Text

Initial Exam 2012-301 Draft Simulator Scenarios
	ML120690593
Person / Time
Site:	Sequoyah
Issue date:	02/21/2012
From:	; NRC/RGN-II
To:	; Tennessee Valley Authority
	Gerald Laska
Shared Package
ML120550268	List: ML120690513; ML120690589; ML120690593;
References
	50-327/12-301, 50-328/12-301
	Download: ML120690593 (308)
	v • d • e

Appendix 0 Scenario Outline Attachment I Facility: Sequoyah Scenario No.: 1 Op Test No.: 2012-30 1 Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 1, 100% power, EOL Turnover: Maintain current conditions; currently in 0-GO-5 Section 5.2, At Power Conditions Target CTs: Manually start the 1 B-B EDG prior to placing equipment in PTL in ECA-0.0 Manually start the 1 B-B SI pump prior to completion of ES-0.5 step 11.

Event No. MaIf. No. Event Type* Event Description

1. CVII I-ATC/SRO VCT Level Channel 129 fails high. The ATC will manually control VCT level by placing 1-LCV-62-1 18 in VCT position using the ARP.

2. CC1OA C-BOP/SRO The lA-A CCS Pump trip coupled with a failure of the lB-B CCS pump TS-SRO to auto start. The BOP will manually start the I B-B CCS pump using

. AOP-M.03. The SRO will address Tech Specs and determines the lA-A pre-insert CCS pump is INOPERABLE.

CCO9B

3. RCO5 C-ATC/SRO A small leak will develop PORV 68-334. The ATC will shut the isolation TS-SRO valve 68-333 to isolate the PORV using Immediate Operator Actions and AOP-R.05. The SRO will address Tech Spec and determines the PORV is INOPERABLE.

4. TS-SRO The crew receives notification from Engineering that SI Pumps lA-A and 1 B-B have the wrong grade of lube oil. The SRO will address Tech Specs and determines both SI pumps are INOPERABLE.

5. R ATC The crew initiates a power reduction using AOP-C.03 in order to comply N BOP/SRO with the LCO action requirements and station a management directive

6. THO2C M-AII A SBLOCA will develop. The crew will respond using E-0 to trip the reactor and initiate Safety Injection and ultimately transition to E-1.

7. EDO1 M-AII Loss of Off-Site Power resulting in a loss of power to both 6.9 KV Shutdown Boards.

8. EGO8B C-BOP 1 B-B EDG fails to auto start.

IA-A EDG trips and cannot be started.

pre-insert The BOP manually starts lB-B EDG to energize shutdown board lB-B.

EGO2A

9. CVO1 B C-ATC lB-B CCP pump breaker trips.

pre-insert The lB-B SI fails to auto start, the ATC manually starts the lB-B SI SI13B pump.

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

Appendix D Scenario Outline Attachment I 2012-301 Scenario I Summary EVENT I Following turnover when directed by the lead examiner, VCT Level Channel 129 fails high. The ATC will manually control VCT level by placing 1 -LCV-62-1 18 in VCT position using the ARP.

EVENT 2 When directed by the lead examiner, the lA-A CCS Pump trip coupled with a failure of the 1 B-B CCS pump to auto start. The BOP will manually start the 1 B-B CCS pump using AOP-M.03. The SRD will address Tech Specs and determines the lA-A CCS pump is INOPERABLE and enters LCO 3.7.3.

EVENT 3 When directed by the lead examiner, a small leak will develop PORV 68-334. The ATC will shut the isolation valve 68-333 to isolate the PORV using AOP-R.05. The SRO will address Tech Spec and determines the PORV is INOPERABLE.

EVENT 4 When directed by the lead examiner, the crew will receive notification from Engineering that SI Pumps lA-A and 1 B-B have the wrong grade of lube oil. The SRO addresses Tech Spec and determines both SI pumps are INOPERABLE. The SRO will determine the action of LCO 3.0.3 applies and makes preparation to reduce power within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

EVENT 5 The crew initiates a power reduction using AOP-C.03 in order to comply with the LCO action requirements and a station management directive.

EVENT 6 When directed by the lead examiner, a SBLOCA will develop. The crew will respond using E-0 to trip the reactor and initiate Safety Injection and ultimately transition to E-1.

EVENT 7 and 8 Shortly after the trip when directed by the lead examiner, off-site power will be lost. In addition, lB-B EDG fails to auto start, and must be started manually. The lA-A EDG trips and cannot be started. The BOP manually starts 18-B EDG to energize shutdown board lB-B.

EVENT 9 During implementation of the EOPs, the lB-B CCP Pump trips and the I B-B SI pump fails to auto start. The ATC manually starts the 1 B-B SI pump.

The scenario terminates as directed by the Lead Examiner upon completion of FR-Z.l EOP flow: E-0, FR-Z.1, E-1 (Note; ECA-0.0 MAY be entered briefly prior to starting EDG)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # Page 1 of 54 Event

Description:

Volume Control Tank Level Transmitter LT-62-129 Fails High Time fl Position Applicants Actions or Behavior Console Operator: When directed, initiate Event 1 VCT Level Ch 129 fails high Indications available:

. Alarm XA-55-6C, A-3, LS-62-129A/B VOLUME CONTATCL TANK LEVEL HI-LOW (If actual VCT level gets to the low level alarm setpoint.

. 1-LT-62-129 Indication failing high (ICS or M-6 Trend Recorder)

LS-62-129A/B VOLUME CONTROL TANK LEVEL HI-LOW Probable 1. High Level Causes [a] VOT divert valve malfunction or misaligned.

[b] Letdown flow rate greater than makeup flow rate.

[C] i-LT-62-130A failing high.

CAUTION If actual level is permitted to become low, charging pump gas intrusion could occur. C.51 NOTE 1 High failure of i-LT-62-129A or 1-LT-62-130A defeats auto switch over to RWST on low level.

NOTE 2 High failure of 1-LT-62129A will divert letdown flow with NO affect on Auto makeup.

ATC Responds to ARP 1-AR-M6-C A-3.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

[1] COMPARE indicated level between [i-U-62-129] (i-M-6) arid ATC ICS computer point LOII2A (1-LT-62-130).

31 IF 1-LT-62-129A or 130A failed high, THEN ENSURE f 1-LcV-62-1181 in VCT position USING f1-HS2-118A]

ATC AND manually operate as required to maintain VCT level.

Low failure of 1-LT-62-130A will initiate Auto makeup.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # I Event # 1 Page 2 of 54 Event

Description:

Volume Control Tank Level Transmitter LT-62-129 Fails High Time I Position I Applicants Actions or Behavior

[6] IF HIGH level. THEN

[a] ENSURE [i-LV-62-1i8] aligned to HUT

[b] STOP VCT makeup.

Examiner Note: SRO may discuss effect of failure as per Notes 1 and 2 above.

Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS). (Note:

Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when desired.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 2 Page 3 of 54 Event

Description:

lA-A CCS Pump trip, the BOP will manually start the 18-B CCS pump Time fl Position Applicants Action or Behaviors Console Operator: When directed, initiate Event 2, lA-A CCS Pump trip Indications available:

O-AR-M27-B-A, Al, CCS REAC BLDG SUPPLY HEADER FLOW LOW O-AR-M27-B-A, E4, ERCWICCS PUMP MOTOR TRIP Trip indication on IA-A CCS Pump (Red light off, Green and white lights off)

ERCW!CCS PUMP MOTOR TRIP t2] IF CCS motor trip, THEN GO TO AOP-M.03, Loss of Component Cooling Water.

[3] DETERMINE which motor tiipped.

[4] TURN control switch to OFF position to reset alarm.

[5] DISPATCH operator to investigate cause of alarm 161 EVALUATE LCO 31.3 (COS) or 3.7A (ERCW).

CCS REAC BLDG SUPPLY HEADER FLOW LOW

[1] IF Phase B isolation, THEN CONTINUE with emergency procedure(s) in progress.

[2] CHECK reactor building supply header flow by observing 11 -FI-70-1 421

[3] ENSURE CCS heat exchanger aligned propeily in accordance with 1 -SO-70-1, component Cooling Water System Train k

[4] IF pump problem exists with inservice pump, THEN START standby CCS pump if available.

[5] IF loss of component cooling water is suspected, THEN GO TO AOP-MJJ3, Loss of component Cooling Wate, Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario# 1 Event# 2 Page 4 of 54 Event

Description:

IA-A CCS Pump trip, the BOP will manually start the 1 B-B CCS pump Applicants Action or Behaviors Responds to ARP O-AR-M27-B-A, Al or E4.

Transitions to AOP-M.03, Loss of Component Cooling Water DIAGNOSE the failure:

GOTO IF... SECTION PAGE CCS Pump trip OR 2.1 4 CCS Pump failure (running pump NOT pumping forward)

SRO Enter AOP-M.03, Loss of Component Cooling Water SRO Determine section 2.1 applies (CCS Pump Trip or Failure) 2.1 CCS Pump Trip or Failure CAUTION

If Train A CCS flow is lost and CANNOT be restored promptly OR if RCP motor thrust bearing temp alarm (M-5B, E-3) is received, then RCPs must be stopped in Step 3 to prevent damage.

. If any Containment Spray Pump is running with NO CCS cooling, spray pump may experience bearing failure after 10 minutes.

1. IDENTIFY and LOCK OUT taHed CCS BOP Pump. fO-M-27B BOP Places lA-A CCS pump HS in PTL BOP 2. CHECK affected pump aligned to supply Train A CCS.

3. ENSURE affected units standby CCS SRO Pump (aligned to Train A) RUNNiNG.

DI.i, fh IP..R ri,mn I-l fr TRT

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # I Event # 2 Page 5 of 54 Event

Description:

IA-A CCS Pump trip, the BOP will manually start the 1 B-B CCS pump Time Position Applicants Action or Behaviors

4. CHECK Train A CCS Heat Exchanger inlet pressure NORMAL for present plant conditions.

[1-Pl-70-24A, IA1/1A2 CCS HXI

[2-Pl-70-17A, 2A1/2A2 CCS HX

Between 87 psig and 110 psig NOTE

When Train A CCS is out of service, the affected units Train A CCPs, SI Pumps, and RHR Pumps are INOPERABLE for ECCS purposes due to not being able to fulfill their design function for sump recirculation (due to loss of CCS to RHR Hx).

If necessary, the affected CCPs, SI Pumps, and RHR Pumps can be operated without CCS cooling water to mechanical seal HXs. [CA]

5. EVALUATE Tech Specs and EPIP-1 SRO USING Appendix H.

L........ LL.. I ff 7 A £.... f%fr I A LIMITiNG CONDITION FOR OPERATION 3J3 At least two independent component coo4 water loops shall be OPERABLE.

APPL1CABIU1Y MODES 1,2,3 and 4.

ACTION:

With only one component cooling water loop OPERABLE, restore at least two loops to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 31) hours.

6. IF standby Thermal Barrier Booster Pump(s) running, BOP THEN ENSURE one pump in standby USING 1 (2)-SO-70-1, Component Cooling Water System.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 2 Page 6 of 54 Event

Description:

lA-A CCS Pump trip, the SOP will manually start the 16-8 CCS pump Time Position Applicants Action or Behaviors

7. GOTOStepl5.

CREW p

15. NOTIFY SM to evaluate OPDP-9, Emergent Issue Response.

16. INITIATE Maintenance on failed pump.

CREW

17. GO TO appropriate plant procedure.

END OF SECTION Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event when Technical Specifications are identified.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 3 Page 7 of 54 Event

Description:

PORV 68-334 leaks, the ATC will shut the isolation valve 68-333 to isolate the PORV Time Position Applicants Actions or Behavior Simulator Operator: at Lead Examiner direction, insert Event 3, 1-FCV-68-334 Pressurizer PORV fails 5% Open IndicationslAlarms:

Indications 1-M-4:

1-XX-68-363A, PZR PORV ACOSROTIC MONITORS: XI-68-334A indicates elevated acoustic (flow) noise; (Possible)

1-Tl-68-331: 68-340.334, XE-340.334 TAILPIPE TEMPS 1-M-5

RCS PR PRESS (Chs 1-4), 1-PI-68-340A, 334, 323, 322: showing RCS (Pzr) pressure going down; (Possible)

PRT LEVEL, 1-Ll-68-300 shows an increasing trend (magnitude proportional to time PORV remained open) (Possible)

PRT PRESSURE, 1-Pl-68-301 shows an increasing trend (magnitude proportional to time PORV remained open) (Possible)

PRT TEMPERATURE, 1-Tl-68-309 shows an increasing trend (magnitude proportional to time PORV remained open) (Possible)

RCS PZR PRESS Recorder 1-PR-68-340 shows a decreasing pressure trend proportional to time PORV remained open (Possible)

RCS LOOP I HL WIDE RANGE PRESS Recorder 1-PR-68-69 shows a decreasing pressure trend proportional to time PORV remained open (Possible) 1-M-6

RCS WR HL PRESSURE LOOP 3 1-Pl-68-66A, shows a decreasing pressure value; (Possible)

RCS HL PRESS WIDE RANGE 1-Pl-68-62, shows a decreasing pressure value; (Possible)

RCS HL PRESS WIDE RANGE 1-PI-68-69, shows a decreasing pressure value; (Possible)

Annunciators:

1-M-5

1-XA-55-5A D-4: PS-68-340G1F PRESSURIZER PRESSURE LOW BACKUP HTRS ON (Possible)

E-2: TS-68-331 PRESSURIZER POWER RELIEF LINE TEMP HIGH

1-XA-55-5C B-6: XS-68-363 PRESSURIZER RELIEF VALVE OPEN (Possible)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # I Event # 3 Page 8 of 54 Event

Description:

PORV 68-334 leaks, the ATC will shut the isolation valve 68-333 to isolate the PORV Time Position fl Applicants Actions or Behavior TS48-331 PRESSURIZER POWER RELIEF LINE TEMP HIGH

[1] IF PZR pressure is less than 2315 psig (PORV reset> THEN ENSURE both power relief valves closed.

f2] IF PORV failed open or suspected partially open, THEN GO TO AOP-L04, Pressurizer Instrument and Control Malfunctions.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

ATC Responds to ARP 1-AR-M5-A, E-2.

SRO transitions to AOP-I.04, Pressurizer Instrument And Control SRO Malfunctions Section 2.1, Uncontrolled RCS pressure drop due to open PORV in Modes 1-3 NOTE: If spray valve is open due to pressure instrument failure, then Section 13 is the appropriate entry point.

I. DIAGNOSE the failure:

GOTO IF... SECTION PAGE Uncontrolled RCS pressure drop due to open PORV 2.1 4 in Modes 1-3

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 3 Page 9 of 54 Event

Description:

PORV 68-334 leaks, the ATC will shut the isolation valve 68-333 to isolate the PORV Time Position AppIicants Actions or Behavior 2.1 Uncontrolled RCS Pressure Drop Due to Open PORV in Modes 1-3 CAUTION Partially open PORV may display no light indications.

NOTE Step I is an IMMEDIATE ACTION.

1. CHECK pzr PORVs CLOSED: CLOSE affected PORV and/or block valve as necessary to stop RCS pressure drop.

. valve position indication IF PORV and/or block valve cannot be

. acoustic monitors, closed or isolated, ATC THEN TRIP the reactor AND INITIATE Safety Injection AND GO To E-0, Reactor Trip or Safety Injection MONITOR RCS pressure STABLE or RISING.

ATC 3. CHECK SI signal NOT actuated.

ATC 4. ENSURE available pzr heaters ENERGIZED as necessary.

ATC Places HS-68-341 H to ON, if required.

CAUTION RCS pressure changes and changes in RCS boron concentration (due to differences between pzr and RCS boron) may impact core reactivity.

5. MONITOR reactor power:

a. CHECK reactor in Mode 1 or 2 ATC

b. MONITOR core thermal power for unexpected changes.

6. EVALUATE EPIP-1, Emergency Plan Classification Matrix.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 3 Page 10 of 54 Event

Description:

PORV 68-334 leaks, the ATC will shut the isolation valve 68-333 to isolate the PORV Time Position Applicants Actions or Behavior

7. EVALUATE the following Tech Specs for applicability:

SRO

. 3.2.5 DNB Parameters

. 3.4.3.2, PORVs LIMNG CONDITION FOR OPERA11ON 3.2.5 The folkiwing DNB related parameters shall be maintained within the limits sho on Table 3.2-1:

a Reactor Coolant System (RCS)T

b. Pressurizer Pressure

c. RCSToIaI Row Rate APPLICABIUTY: MODEl ACTION:

Wrtli any of the above parameters exceeding Its limit restore the parameter to within its llmit within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months o reduce THERMAL POWER to less than 5% of RATED ThERMAL POWER within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

TABtE 3.2-1 DNB PARAMETERS LIMITS 4locçsln PARAMETER Reactcw Codant System T <583°F Pessuizer Pressure 2220 psta° Reado Coornt System FiOure 32-1 Ta1 fl 3.4.3.2 T power relief valves (PORVs) and their associated block valves shall be OPERABLE.

APP1JCABIUTY: MODES 1,2, antI 3.

ACTION:

b. With one PORV inoperable and incapable of RCS pressure control, wIthin 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months either restore the PORV to OPERABLE status or close the associated block valve and remeve por from the block valve; restore the PORVtO OPERABLE status within the following 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 3 Page 11 of 54 Event

Description:

PORV 68-334 leaks, the ATC will shut the isolation valve 68-333 to isolate the PORV Time Position Applicants Actions or Behavior

& IF PORV block valve must be closed OR power must be removed from block valve OIDI to comply with LCO 3.4.3.2, THEN REFER TO 0-80-68-3, Pressurizer Pressure Control System.

Examiner Note: The following CREW Brief and Notification actions are not contained in the procedure.

Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when the SRO completes Tech Spec evaluation.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 4 Page 12 of 54 Event

Description:

SI Pumps lA-A and 16-B have the wrong grade of lube oil Applicants Actions or Behavior Receives call that SI Pumps lA-A and I B-B have the wrong grade of lube oil, affecting operability of both pumps.

LIMITING CONDITION FOR OPERATION 3.52 Two ECCS trains slalI be OPERABLE NOTES -

1. In MODE 3, both safety injectkin (SI) pump tk,v paths may be isolated by dosing the isolation valves for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to perform pressure isolation valve testing per SR 4.4.6.3.

2. In MODE 3, ECCS pimps may be made incapable of injecting to sipod transition into or from the APPIJCABILITY of LCO 3.4.12, Low Temperature Oveipressure Protection (ITOP)

System, for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or iritil the temperature of all RCS cold legs exceeds LTOP arming temperature (350F) specified in the PTLR plus 25F, whichever comes first APPUCABIUW: MODES 1,2 and 3.

ACTION:

a. With one or more trains inoperable and with at least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available, restore the inoperable train(s) to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be ni at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the felk,ing 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b, With less than 100% of the ECCS how equivalent to a single OPERABLE ECCS train available, immediately enter LCD 3.0.3.

a4 IJMmNG CONDITIONS FOR OPEATION AND SURVEILLANCE REQUIREMENTS 314.0 APPUCABIIJTY UMNG CONDITION FOR OPERATION 3.C3 lMien a Umilinq Condition for Operation is not met, except as provided in the associated ACTION requirements, within one hour action shall be initiated to place the unit ni a MODE in which the Specification does not apply by placing it, as applicable, in:

1. At least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

2. At least HOT SHUTDOWN within the folkwing 5 hews, and

3. At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Where corrective measures are completed that permit operation tinder the AC11ON reqtkements, the ACTION may be talen in accordance with the specified time limits as measured from the lime dfailure to meet the Limiting Con&tion for Operation. Exceptions to these requirements are stated in the individual Specifications.

Examiner Note: If desired, prompt the Booth Operator to provide the cue from station management to reduce power within one hour.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event# 5 Page 13 of 54 Event

Description:

Power reduction using AOP-C.03 Time Position Applicants Actions or Behavior Simulator Operator: No action required for Event 5, Rapid Power reduction SRO Directs performance of AOP-C.03 RAPID SHUTDOWN OR LOAD REDUCTION.

ENSURE crew has been biefed on read Mty S RO management expectations USING Appendix A.

REACTIVITY MANAGEMENT BRIEFING NOTE This appendix should be used in addition to event-based brief.

[1] ENSURE crew has been briefed on the following:

a Reason for Rapid Shutdown or Load Reduction a Load Reduction Rate:________

a Desired final power level:______

a Reactivity Management expectations:

a Unit Supervisor shall concur with all reactivity manipulations a Ensure reactor responding as expected using diverse indications a Tavg-Tref Mismatch requirements:

a 3°F control band a 5°F reactor trip criteria a Crew focus Will be on reducing power in a controlled and conservative manner.

OATC will monitor rod insertion limits and AFD limit a Boration source:

. Crew will monitor reactor trip and turbine trip criteria using App. B a CR0 will stop secondary plant equipment using App. C, a If time permits, review expected annunciators (ex. Computer Alarm, Upper and Lower Flux Dev) a Termination Criteria (conditions requiring Reactor Trip, Turbine Trip, or condition no longer requiring rapid load reduction):

Appendix D Reauired Qoerator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario# 1 Event# 5 Page 14 of 54 Event

Description:

Power reduction using AOP-C.03 Chooses a power reduction rate of 2% to 3% final power level of 20% and BAT as SRO the boration source.

2. NOTiFY toflow:rig perscnnei of rapid shutdown t load reduction.

. Load coordinator [C.1]

CREW

Cremisiry

Radiation Protection

Plant Management CREW Makes notifications as required.

3. MONITOR reactorlturbine trip NOT required CREW USING Appendix B, Reactor and Turbine TrIp criteria.

Examiner note: Appendix B reactor and turbine trip criteria see page 18 4 CHECK VALVE POSEi1ON LIMIT light BOP DARK on EHC panel. [M-2J NOTE: BoratiOn volumes and fiowrates listed in this procedure are recommendations and may be adjusted as necessary

5. INITIATE boralion:

a. CHECK rod control AVAILABLE:

ATC

Control Bank D rods capable of being moved

NO dropped or misaligned rods in Control Bank D.

5. b. CHECK Control Bank D group postion greater than 200 steps.

ATC

c. CHECK boration capabihty from BAT AVAILABLE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenano# 1 Event# 5 Page 15 of 54 Event

Description:

Power reduction using AOP-C.03 Time Position Applicants Actions or Behavior

d. DETERMINE recommended boration volume from BAT:

-800 gal to reduce power from 100% to 20%

OR SRO

10 gal for each 1% power reduction (from current power level)

OR

. volume recommended by Reactor Engineering.

SRO Determines 800 gal to reduce power from 100% to 20%.

5. e DETERMINE recommended boration Ilowrate from table below or from Reactor Engineering:

SRO LOAD REDUCTION BORATION RATE(%!rnin) FLOWRATE 2% 30gpm 3% --45 gpm SRO Chooses a 2% to 3% load reduction rate.

f. ENSURE concurrence obtained from ATC STA for boration volume and tlowrate g ENSURE boric acid transfer pump ATC aligned to blender in FAST speed.

h ADJUST FCV 138 to estabhsh ATC desired flow rate ATC Adjusts FCV-62-138 to between 30 to 45 gpm.

f. CONTROL boration flow as required to inject desired boric acid voiume

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario# 1 Event# 5 Page 16 of 54 Event

Description:

Power reduction using AOP-C.03 Time fl Position 1 Applicants Actions or Behavior CAUTION: If borating from the RWST, Turbine Load Reduction Rate greater than 2% per minute could result in violating Rod Insertion Limit.

6 INITIATE load reduction as follows:

a ADJUST load rate to desired value:

between 1% and 4% per minute if borating via FCV-62-i38 BOP OR

between 1% and 3% per minute if borating via nonm I boration (App H)

OR

2% per minute if borating from RWST

b. ADJUST setter for desired power level:

BOP If DESIRED RECOMMENDED RX POWER LEVEL SETTER VALUE I 20%ocless 15

6. C. VERIFY boration how established.

BOP d INATE tuitine load reduction by depressing GO pushbutton BOP Depresses GO pushbutton.

e. CONTROL turbine load reduction as necessary to reduce power to desired level

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # Event# 5 Page 17 of 54 Event

Description:

Power reduction using AOP-C.03 Time Position Applicants Actions or Behavior 1 MONITOR T-avglT-ref mismatch:

ATC

a. CHECK T-ref indication AVAILABLE.

7. b. MONiTOR automatic rod control ATC maintaining T-avgiT-ref msmach less than 3F.

L I ATC Coordinates with the BOP to maintain T-avgiT-ref mismatch less than 3°F.

8. MONITOR automatic control of BOP MFW pump speed AVAILABLE.

9. STOP secondary plant equipment BOP USING Appendix C, Seconday Plant Equipment.

Examiner Note: Appendix C, Secondary Plant Equipment starts at page 19.

Examiner Note: Additional AOP-C.03 steps not included as required power reduction should be complete at or around this step.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2OI2-301 Scenario# 1 Event# 5 Page 18 of 54 Event

Description:

Power reduction using AOP-C.03 APPENDIX B REACTOR AND TURBINE TRIP CRITERIA REACTOR TRIP CRITERIA TURBINE TRIP CRITERIA Turbine trip required or imminent Turbine vibration exceeding 14 rolls with reactor power greater than P.9(50%) with one of the following:

Uncontrolled rod movement which CANNOT be

high vibration on multiple bearings stopped by placing rods in MANUAL OP-C.l)

OR Loss of SIG level control:

abnormal noiseNibration apparent level dropping or rising toward trip setpoint and level CANNOT be restored oP-s.oij More than one dropped rod op-coi T-avg/T.-ret mismatch CANNOT be maintained less than 5°F (refer to Step 7 or App. E) 30% turbine load: <30% turbine load:

Condenser Pressure > 2.7 psia AND CANNOT Condenser Pressure> 1.72 psia be restored within 5 minutes .o-so (AOP-S.&2)

Any automatic reactor trip seipoint reached Any automatic turbine trip setpoint reached OR automatic trip imminent OR automatic trip imminent

Turbine trip above P-9 (50%)

High Stator Cooling Water temp 90°C

Safety injection OR Stator D/P 12 psig below normal

Power Range high flux 109%

Both MFPTs tripped

Power Range flux rate +/-5% in 2 seconds

Low Auto Stop Oil pressure 45 psig

Pressurizer high level 92%

High SIG level 81% nairow range

Pressurizer pressure low 1970 psig

Main Turb Bearing Oil low pressure 7 psig

Pressurizer pressure high 2385 psig

Thrust Bearing Oil high pressure 60 psig a RCS low flow 90%

Turbine Overspeed 1980 rpm

RCP undervoltage 5.022 FCIIOVGIIS

Loss of EHC pressure

RCP underfrequencI 56.0

Generator PCBs tripped.

OTAT 115% (variable)

OPAT 108.7% (variable)

S!G low level 10.7% [15% EAMI

SSPS genera) warning in both trains

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O12-301 Scenario# 1 Event# 5 Page 19 of 54 Event

Description:

Power reduction using AOP-C.03 APPENDIX C SECONDARY PLANT EQUIPMENT

[1] ENSURE plant announcement(s) made on the following:

starting rapid shutdown (or load reduction) due to (reason) C

stopping secondary plant equipment U NOTE I If reactor power will be reduced be!ow 50%7 AUO should be on station at #3 heater drain tank (if possible) when 80% power is reached.

NOTE 2 Dispatching of AUO in Steps [2] and [3] may be performed out of sequence.

[2] IF reactor power Will be reduced below 50%,

THEN DISPATCH AUO with Appendix J (Unit 1) or K (Unit 2) to #3 Heater Drain Tank. U

[3] IF one MFP Will be shutdown using this appendix, THEN DISPATCH AUO to OPEN MFWP recirc manual Isolation valve for MFWP to be removed from service (N/A valves NOT opened)

UNIT MFWP VALVE LOCATION IA 1-VLV-3-576 TB eL 706, Northeast corner of IA condenser 18 i-VLV-3-577 TB el. 706, NOrtheaSt COflf of IA condenser 2 2A 2-VLV.-3-576 TB eL 706, Southeast corner of 2A condenser 28 2-VLV-3-577 TB: el. 706. Southeast corner of 2A condenser

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event # 5 Page 20 of 54 Event

Description:

Power reduction using AOP-C.03 APPENDIX C

[4] IF BOTH of the following conditions are met:

power is being reduced as directed by AOP-&Oi (Main Feedwater Malfunctions) or AOP-S.04 (Condensate or Heater Drain Malfunctions)

leaving secondary pumps in service is desired, ThEN GO TO Step [8L U

[5] WHEN turbine impulse pressure is approximately 80% or less, THEN PERFORM the following:

[a] ENSURE one Cortd Demin Booster Pump STOPPED. El

[b] ENSURE associated suction valve CLOSED:

COND DEMIN OR B FCV-2-285

[

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC 2012-301 Scenario# 1 Event# 5 Page 21 of 54 Event

Description:

Power reduction using AOP-C.03

[6] WHEN turbine impulse pressure is approximately 7O-75%

THEN PERFORM the following:

[a] ENSURE one Condensate Booster Pump STOPPE*0

[b] ENSURE associated CBP suction valve CLOSED:

CONDENSATE BOOSTER PUMP SUCTION VALVE CLOSED A FCV-2-94 U OR FCV-287 U OR FCV-2-81 U

[C] PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary)

1-SO-2!3-i Section 7.2 OR

2-S0-2(3-1 Section 7.3 U

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenano# 1 Event# 5 Page 22 of 54 Event

Description:

Power reduction using AOP-C.03

[7] WHEN turbine impulse pressure is approximately 65% or less, THEN PERFORM the following:

[a] STOP remaining two Conci Demin Booster Pumps simultaneously.

[b] ENSURE suction vaives CWSED:

COND DEMIN BOOSTER PUMP SUCTION VALVE CLOSED A FCV-2-290 U B FCV-2-285 U C FCV-2-280 U IC] STOP one No.3 Heater Drain pump.

Id] STOP one No. 7 Heater Drain pump.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event # 5 Page 23 of 54 Event

Description:

Power reduction using AOP-C.03 181 IF reactor power Will be maintained greater than 50%,

THEN GO TO Notes prior to Step [111.

CAUTION Isolation of all three intermediate heater strings could occur if turbine is tripped prior to fully opening LCV-6-1 05A and B using Appendix J or K.

[9] WHEN reactor power is less than 60%

AND AUO with App J Uniti) or K (Unit 2) is on station at #3 Heater Drain Tank, THEN PERFORM the following:

[a] STOP #3 Heater Drain Tank Pumps (b] NOTIFY AUO to perform App. J (Unit 1) or App. K (Unit 2),

Fully Opening #3 Heater Drain Tank Bypass Valves. 0

[c] CLOSE isolation valves from #3 I-Hr Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED I FCV-.6-108 Htr Drain Tk Pump 3 to Htr String A U FCV-6-103 Htr Drain Tk Pump 3 to Htr String B U FCV-6-1 10 Htr Drain Tk Pump 3 to Htr String C U

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 5 Page 24 of 54 Event

Description:

Power reduction using AOP-C.03 NOTE I The following step ensures that MFW Bypass values are available to control feedwater flow at low power.

NOTE 2 if any MFW Req valve is in MANUAL, the associated MFW Bypass valve controller should remain in MANUAL to prevent undesired opening of bypass valve.

[10] WHEN Reactor power is less than 50%,

THEN PERFORM the following:

a] IF all MFW Req Valves are in AUTO, ThEN PLACE MFW Bypass Req Valve controllers in AUTO b] IF any MFW Req Valve is in MANUAL.,

THEN PERFORM the following:

1) MAINTAIN MFW Bypass Req Valve in MANUAL for SIG Wfth MFW Req valve in MANUAL.

2) PLACE MFW Bypass Req Valves in AUTO for remaining SIGs.

Appendix D Required Operator Actions Form ES-D-2 NOTE I If performing this AOP to reduce power to allow shutting down one MFW pump the affected MFWP may be removed from service at power level less than 55% (Unit 1) or 65% (Unit 2).

NOTE 2 AFW start function on loss of both MFW pumps is inoperable when a MFW pump is RESET but NOT pumping forward.. LCO 3.3.2.1 (Unit 1) or 3.3.2 (Unit 2) allows AFW start channel to be inoperable for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months when shutting down a MFWP.

[ii] WHEN it is desired to remove one MFW pump from service AND power level is less than applicable limit:

turbine impulse pressure less than approximately 45%

OR

reactor power less than value specified in Note 1 THEN PERFORM the following:

La] ENSURE MFWP Recirc Manual Isolation valve OPEN for MFWP to be removed from service: (N/A valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN q IA I-VLV-3-576 T6eL706,NortheastcornerofiAcondenser 1

16 l-VLV-3-577 TB eL 706, Noflheast corner of IA condenser 24 2-VLV-3-576 TB eL 706, Southeast corner of 24 condenser 2

213 2-VLV-3-577 TB el. 706, Southeast corner sf24 condenser

[b] THROTTLE OPEN recirc valve in MANUAL (30-50% OPEN) for MFWP to be removed from service.

[C] PLACE speed: controller in MANUAL for MFWP to be removed from service.

[d] REDUCE speed gradually on MFWP to be removed from service. LI

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 5 Page 26 of 54 Event

Description:

Power reduction using AOP-C.03

[11] (Continued)

ENSURE proper loading on remaining MFWP. fl (f] IF MFWP CANNOT be fully unloaded with speed controller, THEN PERFORM one of the following:

NOTIFY l&C to slowly adjust hand speed changer for affected MFWP UNTIL MFWP is fully unloaded.

OR

THROTTLE OPEN recirc valve for affected MFWP to assist in unloading IVIFWP OR

SLOWLY CLOSE governor valve by bumping dosed governor valve :posifioner (if operable) C]

OR

OBTAIN SRO concurrence that MFWP flow is sufficiently low to allow tripping MFWP.

fg] WHEN MFWP is unloaded sufficiently 1

THEN TRIP affected MFWP. C]

{h] CLOSE recirc valve for MFWP removed from service. C i] CLOSE redrc valve Manual Isolation inlet valve for MFWP removed from service. C Ci] OPEN drain valves for MFWP removed from service: EM-31

fljS4S-141, MAP A drain valves OR

[HS-4631], MAP B drain valves. C

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event # 5 Page 27 of 54 Event

Description:

Power reduction using AOP-C.03

[12] WHEN turbine impulse pressure is approximately 45% or less, THEN PERFORM the following:

[a] STOP remaining No. 7 Heater Drain pump.

[b] CLOSE isolation valves from #7 Heater Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED -4 FCV-&143 Htr Drain Tk Pump 7 to Htr String A U FcV6-183 Htr Drain Tk Pump 7 to Htr String B U ECV-B--I 84 Htr Drain Tk Pump 7 to Htr String C U

[13] WHEN turbine impulse pressure is approximately 30% or less, THEN PERFORM the following:

[a] ENSURE main turbine EHC controls in IMP OUT.

[bilE #3 heater drain tank pumps are still running, THEN PERFORM Step [9]

[ci STOP one of two remaining Condensate Booster Purnp& U (steo continued on next paQe)

Appendix D Required Operator Actions Form ES-D-2 t131 (Continued)

(d] ENSURE associated C8P suction valve CLOSED:

OR FCV-2-87 OR

[ C FCV-2-81

[e] STOP one of three Hotwell Pumps.

tfl PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary) 1-SO-213-i Section 72 OR

. 2-SO-213-i Section 7.3

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 201 2-301 Scenario # 1 Event # 6, 7, 8, 9 Page 29 of 54 Event

Description:

SBLOCA/Loss of Off-Site Power/EDG/1A-A Fails/i B-B Charging and SI Pump fail to Auto Start Time I Position 1 Applicants Actions or Behavior Simulator Operator: at Lead Examiner direction, insert Event6SBLOCA resulting in reactor trip and safety injection.

IndicationslAlarms:

Indications 1-M-4:

RCS PZR LVL, 1-Ll-68-339A, shows a decreasing level value

RCS PZR LVL, 1-LI-68-335A, shows a decreasing level value

RCS PZR LVL, 1-Ll-68-320, shows a decreasing level value

1-XI-94-1011102, Core Exit Temp Margin to Saturation (exo sensors Tm A & B) pressure indications trending down.

1-M-5:

RCS PR PRESS (Chs 1-4), 1-PI-68-340A, 334, 323, 322: showing RCS (Pzr) pressure going down;

RCS PZR PRESS Recorder 1-PR-68-340 shows a decreasing pressure trend;

RCS LOOP I HL WIDE RANGE PRESS Recorder 1-PR-68-69 shows a decreasing pressure trend.

1-M-6:

RCS WR HL PRESSURE LOOP 3 1-PI-68-66A, shows a decreasing pressure value;

RCS HL PRESS WIDE RANGE 1-PI-68-62, shows a decreasing pressure value;

RCS HL PRESS WIDE RANGE 1-Pl-68-69, shows a decreasing pressure value; Annunciators 1-M-5:

I -XA-55-5C Window B-I: TS-30-3I LOWER COMPT TEMP HIGH

B-3: TS-30-24I LOWER COMPT MOISTURE HI

B-4: TS-30-240 LOWER COMPT MOISTURE HI 1-M-6:

1-XA-55-6E Window C-6: ZS-61 -1 86 ICE CONDENSER LOWER INLET DOOR OPEN Examiner Note: following IOA performance, prior to Steps 1-4 immediate action verification, ATC/BOP surveys MCBs for any expected automatic system response that failed to occur. Upon discovery, they may take manual action(s) to align plant systems as expected for the event in progress. (Ref. EPM-4, Prudent Operator Actions)

Examiner Note: Based on plant conditions the SRO may direct the crew to manually trip the Reactor and initiate Safety Injection.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-301 Scenario # 1 Event # 6,7,8,9 Page 30 of 54 Event

Description:

SBLOCAILoss of Off-Site Power/EDG/1A-A Fails/i 6-B Charging and SI Pump fail to Auto Start Time Position I Applicants Actions or Behavior CREW Performs the first four steps of E-O unprompted.

SRO Directs performance of E-O NOTE I Steps I through 4 are immediate action steps NOTE 2 This procedure has a foldout page.

1. VERIFY reactor TRIPPED:

Reactor trip breakers OPEN

Reactor trip bypass breakers DISCONNECTED or OPEN ATC

Rod bottom lights LIT

Rod position indicators less than or equal to 12 steps.

Neutron flux DROPPING

2. VERIFY turbine TRIPPED:

BOP

Turbine stop valves CLOSED.

3. VERIFY at least one 6.9KV shutdown ATTEMPT to start DIGs.

board ENERGIZED on this unit.

IF power CANNOT be immediately restored to at least one shutdown board BOP on this unit, THEN GO TO ECA-O.O. Loss of All AC Power.

Examiner Note: The BOP has guidance to manually start the I B-B EDG, the IA-A EDG has a malfunction and will not start. If the crew fails to start the I B-B EDG in E-0, the crew will transition to ECA 0.0. Go to page 44 for ECA-0.0 details.

Examiner Note: Following SI actuation, the lA-A DG fails to start. BOP Operator will manually start 1 B-B EDG from either 1-M-1 using 1-HS-82-15, DG EMERG START or back panel O-M-26A using emergency start pushbutton O-HS-82-16A.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-301 Scenario # Event# 6,7,8,9 Page 31 of 54 Event

Description:

SBLOCAILoss of Off-Site Power/EDG/1A-A Fails/i B-B Charging and SI Pump fail to Auto Start Time Position i Applicants Actions or Behavior

& DETERMINE if SI actuated:

ATC

ECCS pumps RUNN1NG

Any SI alarm LIT [M-4D].

5. PERFORM ES-O.5, Equipment BOP Verifications WHILE continuing in this procedure.

Continue with the performance of E-0 REACTOR TRIP OR SAFETY SRO/ATC INJECTION BOP Performs ES-O.5, Equipment Verifications go to page 48 for details SRO Addresses foldout page, see next page for details.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6, 7, 8, 9 Page 32 of 54 Event

Description:

SBLOCNLoss of Off-Site Power/EDG/1A-A Fails/i B-B Charging and SI Pump fail to Auto Start FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

RCS pressure less than 1250 psig AND at least one CCP or Si pump running OR

Phase B isolatlen, THEN STOP all RCPs EVENT DIAGNOSTICS a IF any SIG pressure is dropping uncontrolled, ThEN PERFORM the following:

a.. CLOSE MSIVs and MSIV bypass. valves.

Ii IF any S/G pressure continues to drop uncontrolled, THEN PERFORM the following:

1) ENSURE SI actuated..

2) IF at least one SIC Is intact (SIC pressure controlled or rising),

THEN iSOLATE AFV( to faulted S/C(s):

CLOSE AFW level control valves for faulted SIC(s)

IF any AFW valve for faulted SIC CANNOT be CLOSED, THEN PERFORM Appendix E, Isolating AFW to Faulted SIC.

3) ENSURE at least one of the following conditions met:

total AFW flow greater than 440 gpm OR

Narrow Range level greater than 10% [25% ADV] in at least one intact S/C.

IF both trains a! shutdown boards de-energized, THEN GO TO ECA-0.0, Loss of All AC Power..

TANK SWITCHOVER SETPOINTS a IF CST level less than 5%, THEN AUGN AFW suction to ERCW

IF RWST level less than 27%, THEN GO TO ESi .3, Transfer to RHR Containment Sump.

ppendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6, 7,8,9 Page 33 of 54 Event

Description:

SBLOCA/Loss of Off-Site Power/EDG/1A-A Fails/i B-B Charging and SI Pump fail to Auto Start Time Position Applicants Actions or Behavior

6. DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpm.

b. CHECK narrow range level b. MAINTAIN total feed flow greater than 10% [25% ADV] greater than 440 gpm ATC in at least one SIG. UNTIL narrow range level greater than 10% [25% ADV]

in at least one SJG.

c. CONTROL feed flow to maintain narrow range level between 10% [25% ADV] and 50%

in intact or ruptured SIGs.

T CHECK if main steam lines should be isolated:

a CHECK it any of the following a GO TO Step 8.

conditions have occurred:

Any SIG pressure less than 600 psig ATC OR

Any S/G pressure dropping UNCONTROLLED OR a Pliase B actualion

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event # 6, 7, 8, 9 Page 34 of 54 Event

Description:

SBLOCNLoss of Off-Site Power/EDG/1A-A Fails/i B-B Charging and SI Pump fail to Auto Start Time Position Applicants Actions or Behavior

8. CHECK RCP trip criteria:

a. CHECK the following:

. RCS pressure less than 1250 psig ATC AND

. At least one CCP OR SI pump RUNNING.

b. STOP RCPs.

ATC Manually places HS 68-8A, 31A, 50A, and 73A RcPs to STOP.

9. MONITOR RCS temperatures: IF temperature less than 547 F and dropping, IF any RCP running, THEN THEN PERFORM the following:

CHECK T-avg stable at or trending to between 547°F and 552°F. a. ENSURE steam dumps and atmospheric reliefs CLOSED.

OR

b. IF cooldown continues, IF RCPs stopped, THEN THEN CONTROL total feed flow:

CHECK T-cold stable at or trending ATCIBOP 1) ENSURE total AFW flow to between 547°F and 552°F.

less than or equal to 600 gpm.

2) MAINTAIN total AFW flow greater than 440 gpm UNTIL narrow range level is greater than 10% t25% ADV]

in at least one S/G.

c. IF cooldown continues after AFW flow is controlled, THEN CLOSE MSIVs and MSIV bypass valves.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6, 7, 8, 9 Page 35 of 54 Event

Description:

SBLOCAILoss of Off-Site Power/EDG/1A-A Fails/i B-B Charging and SI Pump fail to Auto Start Time Position Applicants Actions or Behavior

10. CHECK pressurizer PORVs, safeties, and spray valves:

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

ATC c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

it DETERMINE if S/G secondary pressure boundaries are INTACT:

CHECK all S/G pressures ATC CONTROLLED or RISING.

CHECK all SIG pressures greater than 140 psig.

12. DETERMINE if SIG tubes are INTACT:

. All S/G narrow range levels CONTROLLED or DROPPING ATC

. Secondary radiation NORMAL USING Appendix A, Secondary Rad Monitors. (App. A performed in ES-0.5).

13. DETERMINE if RCS is INTACT: PERFORM the following:

. Containment pressure NORMAL

a. INITIATE ES-0.5 Appendix 0,

. Containment sump level NORMAL Hydrogen Mitigation Actions.

ATC

LOWER COMPT TEMP HIGH alarm b. MONITOR status trees.

DARK. [M-5C, BI]

Containment radiation NORMAL c. GO TO E-1, Loss of Reactor or USING Appendix B, Containment Secondary Coolant.

Rad Monitors. (App. B performed inES-0.5

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # I Event # 6,7,8,9 Page 36 of 54 Event

Description:

SBLOCAJLoss of Off-Site Power/EDG/1A-A Fails/I B-B Charging and SI Pump fail to Auto Start Time Position Applicants Actions or Behavior Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via ICS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the SOP) to verify status tree conditions using 1-FR-O, UNIT I STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

When a RED Path for Containment is evident on ICS, the SRO will transition to FR-Z.1, go to page 40 for details.

E-1, LOSS OF REACTOR OR SECONDARY COOLANT NOTE This procedure has a foldout page.

See next page for details I. CHECK RCP trip criteria:

a. CHECK the following: a. GO TO Step 2.

. At least one CCP OR SI pump RUNNING ATC AND

. RCS pressure less than 1250 psig.

b. STOP RCPs.

2. CHECK SIG secondary pressure boundaries INTACT:

ATC/BOP

S/G pressures CONTROLLED or RISING

S/G pressures greater than 140 psig.

3. MAINTAIN Intact S1G narrow range levels:

a. Greater than 10% [25% ADVI.

ATC/BOP

b. Between 10% [25% ADV] and 50%.

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6, 7, 8, 9 Page 37 of 54 Event

Description:

SBLOCNLoss of Off-Site Power/EDG/1A-A Fails/i B-B Charging and SI Pump fail to Auto Start FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

RCS pressure less than 1250 psig AND at least one CCP or SI pump running OR

Phase B isolation, THEN STOP all RCPs.

SI REINITIATION CRITERIA IF any of the follong conditions occurs:

RCS subcooling based on core exit T/Cs less than 40°F OR

Pressurizer level CANNOT be maintained greater than 10% [20% ADV],

THEN RAISE ECCS flow by performing one or both of the following as necessary:

ESTABLISH CCPIT flow USING Appendix C

START CCPs or SI pumps manually.

EVENT DIAGNOSTICS

IF both trains of shutdown boards de-energized, ThEN GO TO ECA-0.0, Loss of All AC Power.

IF any SIG pressure dropping in an uncontrolled manner or less than 140 psig AND SIG NOT isolated, THEN GO TO E-2, Faulted Steam Generator Isolation.

IF any S/G has level rising in uncontrolled manner or has abnormal radiation, THEN:

a. RAISE ECCS flow by performing one or both of the following as necessary:

ESTABLISH CCPIT flow USING Appendix C

START CCPs or SI pumps manually.

b. GO TO E-3, Steam Generator Tube Rupture.

TANK SWITCHOVER SETPOINTS

IF CST level less than 5%,

THEN ALIGN AFW suction to ERCW.

IF RWST level less than 27%,

THEN GO TO ES-1.3, Transfer to RHR Containment Sump.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6, 7, 8, 9 Page 38 of 54 Event

Description:

SBLOCA/Loss of Off-Site Power/EDG/1A-A Fails/i B-B Charging and SI Pump fail to Auto Start Time

]I Position Applicants Actions or Behavior

4. VERIFY secondary radiation NORMAL:

a. CHECK secondary radiation NORMAL USING Appendix A, Secondary Rad Monitors.

b. NOTIFY Chem Lab to take SIG activity samples.

c. WHEN Chem Lab is ready to sample S/Gs, THEN PERFORM the following:

ATC 1> ENSURE FCV-i 5-43 Blowdown Flow Control valve CLOSED.

2) ENSURE Phase A RESET.

3) OPEN blowdown isolation valves.

d. NOTIFY RADCON to survey main steam lines and SIG blowdown.

e. WHEN SIG samples completed, THEN CLOSE blowdown isolation valves.

CAUTION Any time a pressurizer PORV opens, there is a possibility that it may stick open.

5. MONITOR pressurizer PORVs and block valves:

a. Power to block valves AVAILABLE, a. DISPATCH personnel to restore power to block valves USING EA-201-1, 480V Board Room Breaker Alignments.

ATC b. Pressurizer PORVs CLOSED. b. IF pressurizer pressure less than 2335 psig, THEN CLOSE pressurizer PORVs.

IF pressurizer PORV CANNOT be closed, THEN CLOSE its block valve.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6,7,8,9 Page 39 of 54 Event

Description:

SBLOCAJLoss of Off-Site PowerIEDGI1A-A Fails/I B-B Charging and SI Pump fail to Auto Start Time Position Applicants Actions or Behavior

6. MONITOR SI termination criteria:

ATC a. RCS subcooling based on core exit TICs a. GO TO Step 7.

greater than 4OF.

Scenario may be terminated when the crew determines that SI cannot be terminated or earlier, at discretion of Lead Examiner.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6,7,8,9 Page 40 of 54 Event

Description:

SBLOCA/Loss of Off-Site Power/EDG/1A-A Fails/i B-B Charging and SI Pump fail to Auto Start Time Position Applicants Actions or Behavior FR-Z.1 Actions NOTE If this procedure has been entered for an orange path and performance of ECA-1 .1 (Loss of RI-aR Sump RecircuLation) is required, FR-Z1 may be performed concurrenuy with ECA-li.

I. MONITOR RWST level BOP greater than 27%.

2. VERIFY Phase B valves CLOSED:

BOP Panel 6K PHASE B GREEN

Panel 6L PHASE B GREEN.

3. ENSURE RCPS STOPPED.

BOP

4. DETERMINE if this procedure should be exited:

a. CHECK for faulted SIG: a GO TO Step 5.

Any S/G pressure DROPPING BOP in an uncontrolled manner OR

Any S/G pressure less than 140 psig.

5 VERIFY containment spray operation:

a. IFECA-li, Loss oIRHR Sump Recirculation, is IN EFFECT.

ThEN PERFORM the following:

1) OPERATE containment spray as directed by ECA-1 .1 -

2) GO TO Step 6, BOP

b. VERIFY containment spray pumps RUNMNG.

C. CHECK RWST level greater than 27%.

Appendix D Required Operator Actions Form ES-D-2 1 Op Test No.: NRC 2012-301 Scenario # I Event # 6, 7, 8, 9 Page 41 of 54 Event

Description:

SBLOCAILoss of Off-Site Power/EDG/1A-A Fails/I B-B Charging and SI Pump fail to Auto Start Time Position Applicants Actions or Behavior

5. d VERIFY containment spray suction AUGNED to RWST:

FCV-72-22 OPEN

FCV-72-21 OPEN.

e VERIFY containment spray &scharge valves OPEN:

FCV-72-39 BOP

FCV-72-2.

f. VERIFY containment spray recwc valves CLOSED:

FCV-72-34

FCV-72-13.

g VERIFY containment spray 110w greater than 4750 gpm on each train

6. MONITOR containment aw return tans:

. WHEN at least 10 minutes BOP have elapsed from Phase B, THEN ENSURE containment air return fans RUNN1NG

7. VERIFY containment ventilation dampers CLOSED:

BOP PaneI6KCNTMTVENTGREEN

Panel 6L CNTMT VENT GREEN.

& VER1FY Phase A valves CLOSED:

BOP Panel 6K PHASE A GREEN

Panel 6L PHASE A GREEN.

9 VERiFY cntmnt vacuum relief isolation valves CLOSED: [Pnl 6K MANUALI BOP FCV-30-46

FCV-30-47 FCV-30-48.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-301 Scenario # 1 Event # 6,7,8,9 Page 42 of 54 Event

Description:

SBLOCNLoss of Off-Site Power/EDO/IA-A Fails/i B-B Charging and SI Pump fail to Auto Start Time Position Applicants Actions or Behavior

10. VERIFY MSIVs and MSIV bypass valves BOP CLOSED.

11 DETERMINE f any 5/0 Intact:

a. CHECK at least one SIG pressure:

BOP CONTROLLED or RISiNG AND

Greater Than 140 psig.

CAUTION isolating all SIGs will result in a loss of secondary heat sink.

12. DETERMINE it any SIC Faulted:

a CHECK SIC pressurea a. GO TO Step 13.

Any SIG pressure DROPPING BOP tn an unconIrntei manner OR

Any SIG pressure less than 140 psig.

13. MONITOR it RI-St spray should be placed in service:

BOP a CHECK ipe following: a. GO TO Step 14.

Containment pressure greater than 9.5 psig

14. MONITOR ii containment spray should be stopped:

a. CHECK any containment spray pump a. GO TO Step 15.

RUNNING.

BOP

b. CHECK containment pressure b. GO TO Step 15.

less than 2.0 psg

15. RETURN TO procedure and step lit efFect BOP END

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 201 2-301 Scenario # 1 Event # 8 Page 43 of 54 Event

Description:

ECA-O.O Actions, if required Time Position Applicants Actions or Behavior ECA-O.O, Loss Of AU AC Power Examiner Note: The IA-A DG fails to start. BOP Operator is expected to manually start I B-B EDG from either I-M-1 using 1-HS-82-15, DG EMERG START lA-A, 2A-A, lB-B, 2B-B handswitch or back panel 0-26A using emergency start pushbutton 0-HS-82-16A.

NOTE Steps 1, 2, and 3 are immediate action steps.

1. SUSPEND FRP implementation and SRO MONITOR status trees for information only.

2. VERIFY reactor TRIPPED:

. Reactor trip breakers OPEN ATC

Reactor trip bypass breakers OPEN or DISCONNECTED

Neutron flux DROPPING

3. VERIFY turbine TRIPPED:

BOP

ALL turbine stop valves CLOSED

[SSPS status lights on M-61.

ATC 4. ENSURE RCPs STOPPED.

NOTE Step 5 should be handed off to a Unit Operator.

5. PERFORM the following notifications:

a. NOTIFY four AUOs to report to MCR immediately to be available as necessary for DC load shed and BOP local operation of TD AFW LCVs.

b. NOTIFY Site Security to station officers at key vital doors USING SSI-1, Security Instructions for Members of the Security Force.

I Appendix D Required ODerator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event# 8 Page 44 of 54 Event

Description:

ECA-O.O Actions, if required Time Position I Applicants Actions or Behavior

6. CHECK RCS ISOLATED:

a. Pressurizer PORVs CLOSED.

b. Letdown isolation valves CLOSED:

FCV-62-69

FCV-62-70

FCV-62-72

FCV-62-73 ATC

FCV-62-74

c. Excess tetdown isolation valves CLOSED:

FCV-62-54

FCV-62-55

d. Reactor vessel head vents CLOSED:

FSV-68-394

FSV-68-395

FSV-68-396

FSV-68-397 NOTE

On loss of auxiliary control air, TD AFW LCVs fail open.

Auxiliary air compressors are powered from 480V C&A Vent Boards 2A1-A and 281-B.

7. MONITOR AFW flow:

BOP

a. CHECK TD AFW pump RUNNING.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-301 Scenario# 1 Event# 8 Page 45 of 54 Event

Description:

ECA-O.0 Actions, if required Time Position 1 Applicants Actions or Behavior

b. CONTROL TD AFW pump USING EA-3-1, MCR Operation of TD AFW Pump.

7. c. MONITOR Aux Control Air AVAILABLE:

BOTH Unit 2 Shutdown Boards ENERGIZED

Train A and B Aux Control Air pressure on 1-M-15 (prior to DC load-shedding).

d. MAINTAIN AFW flow greater than 440 gpm UNTIL narrow range level greater than 10% [25% ADVI in at least one S/G.

e. CONTROL intact or ruptured SIG narrow range levels between 10% [25% ADVI and 50%.

CAUTION DO NOT attempt to start DIGs if both trains of ERCW are unavailable due to catastrophic event.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-301 Scenario # 1 Event # 8 Page 46 of 54 Event

Description:

ECA-O.O Actions, if required Time Position Applicants Actions or Behavior Examiner Note: The IA-A DG fails to start. BOP Operator is expected to manually start I B-B EDG from either 1-M-1 using I-HS-82-15, DG EMERG START or back panel O-M-26A using emergency start pushbutton O-HS-82-l 6A.

8. ATTEMPT to restore power to any shutdown board on this unit:

a. CHECK for any of the following: a IF BOTH D/Gs on this unit are KNOWN to be NOT capable of

any DIG on this unit potentially supplying power to shutdown boards, available (capable of supplying THEN power to shutdown board> GO TO Substep 8.d.

OR

availability of any DIG on this unit is UNKNOWN.

b. RESET DIG start lockout relays for D/G(s) to be started. [O-M-26]

c. EMERGENCY START diesel c. ACTUATE SI to attempt generators. fM-i switch and to start DIGs.

M-26 pushbutton]

ENSURE DIG lockout relay RESET for DIG(s) to be started.

d. VERIFY at least one shutdown board ENERGIZED from DIG on this unhl

e. VERIFY ERCW suppy established to running diesel generators.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # I Event# 8 Page 47 of 54 Event

Description:

ECA-O.O Actions, if required Time Position Applicants Actions or Behavior

f. CHECK at least one shutdown board on Ifls unit ENERGIZED

g. RESUME FRP implementation.

fl. RETURN TO procedure and step in effect

Op Test No.: NRC 2012-301 Scenario # Event # ES-0.5 Page 48 of 54 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior ES-O5 Actions j BOP 1 VERIFY DIGS RUNNING.

$W.82WR START BOP 2. VERIFY D/G ERW supply valves OPEN BOP & VERIFY at least four ERCW pumps RUNNING.

4. VERIFY ccs pumps RUNNING:

Pump lA-A (2A-A)

BOP

Pump lB-B (28-B)

Pump C-S.

BOP 5 VERIFY EGTS fans RUNNING.

BOP 6.. VERIFY generator breakers OPEN.

7. NOTIFY at least two AUOS to report BOP to MCR to be available for local actions.

& VERIFY AFW pumps RUNNING:

a MD AFW pumps BOP

b. TDAFWpUmp.

NOTE AFW level control valves should NOT be repositioned it manual action has been taken to control S!G levels, to establish 110w due to failure.

or to isolate a faulted SIG.

OpTestNo.: NRC2O12-301 Scenario# Event# ES-O.5 Page 49 of 54 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

9. CHECK AFW valve alignment:

a. VERIFY MD AFW LCV5 in AUTO.

BOP b. VERIFYTDAFWLCVs OPEN.

c. VERIFY MD AFW pump recirculation valves FV-3-400 and FcV-3-401 CLOSED.

iO VERIFY MFW Isolation:

a. CHECK MFW pumps TRIPPED.

b. ENSURE the following:

BOP

MFW regulating valves CLOSED

MFW regulating bypass valve controllers in MANUAL with output ZERO

MEW isolation valves CLOSED.

11. MONITOR ECCS operation:

a. VERIFY ECCS pumps RUNNING:

BOP

CCPs

RHR pumps

St pumps

OpTestNo.: NRC2O12-301 Scenario# Event# ES-0.5 Page 50 of 54 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior Ii VERIFY CCP 110w through CCPIT.

c. CHECK RCS pressure less than 1500 psg.

BOP ci. VERIFY SI pump flow.

e. CHECK RCS pressure e. GO TO Step 12 less than 300 psg.

f VERIFY R[IR pump 110w.

12. VERIFY ESF systems AIJGNED:

a. Phase A ACTUATED:

PHASE A TRAIN A alarm UT

[M-6C, 65].

PHASE A TRAIN B alarm LIT

[M-6C, 06].

b. Cntmt Vent Isolation ACTUATED:

CNTMT VENT ISOLATION TRAIN A alarm LIT [M-6C, C5j.

CNTMT VENT ISOLATION TRAIN 8 alarm LIT [M-6C, 061

c. Status monitor panels:

BOP

6CDARK

6DDARK

6E LIT OUTSIDE outhnecl area

SH DARK

6JLIT.

d. Train A status panel 6K:

CNTMT VENT GREEN

PHASE A GREEN

e. Train B status panel 6L:

CNTMT VENT GREEN

PHASE A GREEN

Op Test No.: NRC 2012-301 Scenario # Event # ES-0.5 Page 51 of 54 Event

Description:

Equipment Verifications Time Position A Applicants Actions or Behavior

13. MONITOR for containment spray and Phase B actuation:

a. CHECK for any of the following:

Phase B ACTUATED OR

Containment pressure greater than 2.8 psig.

b. VERIFY containment spray INITIATED:

1> Containment spray pumps RUNNING.

2> Containment spray header isolation valves FCV-72-39 and FCV-72-2 OPEN.

BOP

3) Containment spray recirculation valves to RWST FCV-72-34 and FCV-72-13 CLOSED.

4) Containment spray header flow greater than 4750 gpm per train.

5) Panel 6E LIT.

c. VERIFY Phase B ACTUATED:

PHASE B TRAIN A alarm LIT

[M-6C, A5].

PHASE B TRAIN B alarm LIT

[M-6C, A6].

d. ENSURE RCPs STOPPED.

e. VERIFY Phase B valves CLOSED:

Panel 6K PHASE B GREEN.

Panel 6L PHASE B GREEN.

OpTestNo.: NRC2O12-301 Scenario# Event# ES-0.5 Page 52 of 54 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

f. WHEN 10 minutes have elapsed, THEN ENSURE containment air return fans RUNNING.

NOTE The continuous action in Step 14 remains applicable if containment pressure rises above 1.5 psig alter ES-O.5 is completed.

14. MONITOR if containment vacuum relief isolation valves should be closed:

BOP a. CHECK containment pressure a. GO TO Step 15 greater than 1 5 psig.

15. CHECK secondary and containment rad monitors USING The following:

BOP . Appendix A. Secondary Rad Monitors

Appendix B, Containment Rad Monitors.

APPENDIX A SECONDARY PAD MONITORS

1. IF SI occurred on Unit 1.

THEN CHECK foflbwing rad monitors including available trends prior to isolation:

condenser exhaust recorder 1-RR-90-1 19 BOP

510 blowclown recorder 1-RR-90-120

Unit I Main steam line rad monitors [i-M-301

Post-Acddent rad recorder 1-RR-90-2688 points 3 (blue), 4 (violet), 5 (black), and 6 (turquoise)

[i-M-31 (back of 1-M-30)]

3. NOTIFY Unit Supervisor whether secondary radiation is NORMAL or HIGH.

Op Test No.: NRC 2012-301 Scenario # Event # ES-0.5 Page 53 of 54 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior APPENDIX B CONTAINMENT RAD MONITORS

1. IFSloccurredonUnitl.

THEN CHECK following rad monitors:

BOP

Upper containment post-accident rad monitors 1-RM-90-271A and 1-RM-90-272A NORMAL [i-M-30]

. Lower containment post-accident md monitors 1-RM-9O273A and 1-RM-90-274A NORMAL [1-M-301

Containment rad recorders I-RR-90-i 12 and 1-RR-90-106 NORMAL [O-M-12] (prior to iso1ation) 16 WHEN directed by E-O, THEN BPC PERFORM Appendix D, Hydrogen Mitigation Action&

17. CHECK pocket sump pumps STOPPED:

fM-i 5, upper left comerl

Rx Bldg Aux floor and BOP Equipment Drain Sump pump A s HS-77-41 1, Rx Bldg AUX floor and Equipment Drain Sump pump B.

18. DISPATCH personnel to perform BOP EA-O-i, Equipment Checks Following ESF Actuation.

19 ENSURE plant announcement has been BOP made regarding Reactor Trip anti Si.

2(1 PERFORM Appendix E, Spent Fuel BOP Cooling Actions, as time permits.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario# 1 Event# Critica!Task(s) Page 54 of 54 Event

Description:

Critical Task Listing Critical Tasks: Critical Task Statement

1. Manually start the 1 B-B EDG prior to placing equipment in PTL in ECA-O.O

2. Manually start the 1 B-B SI pump prior to completion of ES-O.5 step 1 1.

Appendix D Scenario Outline Attachment I Facility: Sequoyah Scenario 2 Op Test No.: 2012-301 No.:

Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 1 at 48% RTP in MODE 1 in 0-GO-5.

Turnover: Maintain power at 48% until directed by management.

Target CTs: Depressurize RCS to meet SI termination criteria prior to the ruptured SG dome level exceeding 100%.

Isolate steam flow from and feed flow to ruptured SG prior to initiation of RCS Cooldown to target temperature.

Establish cooldown and maintain RCS temperature so that transition from E3 does not occur because the RCS temperature causes an extreme (red-path) or a severe (orange-path) challenge to the subcriticality and/or the integrity CSF Event No.

1.

MaIf. No.

CVO1B

[ Event Type*

C-ATC/SRO

[ Event Description The lB-B CCP trips resulting in a loss of letdown, the ATC will address the ARP TS-SRO and start the lA-A COP using AOP-M.09. The SRO will address Tech Specs and determines the 1 B-B COP pump is INOPERABLE.

1 .a N ATO The ATO will restore letdown.

2 RX25B O-BOP/SRO Feed water header pressure transmitter PT-3-1 B fails high. The MFP Master Controller shifts to MANUAL resulting in lowering feed flow to all SGs. The BOP maintains S/G levels with the MFP Master Controller in MANUAL using AOP S.01.

3 NIO7A l-ATC/SRO NIS Power Range instrument Channel I fails high, the ATO places rod control in TS-SRO manual due to inadvertent insertion using immediate operator actions and AOP 0.01. The BOP will defeat the failed channel and the ATC will place rod control to automatic AOP-l.01. The SRO addresses Tech Specs and determines the power range instrument to be INOPERABLE.

4 THO5B C-ATC/SRO A 47 gpm SG Tube Leak develops on the #2 S/G. The ATC will manually TS-SRO increase charging flow and isolate letdown using AOP-R.01. The SRO addresses Tech Specs and determines entry into LCO 3.4.6.2.c is required.

5 R ATC The crew initiates a power reduction using AOP-C.03 due to the SGTL NBOP/SRO 6 THO5B M-All The #2 SGTL will degrade to a SGTR 800 gpm over five minutes. The crew will respond by initiating a Reactor Trip and Safety Injection using E-0 and ultimately isolate #2 S/G and depressurize the RCS using E-3.

7 FWO4B C-BOP #2 SG MDAFW Level Control Valve Fails Open. The BOP will stop the lA-A MDAFW Pump and shut the #2 TDAFW LCV to reduce the inflow to the #2 SG using E-0 and ES-0.5.

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

Appendix D Scenario Outline Attachment I 2012-301 Scenario 2 Summary EVENT I Following turnover when directed by the lead examiner, the I B-B CCP trips resulting in a loss of letdown, the ATC will address the ARP and start the lA-A COP using AOP-M.09. The SRO will address Tech Specs and determines entry into LCO 3.5.2 action A and TRM item 3.1.2.4 is required.

EVENT 2 When directed by the lead examiner, Feed water header pressure transmitter PT-3-1 B fails high. The MFP Master Controller shifts to MANUAL resulting in lowering feed flow to all SGs. The BOP maintains SIG levels with the MFP Master Controller in MANUAL using AOP-S.01.

EVENT 3 When directed by the lead examiner, NIS power range channel I will fail high resulting in rod insertion. The ATC will place rod control to manual control to stop the insertion using Immediate Operator Actions and AOP-C.01. The BOP will defeat the failed channel and the ATC will place rod control to automatic AOP-l.01. The SRO addresses Tech Specs and determines the power range instrument to be INOPERABLE and entry into LCO 3.3.1.1 Table 3.3-1 functional unit 2, 3, & 4 Action 2 is required.

EVENT 4 When directed by the lead examiner, a 47 gpm SG Tube Leak develops on the #2 SIG. The ATC will manually increase charging flow and isolate letdown using AOP-R.01. The SRO addresses Tech Specs and determines entry into LCO 3.4.6.2.c is required.

EVENT 5 The crew initiates a power reduction using AOP-C.03 due to the SGTL.

EVENT 6 The #2 SGTL will degrade to a SGTR 800 gpm over five minutes. The crew will respond by initiating a Reactor Trip and Safety Injection using E-0 and ultimately isolate #2 SIG and depressurize the RCS using E-3.

EVENT 7 During EOP implementation, the #2 SG MDAFW Level Control Valve fails open. The BOP will stop the lA-A MDAFW Pump and shut the #2 TDAFW LCV to reduce the inflow to the #2 SG using E-0 and ES-0.5.

EOP flow: E-0, E-3 The scenario terminates as directed by the Lead Examiner upon completion of E-3 Step 24, CCPIT isolation.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-302 Scenario # 2 Event # 1 Page 1 of 68 Event

Description:

1 B-B CCP trip Time Position Applicants Actions or behavior Simulator Operator: When directed, initiate Event I, lB-B CCP Trip Indications! Annunciators available:

Annunciators:

1-M-1

. 1-AR-MI-B, E-3, MOTOR TRIPOUT PNL 1-M-1 THRU I-M-6 I-M-6

. I-AR-M6-C, D-3, FS-62-93A1B CHARGING LINE FLOW ABNORMAL Indications:

I-M-5

. I-AR-M5-B, C-3, FS-62-I, REAC COOL PMPS SEAL WATER FLOW LO FS-62-1 REAC COOL PMPS SEAL WATER FLOW LO

[1] CHECK seal water flow to each pump on flow indicators on 1 -M-5 or locally in 690 penetration room.

[2] IF all seal water supply flows are low, THEN CONSIDER the following:

[a] ADJUST [1-PCV-62-89] as necessary

[b] IF f1-PCV-62-891 has failed, THEN ADJUST seal flows as necessary using the manual isolations and/or bypass valves in accordance with 1 -SO-62-1 -

[c] IF seal water injection filter is the problem, THEN CHANGE filters in accordance with 1 -SO-62-7, Seal injection Rlteis

[d] IF loss of wnning CCP has occurred, THEN GO TO AOP-M09, Loss o?Cliarqinct Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 2 Event# 1 Page 2 of 68 Event

Description:

lB-B CCP trip Time Position Applicants Actions or behavior

]

I. CHECK any CCP RUNNING. GO TO Step 4.

ATC

4. ENSURE normal letdown ISOLATED:

. FCV-62-72 CLOSED ATC

FCV-62-73 CLOSED

FCV-62-74 CLOSED

5. ENSURE excess letdown ISOLATED:

ATC

FV-62-54 CLOSED

FCV62-55 CLOSED.

CAUTION If both RCP thermal barrier cooling flow and seal injection 110w have been lost, RCP seals will overheat rapidly.

NOTE It all RCP seal cooling has been lost, this AOP takes precedence over AOP-R04, RCP Malfunctions, and AOP-M.03, Loss of Component Cooling Water.

6. MONiTOR RCP lower bearing and seal water temperatures:

IF any RCP lower bearing temp or ATC seal water temp is greater than 230°F.

THEN GO TO Notes prior to Step 18.

7. CHECK charging/seal injection header ATC INIACT (NO indication of rupture)

8. ENSURE CCP suction path established:

a. CHECK SI signal NOT actuated.

b. ENSURE suction from VCT established:

ATC

VCT level greater than 13%

LCV-62-i32 and LCV-62-133 VCT Outlet to CCP OPEN.

CAUTION If gas intrusion is suspected, NO CCP should be started UNTIL CCP has been vented (addressed in later steps).

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 2 Event# 1 Page 3 of 68 Event

Description:

1 B-B CCP trip Time Position Applicants Actions or behavior

9. CHECK if any CCP available for immediate start:

cCP available ATC AND

gas intrusion is NOT suspected.

CREW 10. DISPATCH AUO to locally veriry CGP is ready to be started.

NOTE If RCP thermal barrier cooling is established and: sufficient time exists for local inspection of the stan&y pump, then CCP start in: Step I I should be delayed until alter inspection is completed.

11. START available cCP.

ATC ATC 12. CHECK SI signal NOT actuated.

ATC 13. MONITOR CCP suction aligned to VCT.

14 ENSURE normaj charging and letdown IF RCP seal injection 110w established USING EA-62-5, Establishing CANNOT be established or maintained, ATC Normal Charging and Letdown. THEN GO TO Notes prior 1 Step 18.

ATCj pce S

4 1 08A, 1A ES?LISHI Examiner note: The following are from EA-62-5. SRO continues the performance of AOP-M.09 actions on page 6.

2. IF normal letdown flow is to be estabilshed, THEN GO TO SectIon 4.3.

ATC NOTE EA-62-3, Establishing Excess Letdown, may be utilized if Normal Letdown cannot be establIshed.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 2 Event # 1 Page 4 of 68 Event

Description:

lB-B CCP trip Time jj__Position Applicants Actions or behavior 1 IF charging flow NOT estabhshed, ATC THEN PERFORM Section 42.

ATC 2. VERIFY pressurizer level greater than 17%.

3. ENSURE letdown orifice isolation valves CLOSED:

LETDOWN ORIFICE ISOLATION VALVES CLOSED ATC FCV-62-72 0 FCV-62-73 0 FCV-62-74 0

4. OPEN Ietown isolation valves:

LETDOWN ISOLATION VALVES OPEN ATC FGV-62-69 C FCV-62-70 C FCV-2-77 C NOTE Placing cooling water on the Letdown Heat Exchanger plior to restoring letdown flow should prevent TIS-62-7951A from actuating and fully opening TCV-70-192.

5. PLACE [HlC4278j in MANUAL, AND OPEN ITCV-70.192] to 50%.

6. PLACE letdown pressure controller [PCV42-811 in MANUAL and, ADJUST output between 40% and 50%, (50%-60% open).

I ATC 7. ADJUST charging flow as necessary to prevent flashing in the letdown line.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 2 Event # 1 Page 5 of 68 Event

Description:

1 B-B CCP trip Time Applicants Actions or behavior 1__Position

8. OPEN letdown orifice isolation values as needed:

LETDOWN ORIFICE ISOlATION VALVES OPEN I

ATC FCV-62-72 D l-CV. 52-73 FCV-f32-71 ATC Places HS-62-73 (or 74) Letdown Orifice B (or C) isol 7. gpm to OPEN.

NOTE Normal letdon pressure is 325 psig at normal operating lemperalure 9 ADJUST letdown pressure controller [PCV42-813 output to obtain desired pressure.

10. ADJUST letdown pressure controller [PcV-62-81] setpoint to match existinq pressure.

Adjusts letdown pressure controller PCV-62-81 setpoint to match existing ATC pressure.

11 PLACE letdown pressure controller [PcV-62-811 in AUTO NOTE Normal letdown temperature is 1OOF.

12. ADJUST [H1C-62-78A1 to obtain desired letdown temperature, as indicated on fli-62J81.

Examiner Note: Several steps, notes, and cautions in the procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Examiner Note: Letdown temperature may swing due to repeated actuation of TIS-62-79B/A, which causes letdown temperature control valve TCV-70-192 to fully open.

Appendix D Scenario Outline Attachment I OpTestNo.: NRC2O12-302 Scenario# 2 Event# I Page 6 of 68 Event

Description:

I B-B CCP trip Time Position Applicants Actions or behavior Examiner Note: SRQ continues the performance of AOP-M.09 actions here

15. NOTIFY STA or other available SRO licensed operator to refer to App. A, Tech Spec Impacts.

UMITThIG CONtNTION FOR OPERATION 3.fi.2 Two EGGS rains shall be OPERABLE.

NOTES-------------

1. In MODES, both safety injeon (S)panp ow paths may be isolated by dosing the isdadon valves for up to 2 hcwsto perform pressue clation valve s1ing per SR 4.4.8.3.

2, In MODES, EGGS piaaps may be made incable of irectin to suWort ttansiticn into or from IheAPPUCABLITh of LCO SA.12, Low Temperature Ovepreswre Protection TOP)

System for upto4 hours or until the temperature of a RCS cold legs exceeds LTOP armtog temperature 35O9 specifIed in the PTLR plus 25SF, wtiicheirer comes first, APPLICABILITY: MODES 1,2 d 3.

ACTION:

a. W ore or more Irans woperabIe ano wit at east 100% of ie ECCS flow eq ,sert to a wne OPERABLE ECCS Iran aaiIab!e, restore the no erable ran1is to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months orbe n al east HOT SANDBY w.:hin the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and HOT SHUTDOWN wth the fiwng 6 hcurs.

SRO Enters the TR 3,t2.4 Action LIMLflNG CONDITION FG OPERATION TR 3L2 4 At Ieal two charg ng pumps shall be OPERABL APPLICABILITY: MODES 1.2, asd 3 ACTION:

Wth only one darging psnp OPERABLE. restore at least two dargixtg pumps to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months crbw in at least I-tOT STANDBY and berated to a SHUTDOWN MARGIN equivalent to at least 1% delta (k at 20CFwith%n the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ; restore at least two charging pumps to OPERABLE status within the next 7 days or bern HOT SHUTDOWN within the next 3& hours.

Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event when the SRO has addresses Tech Specs and the TRM.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenano# 2 Event# 2 Page 7 of 68 Event

Description:

Feed water header pressure transmitter PT-3-1 B fails high Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 2, Feed water header pressure transmitter fails high; PT-3-IB.

I ndicationslAlarms Annunciator:

1-M-3

1-XA-55-3B-DI MAIN FEEDWATER DIGITAL CONTROL SYS TRANSFER TO MANUAL Indications:

I-M-3

FW MASTER CONTROLLER shifts to MANUAL (AMBER) 1-M-4

1-FI-3-35A, 35B, 48A, 48B, 90A, 90B, 103A, 103B, SG-I thru 4 SG FW INLET FLOW Chs I&2 increasing flow- above steam flow ICS

Thermal Power Increasing MAIN FEEDWATER DIGITAL CONTROL SYS TRANSFER TO MANUAL

[1] IF using the hand controllers to deternine wNch Digital Feedwater controller(s) has transferred to manu, TI-EN DETERMIE which controller(s) in Manual by ORANGE baddit Manua1 on ccitroller

[2] IF using the DCS Operator Display monitors to detemine which Digital Feedwater contrdler(s) has transferrad to W4NUAL, THEN OBSERVE controller(s) ye1Iow status light being UT.

[31 ADJUST controller(s) to maintain system parameters steady.

[4] NOTIFY US which controller(s) are in manual and system status

Appendix D Scenario Outline Attachment I OpTestNo.: NRC2O12-302 Scenario# 2 Event# 2 Page 8 of 68 Event

Description:

Feed water header pressure transmitter PT-3-1B fails high Time Position I Applicants Actions or Behavior 1$] WanyofthefoUaAngaccur

System parameters can NOT be mailitained OR

AtthecfisretionoftheUS THEN GO TO any of the followinq:

AOP-CQ3, Emergency Shutdown

AOP-S.U1, Main Feedwater Ma1ft#cfions

E-Q, f?eaoor Trip & Safety 1njecbon BOP Responds to ARP 1-AR-M3B D-1.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Evaluator Note: For this event, crew may respond per the Annunciator Response Procedure directly enter AOP-S.O1 Section 2.2. Section 2.2 Step I is an IMMEDIATE ACTION step; the BOP may perform the action(s) associated with Step 1 from memory without direction.

t DIAGNOSE the failure:

IF GOTO PAGE SECTION Failure of Automatic SIG Level Control 2.1 4 Failure of Automatic MFW Pump Control 2.2 7 LOSS of One Main Feedwater Pump 2.3 12 Above 76% (Unit 1 or 77% (Unit 2) Turbine Load Main Feedwater Pump Thp 2.4 19 Below 76% (Unit 1) or 77% (Unit 2) Turbine Load NOTE Step I is an IMMEDIATE AGTION

$1 ----

74.!

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 2 Event # 2 Page 9 of 68 Event

Description:

Feed water header pressure transmitter P1.3-i B fails high Time Position Applicants Actions or Behavior

1. RESTORE feedwater pressure:

a. ENSURE affected MFP speed controuer(s) in MANUAL:

MFPT A & B Speed Control OR

MFPT A Speed Controller BOP OR

MFPT B Speed Controller

b. ADJUST speed on affected MFP(s) to restore feedwater pressure to normal (1O4O psig at fUll power) 2 DETERMINE ft MFP trip is needed:

BOP

a. CHECK BOTh MFW pumps IN SERVICE.

CAUTION: Feed flow transients may impact core thermal power.

3. MAINTAIN steam generator level(s)

BOP on prograni NOTE: Appendix C or DCS Operator Display monitors MFP Control screen may be used to determine program feedwater DIP for current power

4. MAINTAIN MFP discharge pressure BOP on program USING OCS Operator Display monitors, ICS, or available control board indications.

CAUTION Reactor operation at low power levels for extended periods may challenge reactivity control due to xenon changes.

BOP 5 CHECK Reactor power greater than 5%.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario# 2 Event# 2 Page 10 of 68 Event

Description:

Feed water header pressure transmitter PT-3-1B fails high Time Position Applicants Actions or Behavior CREW & INITIATE repairs on faIed equipment.

7. WHEN automatic control of affected MFW pump controller(s) is available and reiiab1e THEN PLACE controller(s) in AUTO USING 1 ,2-SO-98-T, Distributed Contiol System.

SRO NOTE: Instructions fbi restoring bypassed instrument channels are contained in 1 ,2-SO-98-1,

8. GO TO appropriate plant procedure END OF SECTION Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

END OF SECTION Lead Examiner may cue the next event when plant is stable with MFP speed control in manual.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 3 Page 11 of 68 Event

Description:

NIS Power Range instrument Channel I fails high Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 3, NIS Power Range Channel I (N41) OUTPUT Signal Failure High Indications available:

. Control Rods Inserting M-4 Indicator ramps to full scale

. I-AR-M4-B. D3 IPRS NIS POWER RANGE OVERPOWER ROD WITHDRAWAL STOP

. I-AR-M6-A. BI NC-4IUINC-41-K NIS POWER RANGE HIGH NEUTRON FLUX RATE

I-AR-M6-A. DI NC-41R NIS POWER RANGE HIGH SETPOINT HIGH FLUX LEVEL es edia o o Ia -8 nsi o .OlRodC S io DIAGNOSE the failure:

GOTO IF... SECTION PAGE Uncontrolled rod bank movement (rod movement NOT clue to actual Tavg/T-.ret mismatch 21 4 or change in reactor!turbine power)

NOTE: Step I is an immediate action step

1. STOP uncontrolled rod motion:

a PLACE rod control in MAN ATC

b. CHECK rod motion STOPPED.

CAUTION: Control Rods should NOT be manually withdrawn during a plant transient.

2 CHECK for plant transient:

ATC a. CHECK reactor power and T-avg STABLE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 2 Event# 3 Page 12 of 68 Event

Description:

NIS Power Range instrument Channel fails high Time Position Applicants Actions or Behavior

3. CHECK for instwmentation malfunction:

a CHECK all Vital Instrument Power Boards ENERGIZED:

ATC

. VITAL POWER BOARD UV OR BREAKER TRIP alarms [M-IC windows A-7, 8-7, C-7, and D-7 DARK

b. CHECK nuclear instrumentation b. GO TO AOP-L0i, Nuclear Instrument ATC OPERABLE. Malfunction.

SRO Transitions to AOP-l.O1. Nuclear Instrument Malfunction.

DIAGNOSE the failure:

GOTO PAGE SECTION Power Range Failure 2.3 14 t PLACE rod control in MAN, ATC

2. IF power rise is in progress, ATC THEN STABILIZE reactor power at current leveL

3. EVALUATE the tollowrng Tech Specs for applicability:

3.311 (3.31). Reactor Trip System Instrumentation

3.3.3.5, Remote Shutdown SRO Instrumentation

3.3.3.7, Accident Monitoring Instrumentation

4.2.4.2, QPTR with one PR Channel Inoperable

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 3 Page 13 of 68 Event

Description:

NIS Power Range instrument Channel fails high Time Position 1 Applicants Actions or Behavior L}MNG CONDITION FOR OPERAI1ON 3.3.1,1 As a minimum, the reacter ip system inumentati channels and nterlocs sTable 3.3-1 that be OFERA.LE.

APPIiCABTUTY: As .hwn in Table 3.3-1 ACflOPt As shown in Table 3.3-1.

2. PowerRange, Neutron Fb 4 2 3 1,2 2

3. Power Range, Neutron Pox 4 2 3 1.2 2 High Positlee Rate

7. Overtemperature T Four 4 2 3 1.2 8 Loop Operaboo

5. OwepoweiFowLcop 4 2 3 1.2 8 Ooerabon

4. CHECK ThREE power range channels ATC OPERABLE

5. PLACE following switches located on Detector Current Comparator drawer

[M-13, N501 in position corresponding to failed Power Range Channel:

. Upper Section CREW

. Lower Section

. Appropnate Rod Stop Bypass switch

. Appropriate Power Mismatch Bypass switch

6. DEFEAT failed Power Range Channel USING Comparatol Channel Defeat switch:

CREW

. Comparator and Rate Drawer

[M-13, N37]

CAUTION: Control rods should NOT be manually withdrawn during a plant transient.

NOTE: Tavg is requirei to be within 1°F of Tref when restoring automatic rod control.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 3 Page 14 of 68 Event

Description:

NIS Power Range instrument Channel I fails high Time Position Applicants Actions or Behavior

7. RESTORE Tavg as necessary USING one of the following:

manual rod control ATC a RCS borationlddulion OR.

turbine load reduction ATC Places HS-85-51 11 Rod control to OUT to restore TAVE to within 1 5 deg F of TREF

8. IF reactor power is greater than P-6 (10 %)

THEN ENSURE OPERABLE Power Range channel selected on the following:

ATC

NR-45 Recorder [M-4]

RCS Temp T recorder (green pen)

[M-5, XS-68-2B1 9 IF auto rod control IS desired, ATC THEN RESTORE rod control to AUTO.

ATC Places HS-85-51 10 ROD CONTROL MODE SELECTOR in AUTO.

10 CHECK reactor power gier thdn 75 GO TO Step :2 CREW

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 3 Page 15 of 68 Event

Description:

NIS Power Range instrument Channel I fails high Time Position Applicants Actions or Behavior

12. NOTIFY l&C to remove tailed power range channel lrnm service USING appropriate Appendix:

POWER RANGE PROT CHANNEI CR APPENDIX N-41 I A N-42 II B CREW N-43 III C N-44 IV 0

13. GO TO appropliate plant procedure.

END OF SECTION Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Manaciement Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

When technical specifications have been identified or at discretion of the Lead Examiner, proceed to the next event

[ Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-302 Scenario # 2 Event# 4 Page 16 of 68 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 4, #2 SG Tube Leakage of 47 gpm Indications available:

Annunciators:

I-M-I O-XA-55-12A Window 8-5, I-RA-120A1121A, STM GEN BLDN LIQ SAMP MON HI RAD O-XA-55-12A Window C-I, I-RA-90-II9A, CNDS VAC PMP LO RNG AIR EXH MON HIGH RAD XA-55-30 C-8, RA-421A, MN STM LN HI RAD Indications available:

Deviations or unexpecteci indications on any of the following may indicate a steam generator tube leak:

1. charging flow rises to maintain Pressurizer level.

2. Rise in rnaiceup to VCT,

3. Rising activity on:

Condenser Vacuum Exhaust Radiation Monitor

SIG Blowclown Liquid Radiation Monitor

Main Steam Line Monitor

& S!G sample results indicating greater than or equal to 5 gallons per day (gpd) on any 31G.

I -RA-90-I 19A CNDS VAC PMP 10 RNG AIR EXH MON HIGH RAD

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O12-302 Scenano# 2 Event# 4 Page 17 of 68 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior

[1] CKECK 1-RM-90-1 19 rate meter and 1-RR-90-119 on O-W12 for indication of increased radiation.

NOTE Alarm dtty may be detemined based on absence of insfrument malfunction alarm, indicated response of the rad monitor, id, if possibe, other indications such as b4owdn monitor (recognizing the difference in response time due to blowdown transport time).

[2J IF aLarm is valid, ThEN NOTIFY RCLto perform I CEM.O68-1375 Primary to Secondary Leaka via Steam Generators.

[3] IF alarm is valid, THEN GO TO AOP-ftOI, Steam Generator Tube Leal [C.2]

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Examiner note if the crew implements section 2.2 go to page 20

1. DIAGNOSE the failure:

IF... 0070 SECTION PAGE High Secondary Radiation AND 2.1 4 Pressurizer level dropping OR charging flow rising

1. MONITOR if Pressurizer level can be maintained:

a. CONTROL charging flow USING FCV-62-93 and FCV-62-89 as necessary to maintain pzr level on program.

b. MONITOR pressurizer level STABLE or RISING.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 4 Page 18 of 68 Event

Description:

Steam Generator Tube Leak Time Applicants Actions or Behavior II__Position

b. MONITOR pressurizer level STABLE b. PERFORM the following; or RISING.

1) ENSURE letdown isolated:

ATC

FCV-62-72 CLOSED

FCV-62-73 CLOSED

FCV-62-74 CLOSED FCV-62-73

_.._...L_and_FCV-62-74toCLOSE. *.__

NOTE I Appendix F or G can be used to estimate leak rate.

NOTE 2 It letdown was isolated in Step 1 the leak rate may have exceeded the capacity

[ of one CCP in the normal charging alignment (EAL I .2.2P).

Examiner note; Appendix F starts on page 23

2. EVALUATE EPIR-1, Emergency Plan SRO Classification Matrix.

3. MONITOR VCT level:

MAINTAIN VCT level greater than 13%

ATC USING auto or manual makeup

CHECK VCT makeup capability adequate to maintain level.

4. MONITOR indications of leaking S/G:

a. NOTIFY Chem Lab to evaluate Primary to Secondary Leakage USING 1 (2)-Sl-CEM-068-1 37.5:

CREW

Method 1, Rapid Identification of Leaking Steam Generators

Method 3, Condenser Vacuum Exhaust (CVE) Sampling for Determination of Primary-to-Secondary (P/S) Leakage.

b. NOTIFY Radiation Protection to monitor Turbine Building and site environment:

CREW

Steam lines

S/G blowdown

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 4 Page 19 of 68 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior

c. IDENTIFY leaking S/G(s)

USING any of the following:

. Unexpected rise in any SIG narrow range level OR

S)G sample results CREW OR

Radiation Protection survey of main steamlines and S/G blowdown lines OR a High radiation on any main steamline radiation monitor.

Evaluator Note: SRO may refer to Operations Chemistry Information Sheet in turnover package.

5. EVALUATE the following Tech Specs for applicabiHty:

. 3.4&2, Operational Leakage a 3.7.1.4, Secondary Coolant Activity NOTE Initiating shutdown required by Tech Specs requires 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months NRC notification per SPP-3.5, Regulatory Reporting Requirements.

6. INITiATE rapid shutdown by performing the following:

a. ANNOUNCE S/G tube leak on PA system.

b. PERFORM rapid shutdown CREW USING AOP-C.03 WHILE continuing in this section.

c. ENSURE power reduced to less than 50% within one hour.

d. ENSURE unit in Mode 3 within the following 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 20 of 68 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior I

Examiner note AOP-C.03 actions start on page 27 CR0 Continues with performance of AOP-R.O1 L M:INIMIZE Spread of contamination:

a. IF tube leak identified on SIG #1 AND SIG #4 is intact, THEN PERFORM the following:

BOP

1) EVALUATE LCO 37t2

2) CLOSE FCV-1-15 TDAFWP steam supply from S!G #1.

3) ENSURE FCV-1 -16 TDAFWP steam supply from SiC #4 OPEN.

b PERFORM EA-O-3, Minimizing Secondary Plant Contamination.

c IF SIC blowdown is aligned to the river, THEN TERMINATE SJG Blowdown to river.

1) ENSURE SIC blowdown flow control BOP FCV-15-43 CLOSED

2) DISPATCH opemtor to perform EA-15-1, Realigning SIC Blowdown to Cond D1

3) WHEN EA-15-1 completed, THEN ADJUST FCV-15-43 to establish desired blowdown flow.

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 4 Page 21 of 68 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior

7. d. NOTIFY Chem Lab to determine release rate for condenser vacuum exhaust: USING O-Si-CEM-030-415.O and O-Sl-CEM-030-4072.

e NOTIFY Chem Lab to evaluate rerouting steam generator sample drain lines to FDCT USING O-Tl-CEM-OOO-OI6..4.

f. WHEN notified by Chemistry to bypass Condensate DI, THEN DISPATCH AUO to bypass polishers an affected unit:

Unit 1 Only:

PLACE I-HS-14-3, Condensate Polisher Bypass Valve to OPEN

[Cond Dl BIdg SOP

Unit 2 Only:

PLACE 2-HS-14-3, Condensate Polisher Bypass Valve to OPEN.

[Cond Dl BIdg]

g. EVALUATE Appendix C, Contingency Plan for Control and Processing of Large Volumes of Contaminated Water C.5).

Examiner note Section 2.2 starts here.

NOTE This section provides steps to nxnitor primary to secondary leakage and directs unit shutdown if leakage limits are exceeded. Entry into this section is required when secondary radiation monitors indicate a rise in primary-to-secondary leakage or when Chemistry determines SIG leak rate exceeds 5 gal. per day (gpd).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 2 Event# 4 Page 22 of 68 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior

1. MONITOR charging flow and IF Charging flow rising Pressunzer level STABLE. OR Pressurizer level dropping due to SIG tube leak, ATC THEN GO TO Section 21:.

2. EVALUATE EPIP-1, Emergency Plan SRO Classification Matrix.

a. EVALUATE the following Tech Specs for applicability:

ATC

3.4.6.2, Operational Leakage

3.7.1.4, Secondary Coolant Activity NOTE Lower containment r&d monitor count rate rising concurrenfly with secondary r&d monitors may indicate a sudden fuel defect, which could give a false indication of SIG tube leak. Threshold values for coneiating RM-9O99/1 19 count rate to SIG tube leakage must be recalculated if RCS activity has changed significantly.

4. INITIATE sampling to confirm S!G leak:

a. CHECK Lower containment rad monitor CREW count rate STABLE or DRoPPING.

b. PERFORM Appendix E, Chemistry Sampling Actions.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 23 of 68 Event

Description:

Steam Generator Tube Leak Time I Position Applicants Actions or Behavior CAUTION: The clock starts for power reduction or shutdown in Step S when any valid indication is available that the applicable leak rate threshold is exceeded.

Required time limits for power reduction or shutdown should NOT be exceeded due to delays in confirming leak rate.

NOTE 1: Based on monitor sensitMty, condenser vacuum exhaust rad monitor (RM-90-99 or -119) is prefelTed indication for leak rate monitoring. Other secondary lad monitors (if available) and/or S!G sampling should be used for conhirrnat[on.

Confirmation time should be kept to a minimum.

NOTE 2: Rai Monitor values (cpm) must be converted to a gallons per day (gpd) equivalency to determine leakrate. Correlation of RM-90-99/1 19 responses to Primary -

Secondary leak rates and limits are provided by Chemistry in turnover package.

NOTE 3: Steady State conditions (less thanlO% power change per hour> are required to accurately correlate cpm readings vith gpd leakage.

5. MONITOR primary-to-secondary leak rate:

a. PERFORM Appendix A, Radiation Monitor Trending Data every 15 mm.

USING available lad monitors.

b. VERIFY rise in count rate validated by at least one of the following:

SRO

sample results confirming rise in S/C activity OR

two independent secondary fad monitors showing rise in count rate.

c. REFER TO Appendix B, Summary of Action Levels for SIC Tube Leak.

NOTE I When monitoring leakage using radiation monitors, primary to secondary leakage should be monitored over several minutes to ensure that rise in leakage is not a temporary spike.

NOTE 2 Leakage action levels apply to leak rate from a single 31G. If unable to determine leakage from individual S!Gs, total leakage should be assumed to be coming from one 3/G.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 24 of 68 Event

Description:

Steam Generator Tube Leak Time Position 0 Applicants Actions or Behavior

6. MONITOR shutdown requirements:

BOP a. CHECK condenser vacuum exhaust Tad monitor RM-9C1-99 or RM90-i 19 OPERABLE NOTE if leak rate exceeds 7 gal per day (Action Level 3) based upon condenser vacuum exhaust rad monitor and NO SIG blowdown lad monitor is available to validate leak, required actions to shut down shall be initiated based upon the one available rad monitor.

& Ii CHECK Pflmary to Secondary leak b. IF leak rate in affected SIG(s) rate in affected SIG(s) greater than or equal to 75 gal per ,

less than 75 gal per y. ThEN PERFORM the following:

1) ENSURE power less than 50%

BOP within 1 hrandunittnMode3 within next 2 hrs (total of 3 flrs).

2) GO To Section 2.1 to shut do.

Examiner Note: crew should realize leak is sufficient and transitions to section 2.1, page 7 Step 6 RNO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 25 of 68 Event

Description:

Steam Generator Tube Leak SON STEAM GENERATOR TUBE LEAK AOP-R.O1 Rev26 Page 1 of 1 APPENDIX F ESTIMATING RCS LEAK RATE USING CVCS FLOW BALANCE NOTE I This method is recommended when leak requires rise in charging flow greater than -10 gpm.

Appendix G is more accurate for smafler leak rates.

NOTE 2 This appendix assumes RCS temperature and charging flow are approximately constant.

INITIAL FINAL CHANGE PZR Level (neeative for eve decrease iii I Time 1 Charging Flow (3]

Letdown Flaw Total RCP Seal Return Flow Pressurizer Level Conversion

[4]

151 I Pressurizer level conversion Time Change Pzr Level Rate of Change change factor (positive for tevel rising)

% x 62 gal! mm gprn step 11] above step [2] above [6]

Leak Rate Calculation Charging Flow Letdown Flow Seal Return Pzr Level Instrument error RCS Leak Flow Rate of Change correction factor Rate

+ 3gpm gpm step [1 above step [4] above step [51 above step [6] above Page 64 of 68

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 2 Event# 4 Page 26 of 68 Event

Description:

Steam Generator Tube Leak SON STEAM GENERATOR TUBE LEAK L

Page 1 of 1 APPENDIX G ESTIMATING RCS LEAK RATE USING VCT AND PZR LEVEL CAUTION This appendix CANNOT be used during VCT makeup. boration, or dilution.

NOTE This appendix assumes RCS temperature is approximately constant.

VCT LEVEL (%) PZR LEVEL (%) TiME (mm)

INITIAL FINAL CHANGE iii 12] 131 (positive f& level decrease) positive toc level decrease)

VCT Level Conversion VCT level change conversion Time Change VCT Level factor Rate of Change (positive for level lowering)

% X 2OgaI/% . mm = gprn step [1] above step [31 above [4]

Pressurizer Level Conversion Pressurizer level conversion Time Change Pzr Level change factor Rate of Change (positive for level lowering)

% X 62ga11% ÷ miri = gpm step [2] above step [3] above [5]

Leak Rate Calculation VCT Level Pzr Level RCS Leak Rate Rate of Change Rate of Change

+ gpm step [4] above step 151 above Page 65 of 68

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 5 Page 27 of 68 Event

Description:

Power reduction Time Position N Applicants Actions or Behavior Simulator Operator: No action required for Event 5, Rapid Power reduction SRO Directs performance of AOP-C.03 RAPID SHUTDOWN OR LOAD REDUCTION.

ENSURE crew has been briefed on reactivity SRO management expectations USING Appendix A.

REACTIVITY MANAGEMENT BRIEFING NOTE This appendix should be used in addition to event-based brief

[1] ENSURE crew has been briefed on the following:

. Reason for Rapid Shutdown or Load Reduction

Load Reduction Rate:________

. Desired final power level:______

. Reactivity Management expectations:

Unit Supervisor shall concur with all reactivity manipulations

. Ensure reactor responding as expected using diverse indications

. Tavg-Tref Mismatch requirements:

. 3F control band

. 5F reactor trip criteria

. Crew focus will be on reducing power in a controlled and conservative manner.

. OATC will monitor rod insertion limits and AFD limit

. Boratiori source:

. Crew will monitor reactor trip and turbine trip criteria using App. B

CR0 will stop secondary plant equipment using App. C.

. If time permits, review expected annunciators (ex Computer Alarm, Upper and Lower Flux Dev)

. Termination Criteria (conditions requiring Reactor Trip, Turbine Trip, or condition no longer requiring rapid load reduction):

Appendix D Required Operator Actions Form ES-D-2 Applicants Actions or Behavior

2. NOTIFY following personnel of rapid shutdown or load reduction:

. Load Coordinator [Cii CREW

Chemistry

. Radiation Protection

. Plant Management CREW Makes notifications as required.

3. MONITOR reactor/turbine trip NOT required CREW USING Appendix B, Reactor and Turbine Trip Criteria.

Examiner note: Appendix B reactor and turbine trip criteria see page 32 4.. CHECK VALVE POSITION LIMIT light B P DARK on EHC panel. [M2]

NOTE: Boration volumes and tlowrates listed in this procedure are recommendations and may be: adjusted as necessary.

5. INITIATE boration:

a. CHECK rod control AVAILABLE:

ATC

Control Bank D rods capable of being moved

NO dropped or misaligned rods in Control Bank 0.

5. Ii CHECK Control Bank D group position greater than 200 steps.

ATC

c. CHECK boratlon capabiltty from BAT AVAILABLE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 5 Page 29 of 68 Event

Description:

Power reduction Time Position Applicants Actions or Behavior ci. DETERMINE recommended boratton volume from BAT:

-80Q gal to reduce power from 100%to2O%

OR SRO

10 gal for each 1% power reduction (from current power level)

OR

volume recommended by Reactor Engineering.

5 e. DETERMINE recommended boration flowrate from table below or from Reactor Engineering:

SRO LOAD REDUCTiON BORATION

. RATE(%Irnin) FLOWRATE 2% -30 gpm 3% -45gpm a f. ENSURE concurrence obtained from ATC STA for boration volume and fiowrate

g. ENSURE boric acid transfer pump ATC aligned to blender in FAST speed.

h. ADJUST FCV-62-13B to establish ATC desired flow rate f CONTROL boration flow as required to inject desired boric acid volurn&

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 5 Page 30 of 68 Event

Description:

Power reduction Time Position Applicants Actions or Behavior CAUTION: If borating from the RWST, Turbine Load Reduction Rate greater than 2% per minute could result in violating Rod Insertion Limit.

INATE load reduction as follows:

a. ADJUST load rate to desired value:

between 1% and 4% per minute it borating via FCV-62-138 BOP OR

between 1% and 3% per minute if borating via normal boration (App H)

OR

2% per minute if borating from RWST

b. ADJUST setter for desired power level:

DESIRED RECOMMENDED BOP RX POWER LEVEL SETTER VALUE 20%orless 15 S. c VERIFY boration flow established.

BOP

d. INATE turbine load reduction by depressing GO pushbuttorL BOP Depresses GO pushbutton.

e. CONTROL turbine load reduction as necessary to reduce power to desired level.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 5 Page 31 of 68 Event

Description:

Power reduction Time Position Applicants Actions or Behavior

7. MONITOR T-avg)T-ref mismatch:

ATC

a. CHECK T-ref indicaton AVAILABLE.

7 b. MONITOR automatic rod control ATC maintaining T-avglT-ret mismatch less than 3F.

ATC Coordinates with the BOP to maintain T-avg!T-ref mismatch less than 3°F.

8. MONITOR automatic comrol of BOP MFW pump speed AVAILABLE

9. STOP secondary plant equipment BOP USING Appendix C, Secondary Plant Equipment.

Examiner Note: Appendix C, Secondary Plant Equipment starts at page 33.

Examiner Note: Additional AOP-C.03 steps not included as required power reduction should be complete at or around this step.

Examiner Note: When the crew has sufficiently reduced power go to event 6 page 43.

Appendix D Required Operator Actions Form ES-D-2 APPENDIX B REACTOR AND TURBINE TRIP CRITERIA REACTOR TRIP CRITERIA TURBINE TRIP CRITERIA Turbine trip required or imminent Turbine vibration exceeding 14 mils with reactor power greater than P-9 (50%) with one of the following:

Uncontrolled rod movement wiiich CANNOT be

high vibration on multiple bearings stopped by placing rods in MANUAL oc.oii OR Loss of SIG level control:

abnormal noiseMbration apparent level dropping or rising toward trip setpoint and level CANNOT be restored oP-s.a1)

More than one dropped rod oc.üi T-avgiT-ref mismatch CANNOT be maintained less than 5°F (refer to Step 7or App. E) 30% turbine load: <30% turbine load:

Condenser Pressure > 2.7 psia AND CANNOT Condenser Pressure> 1.72 psia be restored within 5 minutes (AoP-s.02) {AOP-S2>

Any automatic reactor trip setpoint reached Any automatic turbine trip setpoint reached OR automatic trip imminent OR automatic trip imminent

Turbine trip above P-9 (50%) a High Stator Cooling Water temp 90*C a Safety injection OR Stator DIP 12 psig below normal

Power Range high flux 109%

Both MEPEs tripped

Power Range flux rate +/-5% in 2 seconds

Low Auto Stop Oil pressure 45psig

Pressurizer high level 92%

High SIG level 81% narrow range

Pressurizer pressure low 1970 psig

Main Turb Bearing Oil low pressure 7 psig

Pressurizer pressure high 2385 psig

Thrust Bearing Oil high pressure 60 psig

RCS low fjw :98% Turbine Overspeed 1980 rpm

RCP undervoltage 5.022 kilovolts

LossofEHcpressure

RCP undertrequency 56.0 Kz

Generator PCB5 tripped.

OTAT 115% (variable)

OPAT 108,7% (variable)

SIG low level 10.7% [15% EAM]

SSPS general warning in both trains

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC 2012-302 Scenario# 2 Event# 5 Page 33 of 68 Event

Description:

Power reduction APPENDIX C SECONDARY PLANT EQUIPMENT ti] ENSURE plant announcement(s) made on the following:

starting rapid shutdown (or load reduction) due to (reason) Ci

stopping secondary plant equipment U NOTE I If reactor power will be reduced below 50%, AUO should be on station at #3 heater drain tank (if possible) when 60% power is reacheti NOTE 2 Dispatching of AUO in Steps [2] and [3] may be performed out of sequence.

[2] IF reactor power will be reduced below 50%,

THEN DISPATCH AUO with Appendix J (Unit 1) or K (Unit 2) to #3 Heater Drain Tank U

[3] IF one MFP will be shutdown using this appendix, THEN DISPATCH AUO to OPEN MFWP recirc manual isolation valve for MFWP to be removed from service: (NIA valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN I 1 IA :1/LV.3576 TB el. 706, Northeast corner of IA condenser U IB 1-VLV-3-577 TB eL 706. Northeast corner of 1A condenser fl 2 2A 2-VLV-3-576 TB eL 706, Southeast corner of 2A condenser U 28 2-VLV-3-577 TB el. 706, Southeast corner of 2A condenser fl

Appendix D Required Operator Actions Form ES-D-2 APPENDIX C t4 IF BOTH of the following conditions are met

power is being reduced as directed by AOP-S01 (Main Feedwater Malfunctions) or AOP-S.04 (Condensate or Heater Drain Malfunctions) leaving secondary pumps in service is desired.

THEN GO TO Step 8J 0 f5 WHEN turbine impulse pressure is approximately 80% or less, THEN PERFORM the following:

ia ENSURE one Cond Demin Booster Pump STOPPED. LI Ib] ENSURE associated suction valve CLOSED:

OR B FCV-2-285 c J CV28

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 5 Page 35 of 68 Event

Description:

Power reduction

[6) WHEN turbine impulse pressure is approximately 70-75%,

THEN PERFORM the following:

[a] ENSURE one Condensate Booster Pump STOPPE[DL

[b] ENSURE associated CBP suction vaLve CLOSED:

CONDENSATE BOOSTER pup SUCTION VALVE CLOSED 4 A FCV2-94 B FCV.287 OR FCV-2-81 J

[c] PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary)

1SO-2/3--1 Section 7.2 OR 2-S0-213-1 Section 7.3 U

Appendix D Required Operator Actions Form ES-D-2

[7] WHEN turbine impulse pressure is approximately 65% or less, THEN PERFORM the following:

[a] SI OP remaining two Cond Demin Booster Pumps simultaneously. U

[I,] ENSURE suction valves CLOSED:

COND DEMIN BOOSTER PUMP SUCTION VALVE CLOSED I A FCV-2-290 U B FCV2-285 U C FCV-2-280 U Ic] STOP one No 3 Heater Drain pump Id] STOP one No 7 Heater Drain pump.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 5 Page 37 of 68 Event

Description:

Power reduction 8j IF reactor power will be maintained greater than 5D%

THEN GO TO Notes prior to Step [1 1] U CAUTION Isolation of all three intermediate heater strings could occur if turbine is tripped prior to fully opening LCV-6-1 05A and B using Appendix J or K.

(9] WHEN reactor power is less than 60%

AND AUO with App. J (Unit 1) or K (Unit 2) is on station at #3 Heater Drain Tank, THEN PERFORM the following:

(a] STOP #3 Heater Drain Tank Pumps.

[b] NOTIFY AUO to perform App. J (Unit 1) or App. K (Unit 2),

Fully Opening #3 Heater Drain Tank Bypass Valves.

[c] CLOSE isolation valves from #3 Htr Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED I FCV-6-108 Htr Drain Tk Pump 3 to Htr String A U FCV-6-109 Htr Drain Tk Pump 3 to Htr String B U FCV-6-ii0 HtrDrainTkPump3toHtrStringC U

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 5 Page 38 of 68 Event

Description:

Power reduction NOTE I The following step ensures that MEW Bypass valves are avaitab to control feedwater flow at low power NOTE 2 if any MEW Reg valve is in MANUAL, the associated MFW Bypass valve controller should remain in MANUAL to prevent undesired opening of bypass valve.

[101 WHEN Reactor power is less than 50%,

THEN PERFORM the following:

Ia] IF all MEW Reg Valves are in AUTO, THEN PLACE MEW Bypass Reg Valve controllers in AUTO

[b] IF any MEW Reg Valve is in MANUAL, THEN PERFORM the following:

1) Mi INTAIN MEW Bypass Reg Valve in MANUAL for SIG with MEW Reg valve in MANUAL

2) PLACE MEW Bypass Reg Valves in AUTO for remaining S!Gs. U

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 5 Page 39 of 68 Event

Description:

Power reduction NOTE I if performing this AOP to reduce power to allow shutting down one MFW pump, the affected MFWP may be removed from service at power level less than 55% (Unit 1) or 65% (Unit 2)

NOTE 2 AFW start function on loss of both MFW pumps is inoperable when a MFW pump is RESET but NOT pumping forward LCO 3321 (Unit 1) or 3.3.2 (Unit 2) allows AFW start channel to be inoperable for upto 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months when shutting down a MFWP.

till WHEN it is desired to remove one MFW pump from service AND power level is less than applicable limit:

a turbine impulse pressure less than approximately 45%

OR

reactor power less than value specified in Note I THEN PERFORM the following:

fa] ENSURE MFWP Recirc Manual Isolation valve OPEN for MFWP to be removed from service: (NIA valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN q IA I -VLV-3-576 TB el 706, Noiiheast corner of IA condenser []

15 1-VLV-3-577 TB el. 706, Noitheastcorner of IA condenser 2 2A 2-VLV-3-576 TB el. 706, Southeast corner of 2A condenser fl 213 2-VLV-3-577 TB eL 706, Southeast corner of 2A condenser []

[b] THROTTLE OPEN recirc valve in MANUAL (30-50% OPEN) for MFWP to be removed from service. 0

[C) PLACE speed controller in MANUAL for MFWP to be removed from service.

[d] REDUCE speed gradually on MFWP to be removed from service.

Appendix D Required Operator Actions Form ES-D-2

[11] (Continued) te ENSURE proper loading on remaining MFWP.

[f] IF MFWP CANNOT be fully unloaded with speed controller, THEN PERFORM one of the following:

a NOTIFY i&C to slowly adjust hand speed changer for affected MFWP UNTIL MFWP is fully unloaded.

OR

THROTTLE OPEN recirc valve for affected MFWP to assist in unloading MFWP L:i OR

SLOWLY CLOSE governor valve by bumping dosed governor valve positioner (if operable)

OR

OBTAIN SRO concurrence that MFWP flow is sufficiently low to allow tripping MFWP.

tg] WHEN MFWP is unloaded sufficiently, THEN TRIP affected MAP.

[ii] CLOSE recirc valve for MFWP removed from service.

i] CLOSE recirc valve Manual Isolation inlet valve for MFWP removed from service.

U] OPEN drain valves for MFWP removed from service: IM-3]

IHS4S-14], MFWP A drain valves OR

1HS4631L MFWP B drain valves. n

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 5 Page 41 of 68 Event

Description:

Power reduction

[12] WHEN turbine impulse pressure is approximately 45% or less, THEN PERFORM the following:

[a] STOP remaining No 7 Heater Drain purnp U

[b] CLOSE isolation valves from #7 Heater Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED J

Fcv143 Htr Drain Th Pump 7 to Htr String A U FCV-6-163 Htr Drain Tk Pump 7 to Htr String B U FCV-6-184 Htr Drain Tk Pump 7 to Htr String C U 113] WHEN turbine impulse pressure is approximately 30% or less ThEN PERFORM the following:

[a] ENSURE main turbine EHC controls in IMP OUL

[1] IF #3 heater drain tank pumps are still running, THEN PERFORM Step f9] U Lcl STOP one of two remaining Condensate Booster Pumps.

(step continued on next ae)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 5 Page 42 of 68 Event

Description:

Power reduction

[131 (Continued)

[d] ENSURE associated CBP suction valve CLOSED:

OR FCV-2-87 El OR L c FCV-2.-81 El tel STOP one of three Hotwell Pumps. El

!1 PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary) 1SO-2i3-1 Section 72 OR

. 2.-SO-2/3-i Section 7.3

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event# 6,7 Page 43 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time fl Position Applicants Actions or Behaviors Booth Operator: When directed, initiate Event 7 Increases the SGTL to 800 gpm over three minutes.

Indications available:

1-M-3:

LOOP #2 FEEDWATER MAIN REG VALVE indicator shows a lower feed flow that steam flow; 1-M-4:

LOOP #2 FE indicators showing lower flow than SF for a constant power level.

RCS Pzr LEVEL Chs, 1-LI-68-339A, 335A & 320 going down slowly initially; 1-M-5:

RCS PZR LEVEL 1-LR-68-339 shows Pzr level trending down initially.

1-PR-68-69, RCS LOOP I HL WIDE RANGE PRESS indicator trending down.

CHARGING HDR FLOW lFl-62-93A indicating above normal flow to maintain Pzr level on program.

1-M-6:

1-Pl-68-66A, HL Pressure LOOP 3 indicator trending down.

1-Pl-68-62, RCS HL Press WR indicator trending down.

1-Pl-68-69, RCS HL Press WR indicator trending down.

Examiner Note: following IOA performance, prior to Steps 1-4 immediate action verification, ATC/BOP surveys MCBs for any expected automatic system response that failed to occur. Upon discovery, they may take manual action(s) to align plant systems as expected for the event in progress. (Ref. EPM-4, Prudent Operator Actions)

Examiner Note: Based on plant conditions the SRO may direct the crew to manually trip the Reactor and initiate Safety Injection.

I Appendix D Required Operator Actions Form ES-D-2 Time Position Applicants Actions or Behaviors CREW Performs the first four steps of E-O unprompted.

NOTE I Steps 1: through 4 are immediate action steps.

NOTE 2 This procedure has a foldout page.

1. VERIFY reactor TRIPPED:

Reactor trip breakers OPEN

Reactor trip bypass breakers DISCONNECTED or OPEN ATC

Rod bottom lights LIT

Rod position indicators less than or equal to 12 step&

Neutron flux DROPPING

2. VERIFY turbine TRIPPED:

BOP

Turbine stop valves CLOSED.

3. VERIFY at least one 6.9KV shutdown ATTEMPT to start DIGs.

board ENERGIZED on this unit.

IF power CANNOT be immediately restored to at least one shutdown board BOP on this unit, THEN GO TO ECA-O.O, Loss of AJI AC Power.

4. DETERMINE if SI actuated:

ATC

ECCS pumps RUNN1NG

Any SI alarm LIT [M-4D].

5 PERFORM ES-O5, Equipment BOP Verifications WHILE continuing in this procedure.

Continue with the performance of E-O REACTOR TRIP OR SAFETY SRO/ATC INJECTION BOP Performs ES-O.5, Equipment Verifications go to page 62 for details

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O12-302 Scenano# 2 Event# 6,7 Page 45 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behaviors pr I j j SRO Addresses foldout page.

FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

RCS pressure less than 1250 psig AND at least one CCP or SI pump running OR

Phase B isolation, THEN STOP all RCPs.

EVENT DIAGNOSTICS

IF any SIG pressure is dropping uncontrolled, THEN PERFORM the following:

a. CLOSE MSIVs and MSIV bypass valves.

b. IF any SIG pressure continues to drop uncontrolled, THEN PERFORM the following:

1) ENSURE SI actuated, 2> IF at least one SJG is intact (S!G pressure controlled or rising),

THEN ISOLATE AFW to faulted SIG(s):

CLOSE AFW level control valves for faulted S1G(s)

IF any AFW valve for faulted S/G CANNOT be CLOSED, THEN PERFORM Appendix E, Isolating AEW to Faulted 51G.

3) ENSURE at least one of the following conditions met

total AFW flow greater than 440 gpm OR

Namw Range level greater than 10% [25% ADVI in at least one intact 51G.

IF both trains of shutdown boards de-energized, THEN GO TO ECA-IlO, Loss of All AC Power.

TANK SWITCHOVER SETPOINTS

IF CST level less than 5%, THEN AIJGN AFW suction to ERCW.

IF RWST level less than 27%, THEN GO TO ES-13, Transfer to RI-IR Containment Sump.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-302 Scenario # 2 Event# 6,7 Page 46 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior

6. DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpm.

b. CHECK narrow range level b. MAINTAIN total feed flow greater than 10% [25% ADVI greater than 440 gpm ATC in at least one Sf0. UNTIL narrow range level greater than 10% [25% ADV]

in at least one 51G.

c. CONTROL feed flow to maintain narrow range level between 10% [25% ADVI and 50%

in intact or ruptured S/Gs.

Evaluator Note: ATC/BOP may perform the POA stated above to isolate AFW to the affected SG, once at least I of 4 SG5 is >10% NR for heat sink concerns.

L CHECK if main steam tines should be isolated:

a. CHECK if any of the following a GO TO Step 8.

conditions have occurred:

Any Sf0 pressure less than 600 psig ATC OR

Any Sf0 pressure dropping UNCONTROLLED OR

Phase B actuation.

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 2 Event# 6,7 Page 47 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior

8. CHECK RCP trip criteria:

a CHECK the following: a. GO TO Step 9.

RCS pressure ATC less than 1250 psig AND

. At least one CCP OR SI pump o ItStt.m%1(

9. MONITOR RCS temperatures: IF temperature less than 547°F and dropping,

. IF any RCP running, THEN THEN PERFORM the following:

CHECK T-avg stable at or trending to between 547°F and 552°F. a. ENSURE steam dumps and atmospheric reliefs CLOSED.

OR

b. IF cooldown continues, IF RCPs stopped, THEN THEN CONTROL total feed flow:

CHECK Tcold stable at or trending ATC/BOP 1) ENSURE total AFW flow to between 547°F and 552°F.

less than or equal to 600 gpm.

2) MAINTAIN total AFW flow greater than 440 gpm UNTIL narrow range level is greater than 10% [25% ADV]

in at least one SIG.

c. IF cooldown continues after AFW flow is controlled, THEN CLOSE MSIVs and MSIV bypass valves.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-302 Scenario # 2 Event # 6,7 Page 48 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior

10. CHECK pressurizer PORVs, safeties, and spray valves:

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

ATC c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

11 - DETERMINE if SIG secondary pressure boundaries are INTACT:

CHECK all SIG pressures ATC CONTROLLED or RISING.

CHECK all S/G pressures greater than 140 psig.

12 DETERMINE if SIG tubes are INTACT: IF any SIG has level nsing in an uncontrolled manner

All SIG narrow range levels OR has high radiation, CONTROLLED or DROPPING ThEN PERFORM the fdlowing:

ATC

Secondary radiation NORMAL USING Appendix A, Secondary Rad a. MONITOR status irees.

Monitors. (App. A pellormed in ES-0.5). b. GO TO E-3, Steam Generator Tube Rupture Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via SPDS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT I STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 6,7 Page 49 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior f SRO f Direct performance of E-3, Steam Generator Tube Rupture NOTE This procedure has a (oldout page.

FOLDOUT PAGE Si REINITIATION CRITERIA iF SI has been terminated AND either of the following conditions occurs:

RCS subcooIing based on core exit TICs less than 40F OR

Pressurizer level CANNOT be maintained greater than 10% [20% ADVI, THEN a ESTABLISH ECCS flow by performing one or both at the following:

ESTABLISH CCPIT flow as necessary USING. App ndix C

START CCPs or SI pumps manually as necessary.

b. GO TO ECA-3.1, SGTR and LOCA- Subcooled Recovery.

EVENT DIAGNOSTICS

IF both trains of shutdown boards deenergized, THEN GO TO ECA-DD, Loss of All AC Power.

IF any 510 pressure dropping in an uncontrolled manner or less th 140 psig AND Sf0 NOT isolated AND 510 NOT needed for RCS cooldown, THEN GO TO E-2, Faulted Steam Generator Isolation.

IF any Intact SIG has level rising in an uncontrolled manner OR has abnormal radiation.

THEN STOP any deliberate RCS cooldown or depressuiization and GO TO E-3 Step 1.

TANK SWITCHOVER SETPOINTS

IF CST level less than 5%,

THEN ALIGN AFW suction to EROW.

a IF RWST level less than 27%,

THEN GO TO ES-i.3, Transfer to RHR Containment Sump.

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC2O12-302 Scenario# 2 Event# 6,7 Page 50 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior ATC 1. MONITOR at least one RCP RUNNING.

2. MONITOR RCP trip criteria:

a. CHECK the following: a. GO TO Step 3.

RCS pressure less than 1250 psig ATC AND

At least one CCP OR Si pump RUNNING.

b. STOP RCPs.

3. MONITOR indications of Ruptured SIG(s):

a. IDENTIFY Ruptured 81(3(s) as indicated by any of the following:

. Unexpected rise in any 81(3 narrow range level.

OR

High radiation from any SIG Crew sample.

OR

RADCON survey of main steam lines and S!G bowdown lines.

OR

High radiation on any main steamline radiation monitor.

CAUTION It the TD AFW pump is the only source of feed flow, isolating both steam supplies will result in loss of secondary heat sink.

[Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 6,7 Page 51 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time j Position Applicants Actions or Behavior

4. ISOLATE flow from Ruptured SIG(s):

ATC/BOP

a. ADJUST Ruptured SiGs) atmospheric relief controller setpoint to 87% in AUTO. (1040 psig)

ATIBOP Places PIc-1-13A setpoint to 87%

h. CHECK Rupturec SG(s b. WHEN Rup:urei SGs, pressure atmospheric relief hand switch in less than 1040 psig, P-AUTO and valve(si CLOSED. THEN PERFORM the following:

1> VERIFY atmospheric relief CLOSED.

2) IF atmospheric relief NOT closed, ATC/BOP THEN CLOSE atmospheric relief.

IF Ruptured SIG(s) atmospheric relief CANNOT be closed, THEN DISPATCH personnel to close atmospheric relief USING EA-1-2, Local Control of S!G PORVs.

c. CHECK SIG #1 or #4 ruptured C. GO TO Substep 4e.

ATC/BOP e VERIFY Ruptured SIG(s) blowdowrt isolation valves CLOSEE1

f. CLOSE Ruptured S/G(s) MSIV ATC/BOP and MSIV bypass valve.

5. MONITOR Ruptured SIG(s) level:

ATC/BOP

a. CHECK ruptured SIG narrow range level greater than 10% [25% AD?].

Appendix D Required Operator Actions Form ES-D-2]

Op Test No.: NRC 201 2-302 Scenario # 2 Event# 6,7 Page 52 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior 1

b. ENSURE AFW isolated b. 1F any AFW valve for ruptured 51(3 to ruptured SIG: CANNOT be CLOSED AND affected AFW flowpath

1) CLOSE AFW LCVs is NOT isolated locally, for ruptured SIG. THEN PERFORM Appendix E, Isolating

2) PLACE Turtine Dnven AFW AFW to Ruptured 51(3.

LCV for ruptured 51(3 in CLOSE PULL TO LOCK.

APPENDIX E iSOLATiNG AFW TO RUPTURED SIG IF motor-driven AFW LCV for ruptured SIG AT(It CANNOT be closed.

THEN PERFORM the following:

a. iF at least one other AEW pump is available, THEN PLACE affected MD AFW pump in PULL TO LOCK.

ces ump oSTO K

IT CAL ATC/BO Places HS-3 173A to CLOSE and PTL *,*

6. VERIFY Ruptured SIG ISOLATED from Intact SJG(s):

a CHECK either of the following conditions SATISFIED:

Ruptured Sf0 MSIVs and MSIV bypass valves CLOSED ATC!BOP

. MSIV(s) and MSIV bypass valve(s)

CWSED on Intact 510(s) to be used for RCS cooldown.

b CHECK SIG #1 or #4 ruptured. b GO TO Step 7

7. CHECK Ruptured Sf0 pressure ATC/BOP greater than 550 psig (Unflj) or 425 psig (Unit 2).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event# 6,7 Page 53 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior NOTE

Blocking low steanine pressure SI as soon as pressurizer pressure is less than 1960 psig will prevent an inadvertent MSIV closure and keep the condenser available for steam dump.

After the low steamhne pressure SI signal is blocked, main steamlifle isolation will occur if the high steam pressure rate setpoint is exceeded.

The 1250 psig RCP trip criterion is NOT applicable after RCS cooldown is initiated in the following step.

8. INITIATE RCS cooldown:

a. DETERMiNE target core edt T/C temperature based on Ruptured SIG pressure:

ATC/BOP IL Lowest Ruptured SIG pressure (psig r Target Core Exit TIC Temp (F)

SRO/ATC U 1000 - l09 Determine target cooldown temperature of 486 dég .F..

486

8. b. WHEN RCS pressure less than 1960 psig, THEN PERFORM the following:

1) BLOCK low steamline pressure SI.

2) CHECK STEAMLINE PRESS ISOL/SI BLOCK RATE ISOL ENABLE permissive LIT.

[M-4A, M]

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-302 Scenario # 2 Event # 6,7 Page 54 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior

c. DUMP steam to condenser from Intact SIG(s) at maximum achievable rate:

1) CHECK condenser available:

C-9 condenser interlock permissive LIT.. [M-4A, E6]

intact SIG MSIVs OPEN

2) PLACE steam dumps in OFE

3) ENSURE steam dumps in steam pressure mode with demand less than 25%.

4) PLACE steam dumps in ON.

5) ADJUST steam dump demand to FULLY OPEN three cooldown valves.

6) WHEN T-avg is less than 540°F.

THEN BYPASS steam dump interlock.

7) RAISE AFW flow to intact S1Gs as necessary to support cooldown.

HS- S 0 ly e Du V es.

Places S- - a T INTLK when TAVG is less than 540 deg F

Appendix D Required Operator Actions Form ES-D-2 I Time Position Applicants Actions or Behavior 8 d. WHEN core exit TICS less than target temperature determined in Substep 8.a, THEN PERFORM the foflowing:

1) CLOSE steam dumps or SIG atmospheric reliefs.

2) REDUCE total AFW 110w to less than 600 gpm to stop cooldown..

MAINTAIN total feed flow greater than 440 gpm UNTIL level greater than 10% [25% ADVI in at least one Intact SIG.

3) MAINTAIN core exit TICS less than target temperature USING steam dumps or atmospheric reliefs.

9.. MAINTAIN Intact SIG narrow range leveLs:

a Greater than 10% [25% ADVI

b. Between 20% [25% ADV] and 50%

I Appendix D Required Operator Actions Form ES-D-2 I Time Position Applicants Actions or Behavior

10. MONITOR pressurizer PORV5 and block valves:

a. Power to block valves AVAILABLE ATC b Pressurizer PORVs CLOSED

c. At least one block valve OPEN.

11. RESET St signal.

ATC

. ATC Depresses HS-63-134A and 1346 SIS RESET TRAIN A & B BOP 12. MONITOR AC busses energized from start busses ATC 13. ENSURE Phase A and Phase B RESET.

ATC Depresses HS-30-63D arid 63E Phase A Isol Reset Train A & Train B

14. CHECK control air established to containment. [Panel 6K and 6L]

. I-FCV328O (2.FCV.32-8}

Train A essentaI ar OEN ATC

. I-FcV-:32-102 (2-FcV 103i Train B essential air OPEN

. 1-FCV-32-1iO(2-FCV-32-i1i) non-essential air OPEN.

Appendix D Required Operator Actions Form ES-D-2 Time Position Applicants Actions or Behavior

15. DETERMINE it RHR pumps should be stopped:

a CHECK RHR pump suction aligned from RWST.

b CHECK RCS pressure greater than 300 psig.

C. STOP RHR pumps and PLACE in A-AUTO.

d MONITOR RCS pressure greater than 300 psig.

ATC Places HS-74-IOA and 20A RHR Pumps_IA and IS to STOP

16. CHECKjfRCSoddow should be stopped:

a CHECK core exit TICS less than target temperature determined in Substep 8.a.

b. CLOSE steam dumps or atmosptieiic reliefs.

BOP c. REDUCE total AFW flow to less than 600 gpm to stop cooldown.

MAINTAIN total feed flow greater than 440 gpm UNTIL level greater than 10% [25% ADVI in at least one Intact SIG.

d. MAINTAIN core exit TICs less than target temperature USING steam dumps or atmospheric reliefs.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 6,7 Page 58 of 68 Event

Description:

2 SGTR and #2 SO MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior MONITOR Ruptured SIG(s) pressure BOP STABLE or RISING.

ATC 18. CHECK RCS subcooling based on core exit TiCs greater than 60°F.

19. DEPRESSURIZE RCS to minimize break flow and to reflfl pressurizer

a. CHECK normal pressurizer spray AVAiLABLE.

b. INITIATE maximum available pressurizer spray.

c. CHECK depressunzation rate ADEQUATE.

d. REDUCE RCS pressure UNTIL any ot the following conditions (also listed on handout page) are met:

Both of the following:

1) RCS pressure less than Ruptured 510(s) pressure AND

2) Pressurizer level greater than 10% [20% ADVI OR a Pressurizer level greater than 65%.

OR

RCS subcooling based on core exit T/Cs less than 40°F.

I Appendix D Required Operator Actions Form ES-D-2 Time Position Applicants Actions or Behavior

e. CLOSE spray valve(s):

1) Normal spray valves

2) Auxiliary spray valve.

t. GO TO Caution pnor to Step 22.

P A

pressu eria et.

CAUTION Any delay in terminating SI after termination criteria are met may cause Ruptured SIG(s) overfill.

Appendix D Required Operator Actions Form ES-D-2 Time Position Applicants Actions or Behavior

22. CHECK if ECCS flow should be terminated:

a. RCS subcoollng based on core exit T/Cs greater than 40F.

b Secondary heat sink:

Narrow range level in at least one Intact SIG greater than 10% [25% ADV]

ATC OR

Total feed flow to SIGs greater than 440 gpm AVAILABLE

c. RCS pressure STABLE or RISING.

ci. Pressurizer level greater than 10% [20% ADVI.

23. STOP the following ECCS pumps:

a. STOP SI pumps and PLACE in A-AUTO.

ATC b. CHECK offsite power supplying shutdown boards.

c. STOP all BUT one CCP and PlACE in A-AUTO.

Lppendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 6,7 Page 61 of 68 Event

Description:

2 SGTR and #2 SG MDAFW Level Control Valve Fails Open Time Position Applicants Actions or Behavior 2& ISOLATE CCPIT:

a CLOSE inlet isolation valves ATC FCV-63-39 and FCV-63-40 lx CLOSE outlet isolation ialves FCV-63 26 and FCV-63-25.

ATC Places HS-63-39A and 40A CCPIT inlet isolation valves to CLOSE ATC Places HS-63-25A and 26A CCPIT outlet isolation valves to cLOSE Scenario may be terminated when the CCPIT is isolated or earlier, at discretion of Lead Examiner

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 2 Event# ES-0.5 Page 62 of 68 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior Equipment Verifications, ES-O.5 Evaluator Note: #1 SG MDAFW Level Control Valve Fails Open; the crew will need to decide how control

1 SG to prevent overfill.

BOP 1. VERIFY DIGs RUNNING.

BOP 2. VERIFY DIG ERSW supp1 valves OPEN.

BOP , VERiFY at least four ERCW pumps RUNNING.

4. VERIFY CCS pumps RUNNING

Pump IA-A (2A-A)

BOP

Pump 18-B (2B-B)

Pumpc-S.

BOP 5. VERIFY EGTS fans RUNNING.

BOP 6. VERIFY generator breakers OPEN.

7. NOTIFY at least two AUOS to report BOP to MCR to be available for local actions,

8. VERIFY AFW pumps RUNNING:

a. MDAFWpumps BOP

b. TDAFW pump.

NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control S1G levels, to establish 110w due to failure, or to isolate a faulted S1G.

Time Position Applicants Actions or Behavior

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 201 2-302 Scenario # 2 Event # ES-0.5 Page 63 of 68 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior 9 CHECK AFW valve alignment:

a. VERIFY MD AFW LGVs in AUTO.

BOP Ii VERIFY TD AFW LcVs OPEN

c. VERiFY MD AFW pump recirculation valves FCV-3-400 and FcV-3-401 CLOSED.

10 VERIFY MEW IsoLation:

a CHECK MEW pumps TRIPPEI1 Ii ENSURE the following:

BOP

MEW regulating valves CLOSED

MEW regulating bypass valve controllers in MANUAL with output ZERO

MFW isolation valves CLOSED..

11. MONITOR ECCS operation:

a. VERIFY ECCS pumps RUNNING:

CCPs RHR pumps BOP

SI pumps

b. VERIFY CCP flow through CCPIT.

c. CHECK RCS pressure less than 1500 psig d VERIFY SI pump flow.

Lppendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # ES-0.5 Page 64 of 68 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior

e. CHECKRCSpressure e. GOTOStepi2.

less than 300 psig.

1. VERIFY RHR pump flow.

12. VERIFY ESF systems ALIGNED:

a. Phase A ACTUATED:

PHASE A TRAIN A alarm LIT

[M-6C, 851.

a PHASE A TRAIN B alarm UT (M-6C, 861.

b. Cntmt Vent Isolation ACTUATED:

CNTMT VENT ISOLATION TRAIN A alarm LIT [M-6C, CS].

a CNTMT VENT ISOLATION TRAIN 8 alarm UT (M-6C, C6].

c.. Status monitor panels:

BOP

6C DARK

GD DARK

GE LIT OUTSIDE outlined area

61-I DARK

6JLIT ci. Train A status panel 6K:

CNTMT VENT GREEN

PHASE A GREEN

e. TraIn B status panel 6L:

CNTMT VENT GREEN

PHASE A GREEN

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-302 Scenario # 2 Event # ES-0.5 Page 65 of 68 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior

13. MONITOR for containment spray and Phase B actuation:

a. CHECK for any of the following:

Phase B ACTUATED OR

Containment pressure greater than 2.8 psig.

b. VERIFY containment spray INITIATED:

1) Containment spray pumps RUNNING.

2> Containment spray header isolation valves FCV-72-39 and FCV-72-2 OPEN.

3) Containment spray recirculation valves to RWST FCV-72-34 BOP and FCV-72-13 CLOSED.

4) Containment spray header flow greater than 4750 gpm per train.

5) Panel 6E LIT.

c. VERiFY Phase B ACTUATED:

PHASE B TRAIN A alarm LIT

[M-6C, A5].

PHASE B TRAIN B alarm LIT

[M-6C, A6].

d. ENSURE RCPs STOPPED.

e. VERIFY Phase B valves CLOSED:

Panel 6K PHASE B GREEN.

Panel 6L PHASE B GREEN.

f. WHEN 10 minutes have elapsed.

THEN ENSURE containment air return fans RUNNING.

I Appendix D Required Operator Actions Form ES-D-2 I OpTestNo.: NRC2O12-302 Scenario# 2 Event# ES-O.5 Page 66 of 68 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior NOTE The continuous action in Step 14 remains applicable if containment pressure rises above 1.5 psig after ES-O.5 is compieted.

14. MONITOR if containment vacuum relief isolation valves should be closed:

BOP a. CHECK containment pressure a. GO TO Step 15.

greater than 1.5 psig.

15. CHECK secondary and containment rad monitors USING tile following:

BOP

Appendix A, Secondary Rad Monitors

Appendix B, Containment Rad Monitors.

APPENDIX A SECONDARY RAD MONITORS

1. lFSloccurreclonlJnjji.

THEN CHECK following rad monitors including available trends pror to isolation:

Condenser exhaust recorder 1-RR--90-119 BOP

SIG blowdown recorder 1-RR-90-120

Unit I Main steam line rad monitors [1-M-30]

PostAccident raci recorder 1-RR-90-268B points 3 (blue), 4 (violet), 5 (black), and 6 (turquoise).

[i-M31 (back of 1-M-30)J

3. NOTIFY Unit Supervisor whether secondary radiation is NORMAL or HIGH.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-302 Scenario # 2 Event# ES-0.5 Page 67 of 68 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior APPENDIX B CONTAINMENT RAD MONITORS t lFSloccurredonlJnjtl.

THEN CHECK following rad monitors:

BOP

Upper containment postaccident ract monitors 1-RM-90-271A and 1-RM-90-272A NORMAL [1-M-301

Lower containment post-accident raci monitors i-RM-90-273A and 1-RM-90.-274A NORMAL 114v1-301

Containment rad recorders i-RR-90-112 and i-RR-90-106 NORMAL 1041-12] (prior to isolation).

16 WHEN directed by E-O, THEN BOP PERFORM Appendix D, Hydrogen Mitigation Actions 17 CHECK pocket sump pumps STOPPED:

[M-15, upper left corner]

HS-77-410, Rx Bldg Aux floor and BOP Equipment Drain Sump pump A

HS-77-41 1, Rx Bldg Aux Floor and Equipment Drain Sump pump8

18. DISPATCH personnel to perform BOP EA-0-1, Equipment Checks Following ESFActuation

19. ENSURE plant announcement has been BOP made regarding Reactor Trip and Si.

20. PERFORM Appendix E, Spent Fuel BOP Cooling Actions, as time permit&

END OF TEXT

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC 2012-302 Scenario # 2 Event # Page 68 of 68 Event

Description:

Critical Task Critical Tasks: Critical Task Statement

1. Depressurize RCS to meet SI termination criteria prior to the ruptured SG dome level exceeding 100%.

2. Isolate steam flow from and feed flow to ruptured SG prior to initiation of RCS Cooldown to target temperature.

Establish cooldown and maintain RCS temperature so that transition from E3 does not

3. occur because the RCS temperature causes an extreme (red-path) or a severe (orange path) challenge to the subcriticality and/or the integrity CSF

Appendix D Scenario Outline Attachment I Facility: Sequoyah Scenario No.: 3 Op Test No.: 2012-301 Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 2, 2% Reactor Power, A Main Feedwater Pump I/S Turnover: Continue Plant Startup. Currently at 0-GO-4, Section 5.2 Step 3.

Target CTs: Manually initiate a Phase B isolation prior to completing ES-0.5 step 13.

Manually stop one Containment Spray Pump prior to completing ES-i .3 step 2 Manually align CCP and SI pump flowpath for sump Recirc prior to completing ES-i.3 step 12 Event No. Malf. No. Event Type* Event Description

1. N/A R-ATC Continue Power Increase from 2%.

NSRO l.a N/A N-BOP Place feed Reg Valves in AUTO using 0-GO-4.Section 5.1 Step 4

2. MSO9 C-BOP/SRO Gland Seal Steam Regulator, l-PCV-47-183 fails closed, challenging condenser vacuum. The BOP will manually control gland seal pressure bypass FCV-47-l8i using the ARP.

3. CV25A I-ATCISRO CVCS Letdown Pressure instrument PT-62-81 fails low. The ATC will manually control letdown pressure using the ARP. The crew may decide to isolate Letdown and place Excess Letdown in service.

4. RXO7A I-ATC/SRO The Pressurizer Pressure instrument PT 68-340 will fail high resulting in pressurizer spray valves opening. The ATC will manually close the spray valves TS SRO and stop the RCS depressurization using immediate operator actions and AOP 1.04. The SRO will address Tech Spec and determine the instrument is INOPERABLE.

5. MS12D C-BOPISRO The #4 S/G PORV fails open, the BOP will manually close the PORV using AOP S.05

6. THOI B TS-SRO A Small RCS Leak (21 gpm) in Loop 2 Hot leg will develop. The crew will respond using AOP-R.05. The SRO will address Tech Specs and determine that RCS Leakage is in excess of LCO requirements.

7. THO1 B M-All The RCS leak increases to a LOCA, the crew will initiate a Rx trip and Safety

. Injection and transitions to E-0. During the performance of E-0, the Hi-Hi re-insert containment pressure logic to initiate Phase B containment isolation fails. The RPO7 C-ATC ATC will manually initiate a Phase B using prudent operator actions.

8. RHR14 M-All The crew will transition from E-0 to E-l and ultimately ES-i .3 to align RHR to the Containment Sump.

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

Appendix D Scenario Outline 2012-301 Scenario 3 Summary EVENT I The crew will assume the shift, place the feed reg valves in AUTO using 0-GO-4.Section 5.1 Step 4 and continue the power increase.

EVENT 2-When directed by the lead examiner, Gland Seal Steam Regulator, 1-PCV-47-183 fails closed, challenging condenser vacuum. The BOP will manually control gland seal pressure bypass FCV-47-181 using the ARP.

EVENT 3 When directed by the lead examiner, CVCS Letdown Pressure instrument PT-62-81 fails low.

The ATC will manually control letdown pressure using the ARP. The crew may decide to isolate Letdown and place Excess Letdown in service.

EVENT 4 When directed by the lead examiner, the Pressurizer Pressure instrument PT 68-340 will fail high resulting in pressurizer spray valves opening. The ATC will take immediate operator action (lOA) to manually close the spray valves and stop the RCS depressurization. The crew will respond using AOP 1.04, Pressurizer Instrument Malfunction, Section 2.3 to implement mitigating actions, select another controlling channel, and return spray control to automatic. The SRO will enter LCO 3.2.5.b; 3.3.1.1.

Functional Units 7, 9, 10, Action 6; 3.3.2.1 Functional Units 1 .d- Action 17, 8.a- Actions 22a EVENT 5 When directed by the lead examiner, the #4 S/G PORV fails open, the BOP will manually close the PORV using AOP-S.05.

EVENT 6 When directed by the lead examiner, a small unisolable RCS leak (-20-25 gpm) will occur. The crew will respond toARPs i-AR-M5C B-i, B-3, 1-AR-M6-E S-6 and 0-AR-M12AA-1, A-4, which will direct them to implement AOP-R.05, RCS Leak and Leak Source Identification to attempt actions to isolate leak.

The SRO will enter LCO 3.4.6.2.a or b action a.

EVENT 7 When directed by the lead examiner, the RCS leak will be increased to a Large Break LOCA requiring Reactor Trip and Safety Injection. The crew will implement E-0, Reactor Trip/SI. During the performance of E-0, the Hi-Hi containment pressure logic to initiate Phase B containment isolation fails.

The ATC will manually initiate a Phase B using prudent operator actions. During the transition to E-1, status tree monitoring will occur. The crew will identify red path condition and implement FR-Z.1 for High Containment Pressure and potentially FR-P.1 for Pressurized Thermal Shock RED Path.

EVENT 8 During performance of the EOPs, the RWST b-b level will occur requiring the crew to transition from E-0 to E-1 and ultimately ES-i .3 to align RHR to the Containment Sump.

The scenario terminates as directed by the Lead Examiner upon completion of FR-Z.1 and FR-P-I if applicable, when ECCS is aligned for RHR sump recirculation using one train of RHR.

EOPfbow: E-0, E-I, FR-Z.1, FR-P.1, ES-i.3

Appendix D Reouired ODerator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 3 Event# 1 Page 1 of 56 Event

Description:

Raise plant power to 13-15% RTP Time Position 1 Applicants Actions or Behavior Booth Operator: No action required for event I Indications Available: None Applicable Examiner Note: The crew will shift Feed Reg Valves to AUTO using O-GO-4, Section 5.1 Actions To Be Performed Prior To_Raising Reactor Power.

5.1 Actions To Be Perfomed Prior To Raising Reactor Power (continued)

NOTES

1) MEW Bypass valves will be using single element control which means the desired SG level setpoint will be compared to the actual SG level until adequate steam and feedwater flow are available. Single Element to Three Element control transition occurs at 13% RTP (.494E6 L8MIHR steam flow per loop).

2) MEW Reg valves may have a positive deviation if reactor power is in the upper range of the control band (1-4%) in the following step.

[41 PERFORM the following:

[4.1] ENSURE four MFW Bypass Reg valves in AUTO.

[4.2] ENSURE MEW Reg. valves have minimal controller deviation.

BOP 14.3] ENSURE MFW Reg. valves are CLOSED 14.4] PLACE MEW Reg. valves in AUTO.

[4.5] ENSURE MEW valve contjoi mode in 3 Element Enable& (click target located in the center of each screen under the appropriate Loop S control button)

Examiner Note: When the crew has shifted Feed Reg Valves to AUTO inform the crew that all remaining steps in O-GO-4, Section 5.1 are complete and to go to Section 5.2 Reactor Power Ascension To Between 13% And 15% RTP.

Examiner Note: The crew will perform power change lAW O-GO-4, Section 5.2 Reactor Power Ascension To Between 13% And 15% RTP Direct a load increase in accordance with O-GO-4, Reactor Power Ascension To SRO Between 13% And 15% RTP, Section 5.2, and O-SO-62-7 Boron Concentration Control, Section 6.1 or Section 6.2.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 1 Page 2 of 56 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior NOTES

1) Actions effecting reactivity are directed in the following step. O-SO-82-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water). All appropriate verilications and peer checks shall be utilized during performance.

2) Recommended dilution rate is 50 to 75 gallon batches every 12 to 15 minutes for a steady power rise. Rod movement should be limited to 112 step increments approximately every 1 1/2 minutes. Dilution and rod movement rates may be adjusted depending on SG level control stability.

3) Control Rod withdrawal and I or dilution requirements may be significantly impacted by the change in core reactivity due to changing Xenon concentration.

[3] INITIATE a methodical and deliberate reactor power ascent by CREW manual adjustment of the control banks or by diluting the RCS.

Examiner Note: The following Steps are from 0-SO-62-7 Boron Concentration Control, Section 6.2, Dilute CAUTION I When making an RCS dilution of 3000 gallons, it should be done in batches with an RCS boron concentration verification at the halfway point (e.g.. 1500 gallons). Allow at least 15 minutes between batches. [C .5] [C.7]

CAUTION 2 Returning the Boric Acid Blender to service after unplugging, cleaning, or maintenance on the Boric Acid System could introduce debris, sludge, air or chunks of solidified boron into the CCP suction resulting in pump damage. Extreme care must be exercised to properly flush the Boric Acid Blender system following an outage. [C.2]

NOTEI If an excessive amount of dilution is required (plant startup), the pressurizer heaters should be energized to cause pressurizer spray operation for equalizing boron ci ncentration in RCS and pressurizer.

NOTE 2 Dilute mode will be used anytime a long-term positive reactivity addition is deSired. The operator should use the normal dilute mode whenever conditions permit Examiner Note: Dilutions will be performed based on the Reactor Engineering provided Reactivity Spreadsheet; based on 0-GO-4 Notes, recommended dilution rate is 50 to 75 gallon batches every 12 to 15 minutes for a steady power increase. During subsequent power escalation, large volume dilutions will be divided evenly over each hour as determined by the crew [i.e.: one-third, one-quarter of the volume over each hours period (e.g.: 60 gallons, 4 times per hour for 240 gallons for the first hour)].

ATC [1] ENSURE unit is NOT in a Tech Spec or TRM action that prohibits positive reactivity additions. [C.1]

NOTE: HUT level increase of 1% is equal to 1380 gallons (Tl-28 fig. 34).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 1 Page 3 of 56 Event

Description:

Raise plant power to 13-15% RTP fl Time 1 Position Applicants Actions or Behavior U

ATC [2] ENSURE sufficient capacity available in the HUT selected to receive expected amounts of CVCS letdown: (N!A if not used)

HUT LEVEL INITIALS A

B ATC [3] ENSURE makeup system is aligned for AUTO operation in accordance with Section 5.1.

ATC [4] RECORD the quantity of dilution water required to achieve desired boron concentration using Appendix D. (NIA for minor power changes)

NOTE Due to eyeball interpolation the verified calculation may slightly differ from the initial calculation. The following signoff indicates that any differences in the two results have been discussed and are close enough to be considered validated.

ATC [5] PERFORM Appendix I Independent Verification of Calculation for Amount of Boric Acid or Primary Water. (N/A if App. D was performed by SRO to verify data from Rx Engineering)

(Step not required provided in shift turnover package)

ATC [6] PLAC [HS 2-140 1, Bo cAci Suppl oB n lo Cont S the STOP position.

T 1408 V Makeup tc he SI TC [8] E SURE [H 2- Dl. B c Aci alve to the nd CLOS D Gree light is LIT).

[9] SET [FQ-62-1 421, Batch I rator fort e& uá NOTE Primary Water Flow Controller [FC-62-142] receives its reference signal (70 gpm) from setpoint potentiometer (dial indicator) located on panel M-6. A setpoint of 35% corresponds to a 70 gpm primary water flow rate ATC [1.0 ADJUST LFC-62-1421, Primary Makeu atér Conci er fo e AdSnrwit ATC [12] VERIFY the following;

[a] Inlet to top of VCT [FCV-62-1 281 is OPEN.

[b] Primary Water flow by FFI-62-142A1 OR IFQ-62-1421.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC2O12-302 Scenario# 3 Event# 1 Page 4 of 56 Event

Description:

Raise plant power to 13-15% RTP Time Position 1 Applicants Actions or Behavior NOTE Alternate dilution in small amounts is acceptable on a regular basis, provided no significant changes in seal water temperature or seal leakoff are indicated.

Batches of 5 to 10 gallons may be added through FCV-62-144 on a frequency not to exceed once per 30 minutes. ICS points for No. 1 seal leakoffs and seal water temperatures on the RCPs should be monitored during and after dilution.

ATC [13] IF primary water addition to the bottom of the VCT [FCV-62-1441 is desired, THEN ATC [a] CLOSE [FCV-62-1281 with [HS-62-1281.

ATC [b] OPEN [FCV-62-1441 with [HS-62-1441.

ATC [c] VERIFY Primary Water flow by [Fl-62-142A1 OR [FQ-62-142].

NOTE It may take approximately 15 minutes before any changes to reactivity are indicated on nuclear instrumentation or RCS temperature indication.

ATC [14] MONITOR nuclear instrumentation and reactor coolant temperature to ensure the proper response from dilution.

ATC [15] IF [LI-62-1 291, Volume Control Tank Level, increases to 63 percent, THEN ENSURE [LCV-62-1181, Volume Control Tank Divert Valve OPENS to divert excess water to the Holdup Tanks.

ATC [16] WHEN dilution is complete, THEN ATC [a] :LAGE IH Al ,ric Acid to Blender F ontro! Switch t: the ATC [c] VERIFY no primary water flow on either rFl-62-142A1 OR [FQ-62-141.

ATC [d] ENSURE FFCV-62-1 281 is CLOSED ATC [17] IF power increase in progress and additional dilutions will be required, THEN use this table to re-perform steps [4] through [18] (next page)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # 1 Page 5 of 56 Event

Description:

Raise plant power to 13-15% RTP Unit______________ Date...

6..2 Dilute (Continued)

[17] IF power ascension in progress and additional dilutions will be required, THEN use this table to re-periorm steps [41 throuqh 1181..

STEP jt 2 n d 3 r d

[41 RECORD the quantity of dllution water required to achieve desired boron concentration using Appendix D.

[5] PERFORM Appendix I, IV of Calculation for amount Of BA or PW R( I3

[61 PLACE [HS-62-140A], Boric Acid Supply to Blender Flow Control SWitch to the STOP position. CV 1 CV 1 CV 171 PLACE [62140B], CVCS Makeup Selector Switch to the DILUTE position. 1] [] [1

[8] ENSURE [HS-62140D] Boric Acid Valve to Blender is CLOSED (Green ght UT). 0 0 0

[9] SET [FQ-G2-j4, Batch Integrator for the desired quantity

[10] ADJUST [FC-62-1421, Primary Makeup Water Flow Controller for the desired flow rate..

[11] PLACE [HS-62-140A1 BA Supply to Blender Flow Control Switch to START.. I I I

[12] VERIFY the following:

1a Inlet to top of VCT fFGV-62-l 281 is OPEN. 0 0 0

[b] Primary Water flow by [42442Aj or [FQ-62-1 42]. LI [1 El IaI IF PW addition to top of VCT [FCV-62-1281 is not warranted, but PW addItion to the bottom of the VCT IFCV-62-1441 is desired, THEN La] CLOSE [FCV-62-1283wj1h [HS-62-?] LI 0 LI

[bj OPEN IFCV$Z4441 VJlth [HS2.144]. 0 [1 0 IC] VERIFY Primary Water flow by [FI-62-142A) or [FQ42-4421. LI 0 LI

[14] MONITOR nuclear instrumentation and reactor coolant temperature to ensure the proper response from dilution. U LI LI

[15] iF [L142-1291, VCT level, rises to 63 percent, THEN ENSURE

[LCV421 181,_VCT Divert Valve._OPENS to_divert excess water to the_HUTs. C] El LI

[163 WHEN dilution is complete, ThEN i I t1 PLACE [HS-62-140A1, Boric Acid to Blender Flow Control Switch to STOP w

[b] IF [FCV-62-144] was previousy OPENED, THEN CLOSE [FCV42-1441 with [HS-62-144t LI El U

[c] VERIFY no primary water flow on either [Fl-62-142A1 or tFQ-62-1421. LI El El

[d) ENSURE [FCV42-128] is CLOSED.. LI LI LI

[1 83 iF Step [17] will be repeated, THEN PERFORM the following:

[a] PLACE [HS-62-140B], CVCS Makeup Selector Switch to the AUTO position.. i CV

[I,] PLACE [HS-62-14G], BA to Blender Flow Control Switch to START position. El fc] ENSURE dilution is logged in Unit Narrative Log.. [1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # I Page 6 of 56 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior ATC [19] REALIGN the blender controls for AUTO makeup to the CVCS in accordance with Section 5.1.

ATC [20] ENSURE dilution(s) is logged in Unit Narrative Log.

NOTE Sample may be obtained at normal RCS sample intervals provided the unit is at power and the unit response following the dilution is as expected.

ATC [21] IF RCS boron sample is required, THEN NOTIFY Chem Lab to obtain RCS boron sample.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 1 Page 7 of 56 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or behavior O-SO-85-1, Control Rod Drive System, Section 6.4, Transferring from Manual to Auto Rod Control; &

Section 6.5, Transferring from Auto to Manual Rod Control Examiner Note: As stated in each sections procedural Step I Note I, the operators will use a laminated copy of Sections 6.4 & 6.5 available on the book desk under the glass at I M-4. It has been verified as current, in-effect revision routinely to assure currency.

NOTES

1) A laminated copy of this section can be maintained in the Unit Control Room for repetitive use for routine rod manipulations.

2) Defeating or restoring TavglDefta T or NIS channel may cause step change in input to rod control. A delay of at least 3 minutes prkr to returning rod control to automatic will allow lead/lag signal to decay oft

3) This Section may be N/A if Rod Control is being returned to AUTO in response to a transient (runback) condition.

ATC [1] ENSURE turbine power is greater than 15 percent.

ATC [2] ENSURE Window 31 (E-3), LOW TURB IMPULSE PRESS ROD WITHDRAWAL BLOCKED C-5, Permissive light on panel [XA-55-4A] is NOT LIT.

ATC [3] ENSURE less than 1 degree Tavg/Tref mismatch.

ATC [4] PLACE [HS-85-5110], Rod Control Mode Selector in the AUTO position.

ATC [5] VERIFY Rod Speed Indicator [SI-41 2], indicates 8 Steps/minute.

End of Section 6.4

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 1 Page 8 of 56 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or behavior Section &5, Transferring from Auto to Manual Rod Control NOTES

1) A laminated copy of this section can be maintained in the Unit Control Room for repetitive use for routine rod manipulations

2) Manual rod withdrawal is inhibited by any of the following signals:

A C-i, High Flux Intermediate Range Monitor B. C-2, High Flux Power Range Monitor C. C-3, Overtemperature Delta-T ft -4, Overpower Delta-T ATC [1] PLACE [HS-85-5110], Rod Control Mode Selector in the MANUAL position.

ATC [2] VERIFY Rod Speed Indicator [SI-412], indicates 48 Steps/minute.

ATC [3] IF control rod movement is required, THEN ADJUST position using [HS85-511 1], Rod Control Switch.

ATC [4] IF it is desired to leave [HS-85-5110], Rod Control Mode Selector in Manual for an extended period of time, THEN PLACE this Section in the Active Procedures Book.

ATC [5] WHEN it is desired to place [HS-85-51 10], Rod Control Mode Selector to Automatic, THEN GO TO Section 6.4.

End of Section &5

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 1 Page 9 of 56 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior O-GO-4, Section 5.2 Reactor Power Ascension To Between 13% And 15% RTP Examiner Note: Crew will coordinate control rod withdrawal and dilutions based on the Reactor Engineering provided Reactivity Spreadsheet and would coordinate rod withdrawal and dilutions observing the guidance the Step 3 NOTES above.

MODE I Examiner Note: Mode change call is made using Loop AT indications on the MCB and ICS, not Nis; NIs may be referred to during the MODE change determination Refer to O-G04 Section 3.1, Precaution C, specifically bullets 2 & 3 (below):

C During startup 7 NIS power range indication may be reading significantly higher than true power until calibration adjustments are made. The following should be used to determine the most accurate indication for comparison with NIS:

When reactor power is less than or equal to 15%, use average loop AT (U0485)

When reador power is greater than 15%, use LEFM core thermal power indication (U21 18) If LEFM is NOT available, then continue using average loop AT up to 40%. (UI 118 will be used above 40% with LEFM unavailable).

[4] WHEN reactor power is above 5%,

ATC THEN LOG Mode 1 entry in the Unit Narrative Log.

ATC would be monitoring the mode change; any crew member may make the initial identification however the SRO should announce transition to MODE I based on Loop SRO AT indication. Normally, both MCB and ICS indications are reviewed for MODE transition verification.

Crew member replaces the MODE 2 sign with MODE I sign on 1-M-4 under the clock.

v- sn*& *ttb* tt4.b

[5j MAINTAIN the SG levels on program by periodically adjusting BOP I the MFW Bypass controller level setpoints using Appendix B and 1, 2-SO-98-1, Distributed Control System (DCS).

Examiner Note: According to turnover information, the crew will not prepare for nor perform MT roll; Step 6 is N/A for this exam.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # 1 Page 10 of 56 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior

[6] IF Turbine Roll in parallel with power increase is desired, N/A THEN PERFORM Section 5.3 in parallel with the remainder of this section.

[7] IF the intermediate range rod stop setpoint is reached before P-1O energizes, ATC THEN

[7.1] STOP the power escalation.

[7.2] CONTACT Reactor Engineering to evaluate power_range calibration. [C.3]

When the crew has sufficiently raised power the Lead examiner may proceed to Event 2.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 1 Page 11 of 56 Event

Description:

Raise plant power to 13-15% RTP Examiner note: The following 5 pages are the guidance for maintaining SIG levels using the DCS (Digital Feed Control).

6,1 Changing MEW Bypass Reg Valve Controller Setpoint With Hand Controller Using the JOG Method NOTES

1) With the MFW Bypass Reg Valve controller in auto, SG level setpoints are digitally limited to between 30 and 50%. This action prevents an inadvertent setpoint insertion by the operator from causing too much of a level swing.

2) MFW Bypass Reg Valve controller setpoint can NOT be changed when the Turbine Impulse program is in control. Turbine Impulse program will take control above -27%

during a power rise and reset at less than -23% for a power reduction

3) SG setpoints can be changed from either the DOS Operator Display monitor or the hand controller station

4) Two handed operation will be required to change the SG controller setpoint, when using the hand controller.

5) Setpoint push button will change from gray to red on the Hand Controller and the DOS Operator Display monitor

[1] PRESS and HOLD SETPOINT push button for applicable Bypass Reg Valve (N/A valves not operated):

SIG UNID INITIALS I 1L1C335 2 1-LIC-3-48 3 i-L1C-3-90 4 1LlC-3-103

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 1 Page 12 of 56 Event

Description:

Raise plant power to 13-15% RTP NOTE The following method (JOG method) Will cause the setpoint to change in 0.5% ncrernents each time the button is pressed. The push buttons are momentary contact closure type, so continuously holding the push button down will NOT change the setpoint. The push button will have to be released and then pressed again to change the setpoint.

[2] PRESS either the raise () or the rower () push buth ns to obtain the desired setpoint (N!A valves not operated):

SIG UNID INITIALS 1: 1LIC335 2 1-LIC-3-48 3 1LlC-3-90 4 1-LIC-3-103 13] RELEASE the SETPOINT push button. (N1A valves not operated).

SIG UNID INITIALS I 1-UC-3-35 2 1-LIC-3-48 3 I-LIC-3-S0 4 I-LIC-3-103 14] REPEAT Steps $i[I]-6.i[3] as necessary to maintain 810 level in desired range.

End of Section

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 1 Page 13 of 56 Event

Description:

Raise plant power to 13-15% RTP 8.2 Changing MFW Bypass Reg Valve Controller Setpoint With OCS Operator Display Monitor NOTES

1) With the MEW Bypass Reg Valve controller in auto, SG level setpoints are digitally limited to between 30 and 50%. This action prevents an inadvertent setpoint insertion by the operator from causing too much of a level swing.

2) MFW Bypass Reg Valve controller setpoint can NOT be changed when the Turbine Impulse program is in control. Turbine Impulse program will take control above 27%

during a power rise and reset at less than P23% for a power reduction.

3) SG setpoints can be changed from either the DCS Operator Display monitor or the hand controller station.

4) Setpoint push button will change from gray to red on the Hand Controller and the DCS Operator Display monitor.

[1] SELECT the appropriate feedwater controller display screen from either DCS Operator Display monitors (N/A valves not operated).

LOOP UNID INITIALS 1 1 -LIC-3-35 2 1 -LIC-3-48 3 1 -LIC-3-90 4 1-LIC-3-103

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # 1 Page 14 of 56 Event

Description:

Raise plant power to 13-15% RTP 6.2 Changing MFW Bypass Reg Valve Controller Setpoint With DCS Operator Display Monitor (continued)

[2] SELECT the SETPOINT push button for applicable Bypass Reg Valve (N/A others).

LOOP UNID 1 1-LIC-3-35 2 1-LIC-3-48 3 1-LIC-3-90 4 1-LIC-3-103 NOTE Using the JOG method will cause the setpoint to change in O.% increments each time the button is pressed. The push buttons are momentary contact closure type, so continuously holding the push button down will NOT change the setpoint. The push button will have to be released and then pressed again to change the setpoint.

[3] IF using the JOG method (preferred),THEN SELECT either the raise (t) or the lower (1) push buttons to obtain the desired setpoint. 0 NOTES

1) The RAMP method of changing Bypass Reg Valve setpoints is NOT preferred. This is due to the large rate of change in valve position.

2) Using the RAMP push button along with the raise (LE) or the lower (11) push buttons will cause the setpoint to change at a rate of 1.67% per second. A change of O%1OO% would take approximately 1 minute.

[4] IF using the RAMP method, THEN SELECT the raise (t>t) or the lower (i1) push button to obtain the desired setpoint. 0

[5] WHEN the desired setpoint is obtained, THEN CONFIRM SETPOINT is correctly displayed on the screen. 0

[6] SELECT the SETPOINT push button.

[7] CONFIRM SETPOINT push button changes from red to gray. 0 End of Section

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: -- NRC 2012-302 Scenario # 3 Event# 2 Page 15 of 56 Event

Description:

Gland Seal Steam Regulator, 1-PCV-47-183 fails closed Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 2 Indications available:

. Annunciator XA-55-2A Window A-5 PIS-47-196 TURBINE SEAL STEAM PRESS. ABNORMAL

. Indicator 1-Pl-47-189 indicates 12 psig

. Indicator 1-PI-47-187 indicates 0 psig

. Main Condenser Vacuum 0.5 to 0.8 psig PS-47-196B TURBINE SEAL STEAM PRESS. ABNORMAL

[11 CHECK fI-PI-47-1 871 n 1-M2 to veiif, header pressure

( 125 psig)

[2] (F header pressure low, THEN

[a] BLIMP OPEN 11 .FCV47-i81i steam seal bypass to restore header pressure. (1 -P1-47-189 19 psig)

[hi PERFORM 1-SO-29, Codetiser Vacuum And Tu,tAne Steam Seal System Operation, to complete 1ypass of 1-PCV-47-183.

[3] IF header piesswe is high due to 1-PCV-47.-183 failure, THEN

[a] THROITLE i1-FCV47-1801 locaByto restore header pressure to approximately 125 psig.

[bJ IF 1-FCV-47-1&) is NOT responsive, ThEN locally THROITLE [1-Vt.V47-1G111 PCV manual isdation to restore header piessureto approximately 125 psig.

[C] WHEN header pressure controlled, ThEN Bypass 1-PCV-47-183 US4G 1-SO.2-9 Condenser Vacuum And Turbine Steam Seal System Operation.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

BOP Responds to alarm using ARP 1-AR-M2A, A5 Places HS-47-181A to OPEN as required to raise pressure on P1-47-187 and BOP clear alarm M2A, A5

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event# 2 Page 16 of 56 Event

Description:

Gland Seal Steam Regulator, 1-PCV-47-183 fails closed Time Position Applicants Actions or Behavior

[4] IF Header pressure is high due to failore of 1-FCV-47-193, ThEN BYPASS 1-FCV-47-193 h accordance with 1-SO-2-9, Co,denser Vacuum aixt Tuthine Steam Seal System qoeration.

151 CHECK operation of PCV-47-183 HP Steam SeaL 16] CHECK plant cotnputer to detemiine which seal has abnornal pressure.

BOP [71 DiSPATCH operator to detemine steam seal supply pressure to each seal (on local indicator).

181 ADJUST steam seal supply pressure to I .3 psi9 using the manual bypass valve located below the grating on the turbine skirt for the applicable steam seal USJG 1-SO.2-9 Condenser Vacuum Md TurNne Steam Seal System Operation.

191 MONITOR condenser vacuum Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event when Gland Seal Steam has been restored.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 3 Page 17 of 56 Event

Description:

CVCS Letdown Pressure instrument PT-62-81 fails low Time Position I Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 3 CVCS Letdown Pressure instrument PT-62-81 fails low.

Indications available:

Annunciator XA-55-6C Window A-4

Annunciator XA-55-6C Window C-4 Indicator 1-FI-62-82 indicates O gpm [M-6]

Indicator 1-PI-62-81 indicates pressure lowers to 0 psig [M-6]

TS-62-75

[.0W PRESSURE LETDOWN RELIEF TEMP HIGH (1] MONITOR letdT1: press&e on 1l-Pl62-6l.

[2] F ii -PCV-62-811 is Closed, ThEN TAKE manual control of fl-PCV-62-811 and RESTORE normal down sow.

(3] MONITOR low press letdown relief tallppe temp on Ii-Th62-751.

[4] MONITOR VCT and PRT levels.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

ATC Responds to alarm using ARP 1-AR-M6C, C4 Examiner Note: If normal letdown flowpath remains in serve, PCV-62-81 will remain in manual control for the remainder of the scenario; and, the ATC is expected to manually control letdown pressure.

Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when charging flow is controlled.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 4 Page 18 of 56 Event

Description:

Pressurizer Pressure Controlling Channel Fails High Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 3 Controlling Pzr Pressure Transmitter PT 68-340 Fails High I ndicationslAlarms Annunciator:

1-M-5

1-XA-55-5A Window B-3, PS-68-340F1G PRESSURIZER PRESS ABOVE REF SET POINT 1-M-6

1-XA-55-6A Window C-5, PS-68-340A PRESSURIZER HIGH PRESSURE Indications 1-M-5

1-PI-68-334, 323, 322 RCS PZR PRESS indicators decreasing Significant Resultant Alarmsllndications:

1-M-4

1-XI-68-340B & 340D RED indicating lights illuminated indicating Pzr Spray Valves open PS-68-340F1G PRESSURIZER PRESS ABOVE REF SET POINT

[1] CHECK pressurtzer pressure.

[2] IF channel failed, THEN GO TO AOP-104, Pressurizer InsüumentMaifunctiot

[3] IF pressurizer pressure h, THEN PERFORM the flo4nq:

[a] ENSURE pressurizer heaters OFF.

[hi ENSURE pressurizer spray valves OPEN.

[C] ADJUST plant paraneters as necessy

[4] EVALUATE TS 3.31,3.32,3.3,3.5.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

ATC Responds to alarm using ARP 1-AR-M5A, B3

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 4 Page 19 of 56 Event

Description:

Pressurizer Pressure Controlling Channel Fails High Time Position Applicants Actions or Behavior I Places PIC-68-340A, Master Pressure Controller in MANUAL and lowers output.

PZR Spray controllers PIC-68-340D (Loop 1) and/or PIC-68-340B I { (Loop 2) and lowers output.

j Using immediate operator actions (lOAs)

Oressunzer I NOTE: If spray valve is open clue to pressure instrument failure, then Section 2.3 is the appropriate entry point t DIAGNOSE the failure:

GOTO IF...

SECTION PAGE Pressurizer Pressure Instrument OR Controller Malfunction 2.3 11 NOTE Step 1 is an IMMEDIATE ACTION.

1. CHECK normal spray valves CLOSED. IF RCS pressure is less than 2260 psig.

THEN CLOSE affected spray valve(s)

USING the following:

. PIC-68-340A, Master Pressure Controller.

SRO OR

. PZR Spray controllers PIC-68-3400 (Loop 1) ancVor PIC-68-3408 (Loop 2).

MONITOR pressurizer pressure stable or trending to desired pressure.

NOTE: Appendix L shows layout of PZR pressure control for operator reference.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # 4 Page 20 of 56 Event

Description:

Pressurizer Pressure Controlling Channel Fails High Time Position Applicants Actions or Behavior

3. CHECK PI-68-340A NORMAL PERFORM the following:

a. ENSURE PRESS CONTROL SELECTOR switch XS-68-3400 in PT-68-334 & 323.

b. ENSURE LOOP TAVG T RECISEL selector switch XS-68-28 ATC tn LOOP 2,3, or 4.

c. ENSURE PRESS REC CHANNEL SELECTOR XS-8-3408 in PT-88-334, PT-68-323. or PT-68-322

i. GO TO Caution prior to Step 8.

Places LOOP TAVG T RE/SEL selector switch XS-68-2B in LOOP 2 ATC CAUTION RCS pressure changes and changes in RCS boron concentration (due to differences between pzr and RCS boron) may cause small change in core reactivity.

8. MONITOR reactor power:

a. CHECK reactor in Mode I or 2..

ATC b MONITOR core thermal power for unexpected changes.

9 EVALUATE the fbllong Tech Specs for applicability:

a 32.5 DNB Parameters a 3.311 (3.31). Reactor Trip System SRO Instmrnentatkn a 3.321 (3.32). ESF Actuation System Instrumentation a 3.3.3.5 Remote Shutdown Instrumentation

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 4 Page 21 of 56 Event

Description:

Pressurizer Pressure Controlling Channel Fails High Time I Position Applicants Actions or Behavior 3.2.5 The following ONS related pzameters ha be maintained within the limits showm on Tthle 52-1:

a. Reactor Coolant System (RCS)T

b. Pressurizer Pressure

c. RCS Total flow Rate APPLlCABLlTY: MODE I ACTION:

With any rJtheaboe parameters exceeding its Limit, restore the paramekerto within its limit within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or reduce THERMAL POWER to less than 5% of RATED THERMAL DOWER welvn the next SRO 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

LIMITS l4

_oops in PARAMETER Ooeraon Reactor Coolant. System T 5S3 Pressurizer Pressure 2220 psi&

Reactor CooLant System Fixe 12-i Total Flow LIMITING CONDITION FOR OPERATION 3.3.tI As a nwiimwn. the reactor top system insumentatiou channels and rterlocks of Taitle 13-1 shall be OPERABLE.

APPUCABIIJTY; As shown in Tale 13-1.

ACIION As shown nTbIe 3.3-1.

. Pressurizer Pressure-Low 4 2 3 1,2 8 SRO

10. Pressurizer PressureH4 4 2 S 1,2 8 ACTION 8- Wtt, the rna,,l erof OPERABLE channels one loss than the Tot Nurnbor of Channels. STARTUP andfor ROWER OPERATION may proceed pxovloed the foowtog conditions e satis5ed:

a. The inopcab4e channel ts placed to the tripped condition within S hours.

I,. The Muwnum Channels C ERABLE requirement is met hOWEJ thS nO 5&hte ChaWIel may be bypassed tor to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for survedlance tesiTn of c4her channels per Specillcation 43.1.1t

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 3 Event# 4 Page 22 of 56 Event

Description:

Pressurizer Pressure Controlling Channel Fails High Time Position Applicants Actions or Behavior LIMNG CONDITION FOR OPERATiON 3.32.1 The Engineered Safety Feabxre Actuation System (ESFAS) menlation channels and interlocks shown in ThbIe 3.3-3 shall be OPERABLE with their trip selpoirrts set consistent with the values shown in the Nominal Trip Setpoint column of Table 3.3-4.

PUCABflJTY As shown in Table 33-ACTION:

a. With an ESFAS instrumentation channe4 or inteilcck trip setpoint less conservative th the value shown in the vableVabes column of Table 3.34. lecte the hannel iscperable and apply the apphoable ACTION requirement of Table &3-3 until the channel is restored to OPERABLE st3tus with the trip sepoint adjusted consistent wtkh The Nominal Trip Setpoint value.

b. With an ESFAS strumentation channel or interlock inoperable, lake the ACTION shown in Table 3.3-3.

SRO

1. SAFETY INJECTION, TURBINE TRfl AND FEEDWATER ISOLATION

4. Pressurizer Pressure- 3 2 2 1.2, 17 Low ACTION 17 - With the number of OPERABLE Channels one less than the Total Number of Channels, STARTUP an&or POWER OPERATION may proceed provided the foflowing conditions e satisfied:

a The inoperable channel is placed in the tripped condition within hours.

b The Mininium Channels OPERABLE requirements is met: howeve the inoperable channel maybe bassed for up to 4 hoss for surveance testing of other channels per Specification 4.I21.t

10. CHECK PZR PRESS and PZR SPRAY WHEN malfunction has been identified controllers in AUTO. AND isolated or corrected, THEN PERFORM the following:

a. ENSURE Master Pzr Pressure ATC Controller PIC-68--340A Output Percent Meter is less than 40%.

Ii. ENSURE PZR PRESS Controller, PZR SPRAY controller, and PZR IITRS in AUTO.

NOTE: If performing AOP in conjunction with AOP-Mi for an Eagle LCP failure, then actions to hard tllp bistables houki be delayed until Eagle system reset is atternpted Actions to hard trip bistables must be completed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months UNLESS affected loop Ls restored to operable status by resetting Eagle racic

Appendix D Reauired Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 4 Page 23 of 56 Event

Description:

Pressurizer Pressure Controlling Channel Fails High Time Position Applicants Actions or Behavior

11. REMOVE faded pressurizer pressure channel from service:

a. CHECK any pressurizer pressure channel INOPERABLE.

b. CHECK OThT setpoint on affected channel NORMAL..

any of the following conditions exists:

CREW

. this procedure was entered due to EagLe 21 malfunction (AOP-[1 1)

OR

Engineering or Maintenance has verified OTAT setpoint is NOT affected by failure, THEN PERFORM applicable appendix:

PZR PRESSURE CHANNEL AFFECThD APPENDIX INSTRUMENT RACK P-68-340 (P455) I I E CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event when Pzr Pressure control is in AUTO and Tech Specs are identified

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 5 Page 24 of 56 Event

Description:

SIG #4 ARV fails Open Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 5 SIG #4 ARV fails Open IndicationslAlarms Annunciator:

1-M-5

. 1-XA-55-5A, A-6, TS-68-2MIN RC LOOPS T AVGIAUCT T AVG DEVN HIGH-LOW

C-6, TS-68-2PIQ REAC COOL LOOPS T REF T AUCT HIGH-LOW 1-M-6

. 1-XA-55-6B, D-7, FS-3-103B STM GEN LOOP 4 STEAMIFEEDWATER FLOW MISMATCH Indications 1-M-4

. 1-FI-3-103A, 103B SG-4 FW INLET FLOW CH-1, CH-2 indicating increasing flow (compared to SGs 1-3)

. 1-FI-1-28A, 28B SG-4 STEAM FLOW CH-1, CH-2 indicating increasing flow (compared to SGs 1-3) 1-M-5

. 1-TR-68-2B RCSITURBINE TEMP recorder shows RCS temperature deviating from reference temperature

. Red light above HS-1-31 ON

[ Time Position Applicants Actions or Behavior TS-68-2MIN RC LOOPS T AVG TS-68-2P10 IAUCT T AVG REAC COOL LOOPS DEVN HIGHJ.OW T REF T AUCT HIGH-LOW OR

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # 5 Page 25 of 56 Event

Description:

S/G #4 ARV fails Open Time Position Applicants Actions or Behavior

[1] CHECK i-XX-55-S, Trip status panel for any bistaNes that may be lit, AND EVALUATE Reactor Trip criteria with SRO by conadscn with redundant instrumentation.

12] IF reactor trips, THEN GO TO E-O, F?eactor Tnp or Safety injection.

[3] IF Tavg channel failed, THEN GO TO AOP-L02, RCS LOOP RTD INSTRUMENT MALFUNCTION.

[4] IF rod control system is malfunctioning, THEN GO TO AOP-C.C1, Rod Control System Malfunctions.

[5] IF a SFIFF mismatch beteeen SIGs is suspected. THEN CHECK the foIlcritng:

a. SIG POIVS CLOSED lx Main Steam lines for leaks.

c. FW rag, valves operating normal for conditions.

d. Feedwater kae leakage.

[6] Wa steam lute or feediater line break or leak is sespected, THEN GO TO AOP-SO5, Steam Line or Feedwater Line &eak4eak Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

ATC Responds to alarm using ARP 1-AR-M5A, A6 May place HS-1 -31, SIG 4 ATM Relief valve to CLOSE based on prudent BOP operations actions.

SRO Transitions to AOP-S.05, Steam Or Feedwater Leak

1. MONITOR personruei safety:

a. IF steam or teedwater lines need to SRO be immediatety isolated to protect personnel, THEN PERFORM the following:

2. MONiTOR steam generator levels BOP STABLE on program.

3. CHECK the following: IF any SIG atmospheric relief valve or steam dump is leaking or failed open, BOP

S/G atmosphenc relief valves CLOSED THEN CLOSE valve(sJ USING MCR switch.

steam dumps CLOSED.

_Lead Examiner may cue next event when Atmospheric Relief Valve is closed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 6 Page 26 of 56 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

Time Position fl Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 5 RCS Loop 2 Hot Leg Leak 21 Gpm.

IndicationslAlarms Indications I-M-5

1-LR-68-339, RCS PZR LEVEL actual level deviating low from program level indication

I-Fl-62-93A, CHARGING HDR FLOW increasing flow I-M-6

I-Ll-62-129, VCT LEVEL decreasing

1-PDIR-30-133, CNTMT ANN increasing trend O-M-12

I-RR-90-106, CNTMT LOWER COMPT RADMON recorder shows increasing trend

I-RR-90-112, CNTMT UPPER COMPT RADMON recorder shows increasing trend

I-Rl-90-106A, CNTMT LOWER COMPT RADMON-PART & GAS increasing counts

1-RM-90-112A, CNTMT UPPER COMPT RADMON-PART increasing counts

I-RM-90-112B, CNTMT UPPER COMPT RADMON-PART increasing counts Significant Resultant AIarmsIl ndications:

Annunciator:

I-M-5

1-XA-55-5A C-5, LS-77-410A REACTOR BLDG AUX FL & EQ DRAIN SUMP HI (

s 1 t one after -12 mm)

O-M-12

O-XA-55-12A A-I, I-RA-90-II2A CNTMT BLDG UP COMPT AIR MON HIGH RAD

A-4, I-RA-90-106A CNTMT BLDG LWR COMPT AIR MON HIGH RAD Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Identifies Pzr below program, Charging flow increasing w/ VCT level ATC decreasing.

BOP Checks rad monitors, determines increasing trend on containment monitors

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 6 Page 27 of 56 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

Time Q Position Applicants Actions or Behavior

1. IF leak results in radiological hazard or safety hazard THEN EVACUATE unnecessary personnel from affected areas.

2. DIAGNOSE the failure:

GOTO IF. SECTION PAGE ANY of the following indications with RCS temperature greater than 375°F:

Pressulizer level dropping unexpectedly

. Charging flow rising unexpectedly with stable pzr level 2.1 4 a VCT level dropping with Aux Bldg or Containment radiation using

High Energy Line Break recorder indicating unexpected rise in temperature a other indications of RCS leak (local or MCR)

IL CONTROL charging flow using one CCP:

ADJUST FCV-62-93 and FCV-62-89 as necessary to maintain pzr level ATC on program.

a MAINTAIN seal injection flow at least 6 gpm to each RCR Examiner Note: Crew may implement RNO at this time to isolate letdown; Crew may return to perform RNO for Trip Rx and initiate SI later when Leak increases.

Examiner Note: Since this is a MONITOR step, the crew may continue in the procedure while developing a Pzr/RCS level trend. If so, steps 3, 4 or 5 could be the decision point and therefore initiate the reactor trip and E-O implementation. If a loss of Pzr level is imminent, the crew may decide to trip the reactor and transition to E-O based on this step.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 6 Page 28 of 56 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

Time I Position Applicants Actions or Behavior 2 MONITOR pressunzer level STABLE IF sufficient time is avaIlable, or RISING. THEN ISOLATE normal and excess letdown:

a. ENSURE FcV-62-72, 73, and 74 CLOSED.

b. CLOSE FCV-62-69 and 70.

c. ENSURE FCV-62-54 and 55 CLOsED.

ATC IF loss of pressurizer level is immment OR low pressure reactor trip (1970 psig) is imminent, THEN PERFORM the following:

a. TRIP the reactor.

b. INiTIATE Safety Injection.

c. GO TO E-O, Reactor Trip or Safety Injection.

3. MONITOR containment pressure IF containment pressure is STABLE or DROPPING. approaching t5 psig, THEN PERFORM the following:

a. ThlPtflereactor.

ATC

b. INITIATE Safety Injection.

c. GO TO E-0, Reactor Trip or Safety injection.

CAUTION If Unit is in Mode 3 with low pressurizer pressure SI NOT blocked.

SI should NOT be manually blocked to prevent safety injection.

4. MONITOR RCS pressure STABLE or RISING.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # 6 Page 29 of 56 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

Time Position Applicants Actions or Behavior Examiner Note: RCS leak will progress into a SBLOCA. As the crew responds using AOP-R.05 Section 2.1, the lowering Pzr level and increased charging flow may result in a challenge to VCT Make-up capability. Subsequently the crew may initiate a reactor trip and enter E-O based on this step.

5. MAINTAIN VCT level greater than 13%

USING automatic or manual makeup.

NOTE 1: Appendix I or J may be used to estimate RCS leak rate.

NOTE 2: if letdown was isolated in Step 2, the leak rate may have exceeded capacity of one CCP in the normal charging alignment (EAL I 2.2P)

& EVALUATE EPIP-1, Emergency Plan Classification Matrix.

SRO L EVALUATE Tech Spec/TRM LCOS USiNG Appendix K, Evaluating Tech Specs and TRM 3.4.82 Reactor Cootant System leakage be limited to:

a. No PRESSURE BOUNDARY LEAKAGE,

b. I GPM UNIDENTIFIED LEAKAGE.

c 150 gacns per day of ocuny-to-seccadafy leakage thmu any ow steam genetcc. and

d. 10 GPM IDENTIFIED LEAKAGE from the Reactor Coolant Stem.

SRO APPHCABI[ITt MODES I23aed4 ACTiON:

a With any PRESSURE BOUNDARY LEAKAGE or with ptimay-to-seconday leakage not Within be in at least HOT STANDBY wiin 8 hoas and in COLD Si-IU1DOWN within the fofowing 30 hows.

b With any Reactor Coolant System leakage greater than anyone of the above rite.

exc1udit PRESSURE BOUNDARY LEAKAGE or pnmary-to-5eoonday leakage.

reduce the leakage rate to within lin within 4 bows orbe in at least HOT STANDBY Within the nestS bows and in COLD SI-IUTOOWN within the fdlowlng 30 bows.

Examiner Note: When the Examinee enters LCO 34.6.2 proceed to Event 7

Appendix D Required Operator Actions Form ES-D-2 Op Test No,: NRC 2012-302 Scenario # 3 Event # 6 Page of 30 56 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

SQN RCS LEAK AND LEAK SOURCE IDENTIFICATION I AOP-R.05 Rev14 Page 1 of I APPENDIX I ESTIMATING RCS LEAK RATE USING CVCS FLOW BALANCE NOTE I This method is recommended when leak requwes rise in charging fb greater than 10 gpm.

Appendix J is more accurate for smaller leak rates.

NOTE 2 This appendix assumes RCS temperature and charging flak are approximately constant.

INII1AL FINAL CHANGE PZR Level [1]

(nlive fcc level decrease)

Time Charging Flow [3]

Letdown Flow [4]

Total RCP SaI Return Flow [5]

Pressurizer Level Conversion Pressurizer level conversion Time Change Pzr Level Rate of Change change factor (P for level nsln)

% X 62ga11% mm = gpm step [Ii above step [2] above [61 Leak Rate Calculation charging Flow Letdown FkYN Sea turn Pzr Level Instrument error RCS Leak Rate of Change correction factor Rate

+ 3gpm = gpm step [31 above step [4] above step [5J step [61 above above Page 730180

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 6 Page 31 of 56 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

SQN RCS LEAK AND LEAK SOURCE IDENTIFICATION Page 1 of I APPENDIX J ESTiMATING RCS LEAK RATE USING VCT AND PZR LEVEL CAUTION This appendix CANNOT be used during VCT makeup, boration, or dilution.

NOTE This appendix assumes RCS temperature is approximately constant VCT LEVEL (%) PZR LEVEL (%) TIME (mm)

INITIAL FINAL CHANGE [1] [2] [3]

(positive for level decrease) (p(itjve for level decrease)

VCT Level Conversion VCT level change conversion Time Change VCT Level factor Rate of Change (positive for level lowering)

% X 2OgaI/% - min gpm step [1] above step 11 above [4]

Pressurizer Level Conversion Pressurizer level conversion Time Change Pzr Lev change factor Rate of Change (positive for level lowering)

% X 62ga1!% ÷ mm = gpm step [2] above step {3] above 1]

Leak Rate Calculation VCT Level Pzr Level RCS Leak Rate Rate of Change Rate of Change

+ gpm step [4] above step [5] above Page 74 of 80

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 5 Event # 7&8 Page 32 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time fl Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 7 Loop #2 LOCA-To Require Rx Trip and Safety Injection.

Indications available:

1-M-4:

1-Xl-94-1011102, Core Exit Temp Margin to Saturation (exo sensors Tm A & B) pressure indications trending to SI actuation pressure value.

1-Ll-68-339A, 335A, 320A, RCS PZR LEVEL indicators trending down (<5%)

1-M-5:

1-Pl-68-334, 1-PI-68-323, 1-PI-68-322, RCS PZR PRESS narrow range indicators trending to Rx TripISI actuation pressure values.

1-PR-68-69, RCS LOOP I HL WIDE RANGE PRESS indicator trending to Rx TripISI actuation pressure value.

1-PR-68-340, RCS PZR PRESS Recorder trending down;

1-PR-68-69, RCS LOOP I HL WIDE RANGE PRESS Recorder trending down;

1-LR-68-339, RCS PZR LEVEL Recorder trending down;

1-FI-68-93A, CHARGING HDR FLOW Indicator indicating 115-1 20 gpm (I CCP at maximum flowrate);

1-M-6:

1-LI-62-129, VCT LEVEL Indicator trending down wI VCT M-U in progress;

1-FI-62-139A, BORIC ACID TO BLENDER Indicator stable at 20-25 gpm;

1-Fl-62-142A, PRIMARY WATER TO BLENDER Indicator stable at -70 gpm;

1-Pl-68-66A, HL Pressure LOOP 3 indicator trending to actuation pressure value.

1-PI-68-62, RCS HL Press WR indicator trending to actuation pressure value.

1-PI-68-69, RCS HL Press WR indicator trending to actuation pressure value.

1-PDI-30-42, 43, 44, 45, CNTMT PRESSURE WIDE RANGE Indicators trending up (1.5 psi-SI Actuation)

Direct Manual Reactor Trip and Safety Injection based on one several S monitor steps in AOP-R.05 fo & her Pres r 1ev tai ent Pr re SRO Enter and Direct performance of E-O. Reactor Trip Or Safety Injection.

Examiner Note: following IOA performance, prior to Steps 1-4 immediate action verification, ATC/BOP surveys MCBs for any expected automatic system response that failed to occur. Upon discovery, they may take manual action(s) to align plant systems as expected for the event in progress. (Ref. EPM-4, Prudent Operator Actions)

Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via ICS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT I STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 33 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time fl Position fl Applicants Actions or Behavior CREW Performs the first four steps of E-O unprompted.

SRO Directs performance of E-O NOTE I Steps I Through 4 are immediate action steps.

NOTE 2 This procedure has a foldout page.

1. VERIFY reactor TRIPPED;

Reactor tiip breakers OPEN

Reactor trip bypass breakers DISCONNECTED or OPEN ATC

Rod bottom lights LIT

Rod position indicators less than or equal to :12 steps.

Neutron flux DROPPING

2. VERIFY turbine TRIPPED:

SOP Turbine stop valves CLOSED.

3. VERIFY at least one 6.9KV shutdown BOP board ENERGIZED on this unit.

4. DETERMINE if SI actuated:

ATC

ECCS pumps RUNNING.

Any SI alarm UT [M-4D].

5. PERFORM ES-O.5, Equipment BOP Verifications WHILE continuing in this procedure.

Continue with the performance of E-0 REACTOR TRIP OR SAFETY SRO/ATC INJECTION BOP Performs ES-0.5, Equipment Verifications go to page 50 for details SRO Addresses foldout page, see next page for details.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 34 of 56 Event

Description:

Large Break LOCNFailure of Phase B to Actuate.

FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

RCS pressure less Than 1250 psig AND at least one CCP or SI pump running OR

Phase B isolation, THEN STOP all RCPs EVENT DIAGNOSTICS

IF any S!G pressure is dropping uncontrolled, THEN PERFORM the following:

a. CLOSE MSIV5 and MSIV bypass valves.

b IF any SIG pressure continues to drop uncontrolled, THEN PERFORM the following:

1) ENSURE SI actuated..

2) IF at least one 510 is intact (S/C pressure controlled or rising),

THEN ISOLATE AFW to faulted SiC(s):

CLOSE AFW level control valves for faulted Sic(s)

IF any AFW valve for faulted S/C CANNOT be CLOSED, THEN PERFORM Appendix E, Isolating AFW to Faulted SIC.

3) ENSURE at least one of the following conditions met

total AFW flow greater than 440 gpm OR

Narrow Range level greater than 10% 25% ADV] in at least one intact 51G.

IF both trains of shutdown boards do-energized, THEN GO TO ECA-CLO, Loss of NI AC Power.

TANK SWITCHOVER SETPOINTS

iF CST level less than 5%, ThEN ALIGN AFW suction to ERCW.

IF RWST level less than 27%, THEN GO TO ES-t3, Transfer to RI-IR Containment Sump

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 5 Event# 7&8 Page 35 of 56 Event

Description:

Large Break LOCNFailure of Phase B to Actuate.

Time Position Applicants Actions or Behavior

6. DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpm.

b. CHECK narrow range level b. MAINTAIN total feed flow greater than 10% [25% ADVI greater than 440 gpm ATC in at least one SIC. UNTIL narrow range level greater than 10% [25% ADV]

in at least one SIG.

c. CONTROL feed flow to maintain narrow range level between 10% [25% ADVI and 50%

in intact or ruptured S/Cs.

7. CHECK if main steam lines should be isolated:

a. CHECK if any of the following a. GO TO Step 8.

condibon.s have occurred:

. Any SIC pressure less than 600 psig ATC OR

. Any SIC pressure dropping UNCONTROLLED OR

. Phase B actuation.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 36 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior

8. CHECK RCP trip criteria:

a. CHECK the following:

. RCS pressure less than 1250 psig ATC AND

. At least one CCP OR SI pump RUNNING.

b. STOP RCPs.

9. MONITOR RCS temperatures: IF temperature less than 547°F and dropping,

. IF any RCP running, THEN THEN PERFORM the following:

CHECK T-avg stable at or trending to between 547°F and 552°F. a. ENSURE steam dumps and atmospheric reliefs CLOSED.

OR

b. IF cooldown continues,

. IF RCPs stopped, THEN THEN CONTROL total feed flow:

CHECK T-cold stable at or trending AT(fliD 1) ENSURE total AFW flow

- t b tw 547°F d552°F . less than or equal to 600 gpm.

2> MAINTAIN total AFW flow greater than 440 gpm UNTIL narrow range level is greater than 10% [25% ADVI in at least one SIG.

c. IF cooldown continues after AFW flow is controlled, THEN CLOSE MSIVs and MSIV bypass valves.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 37 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior

10. CHECK pressurizer PORVs, safeties, and spray valves:

a. Pressurizer PORVs CLoSED.

b. Pressurizer safety valves CLOSED.

ATC c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

11. DETERMINE if S/G secondary pressure boundaries are INTACT:

ATC CHECK all SIG pressures CONTROLLED or R1SING.

CHECK all S/G pressures greater than 140 psig.

12. DETERMINE if S/G tubes are INTACT:

. All SIG narrow range levels CONTROLLED or DROPPING ATC

. Secondary radiation NORMAL USING Appendix A, Secondary Rad Monitors. (App. A performed in ES-0.5).

13 DETERMINE if RCS is INTACT: PERFORM the following:

. Containment pressure NORMAL

a. INATE ES-O.5 Appendix 0,

. Containment sump level NORMAL Hydrogen Mitigation Actions.

ATC

LOWER COMPT TEMP HIGH alarm b MONITOR status trees.

DARK [M-5C, B1j

. Containment radiation NORMAL C. GO TO E-1, Loss of Reactor or USING Appendix 8, Containment Scondary Coolant.

Rad Moritors. (App B performed in ES-U5)

Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via SPDS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT I STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 38 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior When a RED Path for Containment is evident on SPDS, the SRO will transition to FR-Z.1, go to page 46 for details When a RED Path is for PTS evident on SPDS, the SRO will transition to FR-Z. 1, go to page 48 for details E-1, LOSS OF REACTOR OR SECONDARY COOLANT NOTE This procedure has a foldout page.

See next page for details

1. CHECK RCP trip criteria:

a. CHECK the following: a. GO TO Step 2.

. At least one CCP OR SI pump RUNNING ATC AND

RCS pressure less than 1250 psig.

b. STOP RCPs.

ATC Manually places HS 68-8A, 31A, 50A, and 73A RCPs to STOP.

2. CHECK S!G secondary pressure boundaries INTACT:

BOP

S/G pressures CONTROLLED or RISING

S/G pressures greater than 140 psig.

3. MAINTAIN Intact S/G narrow range levels:

a. Greater than 10% [25% ADV].

BOP

b. Between I 0% [25% ADVI and 50%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 39 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

RCS pressure less than 1250 psig AND at least one CCP or SI pump running OR

Phase B isolation.

THEN STOP all RCPs.

SI REINITIATION CRITERIA IF any of the following conditions occurs:

RCS subcooling based on core exit T/Cs less than 40F OR

Pressurizer level CANNOT be maintained greater than 10% 120% ADVI, THEN RAISE ECCS flow by performing one or both of the following as necessary:

ESTABLISH CCPIT flow USING Appendix C

START CCPs or SI pumps manually.

EVENT DIAGNOSTICS

IF both trains of shutdown boards de-energized, THEN GO TO ECA-0.0, Loss of All AC Power.

IF any SJG pressure dropping in an uncontrolled manner or less than 140 psig AND SIG NOT isolated, THEN GO TO E-2, Faulted Steam Generator Isolation.

IF any S/G has level rising in uncontrolled manner or has abnormal radiation, THEN:

a. RAISE ECCS flow by performing one or both of the following as necessary:

ESTABLISH CCPIT flow USING Appendix C

START CCPs or SI pumps manually.

b. GO TO E-3, Steam Generator Tube Rupture.

TANK SWITCHOVER SETPOINTS

IF CST level less than 5%,

THEN ALIGN AFW suction to ERCW.

IF RWST level less than 27%,

THEN GO TO ES-I .3, Transfer to RHR Containment Sump.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event# 7&8 Page 40 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

[ Time Position Applicants Actions or Behavior

4. VERIFY secondary radiation NORMAL:

a. CHECK secondary radiation NORMAL USING Appendix A, Secondary Rad Monitors.

b. NOTIFY Chem Lab to take SIG activity samples.

c. WHEN Chem Lab is ready to sample SIGs.

THEN PERFORM the following:

ATC

1) ENSURE FCV-15-43 Blowdown Flow Control valve CLOSED.

2) ENSURE Phase A RESET.

3) OPEN blowdown isolation valves.

d. NOTIFY RADCON to survey main steam lines and S/G blowdown.

e. WHEN S/G samples completed, THEN CLOSE blowdown isolation valves.

CAUTION Any time a pressurizer PORV opens, there is a possibility that it may stick open.

5. MONITOR pressurizer PORVs and block valves:

a. Power to block valves AVAILABLE, a. DISPATCH personnel to restore power to block valves USING EA-201-1, 480V Board Room Breaker Alignments.

ATC b. Pressurizer PORVs CLOSED. b. IF pressurizer pressure less than 2335 psig, THEN CLOSE pressurizer PORVs.

IF pressurizer PORV CANNOT be closed, THEN CLOSE its block valve.

Arendix D Reciuired ODerator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 41 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior

6. MONITOR SI termination criteria:

ATC a. RCS subcooling based on core exit T/Cs a. GO TO Step 7.

greater than 4OF. IIIIuIIIIIIIIIIIIIIIIIIIII Examiner Note: When alarm M6E-E4 is on the crew will transition to ES-I .3 Transfer To RHR Containment Sump LS-63-50A RWST LVL LO Corrective [I] IF SIS has occurred with RWST level decreasing to 27%, THEN Actions PERFORM ES-1.3, Tran.sferto RHR Containment Surnp, as applicable.

SRQ Transitions to ES-I .3 Transfer To RHR Containment Sump.

CREW 1. SUSPEND FRP imp1ementation Z DETERMINE if containment spray shouki be stopped:

a CHECK any containment spray pump RUNNING.

b. ENSURE the following:

ATC

one Cntmt Spray pump in PULL-TO-LOcK

remaining Cntmt Spray pump RUNNING.

d. MONITOR one cntmt spray pump RUNNING and delivering 11ow

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 42 of 56 Event

Description:

Large Break LOCNFailure of Phase B to Actuate.

Time Position Applicants Actions or Behavior Examiner Note: If Containment pressure is less 2.0 psig than then go to step 2c RNO.

Examiner Note: If Containment pressure is still greater than 2.0 psig, then go to step 2 d

2. DETERMINE if containment spray should be stopped:

c. CHECK containment pressure c. PERFORM the following:

greater than or equal to 20 psg.

1) RESET containmentspray signal.

2) ENSURE both cntmt spray pumps I

STOPPED and PLACE in A-AUTO.

3) CLOSE cntmt spray discharge vaLves FCV-72-39 and FGV-72-2

4) GO TO Step 3 Places both Containment Spray reset pushbuttons 1-HS-72 43 and 1HS-72 42 ontainme S ump han switc ta e s arge v ye handswitches F V-7 -

t 2 DETERMINE if containment spray should be stopped:

ATC d. MONITOR one cntmt spray pump RUNNING and delivering flow.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 43 of 56 Event

Description:

Large Break LOCNFailure of Phase B to Actuate.

Time Position Applicants Actions or Behavior

3. MONITOR RHR automatic sMtct1over

a. CHECK containment sump level greater than 11%.

ATC

b. CHECK containment sump valves FCV-63-72 and FCV-63-73 OPEN.

c. CHECK RHR suction valves FGV-74-3 and FGV-74-21 CWSING.

4. MONITOR RWST supply to ECCS pumps:

ATC

RWST LVL LO-LO alarm DARK

[M-6E, E41.

RWST level greater than: 8%.

5. MONITOR RI-IR pumps RUNNING.

ATC CAUTION Transfer to sump recirculation may cause high radiation in Aux Building.

NOTE Step 6 should be handed off to a Unit Operator.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 44 of 56 Event

Description:

Large Break LOCNFaiIure of Phase B to Actuate.

Time Position Applicants Actions or Behavior

6. PERFORM the following:

a. DISPATCH personnel to restore power to FCV-63-1 USING EA-201 -1, 480 V Board Room Breaker Alignments.

b. OPEN RI-fR heat exchanger outlet valves FCV-70-156 and FCV..7Q-1 53.

BOP

c. VERIFY CCS 110w F1-70-159A and FI-70i 65A greater than 5050 gprn.

d. MONITOR CCS temperature and surge tank level.

7. VERIFY RHR automatic switchover

a. VERIFY containment sump valves FCV-63-72 and FCV-63-73 oPEN.

ATC b ENSURE RWST to RHR suction valves FCV-74-3 and FCV-74-.21 CLOSED.

CAUTION SI pump operation with minifiow isolated and RCS pressure above shutoff head Will result in SI pump damage.

NOTE The following continuous action applies even after this procedure is exited.

8. MONITOR RCS pressure ATC less than 1500 psig.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event# 7&8 Page 45 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior

9. CLOSE S pump miniflow to RWST valves:

ATC

FCV-63-3

FCV-63-4 FCV-63-1 75 Scenario may be terminated when the crew transfers RHR to Containment Sump step 12 or earlier, at discretion of Lead Examiner.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 46 of 56 Event

Description:

Large Break LOCAJFailure of Phase B to Actuate.

Time Position Applicants Actions or Behavior FR-Z.1 Actions NOTE If this procedure has been entered for an orange path and performance of ECA-LI (LOSS of RHR Sump Recirculation) is required, FRZ1 may be performed concurrently with ECA-i .1.

1 MONITOR RWST level ATC/BOP greater than 27%.

2.. VERIFY Phase B valves CLOSED:

ATC/BOP Panel 6K PHASE B GREEN

Panel 6L PHASE B GREEN..

ATC/BOP 3.. ENSURE RCPs STOPPED.

4. DETERMINE if this procedure should be exited:

a. CHECK for faulted SIG: a, GO TO Steps.

ATC/BOP Any S1G pressure DROPPING OR

Any S/G pressure less than 140 psig,

5. VERIFY containment spray operation:

a. IF ECA-1 .1, Loss of RHR Sump Recirculation, is IN EFFECT, ThEN PERFORM the following:

1) OPERATE containment spray as directed by EGAli.

2) GO TO Step 6.

ATC/BOP

b. VERIFY containment spray pumps RUNNING.

c. CHECK RWST level greater than 27%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 47 of 56 Event

Description:

Large Break LOCAIFailure of Phase B to Actuate.

Time Position ApplicanVs Actions or Behavior

5. c VER1FY containment spray suction ALIGNED to RWST:

FCV-72-22 OPEN

- FCV-72-21 OPEN.

e. VERIFY containment spray dfscharge valves OPEN:

. FCV-72-39 ATC/BOP

FCV-722.

f. VERIFY containment spray recirc valves CLOSED:

FCV72-34

FCV-72-13.

g. VERIFY containment spray flow greater than 4750 gpm on each train.

6. MONITOR containment air return fans:

WHEN at least 10 minutes ATC/BOP have elapseil from Phase B, THEN ENSURE containment air return tans RUNNING.

7 VERIFY containment ventilation dampers CLOSED:

ATC/BOP Panel 6K CNTMT VENT GREEN

- Panel SL CNTMT VENT GREEN.

8. VERIFY Phase A valves CLOSED:

ATC/BOP Panel 6K PHASE A GREEN

Panel 6L PHASE A GREEN.

9. VERIFY cntmnt vacuum relief isolation valves CLOSED: [Pnl 6K MANUAl..]

ATC/BOP FCV-3O-46

FCV-30-47

FCV-30-4&

10. VERIFY tASP/s and MSIV bypass valves ATC/BOP CLOSED.

Appendix D Reauired Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 5 Event # 7&8 Page 48 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior 11 DETERMINE H any S!G Intact:

a, CHECK at least one SIG pressure:

ATC/BOP - CONTROLLED or RISING AND

Greater than 140 psig.

CAUTON solatthg all SIGs will result in :a loss of secondary heat sink.

12. DETERMINE if any SIC Faulted:

a. CHECK S/C pressures: a. GO TO Step 13.

AnySIG pressure DROPPING P. I L.I D P ATrs,r hi an uncontrolled manner OR

AnyS/G pressure less than 140 psig.

13. MONITOR if RHR spray should be placed in service:

ATC/BOP a. CHECK the following: a. GO TO Step 14.

- Containment pressure greater than 9.5 psig

14. MONITOR if containment spray should be stopped:

a. CHECK any containment spray pump a. GO TO Step 15.

RUNNING.

ATC/BOP

b. CHECK containment pressure b. GO TO Step 15.

less than 2.0 psig.

15. RETURN TO procedure and step in eftect.

ATC/BOP END FR-P.1 Actions

1. MONITOR RWST level ATC/BOP greater than 27%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 7&8 Page 49 of 56 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior ATC/BOP Z MONITOR CST level greater than 5%.

3 CHECK RCS pressure IF any of the following conditions exist greater than 300 pstg. -

RHR injection flow on Fi-63-91A F163--92A greater Than 1000 gprn OR ATC/BOP

both RHR pumps STOPPED AND sump recirc capabihty has been lost ThEN RETURN TO procedure and step in effect.

ATC/BOP

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # ES-0.5 Page 50 of 56 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior ES-O.5 Actions SOP 1. VERIFY DIGS RUNNING BOP 2 VERIFY DIG ERW supy valves OPEN.

BOP 3. VERIFY at least four ERCW pumps RUNNING,

4. VERIFY CCS pumps RUNNING:

Pump lA-A (2A-A)

BOP

Pump 18-B (28-B)

Pump C-S.

BOP 5. VERIFY EGTS tans RUNNING.

BOP & VERIFY generator breakers OPEN.

7 NOTIFY at least two AUOs to report BOP to MCR to be available for local actions.

8. VERIFY AFW pumps RUNNING:

a. MDAFW pumps BOP

b. TOAFWpurnp.

NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control S!G levels, to estabhsti flow due to failure, or to isolate a faulted S1G.

9. CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

BOP b. VERIFY TD AFW LCV5 OPEN.

C.. VERIFY MD AFW pump recirculation valves FCV-3-400 and FcDV3-4Ol CLOSED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # ES-0.5 Page 51 of 56 Event

Description:

Equipment Verifications

[ Time Position Applicants Actions or Behavior

10. VERIFY MEW IsolatIon:

a CHECK MEW pumps TRIPPED.

b. ENSUREthefollowing:

BOP MFW regulating valves CLOSED

MEW regulating bypass valve controllers in MANUAL with output ZERO

- MEW isoLation valves CLOSED.

ii MONITOR ECCS operation:

a. VERIFY ECCS pumps RUNNING:

CCP5

RHR pumps SI pumps b VERIFY CCP flow through CCPIT.

BOP

c. CHECK RCS pressure less than 1500 psig

d. VERIFY Si pump flow.

e. CHECK RCS pressure e. GO TO Step 12.

less than 300 psg

1. VERIFY RHR pump flow

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # ES-0.5 Page 52 of 56 Event

Description:

Equipment Verifications Time Q Position Applicants Actions or Behavior

12. VERIFY ESF systems ALIGNED:

a. Phase A ACTUATED:

PHASE A TRAIN A alarm UT

[M-6C, 35].

PHASE A TRAIN B alarm UT

[M-6C, 36].

b. Cntmt Vent Isolation ACTUATED:

. CNTMT VENT ISOLATION TRAIN A alarm LIT [M-6C, CS].

CNTMT VENT ISOLATION TRAIN B alarm LIT IM-6C, C6].

c. Status monitor panels:

BOP GC DARK

GD DARK

GE LIT OUTSIDE outlined area

6H DARK

6JLIT.

d Train A Status panel BK:

CNTMT VENT GREEN

PHASE A GREEN

e. Train B status panel 6L:

CNTMT VENT GREEN

PHASEA GREEN

Appendix D Reciuired ODerator Actions Form ES-D-2 Op Test No.: NRC2OI2-302 Scenario# 5 Event# ES-O.5 Page 53 of 56 Event

Description:

Equipment Verifications Time Position I Applicants Actions or Behavior

13. MONITOR for containment spray and Phase B actuation:

a. CHECK for any of the following:

Phase B ACTUATED OR

Containment pressure greater than 2.8 psig.

b. VERIFY containment spray INITIATED:

BOP

1) Containment spray pumps RUNNING.

2) Containment spray header isolation valves FCV-72-39 and FCV-72-2 OPEN.

3) Containment spray recirculation valves to RWST FCV-72-34 and FCV-72-13 CLOSED.

4) Containment spray header flow greater than 4750 gpm per train.

5) Panel 6E LIT.

c. VERIFY Phase B ACTUATED:

PHASE B TRAIN A alarm LIT

[M-6C, AS].

PHASE B TRAIN B alarm LIT

[M-6C, A6].

d. ENSURE RCPs STOPPED.

e. VERIFY Phase B valves CLOSED:

Panel 6K PHASE B GREEN.

Panel 6L PHASE B GREEN.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # ES-0.5 Page 54 of 56 Event

Description:

Equipment Verifications L Time Position 1 Applicants Actions or Behavior WHEN 10 minutes have elapsed, f.

THEN ENSURE containment air return fans RUNNING.

NOTE The continuous action in Step 14 remains applicable if containment pressure rises above I 5 psig after ES-U.S is completed.

14. MONITOR ir containment vacuum relief isolation valves should be closeti:

BOP a. CHECK containment pressure a. GO TO Step 15.

greater than 1.5 psg.

i5 CHECK secondary and containment rad tTIOrli 015 USING the following:

BOP a Appendix A, Secondary Rad Monitors a Appendix B, Containment Rad Monitors.

APPENDIX A SECONDARY RAD MONITORS t IFSIoccuffedoflUniti.

THEN CHECK following rad monitors including available trends prior to isolation:

Condenser exhaust recorder I -RR9O-I 19

SIG blowdown recorder 1-RR-9O-420

Unit I Main steam line fad monitors [I-M-301

Post-Accident rad recorder i-RR-90-268B points 3 (blue), 4 (violet), :5 (black), and 6 (turquoise)

[1-M-31 (back of 1-M-30)1 3, NOTIFY Unit Supervisor whether secondary radiation is NORMAL or HIGH.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O12-302 Scenario# 5 Event# ES-O.5 Page 55 of 56 Event

Description:

Equipment Verifications Time I Position Applicants Actions or Behavior APPENDIX B CONTAINMENT RAD MONITORS 1, lFSloccurredonUniti.

THEN CHECK following rad monitors:

BOP a Upper containment post-accident cad monitors 1-RM-90-271A and 1RM90272A NORMAL [1463O]

a Lower containment post-accident Fad monitors i-RM-90-273A and 1-RM-90-274A NORMAL [1-M-30]

Containment rad recorders 1-RR-90-i 12 and 1-RR-90-106 NORMAL [O-M-121 (prior to isolation).

16. WHEN directed by E-G, ThEN BP

-. PERFORM Appendix 0, Hydrogen Mitigation Actions.

IL CHECK pocKet sump pumps STOPPED:

{M-15, upper left corner]

Bldg Aux Floor and BOP a Equipment Drain Sump pump A a 1-IS-77-41 1, Rx Bldg Aux Floor and Equipment Drain Sump pump B.

18. DISPATCH personnel to pertomi BOP EA-O-1, Equipment Checks Following ESF Actuation.

19. ENSURE plant announcement has been BOP made regarding Reactor Trip and SL

20. PERFORM Appendix E, Spent Fuel BOP Cooling Actions, as time permits.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 5 Event# Page 56 of 56 Event

Description:

Critical Task Critical Tasks: Critical Task Statement

1. Manually initiate a Phase B isolation prior to completing ES-O.5 step 13.

2. Manually stop one Containment Spray Pump prior to completing ES-I .3 step 2

3. Manually align CCP and SI pump flowpath for sump Recirc prior to completing ES-i .3 step 12

Appendix D Scenario Outline Attachment I Facility: Sequoyah Scenario No.: 4 Op Test No.: 2012-301 Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 1, 100% power, BOL Turnover: Maintain current conditions: currently in 0-GO-5 Section 5.2, At Power Conditions Target CTs: Insert negative reactivity into the core by at least one of the following methods before completing the immediate-action steps of FR-Si:

Direct de-energizing the control rod drive MG sets

Insert RCCAs

Establish emergency boration flow to the RCS Isolate AFW flow to the Faulted SG prior to completing E-2 step 4.

Event No.

1.

1 Malt. No.

RX24B Event Type*

1 Event Description C-BOPISRO Feed water header pressure transmitter PT-3-1 B fails low. The MFP Master Controller shifts to MANUAL resulting in lowering feed flow to all SGs. The BOP maintains S/G levels with the MFP Master Controller in MANUAL using AOP S.01.

2. RXI 9 I-ATC/SRO A gradual Auto Rod Motion insertion occurs due to a Tave Computer failure. The ATC will place control rods to manual to stop rod motion using Immediate Operator Actions and AOP-C.01.

3. RXO6A l-ATC/SRO The controlling pressurizer level channel LT 68-339 will fail low resulting in letdown isolation and de-energizing Pressurizer heaters. The ATC will remove the T channel from service and restore Pressurizer heaters using AOP-l.04. The SRO will address Tech Specs and determines the instrument is INOPERABLE.

3.a N-ATC The ATC will restore letdown.

4. RDO7M2 TS-SRO A control rod will drop into the core, the crew will take action to stabilize the power using AOP-C.01 .The SRO will address Tech Specs and determines entry into LCO 3.1.3.1 action c.4 is required.

5. R-ATC The crew will reduce power in response to the dropped rod using AOP-C.03 N-BOP/SRO

6. RCO2C C-ATC The #3 RCP motor trips with a failure of the RPS to initiate a Reactor Trip resulting in an ATWS. The crew will attempt to trip the Reactor from the control RPO1C CBOP room using E-0 and transition to FR-S.1 where the ATC manually inserts control

[pre-insert] rods and the BOP manually trips the main turbine and initiates emergency boration.

7. MSO6C M-AlI Following the reactor trip an unisolable steam leak will occur on Steam Generator Loop 3 outside containment upstream of the Main Steam Isolation Valve. The crew transitions to E-2.

8. FWO4C C-BOP The Loop #3 MDAFW LCV-3-148 tails open, the BOP will secure teed to the faulted Steam Generator tripping the 1 B-B MD AFW pump and manually closing the Turbine Driven AFW pump level control valve.

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

Appendix 0 Scenario Outline Attachment 1 201 2-301 Scenario 4 Summary EVENT I Following turnover, Feed water header pressure transmitter PT-3-1 B fails low. The MFP Master Controller shifts to MANUAL resulting in lowering feed flow to all SGs. The BOP maintains SIG levels with the MFP Master Controller in MANUAL using AOP-S.01.

EVENT 2 When directed by the lead examiner, gradual Auto Rod Motion insertion occurs due to a Tave Computer failure. The ATC will place control rods to manual to stop rod motion using Immediate Operator Actions and AOP-C.01.

EVENT 3 When directed by the lead examiner, the controlling pressurizer level channel LT 68-339 will fail low resulting in letdown isolation and de-energizing Pressurizer heaters. The ATC will remove the channel from service and restore Pressurizer heaters using AOP-l.04. The SRO will address Tech Specs and determines the instrument is INOPERABLE and enters LCO 3.3.1.1 Table 3.3-1 functional unit 11 Action 6; TS 3.3.3.7 Table 3.3-10 Functional Units 7 Action 2.

EVENT 4 When directed by the lead examiner, a control rod will drop into the core, the crew will take action to stabilize the power using AOP-C.01 .The SRO will address Tech Specs and determines entry into LCD 3.1.3.1 action c.4 is required.

EVENT 5 The crew will reduce power in response to the dropped rod using AOP-C.03.

EVENT 6 When directed by the lead examiner, the #3 RCP motor trips with a failure of the RPS to initiate a Reactor Trip resulting in an ATWS. The crew will attempt to trip the Reactor from the control room using E-0 and transition to FR-S.1 where the ATC and manually inserts control rods and the BOP manually trips the main turbine and initiates emergency boration. The crew will direct operators to locally trip the reactor trip breakers.

EVENT 7 When the reactor is tripped and at Lead Examiner direction, an unisolable steam leak will occur on Steam Generator Loop 3 outside containment upstream of the Main Steam Isolation Valve. The crew will transition to E-0 and subsequently E-2, to isolate the #3 Steam Generator.

EVENT 8 During performance of the EOPs, the Loop #3 MDAFW LCV-3-148 fails open, the BOP will secure feed to the faulted Steam Generator tripping the 1 B-B MD AFW pump and manually closing the Turbine Driven AFW pump level control valve using the FOP of E-0.

E- Procedure Path: E-0, FR-S.1, E-0, E-2 The scenario terminates as directed by the Lead Examiner when the crew has isolated the #3 S/G using E 2.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 4 Event# 1 Page 1 of 62 Event

Description:

Feed water header pressure transmitter PT-3-1 B fails low Time fl Position fl Applicants Actions or behavior Simulator Operator: When directed, initiate Event I Feed water header pressure transmitter fails low; PT-3-I IndicationslAlarms Annunciator:

1-M-3

1-XA-55-3C, C-I PS-3-4 NO I FW HTR PRESSURE Low

I-XA-55-3B, D-I Main Feedwater Digital Control Sys Transfer To Manual Indications:

I-M-4

I-Fl-3-35A, 35B, 48A, 48B, 90A, 90B, 103A, 103B, SG-I thru 4 SG FW INLET FLOW Chs 1&2 increasing flow- above steam flow I-M-3

FW MASTER CONTROLLER shifts to MANUAL (AMBER) 1-M-4

I-FI-3-35A, 35B, 48A, 48B, 90A, 90B, I03A, 103B, SG-I thru 4 SG FW INLET FLOW Chs I&2 increasing flow- above steam flow Significant Resultant Alarmsllndications:

Indications:

ICS

Thermal Power Increasing MAIN FEEDWATER DIGITAL CONTROL SYS TRANSFER TO MANUAL

[1] IF using the hand controllers to detemne which Dital Feedwater controller(s) has transferred to rnanuai, THEN DETERMINE which controHers in Manual by ORANGE acldit Manuat on controller

[2) IF usg the DCS Operator DLclay rnonitos to detemine which Digital Feedwater acofrdler(s) has transfetred to WNUAL, ThEN OBSERVE controller(s) yet1ow status light being LIT.

[31 ADJUST contmller() to maintain system parameters steady.

[4] NOTIFY US which controller(s) are in manual and system status

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 1 Page 2 of 62 Event

Description:

Feed water header pressure transmitter PT-3-1 B fails low Time Position fl Applicants Actions or behavior t5) F any of the following occur:

Sytern paramete can NOT be maintained OR

AtthediscretionoftheUS ThEN GO TO any of the fdlowng:

AOP-C03, Emergeicy Shutdown

AOP-S01, Main FeedwaterMztlftinciions

E-0, Reactor Trip or Safay hijection BOP Responds to ARP 1-AR-M3B D-1.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Evaluator Note: For this event, crew may respond per the Annunciator Response Procedure directly enter AOP-S.O1 Section 2.2. Section 2.2 Step us an IMMEDIATE ACTION step; the BOP may perform the action(s) associated with Step 1 from memory without direction.

I. DIAGNOSE the failure:

IF GO TO PAGE SECTION Failure of Automatic SIG Level Control ii 4 Failure of Automatic MFW Pump Control 22 7 Loss of One Main Feeclwater Pump 2.3 12 Above 76% (Unit 1)01 77% (Unit 2) Turbine Load Main Feedwater Pump TIip 2.4 19 Below 76% (Unit 1) or 77% (Unjt 2 Turbine Load NOTE Step 1 is an IMMEDIATE ACTION MFP (Master) Speed control shifts to MANUAL, manually control of MFP BOP (Master) Speed, reduces Main Turbine load as required to maintain Thermal Power within limits.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 1 Page 3 of 62 Event

Description:

Feed water header pressure transmitter PT-3-1 B fails low Time Position Applicants Actions or behavior

1. RESTORE feedwater pressure:

a. ENSURE affected MEP speed controller(s) in MANUAL:

MFPT A & B Speed Control OR BOP

MEPT A Speed Controller OR

. MFPT B Speed Controller b ADJUST speed on affected MFP(s) to restore feedwater pressure to normal (-1O4Q psig at full power)

Manually raises output MFP (Master) Speed Control to maintain S/G levels BOP I on program level.

2. DETERMINE it MFP rnp is needed:

BOP a CHECK BOTH MEW pumps IN SERVICE.

CAUTION: Feed flow transients may impact core thermal power.

BOP INThIN steam generator level(s) on program NOTE: Appendix C or DCS Operator Display monitors MFP Contror screen may be used to determine program feedwater DIP for current power.

4. MAINTAIN MFP discliarge pressure BOP on program USING OCS Operator Display monitors, ICS, or available control board indications.

CAUTION Reactor operation at low power levels for extended periods may challenge reactivity control due to xenon changes.

BOP 5. CHECK Reactor power greater Than 5%.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 1 Page 4 of 62 Event

Description:

Feed water header pressure transmitter PT-3-1 B fails low Time Position__II Applicants Actions or behavior CREW 6. INITIATE repairs on fa1ed equipment.

7. WHEN automatic control of affected MFW pump controfler(s) is available and reliable, THEN PLACE controller(s) in AUTO USING 1 ,2-SO-98-1, Distributed Control System.

SRO NOTE: Instructions for restoring bypassed instrument ctiannels are contained in I ,2-SO-98-1.

8. GO TO appropriate plant procedure.

END OF SECTION Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Orerations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

END OF SECTION Lead Examiner may cue the next event when plant is stable with MFP speed control in manual.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 2 Page 5 of 62 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 2 Auto Rod Motion Failure (Tave Computer failure)

Indications available:

Annunciators:

. XA-55-5A Window C-6 I-M-5 Indication:

. TR-68-2B, TREF increasing ramp TS-68-2PIQ REAC COOL LOOPS TREFTAUCT HIGH-LOW

[1] COMPARE plant indicators to verify validity of alarm.

NOTE I iF annuncin is an expected response during the performance of t-RT-MOD-S20-003.O, 20%

Load Step Change, rods thould be felt in AUTO.

NOTE 2 IF a rapid load reduction is in progress and aitomatic rod control is ftnctionai, AOP-C.03 allows reducing turbine load rate prior to placing rod control in manuaL

[2] IF AOP-C03, Rapkt Shutdown or Load rejection. is in progress, THEN

[a] REFER to AOP-C03 guidance for rod control operatiOn

[b] GO TO step 141W

[3] IF controls are in AUTO wtn alann occurs, THEN PLACE rod control system (1-1-13-85-5110) in manual and match Tavg with Tref.

[41 IF rod control system is ma1functlon, or there is irdcation of a failure of the Tref signal to the rod control system. THEN GO TO AOP-CO1, Rod Control System Mauncrions.

BOP Responds to ARP I -AR-M3B D-1.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012301 Scenario# 4 Event# 2 Page 6 of 62 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time I Position Applicants Actions or Behavior DIAGNOSE the failure:

GOTO IF... SECTION PAGE Uncontrolled rod bank movement (rod movement NOT due to actual Tavg/T-ref mLsmatch 21 4 or change in reactor!turbine power)

NOTE: Step I is an immediate action step.

I. STOP uncontrolled rod motion:

a PLACE rod control in MAN.

ATC

b. CHECK rod motion STOPPED.

CAUTiON: Control Rods should NOT be manually withdrawn during a plant transient.

2. CHECK for plant transient:

ATC a. CHECK reactor power and T-avg STABLE

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 2 Page 7 of 62 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time Position Applicants Actions or Behavior

& CHECK for instn.irnentation malfunction:

a. CHECK all Vital Instrument Power Boards ENERGIZED:

. VITAL POWER BOARD UV OR BREAKER TRIP alarms [M-1C windows A-7, 6-7, C-7, and D-71 DARK ATC

b. CHECK nuclear instrumentation OPERABLE

c. CHECK RCS RTDs OPERABLE d CHECK turbine impulse pressure channels OPERABLE.

3. e CHECK Tef OPERABLE e. PERFORM the following:

USiNG TR-68-28.

1) PLACE Steam Dumps n Steam Pressure Mode USiNG 0-SO-i -2, Steam Dump System.

ATC

2) DETERMINE Program T-avg for current reactor power USING Appendix A or ICS (Trend Menu, Program Tavg.)

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 2 Page 8 of 62 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time Q Position Applicants Actions or Behavior 0-SO-I -2, STEAM DUMP SYSTEM, section 8.2 8.2 Placing Steam Dump Controls in Pressure Mode.

CAUTION Placing steam dumps in service with water accumulated in header could result in severe water hammer. Monitoring and confirmation of normal Main Steam Dump Drain Tank operation by 0-GO-I 4-3 and 0-00-14-4 performance provides assurance that the line does not contain sufficient water to produce a water hammer.

[1] PLACE FHS1 -I 03A1 Steam Dump A FSV handswtch to OFF.

[2] PLACE [H S-I-I 03B1 Steam Dump B FSV handswitch to OFF.

[3] PLACE [MS-I-I 0301 Steam Dump Mode selector to STEAM PRESS,

[4] VERIFY IXI-I-103A(B1 Steam Dumps Armed white light is LIT. D

[5] IF IPIC-I -331 Steam Dump Controller in MANUAL, THEN BOP ENSURE demand is Zero on controller. D

[6] IF IPIC-I-331 Steam Dump controller in AUTO, THEN ADJUST setpoint to obtain zero output (demand).

CAUTION If a demand signal is present on XI-1-33 Steam Dump demand and dumps are armed.

then the dump valves will open when Steam Dump FSV handswitches are placed in ON position.

[I] PLACE EHS-I-103A1 Steam Dump A FSV handswitch to ON.

PLACE IHS-I -1 0361 Steam Dump B FSV handswitch to ON.

ADJUST IPIC-1431 Steam Dump controller to maintain desired steam pressure. C END OF TEXT

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 2 Page 9 of 62 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time Position Applicants Actions or Behavior

f. CHECK Auctloneered T g ATC OPERABLE USING TR-68-2B,

4. CHECK for inadvertent RCS dilution:

a. CHECK evidence of dilution a. GO TO Step 5.

INDICATED:

ATC

VCT level indication OR

Tavg rising unexplained with stable turbine load.

5. CHECK for inadvertent boration flow:

a. CHECK evidence of boration 110w a. GO TO Step 6.

INDICATED:

Batch counters 110w indication ATC OR a VCT level indication OR Tjg dropping unexplained.

NOTE: When adjusting T-avg, reactiiity changes should be accomplished by only one method at a time.

6. RESTORE to within I .5F of T-a POSITION control rods OR ATC

ADJUST turbine load OR

ADJUST RCS boron concentration USING 1)-SO-62-7, Boron Concentration Control.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 2 Page 10 of 62 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time Position Applicants Actions or Behavior Places HS-85-51 11 Rod Control to OUT as directed by the SRO to restore 1

ATC I ... .

7. EVALUATE the following Tech SpeCsITRM for appiicabilit:

3.1.i.1,Shutdown Margin- T-avg Greater than 200F

. 31 14, Minimum Temperature for Criticality SRO

3131 Movable Control Assemblies, Group Height

31.3,5, Shutdown Rod Insertion Limit

31.3.6.. Control Rod Insertion Limits

3.2, Power Distribution Limits (entire section) 8 CHECK cause of continuous rod motion IDENTIFIED.

CREW 9. ENSURE Maintenance initiated as rquired.

10. ENSURE Plant Management notified of failure.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 2 Page 11 of 62 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

[ Time Position Applicants Actions or Behavior 11, WHEN problem corrected AND automatic rod control is available, THEN PERFORM the tIowing:

a. ENSURE Tavg and T-f matched within 1°F.

ATC

b. PLACE control rods in AUTO USING 0-50-85-1, Rod Control System.

12, GO TO appropriate plant procedure.

Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event when ready.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 3 Page 12 of 62 Event

Description:

Pzr Level Controlling Channel LT 68-339 fails low Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 3 Controlling Pzr Lvl Transmitter fails low (LT 68-339)

IndicationslAlarms Annunciator:

1-M-5

1-XA-55-5A C-3, PRESSURIZER LEVEL HIGH-LOW

E3, PRZR LVL LOW HEATER OFF & LETDOWN SECURED Indications:

1-M-4

1-Ll-68-339 RCS PZR LEVEL indicates 0 level Significant Resultant Alarmsllndications:

1-M-6

. 1-FI-62-82, LETDOWN HX OUTLET FLOW indicates 0 flow O-M-27

O-XA-27B-B A-5, LETDOWN HX OUTLET FLOWITEMP ABNORMAL LS-68-335D1E PRESSURIZER LEVEL HIGH-LOW til CHECK pressurizer leI (1-U-&8-339A, 335A, 320)

[21 IF level is ugh, THEN ENSURE bakup heaters 0N

[31 ENSURE level control system is attempting to return level to pogram wIth letdown and dging.

[4] IF level channel felled, THEN GO TO AOP-L 04, Prestzer Instrument Malfunction.

BOP Responds to ARP 1-AR-M5A C-3.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 4 Event# 3 Page 13 of 62 Event

Description:

Pzr Level Controlling Channel LT 68-339 fails low Time Position Applicants Actions or Behavior DIAGNOSE the failure:

GOTO IF....

SECTION PAGE Pressurizer Levef Instrument Malfunction 2A 20 2.4 Pressurizer Level Instrument Malfunction CAUTION Chemistry sampling of PZR Liquid Space may result in additional bistables actuating due to impact on I-LT-68-320 or 2-LT-68-335.

NOTE Appendix M shows layout of PZR level control for operator reference.

l. CHECK 11-68-339 NORMAL PERFORM the following:

a ENSURE LEVEL CONTROL CHANNEL SELECTOR switch XS-68-339E in LT-68-335 & 320.

ATC b. ENSURE LEVEL REC CHANNEL SELECTOR switch XS-68-339B in LT-68-320 or LT-68-335.

c GOTOStep4 Examiner note: The following are from EA-62-5, go to page 16 for AOP-l.-4 actions.

EA-62-5 ESTABLISHING NORMAL CHARGING AND LETDOWN actions

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 4 Event# 3 Page 14 of 62 Event

Description:

Pzr Level Controlling Channel LT 68-339 fails low Time Position_[ Applicants Actions or Behavior

2. IF normal letdown flow is to be established, THEN ATC GO TO Section 43.

4,,3 Establishing Normal Letdown Flow NOTE EA-62-3, Establishing Excess Letdown, may be utilized it Normal Letdown cannot be established.

1. IF charging flow NOT established, ATC THEN PERFORM Section 42.

ATC 2. VERIFY pressurizer level greater than 17%.

3. ENSURE letdown oril ce isolation valves CLOSED:

LETDOWN ORIFICE ISOLATION VALVES CLOSED ATC FCV-62-72 Li FCV-62-73 Li FCV-62-74 Li 4 OPEN letdown isolation valves:

LETDOWN ISOLATION VALVES ATC FCV-62-69 FCV-.62-70 FCV-62-77 NOTE Placing cooling water on the Letdown Heat Exchanger prior to restoring letdown flow should prevent TIS 62-79B/A from actuating and fully opening TCV-70-192.

5. PLACE ftHC-62-781 in MANUAL, AND ATC OPEN CV-7O192I to 5O%

Appendix 0 Scenario Outline Attachment I Op Test No.: NRC2O12-301 Scenario# 4 Event# 3 Page 15 of 62 Event

Description:

Pzr Level Controlling Channel LT 68-339 fails low Time Position I Applicants Actions or Behavior

6. PLACE letdown pressure controller [PCV-62-81] in MANUAL and ADJUST output between 40% and 50%, (50%-60% open)

7. ADJUST charging flow as necessary to prevent flashing in the ATC letdown line.

W OPEN letdown orifice isolation valves as needed:

LETDOWN ORIFICE ISOLATION VALVES OPEN ATC ATC l FCV-62-73

. j Places HS-62-73(or 74) Letdown Orifice B (or C) Isol 75 gprn to OPEN.

NOTE Normal letdown pressure is 325 psig at normal operating Lempe rature.

9. ADJUST letdown pressure controller IPCV-62-811 output to obtain desired_pressure.

1 1. PLACE letdown pressure controller [PCV-62-8i] n AUTO.

ATC Places letdown pressure controller PCV-62-81 in AUTO.

NOTE Normal letdown temperature is -.

100CF.

12. ADJUST [H1C42-78A1 to obtain desired letdown temperature, as indicated on [TI-62-i$].

13 PLAOE IHLC-62-78A1 in AUTO.

1

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 4 Event# 3 Page 16 of 62 Event

Description:

Pzr Level Controlling Channel LT 68-339 fails low

[ Time Position Applicants Actions or Behavior ntr W Examiner Note: Several steps, notes, and cautions in the procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Examiner Note: Letdown temperature may swing due to repeated actuation of TIS-62-79B/A, which causes letdown temperature control valve TCV-7O192 to fully open.

Examiner note: AOP-l.04 actions recommence here.

5. EVALUATE the folloirIg Tech Specs for applicability:

SRO

3.3.1.1 (3.3.1), Reactor Trip System Instrumentation

3.3.3.7 Accident Monitoring Instrumentation UMNG CONDITION FOP OPERATION 3.3.1.1 Asa muimurn, the reactor hip system insthrmentatlcn nnels and intedoc&s of Table 3.3-1 shall be OPERABLE.

APPUCABILITY As shovm in Table 3.3i.

ACTION As shown in Table 3.3-1.

11. PessurizerWa.erLevel 3 2 2 1,2 6 l{igh ACTION 6 WIth the number of OPERABLE d1annels one less than the Tet Number of Channels, STARTUP ndtor POWER OPERA11ON may proceed provided the fcowin conditions we satisfied:

a. The inoperable channel ls placed in the tripped conaition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

3.3.7 The accident mnit insthn)entalion channels. shown in Table 3,3-10 shlbe OPERABLE, APPUCARILITY: MODES 1,2 and 3 ACTION: P,ssbown in Table 3.3-10

7. PressurerLevelWideRang.e 3 3 2 (Instrument Loops 68-32035-330)

ACTiON 2- NOTE Also refer to the applicable action requirements from Tables 3.3-1 since it may contain more restrie actions.

a. With the nuniberof channels one less than the minimum channels reqitred, restore the inoperable channel t OPERABLE status within 34) days ow be in at least HOT STANDBY wibe, the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN widen the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Appendix D Scenario Outline Attachment I Op Test No.: NRC2O12-301 Scenario# 4 Event# 3 Page 17 of 62 Event

Description:

Pzr Level Controlling Channel LT 68-339 fails low

- - . . Applicants Actions or Behavior - -

. . SRO Enters LCO 3.3.1.1 Action 6 and LCO 3.3.3.7 Action 2

6. ENSURE pressurizer heaters restored ATC to service CAU11ON RCS pressure changes and changes in RCS boron concentration (due to differences between pzr and RCS boron) may impact core reactivity.

7. MONITOR reactor power:

a. CHECK reactor in Mode 1 or I b MONITOR core thermal power for unexpected changes.

NOTE:

If performing AOP in conjunction with AOP-l.11 for an Eagle LCP failure, then actions to hard trip bistables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months UNLESS affected loop is restored to operable status by resetting Eagle rack.

8. NOTIFY I&C to remove failed pressurizer level channel from servTce USING appropriate Appendix:

L-68-339 Appendix I Lead Examiner may cue the next event when Letdown is restored and Technical Specifications are addressed.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 4 Page 18 of 62 Event

Description:

Dropped Rod Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 4 Dropped Rod: M2 SDB A rod.

I ndicationslAlarms Annunciator:

1-M-4

. 1-AR-M4-B, D4, COMPUTER ALARM ROD DEV & SEQ PWR RANGE TILTS

. 1-AR-M4-B, D7, FULL LENGTH RODS AT BOTTOM

. 1-AR-M4-B, E3, NIS POWER RANGE CHANNEL DEVIATION

. 1-AR-M4-B, B3, NIS POWER RANGE UPPER DETECTOR HI FLUX DEVN OR AUTO DEFEAT (Later)

. 1-AR-M4-B-C3, NIS POWER RANGE LOWER DETECTOR HI FLUX DEVN OR AUTO DEFEAT (Later)

Indications available:

I-M-4

. I Rod Bottom Light illuminated on M-4 IRPI Display FULL LENGTH RODS RODS AT BOTTOM (1 j CHECK rod sit.

(2] IF more than one rod drops, THEN TRiP the reactor and GO TO E-O, Reactor Tr4i or Safety I*ctidn

[3] IF a single rod dropped, THEN GO TO AOP-C.G1, Rod CotraI System Maffwcbons.

(4] IF RJI maifunctioci or failures THEN GO TO AOP-C.Q1, Rod Ccniro System MaffLmdions (51 IF &opped rod occurs or rod position indication is the nmction, THEN REFER TO Technical Specifications 324, 3.tii, 3.I35, and 321.

BOP Responds to ARP 1-AR-M4-B D-7.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 4 Event# 4 Page 19 of 62 Event

Description:

Dropped Rod Time Position Applicants Actions or Behavior

1. DIAGNOSE the failure:

GOTO lF... SECTION PAGE Dropped shutdownicontrol rod(s) 2.2 ID with reactor initially in Mode I or 2 NOTE: Step I is an immediate action step.

[ ATC J 1. PLACE rod control in MAN.

2. VERIFY ONLY ONE rod dropped.

NOTE: If a dropped rod occurs at low power level, retrieval of the dropped rod is NOT the conservative action to take and could violate Tech Specs (if Mode 2 has been entered). [C.2]

ATC MONITOR reactor power greater than 5%.

4. REDUCE load to control T-:

9

a. MONITOR F-avg greater than 541°F.

(LCO 3.1.1.4)

BOP

b. CHECK main turbine loaded.

c. REDUCE turbine load to establlsh F-avg Within 3°F of F-ref.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 4 Page 20 of 62 Event

Description:

Dropped Rod L__Time Position Applicants Actions or Behavior

5. MONITOR Quadrant Power Tilt Ratio (QPTR) less than 1.09 of USING one the following:

a ICS ATC OR a U-SI-NUC-000-i 33.0, Quadrant Power Tilt Ratio.

6. EVALUATE the following Tech SpeCSITRM for applicability:

. 3.. 1.1.4, Minimum Temperature for Criticality

. 3.131, Movable Control Assemblies, Group Height SRO

3.1.3.2, Position Indication Systems Operating a 3.1.3.5, Shutdown Rod Insertion Limit a 3.1.3.6, Control Rod Insertion Limits

12, Power Distribution Limits (entire section)

UMTING CONDITION FOR OPERATION 3.1.31 AfuI1 length (shuoen and cond) rods shat be OPERABLE and p oned within +/- 12 steps (indicated poaion) f their group step counter demand position.

APPUCABILITi: MODES 1.and 2 ACTION:

c. Kith one full length rod ntisned*cn its group sinp cowter demand he4Iit by more than

+/- 12 steps (irxkated position). POWER OPERATION may coritioue pmvided that within SRO onelreither

1. The rod is restored within the above mwnt requirements, or

2. The remainder of ihe rods inthe group with 11w n edrodarealnedwithin +/-

12 steps of the misaed mod while mainining. the rod sequere and insertion limit of speoficalion 3.13.8. The ThERMAL POWER Ieve4 slisilbe resiricted pursuant to Specification 3.t3i6 ourg subseent operation, or 3, The moo is declxed sioperable and the SHUTDOWN MARGiN requitemnentof SpecWaia3.t1.1 is satisfle POWER OPERA11ON may then ooninue provided th

Appendix 0 Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 4 Page 21 of 62 Event

Description:

Dropped Rod Time Position Applicants Actions or Behavior UMITING CONOfflON FOR OPERA11ON 3.1.35 A shutdown rods thaif be limited in physca{ wserbon as specified in the COLR APPLIOABILITY: MODES 1 sndT#

ACTION:

a. With a manmim of one shutdown rod Inserted beyond the insertion tinit specified in the COLFL exce for swveillance testng punSpeciScarion 41.312:OrWhefl complying with ACTION bof this spec&aton. within one hwr either

1. Restore the rod to within the insertion limit specified in the COLR. or

2. Declare the rod to be inoperabie and apply ACTION 1 .31 32A The QUADRANT POWER TiLT RATIO sh not exceed I £12.

APPUCABlUT: MODEl abore 5(1% of RATED THERMAL POWER ACTION:

a. With the QUADRANT POWER TILT RATIO detemitted to exceed LD2 but less than cc equal to L09 1 CalcuLate the QUADRANT POWER TILT RATIO at least once per ho untt al Either the JADRANT POWER TILT RATiO a reduced tr within its limit. or b) THERMAL POWER is reduced to less than 50% of RATED THERMAL POWER

2. Within 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months s:

a) Ether reduce the QUADRANT POWER TILT RATiO to within its knit, or b) Reduce THERMAL POWER at least 3% froni RATED THERMAL POWER for each 1% of indicated QUADRANT POWER TILT RATIO in excess of 1.02 and sintitarly reduce the Power Range Neutron Flux44i TrlpSeoints within the neirt4 hours,

3. Verify that the QUADRANT POWER liLT RATIO is within its unit within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after exceeding the fend or reduce THERMAL POWER to less than 50% of RATED ThERMAL POWER within the next 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and reduce the Power Range Neutron Fitix-High Trip setpoints to less. than crequ to 55% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

4. Identify and cottect the cause Of the out of limit condition priorto increasing THERMAL POWER subsequent POWER OPERATION above 50% of RATED THERMAL power may proceed provided that the QUADRANT POWER TILT RATIO j verifIed within its limit at least once per hour for 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or unIt verified acceptable at (15% or greater RATED THERMAL POWER

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 4 Page 22 of 62 Event

Description:

Dropped Rod Time Position Applicants Actions or Behavior NOTE Core thermal power must be reduced to less than 75% within one hour and shutdown margin must be verified within one [our UNLESS dropped rod can be restored in one hour (LCO 31 31 action C)

7. PERFORM the following to comply with LCO3.1.3.i:

a. INITIATE power reduction to less than 75% USING one of following:

AOP-C.03, Rapid Shutdown or Load Reduction SRO OR

. 0-GO-S. Normal Power Opefation b VERIFY adequate Shutdown Margin within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months USING Sl-NUc-O0O-03&0 Transitions to AOP-C.03 RAPID SHUTDOWN OR LOAD REDUCTION, go SRO to page 23 for details.

When Technical Specifications are addressed, the Lead Examiner may cue the next event

Appendix 0 Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 5 Page 23 of 62 Event

Description:

Power Reduction Time Position N Applicants Actions or Behavior Simulator Operator: No action required for Event 5, Rapid Power reduction Directs performance of AOP-C.03 RAPID SHUTDOWN OR LOAD SRO REDUCTION.

1. ENSURE crew has beefi briefed on reactivity SRO management expectations USING Appendix A.

REACTIVITY MANAGEMENT BRIEFING NOTE This appendix should be used in addition to event-based brief.

[1] ENSURE crew has been briefed on the following:

. Reason for Rapid Shutdown or Load Reduction

Load Reduction Rate:_______

. Desired final power level:______

. Reactivity Management expectations:

a Unit Supervisor shall concur with all reactivity manipulations

Ensure reactor responding as expected using diverse indications

Tavg-Tref Mismatch requirements:

3F control band

. 5 J

0 E reactor trip criteria a Crew focus will be on reducing power in a controlled and conservative manner.

a OATC will monitor rod insertion limits and AR) limit

Boration source:

Crew will monitor reactor trip and turbine trip criteria using App. B a CR0 will stop secondary plant equipment using App C.

a If time permits, review expected annunciators (ex. Computer Alarm, Upper and Lower Flux Dev) a Termination Criteria (conditions requiring Reactor Trip, Turbine Trip, or condition no longer requiring rapid load reduction):

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 5 Page 24 of 62 Event

Description:

Power Reduction Time Position Applicants Actions or Behavior

2. NOTIFY fo4iowing personnel of rapid shutdown or load reduction:

. Load Coordinator [C.1J CREW

chemistry

. Radiation Protection

Plant Management CREW Makes notifications as required.

3. MONITOR reactoriturbine ffip NOT required CREW USING Appendix B, ReactOr and Turbine Trip Criteria..

Examiner note: Appendix B reactor and turbine trip criteria see page 28

4. CHECK VALVE POSITION LIMIT light BOP DARK on EHC panel.. [M-.2]

NOTE: Boration volumes and fkmrates listed in this procedure are recommendations and may be adjusted as necessary.

5.. INITIATE boration:

a.. CHECK rod control AVAILABLE:

ATC

Control Bank D rods capable of being moved

NO dropped or misaligned rods in Control Bank 0.

5.. b CHECK Control Bank 0 group position greater than 200 steps.

ATC

c. CHECK boration capability from BAT AVAILABLE.

Appendix D Scenario Outline Attachment I OpTestNo.: NRC 2012-301 Scenario# 4 Event# 5 Page 25 of 62 Event

Description:

Power Reduction Time Position Applicants Actions or Behavior

d. DETERMINE recommended boration volume from BAT:

a 80O gal to reduce power from 100% to 20%

OR SRO a 10 gal for eact 1% power reduction (from current power level)

OR

volume recommended by Reactor Engineering.

SRO Determines 250 gal to reduce power from 100% to 75%.

5 e. DETERMINE recommended boration flowrate from table below or from Reactor Engineering:

SRO LOAD REDUCTION BORATION RATE(%Imin) 2% -30gpm 3% -45 gpm

f. ENSURE concurrence obtained from ATC STA for boration volume and flowrate g ENSURE boric acid transfer pump ATC aligned to blender in FAST speed

h. ADJUST FCV-62-138 to establish desired flow rate.

L CONTROL boration flow as required to inject desired boric acid voium&

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 5 Page 26 of 62 Event

Description:

Power Reduction Time Position Applicants Actions or Behavior CAUTION: If borating from the RWST, Turbine Load Reduction Rate greater than 2% per minute could result in violating Rod Insertion Limit.

6. INITIATE load reduction as follows:

a. ADJUST load: rate to desired value:

between 1%and4%perminute if borating via FCV-62-138 BOP OR

between 1% and 3% per minute if borating via normal boration (App. H)

OR

2%perminute if borating from RWST ADJUST setter for desired power level:

DESIRED RECOMMENDED RX POWER LEVEL SETTER VALUE BOP I .1 80% 56 70% 46

& c VERIFY boration flow established BOP d INITIATE turbine load reduction by depressing GO pusIibutton

e. CONTROL turbine l:oad reduction as necessary to reduce power to desired level.

Appendix D Scenario Outline Attachment I Op Test No.: NRC2O12-301 Scenario# 4 Event# 5 Page 27 of 62 Event

Description:

Power Reduction Time Position__IL Applicants Actions or Behavior

7. MONITOR T-avg/T-ref mismatch:

a. CHECK T-ref widication a. PERFORM the following:

AVAILASLE.

1) MONITOR Program T-avg for current reactor power USING TT-28 Figure 3 or ICS (NSSS / SOP, Program Reactor Average Temperature).

2) USE program T-avg in place of T4eL

3) MAINTAIN T-avg within 3F of program T-avg USING manual rod ATC contra

4) ADJUST turbine load rate as necessary.

5) IF mismatch between T-.avg and program value CANNOT be maintained less Than 5F.

THEN TRIP The reactor and GO TO EU, Reactor Tnp or Safety Injection.

BOP 8. MONITOR automatic control of MFW pump speed AVAILABLE.

9 STOP secondary plant equipment BOP USING Appendix C, Secondary Plant Equipment.

Examiner Note: Appendix C, Secondary Plant Equipment starts at page 29.

Examiner Note: Additional AOP-C.03 steps not included as required power reduction should be complete at or around this step.

Appendix D Scenario Outline Attachment I OpTestNo.: NRC2OI2-301 Scenario# 4 Event# 5 Page 28 of 62 Event

Description:

Power Reduction APPENDIX B REACTOR AND TURBiNE TRIP :C:RITERIA REACTOR TRIP CRITERIA TURBINE TRIP CRITERIA Turbine trip required or imminent Turbine vibration exceeding 14 mils with reactor power greater than P-*9 5O%) with one of the roliowing:

Uncontrolled rod movement wliich CANNOT be

high vibration on multiple bearings stopped by placing rods in MANUAL oi-c.ci OR Loss of SIG level control:

abnormal noise/vibration apparent level dropping or rising toward trip setpoint and level CANNOT be restored OP-S.Oi)

More than one dropped rod {AoP-co1)

T-avg/T-ref mismatch CANNOT be maintained less than 5F (refer to Step 7 or p. E) 30% turbine load: <30% turbine load:

Condenser Pressure >27 psia AND CANNOT Condenser Pressure> 1.72 psia be restored within 5 minutes ao-s.o (AOP-S.02)

Any automatic reactor trip setpoint reached Any automatic turbine trip setpoint reached OR automatic trip imminent: OR automatic trip imminent

Turbine trip above P-9 (50%)

High Stator Cooling Water temp 9OaC

Safety injection OR Stator DIP :12 psig below normal

Power Range fligh flux 109%

Both MFPTs tripped

Power Range flux rate +/-5% in 2 seconds

Low Auto Stop Oil pressure 45 psig

Pressurizer high level 92%

High Sf0 level 81% narrow range

Pressurizer pressure low 1970 psig

Main Turb Bearing Oil low pressure 7 psig

Pressurizer pressure hiçh 2385 psig

Thrust Bearing Oil high pressure 60 psig

RCS low how 90%

Turbine Overspeed 1980 rpm

RCP undervoltage 5.022 kilovolts

Loss of El-IC pressure

RCP underfrequency 56.0 Hz

Generator PCBS tipped.

OTAT 115% (variable)

OPAT 108.7% (variaNe)

S/Glow level 10.7% (15% EAM]

SSPS general warning in both trains

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 5 Page 29 of 62 Event

Description:

Power Reduction APPENDIX :C SECONDARY PLANT EQUIPMENT

[1] ENSURE plant announcement(s) made on the following:

starting rapid shutdown (or load reduction) due to: (reason) C

. stopping secondary plant equipment D NOTE I If reactor power will be reduced below 50%, AUO should be on station at #3 heater drain tank (if possible) when 60% power is reached.

NOTE 2 Dispatching of AUO in Steps [2] and [3] may be performed out of sequence.

[2] IF reactor power will be reduced below 50%,

THEN DISPATCH AUO with Appendix J (Unit 1) or K (Unit 2) to #3 Heater Drain Tank. C

[3] IF one MFP will be shutdown using this appendix, THEN DISPATCH AUO to OPEN MFWP recirc manual Isolation valve for MFWP to be removed from service (N/A valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN I IA I-VLV-3-576 TB el. 706, Nodheast corner of IA condenser C 18 i-VL.V-3-577 TB eL 706, Northeast corner of IA condenser C 2 24 2-VLV-3-576 TB eL 706, Southeast corner of 2A condenser C 28 2-VLV-3-577 TB el. 706, Southeast corner of 2A condenser C

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 5 Page 30 of 62 Event

Description:

Power Reduction APPENDIX C

[4] IF BOTH of the following conditions are met:

a power is being reduced as directed by AOP-S01 (Main Feedwater Malfunctions) or AOPS.04 (Condensate or Heater Drain Malfunctions) a leaving secondary pumps in service is desired, ThEN GO TO Step [8].

[5] WHEN turbine impulse pressure is approximately 80% or less, THEN PERFORM the following:

[a] ENSURE one Cond Demin Booster Pump STOPPED. El

[b] ENSURE associated suction valve CLOSED:

OR j B FCV-2-285 El OR

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 5 Page 31 of 62 Event

Description:

Power Reduction 16] WHEN turbine impulse pressure is approximately 70-75%,

THEN PERFORM the following:

La] ENSURE one Condensate Boaster Pump STOPPED..

[b] ENSURE associated CBP suction valve CLOSED:

CONDENSATE BOOSTER PUMP SUCTION VALVE CLOSED ij A FCV-2-94 FCV-2-87 OR OR FCV-2-81 El Id PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary) a 1-S0-2/3-1 Section 72 OR

2SO-213-1 Section L3

Appendix D Scenario Outline Aftachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 5 Page 32 of 62 Event

Description:

Power Reduction

[7] WHEN turbine impulse pressure is approximately 65% or less, THEN PERFORM the following:

[a] STOP remaining two Cond Demin Booster Pumps simultaneously.

] ENSURE suction vatves CLOSED:

COND DEMIN BOOSTER pup SUCTION VALVE CLOSED A FCV-2-290 U B FCV-2-285 U C FCV-2-280 U fc] STOP one No. 3 Heater Drain pump. U Id] STOP one No. 7 Heater Drain pump U

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event# 5 Page 33 of 62 Event

Description:

Power Reduction t8 IF reactor power Will be maintained greater than 50%

THEN GO TO Notes prior to Step III]

CAUTION Isolation of all three intermediate heater strings could occur if turbine is tripped prior to fully opening LCV-6-I 05A and B using Appendix J or K.

[9] WHEN reactor power is less than 60%

AND AUO with App. J (Un 1) or K (Unit 2 is on station at #3 Heater Drain Tank, THEN PERFORM the following:

[a] STOP #3 Heater Drain Tank Pumps. D

[b] NOTIFY AUO to perform App. J (Unit 1) or App. K (Unit 2),

Fully Opening #3 Heater Drain Tank Bypass Valves.

[ci CLOSE isolation valves from #3 Ktr Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED .I FCV6-108 Htr Drain Tk Pump 3 to Htr String A FCV-6-109 Htr Drain Tk Pump 3 to Htr String B U FCV-6-1 10 Htr Drain Tk Pump 3 to Htr String C El

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 5 Page 34 of 62 Event

Description:

Power Reduction NOTE I The following step ensures that MFW Bypass valves are available to control feedwater flow at low power.

NOTE 2 If any MFW Reg valve is in MANUAL, the associated MFW Bypass valve controller should rein am in MANUAL to prevent undesired opning of bypass valve,

[101 WHEN Reactor power is less than 50%,

THEN PERFORM the following:

Ia] IF all MFW Reg Valves are in AUTO, THEN PLACE MFW Bypass Reg Valve controllers in AUTO. D

[1,] IF any MFW Reg Valve is in MANUAL THEN PERFORM the following:

1) MAINTAIN MFW Bypass Reg Valve in MANUAL for S/G with MFW Reg valve in MANUAL.

2) PLACE MFW Bypass Reg Valves in AUTO for remaining S1Gs..

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 5 Page 35 of 62 Event

Description:

Power Reduction NOTE I If performing this AOP to reduce power to allow shutting down one MFW pump, the affected MFWP may be removed from service at power level less than 55% (Unit 1) or 65% (Unit 2)

NOTE 2 AFW start function on loss of both MFW pumps is inoperable when a MFW pump is RESET but NOT pumping forward LCO 3321 (Unit 1) or 332 (Unit 2) allows AFW start channel to be inoperable for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months when shutting down a MFWP

[113 WHEN it is desired to remove one MFW pump from service AND power level is less than applicable limit:

turbine impulse pressure less than approximatety 45%

OR

reactor power less than value specified in Note I THEN PERFORM the fol1owng:

[a] ENSURE MFWP Recirc Manual Isolation valve OPEN for MFWP to be removed from service: (N/A valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN 1A 1-VLV-3-576 TB el. 706, Northeast corner of 1A condenser lB 1-VLV-3-577 TB el. 706, Northeast corner of 1A condenser 2 2A 2-VLV3-576 TB el. 706, Southeast corner of 2A condenser 28 2-VLV-3-577 TB el. 706, Southeast corner of 2A condenser Eb] THROTTLE OPEN recirc valve in MANUAL (30-50% OPEN) for MFWP to be removed from service.

[c] PLACE speed controller in MANUAL for MFWP to be removed from service.

[ci] REDUCE speed gradually on MFWP to be removed from service.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 5 Page 36 of 62 Event

Description:

Power Reduction

[ii] (Continued) fe3 ENSURE proper loading on remaining MFWP tfl IF MFWP CANNOT be fully unloaded with speed controller, THEN PERFORM one of the following:

NOTIFY i&C to slowly adjust hand speed changer for affected MFWP UNTIL MFWP is fully unloaded OR

THROTTLE OPEN recirc valve for affected MFWP to assist in unloading MFWP OR

SLOWLY CLOSE governor valve by bumping closed governor valve posioner (if operable) fl OR

OBTAIN SRO concurrence that MFWP flow is sufficiently low to allow tripping MFWP

[g] WHEN MFWP is unloaded sufficientty THEN TRIP affected MFWP.

[N CLOSE recirc valve for MFWP removed from service..

Li] CLOSE recirc valve Manual Isolation inlet valve for MEW P removed from service..

U] OPEN drain valves for MFWP removed from service: fM-3]

[HS-46-141, MFWP A drain valves OR

IHS-46-41]. MFWP B drain valves..

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 5 Page 37 of 62 Event

Description:

Power Reduction t121 WHEN turbine impulse pressure is approximately 45% or less, THEN PERFORM the following:

[a] STOP remaining No. 7 Heater Drain pump. U Eb] CLOSE isolation valves from #7 Heater Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED.4 FCV-6-143 Htr Drain Tk Pump 7 to Htr String A U FV61:63 Htr Drain Tk Pump 7 to Htr String B U FCV-6-184 Htr Drain Tk Pump 7 to Htr Stung C 0

[131 WHEN turbine impulse pressure is approximately 30% or less, THEN PERFORM the following:

[a] ENSURE main turbine EHC controls in IMP OUT. U

[b] IF #3 heater drain tank pumps are still running, THEN PERFORM Step [9].

[c] STOP one of two remaining Condensate Booster Pumps.

(steD continued on next paqe)

Appendix D Scenario Outline Attachment I Op Test No: NRC 2012-301 Scenario # 4 Event # 5 Page 38 of 62 Event

Description:

Power Reduction

[131 (Continued)

Id] ENSURE associated CBP suction valve CLOSED:

I CON:DENSATE SUCTION VALVE CLOSED 4 I BOOSTER PUMP

[ A FCV-2-94 FCV287 D

[ C FCV-2-81

]e STOP one of three Hotwell Pumps.

ifi PERFORM applicable procedure to adjust seal injection water pressure an stopped CEP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary)

i-SO-2/31 Section 72 El OR

2-S0--213-1 Section 13 El

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 6 Page 39 of 62 Event

Description:

RCP Trip/ATWS Time Position Applicants Actions or Behavior Booth Operator: When directed, initiate Event 7 #3 RCP tripIATWS Indications available:

Indications/Alarms Annunciator:

. 1-M-4-D, D-3 One Loop Low Flow Reactor Trip Indications:

1-M-4

#3 RCP Tripped Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

ONE LOOP LOW FLOW REACTOR TRIP

[1] IF reactor trips, THEN GO TO E-O, Reactor Trip or Safety Inject/on.

Examiner Note: following IOA performance, prior to Steps 1-4 immediate action verification, ATC/BOP surveys MCBs for any expected automatic system response that failed to occur. Upon discovery, they may take manual action(s) to align plant systems as expected for the event in progress. (Ref. EPM-4, Prudent Operator Actions)

Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via SPDS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT 1 STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

CREW Performs the first four steps of E-O unprompted.

SRO Directs performance of E-O NOTE I Steps I through 4 are immediate action steps.

NOTE 2 This procedure has a foldout page.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 6 Page 40 of 62 Event

Description:

RCP Trip/ATWS Time Position Applicants Actions or Behavior

1. VERIFY reactor TRIPPED: TRIP reactor.

Reactor trip breakers OPEN IF reactor CANNOT be tripped, THEN

Reactor trip bypass breakers PERFORM the following:

DISCONNECTED or OPEN ATC a. MONITOR status trees.

Rod bottom lights LIT ii GO TO FR-S 1, Nuclear Power

Rod position indicators GenerationlATWS.

less than or equal :o i2 steps

Neutron flux DROPPING SRO Transitions to FR-S. 1, Nuclear Power Generation!ATWS CAUTION RCPS should NOT be tripped with reactor power greater than 5%.

NOTE Steps 1 and 2 are immediate action steps

1. VERIFY reactor TRIPPED: TRIP reactor.

. Reactor trip breakers OPEN IF reactor trip breakers will NOT open, THEN

. Reactor trip bypass breakers MAINTAIN auto or manual rod insertion OPEN or DISCONNECTED at max achievable rate ATC UNTIL rods are at bottom.

Neutron flux DROPPING

Rod bottom lights LIT

Rod position indicators less than or equal to 12 steps.

2 VERIFY turbine TRIPPED:

BOP

. ALL turbine stop valves CLOSEII

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event# 6 Page 41 of 62 Event

Description:

RCP TripIATWS

[ Time ) Position Applicants Actions or Behavior 3.. CHECK AFW System operation:

a. MD AFW pumps RUNNING

b. TO AFW pump RUNNING.

BOP

c. MD AFW LCVs in AUTO d TO AFW LCVS OPEN.

d. CHECK pressunzer pressure less thrn 2335 psig BOP Places HS-1-51A TriplThrottle Vlv Pos to OPEN.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 6 Page 42 of 62 Event

Description:

RCP Trip/ATWS Time Position I Applicants Actions or Behavior EMERGENCY BORATE RCS by pertorming the following:

Examiner Note: When the crew has sufficiently taken the actions to meet the critical task for reactivity control for the ATWS direct the facility operator to allow the AUOs to open Rx Trip Bkrs in sequence.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 4 Event# 6 Page 43 of 62 Event

Description:

RCP Trip/ATWS Time Position Applicants Actions or Behavior Examiner Note: When the crew has sufficiently taken the actions to meet the critical task for reactivity control for the ATWS direct the facility operator to insert Event 8.

Examiner Note: Crew may close MSIVs and attempt to isolate AFW to faulted SI.G WHEN REACTOR IS TRIPPED during performance of FR-S.1. When attempting to isolate AFW, level control valve will not close and crew may elect to stop 1 B AFW Pump at that time.

P1 H S.1 E22A Ma earn o to SE.

Evaluator Note: Auto SI will likely occur when MSIVs are closed after Rx Trip in FR-S.1 and as the faulted SIG depressurizes.

5. VERIFY Containment Purge isolated:

ATC a. VERIFY containment purge and vent dampers (System 30) CLOSEE1

[Panel BK and 6L]

6.. MONITOR for SI signal:

a. CHECK SI signal ACTUATEII ATC

b. PERFORM the following WHILE continuing with this procedure:

1) E-D,ReactorTliporSafety injection, Steps I through 4.

2) ES-O.5, Equipment Verications.

Performs E-0, Reactor Trip or Safety Injection, Steps 1 through 4 and ES-BOP 0.5, Equipment Verifications as required go to page 53 for details.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 4 Event# 6 Page 44 of 62 Event

Description:

RCP Trip/ATWS Time Applicants Actions or Behavior D__Position

7. CHECK reactor and turbine tlip status:

a Reactor TRIPPED.

BOP b Turbine TRIPPED:

ALL turbine stop valves CLOSED.

& MONITOR reactor subcritical:

a. Power range channels less than 5%

ATC b. Intermediate range SUR NEGATIVE.

c. GOTO Step 19.

SRO 19. ENSURE status tree monitoring initiated.

Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via SPDS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT I STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 4 Event# 6 Page 45 of 62 Event

Description:

RCP Trip/ATWS Time Position Applicants Actions or Behavior 20 MAINTAIN 51(3 narrow range levels:

a. Greater than 10% [25% ADVI.

BOP b Between 10% [25% ADVI arid 50%.

BOP Manually controls AFW flow to maintain total AFW flow greater than 440 gpm ju l

e t

h lS/Gar anlO% egrea r n NR 2 1. MONITOR boration termination criteria:

a. NOTIFY Chem Lab to sample RCS boron concentration.

b. CHECK for all of the following:

all control rois FULLY INSERTED

RCS temperature ATC greater than 540°F

no RCS dIution has occurred.

c WHEN emergency boration is no longer needed.

THEN STOP emergency boration USING EA-68-4. Emergenc Borat ion.

22 RETURN TO procedure and step in effect.

SRO END

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event# 6 Page 46 of 62 Event

Description:

RCP Trip/ATWS Time Position Applicants Actions or Behavior SRO Directs performance of E-O NOTE I Steps 1 through 4 are immediate action steps.

NOTE 2 This procedure has a foldout page.

1. VERIFY reactor TRIPPED:

Reactor trip breakers OPEN

Reactor trip bypass breakers DISCONNECTED or OPEN ATC

Rod bottom lights LIT

Rod position indicators less than or equal to 12 steps.

Neutron flux DROPPING

2. VERIFY turbine TRIPPED:

BOP

Turbine stop valves CLOSED.

3. VERIFY at least one 6.9KV shutdown ATTEMPT to start DIGs.

board ENERGIZED on this unit.

IF power CANNOT be immediately restored to at least one shutdown board BOP on this unit, THEN GO TO ECA-0.O, Loss of All AC Power.

4. DETERMINE if SI actuated:

ATC ECCS pumps RUNNING

Any SI alarm LIT [M-4D]

5. PERFORM ES-O.5, Equipment BOP Verifications WHILE continuing in this procedure.

Continue with the performance of E-O REACTOR TRIP OR SAFETY SRO/ATC INJECTION BOP Performs ES-O.5, Equipment Verifications go to page 55 for details SRO Addresses foldout page, see next page for details.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 6 Page 47 of 62 Event

Description:

RCP TripIATWS FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

RCS pressure less than 1250 psig AND at least one CCP or SI pump running OR

Phase B isolation, THEN STOP all RCPs EVENT DIAGNOSTICS

IF any 510 pressure is dropping uncontrolled THEN PERFORM the following:

a. CLOSE MSIVs and MSIV bypass valves.

b. IF any SIG pressure continues to drop uncontrolled, THEN PERFORM the following:

1) ENSURE SI actuated.

2) IF at least one Sf0 is intact <SIG pressure controlled or rising),

THEN ISOLATE AFW to faulted SIG(s):

CLOSE AFW level control valves for faulted S/G(s)

IF any AFW valve for faulted Sf0 CANNOT be CLOSED. THEN PERFORM Appendix E, Isolating AFW to Faulted SIG

3) ENSURE at least one of the following conditions met:

total AFW flow greater than 440 gpm OR

Narrow Range level greater than 10% [25% ADVI in at least one intact 510.

IF both trains of shutdown boards de-energized, ThEN GO TO ECA-()0, Loss of All AC Power TANK SWITCHOVER SETPOINTS

IF CST level less than 5%, THEN AliGN AFW suction to ERCW.

IF RWST level less than 27%, THEN GO TO ES-I 3, Transfer to RHR Containment Sump

Appendix D Scenario Outline Attachment I Op Test No.: NRC2O12-301 Scenario# 4 Event# 6 Page 48 of 62 Event

Description:

RCP Trip/ATWS Time Position Applicants Actions or Behavior APPENDIX E ISOLATING AFW TO RUPTURED SIG IF motor-dflven AFW LCV for niptured SIC CANNOT be dosed.

ATC/BOP ThEN PERFORM the foIlong:

a. IF at least one other AFW pump is available, THEN PLACE affected MD AFW pump in PULL TO LOCK.

DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpm.

b. CHECK narrow range level b. MAINTAIN total feed flow greater than 10% [25% ADV] greater than 440 gpm ATC in at least one 81G. UNTIL narrow range level greater than 10% [25% ADV]

in at least one SIG.

C. CONTROL feed flow to maintain narrow range level between 10% [25% ADV] and 50%

in intact or ruptured SIGs.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 6 Page 49 of 62 Event

Description:

RCP Trip/ATWS Time Position Applicants Actions or Behavior

7. CHECK if main steam lines should be isolated:

a. CHECK if any of the following conditions have occurred:

. Any SIG pressure less than 600 psig OR ATC

Any SIG pressure dropping UNCONTROLLED OR

. Phase B actuation.

b. ENSURE MSIVs and MSIV bypass valves CLOSED.

c. ENSURE applicable Foldout Page actions COMPLETED.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 6 Page 50 of 62 Event

Description:

RCP Trip/ATWS Applicants Actions or Behavior

8. CHECK RCP trip criteria:

a. CHECK the following:

RCS pressure less than 1250 psig ATC AND

At least one CCP OR SI pump RUNNING.

b. STOP RCPs.

9. MONITOR RCS temperatures: IF temperature less than 547°F and dropping,

IF any RCP running, THEN THEN PERFORM the following:

CHECK T-avg stable at or trending to between 547°F and 552°F. a. ENSURE steam dumps and atmospheric reliefs CLOSED.

OR

b. IF cooldown continues,

IF RCPs stopped, THEN THEN CONTROL total feed flow:

CHECK T-cold stable at or trending ATC/BOP 1) ENSURE total AFW flow to between 547°F and 552°R less than or equal to 600 gpm.

2> MAINTAIN total AFW flow greater than 440 gpm UNTIL narrow range level is greater than 10% [25% AD)]

in at least one S!G.

c. IF cooldown continues after AFW flow is controlled, THEN CLOSE MSIVs and MSIV bypass valves.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 4 Event# 6 Page 51 of 62 Event

Description:

RCP TripIATWS Time Position Applicants Actions or Behavior

10. CHECK pressurizer PORVs, safeties, and spray valves:

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

ATC c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

11. DETERMINE if Sf0 secondary pressure PERFORM the followrng:

boundaries are INTACT:

a MONITOR status trees.

CHECK all 510 pressures ATC CONTROLLED or RISLNG. b. GO TO E-2. Fauited Steam Generator I solatori

CHECK dli Sf0 piessures greater than 140 psig SRO Transitions to E-2, Faulted Steam Generator Isolation.

Appendix 0 Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 7,8 Page 52 of 62 Event

Description:

Steam Leak to Break 0/S Containment Upstream Lp #3 MSIV & #3 SG MDAFWP Lvi Control Viv fails open.

Time Position Applicants Actions or Behavior Simulator Operator: When directed, insert Event 7 MS Leak Outside Containment Loop #3 -

upstream of MSIV.

Indications available:

Indications/Alarms Annunciator:

. 1-M-4-D, F-i STEAM LINE LO PRESS SI REACTOR TRIP Indications:

1-M-4

. All S/G Pressures Dropping uncontrolled Time Position Applicants Actions or Behavior CAUTION Unisolating a faulted SIG or secondary break should NOT be considered UNLESS needed for RCS cooldawn,

1. CHECK MSIVs and MSIV bypass valves CLOSE Valves.

CLOSED.

IF any MSIV OR MSIV bypass valve CANNOT be closed, ThEN CLOSE valve USING EA-1-1, Closing MSIVs locally.

cRmcALL Places HS-1-4A, HS-1-IIA,HS-I-22A,HS-1-29A Main Steam isol TASK CLOSE If not already done.

2 CHECK ANY SIG secondary pressure boundary INTACT:

BOP a Any SIG pressure ON1TOLLED or RISING.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 7,8 Page 53 of 62 Event

Description:

Steam Leak to Break 0/S Containment Upstream Lp #3 MSIV & #3 SG MDAFWP Lvi Control Vlv fails open.

Time Position Applicants Actions or Behavior

3. IDENTIFY Faulted S!G(s):

a. CHECK SIG pressures:

Any S!G pressure DROPPING SRO in an uncontrolled manner.

OR

Any S!G pressure less than 140 psig CAUTIONS

Secondary heat sink requires at least one SIG available.

it the TD AFW pump is the only source of feed flow, isolating both steam supplies will result in loss of secondary heat siaL

4. ISOLATE Faulted SIG(s):

a ENSURE MFW isolated to faulted SIG(s) by any of the following:

BOP

feedwater isolation valve CLOSED [M-4J OR

feeciwater regulating valve and bypass valve CLOSED [M-3i

b. ENSURE AFW isolated to faulted SIG(s):

BOP

CLOSE MDAFWLV a CLOSE TD AFW LCV and PLACE in PULL TO LOCK

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 4 Event # 7,8 Page 54 of 62 Event

Description:

Steam Leak to Break 0/S Containment Upstream Lp #3 MSIV & #3 SG MDAFWP Lvi Control Vlv fails open.

Time Position Applicants Actions or Behavior

c. CHECK SIG #1 or#4 faulted. c GO TO Substep 4e.

BOP

4. e. VERIFY S!G blowdown valves cLOSED.

BOP

f. VERIFY atmospheic relief CLOSETI BOP 5. CHECK OST level greater than 5%:

6. VERIFY secondary radiation NORMAL:

a CHECK secondary radiation NORMAL USING Appendix A, Secondary Rad Monitors.

(App. A also contained in ES-0.5)

b. NOTIFY (Them Lab to take S!G activity samples C WHEN Chern Lab is ready to sample SIGs, ThEN BOP PERFORM the following:

1) ENSURE FCV-15-43 Blowdown Flow Control valve CLOSEII

2) ENSURE Phase A signal RESET.

3) OPEN blowdown: isolation valves.

ci. NOTIFY RADCON to survey main steam lines and S/G blowdown.

e. WHEN 51(3 samples completed, THEN CLOSE blowdown isolation valves.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 4 Event # 7,8 Page 55 of 62 Event

Description:

Steam Leak to Break 0/S Containment Upstream Lp #3 MSIV & #3 SG MDAFWP Lvi Control VIv fails open.

Time Position Applicants Actions or Behavior 7, CHECK SI termination criteria:

a. RCS subcooflng based on core exit TICS greater than 40°F.

b. Secondary heat sink:

Narrow range level in at least one Intact SIG greater than 10% [25% ADVI OR BOP

Total feed flow to Intact S!Gs greater than 440 gpm.

c.. RCS pressure stable or rising..

d. Pressuilzerleved greater than 10% 120% ADVJ.

e. GO TO ES-Il, SI Termination.

Lead Examiner may terminate the scenario at E-2 Step 7.e, SI Termination criteria determination.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2010302 Scenario # 7 Event # ES-0.5 Page 56 of 62 Event

Description:

Equipment verifications Time 1 Position Applicants Actions or Behavior ES-O.5 Actions BOP I VERIFY DIGs RUNNING.

BOP 2 VERIFY DIG ERCW supply valves OPEIL BOP VERIFY at least four EROW pumps RUNNING.

4 VERIFY ccs pumps RUNNING:

Pump lA-A (2A-A)

BOP Pump 1B-B(2B-B)

Pump CS.

BOP 5. VERIFY EGTS fans RUNNING.

BOP 6. VERIFY generator breakers OPEN.

NOTIFY at lea oAUosto report BOP to MCR to be available for local actions.

& VERIFY AFW pumps RUNNING:

BOP a MDAFWpums

b. TDAFW pump.

NOTE AFW level control vaNes should NOT be repositioned if manual action has been taken to control SIG levels, to establish flow due to failure, or to isolate a faulted SIG.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2010302 Scenario # 7 Event # ES-0.5 Page 57 of 62 Event

Description:

Equipment verifications Time 1] Position 1 Applicants Actions or Behavior 9 CHECK AFW valve ahgnment:

a. VERIFY MD AFW LCVs in AUTO.

BOP b VERIFY TD AFW LCVs OPEN.

C. VERIFY MD AFW pump recirculatlon valves FCV-3-400 an FV3.-4Oi CLOSED.

10. VERIFY MFW Isolation:

a CHECK MEW pumps TRIPPED.

b ENSURE the following:

BOP

MEW regulating valves CLOSED

MEW regulating bypass valve controllers n MANUAL with output ZERO

MEW isolation valves CLOSED..

11. MONITOR ECCS operation:

a. VERIFY ECCS pumps RUNNING:

CCPs RHR pumps BOP

Slpumps ii VERIFY CCP flow through CCPIT

c. CHECK RCS pressure less than 1500 psig.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2010302 Scenario # 7 Event # ES-0.5 Page 58 of 62 Event

Description:

Equipment verifications Time I Position Applicants Actions or Behavior d VERIFY Si pump how.

e. CHECK RCS pressure e. GO TOp 12.

less than 300 psg.

1. VERIFY RHR pump 110w.

IZ VERIFY ESF systems ALIGNED:

a Phase A ACTUATED:

PHASE A TRAIN A alarm LIT

[M-6C, B5]

PHASE A TRAIN B alarm LIT IM-6C, B6I

b. Cntmt Vent Isolation ACTUATED:

CNTMT VENT ISOLATION TRAIN A alarm UT [M-6C, C51.

CNTMT VENT ISOLATION TRAIN B alarm LIT [M-6C, C61

c. Status monitor panels:

BOP

GC DARK

GD DARK

GE LIT OUTSIDE outlined area

6HDARK

GJLIT.

d.. Train A status panel 6K:

CNTMT VENT GREEN

PHASE A GREEN

e. Train B status panel 61:

- CNTMT VENT GREEN

PHASE A GREEN

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2010302 Scenario # 7 Event # ES-0.5 Page 59 of 62 Event

Description:

Equipment verifications Time Position Applicants Actions or Behavior

13. MONITOR for containment spray and Phase B actuation:

a. CHECK for any of the following:

Phase B ACTUATED OR

Containment pressure greater than 2.8 psig.

b. VERIFY containment spray INITIATED:

1) Containment spray pumps RUNNING.

2) Containment spray header isolation valves FCV-72-39 and FCV-72-2 OPEN.

3) Containment spray recirculation valves to RWST FCV-72-34 BOP and FCV-72-13 CLOSED.

4) Containment spray header flow greater than 4750 gpm per train.

5) Panel 6E LiT.

C. VERIFY Phase B ACTUATED:

PHASE B TRAIN A alarm LIT

[M-6C, A5].

PHASE B TRAIN B alarm LIT

[M-6C, AS].

d. ENSURE RCPs STOPPED.

e. VERIFY Phase B valves CLOSED:

Panel 6K PHASE B GREEN.

Panel 6L PHASE B GREEN.

f. WHEN 10 minutes have elapsed, THEN ENSURE containment air return fans RUNNING.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2010302 Scenario # 7 Event # ES-0.5 Page 60 of 62 Event

Description:

Equipment verifications

[ Time Position Applicants Actions or Behavior j NOTE The continuous action in Step 1 remains apphcable if containment pressure rises above 1.5 psig after ES-O.5 is compieted.

14. MONITOR if containment vacuum relief isolation valves should be closeI:

BOP a. CHECK containment pressure a. GO TO Step 15.

greaterthanl5psig.

15. CHECK secondary and containment fad monitors USING the following:

BOP

Appendix A, Secondary Rad Monitors a Appendix [3, Containment Rad Monitors.

APPENDIX A SECONDARY RAD MONITORS

1. IF SI occurred on Unit t ThEN CHECK following rad monitors including avai1ab4 trends prior to isolation:

Condenser exhaust recorder I -RR-9O-i 19

SIG blowdown recorder 1-RR-90-120

Unit 1 Main steam line rad monitors [1-M-301

Post-Accident fad recorder 1-RR-90-268B points 3 (blue), 4 (violet), .5 (black), and. 6 (tUfquoise).

[i-M-31 (back of 1 -M-30)1

3. NOTIFY Unit Supervisor whether secondary radiation is NORMAL or HIGH.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2010302 Scenario # 7 Event # ES-0.5 Page 61 of 62 Event

Description:

Equipment verifications Time jJ Position Applicants Actions or Behavior APPENDIX B CONTA1NME:NT RAD MONITORS t lFSloccurredonUnitl, THEN CHECK following rad monitors:

BOP

Upper containment post-accident rad monitors 1-RM-90-271A and 1-RM-90-272A NORMAL [1-M-301

Lower containment post-accident mci monitors 1-RM-9C[-273A and 1-RM-90-274A NORMAL [1-M-301

. Containment rad recorders 1-RR-90-1 12 and 1-RR-90-106 NORMAL [0-M-12] (prior to isolation).

16 WHEN directed by E-O, THEN B OP PERFORM Appendix D, Hydrogen Mitigation Actions 17.. CHECK pocKet sump pumps STOPPED:

.[M-15, upper left corneij

1-15-77-410, Rx Bldg Aux Floor and BOP Equipment Drain Sump pump A

1-15-77-411, Rx Bldg Aux Floor and Equipment Drain Sump pump B

18. DISPATCH personnel to perform BOP EA-0-1, Equipment Checks FolloiWing ESF Actuation..

19. ENSURE plant announcement has been BOP made regarding Reactor Trip and SL

20. PERFORM Appendix E, Spent Fuel BOP cooing Actions, as lime permits.

[ END OF TEXT

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2010302 Scenario # 7 Event # Critical Task(s) Page 62 of 62 Event

Description:

Critical Task Listing Critical Tasks: Critical Task Statement

1. Insert negative reactivity into the core by at least one of the following methods before completing the immediate-action steps of FR-S.1:

. Direct de-energizing the control rod drive MG sets

. Insert RCCAs

. Establish emergency boration flow to the RCS

2. Isolate AFW flow to the Faulted SG prior to completing E-2 step 4.

Appendix D Scenario Outline Attachment I Facility: Sequoyah Scenario No.: 5 Op Test No.: 2012-301 Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 1, 100% power, BOL Turnover: Maintain current conditions; currently in 0-GO-5 Section 5.2, At Power Conditions Target CTs: Isolate AFW Flow to #4 Steam Generator Prior to completing E-2 step 4.

Manually start the lA-A or lB-B Motor Driven Auxiliary Feed pumps and establish the minimum required AFW flow rate to the SGs before transition out of E-0.

Event No. MaIf. No. Event Type* Event Description

1. RXO2D1 l-ATC/SRO The Loop #4 T-cold instrument will fail high. The ATC will place rod control in TS-SRO manual using Immediate Operator Actions and AOP-l.02. The SRO will address Tech Spec and determines the instrument is INOPERABLE.

2. CC1 1A C-BOP/SRO The 1A Thermal Barrier Booster Pump breaker trips and the I B Thermal Barrier set yp cc2l b = Booster Pump fails to AUTO Start. The BOP manually starts the 1 B Thermal

-1 [pre-insert] Barrier Booster Pump using the ARP.

3. CV25B I-ATC/SRO Letdown backpressure transmitter PT-62-81 fails high, the ATC HIC-62-81 in MANUAL and controls letdown backpressure using the ARP.

4. RX16C TS-SRO Steam Gen Level Transmitter, LT 3-94 Fails low, the crew will enter AOP 1.06.

The SRO will address Tech Specs and determines the instrument is INOPERABLE.

5. CNO9 C-BOP/SRO Main Condenser Vacuum degrades with the standby Condenser Vacuum Pump CN1 1 B failing to start automatically. The BOP manually starts the standby Condenser Vacuum Pump using AOP-S.02.

6. N/A R-ATC The crew reduces plant power using AOP-C.03 due to Condenser Vacuum N- BOP/SRO Leak.

7. EDO1 M-AlI A loss of offsite AC power occurs causing a reactor trip. The crew will respond to the trip using E-0. The crew may subsequently address the loss of offsite power using AOP-P.01, Loss of Offsite Power.

8. IMF FWO9C C-BOP Both motor driven Auxiliary Feed pumps fail to AUTO start and the turbine IMF FWO7C driven Auxiliary Feed trips on overspeed. The BOP manually starts a Motor

. Driven Auxiliary Feed pumps and establish the minimum required AFW flow rate

[pre-insert]

to the SGs.

9. FW 23D M-All The #4 S/G will experience a feed line break inside the containment. The crew will initially transition to E-2, Faulted SG Isolation, to stabilize the plant by isolating AFW to the #4 S/G and ultimately transition to E-1, Loss of Rx or Secondary Coolant, to determine if SI termination criteria is met.

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

Appendix D Scenario Outline Attachment I 2012-301 Scenario 5 Summary EVENT I Following turnover when directed by the lead examiner, the Loop #4 T-cold instrument will fail high. The ATC will place rod control to manual using Immediate Operator Actions. Additionally, the ATC will remove the affected instrument from service using AOP-l.02, RCS Loop RTD Instrument Malfunction.

The crew may enter AOP-C.01, for the unexpected rod motion. The SRO will determine entry in to LCO actions: 3.3.1.1 Table 3.3-1, functional units 7 and 8 Action 6, and 14c Action 10, 3.3.2.1, functional units 6.c.i.c and 6.c.ii.c both Action 37 are required.

EVENT 2 When directed by the lead examiner, the IA Thermal Barrier Booster Pump breaker trips and the 1 B Thermal Barrier Booster Pump fails to AUTO Start. The BOP manually starts the 1 B Thermal Barrier Booster Pump using the ARP.

EVENT 3 When directed by the lead examiner, Letdown backpressure transmitter PT-62-81 fails high, the ATC HIC-62-81 in MANUAL and controls letdown backpressure using the ARP.

EVENT 4 Steam Gen Level Transmitter, LT 3-94 Fails low, the SRO will enter AOP 1.06. The SRO will address Tech Specs and determines the instrument is INOPERABLE and enter LCO 3.3.1.1, 3.3.2.1, 3,3,3,7,10 and 3.3.5.7.

EVENT 5 When directed by the lead examiner Main Condenser Vacuum degrades with the standby Condenser Vacuum Pump failing to start automatically. The BOP manually starts the standby Condenser Vacuum Pump using AOP-S.02.

EVENT 6 The crew reduces plant power using AOP-C.03 due to Condenser Vacuum Leak.

EVENT 7 When directed by the lead examiner, loss of offsite AC power occurs. The crew will respond to the trip using E-0. The crew may subsequently address the loss of offsite power using AOP-P.01, Loss of Offsite Power.

EVENT 8 Both motor driven Auxiliary Feed pumps fail to AUTO start and the turbine driven Auxiliary Feed trips on overspeed. The BOP manually a Motor Driven Auxiliary Feed pumps and establish the minimum required AFW flow rate to the SGs.

EVENT 9 The #4 SIG will experience a feed line break inside the containment. The crew will initially transition to E-2, Faulted SG Isolation, to stabilize the plant by isolating AFW to the #4 SIG and ultimately transition to E-1, Loss of Rx or Secondary Coolant, to determine if SI termination criteria is met.

EOP flow: E-0, E-2, E-1, FR-Z.1, FR-P.1 (possible)

The scenario terminates as directed by the Lead Examiner upon completion of SIG #4 isolation in E-2.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 5 Event# 1 Page 1 of 57 Event

Description:

RC Loop #4 T-cold instrument fails high Time Position j Applicants Actions or Behavior Booth Instructor: When directed, initiate Event I, RC Loop #4 T-cold Fails High Indications available:

Annunciators:

M-5

. 1-XA-55-5A A-6 TS-68-2MIN RC LOOPS T AVG IAUCT T AVG DEVN HIGH-LOW

. 1-XA-55-5A B-6 TS-68-2AIB REACTOR COOLANT LOOPSAT DEVN HIGH-LOW

. I-XA-55-5A E-7 NARROW RANGE RTD FAILURE LOOP 4 XA-55-6A

. 1-XA-55-6A A-2 TS-68-2D REAC COOL LOOPS OVERTEMP AT TRIP ALERT

. 1-XA-55-6A B-2 TS-68-2G REAC COOL LOOPS OVERPOWER AT TRIP ALERT

. 1-XA-55-6A C-2 TS-68-2E OVERTEMP AT AUTO TURB RNBK BLK C-3 ROD WTD

. 1-XA-55-6A D-2 TS-68-2J REACTOR COOLANT LOPS LO LO TAVG 1-M-4 indications:

. I-Xl-1-103D, Steam Dumps Actuated D FSV Energized I-M-5 indications:

. RCS Lp 4 Indicator, 1-TI-68-67E indicates: goes up;

. I-TI-68-67D indicates: goes up;

. 1-TI-68-67A indicates: goes up;

. 1-TI-68-67B indicates: goes up;

. 1-XX-55-5, Reactor Trip Status Panel PROT. SET 4 TROUBLE Status light TS-68-2MIN RC LOOPS T AVG

!AUCT T AVG DEVN HIGH-LOW

[1] CHECK i-XX-55-5, Trip status pane for any bistables that nay beiIt AND EVALUATE Reactor Trtp cdtena Mth SRO by aisor wfth redundant instrumentation.

[2] IF reactor taps, THEN GO TO E-0, ?eactor T1p arSalely Injection.

[3] IF Tavg channel faid, THEN GOTO AOP-t.02 RCS LOOP RID INSTFUMENT MALFUNCTION.

[4] iF rod control system s rnalfunctiorchg, TI-lEN GO TO AOP-C01, Rod Contrd System Mfunctions,

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 5 Event # 1 Page 2 of 57 Event

Description:

RC Loop #4 T-cold instrument faHs high Time JL Position Applicants Actions or Behavior ATC Responds to ARP 1-AR-M-5A A-6.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Takes Immediate action to place HS-85-51 10 ROD CONTROL MODE I SELECTOR in MANUAL.

to AOP-G.01 Rod Control System

1. DIAGNOSE the taikjre:

GOTO lF. SECTiON PAGE Uncontrolled rod bank movement (rod movement NOT due to actual T-avg!T-ref mismatch 2 1 4 or change in reactor!turbine power)

NOTE: Step I is an immediate action step.

t STOP uncontrolled rod motlofi:

a PLACE rod controt in MAN ATC b CHECK rod motion STOPPED.

CAUTION: Control Rods should NOT be manually withdrawn during a plant transient.

2 CHECK for plant transient:

ATC a CHECK reactor power arid Tavg STABLE.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-301 Scenario # 5 Event # I Page 3 of 57 Event

Description:

RC Loop #4 T-cold instrument fails high Time j Position Applicants Actions or Behavior 3 CHECK for instrumentation malfunction:

a. CHECK all Vital Instrument Power Boards ENERGIZED:

. VITAL POWER BOARD UV OR BREAKER TRIP alarms [M-IC winlows A-7, 8-7, C-7, ani D-7j DARK ATC

b. CHECK nuclear Instrumentahon OPERABLE

c. CHECK RCS RTDs OPERABLE. c. GO TO AOP-L02. RCS Loop RTD ATC Instrument MaIfunctIo CAUTION: Control rods should NOT be manually withdrawn during a plant transient.

NOTE: Tavg must be within 1GF of Tref when restoring automatic rod controL SRO Transitions to AOP-I.02 RCS LOOP RTD INSTRUMENT MALFUNCTION t PLACE rod control in MANUAL.

2.. RESTORE Tavg as necessary USING one of the following:

manual rod control ATC OR RCS borationidiiution OR turbine load reduction

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario # 5 Event # 1 Page 4 of 57 Event

Description:

RC Loop #4 T-cold instrument fails high Time Position Applicants Actions or Behavior 3 CHECK loop 1 temperature channel ATC OPERABLE ATC 4 CHECK loop 2 temperature channel OPERABLE.

5. CHECK loops temperature channel ATC OPERABLE.

& CHECK loop 4 temperature channel PERFORM the following:

OPERABLE

a. PULL-TO-DEFEAT TAVG CHANNEL DEFEAT switch XS-68-2M to LOOP 4 ATC

b. PULL.TO-DEFEAT T CHANNEL DEFEAT switch XS-68-2D to LOOP 4 C. PLACE LOOP TAVG IT RECISEL switch XS-68-2B in LOOP 1,2, or 3

. 0 C Places s ch XS-68-2D to OOP 4 and PULL- F iT CHAN EL DEFEAT

7. EVALUATE the following Tech Specs for applicabiliiy:

. 3311 (331), Reactor Trip System SRO Instrumenlalion

. 3.3.2.1 (3.3.2), Engineered Safety Feature Actuation System Instrumentation

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-3Q1 Scenario # 5 Event# 1 Page 5 of 57 Event

Description:

RC Loop #4 T-cold instrument fails high Time Position Applicants Actions or Behavior UMDING CoNDmof4 FOR OPERATION 3.3.1.1 As a ntoimuni, the reactor tip system insumentation channels and interlocks f Table 3.3-I shall be OPERABLE.

APPLICABIIJTY As shown in Table 3.3-1.

ACTION:

As shown 3 Table 3.3-1.

7. Ovemperstore T Four 4 3 1,2 6 Loop Operabon E Oveipower ,T Four Loop 4 2 :3 1.2 6 0

ACTION 8- WIth the inariber of OPERABLE channels one less than the Total Number of Channels, STARTUP ar4ior POWER OPERATION may proceed ptowlded the firiwing :condihons we satisfied:

a. The noperable channel is placed in the tripped condeoi, within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

14. Main Steam Generator Water LevelLow-Low C RCS Loop T 4 (iiloop) 2 3 1,2 10 ACTION 10- WIth the number of OPERABLE channels one less than the Total Number of Channels. STARTI P andlor POWER OPERATION rosy proceed provided that within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . for the alfected protection set.

the Trip Time Delays (! and Tv) threshold power level for zero seconds tine delay is adjusted to 0% RTP.

SRO UMNG CONDITION FOR OPERATION 3.32.1 The Eiineersd Safety Featore Actuation System (ESFASI instnjmenbtlon channels and interlocks shown in Table 33-3 shat be OPERABLE with their trip seipoints set consistent wtiti the values shown in the Nominal Thp Seoint column of Table 3.3-4.

APPLICABILITY As shown in Table 3.3-3.

ACTiON:

a. With an ESFAS in irotallon hanei or interlock trip seoint less conservative than the value shown in the PJlowabfe Values column of Table 3.3-4, declare the channel noperable and appiy the applicable ACTION requirement of Table 3.3-3 iraN the diavrel is restored to OPERABLE status with the trip seipt adjusted consistent wIth the Ncnstial Trip Sekpoirtt value.

8. AUXILiARY FEEDWATER

c. Main Stat Gen.

Water LevelLow-Low I. Start Motor-Driven Pumps Oc RCS LoopT 4(lJloop) 2 3 t,2,3 37 It. StaftTwbereDrivea Pump cc RCS Loop T 4(Moop) 3 1.2,3 37

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-301 Scenario# 5 Event# I Page 6 of 57 Event

Description:

RC Loop #4 T-colci instrument fails high Time Position Applicants Actions or Behavior ACTION 37 - Vih the riumbec & OPERABLE thelsoie less th th Total Nwe of Channels, STARTUP amdIo POWER OPERATION may pioceed provided that withb 8 hows. for the alfecd prot set. the TThe Delays (T 5 aodT,) threth&d power level for zero seoonds time delay is adjusted to 0% RIP.

SRO Enters LCO 3.3.1.1 Action 6 and Action 10 and enters LCO 3.3.2.1 Action 37 NOTE: If performing AOP in conjunction with AOP-L1 I for an Eagle LCP failure, then actions to hard trip bistables should be delayed until Eagle system reset is atternptecL Actions to hard trip bistables must be completed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months UNLESS affected loop is restored to operable status by resetting Eagle rack.

6. NOTIFY l&C to remove failed TAVG Tloop 1om service USING appropriate Appendix:

RCS INSTRUMENT LOOP PROT

! r.ro ri.a APPENDIX NUMBER T-68--2 I A (1-4111412) 2 T-68-25 II B (1-421/422) 3 T-68-44 111 C (1-431)432) 4 T-6B-67 D (T-4411442)

9. IF automatic rod contrd is available, THEN RESTORE rod control to AUTO USING O-SO-85-i.

si;f

10. GO TO appropnate plant procedure END OF SECTION Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event when Technical Specifications are addressed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 5 Event # 2 Page 7 of 57 Event

Description:

1A Thermal Barrier Booster Pump breaker trips with a Failure of the 1 B Thermal Barrier Booster Pump to Auto Start Time Position 1 Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 2, IA Thermal Barrier Booster Pump Trip Indications available:

O-M-27-B-A Annunciators:

. O-XA-27-B-A Window B-I: RC PUMPS THRM BARRIER RETURN HEADER FLOW LOW

. O-XA-27-B-A Window B-2: RC PUMP I BARRIER Outlet FLOW LOW

O-XA-27-B-A Window B-3: RC PUMP 2 BARRIER Outlet FLOW LOW

. O-XA-27-B-A Window B-4: RC PUMP 3 BARRIER Outlet FLOW LOW

O-XA-27-B-A Window B-5: RC PUMP 4 BARRIER Outlet FLOW LOW RC PUMPS THRM BARRIER RETURN HEADER FLOW LOW

[11 CHECK CCS thermal barrier return header flow by obsevinq

[IF1-7O-81AI.

[2j IF pressure on CCS dictates, THEN

[a] START standby CCS punp.

[hI VERIFY CCS hernial barner booster EPIT operating.

[31 IF 0-X4-55-12A Window B-i 1-R490-123A CCS LIQ EFF W)N HIGH RD is darning, THEN REFER to O-AR-M12-A LC.11

[4] VERIFY CCS thermal brier isolation valves i-FCV-71i--90, 1-FCV-70-1 33 l-FCV-70-87, and 1-FCV-70-1 34 are OPEN.

[a] IF CCS to RCP thermal barrier coding odis has isolated, ThEN ENSURE Unit I CCS thermal barrier booster pump han4tches are in the stop PULL. TO LOCK position AND GO TO AOP-MO3, Loss & Co oient Cooling Water, for a loss of Component Cooling Theimal Barrier Booster Purr(s.

[C,t]

BOP Responds to ARP O-AR-M27B-A B-I.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Appendix D Reciuired Orerator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event# 2 Page 8 of 57 Event

Description:

1 A Thermal Barrier Booster Pump breaker trips with a Failure of the 1 B Thermal Barrier Booster Pump to Auto Start Time 1 Position Applicants Actions or Behavior

1. DIAGNOSE the failure:

GOTO IF...

SECTION PAGE CCS Thermal Barrier Booster Pump trip or failure 22 13 NOTE If RCP seal injection flow is lost concurrently with loss of thermal barrier coo4ing, then AOP-M.09 (Loss of Charging) takes precedence over AOP-Mi)i BOP 1. IDENTIFY and LOCK OUT affected Thermal Bamer Booster Pump.

BOP Places HS-70-1 31A Thermal Barrier Booster Pump_IA-A to STOP PTL.

2 CHECK Themial Barner isolation valves OPEN:

FOV-70-87 BOP

FCV-70-90

FCV 133

FCV-70-134 BOP & ENSURE standby Thermal Banier Booster Pump starts

4. ENSURE proper RCP seal injection:

Flowbetween8gpmandl3gpm BOP

VCT outlet temperature less than or equal to 130CF 5 MONITOR RCP Seat and Lover Beaiing BOP temperatures less than or equal to 225*F

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event # 2 Page 9 of 57 Event

Description:

1 A Thermal Barrier Booster Pump breaker trips with a Failure of the I B Thermal Barrier Booster Pump to Auto Start Time Position fl Applicants Actions or Behavior

6. MONITOR CCS radiation levels STABLE or DROPPING:

BOP

RA-90-123A, CCS Liquid Effluent Monitor

. Chen1JSt Sample

7. NOTIFY SM to evaluate OPDP-9, Emergent Issue Response.

SRO

8. INITIATE Maintenance as required.

CAUTION Automatic isolation of the thermal baffler can be caused by a heat exchanger tube leak. Realignment of the thermal baffler may cause additional leakage.

9. CHECK thermal barrier coding in service BOP to affected unit

10. GO TO appropriate plant procedure.

SRO END OF SECTION Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Evaluator Note: Proceed to the next event when ready

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario# 5 Event# 3 Page 10 of 57 Event

Description:

CVCS Letdown Pressure Control Valve Fails Closed (1-PCV-62-81)

Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 3 Letdown backpressure transmitter PT-62-81 fails high.

Indications available:

Annunciator:

1-M-6

1-XA-55-6C B-4 FS-62-82 LOW PRESS LTDN FLOW HIGH PRESSURE HIGH Indicator:

1-FI-62-82 indicates z70-75 gpm [M-6]

1-PI-62-81 indicates pressure rising from 325 to 500-550 psig [M-6]

FS-62-82 LOW PRESS LTDN FLOW HIGH PRESSURE HIGH

[1] CHECK CRT SER point number to determine flow or pressure Ngh.

[2] CHECK letdown how -fl42-82] and letdown pressure fil-62-8i1 on M-6.

[31 IF RHR not inserice, ThEN ADJUST [1PCV-62$ii USING fl-IHC-62-&IAI andlororiflce isolation valves to control pressure and flow(Max. 120 m).

[4] IF RHR letdown inser4ce, ThEN ADJUST [1-FCV-62-83] USING [1-HIC-62-83A1 and I 1-PCV 11 USING (1 -HIC-62-81 Al to control letdown pressure and flow 120 gpo).

[6] IF solid water operations in progress, ThEN ADJUST Letdown and!or ctarging to control presze.

[& IF IWCV-62-811 FAILED, THEN EVALUATE bypassing US#4G 1-50-62-i.

[71 F Unit SRO deems it cecessary, ThEN

[a] REMOVE normal letdown from serIce in accordance with 1-SO-62-1, Cheinioal and Volume Confr-al System.

[b] PLACE excess letdown in service in accordance with 1-50-62.-S. Excess Leldowt

[8] RESTORE cencfttions to normal as soon as possible.

ATC Responds to ARP 1-AR-M6C B-4.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event# 3 Page 11 of 57 Event

Description:

CVCS Letdown Pressure Control Valve Fails Closed (1-PCV-62-81)

Time fl Position Applicants Actions or Behavior Examiner Note: Annunciator 1-XA-55-6C, D-3, FS-62-93A1B CHARGING LINE FLOW ABNORMAL is an expected continuous alarm condition (setpoint: 55 gpm;).

The ATC should re-establish/maintain 6-10 gpm/RCP stable supply flow conditions.

Annunciators 1-XA-55-5B, A-3, 8-3, C-3, D-3 FS-62-XX REAC COOL PMPS SEAL LEAKOFF LOW FLOW may be actuated during transient conditions; operator response is to clear the condition.

Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when letdown flow is controlled manually by the ATC.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event # 4 Page 12 of 57 Event

Description:

Steam Gen Level Transmitter, LT 3-94 Fails low Time fl Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 4 Steam Gen Level Transmitter, LT 3-94 Fails low.

Indications available:

Annunciator:

1-M-6

I-XA-55-6B C-I LS-3-94D STM GEN LOOP 3 LOW FW FLOW LOW WATER LEVEL.

. 1-XA-55-6B C-4 LS-3-938 STM GEN LOOP 3 LOW LOW WATER LEVEL.

Indicator:

. I-LI-3-94 indicates 0% gpm [M-4]

LS-3-93B STEAM GENERATOR LOOP 3 LOW LOW WATER LEVEL

[11 CHECK steam generator evel, üica1ions rW-3-971, 1143-3-94] and 11-U-3-93L 121 IF level channel failed, THEN GO TO AOP$.06, Steam Generator fnstrwnei7t MaIfuncón.

ATC Responds to ARP 1-AR-M6B C-4 Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

I - DIAGNOSE the failure:

GOTO IF... SECTION PAGJ SIC level instrument malfunction 2.2 8

1. VERIFY OCS is maintaining BOP SIC level on program.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event # 4 Page 13 of 57 Event

Description:

Steam Gen Level Transmitter, LT 3-94 Fails low Time Position Applicants Actions or Behavior

2. EVALUATE the following Tech Specs for applicability:

. 3.31.1 (3.ai), ReaclorTrip System Instrumentation

. 3.3.2.1 (3.3.2), Engineered Safety SRO Feature Actuation System Instrumentation

. 3.3.3.5, Remote Shutdown Instrumentation

. 3.3:3.7, Accident Monitoring Instrumentation LIMITING CONDITION FOR OPERATION 3.3.Ii As a minimum. the reacr eip system umentation cthannels and ocis of Table 3.3-1 sha be OPERABlE.

APPtJCABIUTY: As shown in Table 3,3-I.

ACTION; As shown in Table 13-I

14. Main Steam Generator Water levelLow-low A. SmGeneraforWafer 3ISim. Sen. 2iSfrn.. Sen. 2ISbnSe. 1.2 9 LevelLow-low many ineach (Adverse) operate Operating Stm. Gen Stin. Sen.

SRO 12 9 LevelLow-Low (EAM) in any in each operating operating Sthi. Sen. Sho. Sen.

ACTiON 9- Wim the number of OPERABLE ChJelS One less than the Tot Nianberof Channels. STARTUP ar,dtor POWER OPERATION may oceed provided the fouowing conbons

a. The inoperable channel is placed in the tripped condhion vethn hours.

ti. For the affected protection set, the Thp line Delay for one affected steam generator (T ) is adjusted in matith the 5

T, Time Delay for rmEtiple affected steam generators (TM) within 4 haum.

c. The Minimun, Chels OPERABLE requirement met however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance tesbng of other channe4s perspedilloahon 4.3.111.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event # 4 Page 14 of 57 Event

Description:

Steam Gen Level Transmitter, LT 3-94 Fails low Time Position Applicants Actions or Behavior LIMrflNG CONDITION FOR OPERATION 3.321 The Engineered Safety Featire Actuaton System ESFAS) meiitation channels and intexfocks shown in Table 33-3 shall he OPERA&E with their frp sexnts set tent wh the ues shown in the Nominal Trip Setpoint column of Table 3.34.

APPUGABILITY: As shown in Table 13-I ACTiON:

a With an ESFAS: in5J1J7 nt3tOf channel or interlock b4 setpont Less conservative than the value shrenin the owabie Values column of TabLe 3.34, declare the channel toqperable and apply the appE<abie ACTION requirement of Table 13-3 until the channel is restored to OPERABlE status with the trip seipoint adjusted consistent with the Nominal Trip Setpoint valu With an ESFAS instrumentation channel or interlock inoperable take the ACTION shwn in Thble3.3-3.

5. TURBINE TRIP &

FEEDWATER O1ATION

a. Steam Generator 3Jlocp 2lloop in any 28oop in each 1,Z 3 17 Water Level operating loop operang loop Kigtgh ACTION 17 - With the number of OPERABLE Channels one less than the Total Number of Channels, STARTUP andior POWER OPERATION may proceed provided the fcllow*tg conditions are satisfied:

SRO a. The inoperable channel is placed inthe tripped condifion wIthin 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

b. The Minimum Channels OPERABLE requirements is met; however; the soperable channel may be bypassed fOr up to 4 hos for swvelllance testing of other channels per Specification 4.321.t

8. AUXILIARY FEEDWATER c Main 31m Sen.

Water Level.Low-Low I. Start Molcr4)riven Pumps

a. Sam Generator 3lStm. Sen. 2JSIrn. Sen. 2fSlm. Sen. 1,2.3 38 Water level-low- in any in each Law dvwse) operating operating Slrm Sen. Stm. Sen

b. Steam Gun SJStm. Sen 2tS*m. Sen. 2tStrn. Sen. 1,2,3 38 Water Level- in any in each Law-Low (EAM) operating operating Strn Sen. Stm. Sen.

c. MainSlm. Gun.

Water LevelLowLow Start Twbine Driven Pump

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event # 4 Page 15 of 57 Event

Description:

Steam Gen Level Transmitter, LT 3-94 Fails low Time Position I a. Steam Generator Applicants Actions or Behavior 3Stnt Ger. 2fSm Gen 2ISfrn. Gen. , 2,3 38 Water LevelLow- n wry in each Low (Mvise rrng operating Stim Gerr. Sbm Gen

b. Steam Gen 3IStrn. Gen 2fStm. Gert 2tStm. Gei,. 1,2.3 38 Water Level- in any in each Low-Low (EAM) operating operating Stan. Gerr. SIn,. Gerr.

ACTION 38 Wtih the number of OPERABLE channels one less than the Total Number of Charnels, STARTUP and/or POWER OPERATION may proceed provided the Itiulovitog conditions are satisfied:

pçhJ5 channel is placed in the tripped condition within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

b. For the affected protection se*.th Trip Time Delay for ass affected steam generator (Ta) is adisted to match the Trip Time Delay for mu4tipie effedied steam generators (Tn) within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

a. The Mirumurn Channels OPERABLE requwernent is nret however. the inoperable channel may be bypassed for up to 4 bows for surveancetestirg of otherthannels per Specification 43.2.1.1.

S. ENGINEERED SAFETY FEATURE ACTUATION SYSTEM tJTERLOCKS

a. Steam Generatcr Level 34oop 2lloop any 3/loop 1,2 22c P.14 loop ACTION 22 - Wtih less than the Minimum Number of ChanneIsOPERABLE, declareihe interlock inoperable and verify that all affocted channels of thefunal s listed below are OPERABLE or apply the appropriate ACTION statement(s) for ose1usctioris.

Fwctions be evabed are:

UMNG CONDITION FOR OPERATION 3.3.3.5 The remote shutdown monitoring :instmentati channels shown in Table 3,3g shall be OPERABLE with readouts displayed external to the control roorm APPUCABIIITY: MODES 1,2 and 3.

SRO ACTION:

With the number of OPERABLE reroute shutdown moniiming channels less than required by Tabs 3.34.

restore the incpsrable channel(s) to OPERABLE status within 7 days. orbs in HOT SI-IUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ,

7. Steam Generator Level NOTE 2 crnear Auxilitry 0-111(1% 1/steam F. W. Pun generator LIMITING CONDITION FOR OPERATION 3.3.3.7 The accident monitoring instrumentation channels shown in Table 3.3-10 shall be OPERABLE SRO APPLICABILITY: MODES 1,2 and 3.

ACTION: As shown in Table 3.3-10

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 5 Event # 4 Page 16 of 57 Event

Description:

Steam Gen Level Transmitter, LT 3-94 Fails low Time Position I Applicants Actions or Behavior Ia. Stern Generator Level Narrow Rane (Instrument Loops 3342-O52.-D55.-D9L- 9eflf5t0f O7-IO7-I 1O ACI1ON I NOTE:

- Also refer to the applicable acboo eirementsfrorn Tables 13-I and 3.3-3.

and LCD 3.3.3.5 since they may contain more r stricttve adions.

a. With the number of channels one less than the minimum chanse4srequiwd, restore the inoperable channel to OPERABLE status within 30 dabs or be in at least HOT STANDBY wntiin the next hours and in HOT SHUTDOWN within the nestS hours.

b. With the number of channels two less than the minimum channels requbed.

restore at least one inoperable channel to OPERABLE status wi 7 days. or be in HOT STANDBY w?thin the next C hours and in HOT SHUTDOWN within the nestS hours.

NOTE 1: Failure of ONE out of three narrow range level channels will result in OCS averaging the two remaining good signals NOTE 2: Failure of TWO level channels on any S!G will result in associated loop MFW reg valve and bypass valve control transferTing to MANUAL..

3 VERIFY failed channel bypassed for affected loop:

SOP

SiG # Detair screen on DCS indicates failed transmitter bVpassed NOTE: If performing AOP in conjunction with AOP-L1 I for Ea1e LCP failure, then actions to hard trip bistables should be delayed until Eagle system reset is attempted Actions to hard trip bistables must be completed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months UNLESS affected loop is restored to operable status by resetting Eagle rack.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event # 4 Page 17 of 57 Event

Description:

Steam Gen Level Transmitter, LT 3-94 Fails low Time Position Applicants Actions or Behavior

4. NOTIFY 1&C to remove failed Sf0 level instrument from service USING appropriate Appendix:

SIG INSTRUMENT PROT APPENDIX NUMBER CH L-3--38(L-519) II M I L-3-39 (L-518) 111 N L-3-42 (L-517) IV 0 L-3-51 (L-529) I P BOP 2 L-3-52 (L528) ill Q L-3-55 (L-527) IV R L-3-93 (L539) I S 3 L-3-94(L--538) III T L-3-97 (L-537) IV U L-3-106 (L-549) II V 4 L-3-107(L-E48) ill W L-3-i 10 (L-547) IV X NOTE: I ,2-S0-98-I contains instructions for restoration of bypassed instrument loop wten repairs are complete.

& iNITIATE maintenance on failed instrument.

BOP

& CHECK affected loop Sf0 level control in AUTO.

7 GO TO appropriate plant procedure..

SRO END OF SEC1ION Crew Performs a Crew Brief as time allows.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario# 5 Event# 4 Page 18 of 57 Event

Description:

Steam Gen Level Transmitter, LT 3-94 Fails low Time Position Applicants Actions or Behavior Nofifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when Tech Specs have been addressed..

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event# 5 Page 19 of 57 Event

Description:

Loss of Condenser Vacuum with Cond Vac Pp auto start failure Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 5, Loss of Condenser Vacuum- Leak Indications available:

. O-M-12A, C-2, 1-RA-90-119B COND VAC PMP LO RNG AIR EXH MON INSTR MALFUNC

. 1-AR-M2-C, C6, CONDENSER VACUUM LOW

Condenser Vacuum degrading (Monitored on recorder or ICS), Air in leakage increasing PS-2-78 CONDENSER VACUUM LOW

[1] VERIFY alarm via [FrR-J recorder.

(2] VERIFY required number of CCW pumps are inservice.

[3] CHECK condenser vacun e*haust on ICS using either

a. 1F2700A if 1-FCV-2-255 is closed

b. 1F2263A if 1-FCV-2-255 is cn.

(4] IF condenser vacuum ethaust flow >45 CFM, THEN ENSURE t-FCV-2-255 OPEN.

[51 IF alarm is valid, THEN GO TO AOP-S02, Loss of Condenser Vacuum,

[6] WHEN vacuum and sir inleakage are returned to normal, THEN ENSURE 1-FCV-2-255 CLOSED and ü P-AUTO.

BOP Responds to ARP 1-AR-M2B C-6 Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Examiner Note: The crew may recognize vacuum leak early and enter abnormal procedure AOP-S.02, Loss Of Condenser Vacuum, prior to alarm.

Examiner Note: The standby Condenser Vacuum Pump will fail to start automatically; manual start is available and should be manually started in response to this event.

CAUTION Turbine will :tnp automatically when condenser pressure reaches 39 to 5.4 psia.

NOTE: Highest reading operable condenser pressure instrument should be used.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event # 5 Page 20 of 57 Event

Description:

Loss of Condenser Vacuum with Cond Vac Pp auto start failure Time Position Applicants Actions or Behavior

1. MONITOR condenser pressure for tuthine trip crftefla. [Cl]

a. CHECK turbine load greater BOP fl-- or equal to 30%.

b. CHECK condenser pressure less than or equal to 27psia 2.. ENSURE all available condenser BOP cuum pumps RUNNING.

Examiner Note: Direct the Booth Operator to lower the Main Condenser vacuum malfunction when the vacuum pump has been started.

3 ENSURE condenser vacuum breaker BOP CLOSED..

CAUTION: It CCW intake blockage has occurred resulting in pump cavitation (swinging amps) or loss of suction to CCW pumps, continued CCW pump operation could result in pump damage.

4. MONITOR CCW Pump operation:

a. CHECK br any of the followrng: a. GO TO Step 5

less than two CCW Pumps RUNNING on affeded unt EM-IS]

BOP [Ci]

OR

Indication of severe intake blockage resulting in cavitation Of irrwmnent loss of CCW pump suction.

5. CHECK turbine gland seal steam supply BOP pressure between 120 psig and 130 psig

[M-2, P17-187].

6. CHECK HP steam seal steam supply BOP between 16 psia and 2(3 psia

[M-2, P1-47-189]..

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 5 Event# 5 Page 21 of 57 Event

Description:

Loss of Condenser Vacuum with Cond Vac Pp auto start failure Time Position Applicants Actions or Behavior

7. CHECK annunciator P1S-47-i 96 BOP TURBINE SEAL STEAM PRESS.

ABNORMAL, DARK. 12k window A5j

& DISPATCH an operator to perform the following:

a CHECK loop seal on vacuum breaker [Turbine Bldg. 706 elev].

b. CHECK the foflowing components:

Main Turbine rupture discs intact BOP

Condenser shell intact a Main Feedwater Pump rupture discs intact a Main Turbine exhaust hoods c VERIFY Main Steam Dump Drain Tank Ieve control operating property.

BOP 9 CHECK main turbine/generator on line

10. CHECK condenser pressure STABLE or REDUCE turbine load as necessary DROPPING to maintain condenser vacuum USING one of the following:

a AOP-CD3, Rapid Shutdown or Load BOP Reduclon (preferred)

OR

. Valve Position Umiter.

ii ENSURE control rods controlhng in AUTO.

Examiner Note: Direct the Booth Operator to stabilize Main Condenser vacuum when the load reduction has commenced.

Lead Examiner may cue next event when the CREW has stabilized plant power and condenser vacuum.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6 Page 22 of 57 Event

Description:

Plant Power Reduction Time Position Applicants Actions or Behavior Simulator Operator: No action required for Event 6, Rapid Power reduction SRO Directs performance of AOP-C.03 Rapid Shutdown Or Load Reduction.

ENSURE crew has been briefed an reactivity SRO management expectations USiNG Appendix A.

REACTMTY MANAGEMENT BRIEFiNG NOTE This appendix should be used in addition to event-based brief.

[1] ENSURE crew has been briefed on the following:

a Reason for Rapid Shutdown or Load Reduction a Load Reduction Rate:_______

. Desired final power level:______

a Reactivity Management expectations:

. Unit Supervisor shall concur with all reactivity manipulations a Ensure reactor responding as expected using diverse indications a Tavg-Tref Mismatch requirements:

a 3°F control band

5°F reactor trip criteria a Crew focus will be on reducing power in a controlled and conservative manner.

a OATC will monitor rod insertion limits and AFD lImit a Boration source:

a Crew will monitor reactor trip and turbine trip criteria using App B a CR0 will stop secondary plant equipment using App C a If time permIts review expected annunciators (ex. Computer Alarm Upper and Lower Flux Dev) a Termination Criteria (conditions requiring Reactor Trip, Turbine Trip, or condition no longer requiring rapid load reduction):

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event# 6 Page 23 of 57 Event

Description:

Plant Power Reduction Time I Position I Applicants Actions or Behavior Chooses a power reduction rate of 2% to 3% final power level of 20% and BAT SRO as the boration source.

2. NOTIFY following personnel of rapid shutdown or load reduction:

. Load Coordinator 10.11 CREW

Cliemistry

. Radiation Protection

Plant Management CREW Makes notifications as required.

3. MONITOR reactorlturbine tiip NOT required CREW USING Appendix B, Reactor and Turbine Trip Crite,1a Examiner note: Appendix B reactor and turbine trip criteria see page 27.

4. CHECK VALVE POSITION LIMIT light BOP DARK on EHC panel. [M-21 NOTE: BoraUon volumes and tiowrates listed In this procedure are recommendations and may be adjusted as necessary.

5. INITIATE boration:

a. CHECK rod control AVAiLABLE:

ATC

Control Bank D rods capable of being moved

NO dropped or misaligned rods in Control Bank 0.

5. ii. CHECK Control Bank D group posItion greater than 200 steps.

ATC

c. CHECK boration capability from BAT AVAILABLE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event# 6 Page 24 of 57 Event

Description:

Plant Power Reduction Time j Position Applicants Actions or Behavior d DETERMINE recommended bcxation vo4ume from BAT:

800 gal to reduce power from 100% to 20%

OR SRO

10 gal for each 1% power reduction (from current power level)

OR

volume recommended by Reactor Engineering.

Determines a value of boration consistent with 10 gal for each 1% power SRO reduction.

5. e. DETERMINE recommended boration flowrate from table below or from Reactor Engineering:

DESIRED RECOMMENDED RX POWER LEVEL SETTER VALUE 90% 76 80% 56 SRO 70% 46 60% 40 50% 35 40% 30 30% 25 20%orless 15

f. ENSURE concurrence obtained from ATC STA for boration volume and llowrate g ENSURE boric acid transfer pump ATC aligned to blender in FAST speed

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6 Page 25 of 57 Event

Description:

Plant Power Reduction Time Position

[ Applicants Actions or Behavior fl. ADJUST Fc l33 to estabish ATC desired flow rate ATC Adjusts FcV-62-1 38 to between 30 to 45 gpm.

f CONTROL boration flow as required ATC to inject desired boric acid vo!urne.

CAUTION: If borating from the RWST, Turbine Load Reduction Rate greater than 2% per minute COUld: result in violating Rod Insertion Limit.

6. INITIATE load reduction as follows:

a ADJUST load rate to desired value:

between 1% and 4% per minute if borating via FCV-62-138 BOP OR

. betweenl%and3%perminuteif borating via normal boration(App H)

OR

2% per minute if borating from RWST.

BOP Adjusts load rate approx 2% to 3 % per minute b ADJUST setter For desired power level BOP II RX POWER DESiRED LEVEL RECOMMENDED SETrER VALUE I 20%orless 15 6 C VERiFY boration flow established.

BOP cL INITIATE turbine load reduction by depressing GO pushbuttorL BOP Depresses GO pushbutton.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event # 6 Page 26 of 57 Event

Description:

Plant Power Reduction Time Position

[1 Applicants Actions or Behavior

e. CONTROL turbine load reduction BOP as necessary to reduce power to desired level.

7. MONITOR T-avgdT-ref mismatch:

a. CHECK T-ref indication AVAILABLE.

7. b MONITOR automatic rod control ATC maintaining T-avgIT-ret mismatch less than 3°F BOP 8. MONITOR automatic control of MFW pump speed AVAILABLE 9 STOP secondary plant equipment BOP USING Appendix C, Secondary Plant Eijuipmenf..

Examiner Note: Appendix C, Secondary Plant Equipment starts at page 28.

Examiner Note: Additional AOP-C.03 steps not included as required power reduction should be complete at or around this step.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario# 1 Event# 6 Page 27 of 57 Event

Description:

Plant Power Reduction APPENDIX B REACTOR AND TURBINE TRIP CRITERIA REACTOR TRIP CRITERIA TURBINE TRiP CRITERIA Turbine trip required or immtnent Turbine vibration exceeding 14 mIls with reactor power greater than P9 (50%) with one of the following:

Uncontrolled rod movement which CANNOT be

high vibration on multiple bearings stopped by placing rods in MANUAL (AOP-C.D1)

OR Loss of SIC level control:

abnormal noise/Vibration apparent level dropping or rising toward trip selpoint and level CANNOT be restored (AOP-S.O1)

More than one dropped rod OP-C.O1>

T-avg/T-ref mismatch CANNOT be maintained less than 5*F (refer to Step 7 or App E) 30% turbine load: <30% turbine load:

Condenser Pressure> 21 psia AND CANNOT Condenser Pressure> 1.72 psia be restored within 5 minutes AOP-S.o2) (AOP-SU2)

Any automatic reactor trip setpoint reached Any automatic turbine trip setpoint reached OR automatic trip imminent: OR automatic hip imminent:

Turbine trip above P-9 (50%)

High Stator Cooling Water temp 90CC

Safety injection OR Stator DIP 12 psig below normal a Power Range high flux 109%

Both MFPTs tripped a Power Range flux rate +/- 5% in 2 seconds

Low Auto Stop Oil pressure 45 psig

Pressurizer high level 92% High SIC level 81% narrow range

Pressurizer pressure low 1970 psig

Main Turb Bearing Oil low pressure 7psig a Pressurizer pressure high 2385 psig a Thrust Bearing Oil high pressure 60 psig a RCS low how 90% a Turbine Overspeecl 1980 rpm

RCP undervaltage 5022 kilovolts

Loss of EHC pressure

RGP underfrequency 56.0 Hz

Generator PCBs tripped.

OTAT 115% (variable)

OPT 1081% (variable)

S/C low level 10.1% [15% EAM]

a SSPS general warning in both trains

Appendix D Required Operator Actions Form ES-D-2 Op Test NoV: NRC 2012-301 Scenario # 1 Event # 6 Page 28 of 57 Event

Description:

Plant Power Reduction APPENDIX C SECONDARY PLANT EQUIPMENT

[1] ENSURE plant announcement(s) made on the following:

starting rapid shutdown (or load reduction) due to (reason)

stopping secondary plant equipment NOTE I If reactor power will be reduced below 50%, AUO should be on station at #3 heater drain tank (if possible) when 60% power is reached NOTE 2 Dispatching of AUO in Steps [2] and [3] may be performed out of sequence

[2] IF reactor power will be reduced below 50%,

THEN DISPATCH AUO with Appendix J (Unit 1) or K (Unit 2) to #3 Heater Drain Tank t] IF one MFP will be shutdown using this appendix, THEN DISPATCH AUO to OPEN MFWP recirc manual Isolation valve for MFWP to be removed from service: (N/A valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN 1 IA I-VLV-3-576 TB eL 706, Northeast corner of IA condenser IS i-VLV-3-577 TB eL 706, Northeast corner of IA condenser 2 2A 2-VLV-3-576 TB e1 706, Southeast corner of 2A condenser fl 25 2-VLV-3-577 TB el. 706, Southeast corner of 2A condenser

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6 Page 29 of 57 Event

Description:

Plant Power Reduction APPENDIX C t4 IF BOTH of the following conditions are met:

power is being reduced as directed by AOP-S.O1 (Main Feedwater Malfunctions) or AOP-S04 (Condensate or Heater Drain Malfunctions) leaving secondaiy pumps in service is desired THEN GO TO Step [8]. D

[5] WHEN turbine impulse pressure is approximately 80% or less, THEN PERFORM the following:

[a] ENSURE one Cond Demin Booster Pump STOPPED. D

[1] ENSURE associated suction valve CLOSED:

COND DEMIN OR B FCV-2-285 Lz - IY J EJ

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # I Event # 6 Page 30 of 57 Event

Description:

Plant Power Reduction

[] WHEN turbine impulse pressure is approximately 7Q-75%

THEN PERFORM the following:

[a] ENSURE one Condensate Booster Pump STOPPED.

[b] ENSURE associated CBP suction valve CLOSED:

CONDENSATE BOOSTER PUMP SUCTION VALVE CLOSED I A FCV-2-94 U OR OR FCV-2-87 U J

r FCV-2-81

[c] PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary)

1-50-213-1 Section 72 U OR

2-SO-213-1 Section 73

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O12-301 Scenario# 1 Event# 6 Page 31 of 57 Event

Description:

Plant Power Reduction

[7] WHEN turbine impulse pressure is approximately 65% or less, THEN PERFORM the following:

[a] STOP remaining two Conci Demin Booster Pumps simultaneously

[b] ENSURE suction valves CLOSED:

COND DEMIN BOOSTER PUMP SUCTION VALVE CLOSED -4 A FCV-2-290 0 B FCV-2-285 0 C FCV-2-280 0

[c] STOP one No. 3 Heater Drain pump. 0 d] STOP one No. 7 Heater Drain pump. 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6 Page 32 of 57 Event

Description:

Plant Power Reduction

[8] IF reactor power will be maintained greater than 50%,

THEN GO TO Notes prior to Step [11].

CAUTION Isolation of all three intermediate heater strings could occur if turbine is tripped prior to fully opening LCV-6-1 05A and B using Appendix 3 or K.

[91 WHEN reactor power is less than 60%

AND AUO with App J (Unit 1) or K (Unit 2) is on station at #3 Heater Drain Tank?

THEN PERFORM the following:

[a] STOP #3 Heater Drain Tank Pumps.

[b] NOTIFY AUO to perform App. 3 (Unit 1) or App. K (Unitl),

Fully Opening #3 Heater Drain Tank Bypass Valves.

[c] CLOSE isolation valves from #3 Htr Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED FCV-6-1 08 Htr Drain Tk Pump 3 to Htr String A 0 FCV-6-1 09 Htr Drain Tk Pump 3 to Htr String B 0 FCV-6-1 10 Htr Drain Tk Pump 3 to Htr String C 0

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2OI2-301 Scenario# 1 Event# 6 Page 33 of 57 LEvent

Description:

Plant Power Reduction NOTE I The following step ensures that MEW Bypass valves are avaiiab to control feedwater flow at low power.

NOTE 2 if any MFW Reg valve is in MANUAL, the associated MEW Bypass valve controller should remain in MANUAL to prevent undesired opening of bypass valve.

[101 WHEN Reactor power is less than 50%,

THEN PERFORM the following:

[a] IF all MFW Reg Valves are in AUTO, THEN PLACE MFW Byps Reg Valve controllers in AUTO.

1b IF any MFW Reg Valve is in MANUAL THEN PERFORM the following:

1) MAINTAIN MFW Bypass Req Valve in MANUAL for SIG with MEW Req valve in MANUAL.

2) PLACE MEW Bypass Req Valves in AUTO for remaining S/Ga.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario# 1 Event# 6 Page 34 of 57 Event

Description:

Plant Power Reduction NOTE I If performing this AOP to reduce power to allow shutting down one MEW pump, the affected MFWP may be removed from service at power level less than 55% (Unit 1) or 65%: (Unit 2).

NOTE 2 AFW start function on loss of both MFW pumps is inoperable when a MFW pump is RESET but NOT pumping forward. LCO 33.2.1 (Unit 1) or 3:32 (Unit 2) allows AFW start channel to be inoperable for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months when shutting down a MFWP,

[11] WHEN it is desired to remove one MEW pump from service AND power level is less than applicable limit:

turbine impulse pressure less than approximately 45%

OR a reador power less than value specified in Note I THEN PERFORM the following:

[a] ENSURE MFWP Recirc Manual Isolation valve OPEN for MFWP to be removed from service: (N/A valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN I 1A 1-VLV-3-576 TB el, 706, Northeast corner of IA condenser lB 1 -VLV-3-577 TB eT. 706, Northeast corner of IA condenser 2 2A 2-VLV-3-576 TB el. 706, Southeast corner of 2A condenser fl 2B 2-VLV-3-577 TB eL 706, Southeast corner of 2A condenser C t1] THROTTLE OPEN recirc valve in MANUAL (30-50% OPEN) for MFWP to be removed from service.

[c] PLACE speed controller in MANUAL for MEWP to be removed from service. C

[d] REDUCE speed gradually on MFWP to be removed from service.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6 Page 35 of 57 Event

Description:

Plant Power Reduction

[11] (Continued)

[e ENSURE proper loading on remaining MFWP. 0

[f] IF MFWP CANNOT be hilly unloaded with speed controller, THEN PERFORM one of the following:

NOTIFY 18CC to slowly adjust hand speed changer for affected MFWP UNTIL MFWP is fully unloaded. U OR

THRO17LE OPEN recirc valve for affected MFWP to assist in unloading MFWP U OR

SLOWLY CLOSE governor valve by bumping closed governor valve positioner (if operable) U OR

OBTAIN SRO concurrence that MFWP how is sufficiently low to allow hipping MFWR U

[g] WHEN MFWP is unloaded sufficiently, THEN TRIP affected MFWR U

[h] CLOSE recirc valve for MFWP removed from service. U

[I] CLOSE recirc valve Manual Isolation inlet valve for MFWP removed from service. U fi] OPEN drain valves for MFWP removed from service: [M-3}

[KS46-14J, MFWP A drain valves .

U OR

HS4641J, MFWP B drain valves. U

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2OI2-301 Scenario# I Event# 6 Page 36 of 57 Event

Description:

Plant Power Reduction

[12] WHEN turbine impulse pressure is approximately 45% or less, THEN PERFORM the following:

(a] STOP remaining No. 7 Heater Drain pump.

[b) CLOSE isolation valves from #7 Heater Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED FCV-6-143 Htr Drain Tk Pump 7 to Htr String A U FCV-6-163 Htr Drairi Tk Pump 7 to Htr String B 0 FCV-6--184 Htr Drain Tk Pump 7 to Htr String C 0 t13] WHEN turbine impulse pressure is approximately 30% or less, THEN PERFORM the following:

[a] ENSURE main turbine EHC controls in IMP OUT.

[b] IF #3 heater drain tank pumps are still running THEN PERFORM Step [91.

to] STOP one of two remaining Condensate Booster Pump&

(step continued on next paqe)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 6 Page 37 of 57 Event

Description:

Plant Power Reduction f13] (Continued) td] ENSURE associated CBP suction valve CLOSED:

OR FCV-2-87 I_ I FCV-2-81

[e] STOP one of three Hotwell Pumps E ffj PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary) i-SO-2/3.-1 Section 72 OR

. 2-SO-2/3-1 Section 73

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event# 7, 8, 9 Page 38 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event, 7 Loss of Offsite AC Power Indications available:

Annunicators:

1-M-3

1-XA-55-3A, E-1, PS-2-129 LOW NPSH AT MFPS

1-XA-55-3C, C-6, LS-3-171D STM GEN #4 LEVEL LOW

1-XA-55-3C, E-6, LS-3-175D STM GEN #4 LEVEL LOW 1-M-5

1-XA-55-5A, A-7, FS-3-35A STEAM GEN FEEDWATER FLOW HIGH

1-XA-55-5A, B-7, LS-3-42D STEAM GEN LVL HIGH-LOW DEVIATION 1-M-6

1-XA-55-6B, D-1, LS-3-107D STM GEN LOOP 4 LOW FW FLOW LOW WATER LEVEL

1-XA-55-6B, D-4, LS-3-106B STEAM GENERATOR LOOP 4 LOW LOW WATER LEVEL

1-XA-55-6B, D-7, FS-3-103B STM GEN LOOP 4 STEAMIFEEDWATER FLOW MISMATCH Indicators:

1-M-4

1-FI-1-103A, 103B, SG-4 FW INLET FLOW CH-1 & 2: varying feedwater flow

1-Ll-3-110, 107, 106, SG-4NR LEVEL: decreasing level Significant Resultant Alarmsllndications:

Annunciators:

1-XA-55-2C, C-7, D-7, E-7: LS-2-3A, 2-9A, 2-12A CONDENSER HOTWELL LEVEL ABNORMAL Deviations or unexpected conditions:

Increase in feedwater flow.

Deviations on feedwater regulating valves.

Main feedwater pump speed increasing.

Steam generator level dropping

Appendix D Reauired Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event # 7, 8, 9 Page 39 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment Time Position Applicants Actions or Behavior Examiner Note: following IOA performance, prior to Steps 1-4 immediate action verification, ATC/BOP surveys MCBs for any expected automatic system response that failed to occur. Upon discovery, they may take manual action(s) to align plant systems as expected for the event in progress. (Ref. EPM-4, Prudent Operator Actions)

CREW Performs the first four steps of E-O unprompted.

SRO Directs performance of E-O NOTE I Steps I through 4 are immediate action steps.

NOTE 2 This procedure has a foldout page.

I VERIFY reactor TRIPPED:

Reactor rnp breakers OPEN

Reactor trip bypass breakers DISCONNECTED or OPEN ATC

Rod bottom lights LIT

Rod posItion indicators less than or equal to 12 steps.

Neutron flux DROPPING

2. VERIFY turbine TRIPPED:

BOP

Turbine stop valves CLOSED.

3. VERIFY at least one 6.9KV shutdown ATTEMPT to start DIGs.

board ENERGIZED on this unit.

IF power CANNOT be immediately restored to at least one shutdown board B(_P on this unit, THEN GO TO ECA-0.O, Loss of All AC Power.

4, DETERMINE if SI actuated:

ATC

ECCS pumps RUNNiNG.

Any SI alarm LIT [M-4D1.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 7, 8, 9 Page 40 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment

[ Time Position Applicants Actions or Behavior 5 PERFORM ES-05, Equipment BOP Verifications WHILE continuing in this procedure.

SROIATC Continue with the performance of E-O REACTOR TRIP OR SAFETY INJECTION BOP Performs ES-O.5, Equipment Verifications go to page 51 for details SRO Addresses foldout page, see next page for details.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 7, 8, 9 Page 41 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

RCS pressure less than 1250 psig AND at least one CCP or Si pump ninning OR

Phase B isolation, THEN STOP all RCP&

EVENT DIAGNOSTICS a IF any SIG pressure is dropping uncontrolled, THEN PERFORM the following:

a CLOSE MS[Vs and MSIV bypass valves.

b IF any SIG pressure continues to drop uncontrolled, THEN PERFORM the following:

1) ENSURE SI actuated.

2) IF at least one 51(3 ts intact (51(3 pressure controlled or rising),

THEN ISOLATE AFW to faulted S!G(s):

CLOSE AFW level control valves for faulted SIG(s)

IF any AFW valve for faulted S/G CANNOT be CLOSED, THEN PERFORM Appendix E, Isolating AFW to Faulted 51(3.

3) ENSURE at least one of the following conditions met:

total AFW flow greater than 440 gpm OR

Narrow Range level greater than 10% [25% ADVI in at least one intact SIG.

a IF both trains of shutdown boards de-energized, THEN GO TO ECA-0.0, Loss of All AC Power.

TANK SWITCHOVER SETPOINTS

IF CST level less than 5%, ThEN ALIGN AFW suction to ERCW.

IF RWST level Less than 27%, THEN GO TO ES-I 3, Transfer to RHR Containment Surnp

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 7, 8, 9 Page 42 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment j Time Position Applicants Actions or Behavior

6. DETERMINE if secondary heat sink available:

a. CHECK total AFW flow a. IF SIG narrow range level is greater than 440 gpm. less than 10% [25% ADVI in all S/Gs.

THEN START AFW pumps and AliGN valves as necessary to raise AFW Ilow greater than 440 gprn.

ATC

b. CHECK narrow range level b. MAINTAIN total teei flow greater than 10% [25% ADV] greater than 440 gpm in at least one SIG. UNTIL narrow range level greater than 10% [25% ADVI in at least one S/C&

C. CONTROL feed flow to maintain narrow range level between 10% [25% ADV] and 50%

in intact or ruptured SIGs.

7. CHECK if main steam lines should be isolated:

a. CHECK if any of the following conditions have occurred:

Any S/G pressure less than 600 psig OR

Any S/G pressure dropping ATC UNCONTROLLED OR

Phase B actuation.

b. ENSURE MSIVs and MSIV bypass valves CLOSED.

c. ENSURE applicable Foldout Page actions COMPLETED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 7, 8, 9 Page 43 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment Time A Position Applicants Actions or Behavior

8. CHECK RCP trip criteria:

a. CHECK the following:

RCS pressure less than 1250 psig ATC AND

At least one CCP OR SI pump RUNNING.

b. STOP RCPs.

9. MONITOR RCS temperatures: IF temperature less than 547°F and dropping,

IF any RCP running, ThEN THEN PERFORM the following:

CHECK T-avg stable at or trending to between 547°F and 552°F. a. ENSURE steam dumps and atmospheric reliefs CLOSED.

OR

b. IF cooldown continues,

lFRCPsstopped, THEN THEN CONTROL total feed flow:

CHECK T-cold stable at or trending ATC/BOP 1) ENSURE total AFW flow to between 547°F and 552°F.

less than or equal to 600 gpm.

2) MAINTAIN total AFW flow greater than 440 gpm UNTIL narrow range level is greater than 10% [25% ADVI in at least one SIG.

c. IF cooldown continues after AFW flow is controlled, THEN CLOSE MSIVs and MSIV bypass valves.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event # 7,8,9 Page 44 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment Time Position Applicants Actions or Behavior

10. CHECK pressurizer PORVs, safeties, and spray valves:

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

ATC c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

11. DETERMINE if SIC secondary pressure PERFORM the following:

boundaries are INTACT:

a. MONITOR status trees.

CHECKaII SIG pressures ATC CONTRO{I.ED or RISING. b. GO TO E-2, Faulted Steam Generator Isolation.

CHECK all SG pressures greaterthan 140 psig.

Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via ICS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT I STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

When a RED Path for Containment is evident on ICS, the SRO will transition to FR-Z.1, go to page 49 for details.

CAUTION Unisolating a faulted SIG or secondary break should NOT be considered UNLESS needed for RCS cooldown.

CHECK MSIVs and MSIV bypass valves CLOSE valves CLOSED.

IF any MSIV OR MSIV bypass valve CANNOT be closed, THEN CLOSE valve USING EA-1-i, Closing MSIVs Locally.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event# 7,8,9 Page 45 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment Time Position Applicants Actions or Behavior 2 CHECK ANY SIG secondary pressure boundary INTACT:

BOP

Any SIG pressure CONTROLLED or RISING.

3 IDENTIFY Faulted SJG(S)

a. CHECK S1G pressures:

. Any S/G pressure DROPPING SRO in an uncontrolled manner.

OR

Any SG pressure less than 140 psg.

SRO Identifies #4 SIG as faulted.

CAUTIONS

secondary heat sink requires at least one SIG avatlable.

If the TD AFW pump is the only source of feed flow, isolating both steam supplies will result in loss of secondary heat sink.

4. ISOLATE Faulted S/Gts)

a. ENSURE MF\N isolated to faulted SIG(s) b any of the following:

BOP fdVti isolation valve CLOSED IM-4]

OR

. feedwater regulating valve and bypass valve CLOSED [M-3j.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event # 7, 8, 9 Page 46 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment Time Position Applicants Actions or Behavior

b. ENSURE AFW isolated to faulted SIC(S):

BOP

CLOSE MDAFWLCV

CLOSETDAFWLcVard PLACE in PULL TO LOCK.

c. CHECK SiC #1 or #4 faulted.

BOP

d. CLOSE TD AFW pump steam supp4y from faulted SIC FCV-i-1 5 (SIC #1) or FCV-I-1 6 (SIC #4).

4. e. VERIFY SIC blowdown valves CLOSED.

BOP

t. VERIFY atmospheric relief CLOSED.

5. CHECK CST level greater than 5%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # 7, 8, 9 Page 47 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment Time

[ Position Applicants Actions or Behavior

& VERIFY secondary radiation NORMAL:

a, CHECK secondary radiation NORMAL USING Appendix A, Secondary Rad Monitors.

(App. A also contained in ES-O.5)

b. NOTIFY Chem Lab to take 51(3 activity samples.

c. WHEN Chem Lab is ready to sample SIGs, THEN PERFORM the following:

1) ENSURE FCV-15-43 Blowdown Flow Control valve CLOSED.

2) ENSURE Phase A signal RESET.

3) OPEN b4owdown isolation valves.

d. NOTIFY RADGON to survey main steam lines and SIG blowdown.

e. WHEN SIG samples completed, ThEN CLOSE blowdown isolation valves.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event# 7,8,9 Page 48 of 57 Event

Description:

Loss of Offsite AC Power, Manual AFW Initiation, Loop #4 SG Feed Line Break Inside Containment Time Position Applicants Actions or Behavior

7. CHECK SI termination criteria:

a RCS subcoollng based on core exit TICs greater than 40°F.

b. Secondary heat sink:

a Narrow range level in at least one Intact S/G greater than 10% [25% AD?]

OR a Total feed flow to intact SIGs greater than 440 gprn C. RCS pressure stable or rising.

CL Pressurizer level greater than 10% 10% ADV].

e.. GO TO ES-I .1. SI Termination, Lead Examiner may terminate the scenario at E-2 Step 7.e, SI Termination criteria determination.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # I Event # 6, 7, 8 Page 49 of 57 Event

Description:

FR Z.1 and FR-P.1 Actions Time fl Position Applicants Actions or Behavior FR-Z.1 Actions NOTE If this procedure has been entered for an orange path and performance of ECA-1 1 (Loss of RHR Sump Recirculation) is required, FR-Z1 may be performed concurrently with ECA-1 I 1 MONITOR RWST level ATC/BOP greater than 27%.

2. VERIFY Phase B valves CLOSED:

ATC/BOP Panel 6K PHASE B GREEN

Panel 6L p:HASE B GREEN.

3 ENSURE ROPe STOPPED.

ATC/BOP

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event# 6,7,8 Page 50 of 57 Event

Description:

FR Z.1 and FR-P.1 Actions Time Position Applicants Actions or Behavior 4 DETERMINE if this procedure should be exited:

a. CHECK for faulted SIG:

Any SIG pressure DROPPING in an uncontrolled manner OR

Any SJG pressure less than 140 psig.

b. CHECK containment pressure less than 12 psig, ATC/BOP

c. CHECK at least one containment spray pump RUNNING and deilvering flow.

d. CHECK at least one containment air return fan RUNNiNG.

e. RETURN to procedure and step in effect.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event# ES-0.5 Page 51 of 57 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior ES-O.5 Actions BOP 1. VERIFY DIGS RUNNING.

BOP 2. VERIFY DIG ERCW supply valves OPEN.

BOP a. VERIFY at least tour ERCW pumps RUNNING.

4 VERIFY GS pumps RUNNING:

Pump lA-A (2A-A)

BOP Pump 18-8(28-8)

Pump C-S.

BOP 5. VERIFY EGTS fans RUNNING.

BOP 6. VERIFY generator breakers OPEN.

T NOTlFYatleasttwoAUOstorepoft SOP to MCR to be available for local actions.

B. VERIFY AFW pumps RUNNING:

SOP MDAFWpumps b.. TD AFW pump.

NOTE AFW level control valves should NOT be repositkned it manual action has been taken to control 510 levels, to estabhsh flow clue to failure, orto isolate a faulted SIG.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # 1 Event # ES-0.5 Page 52 of 57 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

9. CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

BOP b. VERIFY TD AFW LCVs OPEN.

c. VERIFY MD AFW pump recirculation valves FCV-3-400 and FcV-3-401 CLOSED.

10. VERIFY MFW Isolation:

a CHECK MFW pumps TRIPPED.

b. ENSURE the following:

BOP

MFW regulating valves CLOSED

MFW regulating bypass valve controllers in MANUAL with output ZERO

MFW isolation valves CLOSED.

Ii. MONITOR ECCS operation:

a, VERIFY ECCS pumps RUNNING:

CCPS

R pumps BOP

Slpumps

b. VERIFY CCP 110w through CCPIT.

c. CHECK RCS pressure less than 1500 psig.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: _NRC 2012-301 Scenario # 1 Event # ES-0.5 Page 53 of 57 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior d.. VERIFY Si pump flow.

e. CHECK RCS pressure e. GO TO Step 12.

less than 300 psig.

f. VERIFY RHR pump flow.,

12. VERIFY ESF systems ALIGNED:

a Phase A ACTUATED:

PHASE A TRAIN A alarm [iT

[M.-6C, 85]

PHASE A TRAIN B alarm LIT

[M-6C, 86]..

b. Cntmt Vent Isolation ACTUATED;

CNTMT VENT ISOLATION TRAIN A alarm LIT [M-6C, C5[

CNTMT VENT ISOLATION TRAIN B alarm LIT [M-6C, C61.

c. Status monitor panels:

BOP

6C DARK 6D DARK 6E LIT OUTSIDE outlined area

611 DARK

6J:LIT

d. Train A status panel 6K:

CNTMT VENT GREEN

PHASE A GREEN

e. Train B status panel 6L:

CNTMT VENT GREEN

PHASE A GREEN

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-301 Scenario # Event# ES-O.5 Page 54 of 57 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

13. MONITOR for containment spray and Phase B actuation:

a. CHECK for any of the following:

Phase B ACTUATED OR

Containment pressure greater than 2.8 psig.

1. VERIFY containment spray INITIATED:

1) Containment spray pumps RUNNING.

2) Containment spray header isolation valves FCV-72-39 and FCV-72-2 OPEN.

3) Containment spray recirculation valves to RWST FCV-72-34 BOP and FCV-72-13 CLOSED.

4) Containment spray header flow greater than 4750 gpm per train.

5) Panel 6E LIT.

c. VERIFY Phase B ACTUATED:

PHASE B TRAIN A alarm LIT

[M-6C, A5].

PHASE B TRAIN B alarm LIT

[M-6C, A6].

d. ENSURE RCPs STOPPED.

e. VERIFY Phase B valves CLOSED:

Panel 6K PHASE B GREEN.

Panel 6L PHASE B GREEN.

f. WHEN 10 minutes have elapsed, THEN ENSURE containment air return fans RUNNING.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # ES-0.5 Page 55 of 57 Event

Description:

Equipment Verifications Time H Position Applicants Actions or Behavior NOTE The continuous action in Step: 14 remains applicable if containment pressure rises above t5 psIg after ES-O.5 is completed.

14. MONITOR if containment vacuum relief isolation valves stould be closed:

BOP a CHECK containment pressure a. GO TO Step 15.

greater than 1.5 psig,

15. CHECK secondary and containment fad monitors USING the following:

BOP

Appendix A, Secondary Rad Monitors a Appendix 6, Containment Rad Monitors.

APPENDIX A SECONDARY RAD MONITORS

1. IFsloccurredonunitl.

ThEN CHECK following rad monitors induding available trends prior to isolation:

Condenser exhaust recorder 1-RR-9O-i 19 SIG blowdown recorder 1-RR-90-120

Unit 1 Main steam line rad monitors [1M-3O]

Post-Accident rad recorder 1-RR-90-2686 points 3 (blue). 4 (violet), 5 (black), and 6 (turquoise).

[1-M.-31 (back of 1 -M-30)J

3. NOTIFY Unit Supervisor whether secondary radiation is NORMAL or HIGH

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # 1 Event # ES-0.5 Page 56 of 57 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior APPENDIX B CONTAINMENT RAD MONITORS

1. IFSloccurredonlJnjti.

THEN CHECK following rad monitors:

BOP

. Upper containment post-accident ract monitors 1-RM-90-27iA and 1-RM-90-272A NORMAL [i-M-30]

Lower containment post-accident rad monitors 1-RM90-273A and I -Rtvl-90-274A NORMAL [1-M-30]

Containment Tad recorders I-RR90-1 12 and 1-RR-90-106 NORMAL [0-M-12] (prior to isolation).

16. WHEN directed by E-0.

THEN OP PERFORM Appendix 0, Hydrogen Mitigation Actions.

17. CHECK pocket sump pumps STOPPED:

[M-15, upper left corner]

BOP Bldg Aux Floor and Equipment Drain Sump pump A

. HS-77-41 1, Rx Bldg Aux Floor and Equipment Drain Sump pump B..

1& DISPATCH personnel to perform BOP EA-0-1. Equipment Checks Following ESE Actuation

19. ENSURE plant announcement has been BOP made regarding Reactor Trip and SL

20. PERFORM Appendix E, Spent Fuel BOP Cooling Actions, as time permits.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario # I Event # Page 57 of 57 Event

Description:

Crftical task Critical Tasks: Critical Task Statement

1. Isolate AFW Flow to #4 Steam Generator Prior to completing E-2 step 4.

2. Manually start the lA-A or I B-B Motor Driven Auxiliary Feed pumps and establish the minimum required AFW flow rate to the SGs before transition out of E-O.

ML120690593

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