSAIL entries have been made.

Increase power to 100% at 5% an hour per OP/1/A/61 001003 (ContrOlling Procedure for Unit Operation), Enclosure 4.1, Power Increase.

Boron Concentration Control 1. Purpose To describe the operation of the Boron Concentration Control System. 2. Limits and Precautions OP/liAl6150/009 Page 2 of4 2.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing boron concentration. (R.M.) 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 When changing the boron concentration of the NC System, closely monitor the following for expected indication:

Rodmotion

T-AVG

Nuclear instrumentation 2.2.2 When performing dilutions at or near 100% power, batch additions to the VCT (instead of continuous dilution at low flow rates) are the preferr-ed method. {PIP C99-0587}

2.2.3 If the NC System is filled and vented and the boron concentration is being reduced in the NC System, at least one NC pump shall be in operation, recirculating the NC System. {PIP C99-2510}

2.2.4 If the boron concentration is being increased in the NC System, at least one NC pump or one ND pump shall be in operation, recirculating the NC System. 2.2.5 Following an increase or decrease of the NC System boron concentration of 2: 50 ppm, pressurizer spray shall be operated to equalize the boron concentration throughout the system. 2.2.6 When the reactor is sub critical and dilution is in progress, if the Nuclear Instrumentation increases by a factor of two, secure the operation immediately and evaluate the cause. 2.2.7 If the unit has operated continuously for several months, significant Boron 10 depletion may have occurred. The effective boron concentration of the NC System may be lower than indicated by Chemistry samples. NC temperature shall be carefully monitored following VCT makeup. 2.3 During continuous dilution operations, sample the NC System H2 concentration every eight hours. Boron Concentration Control 1. Purpose To describe the operation of the Boron Concentration Control System. 2. Limits and Precautions OP/liAl6150/009 Page 2 of4 2.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing boron concentration. (R.M.) 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 When changing the boron concentration of the NC System, closely monitor the following for expected indication:

Rodmotion

T-AVG

Nuclear instrumentation 2.2.2 When performing dilutions at or near 100% power, batch additions to the VCT (instead of continuous dilution at low flow rates) are the preferred method. {PIP C99-0587}

2.2.3 If the NC System is filled and vented and the boron concentration is being reduced in the NC System, at least one NC pump shall be in operation, recirculating the NC System. {PIP C99-2510}

2.2.4 If the boron concentration is being increased in the NC System, at least one NC pump or one ND pump shall be in operation, recirculating the NC System. 2.2.5 Following an increase or decrease of the NC System boron concentration of ;:: 50 ppm, pressurizer spray shall be operated to equalize the boron concentration throughout the system. 2.2.6 When the reactor is subcritical and dilution is in progress, if the Nuclear Instrumentation increases by a factor of two, secure the operation immediately and evaluate the cause. 2.2.7 If the unit has operated continuously for several months, significant Boron 10 depletion may have occurred.

The effective boron concentration of the NC System may be lower than indicated by Chemistry samples. NC temperature shall be carefully monitored following VCT makeup. 2.3 During continuous dilution operations, sample the NC System H2 concentration every eight hours.

OP/l!Al6150/009 Page 3 of4 2.4 When manually operating any motor operated valve, minimize the torque applied to the handwheel.

2.5 After

manual operation, maintenance or packing adjustment of any motor operated safety related valve, it shall be cycled electrically to ensure reliable automatic operation.

2.6 With the "NC MAKEUP MODE SELECT" switch in the "DILUTE" position, the makeup flow rate is limited by letdown flow, the VCTspray nozzle, and VCT pressure.

The maximum expected makeup flow rate is approximately 95 gpm. 2.7 With the "NC MAKEUP MODE SELECT" switch in the "ALTERNATE DILUTE" position, the maximum expected makeup flow rate is approximately 130 gpm. 2.8 With BAT boron concentration greater than or equal to 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is ppm. Automatic or manual makeup can be used when NC System boron concentration is < 1300 ppm. {PIP 03-7305} 2.9 With BAT boron concentration less than 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is 2: 1250 ppm. Automatic or manual makeup can be used when NC -System boron concentration is < 1250 ppm. {PIP 03-730S} 3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Automatic

Makeup 4.2 Boration 4.4 Alternate Dilution 4.5 Manual Operation Of The Makeup Controls 4.6 Operation Of The Boric Acid Transfer Pumps In Miniflow 4.7 Placing Boric Acid Tank #2 In Service For Unit #1 4.8 Valve Checklist

4.9 Rapid

Boration OP/l!Al6150/009 Page 3 of4 2.4 When manually operating any motor operated valve, minimize the torque applied to the handwheel.

2.5 After

manual operation, maintenance or packing adjustment of any motor operated safety related valve, it shall be cycled electrically to ensure reliable automatic operation.

2.6 With the "NC MAKEUP MODE SELECT" switch in the "DILUTE" position, the makeup flow rate is limited by letdown flow, the VCTspray nozzle, and VCT pressure.

The maximum expected makeup flow rate is approximately 95 gpm. 2.7 With the "NC MAKEUP MODE SELECT" switch in the "ALTERNATE DILUTE" position, the maximum expected makeup flow rate is approximately 130 gpm. 2.8 With BAT boron concentration greater than or equal to 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is ;::..1300 ppm. Automatic or manual makeup can be used when NC System boron concentration is < 1300 ppm. {PIP 03-7305} 2.9 With BAT boron concentration less than 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is 2:. 1250 ppm. Automatic or manual makeup can be used when NC boron concentration is < 1250 ppm. {PIP 03-7305} 3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Automatic

Makeup 4.2 Boration Dill.ltid!jj

4.4 Alternate

Dilution 4.5 Manual Operation Of The Makeup Controls 4.6 Operation Of The Boric Acid Transfer Pumps In Miniflow 4.7 Placing Boric Acid Tank #2 In Service For Unit #1 4.8 Valve Checklist

4.9 Rapid

Boration All steps performed by BOP Enclosure

4.3 Dilution

o 0111 D_ O OP/I/A/6150/009 Page 1 of3

mvlillllltiillllllllllll

2. Procedure 1--2.2 o 2.4 o 2.5 o 2.6 o 2.7 o 2.8 0 ..........

' .........

0 ...........

....

... 1.I ****** UI **** Me*.e' .... ** ...... ...... , All steps performed by BOP Enclosure

4.3 Dilution

OP!lIA/61501009 Page 1 of3 Hll;;i.!i'Mt>de

..

OJ . D 1 IWi:A./62 QO/OOI (Cllemi¢alallc:l D.i\A;

2. Procedure "till R 51 gciixltY 2.2 IF 4,J, tQ.e f,setppint on ToB!4Bleiidei-!Ctrl):

gpm D D

D 2. 6 mafeuiiba1cli "the ac!ge<!:".(R,M,!l) 2.9 o 2.9.1 o 2.9.2 o 2.9.3 Enclosure

4.3 Dilution

OP/l!A/6150/009 Page 2 of3 Place the control switch for 1NV-172A (3-Way Divert To VCT-RHT) to the "RHT" position.

Ensure VCT level is monitored continuously while diverting to the RHT. WHEN desired VCT level is reached return INV-l72A (3-Way Divert To RHT) to "AUTO". NOTE: If necessary, dilution can be manually secured at any time by placing the "NC MAKEUP CONTROL" switch to the "STOP" position.

o 2.10 2.11 2.12 2.13 2.14 2.14.1 2.14.2 IF it is desired to change the blender outlet boron concentration, refer to Enclosure 4.1 (Automatic Makeup). OR Enclosure

4.3 Dilution

OP/1!A/6150/009 Page 2 of3 2.9 IF ATAN:¥.lUME it is desired to divert letdown to the RHT manually operate 1 NV -172A (3-Way Divert To VCT-RHT) as follows: NOT DESIRED o 2.9.1 D 2.9.2 D 2.9.3 Place the control switch for INV-I72A (3-Way Divert To VCT-RHT) to the "RHT" position.

Ensure VCT level is monitored continuously while diverting to the RBT. WHEN desired VCT level is reached return INV -InA (3-Way Divert To RHT) to "AUTO". NOTE: Ifnecessary, dilution can be manually secured at any time by placing the "NC MAKEUP CONTROL" switch to the "STOP" position.

2.13 .WHEN\the ofreactbr 2.14.1 IF it is desired to change the blender outlet boron concentration, refer to Enclosure 4.1 (Automatic Makeup). OR 2.14 D

.. (:g.;M!d\

Enclosure

4.3 Dilution

OP/l!Al6150/009 Page 3 of3 2.15 Do NOT file this enclosure in the Control Copy folder of this procedure.

Enclosure

4.3 Dilution

OP/l!Al6150/009 Page 3 of3 2.15 Do NOT file this enclosure in the Control Copy folder of this procedure.

Controlling Procedure For Unit Operation

1. Purpose OP/I/A/6100/003 Page 2 of4 To describe the operation ofthe unit between approximately 1'5% and 100% full power. 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can effect core reactivity by the following: (R.M.)

Control rod movement

Turbine load changes

Feedwater manipulations

Reactor power changes 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 Before returning reactor control to automatic, T -A VG shall be within +/- 1°F of T-REF. 2.2.2 Do NOT exceed rod insertion limits or temporary rod withdrawal limits. 2.2.3 Automatic control rod withdrawal is blocked when Control Bank: D 200 steps withdrawn.

2.2.4 The difference in boron concentration between the PZR and NC System is desired to be maintained within +/- 50 ppm. 2.2.5 Axial Flux Difference (AFD) shall be maintained within the allowable limits as defined in the ROD manual at all power levels above 50% reactor power. (Tech Spec 3.2.3) 2.2.6 During a power change, other indications of reactor power shall be observed along with power range and secondary thermal power indications to aid in determining the reactor power level. Using indications like turbine impulse pressure, CF flow rate, NC loop /)" Ts, and others may help in detecting the miscalibration of a nuclear instrument.

2.3 In the event of an inadvertent power reduction, it is recommended that the power level NOT be increased until an investigation has been conducted and corrective action taken. Controlling Procedure For Unit Operation

1. Purpose OP/l!Al61 00/003 Page 2 of4 To describe the operation of the unit between approximately 15% and 100% full power. 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can effect core reactivity by the following: (R.M.)

Control rod movement

Turbine load changes

Feedwater manipulations

Reactor power changes 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 Before returning reactor control to automatic, T -A VG shall be within +/- 1°F of T-REF. 2.2.2 Do NOT exceed rod insertion limits or temporary rod withdrawal limits. 2.2.3 Automatic control rod withdrawal is blocked when Control Bank D 200 steps withdrawn.

2.2.4 The difference in boron concentration between the PZR and NC System is desired to be maintained within +/- 50 ppm. 2.2.5 Axial Flux Difference (AFD) shall be maintained within the allowable limits as defined in the ROD manual at all power levels above 50% reactor power. (Tech Spec 3.2.3) 2.2.6 During a power change, other indications of reactor power shall be observed along with power range and secondary thermal power indications to aid in determining the reactor power level. Using indications like turbine impulse pressure, CF flow rate, NC loop DoTs, and others may help in detecting the miscalibration of a nuclear instrument.

2.3 In the event of an inadvertent power reduction, it is recommended that the power level NOT be increased until an investigation has been conducted and conective action taken.

OP/l!A/6100/003 Page 3 of4 2.4 lfreactor control is in manual, maintain T-AVG within +/- 2°F ofT-REF to prevent receiving "T-REF/T-AUCT HIILO" alarm. 2.5 Whenever there is a thermal power change greater than or equal to 15% rated thermal power within a one hour period: (OAC point CIL4790 in alarm)

NotifY Chemistry to take an isotopic analysis for iodine within 2 to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months following the last power change that is greater than or equal to 15% rated thermal power within a one hour period. (T.S. SR 3.4.16.2)

When thermal power has stabilized, notifY Radiation Protection to sample and analyze gaseous effluents. (S.L.C. 16.11-6) 2.6 S/G blowdown flowrate shall NOT exceed a maximum of200 GPM per S/G. 2.7 After a thermal power change when plant conditions stabilize, 1EMF-39 setpoints shall be adjusted so the Trip 2 setpoint is set at three times the containment activity and Trip 1 setpoint is set at 70% of Trip 2 setpoint.

2.8 lfthe

RC System condenser inlet temperature drops to less than or equal to 60°F when the Rx is shutdown or less than or equal to 55°F when the Rx is critical, the system shall be configured as follows:

One RC pump running (throttled).

One tower inlet isolated.

All three riser bypasses open. 2.9 OAC point CIK0628 (CF Flow Venturi Correction Factor) shall be reset to 1.0 when either of the following conditions are met:

A step load change such as a load rejection greater than 10% rated thermal power,

A ramp load change of greater than 15% rated thermal power in a one hour period. 2.10 When the unit is engaged in a power maneuver resulting in a mismatch between OAC point C1P1385 (Reactor Thermal Power, Best) and any excore power channel in excess of2% refer to Tech Spec Basis for SR 3.3.1.2. 2.11 The insertion of Control Bank D will affect mismatch between OAC point C1P1385 (Reactor Thermal Power, Best) and the excore power range channels.

This is due to shielding of the power range detectors by Control Bank D. Therefore, refer to Tech Spec Basis for SR 3.3.1.2 when mismatch between Reactor Thermal Power (Best Estimate) and the excore power range channels shall be observed to be exceeding 2%. 2.12 The Reactor Engineering Group normally provides information for planned power maneuvers.

The OAC xenon predict program can be used to help anticipate dilution and boration requirements.

{PIP C99-0587}

OP!l/A/6100/003 Page 3 of4 2.4 If reactor control is in manual, maintain T-AVG within +/- 2°F ofT-REF to prevent receiving "T-REF/T-AUCT HIILO" alarm. 2.5 Whenever there is a thermal power change greater than or equal to 15% rated thermal power within a one hour period: (OAC point C1L4790 in alarm)

Notify Chemistry to take an isotopic analysis for iodine within 2 to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months following the last power change that is greater than or equal to 15% rated thermal power within a one hour period. (T.S. SR 3.4.16.2)

When thenna1 power has stabilized, notify Radiation Protection to sample and analyze gaseous effluents. (S.L.e. 16.11-6) 2.6 S/G blowdoVlll flowrate shall NOT exceed a maximum of 200 GPM per S/G. 2.7 After a thermal power change when plant conditions stabilize, 1EMF-39 setpoints shall be adjusted so the Trip 2 setpoint is set at three times the containment activity and Trip 1 setpoint is set at 70% of Trip 2 setpoint.

2.8 If the RC System condenser inlet temperature drops to less than or equal to 60°F when the Rx is shutdown or less than or equal to 55°F when the Rx is critical, the system shall be configured as follows:

One RC pump running (throttled).

One tower inlet isolated.

All three riser bypasses open. 2.9 OAC point C1K0628 (CF Flow Venturi Correction Factor) shall be reset to 1.0 when either of the following conditions are met:

A step load change such as a load rejection greater than 10% rated thermal power,

A ramp load change of greater than 15% rated thermal power in a one hour period. 2.10 When the unit is engaged in a power maneuver resulting in a mismatch between OAC point C1P1385 (Reactor Thermal Power, Best) and any excore power channel in excess of2% refer to Tech Spec Basis for SR 3.3.1.2. 2.11 The insertion of Control Bank D will affect mismatch between OAC point C1P1385 (Reactor Thermal Power, Best) and the excore power range channels.

This is due to shielding of the power range detectors by Control Bank D. Therefore, refer to Tech Spec Basis for SR 3.3.1.2 when mismatch between Reactor Thermal Power (Best Estimate) and the excore power range channels shall be observed to be exceeding 2%. 2.12 The Reactor Engineering Group normally provides information for planned power maneuvers.

The OAC xenon predict program can be used to help anticipate dilution and boration requirements.

{PIP C99-0587}

OP/l!A/61 00/003 Page 4 of4 2.13 The Steamline N-16 Radiation Monitors (EMF-71, 72, 73, 74) become inaccurate at power levels below 40% due to inaccuracies in the algorithm used to calculate the output of these monitors.

{PIP 99-3980} 2.14 It is recommended that Primary Chemistry be notified prior to all significant boric acid additions or dilutions to the NC System 'Such that proper pH control may be maintained.

Normal boric acid additions and dilutions should be communicated at the Control Room shift briefing.

{PIP C-O 1-665} 2.15 In accordance with INPO best practices when personnel are accessing areas that could experience significant dose rate changes resulting from increasing power, Operations shall maintain Reactor power steady or decreasing.

3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.2 Power

Decrease 4.3 Unit Operation Between 85% and 100% Power 4.4 T-AVG Coastdown 4.4.1 T-AVG Coastdown Data 4.4.2 Adjustment OfDCS ACCEPTED VALUE For T AVG 4.4.3 T-AVG Coastdown Tracking Data (Phase 1 and Phase 2) 4.5 Power Escalation Guideline OP/I/A/61 001003 Page 4 of4 2.13 The Steamline N-16 Radiation Monitors (EMF-71, 72, 73, 74) become inaccurate at power levels below 40% due to inaccuracies in the algorithm used to calculate the output of these monitors.

{PIP 99-3980} 2.14 It is recommended that Primary Chemistry be notified prior to all significant boric acid additions or dilutions to the NC System such that proper pH control may be maintained.

Normal boric acid additions and dilutions should be communicated at the Control Room shift briefing.

{PIP C-O 1-665} 2.15 In accordance with INPO best practices when personnel are accessing areas that could experience significant dose rate changes resulting from increasing power, Operations shall maintain Reactor power steady or decreasing.

3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.2 Power

Decrease 4.3 Unit Operation Between 85% and 100% Power 4.4 T-AVG Coastdown 4.4.1 T -A VG Coastdown Data 4.4.2 Adjustment OfDCS ACCEPTED VALUE For T A VG 4.4.3 T-AVG Coastdown Tracking Data (Phase 1 and Phase 2) 4.5 Power Escalation Guideline Enclosure

4.1 Power

Increase OP/l!Al6100/003 Page 15 of 15 --2.50 IF required due to Generator/Automatic Voltage Regulator (AVR) testing at approximately 75% turbine power MWe), perform the following:

2.50.1 D 2.50.2 IF performing Generator/Automatic Voltage Regulator (A VR) testing, HOLD until Generator/

A VR personnel are ready for Operations to continue with Unit 1 power increase.

Once notified by A VR personnel that A VR testing is complete, at this power, begin power increase.

Person making notification'--

_______ _ CAUTION: Alternate indications of reactor power shall be monitored to verify reactor power level and help prevent NI miscalibration.

2.51 At 75% reactor power, compare OAC heat balance point CIP1385 (Reactor Thermal Power, Best) to nuclear instrumentation.

--2.52 IF required, notify lAE to adjust nuclear instrumentation per Model W/O #00874628.

Person notified ---------------------------

CAUTION: Failure to perform the following step as written may result in lifting the AS Header relief valve. NOTE: OAC Graphics CF Pump Details, CFPMPIA and CFPMPIB, shall be referred to while swapping steam supplies for CFPTs. --2.'53 1\1IIIII1III:

... _" ..............

__ ..,"' * .... m , ** -IAII steps to here complete.

No steps signed off here ... D 2.53.1 Slowly open ISP-3 (SC To CFPT lA & IB) (TB-640, IG-24). D 253.2 Adjust setpoint of lAS-2 (Main Stm To Aux Stm) to 125 psig. D 2.'53.3 Slowly close lAS-12 (AS To CFPT Isol). D 253.4 IF Unit 1 and Unit 2 AS headers are cross-tied, adjust setpoint of2AS-2 (Main Stm To Aux Stm) to maintain the desired AS header pressure.

2.54 IF a temporary PC was installed at the local MSR Panel for placing the MSR's in service, remove the PC. 2.S5 IF desired to increase turbine power to greater than 85%, .go to Enclosure 4.3 (Unit Operation Between 85% and 100% Power). 2.56 File this enclosure in the Control Copy folder of this procedure.

Enclosure

4.1 Power

Increase OP/l!Al6 1 001003 Page 15 of 15 --2.50 IF required due to Generator/Automatic Voltage Regulator (AVR) testing at approximately 75% turbine power MWe), perform the following:

2.50.1 o 2.50.2 IF performing Generator/Automatic Voltage Regulator (AVR) testing, HOLD until Generator/

A VR personnel are ready for Operations to continue with Unit 1 power Increase.

Once notified by A VR personnel that A VR testing is complete, at this power, begin power increase.

Person making notification.

________ _ CAUTION: Alternate indications of reactor power shall be monitored to verify reactor power level and help prevent NI miscalibration.

2.51 At 75% reactor power, compare OAC heat balance point CIP1385 (Reactor Thelmal Power, Best) to nuclear instrumentation.

--2.52 IF required, notify IAE to adjust nuclear instrumentation per Model W/O #00874628. Person notified

CAUTION: Failure to perform the following step as written may result in lifting the AS Header relief valve. NOTE: OAC Graphics CF Pump Details, CFPMPIA and CFPMPlB, shall be referred to while swapping steam supplies for CFPTs. --2.5 3 Y;'petfofni iCE ( urn ." . "'P P.li(,,* .. ,,*.. .............

All steps to here complete.

No steps signed off here .. . o 2.53.1 Slowly open lSP-3 (SC To CFPT lA & IB) (TB-640, lG-24). o 2.53.2 o 2.53.3 o 2.53.4 Adjust setpoint of lAS-2 (Main Stm To Aux Stm) to 125 psig. Slowly close lAS-12 (AS To CFPT Isol). IF Unit 1 and Unit 2 AS headers are cross-tied, adjust setpoint of 2AS-2 (Main Stm To Aux Stm) to maintain the desired AS header pressure.

2.54 IF a temporary PC was installed at the local MSR Panel for placing the MSR's in service, remove the Pc. 2.55 IF desired to increase turbine power to greater than 85%, go to Enclosure 4.3 (Unit Operation Between 85% and 100% Power). 2.56 File this enclosure in the Control Copy folder of this procedure.

Turbine Generator

1. Purpose To describe the proper method for operating the Turbine-Generator.

2. Limits and Precautions OP/l!B/6300/001 Page 2 of5 2.1 This procedure is Reactivity Management related because it controls activities that can effect reactivity. (R.M.) 2.2 Low load operation limits: 2.2.1 The unit can be operated continuously at low loads when exhaust hood temperature is < 175°P. The load shall, however, be increased slowly until the temperature decreases below 125°P before increasing load at normal rate (Multipoint Recorder on IMC3). 2.2.2 Limit turbine/generator operation below 5% load to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to prevent moisture erosion unless directed by the Turbine Engineer for testing 2.2.3 Motoring of the unit is to be avoided. 2.2.4 Excessive use of the exhaust hood sprays shall be avoided to prevent accelerated blade erosion. 2.3 Journal bearings shall NOT be operated with metal temperatures above 250°F (OAC Turbine Bearings graphic (TGBRG)).

2.4 Lube oil cooler discharge temperatures shall be lOO°F to 120 0 P when at rated speed. 2.5 The lube oil temperature rise shall NOT exceed SOop on the main bearings and 45°P on the thrust bearing. 2.6 Under no conditions shall the thrust bearing be operated above 190 0 P metal temperature (OAC Turbine Bearings graphic (TGBRG)).

2.7 Never

allow a hot rotor to stand without rolling. If and when a hot rotor was allowed to stand still, when possible rotate the shaft 180° and allow to stand still again for one-half the time it first stood still, and then put the turbine on turning gear. 2.8 The minimum allowed cold gas temperature is 86°P for operation.

The maximum cold gas temperature is 122°P. (OAC points CIA0522 (Cold Gas from Hydrogen Cooler Turbine End) and CIA0528 (Cold Gas from Hydrogen Cooler Exciter End), Main Generator graphic (MAINGEN)).

Turbine Generator

1. Purpose To describe the proper method for operating the Turbine-Generator.

2. Limits and Precautions OP/l!B/6300/001 Page 2 of5 2.1 This procedure is Reactivity Management related because it controls activities that can effect reactivity. (R.M.) 2.2 Low load operation limits: 2.2.1 The unit can be operated continuously at low loads when exhaust hood temperature is < 175°P. The load shall, however, be increased slowly until the temperature decreases below 125°P before increasing load at normal rate (Multipoint Recorder on 1MC3). 2.2.2 Limit turbine/generator operation below S% load to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to prevent moisture erosion unless directed by the Turbine Engineer for testing 2.2.3 Motoring of the unit is to be avoided. 2.2.4 Excessive use of the exhaust hood sprays shall be avoided to prevent accelerated blade erosion. 2.3 Journal bearings shall NOT be operated with metal temperatures above 250°F (OAC Turbine Bearings graphic (TGBRG)).

2.4 Lube oil cooler discharge temperatures shall be lOO°F to 120 0 P when at rated speed. 2.5 The lube oil temperature rise shall NOT exceed SOop on the main bearings and 4SoP on the thrust bearing. 2.6 Under no conditions shall the thrust bearing be operated above 190 0 P metal temperature (OAC Turbine Bearings graphic (TGBRG)).

2.7 Never

allow a hot rotor to stand without rolling. If and when a hot rotor was allowed to stand still, when possible rotate the shaft 180° and allow to stand still again for one-half the time it first stood still, and then put the turbine on turning gear. 2.8 The minimum allowed cold gas temperature is 86°P for operation.

The maximum cold gas temperature is 122°P. (OAC points C1AOS22 (Cold Gas from Hydrogen Cooler Turbine End) and C1A0528 (Cold Gas from Hydrogen Cooler Exciter End), Main Generator graphic (MAINGEN)).

OP/l!B/63 00100 1 Page 3 of5 2.9 Do NOT exceed the load, hydrogen pressure, and power factor limits per the Unit One Revised Data Book Figure 43. 2.10 Ifthe limits of the Unit One Revised Data Book Figure 43 (Generator Capability Curves) are exceeded, the Turbine Generator shall be tripped. 2.11 The generator shall NOT be operated without excitation.

If the generator is operated without field, the unit shall be immediately tripped off the line and shutdown for inspection.

2.12 Following a trip-out due to differential phase relays, both the armature and field windings shall be meggered and inspected before attempting to resynchronize.

2.13 Do NOT allow turbine generator speed to ex.c;eed 2000 rpm on overspeed tests. 2.14 The turbine shall NOT be operated with condenser vacuum less than 24.3 inches Hg. 2.15 The maximum differential pressure between adjacent LP shell pressures shall NOT exceed 2.0 inches Hg. (main condenser vacuum gauges on 1MC13, OAC points C1P1669 (DIP between A & B Condensers) and C1P1670 (DIP between B & C Condensers) or Main Condenser graphic (CMCOND)).

2.16 Do NOT hold the turbine at speeds < 800 rpm for more than 5 minutes. 2.17 When steam seals are on the turbine, the steam packing exhauster shall be operating, and the turbine shall be on turning gear. The turbine may be taken off gear with steam seals established with concurrence from the Turbine Engineer.

2.18 When a condition arises that is serious enough to make a reduction in speed necessary, it shall be initiated by selecting "MANUAL" and "CONTROL VALVE LOWER" or by tripping the turbine. 2.19 Temperature ofthe LH System reservoir shall be 90°F prior to turbine start (OAC point C1A0188 (LH TEMP)). 2.20 A sudden downward trend on an LP turbine's lower extraction temperature shall be investigated as a possible indication of water induction into the turbine. This is indicated on the recorder on the rear of 1MC8 labeled "TURBINE WATER DETECTION", using any of the LP 8th stage lower temperatures.

2.21 The time the turbine generator is on turning gear shall be kept to a minimum to prevent the buildup of copper dust in the generator coil slots. 2.22 When system is in "EMERG MANUAL" runbacks and limit circuits may NOT be available.

2.23 Control rods shall NOT exceed rod withdrawal limits. Prior to changing power, refer to Reactor Operating Data Book, Temporary Control Rod Withdrawal Limits. OP/I/B/63 00100 1 Page 3 of5 2.9 Do NOT exceed the load, hydrogen pressure, and power factor limits per the Unit One Revised Data Book Figure 43. 2.10 If the limits of the Unit One Revised Data Book Figur-e 43 (Generator Capability Curves) are exceeded, the Turbine Generator shall be tripped. 2.11 The generator shall NOT be operated without excitation.

If the generator is operated without field, the unit shall be immediately tripped off the line and shutdown for inspection.

2.12 Following a trip-out due to differential phase relays, both the armature and field windings shall be meggered and inspected before attempting to resynchronize.

2.13 Do NOT allow turbine generator speed to ex-ceed 2000 rpm on overspeed tests. 2.14 The turbine shall NOT be operated with condenser vacuum less than 24.3 inches Hg. 2.15 The maximum differential pressure between adjacent LP shell pressures shall NOT exceed 2.0 inches Hg. (main condenser vacuum gauges on 1MC13, OAC points C1P1669 (DIP between A & B Condensers) and C1P1670 (DIP between B & C Condensers) or Main Condenser graphic (CMCOND)).

2.16 Do NOT hold the turbine at speeds < 800 rpm for more than 5 minutes. 2.17 When steam seals are on the turbine, the steam packing exhauster shall be operating, and the turbine shall be on turning gear. The turbine may be taken off gear with steam seals established with concurrence from the Turbine Engineer.

2.18 When a condition arises that is serious enough to make a reduction in speed necessary, it shall be initiated by selecting "MANUAL" and "CONTROL VALVE LOWER" or by tripping the turbine. 2.19 Temperature of the LH System reservoir shall be 90°F prior to turbine start (OAC point C1A0188 (LH TEMP)). 2.20 A sudden downward trend on an LP turbine's lower extraction temperature shall be investigated as a possible indication of water induction into the turbine. This is indicated on the recorder on the rear of 1MC8 labeled "TURBINE WATER DETECTION", using any of the LP 8th stage lower temperatures.

2.21 The time the turbine generator is on turning gear shall be kept to a minimum to prevent the buildup of copper dust in the generator coil slots. 2.22 When system is in "EMERG MANUAL" runbacks and limit circuits may NOT be available.

2.23 Control rods shall NOT exceed rod withdrawal limits. Prior to changing power, refer to Reactor Operating Data Book, Temporary Control Rod Withdrawal Limits.

OP/l!B/6300/001 Page 4 of5 2.24 A "LOAD RATE" > "6.2 MW/MIN" shall NOT be used during nonnalload changes. 2.25 The main turbine oil temperature limit of 80 to 90°F shall be maintained when the turbine is on the turning gear. 2.26 Differential temperature between adjacent exhaust hoods shall NOT exceed 30°F unless evaluated and approved by the responsible engineer (Turbine Generator System Expert). (OAC points CIP1667 (A & B Exhaust Hoods Metal Delta Temp) and CIP1668 (B & C Exhaust Hoods Metal Delta Temp) or Main Condenser graphic (CMCOND)).

2.27 During turbine acceleration, the heat up rate of the first stage bowl inner surface (OAC Point CIP1283 (First Stage Metal Temp Rate)) shall be < 150°Fihr.

2.28 During turbine acceleration, the rate of change of the reheat steam temperature (OAC points CIP1287 to CIP1292 (CIV No.1 (to 6) Inlet Temp Rate) or Turbine Generator graphic (TG)) shall be < 125°F/hr.

2.29 Any deviations from this procedure that could affect steam admission rates shall require an engineering evaluation to be perfonned which specifically addresses partial arc admission.

2.30 The 6.9KV Switchgear Automatic Fast Transfer Switches are placed in the ENABLE position whenever the generator breakers are closed and in the DEFEAT position whenever the generator breakers are open. If an autoswap of the tie breaker occurs when in the DEFEAT position, equipment being supplied by the 6.9KV Switchgear is more likely to trip than when the switch in ENABLE. {PIP 98-4093, PIP 98-3589} 2.31 Feedback loops shall NOT be taken in/out of service during turbine control valve movement.

Following turbine control valve movement, DEHC shall be allowed to stabilize prior to placing feedback loops in/out of service to prevent unexpected load changes. (PIP 03-5660) 2.32 The Main Turbine OIU Work Station has the capability to perfonn control functions for the Main Turbine, including tripping and resetting of the turbine. If a control function window is inadvertently selected while manipulating the Main Turbine OIU Work Station, the window shall be closed to prevent actuation of the control function.

2.33 The Main Turbine shall NOT be run more than 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months at 1800 RPM, no load, unless directed by the Turbine Engineer for testing. 2.34 The Excitation System can affect the functioning of heart pacemakers.

Personnel with pacemaker devices shall NOT enter the AVR enclosure/building during operation or testing. If the A VR enclosurelbuilding is NOT installed, personnel with pacemaker devices shall remain at least 20 feet away from the A VR during operation or testing. 2.35 Failure to confinn steam isolation to the turbine prior to opening the generator breaker may result in destructive overspeed of the steam turbine power train. {PIP C-08-S0 18} OP;l/B/63 00/00 1 Page 4 of5 2.24 A "LOAD RATE" > "6.2 MW/MIN" shall NOT be used during nonnalload changes. 2.25 The main turbine oil temperature limit of 80 to 90°F shall be maintained when the turbine is on the turning gear. 2.26 Differential temperature between adjacent exhaust hoods shall NOT exceed 30°F unless evaluated and approved by the responsible engineer (Turbine Generator System Expert). (OAC points C1P1667 (A & B Exhaust Hoods Metal Delta Temp) and C1P1668 (B & C Exhaust Hoods Metal Delta Temp) or Main Condenser graphic (CMCOND)).

2.27 During turbine acceleration, the heat up rate of the first stage bowl inner surface (OAC Point C1P1283 (First Stage Metal Temp Rate)) shall be < 150°Flhr.

2.28 During turbine acceleration, the rate of change of the reheat steam temperature (OAC points C1P1287 to C1P1292 (CIV No.1 (to 6) Inlet Temp Rate) or Turbine Generator graphic (TG)) shall be < 125°Flhr.

2.29 Any deviations from this procedure that could affect steam admission rates shall require an engineering evaluation to be perfonned which specifically addresses partial arc admission.

2.30 The 6.9KV Switchgear Automatic Fast Transfer Switches are placed in the ENABLE position whenever the generator breakers are closed and in the DEFEAT position whenever the generator breakers are open. If an auto swap of the tie breaker occurs when in the DEFEAT position, equipment being supplied by the 6.9KV Switchgear is more likely to trip than when the switch in ENABLE. {PIP 98-4093, PIP 98-3589} 2.31 Feedback loops shall NOT be taken in/out of service during turbine control valve movement.

Following turbine control valve movement, DEHC shall be allowed to stabilize prior to placing feedback loops in/out of service to prevent unexpected load changes. (PIP 03-5660) 2.32 The Main Turbine OIU Work Station has the capability to perfonn control functions for the Main Turbine, including tripping and resetting of the turbine. If a control function window is inadvertently selected while manipulating the Main Turbine OIU Work Station, the window shall be closed to prevent actuation of the control function.

2.33 The Main Turbine shall NOT be run more than 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months at 1800 RPM, no load, unless directed by the Turbine Engineer for testing. 2.34 The Excitation System can affect the functioning of heart pacemakers.

Personnel with pacemaker devices shall NOT enter the AVR enclosure/building during operation or testing. If the AVR enclosurelbuilding is NOT installed, personnel with pacemaker devices shall remain at least 20 feet away from the AVR during operation or testing. 2.35 Failure to confinn steam isolation to the turbine prior to opening the generator breaker may result in destructive overspeed of the steam turbine power train. {PIP C-08-5018}

3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Turbine

Generator Startup 4.2 Load Changing OP/l!B/63001001 Page 5 of5 4.3 Transfer Turbine From Auto Control To Manual Control And Transfer Turbine From Manual Control To Auto Control 4.4 Turbine Generator Shutdown 4.5 Placing (Removing)

Core Monitor And Pyrolysate Collector In (From) Service 4.6 Valve Checklist

4.7 Generator

Operating Limits 4.8 Turbine Generator Roll Computer Points 4.9 Lamp Verification 4.10 Operation of Turbine TSI Panel 4.11 Reboot of the Main Turbine OID Computer 4.12 Transfer of the Main Turbine OID Computer Alarm Switch That Drives the "EHC Fault Annunciator" 4.13 Voltage Regulator Operation From Control Room 4.14 Voltage Regulator Operation From Ul Gen Voltage Reg Local Control Panel 3. Procedure Refer to Section 4 (Enclosures).

4. Enclosures

4.1 Turbine

Generator Startup 4.2 Load Changing OP/l!B/6300100 1 Page 5 of5 4.3 Transfer Turbine From Auto Control To Manual Control And Transfer Turbine From Manual Control To Auto Control 4.4 Turbine Generator Shutdown 4.5 Placing (Removing)

Core Monitor And Pyrolysate Collector In (From) Service 4.6 Valve Checklist

4.7 Generator

Operating Limits 4.8 Turbine Generator Roll Computer Points 4.9 Lamp Verification 4.10 Operation of Turbine TSI Panel 4.11 Reboot of the Main Turbine OIU Computer 4.12 Transfer of the Main Turbine OIU Computer Alarm Switch That Drives the "EHC Fault Annunciator" 4.13 Voltage Regulator Operation From Control Room 4.14 Voltage Regulator Operation From VI Gen Voltage Reg Local Control Panel D 2.1.1.6 2.1.1.7 2.1.1.8 D 2.1.1.9 D Enclosure 4.2 Load Changing OP/l!B/63 00/00 1 Page 2 of4 Verify the following valves close at 15% of full load (181 MW, 105 psig Turbine Impulse Pressure):

ISM-21 (Ctrl Vlv #2 Stm Lead Dm)

ISM-29 (Ctrl Vlv #1 Stm Lead Dm) WHEN CV3 comes off of its fully closed 'Seat (65% of full load, 783 MW), verify ISM-25 (Ctrl Vlv #3 Stm Lead Dm) closes. WHEN CV 4 comes off of its fully closed seat (92% of full load, 1109 MW), verify ISM-33 (Ctrl Vlv #4 Stm Lead Dm) closes. S/G blowdown flowrates shall be adjusted to obtain maximum blowdown for the appropriate load. o 2.1.1.6 2.1.1.7 2.1.1.8 o 2.1.1.9 Enclosure 4.2 Load Changing OP/l!B/63 00100 1 Page 2 of4 Verify the following valves close at 15% of full load (181 MW, 105 psig Turbine Impulse Pressure):

lSM-21 (Ctrl Vlv #2 Stm Lead DID)

lSM-29 (Ctrl Vlv #1 Stm Lead DID) WHEN CV3 comes off of its fully closed seat (65% of full load, 783 MW), verify lSM-25 (Ctrl Vlv #3 Stm Lead DID) closes. WHEN CV 4 comes off of its fully closed seat (92% of full load, 1109 MW), verify 1SM-33 (Ctrl Vlv #4 Stm Lead DID) closes. S/G blowdown flowrates shall be adjusted to obtain maximum blowdown for the appropriate load. ;.'

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'{i[A;RG:E'G" D 2.1.2.7 CAUTION: Enclosure 4.2 Load Changing OP/l!B/63 00/00 1 Page 3 of4 2.2 IF decreasing turbine generator load, perform the following:

2.2.1 Decrease

turbine generator load within the following limitations:

D 2.2.1.1 D 2.2.1.2 D 2.2.1.3 D 2.2.1.4 2.2.1.5 2.2.1.6 Rate of change of First-Stage Bowl Inner Surface Temperature shall NOT exceed IS0°Flhr (OAC point CIP1283 (First Stage Metal Temp Rate)). OAC point CIA1140 (Turbine Lower Inner Shell Temp) vs. Percent Steam Flow (OAC point CIP1588 (Design Total Main Steam Flow, Measured (%)) shall be maintained above and to the left of curve in the Unit One OAC Databook "Load-Changing Recommendations".

Control valve casing difference, OAC point CIA0961 (Turb Valve Chest Inner Surface Metal Temp) minus CIA0967 (Turb Valve Chest Outer Surface Metal Temp), shall NOT exceed curve "Allowable Temp Difference on Control Valve Casing" in the Unit 1 OAC Databook.

S/G blowdown flowrates shall be adjusted to obtain maximum blowdown for the appropriate load. IF CV4 fully closes (92% of full load, 1109 MWE), verify ISM-33 (Ctrl Vlv #4 Strn Lead Dm) opens. IF CV3 fully closes (65% of full load, 783 MWE), verify ISM-25 (Ctrl Vlv #3 Stm Lead Dm) opens. o 2.1.2.7 o o

Enclosure 4.2 OP/l!B/6300/001 Load Changing Page 3 of 4 CA UTI 0 N One Data Book Eigfir y Not be ex;geedeq; 2.2 IF decreasing turbine generator load, perfonn the following:

2.2.1 Decrease

turbine generator load within the following limitations:

o 2.2.1.1 o 2.2.1.2 o 2.2.1.3 o 2.2.1.4 2.2.1.5 2.2.1.6 Rate of change of First-Stage Bowl Inner Surface Temperature shall NOT exceed lS0°Flhr (OAC point C1P1283 (First Stage Metal Temp Rate)). OAC point C1Al140 (Turbine Lower Inner Shell Temp) vs. Percent Steam Flow (OAC point C1P1588 (Design Total Main Steam Flow, Measured (%)) shall be maintained above and to the left of curve in the Unit One OAC Databook "Load-Changing Recommendations".

Control valve casing difference, OAC point C1A0961 (Turb Valve Chest Inner Surface Metal Temp) minus C1A0967 (Turb Valve Chest Outer Surface Metal Temp), shall NOT exceed curve "Allowable Temp Difference on Control Valve Casing" in the Unit 1 OAC Databook.

S/G blowdown flowrates shall be adjusted to obtain maximum blowdown for the appropriate load. IF CV4 fully closes (92% of full load, 1109 MWE), verify 1SM-33 (Ctrl Vlv #4 Stm Lead Dm) opens. IF CV3 fully closes (65% of full load, 783 MWE), verify 1SM-25 (Ctrl Vlv #3 Stm Lead Dm) opens.

Initiating Cues:

1AD-2, Al3, Al8, B/8, C/8 E/8 and others Initiating Cues:

1AD-2, N3, N8, B/8, C/8 E/8 and others CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/N55001016 1 of 14 Rev 24 A. Purpose

To verify the proper response in the event of a nuclear instrumentation malfunction.

B. Symptoms Case I. Source Range Malfunction

Indication lost or erratic

1AD-2, D/1"S/R HI VOLTAGE FAILURE" -LIT

1AD-2, D/3 "SIR HI FLUX LEVEL AT SHUTDOWN" -LIT

1AD-2, D/4 "SIR HI FLUX LEVEL AT SHUTDOWN" -LIT. Case II. Audio Count Rate Malfunction

Audible count rate lost. Case III. Intermediate Range Malfunction

Indication lost or erratic

1AD-2, C/1 "IIR HI VOLTAGE FAILURE" -LIT

1AD-2, C/2 "IIR COMPENSATING VOLTAGE FAILURE" -LIT

1AD-2, C/3 "I/R HI FLUX LEVEL ROD STOP" -LIT

SIR failure to re-energize during shutdown.

Indication lost or erratic

1AD-2, N1"P/R HI NEUTRON FLUX RATE ALERT" -LIT

1AD-2, N2 "P/R HI NEUTRON FLUX LO SETPOINT ALERT" -LIT

1AD-2, N3 "P/R HI NEUTRON FLUX HI SETPOINT ALERT" -LIT

1AD-2, 8/3 "COMPARATOR P/R CHANNEL DEVIATION" -LIT

1AD-2, 8/5 "P/R HI VOLTAGE FAILURE" -LIT

1AD-2, E/8 "OVER POWER ROD STOP" -LIT CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A155001016 1 of 14 Rev 24 A. Purpose

To verify the proper response in the event of a nuclear instrumentation malfunction.

B. Symptoms Case I. Source Range Malfunction

Indication lost or erratic

1AD-2, D/1 "SIR HI VOLTAGE FAILURE" -LIT

1AD-2, D/3 "SIR HI FLUX LEVEL AT SHUTDOWN" -LIT

1AD-2, D/4 "SIR HI FLUX LEVEL AT SHUTDOWN" -LIT. Case II. Audio Count Rate Malfunction

Audible count rate lost. Case III. Intermediate Range Malfunction

Indication lost or erratic

1AD-2, C/1 "IIR HI VOLTAGE FAILURE" -LIT

1AD-2, C/2 "IIR COMPENSATING VOLTAGE FAILURE" -LIT

1AD-2, C/3 "IIR HI FLUX LEVEL ROD STOP" -LIT

SIR failure to re-energize during shutdown.

Indication lost or erratic

1AD-2, Al1 "P/R HI NEUTRON FLUX RATE ALERT" -LIT

1AD-2, Al2 "P/R HI NEUTRON FLUX LO SETPOINT ALERT" -LIT

1AD-2, Al3 "P/R HI NEUTRON FLUX HI SETPOINT ALERT" -LIT

1AD-2, 8/3 "COMPARATOR P/R CHANNEL DEVIATION" -LIT

1AD-2, 8/5 "P/R HI VOLTAGE FAILURE" -LIT

1AD-2, E/8 "OVER POWER ROD STOP" -LIT CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/11 Al5500/0 16 Case IV 10 of 14 Power Range Malfunction Rev 24 DCl: ACTION/EXPECTED RESPONSE I RESPONSE NOT OBTAINED C. Operator Actions IRO DOES THIS PAGE _@ BIWIIllIIlTcftD1Ili

- - MlIPII 2.

N-41 OR

N-42 OR

N-43 OR _8 ... --_ IF unwarranted rod motion is occurring, THEN place "CRD BANK SELECT" to manual. _ Adjust Turbine load to maintain T-Avg at T-Ref. CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 Case IV 10 of 14 Power Range Malfunction Rev 24 DC!: ACTION/EXPECTED RESPONSE C. Operator Actions DOES THIS PAGE _@'VerifyaurOdmotion:':§TPPPED.

2. VgrUYiiii1

N-41 OR

N-42 OR

N-43 OR jPPERABLE.

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_

_ '.(OP DELTA 11. RESPONSE NOT OBTAINED _ IF unwarranted rod motion is occurring, THEN place "CRD BANK SELECT" to manual. _ Adjust Turbine load to maintain T -Avg at T-Ref.

CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM AP/1/A/5500/016 Case IV Power Range Malfunction ACTION/EXPECTED RESPONSE 6.

7.

RESPONSE NOT OBTAINED S THIS PAGE PAGE NO. 11 of 14 Rev 24 CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM AP/1/A/5500/016 Case IV Power Range Malfunction ACTION/EXPECTED RESPONSE 6.

Contr()IAJ1<i1

a.

7 n

_

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/'" forttie RESPONSE NOT OBTAINED BOP DOES THIS PAGE PAGE NO. 11 of 14 Rev 24 CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/Al5500/016 Case IV 12 of 14 Power Range Malfunction Rev 24 ACTION/EXPECTED RESPONSE c.

RESPONSE NOT OBTAINED BOP DOES THIS PAGE EXCEPT LAST STEP c. Remove the instrument power fuses at Power Range B drawer. _ IF rods will not move in manual, THEN adjust turbine load to maintain T -Ave at T-Ref. CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/11A155001016 Case IV 12 of 14 Power Range Malfunction Rev 24 ACTION/EXPECTED RESPONSE

a.

POW*lrfuse:i?l'flI' (l?qvy'er**RG1riY/?Ai:lt?wer.

RESPONSE NOT OBTAINED BOP DOES THIS PAGE EXCEPT LAST STEP .NOTEi fl.UtIjQrizatl{in of

10. b.

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c.

@apipet oJ

11.

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c. Remove the instrument power fuses at Power Range B drawer. _ IF rods will not move in manual, THEN adjust turbine load to maintain T at T-Ref.

CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A155001016 Case IV 13 of 14 Power Range Malfunction Rev 24 DCS ACTION/EXPECTED RESPONSE 13.

14

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__

i;§:ggg*Ii.l:@ngg11 19 RESPONSE NOT OBTAINED TS 3.3.1 Items 2a, 2b, 3, 6, 7, 16b, 16c 16d, 16e CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/Al5500/016 Case IV 13 of 14 Power Range Malfunction Rev 24 DCE ACTION/EXPECTED RESPONSE 13. WHEN

14.

15.

-'9.2.4.

-3.3.1 17{

18; WHEN

to'serviee, 19. peJe':J'l1lli RESPONSE NOT OBTAINED TS 3.3.1 Items 2a, 2b, 3, 6, 7, 16b, 16c 16d, 16e CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 -Page 1 of 1 14 of 14 Rev 24 P/R Bistables That Must Be Tripped CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 -Page 1 of 1 14 of 14 P/R Bistables That Must Be Tripped Rev 24 1.

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P;8 .i;P_9 EIT'§Jlre itJJ@J!gJ(CJWiiJg ijggrsr Initiating Cues:

1AD-5, AJ1, AJ4

1AD-1, F/4 Turbine load decreasing Initiating Cues:

1AD-5, AJ1, AJ4

1AD-1, F/4 Turbine load decreasing CNS LOAD REJECTION PAGE NO. AP/11A155001003 1 of 36 Rev 36 A. Purpose

To verify proper response in the event of a Load R*jection with Unit Tie Switchyard PCBs closed and the switchyard is available.

CASE II Switchyard Not Available:

To verify proper response in the event of a Load Rejection with all Unit Tie Switchyard PCBs open and/or the switchyard is not available, with the Unit carrying it's in-house loads. CNS LOAD REJECTION PAGE NO. AP/1/A/5500/003 1 of 36 Rev 36 A. Purpose

To verify proper response in the event of a Load R*jection with Unit Tie Switchyard PCBs closed and the switchyard is available.

CASE II Switchyard Not Available:

To verify proper response in the event of a Load Rejection with all Unit Tie Switchyard PCBs open and/or the switchyard is not available, with the Unit carrying it's in-house loads.

CNS LOAD REJECTION AP/1/A155001003

...... I'iIIIBJr-11MP'IIIII!8

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."'IM' $ .U,..-. CASE II Switchyard Not Available:

Switchyard not available AND:

1AD-1, F/4 "TURB RUNBACK INITIATED" -LIT

Turbine Generator megawatt output -RAPIDLY DECREASING

"C-7A LOSS OF LOAD INTLK COND DUMP" status light (1SI-18) -LIT * "C-7B LOSS OF LOAD INTLK ATMOS DUMP" status light (1SI-18) -LIT

Condenser or atmospheric steam dump valves -OPEN

Control rods -STEPPING IN. PAGE NO. 2of36 Rev 36 CNS LOAD REJECTION AP/1/A/55001003 B.Syinptoms I

anY'S,WitchyarClHUlitTie "

t0ri;llli: .. '

9fT:.

CASE" Switchyard Not Available:

Switchyard not available AND:

1AD-1, F/4 "TURB RUNBACK INITIATED" -LIT

Turbine Generator megawatt output -RAPIDLY DECREASING

"C-7A LOSS OF LOAD INTLK COND DUMP" status light (1SI-18) -LIT * "C-7B LOSS OF LOAD INTLK ATMOS DUMP" status light (1SI-18) -LIT

Condenser or atmospheric steam dump valves -OPEN

Control rods -STEPPING IN. PAGE NO. 2of36 Rev 36 CNS LOAD REJECTION PAGE NO. AP/1/Al5500/003 Case I 30f36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE c. Operator Actions IRO DOES THIS PAGE -0

',fQllows'D}

b. RESPONSE NOT OBTAINED Perform the following:

a. Select "MANUAL" on turbine control panel. b. Depress "CONTROL VALVES LOWER" pushbutton and reduce turbine load as required.

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Rods fail to work in AUTO a. IF T-Avg Coastdown is in progress, THEN determine T-Ref from table. REFER TO Enclosure 4 (T-Ref Value Following RunbackiPower Reduction).

b. Perform the following:

_ 1) Manually operate S/G PORVs as necessary to maintain T -Avg at T-Ref. _ 2) GO TO Step 4. CNS LOAD REJECTION PAGE NO. AP/1/A/5500/003 Case I 3 of36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE c. Operator Actions IRO DOES THIS PAGE -0 Verify DeggEA&It,lGJN o

et teactotres arise: \;;;;,I ," .'.' /;£1% p, " .. '" . . "v ... *** P... ,.',,,4,. . leCd'1r:ol rodsi+;"IN,"A1JTO"At:413

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NGf 3. Verify urti'RJ

foUows:t ¥Cerify T

b.

RESPONSE NOT OBTAINED Perform the following:

a. Select "MANUAL" on turbine control panel. b. Depress "CONTROL VALVES LOWER" pushbutton and reduce turbine load as required.

_

tom",intain:;i!,tAvg WiUnn Rods fail to work in AUTO I a. IF T-Avg Coastdown is in progress, THEN determine T-Ref from table. REFER TO Enclosure 4 (T-Ref Value Following RunbacklPower Reduction).

b. Perform the following:

_ 1) Manually operate S/G PORVs as necessary to maintain T -Avg at T-Ref. _ 2) GO TO Step 4.

CNS LOAD REJECTION PAGE NO. AP/1/Al5500/003 Case I 40f36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3. (Continued)

IRO DOES THIS PAGE c. d. c. IF steam dump valves are closed AND T-Avg is 3°F greater than T-Ref, THEN: _ 1) Place "STM DUMP CTRL" in manual. _ 2) Adjust "STM DUMP CTRL" to 0% demand. _ 3) Place the steam dumps in pressure mode. _ 4) Manually operate condenser steam dump valves to maintain T-Avg at T-Ref. _ 5) IF steam dump valves fail to operate, THEN dump steam as necessary from available S/G PORVs to maintain T-Avg at T-Ref. d. Perform the following:

_ 1) Place "STM DUMP CTRL" in manual. _ 2) Adjust "STM DUMP CTRL" to 0% demand. _ 3) Place the steam dumps in pressure mode. _ 4) Manually operate condenser steam dump valves to maintain T-Avg at T-Ref. _ 5) IF steam dump valves fail to operate, THEN dump steam as necessary from available S/G PORVs to maintain T-Avg at T-Ref. CNS LOAD REJECTION PAGE NO. AP/1 / Al5500/003 Case I 4of36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE 3. (Continued)

IRO DOES THIS PAGE

CONQ D RESPONSE NOT OBTAINED I c. IF steam dump valves are closed AND T-Avg is 3°F greater than T-Ref, THEN: _ 1) Place "STM DUMP CTRL" in manual. _ 2) Adjust "STM DUMP CTRL" to 0% demand. _ 3) Place the steam dumps in pressure mode. _ 4) Manually operate condenser steam dump valves to maintain T-Avg at T-Ref. _ 5) IF steam dump valves fail to operate, THEN dump steam as necessary from available S/G PORVs to maintain T-Avg at T-Ref. d. Perform the following:

_ 1) Place "STM DUMP CTRL" in manual. _ 2) Adjust "STM DUMP CTRL" to 0% demand. _ 3) Place the steam dumps in pressure mode. _ 4) Manually operate condenser steam dump valves to maintain T-Avg at T-Ref. _ 5) IF steam dump valves fail to operate, THEN dump steam as necessary from available S/G PORVs to maintain T-Avg at T-Ref.

CNS AP/11A155001003 ACTION/EXPECTED RESPONSE 4. LOAD REJECTION PAGE NO. 50f36 Case I Switchyard Available Rev 36 RESPONSE NOT OBTAINED P DOES THIS PAGE a. IF Pzr pressure is less than 2315 PSIG, THEN: _ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve. 3) IF Pzr PORV isolation valve cannot be closed, THEN: _ a) Trip reactor. _ b) GO TO EP/11A15000/E-0 (Reactor Trip Or Safety Injection).

b. IF Pzr pressure is less than 2260 PSIG, THEN: _ 1) Manually close the affected spray valve(s).

_ 2) REFER TO AP/11A155001011 (Pressurizer Pressure Anomalies).

b. GO TO Step 6. c. Manually start standby hotwell pump(s) as necessary.

d. Manually start standby condensate booster pump(s) as necessary.

CNS LOAD REJECTION PAGE NO. AP/1/A/55001003 Case I 50f36 Switchyard Available Rev 36 DCE ACTION/EXPECTED RESPONSE _ b;;

IEg'TPili1i1J (Q§21d!

JI3,EtEVEfilill fVefifCml"n'dbiholwellrufn

'(5) FOR _ ", .. d.

."".H""P,." RESPONSE NOT OBTAINED BOP DOES THIS PAGE a. IF Pzr pressure is less than 2315 PSIG, THEN: _ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve. 3) IF Pzr PORV isolation valve cannot be closed, THEN: _ a) Trip reactor. _ b) GO TO EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).

b. IF Pzr pressure is less than 2260 PSIG, THEN: _ 1) Manually close the affected spray valve(s).

_ 2) REFER TO AP/1/A/55001011 (Pressurizer Pressure Anomalies).

b. GO TO Step 6. c. Manually start standby hotwell pump(s) as necessary.

d. Manually start standby condensate booster pump(s) as necessary.

CNS AP/1/N55001003 ACTION/EXPECTED RESPONSE IRol?* LOAD REJECTION PAGE NO. 6 of 36 Case I Switchyard Available Rev 36 RESPONSE NOT OBTAINED _ Ensure turbine generator load -REDUCED TO APPROXIMATELY 48% AND THE ALARM CLEARS. Perform the following:

a. Ensure feedwater regulating valves -MODULATING TO CONTROL S/G LEVELS AT PROGRAM SETPOINT.

b. IF any S/G(s) N/R level is decreasing in an uncontrolled manner, THEN: _ 1) Trip reactor. _ 2) GO TO EP/1/N50001E-O (Reactor Trip Or Safety Injection).

CNS LOAD REJECTION PAGE NO. AP/1/A155001003 Case I 6 of 36 Switchyard Available Rev 36 OCt ACTION/EXPECTED RESPONSE fi36Pl6.

U PARt(1,: _.

A OVER I R 0 I 7 f91IcjIN§.; _

AfI'SZl3 RESPONSE NOT OBTAINED _ Ensure turbine generator load -REDUCED TO APPROXIMATELY 48% AND THE ALARM CLEARS. Perform the following:

a. Ensure feedwater regulating valves -MODULATING TO CONTROL S/G LEVELS AT PROGRAM SETPOINT.

b. IF any S/G(s) N/R level is decreasing in an uncontrolled manner, THEN: _ 1) Trip reactor. _ 2) GO TO EP/1/A15000IE-O (Reactor Trip Or Safety Injection).

CNS AP/1/A/55001003 ACTION/EXPECTED RESPONSE IRol a. RO LOAD REJECTION PAGE NO. Case I 70f36 Switchyard Available Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Place "CRD BANKSELECT"-switch -IN MANUAL. b. Maintain control rods above insertion limits. c. Operate control rods to stabilize reactor power between 6%-10%. d. IF AT ANY TIME reactor power is less than or equal to 5%, THEN perform the following:

_ 1} Ensure turbine -TRIPPED. _ 2} Concurrently insert control rods to shutdown the reactor. REFER TO OP/1/A/6150100a (Rod Control).

_ 3} GO TO AP/1/A/55001002 (Turbine Generator Trip). e. GO TO Step 10. _ Adjust 1AS-2 (Main Stm To Aux Steam) as required to maintain AS header pressure between 140 PSIG and 150 PSIG. Calculating boron for this is an ADMIN JPM on this exam. If they start to do it, then the next event should begin and the TS can be reviewed during followup.

CNS LOAD REJECTION PAGE NO. AP/1/A/55001003 Case I 70f36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE 9. _ 11. Nll>I1][t:9t RESPONSE NOT OBTAINED Perform the following:

a. Place "CRD BANKSELECT"-switch -IN MANUAL. b. Maintain control rods above insertion limits. c. Operate control rods to stabilize reactor power between 6%-10%. d. IF AT ANY TIME reactor power is less than or equal to 5%, THEN perform the following:

_ 1} Ensure turbine -TRIPPED. _ 2} Concurrently insert control rods to shutdown the reactor. REFER TO OP/1 IA/61501008 (Rod Control).

_ 3} GO TO AP/1/A/55001002 (Turbine Generator Trip). e. GO TO Step 10. _ Adjust 1AS-2 (Main Stm To Aux Steam) as required to maintain AS header pressure between 140 PSIG and 150 PSIG. Calculating boron for this is an ADMIN JPM on this exam. If they start to do it, then the next event should begin and the TS can be reviewed during followup.

CNS LOAD REJECTION PAGE NO. AP/1/A/55001003 Case I 8 of 36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE RO 13. 14. Verify the "RESET" light on "AMSAC FOR CF VALVES" switch -DARK. RESPONSE NOT OBTAINED _ 1) WHEN time and personnel permit, THEN perform applicable steps of OP/1/A/61 001003 (Controlling Procedure For Unit Operation).

_ 2) Do not continue in this procedure until reactor power is less than 30%. _ 3) WHEN reactor power is less than 30%, THEN GO TO Step 14. b Perform the following:

a. IF turbine impulse pressure is less than 190 PSIG, THEN notify IAE to correct the cause of the AMSAC failure to deactivate.

b. Depress the "BYPASS" pushbutton on "AM SAC FOR CF VALVES" switch. c. WHEN 2 minutes has elapsed, THEN verify "RESET" light on "AM SAC FOR CF VALVES" switch has remained dark. CNS LOAD REJECTION PAGE NO. AP/1/A/55001003 Case I 8 of 36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE l Ro l 13. 14. Verify the "RESET" light on "AM SAC FOR CF VALVES" switch -DARK. RESPONSE NOT OBTAINED

_ 1) WHEN time and personnel permit, THEN perform applicable steps of OP/1/A/61 001003 (Controlling Procedure For Unit Operation).

_ 2) Do not continue in this procedure until reactor power is less than 30%. _ 3) WHEN reactor power is less than 30%, THEN GO TO Step 14. b. WHENJheat2Jlfip'pr{§,tetllnb:aG.ktarget

_ 11Stabilizeuriit atlQurrent.pow¢r

_

rogs

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°F6f 1!1':Ref:

{Turi:>!t(ejoad rods -.j0ci'fcil;i;conMntratiOh.

_

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Perform the following:

a. IF turbine impulse pressure is less than 190 PSIG, THEN notify IAE to correct the cause of the AMSAC failure to deactivate.

b. Depress the "BYPASS" pushbutton on "AM SAC FOR CF VALVES" switch. c. WHEN 2 minutes has elapsed, THEN verify "RESET" light on "AMSAC FOR CF VALVES" switch has remained dark.

CNS AP/1/A/55001003 ACTION/EXPECTED RESPONSE LOAD REJECTION PAGE NO. Case I 90f36 Switchyard Available Rev 36 RESPONSE NOT OBTAINED When separated from the grid the turbine reverts to speed control. Perform the following:

a. IF both generator PCBs are open, THEN ensure main turbine speed -MAINTAINED BETWEEN 1792 AND 1807 RPM. b. IF the turbine generator is separated from the grid, THEN: _ 1) Ensure main turbine speed -MAINTAINED BETWEEN 1792 AND 1807 RPM. _ 2) Ensure main generator voltage -MAINTAINED BETWEEN 20.9 KV AND 23.1 KV. c. IF load rejection caused by loss of main busline 1A or 1 B, THEN: 1) Notify Transmission Control Center (TCC), using one of the following methods, to investigate and repair cause of the loss of busline:

704-382-9403

704-382-9404

704-399-9744

704-382-4413 (System Operating Center). _ 2) WHEN notified by TCC that the affected busline is ready to be re energized, THEN restore power to the affected busline. REFER TO Enclosure 1 (Offsite Power Restoration

). CNS LOAD REJECTION PAGE NO. AP/1/A/5500/003 Case I 9 of 36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE 16.

.. . *REFER RESPONSE NOT OBTAINED When separated from the grid the turbine reverts to speed control. Perform the following:

a. IF both generator PCBs are open, THEN ensure main turbine speed -MAINTAINED BETWEEN 1792 AND 1807 RPM. b. IF the turbine generator is separated from the grid, THEN: _ 1) Ensure main turbine speed -MAINTAINED BETWEEN 1792 AND 1807 RPM. _ 2) Ensure main generator voltage -MAINTAINED BETWEEN 20.9 KV AND 23.1 KV. c. IF load rejection caused by loss of main busline 1A or 1B, THEN: 1) Notify Transmission Control Center (TCC), using one of the following methods, to investigate and repair cause of the loss of busline:

704-382-9403

704-382-9404

704-399-9744

704-382-4413 (System Operating Center). _ 2) WHEN notified by TCC that the affected busline is ready to be re energized, THEN restore power to the affected busline. REFER TO Enclosure 1 (Offsite Power Restoration

).

CNS LOAD REJECTION AP/1/A/55001003 Case I Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Load rejection caused by loss of CF pump. PAGE NO. 10 of 36 Rev 36 CNS LOAD REJECTION AP/1/A/55001003 Case I Switchyard Available ACTION/EXPECTED RESPONSE 17. WHEN1lhe

_ *...

_.

rqd$aoqY,e

lrtlIlt§": .

m?ii 6t[3 in T -!\yglWitllitil q *. , TOlbine lo.\:iQi .:. '.C9]'ltrol

Boro ll Gori¢gt[ttEliii>.Q,:

1.8.

q$i)j9l!.he caUse9f.IOad RESPONSE NOT OBTAINED Load rejection caused by loss of CF pump. PAGE NO. 10 of 36 Rev 36 CNS LOAD REJECTION PAGE NO. AP/1/A/55001003 Case I 11 of 36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE _ 3} Shutdown one CF pump as necessary.

REFER TO OP/1/A/62501001 (Condensate and Feedwater System). _ 4} Shutdown excess Condensate Booster Pumps. REFER TO OP/1/A/62501001 (Condensate and Feedwater System). _ 5} Shutdown excess Hotwell Pumps. b. REFER TO OP/1/A/62501001 (Condensate and Feedwater System). RESPONSE NOT OBTAINED a. Perform the following:

_ 1} WHEN reactor power is stable, THEN perform Steps 21.b through 21.g. _ 2} GO TO Step 22. CNS LOAD REJECTION PAGE NO. AP/1/A155001003 Case I 11 of 36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE 20.

IBOP

\a)'

_ 3} Shutdown one CF pump as necessary.

REFER TO OP/1/A162501001 (Condensate and Feedwater System). _ 4} Shutdown excess Condensate Booster Pumps. REFER TO OP/1/A162501001 (Condensate and Feedwater System). _ 5} Shutdown excess Hotwell Pumps. REFER TO OP/1/A162501001 (Condensate and Feedwater System).

dijm;p I R 0 I _9;\

RESPONSE NOT OBTAINED a. Perform the following:

_ 1} WHEN reactor power is stable, THEN perform Steps 21.b through 21.g. _ 2} GO TO Step 22.

CNS LOAD REJECTION PAGE NO. AP/1/A155001003 Case I 12 of 36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 21. (Continued)

IRQ does this page b. c. b. Perform the following:

1) IF using S/G PORVs, THEN: _ a) WHEN T-Avg is within 1°F of T-Ref AND stable, THEN close S/G PORVs. _ b) GO TO Step 21.d. 2) WHEN T-Avg is within 1°F ofT-Ref AND stable, THEN: _ a) Ensure steam dumps -CLOSED. _ b) Perform Steps 21.d through 21.g. _ 3) GO TO Step 22. c. Perform the following:

_ 1) WHEN steam dump valves are closed, THEN perform Steps 21.d through 21.g. _ 2) GO TO Step 22. _ g. IF steam dumps are in "T-AVG" mode, THEN place "STM DUMP CTRL" in auto. CNS LOAD REJECTION PAGE NO. AP/1/A/5500/003 Case I 12 of 36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 21. (Continued)

IRQ does this page b.

-IN. "I:7f>.V:G" MGQE. _ d. . .Ii

'ff 'lIBwiii'is:r"Jl1iti ht e, '., e I Y';"'$ke.

.. Q *. ;h.., g, .* ,".9! J? ...... 9 ..... §

_

PYMPii _ 2JJi

b. Perform the following:

1) IF using S/G PORVs, THEN: _ a) WHEN T-Avg is within 1°F of T-Ref AND stable, THEN close S/G PORVs. _ b) GO TO Step 21.d. 2) WHEN T-Avg is within 1°F ofT-Ref AND stable, THEN: _ a) Ensure steam dumps -CLOSED. _ b) Perform Steps 21.d through 21.g. _ 3) GO TO Step 22. c. Perform the following:

_ 1) WHEN steam dump valves are closed, THEN perform Steps 21.d through 21.g. _ 2) GO TO Step 22. _ g. IF steam dumps are in "T-AVG" mode, THEN place "STM DUMP CTRL" in auto.

CNS LOAD REJECTION PAGE NO. AP/1/N5500/003 Case I 13 of 36 IBOP RO Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE 23.

24. 25. NotiU1, the following sections to take appropriate samples:

Radiation Protection to sample and analyze gaseous effluents.

REFER TO Selected Licensee Commitments Manual, Section 16.11-6.

Primary Chemistry to sample for isotopic analysis of iodine. REFER TO Tech Specs 3.4.16 (Sample must be taken between 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months following last power change greater than or equal to 15% rated thermal power within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period). 26.

RESPONSE NOT OBTAINED Transfer feed flow to CA nozzles. REFER TO Enclosure 2 (Transferring Feed Flow From CF To CA Nozzles).

Perform the following:

a. WHEN CA is no longer needed to feed S/G(s), THEN shutdown the CA System following the automatic start and return CA System to standby readiness.

REFER TO OP/1/N6250/002 (Auxiliary Feedwater System). b. Re-establish S/G blowdown.

REFER TO OP/1/N6250/008 (Steam Generator Slowdown).

Depending on how far they reduce power, this step may apply and they will do step 25. TS 3.1.6 Condition A (if rods are below LoLo insertion limits.) CNS LOAD REJECTION PAGE NO. AP/1/N5500/003 Case I 13 of 36 IBOP Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE 23.

ptdTlPs -

24. 25.

Notify the following sections to take appropriate samples:

Radiation Protection to sample and analyze gaseous effluents.

REFER TO Selected Licensee Commitments Manual, Section 16.11-6.

Primary Chemistry to sample for isotopic analysis of iodine. REFER TO Tech Specs 3.4.16 (Sample must be taken between 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months following last power change greater than or equal to 15% rated thermal power within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period). 26.

fiUfi'

_

.3.1.6 faDtfftbl'tBarnkH;'S'ertillln:m:'its" . '. .L.A" .**..*..**

".. " ..*....** . .*. * .. A .**. JLl .. ",,./. RESPONSE NOT OBTAINED Transfer feed flow to CA nozzles. REFER TO Enclosure 2 (Transferring Feed Flow From CF To CA Nozzles).

Periorm the following:

a. WHEN CA is no longer needed to feed S/G(s}, THEN shutdown the CA System following the automatic start and return CA System to standby readiness.

REFER TO OP/1/N6250/002 (Auxiliary Feedwater System). b. Re-establish S/G blowdown.

REFER TO OP/1/N6250/008 (Steam Generator Slowdown).

Depending on how far they reduce power, this step may apply and they will do step 25. TS 3.1.6 Condition A (if rods are below LoLo insertion limits.)

CNS LOAD REJECTION PAGE NO. AP/1/N55001003 Case I 14 of 36 Switchyard Available Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED CNS AP/1/A/55001003 ACTION/EXPECTED RESPONSE 27. :N9J!fy o{'

_ g:§:i LOAD REJECTION PAGE NO. Case I 14 of 36 Switchyard Available Rev 36 RESPONSE NOT OBTAINED Initiating Cue:

1AO-6 C/12, E/10, F-8 NC Pressure decreasing Initiating Cue:

1AO-6 C/12, E/10, F-8 NC Pressure decreasing eNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/AJ55001011 1 of 9 Rev 22 A. Purpose To ensure proper response in the event of abnormal Pressurizer pressure, assess plant conditions, and identify the appropriate steps for the following cases: Case I Pressurizer Pressure Decreasing Case II Pressurizer Pressure Increasing.

B. Symptoms Case II. Pressurizer Pressure Increasing:

1AD-6, D/8 "PZR LO PRESS ALERT" -LIT

1AD-6, C/8 "PZR HI PRESS DEV CONTROL" -LIT

1AD-6, B/8 "PZR HI PRESS" -LIT

Pressurizer pressure greater than 2235 PSIG and increasing

All Pzr heaters -ENERGIZED.

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/AJ55001011 1 of 9 Rev 22 A. Purpose To ensure proper response in the event of abnormal Pressurizer pressure, assess plant conditions, and identify the appropriate steps for the following cases: Case I Pressurizer Pressure Decreasing Case II Pressurizer Pressure Increasing.

B. Symptoms L po.av

'.

LIT e

': :U;lf e* \1:J\Q16;;AJB:\\I?;l:RlliIJiSf;?Rl;SS:J\trRTl'FLiT:

fi Allpzr

-t,;F ..

Case II. Pressurizer Pressure Increasing:

1AD-6, D/8 "PZR LO PRESS ALERT" -LIT

1AD-6, C/8 "PZR HI PRESS DEV CONTROL" -LIT

1AD-6, B/8 "PZR HI PRESS" -LIT

Pressurizer pressure greater than 2235 PSIG and increasing

All Pzr heaters -ENERGIZED.

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/5500/011 Case I 2of9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions BOP PORV will stick before it gets full closed. a. b. 2) IF the Pzr PORV isolation valve cannot be closed, THEN perform the following:

_ a) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/A/5500/027 (Shutdown LOCA). _ b) Trip reactor. _ c) WHEN reactor tripped OR S/I setpoint reached, THEN ensure S/I initiated.

_ d) GO TO EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/5500/011 Case I 2of9 Pressurizer Pressure Decreasing Rev 22 DeE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c. Operator Actions IsOp PORV will stick before it gets full closed. b. ifF

.'IT'HEN;ii

_ 1) isqU:UIg.Q¥:t!,llgt;

2) IF the Pzr PORV isolation valve cannot be closed, THEN perform the following:

_ a) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/A/5500/027 (Shutdown LOCA). _ b) Trip reactor. _ c) WHEN reactor tripped OR S/I setpoint reached, THEN ensure S/I initiated.

_ d) GO TO EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A15500/011 Case I 30f9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE _ 2.

IBOP RESPONSE NOT OBTAINED Perform the following:

a. Manually close affected spray valve(s).

b. IF affected spray valve(s) will not close, THEN perform the following:

1) IF AT ANY TIME the Control Room Supervisor determines that a reactor trip is required, THEN: _ a) Trip reactor. _ b) WHEN reactor power less than 5%, THEN stop NC Pumps 1A and 18. _ c) GO TO EP/1/A15000/E-O (Reactor Trip Or Safety Injection).

2) Select "FAIL CLOSED" for affected spray valve(s) mode select switch: * "1 NC-27 PZR SPRAY VLV MODE SELECT" * "1 NC-29 PZR SPRAY VLV MODE SELECT". _ 3) IF NC pressure is stable OR increasing, THEN GO TO Step 3. (RNO continued on next page) CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/55001011 Case I 30f9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE

)<;LOSEQ,;$

RESPONSE NOT OBTAINED Perform the following:

a. Manually close affected spray valve{s).

b. IF affected spray valve{s) will not close, THEN perform the following:

1) IF AT ANY TIME the Control Room Supervisor determines that a reactor trip is required, THEN: _ a) Trip reactor. _ b) WHEN reactor power less than 5%, THEN stop NC Pumps 1A and 1B. _ c) GO TO EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).

2) Select "FAIL CLOSED" for affected spray valve(s) mode select switch: * "1 NC-27 PZR SPRAY VLV MODE SELECT" * "1 NC-29 PZR SPRAY VLV MODE SELECT". _ 3) IF NC pressure is stable OR increasing, THEN GO TO Step 3. (RNO continued on next page)

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 Case I 40f9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 2. (Continued)

4) IF NC pressure continues to decrease, THEN: a) IF in Modes 1 or 2, THEN: _ (1) Trip reactor. _ (2) WHEN reactor power less than 5%, THEN stop NC Pumps 1A and 1 B. _ (3) GO TO EP/1/A15000/E-O (Reactor Trip or Safety Injection).

_ b) Stop NC Pumps 1A and 1 B. _ c) IF NC pressure continues to decrease, THEN stop additional NC pumps as required.

_ d) REFER TO AP/1/A155001004 (Loss of Reactor Coolant Pump). _ IF Pzr pressure is less than 2220 PSIG, THEN ensure all Pzr heaters are energized.

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 Case I 4 of 9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 2. (Continued)

IBOP 4) IF NC pressure continues to decrease, THEN: a) IF in Modes 1 or 2, THEN: _ (1) Trip reactor. _ (2) WHEN reactor power less than 5%, THEN stop NC Pumps 1A and 1 B. _ (3) GO TO EP/1/A15000/E-O (Reactor Trip or Safety Injection).

_ b) Stop NC Pumps 1A and 1 B. _ c) IF NC pressure continues to decrease, THEN stop additional NC pumps as required.

_ d) REFER TO AP/1/A155001004 (Loss of Reactor Coolant Pump). _ IF Pzr pressure is less than 2220 PSIG, THEN ensure all Pzr heaters are energized.

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/11A155001011 Case I 50f9 BOP Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE N<J'IlB 7.

perform following:

a. Verify "P-11 PZR SII BLOCK PERMISSIVE" status light (1 SI-18) in required state for unit conditions.

b. Notify IAE to fail following bistables for affected channel per Model W 10 #00874531.

Bistables shall be tripped within 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s:

Pzr low pressure S/I

OT Delta T

Pzr high pressure Reactor Trip

Pzr low pressure Reactor Trip. RESPONSE NOT OBTAINED _ IF pressure continues to decrease, THEN REFER TO AP/11A15500/01 0 (Reactor Coolant Leak). a. Ensure compliance with Tech Spec 3.3.2 (Engineered Safety Features Actuation System (ESFAS) I nstru mentation).

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/5500/011 Case I 5 of 9 Pressurizer Pressure Decreasing Rev 22 DC:: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NOTE Positive. _

at :l\J;!lqi'stJt1&KfollqWimgas T

_ .........

T

.,'1 CootrQlfo'gS;i

=

7.

perform following:

a. Verify "P-11 PZR S/I BLOCK PERMISSIVE" status light (1SI-18) in required state for unit conditions.

b. Notify IAE to fail following bistables for affected channel per Model W/O #00874531.

Bistables shall be tripped within 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s:

Pzr low pressure S/I

OT Delta T

Pzr high pressure Reactor Trip

Pzr low pressure Reactor Trip. _ IF pressure continues to decrease, THEN REFER TO AP/11A15500/010 (Reactor Coolant Leak). a. Ensure compliance with Tech Spec 3.3.2 (Engineered Safety Features Actuation System (ESFAS) Instrumentation).

CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A15500/011 Case I 6of9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE 8.

_ * .....

_*IBIIIJl

... . -.. .... __

_ ............

.., _II RESPONSE NOT OBTAINED TS 3.4.11 Condition B TS 3.4.1 Condition A (based on NC pressure at the time) CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/5500/011 Case I 6of9 Pressurizer Pressure Decreasing Rev 22 ACTION/EXPECTED RESPONSE 8.

T:¢ch _

1:(B.eactQji,Trip (RTS) fli1§lt!:Jrngntatidn

);

SSl§te'hl))

_ Jli

_

2) _

Ltflf9PS:::

_

_ *. @54: 11 (Pre?stirizer (PORVs}),: , (ReStO,,;, 0'e""['6+j'o' nar;'I)'0a' 17a""g""'e)'," _ """,.'<

..

c.

c 9. Determinelpngterm,planf,statll?

RETURN rnl RESPONSE NOT OBTAINED TS 3.4.11 Condition B TS 3.4.1 Condition A (based on NC pressure at the time)

SCENARIO 3 EVENT 6 DATA INITIATING CUE: 1AD-4 D/4 1AD-2 F/9 There was a Case 3 of AP/1/A/5500/00G but it was deleted as a result of the DCS modification.

There is no specific procedural guidance for this failure, other than OMP 1-8, step 7.2.C guidance which states: "When process control, process protection or safety signals are generated in response to valid plant conditions and equipment fails to automatically position, then a licensed operator is expected to properly position the equipment." Crew is expected to manually control valve 1Cf-55 to prevent a low S/G level reactor trip or a high SI<5 level T/G trip based on 1D S/G level. Once they have control and the SRO has consulted Technical Specifications, the Major Event will begin. TS 3.3.1, Item 13.e 3.3.2 Item 5.a.{2} Condition J, Item 5.b.{2} Condition D, Item G.b Condition D 33.3 Item 10 Conditions B, 0, F, alid II "Yt:-3.0.3 {due to two failed channels}

SCENARIO 3 EVENT 6 DATA INITIATING CUE: lAD-4 D/4 lAD-2 F/9 There was a Case 3 of AP/l/A/5500/006 but it was deleted as a result ofthe DCS modification.

There is no specific procedural guidance for this failure, other than OMP 1-8, step 7.2.C guidance which states: "When process control, process protection or safety signals are generated in response to valid plant conditions and equipment fails to automatically position, then a licensed operator is expected to properly position the equipment." Crew is expected to manually control valve lCf-55 to prevent a low S/G level reactor trip or a high S/G level T/G trip based on lD S/G level. Once they have control and the SRO has consulted Technical Specifications, the Major Event will begin. TS 3.3.1, Item 13.e ( 3.3.2 Item 5.a.{2) Condition J, Item 5.b.{2} Condition D, Item 6.b Condition D 3.3.3 Item 10 Conditions B, D, F, alid \I j?t:.-3.0.3 {due to two failed channels}

2nd CF Pump TRIPS. Containment pressure increasing NOTE: LOCA occurs on Rx Trip. 2nd CF Pump TRIPS. Containment pressure increasing NOTE: LOCA occurs on Rx Trip.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 1 of 61 Rev 36 A. Purpose This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of all Reactor Trips and S/I above P-11, valid S/I below P-11 and to assess plant conditions, and to identify the appropriate recovery procedure.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 1 of 61 Rev 36 A. Purpose This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of all Reactor Trips and 5/1 above P-11, valid 511 below P-11 and to assess plant conditions, and to identify the appropriate recovery procedure.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 2 of61 Rev 36 B. Symptoms or Entry Conditions

1. The following conditions are symptoms that require a Reactor Trip:

1 of 2 SIR channels -GREATER THAN 10 5 CPS WHILE BELOW P-6

1 of 2 I/R channels -GREATER THAN 25% FULL POWER AMPS EQUIVALENT WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 25% FULL POWER WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 109% FULL POWER

2 of 4 P/R channels -+5% FULL POWER IN 2 SECONDS

2 of 4 loop -GREATER THAN THE SETPOINT

2 of 4 loop Ts -GREATER THAN THE OT T SETPOINT

2 of 4 Pzr pressure channels -GREATER THAN 2385 PSIG

2 of 4 Pzr pressure channels -LESS THAN 1945 PSIG WHILE ABOVE P-7

2 of 3 Pzr level channels -GREATER THAN 92% WHILE ABOVE P-7

2 of 4 S/G N/R level channels on 1 of 4 S/Gs -LESS THAN LO-LO SETPOINT

2 of 4 NC pump buses -LESS THAN 77% OF NORMAL VOLTAGE (5082 VOLTS) WHILE ABOVE P-7

2 of 4 NC pump buses -LESS THAN 56 HERTZ WHILE ABOVE P-7

2 of 3 NC flow channels on 2 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-7 AND BELOW P-8

2 of 3 NC flow channels on 1 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-8

4 of 4 turbine stop valves -CLOSED WHILE ABOVE P-9

2 of 4 turbine stop valves EHC pressure -LESS THAN 550 PSIG WHILE ABOVE P-9

1 of 2 S/I trains -ACTUATED

2 of 2 SSPS trains -GENERAL WARNING ALARM. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 2 of 61 Rev 36 B. Symptoms or Entry Conditions

1. The following conditions are symptoms that require a Reactor Trip:

1 of 2 SIR channels -GREATER THAN 10 5 CPS WHILE BELOW P-6

1 of 2 I/R channels -GREATER THAN 25% FULL POWER AMPS EQUIVALENT WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 25% FULL POWER WHILE BELOW P-10

2 of 4 P/R channels -GREATER THAN 109% FULL POWER

2 of 4 P/R channels -+5% FULL POWER IN 2 SECONDS

2 of 4 loop -GREATER THAN THE SETPOINT

2 of41oop -GREATER THAN THE SETPOINT

2 of 4 Pzr pressure channels -GREATER THAN 2385 PSIG

2 of 4 Pzr pressure channels -LESS THAN 1945 PSIG WHILE ABOVE P-7

2 of 3 Pzr level channels -GREATER THAN 92% WHILE ABOVE P-7

2 of 4 S/G N/R level channels on 1 of 4 S/Gs -LESS THAN LO-LO SETPOINT

2 of 4 NC pump buses -LESS THAN 77% OF NORMAL VOLTAGE (5082 VOLTS) WHILE ABOVE P-7

2 of 4 NC pump buses -LESS THAN 56 HERTZ WHILE ABOVE P-7

2 of 3 NC flow channels on 2 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-7 AND BELOW P-8

2 of 3 NC flow channels on 1 of 4 NC loops -LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-8

4 of 4 turbine stop valves -CLOSED WHILE ABOVE P-9

2 of 4 turbine stop valves EHC pressure -LESS THAN 550 PSIG WHILE ABOVE P-9

1 of 2 SII trains -ACTUATED

2 of 2 SSPS trains -GENERAL WARNING ALARM.

CNS REACTOR TRIP OR SAFETY INJECTION EP/1/A15000/E-O

2. The following are symptoms of a Reactor Trip:

Any Reactor Trip annunciator

-LIT

Neutron level -RAPIDLY DECREASING

Rod bottom lights -LIT. 3. The following are symptoms that require a Reactor Trip and 5/1:

2 of 4 Pzr pressure channels -LESS THAN 1845 PSIG

2 of 3 containment pressure channels -GREATER THAN 1.2 PSIG. 4. The following are symptoms of a Reactor Trip and 5/1:

Any SII Reactor Trip annunciator

-LIT

NV, NI, and ND pumps -ON * "SAFETY INJECTION ACTUATED" status light (1SI-13) -LIT

E/S Load Sequencer Actuated status lights (1SI-14) -LIT. PAGE NO. 30f61 Rev 36 CNS REACTOR TRIP OR SAfETY INJECTION EP/1 I A/5000/E-O

2. The following are symptoms of a Reactor Trip:

Any Reactor Trip annunciator

-LIT

Neutron level -RAPIDLY DECREASING

Rod bottom lights -LIT. 3. The following are symptoms that require a Reactor Trip and 5/1:

2 of 4 Pzr pressure channels -LESS THAN 1845 PSIG

2 of 3 containment pressure channels -GREATER THAN 1.2 PSIG. 4. The following are symptoms of a Reactor Trip and 5/1:

Any SII Reactor Trip annunciator

-LIT

NV, NI, and ND pumps -ON * "SAFETY INJECTION ACTUATED" status light (1SI-13) -LIT

E/S Load Sequencer Actuated status lights (1SI-14) -LIT. PAGE NO. 30f61 Rev 36 CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP!1!Al5000!E-O ACTION/EXPECTED RESPONSE C. Operator Actions RO DOES THIS PAGE 1. RESPONSE NOT OBTAINED Perform the following:

a. Manually trip reactor. b. IF reactor will not trip, THEN concurrently:

4 of 61 Rev 36

Implement EP!1!Al5000!F-O (Critical Safety Function Status Trees) .

GO TO EP!1!Al5000!FR-S.1 (Response To Nuclear Power Generation!

A TWS). Perform the following:

a. Manually trip the turbine. b. IF turbine will not trip, THEN: _ 1) Depress the "MANUAL" pushbutton on the turbine control panel. _ 2) Rapidly unload turbine by simultaneously depressing the "CONTROL VALVE LOWER" and "FAST RATE" pushbuttons.

3) IF turbine will not runback, THEN close:

All MSIVs _

All MSIV bypass valves. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE C. Operator Actions IRO DOES THIS PAGE @ 'MerifY _

All _

_

G) _

RESPONSE NOT OBTAINED Perform the following:

a. Manually trip reactor. b. IF reactor will not trip, THEN concurrently:

4 of 61 Rev 36

Implement EP/1/A/5000IF-O (Critical Safety Function Status Trees) .

GO TO EP/1/A/5000/FR-S.1 (Response To Nuclear Power Generationl A TWS). Perform the following:

a. Manually trip the turbine. b. IF turbine will not trip, THEN: _ 1) Depress the "MANUAL" pushbutton on the turbine control panel. _ 2) Rapidly unload turbine by simultaneously depressing the "CONTROL VALVE LOWER" and "FAST RATE" pushbuttons.

3) IF turbine will not runback, THEN close:

All MSIVs

All MSIV bypass valves.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE -0 BOP DOES THIS PAGE 0..,...*-_ a. 1 ..... Auto SII is blocked on both channels.

Manual initiation required.

CRITICAL TASK! 50f61 Rev 36 DC!: RESPONSE NOT OBTAINED Perform the following:

a. IF 1 ETA AND 1 ETB are de-energized, THEN GO TO EP/1/A15000/ECA-O.O (Loss Of All AC Power). b. WHEN time allows, THEN attempt to restore power to de-energized switchgear while continuing with this procedure.

REFER TO AP/1/A15500/007 (Loss of Normal Power). _* .... **iiMM .. tIIIS .... _R .... 1lIIIitf.li'

...... 1IU111P1 3} IF S/I is not required, THEN concurrently:

_. Implement EP/1/A15000/F-O (Critical Safety Function Status Trees).

GO TO EP/1/A15000IES-O.1 (Reactor Trip Response).

b. Manually initiate S/I. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1 I A/SOOO/E-O I ACTION/EXPECTED RESPONSE BOP DOES THIS PAGE Auto SII is blocked on both channels.

Manual initiation required.

CRITICAL TASK! b. B6th E/S actuated.

IlIff. S of61 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. IF 1 ETA AND 1 ETB are de-energized, THEN GO TO EP/1/A/5000/ECA-O.O (Loss Of All AC Power). b. WHEN time allows, THEN attempt to restore power to de-energized switchgear while continuing with this procedure.

REFER TO AP/1/A/5S001007 (Loss of Normal Power). a.

the f6I1dWig:g:

t) VerifyconqiiiQiisreqllirjng

_ .' Pzr pressure

.1.

Q;R' _ 2) ma.nually)

SIL 3) IF S/I is not required, THEN concurrently:

Implement EP/1/A/SOOO/F-O (Critical Safety Function Status Trees) .

GO TO EP/1/A/SOOOIES-O.1 (Reactor Trip Response).

b. Manually initiate S/I.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE 8. a. b. 1 0

a. 6 of61 Rev 36 DC:: RESPONSE NOT OBTAINED Perform the following:

a. Manually initiate Feedwater Isolation.

b. IF proper status light indication is not obtained, THEN manually close valves. a. Manually initiate Phase A Isolation.

b. Manually align valves. a. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O IBOpl ACTION/EXPECTED RESPONSE REF BB,1il1(;),'iRP/07A1500Dl001" * ; (NBC

9. . Vjfrift:'8hai;e'"A lContalhtrienOJ$6Jc:ltiot\'

b.

LIT;.

.... , ... .. a.

6 of 61 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Manually initiate Feedwater Isolation.

b. IF proper status light indication is not obtained, THEN manually close valves. a. Manually initiate Phase A Isolation.

b. Manually align valves. iROTE:

NQAlix'

_

FLQ¥\li _

THEN .B!solation s'f' (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A1S000/E-O ACTION/EXPECTED RESPONSE 10. (Continued) 7of61 Rev 36 RESPONSE NOT OBTAINED --_e

.. _ d) e) ...."... __ ** IiflBDperform the following for the affected train(s):

_ (1) Reset ECCS. _ (2) Reset DIG load sequencer.

_ (3) Manually start affected NS pump. _ (4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. _ S) M *** ,..i,. _6) ....... ... _ 7) ...... 1IIIIlI (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTIONIEXPECTED RESPONSE 10. (Continued)

BO 7 of 61 Rev 36 RESPONSE NOT OBTAINED 4)

Ph g se:'&lUS:9Iation

_ aI, Ug,bts':;PARK;

_ b)

Ji§bts are lit, THEN':rjjanuat!y Phase B Isdla,tion, c) Vefityfollowingr:tl9hitqr 1Ig111\ panelligbts

-LIT: -Gfoupl Sp lights -Gt9uP 5 Sp Iigl1J$: -@X,:oup 5SrUg'hts U11.a,)ll:g I1Zil 2. ,j!,v, e) IFNSpUrop{S) did hotstaJiM THEN perform the following for the affected train(s):

_ (1) Reset ECCS. _ (2) Reset DIG load sequencer.

_ (3) Manually start affected NS pump. _ (4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. _ 6) tlpW. _

igQU¢rs,,;: (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O ACTIONIEXPECTED RESPONSE 10. (Continued)

b. IF AT ANY TIME containment pressure exceeds 3 PSIG while in this procedure, THEN perform Step 10.a.

8 of 61 Rev 36 DCS RESPONSE NOT OBTAINED a. Perform the following for the affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected motor driven CA pump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. b. Ensure CA Pump #1 -RUNNING. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 ACTION/EXPECTED RESPONSE 10. (Continued)

b. IF AT ANY TIME containment pressure exceeds 3 PSIG while in this procedure, THEN perform Step 10.a. 11. V,erity

a.

driv@ll b.;3 $JG N/R1foYels 8 of 61 Rev 36 RESPONSE NOT OBTAINED 8

_ 9)

a. Perform the following for the affected train(s):

_ 1) Reset ECCS. _ 2) Reset D/G load sequencer.

_ 3) Manually start affected motor driven CA pump. _ 4) IF AT ANY TIME a B/O occurs, THEN restart S/I equipment previously on. b. Ensure CA Pump #1 -RUNNING.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE -. 14. BOP DOES THIS PAGE 90f61 Rev 36 DC:: RESPONSE NOT OBTAINED Perform the following for affected train{s):

a. R.eset ECCS. b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. Perform the following for affected train{s):

a. Reset ECCS. b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. Perform the following:

a. IF any Unit 2 RN pump is off, THEN manually start affected pump(s). b. IF any Unit 1 RN pump is off, THEN perform the following for affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected pump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTIONIEXPECTED RESPONSE 12.

tlJ.@JoU6)f,£ingS£lpum'i>s

ON.: BOP DOES THIS PAGE 14 V,er*.fy;a*

11***tJ**

n**.t [if.'

d ,1:I."n*****'12*

R.:.:r *.... u' 'm'" .. *5***.* .* '. * . . . .' . . . .........

".. ...PI P .... "J?

15 V Yi"".f!"'rh"Y*iyehlilaU6niSystems . 1*.:JJtQt!.@Ji:....................

........ ..*......**..

i<._ .. _

Ii 'NollP';Unmez:Q' efalor to}erfol':

...* _ ""'N').'i.. . ...........

P .........

..J? ...... OJ';

9 of 61 Rev 36 RESPONSE NOT OBTAINED Perform the following for affected train{s):

a. R.eset ECCS. b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. Perform the following for affected train{s):

a. Reset ECCS. b. Reset DIG load sequencer.

c. Manually start affected pump. d. IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. Perform the following:

a. IF any Unit 2 RN pump is off, THEN manually start affected pump(s). b. IF any Unit 1 RN pump is off, THEN perform the following for affected train(s):

_ 1) Reset ECCS. _ 2) Reset DIG load sequencer.

_ 3) Manually start affected pump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 ACTION/EXPECTED RESPONSE 16. RO 17.

_ a.

10 of 61 Rev 36 RESPONSE NOT OBTAINED Perform the following:

a. Verify the following valves -CLOSED:

All MSIVs _

All MSIV bypass valves

All S/G PORVs. b. IF any valve is open, THEN: _ 1) Manually initiate Main Steam Isolation.

_ 2) IF any valve is still open, THEN manually close valve. a. Manually start NV pump(s) and align valves. b. Perform the following:

_ 1) Ensure ND pump miniflow valve on operating ND pump(s) -OPEN. 2) IF ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop ND pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart S/I equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. _ 3) GO TO Step 18. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE 16.

TIifAN .775 10 of 61 Rev 36 DCS RESPONSE NOT OBTAINED Perform the following:

a. Verify the following valves -CLOSED:

All MSIVs _

All MSIV bypass valves

All S/G PORVs. b. IF any valve is open, THEN: _ 1) Manually initiate Main Steam Isolation.

_ 2) IF any valve is still open, THEN manually close valve. a. Manually start NV pump(s) and align valves. b. Perform the following:

_ 1) Ensure ND pump miniflow valve on operating ND pump(s) -OPEN. 2) IF ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):

_ a) Reset ECCS. _ b) Reset D/G load sequencer.

_ c) Stop ND pump. _ d) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. _ 3) GO TO Step 18.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE 17. (Continued)

IBOP 1_ c. d. IBOP 11 of 61 Rev 36 RESPONSE NOT OBTAINED c. Manually start NI pump(s) and align valves. d. Perform the following:

_ 1) Ensure NO pump miniflow valve on operating NO pump(s) -OPEN. 2) IF the NO pump miniflow valve(s) cannot be opened, THEN perform the following for affected train{s):

_ a) Reset ECCS. _ b) Reset O/G load sequencer.

_ c) Stop NO pump. _ d) IF AT ANY TIME a B/O occurs, THEN restart S/I equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the NO pump. _ 3) GO TO Step 18. e. Manually start NO pump{s) and align valves. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE 17. (Continued)

IBOP I _

FLOW.: e.

11 of 61 Rev 36 OCt RESPONSE NOT OBTAINED c. Manually start NI pump{s) and align valves. d. Perform the following:

_ 1) Ensure ND pump miniflow valve on operating ND pump{s) -OPEN. 2) IF the ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train{s):

_ a) Reset ECCS. _ b) Reset DIG load sequencer.

_ c) Stop ND pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart S/I equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. _ 3) GO TO Step 18. e. Manually start ND pump(s) and align valves.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 IBOP 19.

IBOP I 20.

12 of 61 Rev 36 DC:: a. Perform the following:

_ 1) IF N/R level in all S/Gs is less than 11 % (29% ACC), THEN manually start CA pumps and ensure correct valve alignment.

2) IF N/R level in all S/Gs is less than 11 % (29% ACC) AND feed flow greater than 450 GPM cannot be established, THEN concurrently:

Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).

GO TO EP/1/A/5000/FR-H.1 (Response To Loss Of Secondary Heat Sink). _ Manually open valve{s).

_ Manually align equipment.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-0 Isop Isop " _

b.

NfR

19.

va{2es .. QPEN. <="Is-=-o-=-p

--'1 20 . Verify

'Of;i' 12 of 61 Rev 36 DC:: a. Perform the following:

_ 1) IF N/R level in all S/Gs is less than 11 % (29% ACC), THEN manually start CA pumps and ensure correct valve alignment.

2) IF N/R level in all S/Gs is less than 11 % (29% ACC) AND feed flow greater than 450 GPM cannot be established, THEN concurrently:

Implement EP/11A15000/F-0 (Critical Safety Function Status Trees) .

GO TO EP/11A15000/FR-H.1 (Response To Loss Of Secondary Heat Sink). _ Manually open valve(s).

_ Manually align equipment.

NO"fE IRo 2"-IC<mtrpl?NC leXnpe'ra,lure.

REFER;l\O Con,trQ!p CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE Should already have isolated a PORV per AP/11 earlier. May not perfrom RNO even though PORV is still open, since it IS isolated.

13 of 61 Rev 36 RESPONSE NOT OBTAINED 3} IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:

_ a} Energize H2 igniters.

b} Dispatch operator to perform the following:

_ (1) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ (2) Place containment H2 analyzers in service. REFER TO OP/1/A/6450/010 (Containment Hydrogen Control Systems). (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O ACTION/EXPECTED RESPONSE Should already have isolated a PORV per AP/11 earlier. May not perfrom RNO even though PORV is still open, since it IS isolated.

13 of 61 Rev 36 RESPONSE NOT OBTAINED a.

2315 PSIG, THEN: ' _ /1)

P<qRV( s). :2,)

bei¢lqpect;.:

3) IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:

_ a) Energize H2 igniters.

b) Dispatch operator to perform the following:

_ (1) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ (2) Place containment H2 analyzers in service. REFER TO OP/1 IAl6450!O 1 0 (Containment Hydrogen Control Systems). (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0

22. (Continued)

Isop c. IRO I 23.

NC Pumps may have been previously tripped based on loss of support equipment due to Sp 14 of 61 Rev 36 DCE c) IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). d) Concurrently:

Implement EP/1/A15000/F-0 (Critical Safety Function Status Trees).

GO TO EP/1/A15000/E-1 (Loss Of Reactor Or Secondary Coolant).

b. IF Pzr pressure is less than 2260 PSIG, THEN: _ 1) Manually close spray valve(s).

2) IF spray valve(s) cannot be closed, THEN: _ a) Stop NC pumps 1A and 1B. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required.

c. IF power is available, THEN open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP 111 A/5000/E-0 AClI ON/EX P ECPEO RES P ON St\¥k 22. (Continued)

IBOP IBOP IRO I 23.

OPi::N; \Ii *. ',Fi.' N C; ""b': r,v')b""" d" ',W .* ".... .*Hi**,*""t "

.. ' :§*Y""cQQ

...

NC Pumps may have been previously tripped based on loss of support equipment due to Sp 14 of 61 Rev 36 c) IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). d) Concurrently:

Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).

GO TO EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant).

b. IF Pzr pressure is less than 2260 PSIG, THEN: _ 1) Manually close spray valve(s).

2) IF spray valve(s) cannot be closed, THEN: _ a) Stop NC pumps 1A and 18. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required.

c. IF power is available, THEN open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV.

THEN':' _

qfF, 'ii.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O

24. IRa Isop ACTION/EXPECTED RESPONSE 15 of 61 Rev 36 RESPONSE NOT OBTAINED IF pressure in any S/G is decreasing in an uncontrolled manner OR any S/G is depressurized, THEN perform the following:

a. IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). b. Concurrently:

Implement EP/1/A/5000/F-O (Critical Safety Function Status Trees).

GO TO EP/1/A/5000/E-2 (Faulted Steam Generator Isolation).

IF any EMF trip 1 light is lit OR any S/G level is increasing in an uncontrolled manner, THEN concurrently:

Implement EP/1/A/5000/F-O (Critical Safety Function Status Trees) .

GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O ACTION/EXPECTED RESPONSE 24 f6l1owsj) _

og _

_ *

1, 1

1

_

15 of 61 Rev 36 RESPONSE NOT OBTAINED IF pressure in any S/G is decreasing in an uncontrolled manner OR any S/G is depressurized, THEN perform the following:

a. IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). b. Concurrently:

Implement EP/1/A/5000/F-O (Critical Safety Function Status Trees).

GO TO EP/1/A/5000/E-2 (Faulted Steam Generator Isolation).

IF any EMF trip 1 light is lit OR any S/G level is increasing in an uncontrolled manner, THEN concurrently:

Implement EP/1/A/5000/F-O (Critical Safety Function Status Trees).

GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-O ACTION/EXPECTED RESPONSE 26. 16 of 61 Rev 36 DCE RESPONSE NOT OBTAINED 2) IF the valve for the affected NC pump will not close, THEN perform the following:

_ a) Trip all NC pumps. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-O Isop ACTION/EXPECTED RESPONSE a.

Je' 1 KqG,!;JTLET;:;P1J1L

fli9Yi"" _'. e .

fiLOW;! _

il3l\RRIERllSq\Q\QJ'Ifi::iE:!;:IIILQ fiJ!.OW".

_ }4 ),1

13l\RRI,ERiKC Qt:JTLET"P1!!LQ' fUi.9W'!,1 16 of 61 Rev 36 RESPONSE NOT OBTAINED a.

lhetcml{5,Wirig:

_

Pump<1ATher'm}

_ (N,Gj=?ump 113 Themf fBatOllt)

_ ':"i

{Nq:fE?l:Imp1 BarQt!U _

r>Tf"\erm iBar<:>tIt).

2) IF the valve for the affected NC pump will not close, THEN perform the following:

_ a) Trip all NC pumps. (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A1S000/E-O ACTION/EXPECTED RESPONSE 26. (Continued) 17 of 61 Rev 36 RESPONSE NOT OBTAINED b) Perform the following:

_ (1) Dispatch operator with radio to standby at 1 KC-42SA (NC Pumps Ret Hdr Cont Isol) (AB-S88, GG-S2, Rm 419) (Ladder needed). _ (2) Close 1 KC-42SA (NC Pumps Ret Hdr Cont Isol) from Control Room. _ (3) IF 1 KC-42SA (NC Pumps Ret Hdr Cont Isol) will not close completely from Control Room, THEN have operator locally close 1 KC-42SA (NC Pumps Ret Hdr Cont Isol) (AB-S88, GG-S2, Rm 419). _ (4) WHEN 1 KC-42SA (NC Pumps Ret Hdr Cont Isol) has been closed, THEN close 1 KC-424B (NC Pumps Ret Hdr Cont Isol). _ (S) WHEN 1 KC-42SA (NC Pumps Ret Hdr Cont Isol) is closed, THEN notify the dispatched operator to return. (6) Close the following valves:

1 KC-338B (NC Pumps Sup Hdr Cont Isol)

1 KC-430A (Rx Bldg Drn Hdr Cont Isol)

1 KC-429B (Rx Bldg Drn Hdr Cont Isol). CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-O ACTION/EXPECTED RESPONSE 26. (Continued) 17 of 61 Rev 36 RESPONSE NOT OBTAINED b) Perform the following:

_ (1) Dispatch operator with radio to standby at 1 KC-42SA (NC Pumps Ret Hdr Cant 1501) (AB-S88, GG-S2, Rm 419) (Ladder needed). _ (2) Close 1 KC-42SA (NC Pumps Ret Hdr Cant Isol) from Control Room. _ (3) IF 1 KC-42SA (NC Pumps Ret Hdr Cant Isol) will not close completely from Control Room, THEN have operator locally close 1 KC-42SA (NC Pumps Ret Hdr Cant Isol) (AB-S88, GG-S2, Rm 419). _ (4) WHEN 1 KC-42SA (NC Pumps Ret Hdr Cant 1501) has been closed, THEN close 1 KC-424B (NC Pumps Ret Hdr Cant Isol). _ (S) WHEN 1 KC-42SA (NC Pumps Ret Hdr Cant Isol) is closed, THEN notify the dispatched operator to return. (6) Close the following valves:

1 KC-338B (NC Pumps Sup Hdr Cant Isol)

1 KC-430A (Rx Bldg Drn Hdr Cant Isol)

1 KC-429B (Rx Bldg Drn Hdr Cant Isol).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 ACTIONIEXPECTED RESPONSE 26. (Continued)

_. IF normal off-site power is available, THEN verify containment pressure less than 0.3 PSIG.

Containment high range EMFs -LESS THAN 3 RlHR: _. 1 EMF-53A (Containment Trn A) _. 1 EMF-538 (Containment Trn 8).

Containment EMF trip 1 DARK:

1 EMF-38 (Containment Particulate)

1 EMF-39 (Containment Gas) 27. Verify 511 termination criteria as follows: a. NC subcooling based on core exit TICs -GREATER THAN OaF. 18of61 Rev 36 RESPONSE NOT OBTAINED _ 1)

3) IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). a. GO TO Step 28. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-0 ACTION/EXPECTED RESPONSE 26. (Continued)

b. VefifS1;NC

TH&N 1.

IF normal off-site power is available, THEN verifY containment pressure less than 0.3 PSIG.

Containment high range EMFs -LESS THAN 3 RlHR: _. 1 EMF-53A (Containment Trn A) _. 1 EMF-S38 (Containment Trn 8).

Containment EMF trip 1 DARK:

1 EMF-38 (Containment Particulate)

1 EMF-39 (Containment Gas) *

27. Verify 511 termination criteria as follows: a. NC subcooling based on core exit TICs -GREATER THAN OaF. 18 of 61 Rev 36 RESPONSE NOT OBTAINED b _ 1

2)

_ a) iq? t;!§pdlinglWlil$1

REFER TOl t,titi2Iq$tJrEF13 (Sepuril1g All. Ice

): _ b)

H2 <;iMlyzer§ t* "i\' 'ii,),Y r;SI ;, Ys ems,:: 3) IF both the following conditions exist,

Containment pressure -GREATER THAN 1 PSIG

Containment pressure -HAS REMAINED LESS THAN 3 PSIG _ THEN manually start one VX fan. REFER TO Enclosure S (VX Fan Manual Start). 4 )

(

Tm¢§l*

GOTO EP/1 1 {Loss

a. GO TO Step 28.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 -Page 1 of 1 32 of 61 Foldout Page Rev 36 DC:: 1. IF any S/G(s) suspected ruptured, THEN perform the following:

WHEN the following conditions met:

Total CA flow -GREATER THAN 450 GPM AND

All intact S/G{s) N/R level-GREATER THAN 11%{29% ACC) THEN throttle feed flow to ruptured S/G{s) to maintain ruptured S/G{s) N/R level between 11 %(29% ACC) and 39%. 2. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NVor NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO O°F. 3. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO AP/1/A155001006 (Loss of S/G Feedwater):

1AD-5, H/4 "CACST LO LEVEL" OR

1AD-8, B/1 "UST LO LEVEL". 5. Cold Leg Recirc Switchover Criterion:

IF FWST level decreases to 37% (1AD-9, D/8 "FWST 2/4 LO LEVEL" lit), AND an SII has occurred, THEN GO TO EP/1/A15000/ES-1.3 (Transfer To Cold Leg Recirculation).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 -Page 1 of 1 32 of 61 Foldout Page Rev 36 1. IF any S/G(s) suspected ruptured, THEN perform the following:

WHEN the following conditions met:

Total CA flow -GREATER THAN 450 GPM

All intact S/G(s) N/R level -GREATER THAN 11 %{29% ACC) THEN throttle feed flow to ruptured S/G(s) to maintain ruptured S/G(s) N/R level between 11 %(29% ACC) and 39%. 2. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NV or NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO OaF. 3. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO AP/1/A15S001006 (Loss of S/G Feedwater):

1AD-S, H/4 "CACST LO LEVEL" OR

1AD-8, 8/1 "UST LO LEVEL". !l,> . 'ressure is;lesstha'ilil150mPSTGiANDNViSlJ:.flow*

ath is ali 'oed THENGI.(j)'se 1 Nv.::202B\

.* U., P. . .... ,.. .... ,.. ...... . .. """' *. '" A.,,,.,,,.

,_ ..**. ,.,*.c.c"u.*

..... P.... .' ........ g.. 1 _._ .. _

'. h." ... .

THEN 0 1NV-2,@'3A.

.. d.* %, . g v."" £;;' ....... M . ..*.*. ',--P ... ",,* ... iT"iiY= *. , .*.*.. .JJ., .... , .... ,' S. Cold Leg Recirc Switchover Criterion:

IF FWST level decreases to 37% (1AD-9, D/8 "FWST 2/4 LO LEVEL" lit), AND an S/I has occurred, THEN GO TO EP/1/A1S000/ES-1.3 (Transfer To Cold Leg Recirculation).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 1 of 7 33 of 61 Ventilation System Verification Rev 36 DeE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED :. BOP DOES THIS ENCLOSU a. Perform the following:

_ 1) Shift operating VCIYC trains. REFER TO Enclosure 6 (Shifting Operating VCIYC Train). 2) IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:

OP/OIAl64501011 (Control Room Area Ventiiation/Chilied Water System)

EM/OIAl52001001 (Troubleshooting Cause For Improper Operation of VCIYC System). CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O -Page 1 of 7 330f61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE @:; 'jI bij;eX(rain'ljfitheJgllowing'j eQl1ljpmelitjs.in

';y,;C,chiUe:ti

RESPONSE NOT OBTAINED IBOP DOES THIS ENCLOSURE

a. Perform the following:

_ 1) Shift operating VCIYC trains. REFER TO Enclosure 6 (Shifting Operating VCIYC Train). 2) IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:

OP/O/A16450/011 (Control Room Area Ventilation/Chilled Water System)

EM/O/A15200/001 (Troubleshooting Cause For Improper Operation of VCIYC System).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 2 of 7 34 of 61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1. (Continued)

b.

b. IF chlorine odor is detected in the Control Room, THEN perform the following based on the status of given alarms: 1) IF detectors on both unit intakes are in alarm, THEN: a) Ensure the following VC intake dampers -CLOSED:

1VC-58 (CRA Filt Inlet)

1VC-6A (CRA Filt Inlet)

2VC-58 (CRA Filt Inlet)

2VC-6A (CRA Filt Inlet). _ b) GO TO Step 1.d. 2) IF Unit 1 intake HI chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). b) Ensure the following dampers -OPEN: _. 2VC-58 (CRA Filt Inlet) _. 2VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-O -Page 2 of 7 34 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 1. (Continued) thefoUgyving;;glarrrl's

-

_

CIrfJ,109 i INB'11BY ,.,i\,.

/,' ',. ,:-:;t;,,;

_ *j1 RESPONSE NOT OBTAINED b. IF chlorine odor is detected in the Control Room, THEN perform the following based on the status of given alarms: 1) IF detectors on both unit intakes are in alarm, THEN: a) Ensure the following VC intake dampers -CLOSED: _. 1VC-S8 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet) _

2VC-S8 (CRA Filt Inlet) _. 2VC-6A (CRA Filt Inlet). _ b) GO TO Step 1.d. 2) IF Unit 1 intake HI chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 1VC-S8 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). b) Ensure the following dampers -OPEN: _. 2VC-S8 (CRA Filt Inlet) _. 2VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d. (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EPI1IN5000/E-O -Page 3 of 7 35 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 1. (Continued)

-=i--i>i'i-i J iMi'i"i@i'i"'i*ilalll" -. -. *

........ , .. , .... ... _ *IIBIJJItIIIleI

.... +B .. . RESPONSE NOT OBTAINED 3) IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 2VC-58 (CRA Filt Inlet) _. 2VC-6A (CRA Filt Inlet). b) Ensure the following OPEN: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O -Page 3 of 7 35 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 1. (Continued) ve

_ ;;'41 VC-58

_e FHtlnlet) _

_ *'4 V Ce9A{CRA as folloWs:.

_ ir AnY timelYCIYCrelalgaannu!,)pjators RESPONSE NOT OBTAINED 3) IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN: a) Ensure the following VC dampers -CLOSED: _. 2VC-58 (CRA Filt Inlet) _

2VC-6A (CRA Filt Inlet). b) Ensure the following OPEN: _. 1VC-58 (CRA Filt Inlet) _. 1VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d.

CNS REACTOR TRIP OR SAFETY INJECTION EP/1/Al5000/E-O -Page 4 of 7 2. Ventilation System Verification ACTION/EXPECTED RfSPONSE *"IfDJIIIIJ..... , .. --..... _ ...... *eIl!allllWRIIIIIaII."!Mi lIIBJa -*8IBII:lItllllBl.

W'1V1II _ ...... _ * ...-p, RESPONSE NOT OBTAINED PAGE NO. 36 of 61 Rev 36 DCE CNS REACTOR TRIP OR SAFETY INJECTION EP/1/A/5000/E-O -Page 4 of 7 Ventilation System Verification ACTION/EXPECTED RfSPONSE 2.

f9 U o W S:

the.

(s] fQIJQwsl*

& tQ.(VA

".CLOSE:!:}

. 1 20(Vt.

CEQSSliU RESPONSE NOT OBTAINED PAGE NO. 36 of 61 Rev 36 DC!:

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 -Page 5 of 7 37 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED a. Manually start fan{s}. b. b. Perform the following:

1} IF annulus pressure is more positive than -1.4 in. WC, THEN: a} Verify flow indicated on the following indications:

"VE 1 A FLOW TO STACK" * "VE 18 FLOW TO STACK". b} IF flow is not indicated, THEN dispatch operator to verify status of the following dampers based on their local indication or their operating piston rods being extended 4" to 6":

1AVS-D-2 (VE A Trn Recirc Damp) (AB-603, JJ-51 , Rm 500) -CLOSED

1AVS-D-7 (VE B Trn Recirc Damp) (AB-603, HH-52, Rm 500) -CLOSED

1AVS-D-3 (VE A Trn Exh Damp) (AB-603, JJ-52, Rm 500) -OPEN

1AVS-D-8 (VE B Trn Exh Damp) (AB-603, HH-52, Rm 500) -OPEN. _ c} Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A152001002 (Troubleshooting Cause For VE System Hillo Pressure).

_ d} GO TO Step 3.c. (RNO continued on next page) CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 -Page 5 of 7 37 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 3 at Q,ti:/:' b.

,1 3 41 ti\l!1W.9ANm,,.1.8JIN.

'Wf!+l RESPONSE NOT OBTAINED a. Manually start fan(s). b. Perform the following: 1 ) IF annulus pressure is more positive than -1.4 in. WC, THEN: a) Verify flow indicated on the following indications:

"VE 1 A FLOW TO STACK" * "VE 18 FLOW TO STACK". b) IF flow is not indicated, THEN dispatch operator to verify status of the following dampers based on their local indication or their operating piston rods being extended 4" to 6":

1AVS-D-2 (VE A Trn Recirc Damp) (AB-603, JJ-51 , Rm 500) -CLOSED

1 AVS-D-7 (VE B Trn Recirc Damp) (AB-603, HH-52, Rm 500) -CLOSED

1AVS-D-3 (VE A Trn Exh Damp) (AB-603, JJ-S2, Rm 500) -OPEN

1AVS-D-8 (VE B Trn Exh Damp) (AB-603, HH-52, Rm 500) -OPEN. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A/5200/002 (Troubleshooting Cause For VE System HilLo Pressure).

_ d) GO TO Step 3.c. (RNO continued on next page)

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O -Page 6 of 7 38 of 61 Ventilation System Verification Rev 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3. (Continued)

c. 2) IF annulus pressure is more negative than -1.8 in. WC, THEN: _ a) Determine which VE train indicates highest discharge flow to stack. _ b) Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , ensure VE train that indicates highest discharge flow to stack is secured. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/N5200/002 (Troubleshooting Cause For VE System Hillo Pressure).

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O Enclosure 2 -Page 6 of 7 38 of 61 Rev 36 Ventilation System Verification ACTION/EXPECTED RESPONSE 3. (Continued)

c.

RESPONSE NOT OBTAINED 2) IF annulus pressure is more negative than -1.8 in. WC, THEN: _ a) Determine which VE train indicates highest discharge flow to stack. _ b) Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , ensure VE train that indicates highest discharge flow to stack is secured. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A/5200/002 (Troubleshooting Cause For VE System Hillo Pressure).

CNS REACTOR TRIP OR SAFETY INJECTION EP/11 NSOOO/E-O -Page 7 of 7 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 4. Record time ventilation systems are verified on following table: TIME SYSTEM eve, VE) INITIALS PAGE NO. 39 of 61 Rev 36 CNS REACTOR TRIP OR SAFETY INJECTION EP/1 I NSOOO/E-O -Page 7 of 7 Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 4. Record time ventilation systems are verified on following table: TIME SYSTEM (V(, VE) INITIALS PAGE NO. 39 of 61 Rev 36 DeS CNS REACTOR TRIP OR SAFETY INJECTION EP/1/N5000/E-O -Page 1 of 4 NC Temperature Control ACTION/EXPECTED RESPONSE IRO DOES THIS ENCLOSURE

2. Use NC T-Avg to determine NC temperature as required in subsequent steps. 3. IF AT ANY TIME NC pumps are tripped, THEN use NC T-Colds to determine NC temperature as required in subsequent steps. 5. Continue to monitor NC temperature.

RESPONSE NOT OBTAINED PAGE NO. 41 of 61 Rev 36 DCl: CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O -Page 1 of 4 41 of 61 Rev 36 DCl: NC Temperature Control ACTION/EXPECTED RESPONSE IRO DOES THIS ENCLOSURE

2. Use NC T-Avg to determine NC temperature as required in subsequent steps. 3. IF AT ANY TIME NC pumps are tripped, THEN use NC T -Colds to determine NC temperature as required in subsequent steps . *. ' iNC. **

557:Fi 5. Continue to monitor NC temperature.

RESPONSE NOT OBTAINED ttiEijic:>lIoViiJ;l9;;

req]lirea,';ir CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O -Page 2 of 4 42 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE 6. Do not continue in this enclosure until one of the following occurs:

NC temperature

-GREATER THAN 55rF AND INCREASING IN AN UNCONTROLLED MANNER. OR

NC temperature

-GREATER THAN 55rF AND STABLE. OR

NC temperature

-LESS THAN 55rF AND DECREASING IN AN UNCONTROLLED MANNER. RESPONSE NOT OBTAINED Perform the following:

a. IF NC temperature is greater than 55rF AND increasing, THEN stabilize NC temperature at 55rF as follows: 1) IF steam dumps are available, THEN use steam dumps.

2) IF steam dumps are not available, THEN use S/G PORVs. b. IF the following conditions exist:

NC temperature is greater than 557°F and stable

Time and manpower is available, THEN stabilize NC temperature at 55rF as follows: 1) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use S/G PORVs. c. GO TO Step 9. CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O -Page 2 of 4 42 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE 6. Do not continue in this enclosure until one of the following occurs:

NC temperature

-GREATER THAN 55rF AND INCREASING IN AN UNCONTROLLED MANNER. OR

NC temperature

-GREATER THAN 55rF AND STABLE. OR

NC temperature

-LESS THAN 557°F AND DECREASING IN AN UNCONTROLLED MANNER.

LE:SS THlSt'f A.'N I NG,}' RESPONSE NOT OBTAINED Perform the following:

a. IF NC temperature is greater than 55rF AND increasing, THEN stabilize NC temperature at 557°F as follows: 1) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use S/G PORVs. b. IF the following conditions exist:

NC temperature is greater than 55rF and stable

Time and manpower is available, THEN stabilize NC temperature at 55rF as follows: 1) IF steam dumps are available, THEN use steam dumps. 2) IF steam dumps are not available, THEN use S/G PORVs. c. GO TO Step 9.

CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O Enclosure 4 -Page 3 of 4 430f61 8. NC Temperature Control Rev 36 ACTION/EXPECTED RESPONSE c . .....,.1IIMIi

... ' .............

-** ;1 ........ ;* ...... ;. *.'!!'

__ .. . 1it-w . .,. !"" "'Ll '" > h"", ' ., -IU'": , ifiI ..

.., *....,*= .. I_l". _I RESPONSE NOT OBTAINED b. IF any S/G PORV cannot be closed, THEN close its isolation valve. CNS REACTOR TRIP OR SAFETY INJECTION EP/1/A/5000/E-O -Page 3 of 4 NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 8.

f9 I1 0yt$: PAGE NO. 43 of 61 Rev 36 a.,I=f\$ure atI:S!§l!nldumpSd:

b.BJisyce.qll -iCg;OSED, b. IF any S/G PORV cannot be closed, THEN close its isolation valve. c.

g..

-1,l?M:Hl\ :;1jpMt?§J?

C{;j/;)} .'

j'*;Bldwp* 1 SM .. ?

OtltHdr BldWn} CN).

P[}tJ" Vlv Drn) .1

!($tog. ';1l?M"'43

,(§lop'VJv

3.,eefore:$eat.

Ofn) !. ,1:SM:'A2:('

sr"*

Hlor":WS'at

'd . 7L.*.

e", EL.e Qrn) ..

CNS REACTOR TRIP OR SAFETY INJECTION EP/1/Al5000/E-O -Page 4 of 4 NC Temperature Control ACTION/EXPECTED RESPONSE 8. (Continued)

f. 9.

RESPONSE NOT OBTAINED f. PAGE NO. 44of61 Rev 36 CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O -Page 4 of 4 44 of 61 Rev 36 NC Temperature Control ACTION/EXPECTED RESPONSE 8. (Continued)

f.

9.

,

Lffi6S P,'Si[';Uc c c

,,:j,,/ / C AwK*,**c _ ., .. A" , ,QR RESPONSE NOT OBTAINED f. IF copld:QWl;!)}cc>ntinpes;THENtbrottle feed

1) i;!gllg)N(r'j.9?

":l'

*

bDe':$IG;

'iJiHENlthrottlefeed fIB\W:fllrrther to C.'0 ,

iN!t;:iiht 9 Jriaf (29%ACC); '1FX9Q9fqQWQ)§gJilllhges,'Tfi ENc!Q§eJ . AIlJiiMSf'1:s%

c* 'd

.. ,'.,

it valyesi' CNS RESPONSE TO IMMINENT PRESSURIZED THERMAL PAGE NO. EP/1/A15000/FR-P

.1 SHOCK CONDITION 1 of 55 Rev 18 A. Purpose This procedure provides actions to avoid, or limit, thermal shock or pressurized thermal shock to the reactor pressure vessel, or overpressure conditions at low temperature.

B. Symptoms or Entry Conditions This procedure is entered from EP/1/A15000/F-O (Critical Safety Function Status Trees) (REACTOR COOLANT INTEGRITY) on a RED or either ORANGE condition.

May be entered due to REO or ORANGE path due to Tcolds falling after LOCA and cold injection.

Path IS valid, but procedure recognizes a LOCA in step one (based on NO flow to CLs) and kicks back to procedure and step in effect. CNS RESPONSE TO IMMINENT PRESSURIZED THERMAL PAGE NO. EP/1 / A/5000/FR-P.1 SHOCK CONDITION 1 of 55 Rev 18 A. Purpose This procedure provides actions to avoid, or limit, thermal shock or pressurized thermal shock to the reactor pressure vessel, or overpressure conditions at low temperature.

B. Symptoms or Entry Conditions This procedure is entered from EP/1/AlSOOO/F-O (Critical Safety Function Status Trees) (REACTOR COOLANT INTEGRITY) on a RED or either ORANGE condition.

May be entered due to RED or ORANGE path due to Tcolds falling after LOCA and cold injection.

Path IS valid, but procedure recognizes a LOCA in step one (based on NO flow to CLs) and kicks back to procedure and step in effect.

CNS RESPONSE TO IMMINENT PRESSURIZED THERMAL PAGE NO. EP/1/Al5000/FR-P.1 ACTION/EXPECTED RESPONSE C. Operator Actions 2. Monitor Enclosure 1 (Foldout Page). 3. Verify all NC i-Colds -SiABLE OR INCREASING.

SHOCK CONDITION 2of55 Rev 18 RESPONSE NOT OBTAINED _

Attempt to stop NC System cool down as follows: a. Ensure all S/G PORVs -CLOSED. b. IF any S/G PORV cannot be closed, TI'IEN close its isolation valve. c. Ensure all steam dump valves -CLOSED. d. IF ND is in RHR mode, il'lEN stop any cooldown from ND System. e. Identify faulted S/G(s) as follows: _

Any S/G pressure -DECREASING IN AN UNCONTROLLED MANNER OR _

Any S/G -DEPRESSURIZED. (RNO continued on next page) CNS RESPONSE TO IMMINENT PRESSURIZED THERMAL PAGE NO. EP/1 /A/5000/FR-P.1 ACTION/EXPECTED RESPONSE C. Operator Actions 2. Monitor Enclosure 1 (Foldout Page). 3. Verify all NC T-Colds -STABLE OR INCREASING.

SHOCK CONDITION 2of55 Rev 18 DC:: RESPONSE NOT OBTAINED _ IF antf.step'.in effect; Attempt to stop NC System cooldown as follows: a. Ensure all S/G PORVs -CLOSED. b. IF any S/G PORV cannot be closed, THEN close its isolation valve. c. Ensure all steam dump valves -CLOSED. d. IF ND is in RHR mode, THEN stop any cooldown from ND System. e. Identify faulted S/G(s) as follows: _

Any S/G pressure -DECREASING IN AN UNCONTROLLED MANNER OR _

Any S/G -DEPRESSURIZED. (RNO continued on next page)

Duke Energy Procedure No. Catawba Nuclear Station EP/I/A/5000/E-1 Loss of Reactor or Secondary Coolant Revision No. 023 Electronic Reference No. Continuous Use CP0094CP PERFORMANCE I **********UNCONTROLLEDFORPruNT********** (ISSUED) -PDF Format IAt some point in this procedure, fWST level will drop to 37% and they will transition to ES-1.3 Duke Energy Procedure No. Catawba Nuclear Station EP/I/A/5000/E-1 Loss of Reactor or Secondary Coolant Revision No. 023 Electronic Reference No. Continuous Use CP0094CP PERFORMANCE I **********UNCONTROLLEDFORPruNT********** (ISSUED) -PDF Format At some point in this procedure, fWST level will drop to 37% and they will transition to ES-1.3 CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 1 of 29 Revision 23 A. Purpose This procedure provides actions to recover from a loss of reactor or secondary coolant. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/A15000/E-O (Reactor Trip Or Safety Injection), Step 22, and EP/1/A15000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 41 and EP/1/A15000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 43 when a Pzr PORV is stuck open and its isolation valve cannot be closed. b. EP/1/A15000/E-O (Reactor Trip Or Safety Injection), Step 26, with any of the following symptoms:

high containment radiation, high containment pressure, or high containment recirculation sump level. c. EP/1/A15000/E-O (Reactor Trip Or Safety Injection), Step 36, EP/1/A15000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 8 and EP/1/A15000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 46, when NC pressure is less than the shutoff head pressure of the NO pumps. d. EP/1/A15000/ES-1.1 (Safety Injection Termination), Step 14 and EP/1/A15000/ES-1.1 (Safety Injection Termination), Step 33, and EP/1/A15000/FR-1.2 (Response To Low Pressurizer Level), Step 8, if S/I has to be reinitiated.

e. EP/1/A15000/E-2 (Faulted Steam Generator Isolation), Step 12, after identification and isolation of a faulted S/G. f. EP/1/A15000/ECA-O.2 (Loss Of All AC Power Recovery With SII Required), Step 15, after normal injection mode conditions are established.

g. EP/1/A15000/ECA-1.2 (LOCA Outside Containment), Step 3, when a LOCA outside containment is isolated.

h. EP/1/A15000/FR-C.1 (Response To Inadequate Core Cooling), Step 21 and EP/1/A15000/FR-C.1 (Response To Inadequate Core Cooling), Step 31, and EP/1/A15000/FR-C.2 (Response To Degraded Core Cooling), Step 24, after core cooling has been established.

i. EP/1/A15000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 39, after secondary heat sink has been re-established and all Pzr PORVs are closed. CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/N5000/E-1 1 of 29 Revision 23 A. Purpose This procedure provides actions to recover from a loss of reactor or secondary coolant. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/N5000/E-O (Reactor Trip Or Safety Injection), Step 22, and EP/1/N5000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 41 and EP/1/N5000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 43 when a Pzr PORV is stuck open and its isolation valve cannot be closed. b. EP/1/N5000/E-O (Reactor Trip Or Safety Injection), Step 26, with any of the following symptoms:

high containment radiation, high containment pressure, or high containment recirculation sump level. c. EP/1/N5000/E-O (Reactor Trip Or Safety Injection), Step 36, EP/1/N5000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 8 and EP/1/N5000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 46, when NC pressure is less than the shutoff head pressure of the ND pumps. d. EP/1/N5000/ES-1.1 (Safety Injection Termination), Step 14 and EP/1/N5000/ES-1.1 (Safety Injection Termination), Step 33, and EP/1/N5000/FR-1.2 (Response To Low Pressurizer Level), Step 8, if S/I has to be reinitiated.

e. EP/1/N5000/E-2 (Faulted Steam Generator Isolation), Step 12, after identification and isolation of a faulted S/G. f. EP/1/N5000/ECA-O.2 (Loss Of All AC Power Recovery With S/I Required), Step 15, after normal injection mode conditions are established.

g. EP/1/N5000/ECA-1.2 (LOCA Outside Containment), Step 3, when a LOCA outside containment is isolated.

h. EP/1/N5000/FR-C.1 (Response To Inadequate Core Cooling), Step 21 and EP/1/N5000/FR-C.1 (Response To Inadequate Core Cooling), Step 31, and EP/1/N5000/FR-C.2 (Response To Degraded Core Cooling), Step 24, after core cooling has been established.

i. EP/1/N5000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 39, after secondary heat sink has been re-established and all Pzr PORVs are closed.

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 ACTION/EXPECTED RESPONSE C. Operator Actions 1. 2. 3. a. b. 20f29 Revision 23 RESPONSE NOT OBTAINED IF pressure in any S/G is decreasing in an uncontrolled manner OR any S/G is depressurized, THEN: a. IF any faulted S/G{s) feedlines OR steamlines are not isolated, THEN: _ 1) IF EP/1/A/5000/E-2 (Faulted Steam Generator Isolation) has been performed for the affected S/G, THEN GO TO Step 2 RNO b. _ 2) GO TO EP/1/A/5000/E-2 (Faulted Steam Generator Isolation).

b. IF the affected S/G(s) is faulted outside containment, THEN request RP to perform the following:

_ 1) Monitor the area of the steam fault for radiation.

_ 2) Notify the control room of any abnormal radiation conditions.

a. Maintain total feed flow greater than 450 GPM until at least one intact S/G N/R level is greater than 11 % (29% ACC). b. IF N/R level any S/G continues to increase in an uncontrolled manner, THEN GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1 1 A/5000/E-1 ACTION/EXPECTED RESPONSE C. Operator Actions 2.

fpllows.;!)

_.

_

3. "Xl

.. lntaqf 20f29 Revision 23 RESPONSE NOT OBTAINED IF pressure in any S/G is decreasing in an uncontrolled manner OR any S/G is depressurized, THEN: a. IF any faulted S/G{s) feedlines OR steamlines are not isolated, THEN: _ 1) IF EP/1/A/5000/E-2 (Faulted Steam Generator Isolation) has been performed for the affected S/G, THEN GO TO Step 2 RNO b. _ 2) GO TO EP/1/A/5000/E-2 (Faulted Steam Generator Isolation).

b. IF the affected S/G(s) is faulted outside containment, THEN request RP to perform the following:

_ 1) Monitor the area of the steam fault for radiation.

_ 2) Notify the control room of any abnormal radiation conditions.

a. Maintain total feed flow greater than 450 GPM until at least one intact S/G NIR level is greater than 11 % (29% ACC). b. IF N/R level any S/G continues to increase in an uncontrolled manner, THEN GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 ACTION/EXPECTED RESPONSE

e. 30f29 Revision 23 RESPONSE NOT OBTAINED d. GO TO EP/1/A15000/E-3 (Steam Generator Tube Rupture) . e. Perform the following:

_ 1) Notify station management to evaluate S/G{s) activity results. _ 2) IF S/G(s) activity indicate a SGTR, THEN GO TO EP/1/A15000/E-3 (Steam Generator Tube Rupture).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. E P /1/ A/5000/E-1 ACTION/EXPECTED RESPONSE ,folio' a, ..*

_

toJri$kall

.. 'fO yj: .lCj{

DAg;K: *

-

...........

?EL J .... . _. 1

_

_ ."1 30f29 Revision 23 RESPONSE NOT OBTAINED d. GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture) . e. Perform the following:

_ 1) Notify station management to evaluate S/G{s) activity results. _ 2) IF S/G(s) activity indicate a SGTR, THEN GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 ACTION/EXPECTED RESPONSE 5. a. b. c. d. 40f29 Revision 23 RESPONSE NOT OBTAINED a. Dispatch operator to restore power to affected Pzr PORV isolation valve{s}:

b.

1 EMXD-F02C (PORV Isol Motor (1 NC31 B)) (AB-560, BB-50, Rm 372)

1 EMXC-F03C (Pressurizer Power Operated Relief Isol. Valve 1 NC33A) (AB-577, BB-50, Rm 496)

1 EMXD-F05A (PORV 1501 Motor (1 NC35B)} (AB-560, BB-50, Rm 372). c. Open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV. CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 ACTION/EXPECTED RESPONSE

a.

d. 40f29 Revision 23 RESPONSE NOT OBTAINED a. Dispatch operator to restore power to affected Pzr PORV isolation valve{s):

1 EMXD-F02C (PORV Isol Motor (1 NC31 B)) (AB-560, BB-50, Rm 372)

1 EMXC-F03C (Pressurizer Power Operated Relief Isol. Valve 1 NC33A) (AB-577, BB-50, Rm 496)

1 EMXD-F05A (PORV Isol Motor (1 NC35B)) (AB-560, BB-50, Rm 372). b.lF-THEN:: _ 1")*:

_ :12) pir

c. Open one Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV.

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 ACTION/EXPECTED RESPONSE 6. a. b. Verify secondary heat sink as follows:

N/R level in at least one intact S/G -GREATER THAN 11 % (29% ACC) OR

Total feed flow to all intact S/Gs-GREATER THAN 450 GPM. c. NC pressure -STABLE OR INCREASING.

d. Pzr level -GREATER THAN 11 % (20% ACC). e. GO TO EP/1/A15000/ES-1.1 (Safety Injection Termination).

f. _ g. IF AT ANY TIME S/I ter,mination criteria is met while in this procedure, THEN RETURN TO Step 6. a. 50f29 Revision 23 RESPONSE NOT OBTAINED b. GO TO Step 6.f. c. GO TO Step 6.f. d. Perform the following:

_1) IF NC pressure is increasing AND normal Pzr spray is available, THEN attempt to stabilize NC pressure using normal Pzr spray. _ 2) GO TO Step 6.f. a. Perform the following:

_ 1) IF AT ANY TIME an NS pump(s) starts while in this procedure, THEN perform Step 7. _ 2) GO TO Step 8. CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1

6. ACTION/EXPECTED RESPONSE a. b. Verify secondary heat sink as follows:

N/R level in at least one intact S/G -GREATER THAN 11% (29% ACC) OR

Total feed flow to all intact GREATER THAN 450 GPM. c. NC pressure -STABLE OR INCREASING.

d. Pzr level -GREATER THAN 11 % (20% ACC). e. GO TO EP/1/A/5000/ES-1.1 (Safety Injection Termination).

f. MonttorSllterminat[oFFCr1le'riI3Y<.REFE*Ri

_ g. IF AT ANY TIME SII criteria is met while in this procedure, THEN RETURN TO Step 6. 7. 50f29 Revision 23 RESPONSE NOT OBTAINED b. GO TO Step 6.f . c. GO TO Step 6.f. d. Perform the following:

_ 1) IF NC pressure is increasing AND normal Pzr spray is available, THEN attempt to stabilize NC pressure using normal Pzr spray. _ 2) GO TO Step 6.f. a. Perform the following:

_ 1) IF AT ANY TIME an NS pump(s) starts while in this procedure, THEN perform Step 7. _ 2) GO TO Step 8.

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 ACTION/EXPECTED RESPONSE 7. (Continued)

b.

c. d. Verify operating NS pump{s) -HAVE REMAINED RUNNING SINCE INITIAL PHASE B SIGNAL. 6of29 Revision 23 RESPONSE NOT OBTAINED b. Perform the following:

_ 1) IF NS pump(s) have previously been stopped more than once, THEN GO TO Step 8. _ 2) WHEN containment pressure is less than 1 PSIG, THEN perform Steps 7.e through 7.h. _ 3) GO TO Step 8. c. d. IF NS pump{s) has previously been stopped, THEN GO TO Step 8. CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 ACTION/EXPECTED RESPONSE 7. (Continued)

ISOp I _

_

/5$I3.(NQ>f,?ump'1 ff9:1D 5WSn> c.

-G"Ess>rHAN

d. Verify operating NS pump{s) -HAVE REMAINED RUNNING SINCE INITIAL PHASE B SIGNAL. 6of29 Revision 23 RESPONSE NOT OBTAINED b. Perform the following:

_ 1) IF NS pump(s) have previously been stopped more than once, THEN GO TO Step 8. _ 2) WHEN containment pressure is less than 1 PSIG, THEN perform Steps 7.e through 7.h. _ 3) GO TO Step 8. c. .

_ .1) .*

_

d. IF NS pump{s) has previously been stopped, THEN GO TO Step 8.

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 ACTION/EXPECTED RESPONSE 7. (Continued)

e. Ensure SII -RESET: _ 1) ECCS. _ 2) DIG load sequencers.

_ 3) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on. f. Reset NS. _ g. Stop NS pumps. h. Close the following valves:

1 NS-29A (NS Spray Hdr 1A Cont Isol)

1 NS-32A (NS Spray Hdr 1A Cont Isol)

1NS-1SB (NS Spray Hdr 1B Cont Isol)

1 NS-12B (NS Spray Hdr 1 B Cont Isol). 70f29 Revision 23 RESPONSE NOT OBTAINED 1) Perform the following:

_ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ b) WHEN trip breakers open, THEN reset ECCS. 2) Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372). CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 ACTION/EXPECTED RESPONSE 7. (Continued)

e. Ensure SII -RESET: _ 1) ECCS. _ 2) DIG load sequencers.

_ 3) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on. f. Reset NS. _ g. Stop NS pumps. h. Close the following valves:

1 NS-29A (NS Spray Hdr 1 A Cont Isol)

1 NS-32A (NS Spray Hdr 1A Cont Isol)

1NS-1SB (NS Spray Hdr 1B Cont Isol)

1NS-12B (NS Spray Hdr 1B Cont Isol). 70f29 Revision 23 RESPONSE NOT OBTAINED 1) Perform the following:

_ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ b) WHEN trip breakers open, THEN reset ECCS. 2) Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1

8. ACTION/EXPECTED RESPONSE a. b. NC pressure -STABLE OR INCREASING.

c. At least one ND pump -ON. d. ND pumps suction -ALIGNED TO FWST. e. Verify FWST level-GREATER THAN 45%. 80f29 Revision 23 RESPONSE NOT OBTAINED b. GO TO Step 9. c. GO TO Step 8.h. d. GO TO Step 9. e. Perform the following:

1) IF AT ANY TIME the following conditions exist: _

Any ND pump(s) operating with flow -LESS THAN 1000 GPM TO THE LOOPS

KC to the associated ND HX -ISOLATED, _ THEN stop the affected ND pump(s) within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months . _ 2) GO TO Step 9. CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/11A15000/E-1 ACTION/EXPECTED RESPONSE a. b. NC pressure -STABLE OR INCREASING.

c. At least one ND pump -ON. d. ND pumps suction -ALIGNED TO FWST. e. Verify FWST level-GREATER THAN 45%. 80f29 Revision 23 RESPONSE NOT OBTAINED b. GO TO Step 9. c. GO TO Step 8.h. d. GO TO Step 9. e. Perform the following:

1) IF AT ANY TIME the following conditions exist: _

Any ND pump(s) operating with flow -LESS THAN 1000 GPM TO THE LOOPS

KC to the associated ND HX -ISOLATED, _ THEN stop the affected ND pump(s) within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months . _ 2) GO TO Step 9.

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/N50001E-1 ACTION/EXPECTED RESPONSE 8. (Continued)

f. Ensure SII -RESET: _ 1) ECCS. _ 2) DIG load sequencers.

_ 3) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on. _ g. Stop ND pumps. h. IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart ND pumps. 9. Verify NC and S/G pressures as follows: a. All SIG pressures

-STABlE OR INCREASING.

b. NC pressure -STABLE OR DECREASING.

90f29 Revision 23 RESPONSE NOT OBTAINED 1) Perform the following:

_ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ b) WHEN trip breakers open, THEN reset ECCS. 2) Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGlSB) (AB-560, BB-46, Rm 372). a. IF SIG pressure is decreasing due to a faulted SIG, THEN RETURN TO Step 1. b. RETURN TO Step 1. CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 ACTION/EXPECTED RESPONSE 8. (Continued)

f. Ensure S/I -RESET: _ 1) ECCS. _ 2) DIG load sequencers.

_ 3) IF AT ANY TIME a B/O occurs, THEN restart S/I equipment previously on. _ g. Stop NO pumps. h. IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart NO pumps. 9. Verify NC and S/G pressures as follows: a. All S/G pressures

-STABlE OR INCREASING.

b. NC pressure -STABLE OR DECREASING.

90f29 Revision 23 RESPONSE NOT OBTAINED 1) Perform the following:

_ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ b) WHEN trip breakers open, THEN reset ECCS. 2) Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGlSB) (AB-560, BB-46, Rm 372). a. IF S/G pressure is decreasing due to a faulted S/G, THEN RETURN TO Step 1. b. RETURN TO Step 1.

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 ACTION/EXPECTED RESPONSE 10. a. b.

c. d. *

e. 10 of 29 Revision 23 RESPONSE NOT OBTAINED a. GO TO Step 11. b. Perform the following:

_ 1) Attempt to restore offsite power to affected switchgear.

REFER TO AP/1/A155001007 (Loss of Normal Power). _ 2) GO TO Step 10.d. d. Perform the following:

_ 1) Attempt to restore offsite power to affected switchgear.

REFER TO AP/1/A155001007 (Loss of Normal Power). _2) IF 1 ETA is energized from offsite power, THEN GO TO Step 10J. _ 3) GO TO Step 11. CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. E P 111 A/5000/E-1

10. ISOpl ACTION/EXPECTED RESPONSE a.

oN. b.

eli'ergized;by.off$iie

c. d. e. *

10 of 29 Revision 23 RESPONSE NOT OBTAINED a. GO TO Step 11. b. Perform the following:

_ 1} Attempt to restore offsite power to affected switchgear.

REFER TO AP/1/A/55001007 (Loss of Normal Power). _ 2} GO TO Step 10.d. d. Perform the following:

_ 1} Attempt to restore offsite power to affected switchgear.

REFER TO AP/1/A/55001007 (Loss of Normal Power). _ 2} IF 1 ETA is energized from offsite power, THEN GO TO Step 10J. _ 3} GO TO Step 11.

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 ACTION/EXPECTED RESPONSE 10. (Continued)

ISOPI f. _1) _ 3) 11 of 29 Revision 23 RESPONSE NOT OBTAINED 1) Perform the following:

_ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ b) WHEN trip breakers open, THEN reset ECCS. 2) Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372). Depending on reader speed, FWST may be at 37% by this point. If not they will continue in this procedure until then and transition per Enclosure

1. CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/SOOO/E-1 ACTION/EXPECTED RESPONSE 10. (Continued)

f.

1) c::f§ds'l

_

THEN eqi,lipment

.. , ... , 11 of 29 Revision 23 RESPONSE NOT OBTAINED 1) Perform the following:

_ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ b) WHEN trip breakers open, THEN reset ECCS. 2) Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-S77, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel1DGLSB) (AB-S60, BB-46, Rm 372). Depending on reader speed, FWST may be at 37% by this point. If not they will continue in this procedure until then and transition per Enclosure

1.

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/Al5000/E-1 ACTION/EXPECTED RESPONSE c. d. e. 12 of 29 Revision 23 RESPONSE NOT OBTAINED b. Perform the following:

_ 1} Dispatch operator to place containment H2 analyzers in service. REFER TO OP/1/Al6450/010 (Containment Hydrogen Control System). _ 2} WHEN H2 analyzers are in service, THEN perform Steps 11.c through 11.e. _ 3} GO TO Step 12. c. Perform the following:

_ 1} Obtain recommendation from station management for method to reduce H2 concentration.

_ 2} GO TO Step 12. d. Dispatch operator to place H2 recombiners in service. REFER TO OP/1/Al6450/010 (Containment Hydrogen Control System). CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 ACTION/EXPECTED RESPONSE

,,' .'",','" .. ,., " '. , at Ensure, operatpr has to secure a"""

'units .. REF' , 0 Enclbsure:;3'

i!SecuEing,AIf'I'ondenser: A.ir j, *. , '.' , c.

LE$$,,{WHAN6%,.

e.

haci(j AN less the 12 of 29 Revision 23 RESPONSE NOT OBTAINED b. Perform the following:

_ 1) Dispatch operator to place containment H2 analyzers in service. REFER TO OP/1/A164501010 (Containment Hydrogen Control System). _ 2) WHEN H2 analyzers are in service, THEN perform Steps 11.c through 11.e. _ 3) GO TO Step 12. c. Perform the following:

_ 1) Obtain recommendation from station management for method to reduce H2 concentration.

_ 2) GO TO Step 12. d. Dispatch operator to place H2 recombiners in service. REFER TO OP/1/A164501010 (Containment Hydrogen Control System).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 ACTION/EXPECTED RESPONSE 12. ISOpl a. b. _1) 2) 13 of 29 Revision 23 RESPONSE NOT OBTAINED a. GO TO Step 12.-c. _ 1) GO TO EP/1/A15000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

2) Perform the following:

IF power cannot be verified to minimum number of valves required to perform the following:

Transfer one train of ND to the containment sump

Establish ND flow from containment sump to one train of NV and NI pumps. _ THEN GO TO EP/1/A15000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/SOOO/E-1 ACTION/EXPECTED RESPONSE

..

a.

IN4EC::'flQN MODE b.

as follows: 13 of 29 Revision 23 RESPONSE NOT OBTAINED a. GO TO Step 12.c. _ 1) GO TO EP/1/A/SOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

2) Perform the following:

IF power cannot be verified to minimum number of valves required to perform the following:

Transfer one train of ND to the containment sump

Establish ND flow from containment sump to one train of NV and NI pumps. _ THEN GO TO EP/1/A/SOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000IE-1 ACTION/EXPECTED RESPONSE 12. (Continued)

3) * *

4) *

c. Verify auxiliary building radiation is normal as follows:

EMF-41 (Au x Bldg Ventilation) trip 1 light -DARK

All area monitor EMF trip 1 DARK. 14 of 29 Revision 23 RESPONSE NOT OBTAINED 3) IF power cannot be verified to minimum number of valves required to isolate NI pump miniflow, THEN perform the following:

Attempt to restore power to miniflow isolation valve(s)

Have operator standing by to locally close the required valve:

1 NI-147B (NI Miniflow Hdr To FWST Isol) (AB-548, HH-JJ, 53-54, Rm 234)

1 NI-115A (NI Pump 1A Miniflow Isol) (AB-549, GG-HH, 53-54, Rm 235)

1 NI-144A (NI Pump 1 B Miniflow Isol) (AB-548, HH-JJ, 53-54, Rm 234). _ 4) WHEN criteria for establishing Cold Leg Recirc are met, THEN manual alignment to containment sump will be required.

c. Evaluate cause of abnormal conditions as follows: _ 1) Monitor OAC EMF alarms, OAC VA Graphic, and area monitor EMFs to determine location of activity.

_ 2) Dispatch operator to locate potential leak. _ 3) IF cause of alarm is LOCA outside containment, THEN GO TO EP/1/A15000/ECA-1.2 (LOCA Outside Containment).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 ACTION/EXPECTED RESPONSE 4) .. c. Verify auxiliary building radiation is normal as follows:

EMF-41 (Aux Bldg Ventilation) trip 1 light -DARK

All area monitor EMF trip 1 DARK. 14 of 29 Revision 23 RESPONSE NOT OBTAINED 3) IF power cannot be verified to minimum number of valves required to isolate NI pump miniflow, THEN perform the following:

Attempt to restore power to miniflow isolation valve(s)

Have operator standing by to locally close the required valve:

1 NI-147B (NI Miniflow Hdr To FWST Isol) (AB-548, HH-JJ, 53-54, Rm 234)

1 NI-115A (NI Pump 1A Miniflow Isol) (AB-549, GG-HH, 53-54, Rm 235)

1 NI-144A (NI Pump 1 B Miniflow Isol) (AB-548, HH-JJ, 53-54, Rm 234). _ 4) WHEN criteria for establishing Cold Leg Recirc are met, THEN manual alignment to containment sump will be required.

c. Evaluate cause of abnormal conditions as follows: _ 1) Monitor OAC EMF alarms, OAC VA Graphic, and area monitor EMFs to determine location of activity . _ 2) Dispatch operator to locate potential leak. _ 3) IF cause of alarm is LOCA outside containment, THEN GO TO EP/1/A/5000/ECA-1.2 (LOCA Outside Containment).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 -Page 1 of 2 24 of 29 Foldout Page Revision 23 1. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NVor NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO O°F. 2. 5/1 Reinitiation Criteria:

IF NC subcooling based on core exit TICs is less than O°F OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN manually start S/I pumps and align valves as required to restore subcooling and Pzr level. 3. Secondary Integrity Criteria:

IF pressure in any un isolated S/G is decreasing in an uncontrolled manner OR any un isolated S/G is completely depressurized, THEN GO TO EP/1/A/5000/E-2 (Faulted Steam Generator Isolation).

4. SGTR Transition Criteria:

5.

IF level in any S/G is increasing in an uncontrolled manner OR any S/G has abnormal radiation, THEN: a. Manually start S/I pumps and align valves. b. GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 -Page 1 of 2 24 of 29 Foldout Page Revision 23 1. NC Pump Trip Criteria:

IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:

At least one NV or NI pump -ON

NC subcooling based on core exit TICs -LESS THAN OR EQUAL TO O°F. 2. 5/1 Reinitiation Criteria:

IF NC subcooling based on core exit TICs is less than O°F OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN manually start S/I pumps and align valves as required to restore subcooling and Pzr level. 3. Secondary Integrity Criteria:

IF pressure in any un isolated S/G is decreasing in an uncontrolled manner OR any un isolated S/G is completely depressurized, THEN GO TO EP/1/A15000/E-2 (Faulted Steam Generator Isolation).

4. SGTR Transition Criteria:

IF level in any S/G is increasing in an uncontrolled manner OR any S/G has abnormal radiation, THEN: a. Manually start S/I pumps and align valves. b. GO TO EP/1/A15000/E-3 (Steam Generator Tube Rupture).

5.

...*..

.*. 2tffih.'.1., .. " ,,'

,\ .. "",'

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/N5000/E-1 -Page 2 of 2 25 of 29 Foldout Page Revision 23 6. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO AP/1/N5500/006 (Loss of S/G Feedwater):

_. 1AD-5, H/4 "CACST LO LEVEL" OR

1AD-8, B/1 "UST LO LEVEL". 7. Position Criteria for 1 NV-202B and 1 NV-203A (NV Pumps A&B Recirc Isol):

IF NC pressure is less than 1500 PSIG AND NV SII flowpath is aligned, THEN close 1 NV-202B and 1 NV-203A

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-202B and 1 NV-203A. 8. Loss of Emergency Coolant Recirculation Criteria:

IF emergency coolant recirculation has been established and is subsequently lost, THEN GO TO EP/1/N5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. E P 111 A/5000/E-1 -Page 2 of 2 25 of 29 Foldout Page Revision 23 6. CA Suction Source Switchover Criteria:

IF either of the following annunciators are lit, THEN REFER TO AP/1/A/55001006 (Loss of S/G Feedwater):

_. 1AD-5, H/4 "CACST LO LEVEL" OR

1AD-8, B/1 "UST LO LEVEL". 7. Position Criteria for 1 NV-202B and 1 NV-203A (NV Pumps A&B Recirc 1501):

IF NC pressure is less than 1500 PSIG AND NV S/I flowpath is aligned, THEN close 1 NV-202B and 1 NV-203A

IF NC pressure is greater than 2000 PSIG, THEN open 1 NV-202B and 1 NV-203A. 8. Loss of Emergency Coolant Recirculation Criteria:

IF emergency coolant recirculation has been established and is subsequently lost, THEN GO TO EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

Duke Energy Procedure No. Catawba Nuclear Station EP/I/A/soOO/ES-1.3 Transfer to Cold Leg Recirculation Revision No. 021 Electronic Reference No. Continuous Use CP0094CV PERFORMANCE J **********UNCONTROLLEDFORPRrnT********** (ISSUED) -PDF Format Duke Energy Procedure No. Catawba Nuclear Station EP/I/A/soOO/ES-1.3 Transfer to Cold Leg Recirculation Revision No. 021 Electronic Reference No. Continuous Use CP0094CV PERFORMANCE I **********UNCONTROLLEDFORPRrnT********** (ISSUED) -PDF Format CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/N5000/ES-1.3 1 of 38 Revision 21 A. Purpose This procedure provides the necessary instructions for transferring the safety injection system and containment spray system to the recirculation mode. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/N5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 14, on low FWST level. b. EP/1/N5000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 10, on low FWST level. c. Other procedures whenever FWST level reaches the switch over setpoint.

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 1 of 38 Revision 21 A. Purpose This procedure provides the necessary instructions for transferring the safety injection system and containment spray system to the recirculation mode. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 14, on low FWST level. b. EP/1/A/5000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 10, on low FWST level. c. Other procedures whenever FWST level reaches the switch over setpoint.

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/N5000/ES-1.3 2of38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions _. a,,'djii_.i.lgewillrtJlfJiiltlJ1JIDIB II. __ 1111_1811111" ** ,.

Perform the following:

a. Ensure S/I -RESET: _1) ECCS. _ 2) DIG load sequencers.

_ 3) IF AT ANY TIME a BIO occurs, THEN restart S/I equipment previously on. b. Ensure the following valves -CLOSED:

1 FW-27A (NO Pump 1A Suct From FWST)

1 FW-55B (NO Pump 1 B Suct From FWST). (RNO continued on next page) CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE C. Operator Actions iN0fI:

lEVEL",>3;3 ft n, ; 2of38 Revision 21 RESPONSE NOT OBTAINED Perform the following:

a. Ensure S/I -RESET: _ 1) ECCS. _ 2) DIG load sequencers . _ 3) IF AT ANY TIME a BIO occurs, THEN restart S/I equipment previously on. b. Ensure the following valves -CLOSED:

1 FW-27A (ND Pump 1A Suct From FWST)

1 FW-55B (ND Pump 1 B Suct From FWST). (RNO continued on next page)

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 2. (Continued) 30f38 Revision 21 RESPONSE NOT OBTAINED c. IF valve{s) will not close, THEN: _ 1) Stop associated ND pump{s). 2) Depress the following "DEFEAT" pushbutton{s) for the affected train(s):

"C-LEG RECIR FWST TO CONT SUMP SWAP TRN A" * "C-LEG RECIR FWST TO CONT SUMP SWAP TRN B". _ 3) Close the associated ND pump{s) containment sump suction valve(s).

d. IF FWST level less than 37% due to FWST puncture, THEN RETURN TO procedure and step in effect. e. IF both NS pumps are off, THEN GO TO Step 2 RNO g. f. IF either of the following annunciators are lit:

1AD-20, B/2 "CONT. SUMP LEVEL >2.5 fi" OR _. 1AD-21, B/2 "CO NT. SUMP LEVEL >2.5 fi", _ THEN GO TO Step 3. (RNO continued on next page) CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 2. (Continued) 3 of 38 Revision 21 RESPONSE NOT OBTAINED c. IF valve(s) will not close, THEN: _ 1) Stop associated ND pump(s). 2) Depress the following "DEFEAT" pushbutton(s) for the affected train(s):

"C-LEG RECIR FWST TO CONT SUMP SWAP TRN A" * "C-LEG RECIR FWST TO CONT SUMP SWAP TRN 8". _ 3) Close the associated ND pump(s) containment sump suction valve(s).

d. IF FWST level less than 37% due to FWST puncture, THEN RETURN TO procedure and step in effect. e. IF both NS pumps are off, THEN GO TO Step 2 RNO g. f. IF either of the following annunciators are lit:

1AD-20, 8/2 "CO NT. SUMP LEVEL >2.5 fi" OR _. 1AD-21, 8/2 "CO NT. SUMP LEVEL >2.5 fi", _ THEN GO TO Step 3. (RNO continued on next page)

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/N5000/ES-1.3 ACTION/EXPECTED RESPONSE 2. (Continued)

3. 4of38 Revision 21 RESPONSE NOT OBTAINED g. IF all of the following conditions met:

FWST level -LESS THAN 8%

NC temperature

-GREATER THAN 200°F

Containment Spray -PREVIOUSLY IN SERVICE

Indicated containment sump level -GREATER THAN 0.5 FT. _ THEN GO TO Step 3. h. IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. i. IF both "CO NT. SUMP LEVEL >3.3 fi" annunciators on 1AD-20 and 1AD-21 dark, THEN stop all pumps taking suction from the containment sump. _ j. GO TO EP/1/N5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

_ Establish KC flow to affected NO Hx(s). CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/N5000/ES-1.3 ACTION/EXPECTED RESPONSE 2. (Continued)

3. 4 of 38 Revision 21 RESPONSE NOT OBTAINED g. IF all of the following conditions met:

FWST level -LESS THAN 8%

NC temperature

-GREATER THAN 200°F

Containment Spray -PREVIOUSLY IN SERVICE

Indicated containment sump level -GREATER THAN 0.5 FT. _ THEN GO TO Step 3. h. IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. i. IF both "CO NT. SUMP LEVEL >3.3 fi" annunciators on 1AD-20 and 1AD-21 dark, THEN stop all pumps taking suction from the containment sump. _ j. GOTO EP/1/N5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

_ Establish KC flow to affected NO Hx(s).

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/N5000/ES-1.3 ACTION/EXPECTED RESPONSE 4. b. c. 5 of 38 Revision 21 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ 2) WHEN trip breakers open, THEN reset ECCS. b. Dispatch operator to open the affected sequencer(s) control power breaker:

1EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372). CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/N5000/ES-1.3 ACTION/EXPECTED RESPONSE

a. e'dG'$; c. 5 of 38 Revision 21 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers.

_ 2) WHEN trip breakers open, THEN reset ECCS. b. Dispatch operator to open the affected sequencer(s) control power breaker:

1EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)

1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372).

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3

5. ACTION/EXPECTED RESPONSE a. 1NI-184B will NOT be open. 10 seconds after they secure the pump, there will be a loss of all essential power to A train. "A" train power to essential equipment will not be restored for the remainder of the scenario.

a. 6of38 Revision 21 RESPONSE NOT OBTAINED b)

1 FW-27A (NO Pump 1A Suet From FWST) * (RNO continued on next page) CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 IBOP/5. ACTION/EXPECTED RESPONSE

a.

1

'Sy_. 1NI-184B will NOT be open. 10 seconds after they secure the pump, there will be a loss of all essential power to A train. "A" train power to essential equipment will not be restored for the remainder of the scenario.

6 of 38 Revision 21 RESPONSE NOT OBTAINED a.

_

_ qf suryp1

.. b) .frOIn* the,: FWS1)

1 FW-27A (NO Pump 1ASuct From FWST)

1 FW;.55BjND I?J9m FVYST). (RNO continued on next page)

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A1S000/ES-1.3 ACTION/EXPECTED RESPONSE S. (Continued) 7of38 Revision 21 RESPONSE NOT OBTAINED (1 ) _. 1NI-18SA (NO Pump 1A Cont Sump Suct) (2) *

1NI-18SA (NO Pump 1A Cont Sump Suct) (AB-S4S, EE-FF, S2-S3, Rm 217)

Once they call, it will take 10 minutes to get the valve open, 5 to get there and 5 to open. Both valves are NOT closed. 1NI-185A is open 3) IF both containment sump suction valves are closed, THEN: _ a) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ b) GO TO EP/1/A1S000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/SOOO/ES-1.3 ACTION/EXPECTED RESPONSE S. (Continued) 7of38 Revision 21 RESPONSE NOT OBTAINED Wi{ENtheNd:'

the J ;;IS TH13Nmerform the fOlio >' : (1) Att,ep1p, tJ,o,m, 8,;

co ";i.,,

s'ump

1 NI-185A (NO Pump 1A Cont Sump Suet) * (2) }IF affect

sump,

<i\lfectedvalve(s);!:

'

1 NI-18SA (NO Pump 1A Cont Sump Suct) (AB-S4S, EE-FF, 52-S3, Rm 217) Once they call, it will take 10 minutes to get the valve open, 5 to get there and 5 to open. * ,1 B, 'Gont Sump'$!!Ict) (AS-54;>;,

Rm 21i()Jj Both valves are NOT closed. 1 NI-185A is open 3) IF both containment sump suction valves are closed, THEN: _ a) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ b) GO TO EP/1/A/SOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000IES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

IBOpl b. *

8of38 Revision 21 RESPONSE NOT OBTAINED b. Perform the following:

_ 1) Manually close affected valve{s) . 2) IF valve(s) will not close, THEN: _ a) Stop associated ND pump{s). b) Depress the following "DEFEA Til pushbutton(s) for the affected train(s):

"C-LEG RECIR FWST TO CONT SUMP SWAP TRN A" * "C-LEG RECIR FWST TO CONT SUMP SWAP TRN 8". _ c) Close the associated ND pump(s) containment sump suction valve(s).

d) IF both containment sump suction valves are closed, THEN: _ (1) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ (2) GOTO EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

b.

8 of 38 Revision 21 RESPONSE NOT OBTAINED b. Perform the following:

_ 1) Manually close affected valve(s).

2) IF valve(s) will not close, THEN: _ a) Stop associated ND pump(s). b) Depress the following "DEFEAT" pushbutton(s) for the affected train(s):

"C-LEG RECIR FWST TO CONT SUMP SWAP TRN A" * "C-LEG RECIR FWST TO CONT SUMP SWAP TRN 8". _ c) Close the associated ND pump(s) containment sump suction valve(s).

d) IF both containment sump suction valves are closed, THEN: _ (1) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ (2) GOTO EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

IsOpl c. There should be no valid RED or ORANGE paths that need to be implemented so the crew should go to ECA-1.1. There may be an ORANGE/RED path on NC Integrity which IS valid, but should have been previously addressed.

d. Isolate NI pump miniflow as follows: _ 1) Verify NC pressure -LESS THAN 1620 PSIG. 2) Close the following valves:

1 NI-115A (NI Pump 1A Miniflow Isol)

1 NI-144A (NI Pump 1 B Miniflow Isol). _ 3) Place "PWR DISCON FOR 1 NI-147B" switch in "ENABLE".

_ 4) Close 1NI-147B (NI Pump Miniflow Hdr To FWST Isol). c. RESPONSE NOT OBTAINED 1) Perform the following:

_ a) Stop NI pumps. 90f38 Revision 21 _ b) WHEN pressure is less than 1620 PSIG, THEN start NI pumps. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

ON: There should be no valid RED or ORANGE paths that need to be implemented so the crew should go to ECA-1.1. There may be an ORANGE/RED path on NC Integrity which IS valid, but should have been previously addressed.

d. Isolate NI pump miniflow as follows: _ 1) Verify NC pressure -LESS THAN 1620 PSIG. 2) Close the following valves:

1NI-115A (NI Pump 1A Miniflow Isol)

1 NI-144A (NI Pump 1 B Miniflow Isol). _ 3) Place "PWR DISCON FOR 1 NI-147B" switch in "ENABLE".

_ 4) Close 1 NI-147B (NI Pump Miniflow Hdr To FWST Isol). 9 of 38 Revision 21 RESPONSE NOT OBTAINED

_ 1 al!gnedtqah sli'mp

_

1) Perform the following:

_ a) Stop NI pumps. _ b) WHEN pressure is less than 1620 PSIG, THEN start NI pumps.

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 -Page 1 of 1 20 of 38 Foldout Page Revision 21 1. SII Reinitiation Criteria:

2.

IF NC subcooling based on core exit TICs is less than OaF OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN manually start S/I pumps and align valves as required to restore subcooling and Pzr level. 3. Loss Of FWST Supply To ECCS Pumps:

IF FWST level decreases to less than 11 %, THEN stop NS pumps taking suction from the FWST.

IF FWST level decreases to less than 5%, THEN stop all pumps taking suction from the FWST. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 -Page 1 of 1 20 of 38 Foldout Page Revision 21 1. 5/1 Reinitiation Criteria:

IF NC subcooling based on core exit TICs is less than OaF OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN manually start SII pumps and align valves as required to restore subcooling and Pzr level. .lilFSt (0110 ia>.IF>aij rocg(:fure is'in.effeOl"jt

.. :fENRElf'URNliI0, . roceCture in -.........

..... '-... '-. " ....... ".%g . 'P"'" P" ........ .. h.*......

"., .*. d .. -... -' "P. ........... .. 3. Loss Of FWST Supply To ECCS Pumps:

IF FWST level decreases to less than 11 %, THEN stop NS pumps taking suction from the FWST.

IF FWST level decreases to less than 5%, THEN stop all pumps taking suction from the FWST.

CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/N5000/ECA-1.1 1 of 83 Rev A. Purpose This procedure provides actions to restore emergency coolant recirculation capability, to delay depletion of the FWST by adding makeup and reducing outflow, and to depressurize the NC System to minimize break flow. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/N5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 12, when Cold Leg Recirc capability cannot be verified.

b. EP/1/NSOOO/ES-1.2 (Post LOCA Cooldown And Depressurization), Step 5, when Cold Leg Recirc capability cannot be verified.

c. EP/1/N5000/ES-1.3 (Transfer To Cold Leg Recirculation), Step 5, when at least one flowpath from the sump cannot be established or maintained.

d. EP/1/N5000/ECA-1.2 (LOCA Outside Containment), Step 3, when a LOCA outside containment cannot be isolated. (je--) -CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 1 of 83 Rev A. Purpose This procedure provides actions to restore emergency coolant recirculation capability, to delay depletion of the FWST by adding makeup and reducing outflow, and to depressurize the NC System to minimize break flow. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 12, when Cold Leg Recirc capability cannot be verified.

b. EP/1/A/5000/ES-1.2 (Post LOCA Cool down And Depressurization), Step 5, when Cold Leg Recirc capability cannot be verified.

c. EP/1/A/5000/ES-1.3 (Transfer To Cold Leg Recirculation), Step 5, when at least one flowpath from the sump cannot be established or maintained.

d. EP/1/A/5000/ECA-1.2 (LOCA Outside Containment), Step 3, when a LOCA outside containment cannot be isolated.

CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 ACTION/EXPECTED RESPONSE C. Operator Actions b. May not do this RNO since the power loss is beyond just those breakers.

20f83 Rev 31 RESPONSE NOT OBTAINED a.

d is patch operator and maintenance to determine and correct cause of pump failure. REFER TO EM/1/A/52001005 (Troubleshooting Cause For NO, NI, or NV Pump(s) Failing to Start).

1 EMXA-R080 (NO Pump 1A Suction From Containment Sump Valve 1 N1185A) (AB-577, FF-54, Rm 478)

1EMXB-F01C (NO Pump 1B Suction From Containment Sump Valve 1 N1184B) (AB-560, FF-56, Rm 330). (RNO continued on next page) CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 ACTION/EXPECTED RESPONSE C. Operator Actions a.

FROM _

N!l2J'I),J)!'01P$;

_. N\7P9rng:§ _ * ,Nlptifnp*1

b.

if HI; COhl.l'RQLlBOOty1!;, 1N. *.I;;*1857xlNO'liPufn't1AC*"t Slim" ... *.\ ... k .** *.*"" .*.

... Re.,... 0 .*.... P s\jct)\

May not do this RNO since the power loss is beyond just those breakers.

20f83 Rev 31 RESPONSE NOT OBTAINED a.

dispatch operator and maintenance to determine and correct cause of pump failure. REFER TO EM/1/A/52001005 (Troubleshooting Cause For NO, NI, or NV Pump(s) Failing to Start). b.

1) lJe>travail§ble, THEN

1EMXA-R080 (NO Pump 1A Suction From Containment Sump Valve 1N1185A) (AB-577, FF-54, Rm 478)

1 EMXB-F01 C (NO Pump 1 B Suction From Containment Sump Valve 1 N1184B) (AB-560, FF-56, Rm 330). (RNO continued on next page)

CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 ACTION/EXPECTED RESPONSE 3. (Continued)

This should already have been done in ES-1.3 3 of 83 Rev 31 RESPONSE NOT OBTAINED _ a) IF NO Pump 1A is available, THEN dispatch two operators to standby to open 1 NI-185A (NO Pump 1 A Cont Sump Suct) (AB-545, EE-FF, 52-53, Rm 217). ..**

CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 ACTION/EXPECTED RESPONSE 3. (Continued)

This should already have been done in ES-1.3 3 of 83 Rev 31 RESPONSE NOT OBTAINED 2) IFg12SYercaJi\qgf valve gan:ndrbe CO(lirol roQ,m,. iJ'HEN _ a) IF NO Pump 1A is available, THEN dispatch two operators to standby to open 1 NI-185A (NO Pump 1 A Cont Sump Suet) (AB-545, EE-FF, 52-53, Rm 217). _ b) IF NQ,i=lV!l1P,\1 !:3is:?v::itlai:)le;;! standt>y:t() PU!l11?1'B (AE?f9 45 , RID c of 4£i!lQWltil:g*

L.fe OR B/27G,@NT.§,UMI?

.. _ ). CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/11A1S000/ECA-1.1 ACTION/EXPECTED RESPONSE 3. (Continued) OR

All of the following:
FWST level -LESS THAN 8%
NC temperature

-GREATER THAN 200°F

Containment Spray -PREVIOUSLY IN SERVICE
Indicated containment sump level -GREATER THAN O.S FT. 4 of 83 Rev 31 RESPONSE NOT OBTAINED c. IF NC inventory lost outside containment, THEN GO TO Step 4. CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/SOOO/ECA-1.1 ACTION/EXPECTED RESPONSE 3. (Continued)

c.

_ FJ':: L OR

All of the following:
FWST level -LESS THAN 8%
NC temperature

-GREATER THAN 200°F

Containment Spray -PREVIOUSLY IN SERVICE
Indicated containment sump level -GREATER THAN O.S FT. 4 of 83 Rev 31 RESPONSE NOT OBTAINED c. IF NC inventory lost outside containment, THEN GO TO Step 4.

CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/N5000/ECA-1.1 ACTION/EXPECTED RESPONSE 3. (Continued) Likely NOT restored at this time and should continue. Transition back to ES-1.3 will be per this step or Enclosure 1 guidance.

e. RETURN TO procedure and step in effect. 5 of 83 Rev 31 RESPONSE NOT OBTAINED

a) IF transfer to Cold Leg Recirc is required, THEN perform the following:

(1) Ensure the following valves -OPEN:

1 NS-29A (NS Spray Hdr 1A Cont Isol)
1 NS-32A (NS Spray Hdr 1A Cont Isol)
1 NS-15B (NS Spray Hdr 1 B Cont Isol)
1 NS-12B (NS Spray Hdr 1 B Cont Isol). _ (2) GOTO EP/1/N5000IES-1.3 (Transfer To Cold Leg Recirculation

). _ b) RETURN TO procedure and step in effect. CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 ACTION/EXPECTED RESPONSE 3. {Continued) ISOp 1_ Likely NOT restored at this time and should continue. Transition back to ES-1.3 will be per this step or Enclosure 1 guidance.

e. RETURN TO procedure and step in effect. 5 of 83 Rev 31 DeS RESPONSE NOT OBTAINED d.

1) to restorerecirg follpy{s:

2) a) IF transfer to Cold Leg Recirc is required, THEN perform the following:

(1) Ensure the following valves -OPEN:

1 NS-29A (NS Spray Hdr 1A Cont 1501)
1 NS-32A (NS Spray Hdr 1A Cont 1501)
1 NS-158 (NS Spray Hdr 18 Cont 1501)
1 NS-128 (NS Spray Hdr 18 Cont 1501). _ (2) GOTO EP/1/A/5000/ES-1.3 (Transfer To Cold Leg Recirculation

). _ b) RETURN TO procedure and step in effect. CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/11A1S000/ECA-1.1 ACTION/EXPECTED RESPONSE IBOP 1 4. ., ** , .... a._ c. 1---.1 6. _al 60f83 Rev 31 DC!: RESPONSE NOT OBTAINED a. Perform the following: _ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ 2) WHEN trip breakers open, THEN reset ECCS. b. Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-S77, BB-46, Rm 496)
1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-S60, BB-46, Rm 372). a. GO TO Step 33. CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/11 A/5000/ECA-1.1 ACTION/EXPECTED RESPONSE 4. t;hs,-!re

a.

restart.S/I

5.

IBOP I '.' ":C-LEG

CO{l!lmJSUMIj

_ GO'\;fO 6 of 83 Rev 31 DeS RESPONSE NOT OBTAINED a. Perform the following: _ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ 2) WHEN trip breakers open, THEN reset ECCS. b. Dispatch operator to open the affected sequencer(s) control power breaker:

1 EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-577, BB-46, Rm 496)
1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-560, BB-46, Rm 372). a. GO TO Step 33.

CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/Al5000/ECA-1.1 ACTION/EXPECTED RESPONSE

FWST LEVEL CONTAINMENT PRESSURE GREATER THAN 15 BETWEEN 10 AND 15 LESS THAN 5% N/A c.

flD _ _ a .........

b. Verify at least one of the following annunciators

-LIT: _. 1AD-20, 8/3 "CONT. SUMP LEVEL >3.3 ft" OR

1AD-21, 8/3 "CONT. SUMP LEVEL ->3.3 ft". c. Align NS for recirc. REFER TO Enclosure 3 (Aligning NS for Recirculation).

7of83 Rev 31 RESPONSE NOT OBTAINED a. GO TO Step 10 . (PSIG) NS PUMPS REQU I RED 2 1 0 --. Will secure the 1 B NS pump. b. Perform the following: _ 1) WHEN at least one "CONT. SUMP LEVEL >3.3 ft" annunciator is LIT, THEN GO TO Step 8.c. _ 2) GO TO Step 9. CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 ACTION/EXPECTED RESPONSE fQI!Qwing -OPEN:;

1 NS-:20Al(NS,Pumj:)

'1A Sqct;tf(Qm F;WST)' * (NSd:)ump 1BSuct Ft9m FW,pljH itegpicgQ,:llrQ,Q1.lt1e.wlgllowiQQ)able: FWST LEVEL CONTAINMENT P RESSU Rf GREATER THAN 'G R'EA'T!!ER THAN BETWEEN 10 AND 5% LESS'THAN}I'O LESS THAN 5% N/A the EOUALTQ1INJ9M8ERfjSf;:OljIRijQ?:

a. Ahy NS pump -:*ON., b. Verify at least one of the following annunciators

-LIT: _. 1AD-20, 8/3 "CONT. SUMP LEVEL >3.3 ft" OR _. 1AD-21, 8/3 "CONT. SUMP LEVEL >3.3 ft". c. Align NS for recirc. REFER TO Enclosure 3 (Aligning NS for Recirculation ). 15 15 7 of 83 Rev 31 RESPONSE NOT OBTAINED a. GO TO Step 10. (PSIG) NS PUMPS REQUIRED 2 1 0 0 _ t)I,S pumps as IWili secure the 1 B NS pump. b. Perform the following: _ 1) WHEN at least one "CONT. SUMP LEVEL >3.3 ft" annunciator is LIT, THEN GO TO Step 8.c. _ 2) GO TO Step 9. CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/Al5000/ECA-1.1 ACTION/EXPECTED RESPONSE c. Ii. 80f83 Rev31 ,-,. RESPONSE NOT OBTAINED __ -il ...

_* ...... BIfII1lI ..... D -* QlllII .. lIIIDII _.* ...... 11 ... .... ,. Depending on reader speed 1 NI-184B should be open by this time and the crew would go back to ES-1.3 per
enclosure 1 guidance or previous WHENITHEN step (3.d.2) RNO). CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 ACTION/EXPECTED RESPONSE c. IFATi:ANY?iTIME.NS pumps are . _e

10. Initi.ate 8 of 83 Rev.31 '. RESPONSE NOT OBTAINED a.

_ 1) Ens'eJre;'NS Tfaio!,jA. -.RESET." 2)CI()sethe foll6wing'vab7es: _It 1 Hd(11ACorit Is()!) _ fi ;,:1 HdrttlA Cont

b.

tQILQl&ilig:' _ '1)

2)

-1 NS-158 (t:1JS Cool I S 91) :'\i' (" Hd: 1 Qi C"l .. : ""; ...... * .... 'L:. ..... .,,,, .. P.i3Y ., .... J:hi: on 1$01). Depending on reader speed 1NI-184B should be open by this time and the crew would go back to ES-1.3 per enclosure 1 guidance or previous WHENITHEN step (3.d.2) RNO). CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 -Page 1 of 1 52 of 83 Foldout Page Rev 31 1. Emergency Coolant Recirc Capability Restoration: _ b. RETURN TO procedure and step in effect. 2. ECCS Suction Source Monitoring Criteria:

IF the suction source is lost to any ECCS OR NS pump, THEN stop the affected pump.
IF FWST level decreases to less than 5%, THEN stop all pumps taking suction from the FWST.
IF both "CO NT. SUMP LEVEL >2.5 fi" annunciators on 1AD-20 and 1AD-21 dark, THEN stop all pumps taking suction from the containment sump. 3. CA Suction Source Switchover Criteria:
IF either of the following annunciators are lit, THEN REFER TO AP/1/A/55001006 (Loss of S/G Feedwater):

_. 1AD-5, H/4 "CACST LO LEVEL" OR

1AD-8, 8/1 "UST LO LEVEL". CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 -Page 1 of 1 52 of 83 Rev 31 Foldout Page 1. Emergency Coolant Recirc Capability Restoration:

_ b. RETURN TO procedure and step in effect. 2. ECCS Suction Source Monitoring Criteria:

IF the suction source is lost to any ECCS OR NS pump, THEN stop the affected pump.
IF FWST level decreases to less than 5%, THEN stop all pumps taking suction from the FWST.
IF both "CO NT. SUMP LEVEL >2.5 ft" annunciators on 1AD-20 and 1AD-21 dark, THEN stop all pumps taking suction from the containment sump. 3. CA Suction Source Switchover Criteria:
IF either of the following annunciators are lit, THEN REFER TO AP/1/A/5500/006 (Loss of S/G Feedwater):

_. 1AD-5, H/4 "CACST LO LEVEL" OR

1AD-8, 8/1 "UST LO LEVEL".

, , -It ) l V Duke Energy Catawba Nuclear Station Transfer to Cold Leg Recirculation Continuous Use PERFORMANCE I **********UNCONTROLLEDFORPRrnT********** (ISSUED) -PDF Format Procedure No. EP/IIAl5000/ES-1.3 Revision No. 021 Electronic Reference No. CP0094CV , . -l. ...... Duke Energy Catawba Nuclear Station Transfer to Cold Leg Recirculation Continuous Use PERFORMANCE I **********UNCONTROLLEDFORPRrnT********** (ISSUED) -PDF Format Procedure No. EP/IIAlSOOO/ES-1.3 Revision No. 021 Electronic Reference No. CP0094CV CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 1 of 38 Revision 21 A. Purpose This procedure provides the necessary instructions for transferring the safety injection system and containment spray system to the recirculation mode. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/1/A15000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 14, on low FWST level. b. EP/1/A15000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 10, on low FWST level. c. Other procedures whenever FWST level reaches the switchover setpoint. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/11A1S000/ES-1.3 1 of 38 Revision 21 A. Purpose This procedure provides the necessary instructions for transferring the safety injection system and containment spray system to the recirculation mode. B. Symptoms or Entry Conditions This procedure is entered from: a. EP/11A1S000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 14, on low FWST level. b. EP/11A1S000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 10, on low FWST level. c. Other procedures whenever FWST level reaches the switch over setpoint. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A1S000/ES-1.3 20f38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions BOP DOES ALL THESE ACTIONS .... _111'** .... "* .. * * -_1.11 ..... 11 ___ '18 Perform the following:

a. Ensure SII -RESET: _1) ECCS. _ 2) DIG load sequencers.

_ 3) IF AT ANY TIME a 8/0 occurs, THEN restart SII equipment previously on. b. Ensure the following valves -CLOSED:

1 FW-27A (NO Pump 1A Suet From FWST)
1 FW-SS8 (NO Pump 18 Suct From FWST). (RNO continued on next page) CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/SOOO/ES-1.3 2 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions ISOp DOES ALL THESE ACTIONS (Fcintouf Page).

S/I all time$. NOTE '5 S9Sh6(!JldHe;'** '. '. R .'. ,"W .*. 9 . ,.'... . W' ,'.' J? ' .. ;.1 ""." . :l'dY.. 2: _ * >3.3 f{n :.QR _ ",' 'd>>,'VJ", <<,., , c', '."S,',',,->!'> >""",>>>v> Perform the following:

a. Ensure SII -RESET: _1) ECCS. _ 2) DIG load sequencers.

_ 3) IF AT ANY TIME a 8/0 occurs, THEN restart S/I equipment previously on. b. Ensure the following valves -CLOSED:

1 FW-27 A (NO Pump 1 A Suct From FWST)
1 FW-SS8 (NO Pump 18 Suct From FWST). (RNO continued on next page)

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 2. (Continued) 30f38 Revision 21 RESPDNSE NOT OBTAINED c. IF valve{s) will not close, THEN: _ 1) Stop associated NO pump(s). 2) Depress the following "DEFEAT" pushbutton(s) for the affected train(s):

"C-LEG RECIR FWST TO CONT SUMP SWAP TRN A" * "C-LEG RECIR FWST TO CONT SUMP SWAP TRN 8". _ 3) Close the associated NO pump(s) containment sump suction valve(s).

d. IF FWST level less than 37% due to FWST puncture, THEN RETURN TO procedure and step in effect. e. IF both NS pumps are off, THEN GO TO Step 2 RNO g. f. IF either of the following annunciators are lit:

1AD-20, 8/2 "CONT. SUMP LEVEL >2.5 fi" OR _. 1AD-21, 8/2 "CONT. SUMP LEVEL >2.5 fi", _ THEN GO TO Step 3. (RNO continued on next page) CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 2. (Continued) 30f38 Revision 21 RESPDNSE NOT OBTAINED c. IF valve(s) will not close, THEN: _ 1) Stop associated ND pump{s). 2) Depress the following "DEFEAT" pushbutton(s) for the affected train(s):
"C-LEG RECIR FWST TO CONT SUMP SWAP TRN A" * "C-LEG RECIR FWST TO CONT SUMP SWAP TRN 8". _ 3) Close the associated ND pump(s) containment sump suction valve(s).

d. IF FWST level less than 37% due to FWST puncture, THEN RETURN TO procedure and step in effect. e. IF both NS pumps are off, THEN GO TO Step 2 RNO g. f. IF either of the following annunciators are lit:

1AD-20, 8/2 "CONT. SUMP LEVEL >2.5 fi" OR _. 1AD-21, 8/2 "CONT. SUMP LEVEL >2.5 fi", _ THEN GO TO Step 3. (RNO continued on next page)

'. ,. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A1S000/ES-1.3 ACTION/EXPECTED RESPONSE 2. (Continued)

3. 4of38 Revision 21 RESPONSE NOT OBTAINED g. IF all of the following conditions met:

FWST level -LESS THAN 8%
NC temperature

-GREATER THAN 200°F

Containment Spray -PREVIOUSLY IN SERVICE
Indicated containment sump level -GREATER THAN O.S FT. _ THEN GO TO Step 3. h. IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. i. IF both "CO NT. SUMP LEVEL >3.3 fi" annunciators on 1AD-20 and 1AD-21 dark, THEN stop all pumps taking suction from the containment sump. _ j. GO TO EP/1/A1S000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

_ Establish KC flow to affected NO Hx(s). B train only. No power to A train. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/SOOO/ES-1.3 ACTION/EXPECTED RESPONSE 2. (Continued) 4of38 Revision 21 RESPONSE NOT OBTAINED g. IF all of the following conditions met:

FWST level -LESS THAN 8%
NC temperature

-GREATER THAN 200°F

Containment Spray -PREVIOUSLY IN SERVICE
Indicated containment sump level -GREATER THAN O.S FT. _ THEN GO TO Step 3. h. IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. i. IF both "CO NT. SUMP LEVEL >3.3 fi" annunciators on 1AD-20 and 1AD-21 dark, THEN stop all pumps taking suction from the containment sump. _ j. GO TO EP/1/A/SOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

_ Establish KC flow to affected NO Hx(s). B train only. No power to A train. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A1S000/ES-1.3 ACTION/EXPECTED RESPONSE 4. a. b. c. S of 38 Revision 21 RESPONSE NOT OBTAINED a. Perform the following: _ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ 2) WHEN trip breakers open, THEN reset ECCS. b. Dispatch operator to open the affected sequencer(s) control power breaker:

1EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-S77, BB-46, Rm 496)
1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-S60, BB-46, Rm 372). : CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A1S000/ES-1.3 ACTION/EXPECTED RESPONSE 4.

a.

c.

... S of 38 Revision 21 RESPONSE NOT OBTAINED a. Perform the following: _ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ 2) WHEN trip breakers open, THEN reset ECCS. b. Dispatch operator to open the affected sequencer(s) control power breaker:

1EDE-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSA) (AB-S77, BB-46, Rm 496)
1 EDF-F01 F (Diesel Generator Load Sequencer Panel 1 DGLSB) (AB-S60, BB-46, Rm 372).

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/SOOO/ES-1.3 ACTION/EXPECTED RESPONSE S. *

6of38 Revision 21 RESPONSE NOT OBTAINED a. Perform the following:

_ 1) Manually open affected valve(s) . 2) IF valve{s) will not open, THEN: _ a) Stop the ND pump(s) associated with a closed containment sump suction valve(s). b) Close the associated ND pump(s) suction valve from the FWST:

1 FW-27A (ND Pump 1A Suct From FWST)
1 FW-SSB (ND Pump 1 B Suct From FWST). (RNO continued on next page) CNS TRANSFER TO COLO LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 5.

a SqGD

1 BCcWltSul11g.

- J,,"" ........* ". . .... .'. " 6 of 38 Revision 21 RESPONSE NOT OBTAINED a. Perform the following: _ 1) Manually open affected valve(s).

2) IF valve(s) will not open, THEN: _ a) Stop the NO pump(s) associated with a closed containment sump suction valve(s).

b) Close the associated NO pump(s) suction valve from the FWST:

1 FW-27A (NO Pump 1A Suct From FWST)
1 FW-55B (NO Pump 1 B Suct From FWST). (RNO continued on next page)

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued) 70f38 Revision 21 RESPONSE NOT OBTAINED c) WHEN the ND pump(s)'Suction valve from the FWST is closed, THEN perform the following: (1) Attempt to manually open the affected containment sump suction valve(s).

1NI-185A (ND Pump 1A Cont Sump Suct)
1NI-184B (ND Pump 1B Cont Sump Suet). (2) IF affected containment sump suction valve will not open, THEN dispatch two operators to open the affeeted valve(s):
1NI-185A (ND Pump 1A Cont Sump Suet) (AB-545, EE-FF, 52-53, Rm 217)
1NI-184B (ND Pump 1B Cont Sump Suct) (AB-545, FF-GG, 52-53, Rm 217). 3) IF both containment sump suction valves are closed, THEN: _ a) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ b) GO TO EP/1/A15000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued) 7 of 38 Revision 21 RESPONSE NOT OBTAINED c) WHEN the ND pump(s)suction valve from the FWST is closed, THEN perform the following: (1) Attempt to manually open the affected containment sump suction valve(s) .

1NI-185A(NDPump1A Cont Sump Suct)
1 NI-184B (ND Pump 1 B Cont Sump Suct). (2) IF affected containment sump suction valve will not open, THEN dispatch two operators to open the affected valve(s):
1NI-185A (ND Pump 1A Cont Sump Suct) (AB-545, EE-FF, 52-53, Rm 217)
1 NI-184B (ND Pump 1 B Cont Sump Suct) (AB-545, FF-GG, 52-53, Rm 217). 3) IF both containment sump suction valves are closed, THEN: _ a) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ b) GO TO EP/1/A15000/ECA-1.1 (Loss Of Emergency Coolant Recirculation

). CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

b. *

8of38 Revision 21 RESPONSE NOT OBTAINED b. Perform the following:

_ 1) Manually close affected valve(s) . 2) IF valve{s) will not close, THEN: _ a) Stop associated ND pump(s). b) Depress the following "DEFEAT" pushbutton(s) for the affected train(s):

"C-LEG RECIR FWST TO CONT SUMP SWAP TRN A" * "C-LEG RECIR FWST TO CONT SUMP SWAP TRN S". _ c) Close the associated N D pump(s) containment sump suction valve(s).

d) IF both containment sump suction valves are closed, THEN: _ (1) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ (2) GOTO EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation). CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/NSOOO/ES-1.3 ACTION/EXPECTED RESPONSE S. (Continued) b.Vg@fy .1&YV -27

B;§UGl Fro*itl' 8of38 Revision 21 RESPONSE NOT OBTAINED b. Perform the following:

_ 1) Manually close affected valve(s).

2) IF valve{s) will not close, THEN: _ a) Stop associated ND pump(s). b) Depress the following "DEFEAT" pushbutton{s) for the affected train{s):

"C-LEG RECIR FWST TO CONT SUMP SWAP TRN A" * "C-LEG RECIR FWST TO CONT SUMP SWAP TRN B". _ c) Close the associated ND pump(s) containment sump suction valve(s).

d) IF both containment sump suction valves are closed, THEN: _ (1) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ (2) GO TO EP/1/NSOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation). CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/N5000/ES-1.3 90f38 Revision 21 ACTION/EXPECTED RfSPONSE RESPONSE NOT OBTAINfD 5. (Continued)

c. _1) 2)

c. _1) Should start 1 B NO pump at this time. CRITICAL TASK! 2) IF no ND pump can be started OR no ND train can be aligned for recirc, THEN: _ a) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ b) GO TO EP/1/N5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

1) Perform the following:

_ a) Stop NI pumps. _ b) WHEN pressure is less than 1620 PSIG, THEN start NI pumps. No "A" train power . . CRITICAL STEP due to potential for release of radioactivity to environment. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/SOOO/ES-1.3 ACTION/EXPECTED RESPONSE S. (Continued)

c.

NO'pumpsi\QN. Should start 1 B NO pump at this time. CRITICAL TASK! d. _ 1)

2)

Jg!lqwing,;¥alve§.f _ .*

1 13 .* MIFilfI6v/t

- ...... , .. ,. .."P ..,.. . ...... . - 9 of 38 Revision 21 RESPONSE NOT OBTAINED c. th(!f; foHqWI!5g: _ 1) S19Xt ND\pump{s) alig'(1ed tQ'9n Qpen ,:?ur:nl? suc;tibn va,lYe; 2) IF no ND pump can be started OR no ND train can be aligned for recirc, THEN: _ a) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ b) GO TO EP/1/A/SOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation ). 1) Perform the following: _ a) Stop NI pumps. _ b) WHEN pressure is less than 1620 PSIG, THEN start NI pumps. No "A" train power. CRITICAL STEP due to potential for release of radioactivity to environment. CNS TRANSFER TO COLD lEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

e.

OR
g. RESPONSE NOT OBTAINED No power to 1 ND-32A and 1 NV-203A. f. Perform the following:

10 of 38 Revision 21 _ 1) IF 1 NI-9A (NV Pmp C/l Inj Isol) AND 1NI-10B (NV Pmp C/l Inj Isol) are closed, THEN maintain charging flow greater than 60 GPM. 2) Close the following valves:

1 NV-203A (NV Pumps A&B Recirc Isol)
1 NV-202B (NV Pmps A&B Recirc Isol). 1NI-333B is CRITICAL TASK 1NI-136B is CRITICAL TASK CNS TRANSFER TO COLD lEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

e.

.'. ifr:ain 1A:,Hot l.3:e'}';lo* bl)' ........ ,.."QA _. IsqO; g. OR SuclXEOvei t} ']J); RESPONSE NOT OBTAINED No power to 1 ND-32A and 1 NV-203A. f. Perform the following: 10 of 38 Revision 21 _ 1) IF 1 NI-9A (NV Pmp C/l Inj Isol) AND 1NI-10B (NV Pmp C/l Inj Isol) are closed, THEN maintain charging flow greater than 60 GPM. 2) Close the following valves:

1 NV-203A (NV Pumps A&B Recirc Isol)
1 NV-202B (NV Pmps A&B Recirc Isol).

11 NI-333B is CRITICAL TASK 3 Y 1 NL8mps) 6B(ND $t.tpply .i:4 .. ....... . -136B is CRITICAL TASK CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

h. _2) 3) It is Critical that 1 N 1-1 OOB and 1.u.1\I 'l£:'lA be closed from the ..

control boards and an operator be dispatched to close 1 NV-2S2A (which has no power). Ref DBD for NI system. NOTE: The scenario ends on the next page. 11 of 38 Revision 21 RESPONSE NOT OBTAINED _ 2) Dispatch operator to close 1NI-100B (NI Pmps Suct From FWST) (AB-552, HH-JJ, 53-54, Rm 234). _III _III b) IF 1 NV-253B (NV Pumps Suct From FWST) cannot be closed, THEN dispatch operator to perform the following: _ (1) Open 1 EMXJ-R03A (NV Pump Suction From FWST Motor (1 NV253B>> (AB-560, GG-56, Rm 330). _ (2) Close 1 NV-253B (NV Pumps Suct From FWST) (AB-554, HH-JJ, 53-54, Rm 234) (Ladder needed). CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 11 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 5. (Continued)

h.

_ 2) _ 2) Dispatch operator to close 1 NI-100B It is Critical that 1 NI-1 OOB and '" "IV 25.2f-be closed from the control boards and an operator be dispatched to close 1 NV-252A (which has no power). Ref DBD for Nl system. NOTE: The scenario ends on the next page. (NI Pmps Suct From FWST) (AB-552, HH-JJ, 53-54, Rm 234). b) IF 1 NV-253B (NV Pumps Suct From FWST) cannot be closed, THEN dispatch operator to perform the following: _ (1) Open 1 EMXJ-R03A (NV Pump Suction From FWST Motor (1 NV253B)) (AB-560, GG-56, Rm 330). _ (2) Close 1 NV-253B (NV Pumps Suct From FWST) (AB-554, HH-JJ, 53-54, Rm 234) (Ladder needed). CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

i. * *

6. WHEN FWST level decreases to 11 % (1AD-9, Et8 "FWST LO-LO LEVEL" alarm lit), THEN perform the following:

a. Stop NS Pumps. 12 of 38 Revision 21 RESPONSE NOT OBTAINED i. IF any S/I pump on without a suction flowpath, THEN stop the affected pump(s). THE SCENARIO CAN BE TERMINATED AT THIS POINT. b. Align NS for recirc. REFER TO Enclosure 2 (Aligning NS for Recirculation).

Aligning NS for Recirc is JPM and should not be allowed during this scenario.

7. IF any NS pump in service with suction aligned to FWST, THEN perform the following:

a. Ensure appropriate operator is in possession of Enclosure 2 (Aligning NS for Recirculation).

b. Designate operator to ensure NS pumps immediately secured when FWST level decreases to 11 % OR 1AD-9, E/8 "FWST LO-LO LEVEL" alarm lit. c. IF time and manpower permit, THEN notify designated operator to review Enclosure 2 (Aligning NS for Recirculation) for current plant conditions.

NS pumps (if running) are secured per Enclosure 1 when FWST reaches 11 % level. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 ACTION/EXPECTED RESPONSE 5. (Continued)

i.

fonOws: _. _ _ *

6. WHEN FWST level decreases to 11 % (1AD-9, Et8 "FWST LO-LO LEVEL" alarm lit), THEN perform the following:

a. Stop NS Pumps. 12 of 38 Revision 21 RESPONSE NOT OBTAINED i. IF any S/I pump on without a suction flowpath, THEN stop the affected pump(s). THE SCENARIO CAN BE TERMINATED AT THIS POINT. b. Align NS for recirc. REFER TO Enclosure 2 (Aligning NS for Recirculation).

Aligning NS for Recirc is JPM and should not be allowed during this scenario.

7. IF any NS pump in service with suction aligned to FWST, THEN perform the following:

a. Ensure appropriate operator is in possession of Enclosure 2 (Aligning NS for Recirculation).

b. Designate operator to ensure NS pumps immediately secured when FWST level decreases to 11 % OR 1AD-9, El8 "FWST LO-LO LEVEL" alarm lit. c. IF time and manpower permit, THEN notify designated operator to review Enclosure 2 (Aligning NS for Recirculation) for current plant conditions.

NS pumps (if running) are secured per Enclosure 1 when FWST reaches 11 % level. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 -Page 1 of 1 20 of 38 Foldout Page Revision 21 1. SII Reinitiation Criteria:

IF NC subcooling based on core exit TICs is less than OaF OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN manually start SII pumps and align valves as required to restore subcooling and Pzr level. 2. Loss Of Emergency Coolant Recirculation:
IF Step 5 has been completed AND recirc flow is subsequently lost, THEN perform the following:

a. IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. b. GO TO EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

3. Loss Of FWST Supply To ECCS Pumps:

IF FWST level decreases to less than 11 %, THEN stop NS pumps taking suction from the FWST.
IF FWST level decreases to less than 5%, THEN stop all pumps taking suction from the FWST. CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 -Page 1 of 1 20 of 38 Foldout Page Revision 21 1. SII Reinitiation Criteria:
IF NC subcooling based on core exit TICs is less than OaF OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN manually start SII pumps and align valves as required to restore subcooling and Pzr level. 2. Loss Of Emergency Coolant Recirculation:
IF Step 5 has been completed AND recirc flow is subsequently lost, THEN perform the following:

a. IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. b. GO TO EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).

3. Loss Of FWST Supply To ECCS Pumps:

IF FWST level decreases to less than 11 %, THEN stop NS pumps taking suction from the FWST.
IF FWST level decreases to less than 5%, THEN stop all pumps taking suction from the FWST.}}

@@ Line 2: / Line 2: @@
 | number = ML100470564
 | issue date = 02/02/2010
-| title = Catawba, Initial Exam 2009-301 Final Simulator Scenarios
+| title = Initial Exam 2009-301 Final Simulator Scenarios
 | author name =
 | author affiliation = NRC/RGN-II

ML100470564: Difference between revisions

Revision as of 17:47, 16 April 2019

Text

4.1 revision

4.1 revision

4.3 revision

4.3 revision

2.5 After

4.1 Automatic

4.9 Rapid

2.5 After

4.1 Automatic

4.9 Rapid

4.2 Boration

4.2 Boration

4.2 Boration

4.2 Boration

4.2 Boration

4.2 Boration

4.1 Power

4.1 Power

2.7 Never

2.7 Never

4.1 Turbine

4.7 Generator

4.1 Turbine

4.7 Generator

3.5.2 basis

3.5.2 basis

4.1 revision

4.1 revision

2.5 After

4.1 Automatic

4.9 Rapid

2.5 After

4.1 Automatic

4.4 Alternate

4.9 Rapid

4.3 Dilution

4.3 Dilution

4.3 Dilution

4.3 Dilution

4.3 Dilution

4.3 Dilution

2.8 lfthe

4.2 Power

4.2 Power

4.1 Power

4.1 Power

2.7 Never

2.7 Never

4.1 Turbine

4.7 Generator

4.1 Turbine

4.7 Generator

2.2.1 Decrease

2.2.1 Decrease

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