ML13274A587

Initial Exam 2012-302 Draft Simulator Scenarios

ML13274A587
Person / Time
Site:	Sequoyah
Issue date:	09/27/2013
From:	NRC/RGN-II
To:	Tennessee Valley Authority
References
Download: ML13274A587 (209)

Text

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SIMULATOR SCENARIO I

Appendix 0 Scenario Outline Attachment I Facility: Sequoyah Scenario No.: 1 Op Test No.: 201 2-302 Examiners: Operators:

Initial Conditions: Unit I is in MODE 1, -100% Reactor Power, EOL.

Turnover: Maintain current conditions, currently in 0-GO-5 Section 5.2, At Power Conditions. 1 B EDG is OOS.

Target CTs: Energize at least one 6.9 kv Shutdown Board by resetting the 1A EDG LO relay prior to completing step 8 of ECA-0.0.

Manually establish ERCW flow to the required EDG prior to completing step 8.e of ECA-0.0.

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

1. CV25A l-ATC/SRO 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.

2. RXO7A l-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 T -RO and stop the RCS depressurization using immediate operator actions and AOP 1.04. The SRO will enter LCO 3.2.5.b; 3.3.1.1 Action 6 and LCO 3.3.2.1 Action 17.

3. 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 enters LCO 3.1.3.1 Action C, 3.1.3.2 Action C, 3.1.3.5 Action A and 3.2.4 Action A.

4. R-ATC The crew will reduce power in response to the dropped rod using AOP-C.03 N-BOPISRO

5. RX24 l-BOP/SRO The sensing line to Feed Water Header Pressure Transmitter PT-3-1 fails resulting in the DCS causing an overfeed condition. The BOP will manually control the FWCS to maintain Steam generator levels using AOP-S.01.

6. EDO1 M-All A major grid disturbance results in a Loss of Offsite Power and a Reactor Trip.

. Additionally, the 1A EDG fails to AUTO-START. The Crew responds using E-0 EGO.jA and transitions to ECA-0.0. The crew will manually start the IA EDG by resetting the lockout relay to restore power to the 1A 6.9 Shutdown Board.

7. RW19A C-BOP When the IA EDG starts, the 1A EDG ERCW cooling valve FCV-67-68 fails to auto open. The BOP will manually open FCV-67-68 to restore cooling flow to the 1A EDG.

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

Appendix D Scenario Outline 2012-301 Scenario I Summary EVENT I 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 2 When directed by the lead examiner, Pressurizer Pressure instrument PT 68-340 will fail high resulting in pressurizer spray valves opening. The ATC will manually close the spray valves and stop the RCS depressurization using immediate operator actions and AOP-l.04. The SRQ will enter LCO 3.2.5.b; 3.3.1.1 Action 6 and LCO 3.3.2.1 Action 17 EVENT 3 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 enters LCO 3.1.3.1 Action C, 3.1.3.2 Action C, 3.1.3.5 Action A and 3.2.4 Action A.

EVENT 4 The crew will reduce power in response to the dropped rod using AOP-C.03.

EVENT 5 When directed by the lead examiner, the sensing line to Feed Water Header Pressure Transmitter PT-3-1 fails resulting in the DCS causing an overfeed condition. The BOP will manually control the FWCS to maintain Steam generator levels using AOP-S.01.

EVENT 6 When directed by the lead examiner, A major grid disturbance results in a Loss of Offsite Power and a Reactor Trip. Additionally, the IA EDO fails to AUTO-START. The Crew responds using E-0 and transitions to ECA-0.0. The crew will manually start the 1A EDO by resetting the lockout relay to restore power to the 1A 6.9 Shutdown Board.

EVENT 7 When the 1A EDG starts, the 1A EDO ERCW cooling valve FCV-67-68 fails to auto open. The BOP will manually open FCV-67-68 to restore cooling flow to the 1A EDO.

The scenario terminates as directed by the Lead Examiner upon completion restoration water flow to the 1A EDG EOP Flowpath E-0 ECA-0.0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 1 Page 1 of 44 Event

Description:

CVCS Letdown Pressure instrument PT-62-81 fails low Time H Position fl Applicants Actions or Behavior Booth Instructor: When directed, initiate Event I CVCS Letdown Pressure instrument PT-62-81 fails low.

Indications available:

• Annunciator XA-55-6C Window C-4 Indicator I-Fl-62-82 indicates zO gpm [M-6]

• Indicator 1-Pl-62-81 indicates pressure lowers to 0 psig [M-6]

TS42-75 LOW PRESSURE LETDOWN RELIEF TEMP HIGH

[1] MONITOR letdown pressure on fi-P1-62ait.

121 IF fi-PCV32-&11 sCIosed, THEN TAKE manua confro of 11-PCV-62-811 and RESTORE norma letdown

[3] MONITOR low press letdown relief tailpipe temp on

[iTI62-75I.

[4] MONITOR UCT and FlU 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 RespondstoarrnungARPi-AR-M6C, 9__ -

ATC Places HIC-62-81 Letdown Pressure Pressure Control to MANUAL and lowers output.

Examiner Note: If normal letdown flowpath remains in service, 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 letdown flow is controlled.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 1 Event# 2 Page 2 of 44 Event

Description:

PT 68-340 Fails High Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 2 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 I-M-6

• I-XA-55-6A Window C-5, PS-68-340A PRESSURIZER HIGH PRESSURE Indications I-M-5

• I-PI-68-334, 323, 322 RCS PZR PRESS indicators decreasing Significant Resultant Alarmsllndications:

1-M4

• I-XI-68-340B & 340D RED indicating lights illuminated indicating Pzr Spray Valves open PS-68-340F1G PRESSURIZER PRESS ABOVE REF SET POINT

[11 CHECK pressurizer pressure f2] IF channel failed, THEN GO TOAOP-L04., Pressurizer Instuiment Malftnctict

[3 IF pressurizer pressure high, THEN PERFORM the felloirig:

[i*] ENSURE pressurizer heaters OFF..

[bi ENSURE pressurizer spray valves OPEN.

tal AWUST plant parameters as necessay.

[41 EVALUATETS3.3.1, 332, 3335.

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 I -AR-M5A, B3

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-302 Scenario # 1 Event # 2 Page 3 of 44 Event

Description:

PT 68-340 Fails High Time Position I Applicants Actions or Behavior NOTE: It spray valve is open due to pressure instrument failure, then Section 23 is the appropriate ently point I. DIAGNOSE the failure:

rGOTo IF...

SECTION PAGE Pressurizer Pressure Instrument OR Controller Malfunction 23 I 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) anchor P1C-8-3408 (Loop 2).

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 1 Event # 2 Page 4 of 44 Event

Description:

PT 68-340 Fails High L Time Position Applicants Actions or Behavior

2. MONITOR pressurizer pressure stable or RESTORE pressurizer pressure trending to desired pressure. USING manual control of the following:

. PIC-68-340A, Master Pressure Controller.

OR ATC

. PZR Spray controllers PIC-68-340D (Loop 1) and/or PIC-68-340B (Loop 2)

OR

. Pressurizer Heaters.

ATC - May energize additional Pressurizer heaters. . -.

NOTE: Appendix L shows layout of PZR pressure control for operator rererence.

3. CHECK PI-68-340A NORMAL PERFORM the lollowing:

a. ENSURE PRESS CONTROL SELECTOR switch XS-68-3400 in PT-68-334 & 323.

Ii ENSURE LOOP TAVG ST REC)SEL selector switch XS-68-25 ATC in Loop Z 3, or4.

c. ENSURE PRESS REC CHANNEL SELECTOR XS-68-3408 in PT-68-334, PT-68-323, or PT-68-322.

d.. GO TO autcn prior to Step 8 Places PRESS CONTROL SELECTOR switch XS-58-340D in PT-68-334 &

.: ATC  :

H 323. .

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 Model or 2.

ATC

b. MONITOR core thermal power far unexpected changes.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # Event # 2 Page 5 of 44 Event

Description:

PT 68-340 Fails High Time Position 1 Applicants Actions or Behavior

9. EVALUATE The fbhowing Tech Specs for appIicabHt:

a 3.2..5 DNB Parameters

. 3.3.11 (3.3.1), Reactor Trip System SRO Instrumentation a 3.3.21 (3.3.2), ESF Actuation System Instrumentation a 3.3,3.5 Remote Shutdown Instrumentation 32.5 The fofiowing DNB reated peramterssba bemainizinedwin the siwnon Table 12$:

a. Reactor C lantSstem (RCS)T

b. Pressurizer Pressure

c. RCSTotl Flow Rate APPliCABILITY: MODE I ACTION:

With any of the abo,e parameters exewiing s Init, rewore the paameter to within s Iimft within 2 k rs or reduce THERMAL POWER to less than 5% of RATED THERMAL POWER whhin the next SRO LiMITS 4100ps l PARAMETER Ooeraiion Reactor Cooltt System T ressurizer Pressure 2220 psia Reactor Coolant System Fire 12-I TotI Flow LIMNG CONDITION FOR OPERATION 3.3.1.1 As a minimum, the reactor top system entatioo channels. andtoedocka of Table 3.3-1 shati he OPER41E.

APPUCABIIJTY: As shown in Table 3.3-1 SRO ACTION:

As shown inTable 3.3-I.

. Pressurizer Pressure.Low 4 2 3 1,2 6 ID. Pressurizer PreasureH4% 4 2 S 1,2 6

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-302 Scenario # 1 Event# 2 Page 6 of 44 Event

Description:

PT 68-340 Fails High Time Position Applicants Actions or Behavior ACTION 8- WIth the number of OPERABLE chnels one less than the Total number of Channels, STARTUP andior POWER OPERATION may proceed provided the fcaothicondiiions are safsfled:

The inoperaNe channel is placed in the tripped ondeort idthe8* hours.

b. The Mirilnum Channels OPERABLE requirement is met however, the inoperable channel may be bypassed for up to 4 hra for surveIance testhg of otherdannels per Spe ficailon 4.3.1.t1.

UMNG CONDITION FOR OPERATION 3 32.1 The Engineered Safely Featu Actuabon Sstm (ESFAS) instrurnenlachn dianaelsaM infedos shown in Table 3.3-3sba5 be OPERABLE with ther tr a setosisiwitwab the vabies al-rowe in the Nominal Trip Seipaint column of Table 3.34.

APCABIIfTY: As shown in Table 33-3.

ACTION:

a. an ESFAS insinwientation channel or interlock trip setpotht tess conservat e than the value shown in the P.llowable vabree column ciTable 3.3-4, dede the dwnnel inopetable y the appEcable ACTION requirement of Table 3.3-3 until the dssresel Is restored to and app 1

OPERA&E stsius with the trip a chit adjusted cortatsierit with the Norolnat Trip Selpoint yalue.

b. With en ESFAS Insimmentaton channel or interlock inoperable. take the ACTION shown in Table 3.34.

SRO

1. SAFETY INJECTION, TURBINE TRIP AND FEEDWATER ISOLATION

d. Pressurizer Pressure- 2 2 1,2,3 17 ACTION 17 - With the number of OFERA&E Channels one less than the Total Number of Channels, STARTUP andInt POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

in. The Minimum Channels OPERABLE requirements is met: however, the inoperable channel may be bypassed for up to4 hours for surveillance testing of other channels per SpecifIcation 4.3.2.1.1.

10. CHECK PZR PRESS arid 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-S8-340A Output Percent Meter is less than 40%.

b, ENSURE PZR PRESS ControIIer PZR SPRAY controller, and PZR NTRS in AUTO.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-302 Scenario # 1 Event # 2 Page 7 of 44 Event

Description:

PT 68-340 Fails High Time Position N Applicants Actions or Behavior NOTE: If performing AOP in conjunctkn with AOP-l.i I for an Eagle LCP failure, then actions to hard trip bistabies should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> UNLESS affected loop is restored to operable status by resetting Eagle rack.

11. REMOVE failed pressurizer pressure channel from service:

a. CHECK any pressurizer pressure a. IF all channels are OPERABLE, channel INOPERABLE. THEN GO TO Step 12.

b. CHECK QTT setpoint on affected b. GO TO Substep 11.d.

channel NORMAL.

11 d. IF any of the following conditions exists:

. transmitter signal failed (entire instrument loop affected CREW including OTAT pressure input)

OR

. OTAT pressure input potentially affected or status CANNOT be determined, THEN PERFORM applicable appendix:

PZR PRESSURE CHANNEL APPENDIX INSTRUMENT P-68-340 (P-455) I A 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 Pressurizer Pressure control is in AUTO and Tech Specs are identified

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 1 Event # 3 Page 8 of 44 Event

Description:

Dropped Rod Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 4 Dropped Rod.

IndicationslAlarms Annunciator:

I-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

• I-AR-M4-B, E3, NIS POWER RANGE CHANNEL DEVIATION

• I-AR-M4-B, B3, NIS POWER RANGE UPPER DETECTOR HI FLUX DEVN OR AUTO DEFEAT (Later)

. I-AR-M4-B C3, NIS POWER RANGE LOWER DETECTOR HI FLUX DEVN OR AUTO DEFEAT (Later)

Indications available:

1-M-4

• I Rod Bottom Light illuminated on M-4 IRPI Display FULL LENGTH RODS RODS AT BOTTOM

[1] CHECK rod positioi.

2] IF nre than one rod drops. THEN TRIP the reactor and GO TO E-O, Reactor Thp or Safety in-

[31 IF a single rod dropped, THEN GO TO AOP-C0i, Rc Contrct System Maffunstions

[41 IF RPI malfunction or failure, THEN GO TO AOP-C0i, Rod Control System Matfandions.

[51 IF dropped rod occws or rod posItion indication is the mafftacbon, THEN REFER TO TednicaI Specifications 324, 31.11, 1135. and 311.

BOP Responds to ARP I -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 2012-302 Scenario # Event # 3 Page 9 of 44 Event

Description:

Dropped Rod Time Position Applicants Actions or Behavior

1. DIAGNOSE the failure:

GOTO IF... SECTION PAGE Dropped shutdown!control rod(s) 2.2 10 with reactor initially in Model or 2 NOTE: Step I is an immediate action step t PLACE rod control in MAN ATC 2. VERIFY ONLY ONE rod dropped.

NOTE: It 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 (ii Mode 2 has been entered). [C.2]

ATC

- MONITOR reactor power greater than 5%

4. REDUCE load to control Tvg:

a. MONITOR T-avg greater than 541°F.

(LCO 3.1.1.4)

BOP

b. CHECK main turbine loaded.

c. REDUCE turbine load to establish Tg within 3°F of T-ref..

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-302 Scenario # 1 Event # 3 Page 10 of 44 Event

Description:

Dropped Rod

[ Time Position Applicants Actions or Behavior

& MONITOR Quadrant Power Tilt Ratio (QPTR) less than I 09 USING one of the following:

a ICS ATC OR

• OS1-NUC-OOti-i33.O, Quadrant Power Tilt Ratio.

6 EVALUATE the following Tech SpecsITRM for applicability:

a 3.1.1.4, Minimum Temperature for Criticality a 3.1.3.1, Movable Control Assemblies, Group Height SRO a 3.1.3.2, Position indication Systems -

Operating a 31.3.5, Shutdown Rod Insertion Limit a 31.3.6,, Control Rod Insertion Limits a 3.2, Power Distribution Limits (entire section) urne conio FOR onoi 3.1.3.1 .AIlfudl tength hutdom and control) rd slstfl be OPERABLE and p ondithmn +/- 12 steps (nticated psttion) of their group step intedemand posiion.

APPLIGABILITY: MODES 1 and 2 AC1ION:

c. With onefd ength rod misolgned ftcro its gronp step ter demand heiit by more than SR0 +/- 12 steps (in&ated position). POWER OPERAIIOM rnayoontinueproided that withfr one honreither

1. The rod is restored within the above aUqment requiremenLs. or

2. The remander &the rods si the: group wtih the mis ed rod are aligned to within +/-

12 steps of the ovsaEed rod while maints n the rod suence and nsethon li,ft oWcatton 3.1.3.8. The ThERMAL POWER level 5hafl be restitoted pursuant to 3peoifcation 31.3.6 during subseent operathm. or I The rod is declared inoperable and the SHUTDOWN MARGIN reqementof Speoifation 3.1.1.1 is satisfied. POWER OPERATION may then crinthue provided that

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Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario# 1 Event# 3 Page 12 of 44 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 hour UNLESS dropped rod can be restored in one fouL (LCO 31 3. 1 action .c)

7. PERFORM the following to comply with LCO3t3i:

a. INATE power reduction to less than 75% USING one of following:

a AOP-C03, Rapid Shutdown or Load Reduction SRO OR

• 0-GO-S. Normal Power Operation.

b. VERIFY adequate Shutdown Margin wiThin 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and once eveiy 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> USING Si-NUC-0O0-O3&0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 1 Event # 4 Page 13 of 44 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior Simulator Operator: No action required for Event 4, Rapid Power reduction 1

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

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

[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:

• 3G control band

• 5°F 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

• Boration source:

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

• CRC 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 Op Test No.: NRC 2012-302 Scenario # 1 Event # 4 Page 14 of 44 Event

Description:

Rapid Power Reduction Time N Position Applicants Actions or Behavior 2.. NOTIFY following personnel of rapid sFiutdown or load reduction:

. Load Coordinator [Cii CREW

• cns

. Radiation Protection

. Plant Management CREW Makes notifications as required.

I MONITOR reactor/turbine tilp NOT required CREW USING Appendix B, ReactOr and Turbine Trip Critenfa Examiner note: Appendix B reactor and turbine trip criteria see page 21 NOTE: Step 4 should be handed off to opposite unit or extra operator (if available)

If NO operator is available, notifications should be performed concurrently with subsequent steps (when time permits)

& ENSURE following personnel nofthed of rapid shutdown or load reduction: [Cii

• Balancing Authority (Load Coordinator)

(751-7547).

CREW

. Chemistry

• Radialion Protection

• Plant Management NOTE: oraticn volumes and tlowrates listed in this procedure are recornmendal ions and ma be adjusted as necessary 5 iNITIATE boration:

a. CHECK rod control AVAILABLE:

ATC

• Control Bank 0 rods capable of being moved

• NO dropped or misaligned rods in Control Bank D

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 4 Page 15 of 44 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior 5 b. CHECK Control Bank D group position greater Than 200 steps ATC

c. CHECK boration capability from BAT AVAILABLE.

d DETERMINE recommended boration volume from BAT:

• 8C0 gal to reduce power from 100% to 20%

OR SRO a 10 gal for each 1% pOwer reduction (from current power level)

OR

. volume recommended by Reactor Engineering.

.SRO Determines 250 gal to reduce power from 1 00% to 75%..

5. e. DETERMINE recommended borat;on tiawrate from table below or from Reactor Engineering:

SRO LOAD REDUCTION BORATION RATE(%lmin) FLOWRATE 2% 30 gpm 3% -45 gpm

f. ENSURE concurrence obtained from ATC STA for boratlon volume and fiowrate

g. CHECK the following conditions met:

a normal boration flowpath (blender)

AVAILABLE ATC a desired load reduction rate is less than 4% per minute a time is available for normal boration.

h. INITIATE normal baration ATC USING Appendix H

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 4 Page 16 of 44 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

i. CONTROL boration flow as required ATC to inject desired boric acid volume Examiner note: Appendix H Actions are listed in the following steps.

APPENDIX H NORMAL BORATION

[1] RECORD desired boration volume and flowrate: 0 ATC Volume (gal)

Flowrate (gpm)

ATC [2] PLACE [HS-62-140A] Makeup Control to STOP position ATC Places HS-62-140A to STOP.

3] PLACE IHS-62-140B1 Makeup mode selector switch ATC in BORATE position.

NOTE Boric Acid controller setting is twice the desired flow rate Maximum Boric Acid flow is 45 gpm 141 ADJUST [FC-2-1 391 BA flow confrofler setpoint ATC for desired flow rata 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario# 1 Event# 4 Page 17 of 44 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

[7] ENSURE boric acid transfer pump aligned to blender ATC j FAST speed C

18] IF desired boric acid flow rate NOT obtained, THEN ADJUST one or both of the following as necessary:

ATC

• IFC-62-1 391 BA flow controller LI

. recirculation valve for BAT aligned to blender. LI ENSURE desired boric acid flow indicated on Fl-62-1 39.

[10] RECORD time when boration flow established: LI Time:

[11] WHEN required boric acid volume has been added AND control rods are above low-low insertion limit, THEN ATC PERFORM the following:

[a] PLACE [HS-62-140A1. 1akeup Control to STOP position. U

*ATC Places HS-62-140A to STOP.

[b] ENSURE IFC-62-1421, Primary Water to Blender Flow A TC Controller in AUTO with dial indicator set at 35%. 0

[C] ADJUST IFC-62-1391, Boric Acid Flow Controller to ATC desired blend soluUon USING Tl-44 Boron Tables. LI Td  : Places Flc-6219 to I gpm. .*

Apoendix D Reauired ODerator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 1 Event# 4 Page 18 of 44 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

[d] PLACE IHS-62-140B1, Makeup Mode Selector ATC Switch in AUTO position. LI 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 if 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 RX POWER LEVEL SE1TER VALUE I. I II 80% 56 I 70% 46 j

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # I Event # 4 Page 19 of 44 Event

Description:

Rapid Power Reduction Time Position__[ Applicants Actions or Behavior

6. c. VERIFY boration flow established BOP

d. INATE turbine load reduction by depressing GO pushbutton.

Qp . .

Depresses GO pushbutton. .

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

7. MONITOR T-avgcT-ref mismatch:

a CHECK T-ref indication a. PERFORM the tollowing:

AVAILABLE.

1) MONITOR Program T-avg for current reactor power USING TI-28 Figures or ICS (NSSS I SOP, Program Reactor Average Ttmperature)

2) USE program T-avg in place of T-ret

3) MAINTAIN T-avg within 3°F of program Tag USING manual rod ATC cona

4) ADJUST turbine load rate as necessary.

5) IF mismatch between T-avg and program value CANNOT be maintained less than 5°F, ThEN TR1P the reactor and GO TO EM, Reactor Trip or Safety Injection

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 4 Page 20 of 44 Event

Description:

Rapid Power Reduction T. h MONITOR automatic rod control h. IF auto rod control is functional maintaining T-avg,T-ref mismatch AND situation allows slowing down less than 3°F. load reduction, THEN PERFORM the following:

1) REDUCE turbine load rate to allow auto rod control to restore T-avgiT-ref mismatch

2) WHEN T REF T AUCT HIGH LOW alarm (M-5A. C-6) is clear, ThEN RESTORE turbine load rate to desired value.

IF any of the following conditions met:

auto rod control NOT functional OR

• turbine load rate adjustment is NOT effective in reducing mismatch OR

• situation does NOT allow slowing down load reduction, THEN RESTORE T-avg to within 3°F ofT-ref USING manual rod control as necessary IF T-avglT-ref mismatch CANNOT be maintained less than 5°F, THEN TRIP the reactor and GO TO E-O, Reactor Trip or Safety Injection.

BOP MONITOR automatic control of MEW pump speed AVAILABLE.

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

Examiner Note: Appendix C, Secondary Plant Equipment starts at page 22.

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 the Lead Examiner may go to the next event starting at page 32.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 1 Event # 4 Page 21 of 44 Event

Description:

Rapid Power Reduction 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 wtuch CANNOT be

• high vibration on multiple bearings stopped by placing rods in MANUAL o-c.oi OR Loss of SIG level control:

• abnormal noiselvibration apparent level dropping or rising toward trip selpoint and level CANNOT be restored op-sai More than one dropped rod (A0F-C.1)

T-avglT-ref mismatch CANNOT be maintained less than 5°F (refer to Step 7 or App. E) 30% turbine load: <30% turbine load:

Condenser Pressure > 2.7psia AND CANNOT Condenser Pressure> t72 psia be restored within. 5 rnini4es (AO?-SU2) (AOP-5.02)

Any automatic reactor trip selpoint 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 DIP 12 psig below normal

• Power Range high fluX 1:09% a Both MFPTS tripped

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

• Low Auto Stop Oil pressure 45 psig

• Pressurizer high level 92% a 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

• RS low flow 90%

• Turbine Overspeed 1:980 rpm

• RCP unclervoltage 5.022 kilovoits

• Loss of EHC pressure

• RCP undertrequency 56.0 Hz a Generator PCBs tripped,

• OTAT 115% (variable)

• OPAT 108.7% (variable)

• S1G low leVel 107% [15% EAM]

• SSPS general warning in both trains

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 4 Page 22 of 44 Event

Description:

Rapid 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) El

• stopping secondary plant equipment El NOTE I If reactor power will be reduced below 50%, AUO should be on station at #3 heater drain tank çt possible) when 80% power is reachet NOTE 2 Dispatching of AUO in Steps [2) and [3] may be performed out of sequenca

[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 El

[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: (WA valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN IA 1-VLV-3-576 Thel 706, Northeast cornerof lAcondenser El IB 1 -VLV-3-577 TB eL 706, Northeast corner of IA condenser El 2 24 2-VLV-3-576 TB eL 706, Southeast corner of 2A condenser El 26 2-VLV-3-577 TB el 706, SouTheast corner of.2A condenser El

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # Event# 4 Page 23 of 44 Event

Description:

Rapid Power Reduction APPENDIX C

]4] IF BOTH of the following conditions are met power is being reduced as directed by AOP-&O1 (Main Feedwater Malfunctions) or AOP-S04 (Condensate or Heater Drain Malfunctions)

• leaving secondary pumps in service is desired, THEN GO TO Step [8]. U f5] WHEN turbine impulse pressure is approximately 80% or less, THEN PERFORM the following:

[a] ENSURE one Cond Demin Booster Pump STOPPEIX U

[6] ENSURE associated suction valve CLOSED:

COMB DEMIN OR B FCV-2-285 U J FCv2280 U

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # I Event # 4 Page 24 of 44 Event

Description:

Rapid Power Reduction

[6] HEN turbine impulse pressure is approximately 7Q-75%

THEN PERFORM the following:

[a] ENSURE one Condensate Booster Pump STOPPEI1 U Lbl ENSURE assodated CBP suction vatve CLOSED:

j{ CONDENSATE BOOSTER PUMP SUCTION VALVE CLOSED -iI L A FCV-2.-94 U OR FCV-2-87 U OR FCV-2-81 Ic] PERFORM applicable procedure to adjust seal injection waler pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary) i-S0-2/3-1 Section 72 U OR

• 2-50-213-1 Section 73

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 4 Page 25 of 44 Event

Description:

Rapid 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

[b] ENSURE suction valves CLOSED:

COND DEMIN BOOSTER PUMP SUCTION VALVE CLOSED i A FCV2-290 0 B FCV2-285 0 C FCV-2-280 El cJ STOP one No. 3 Heater Drain pump..

Id] STOP one No.. 7 Heater Drain pump.. LI

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 1 Event # 4 Page 26 of 44 Event

Description:

Rapid Power Reduction

[8] IF reactor power will be maintained greater than 50%,

THEN GO TO Notes prior to Step [ii]. U CAUTION Isolation of all three Intermediate heater strings could occur if turbine is tripped prior to fully opening LCV-6-105A 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. U

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

Fully Opening #3 Heater Drain Tank Bypass Valves. U

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

VALVE DESCRIPTION FCV-6-108 Htr Drain Tk Purr pa to Htr String A FcV-6-109 Htr Drain Tk Pump 3 to 1-hr String B FCV-6-1 10 1-kr Drain Tk Pump 3 to Htr String C

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # I Event # 4 Page 27 of 44 Event

Description:

Rapid Power Reduction NOTE I The following step ensures that MFW Bypass valves are available to control feedwater flow at low power.

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

f 10] WHEN Reactor power is less than 5O%

THEN PERFORM the following:

IF all MFW Req Valves are in AUTO, THEN PLACE MFW Bypass Req Valve controller in AUTCX U IF any MFW Req Valve is in MANUAL, ThEN PERFORM the following:

1) MAINTAIN MFW Bypass Req Valve in MANUAL for SIB with MFW Reg valve in MANUAL. U

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

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 4 Page 28 of 44 Event

Description:

Rapid Power Reduction NOTE I If performing this AOP to reduce power to allow shutting down one MFW pump1 the affected MFWP may be removed from service at power level less than 55% (UnU) 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 foiward. LCO 3.3.21 (Unit 1) or 3.32 (Unit 2) allows AFW start channel to be inoperable for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> when shutting down a MFWP.

[1Ij: WI-lEN 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 I THEN PERFORM the following:

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

UNIT MFWP VALVE LOCATION OPEN J IA 1-VLV-3-576 T8e1706,NortheastcornerofiAcondenser U 15 1-VLV-3-577 TBeI. 706, Northeast cornerof IA condenser Q 2k 2-VLV4-576 TB el. 706, Southeast corner of 24 condenser U 2

25 2-VLV-3-577 TB el. 706, Southeast corner of 24 condenser U b] ThROTTLE OPEN recirc valve in MANUAL (30-50% OPEN) for MFWP to be removed from service. U (c] PLACE speed controller in MANUAL for MFWP to be removed from: service. U (d] REDUCE speed gradually on MFWP to be removed from service. U

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 4 Page 29 of 44 Event

Description:

Rapid Power Reduction

[11] (Continued)

ENSURE proper loading on remaining MF1NP. C

[fJ 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 unloadeti C OR

• ThRO1TLE OPEN redrc valve for affected MFWP to assist in unloading MFWP C OR

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

• OBTAIN SRO concurrence that MFWP how is suftidently low to allow tripping MFWR C

[g] WHEN MFWP is unloaded sufficiently 1

THEN TRIP affected MFWR C

[h] CLOSE redrc valve for MFWP removed from service.. C (I] CLOSE recirc valve Manual Isolation inlet valve for MFWP removed from service. C Li] OPEN drain valves for MFWP removed from service: IM-31

• [HS46-14J, MFWP A drain valves C OR

• fH546-4fl. MFWP B drain valve& C

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 4 Page 30 of 44 Event

Description:

Rapid Power Reduction 112] WHEN turbine impulse pressure is approximately 45% or less, THEN PERFORM the following;

[a] STOP remaining No 7 Heater Drain pump.

[N CLOSE :1t 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 D FCV.-6-163 Htr Drain Tk Pump 7 to Htr String B 0 FCV-&-184 Htr Drain Tk Pump 7 to Htr String C U tISI 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 sifil running, THEN PERFORM Step [9]. U

[c3 STOP one off two remaining Condensate Booster Pump&

(step continued on next paqe

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # I Event # 4 Page 31 of 44

[ent

Description:

Rapid Power Reduction t131 (Continued)

[d] ENSURE associated CBP suction valve CLOSED:

CONDENSATE SUCTION VALVE CLOSED BOOSTER PUMP A FCV-2-94 r FCV-2-87

{ C FCV-2--81 e] STOP one of three Hotwell Pumps.

fJ 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

• 2-50-2/3-i Section T3

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event# 5 Page 32 of 44 Event

Description:

PT-3-1 Falls Low Time 1 Position Applicants Actions or behavior Simulator Operator: When Directed, Initiate Event 5 Feed Water Header Pressure Transmitter Fails Low; PT-3-1 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

• SG-I thru 4 SG FW INLET FLOW increasing flow- above steam flow I-M-3

• FW MASTER CONTROLLER shifts to MANUAL (AMBER)

Significant Resultant Alarmsllndications:

Indications:

CS

• Thermal Power Increasing MAIN FEEDWATER DIGITAL CONTROL SYS TRANSFER TO MANUAL

[Ii IF usmg the hand controllers to detemne which DitaI Feedwater canfroller(s) has transferred to manu, THEN DETERMBIE which controller(s) in Manual by ORANGE backlitManuar on controller.

[2j [F using the DCS :OpetatO( Display monitors to detemine which Diçital Feedwatef ccntrdler(s) has transferred to luV.NUAL, THEN OBSERVE controller(s) ye!low status light being UT.

P1 ADJUST contro{Ier() to maintain system parameters steady.

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

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # I Event # 5 Page 33 of 44 Event

Description:

PT-3-1 Fails Low Time Position Applicants Actions or behavior

[9 IF any of he owing cccur

• System paametes can NOT be maintained OR

• AtthedlscretionoftheUS THEN GO TO any of the fdlowin:

• AOP-C.03, Emergency Shutdown

• AOP-S.O1, Main FedwaterAfuriofions

• E-U, Reactor Trip orSaf&y Injecori 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 I from memory without direction.

t DIAGNOSE the failure:

IF GOTO PAGE

... SECTION Failure of Automatic SIG Level Control 2.1 4 Failure of Automatic MEW Pump Control 2.2 7 Loss of One Main Feedwater Pump 2.3 12 Above 76% (Unit 1) or 77% 1Jnit 2) Turbine Load Main Feedwater Pump Trip 2.4 19 Below 76% (Unit 1) or 77% (Unit 2) Turbine Load NOTE Step I is an IMMEDIATE ACTION

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 5 Page 34 of 44 Event

Description:

PT-3-1 Fails Low Time Position Applicants Actions or behavior RESTORE feedwater pressure:

a. ENSURE affected MFP speed controller(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 (1040 psig at !uH power).

2.. DETERMINE if MFP trip is needed:

BOP a CHECK BOTh MFW pumps IN SERVICE CAUTION: Feed flow transients may impact core thermal power..

BOP 1NTAIN steam generator level(s) on program..

NOTE: Appendix C or DCS Operator Display monitors MFP Control screen may be used to determine program feeciwater DIP for current power..

4.. MAINTAIN MFP discharge pressure BOP USING DCS 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 Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 5 Page 35 of 44 Event

Description:

PT-3-1 Fails Low Time Applicants Actions or behavior II__Position CREW & tNITIATE repairs on faded equipment 7 WHEN automatic control of affected MFW pump controller(s) is available and reliable, THEN PLACE controller(s) in AUTO USING I ,2-SO-98-I, DisIibuted Control System.

SRO NOTE: Instructions for 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 201 2-302 Scenario # 1 Event # 6, 7 Page 36 of 44 Event

Description:

Loss of ALL AC Power, Manually Reset 1A EDG Lockout, Manually Open 1A EDG Cooling Valve Time Position fl Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 6 Loss of Offsite Power Indications available:

. RPI for all control rods at 0

. Reactor trip alarms lit [M-4D].

. Rapid drop in neutron level.

. Simulator Lights reduced to minimum.

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 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-0 unprompted.

SRO Directs performance of E-O NOTE I Steps I through 4 are immediate action step&

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.

Aoendix D Reauired Qoerator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 6, 7 Page 37 of 44 Event

Description:

Loss of ALL AC Power, Manually Reset 1A EDG Lockout, Manually Open IA EDG Cooling Valve Time Position Applicants Actions or Behavior

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-0,0, Loss of All AC Power.

t n ee en o Tra ion o.EA-O.O, o s..O All AC o e ..

SRO Directs actions of ECA-O.O. Loss Of All AC Power.

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

1. SUSPEND FRP implementation and CREW 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:

ATC

• 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.

Appendix D Reciuired Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 1 Event # 6, 7 Page 38 of 44 Event

Description:

Loss of ALL AC Power, Manually Reset 1A EDG Lockout, Manually Open 1A EDG Cooling Valve Time I Position Applicants Actions or Behavior

5. PERFORM the following notifications:

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

b. NOTIFY Site Security to station officers at key vital doors USING 551-1, Security Instructions for Members of the Security Force.

6. CHECK RCS ISOLATED:

ATC

a. Pressurizer PORVs CLOSED.

6. CHECK RCS ISOLATED:

b. Letdown isolation valves CLOSED: b. CLOSE valves.

• FCV-62-69 ATC

• FCV-62-70

- FCV-62-72

• FCV-62-73

• FCV-62-74

6. CHECK RCS ISOLATED:

c. Excess letdown isolation valves ATC CLOSED:

• FCV-62-54

• FCV-62-55

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 6, 7 Page 39 of 44 Event

Description:

Loss of ALL AC Power, Manually Reset 1A EDG Lockout, Manually Open IA EDG Cooling Valve Time Position I Applicants Actions or Behavior

6. CHECK RCS ISOLATED:

d. Reactor vessel head vents CLOSED:

• FSV-68-394 ATC

• FSV-68-395

• FSV-68-396

• FSV68-397 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 231-B.

7. MONITOR AFW flow:

BOP

a. CHECK TD AFW pump RUNNING.

7. MONITOR AFW flow:

BOP b. CONTROL TO AFW pump USiNG EA-3-1, MCR Operation of TD AFW Pump.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # I Event # 6.7 Page 40 of 44 Event

Description:

Loss of ALL AC Power, Manually Reset 1A EDG Lockout, Manually Open 1A EDG Cooling Valve Time Position Applicants Actions or Behavior

7. MONITOR AFW flow:

c MONITOR Aux Control Air AVAILABLE:

BOP

• BOTH Unit 2 Shutdown Boards ENERGIZED

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

7. MONITOR AFW l9ow:

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

7. MONITOR AFW flow:

BOP e. CONTROL intact or ruptured SIG narrow range levels between 10% [25% ADV] 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 Op Test No.: NRC 201 2-302 Scenario # 1 Event # 6,7 Page 41 of 44 Event

Description:

Loss of ALL AC Power, Manually Reset IA EDG Lockout, Manually Open IA EDG Cooling Valve Time Position Applicants Actions or Behavior

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

a. CHECK for any of the following:

BOP

• any DIG on this unit potentially available (capable of supplying power to shutdown board)

OR

• availability of any D/G on this unit is UNKNOWN.

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

BOP

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

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

BOP c EMERGENCY START diesel generators. [M-1 switch and M-26 pushbutton]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # 6, 7 Page 42 of 44 Event

Description:

Loss of ALL AC Power, Manually Reset 1A EDG Lockout, Manually Open 1A EDG Cooling Valve Time Position Q Applicants Actions or Behavior

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

BOP

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

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

BOP

e. VERIFY ERCW supply established e. START ERCW pumps and to running diesel generators. ALiGN ERCW valves as necessary.

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

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

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

g. RESUME FRP implementation.

Arnendix D Reauired ODerator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 1 Event # 6,7 Page 43 of 44 Event

Description:

Loss of ALL AC Power, Manually Reset IA EDG Lockout, Manually Open 1A EDG Cooling Valve Time fl Position Applicants Actions or Behavior

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

h. RETURN TO procedure and step in effect.

Examiner Note: Lead Examiner may terminate the scenario when ERCW cooling flow has been established to the IA EDG.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 1 Event # Page 44 of 44 Event

Description:

Critica Task Critical Tasks:_[ Critical Task Statement I Energize at least one 6.9 kv Shutdown Board by resetting the IA EDG LO relay prior to completing step 8 of ECA-O.O.

2 Manually establish ERCW flow to the required EDG prior to completing step 8.e of ECA 0.0.

Time: Now Date: Today Unit I MCR Checklist (751-6338 ID 950848) Then Press 2 Páftjb$-gjgShiftIReviewed;b rO coiflinSiift f Mode 1, 100% Power NRC phone Authentication Code PSA Risk: Green Grid Risk: Green RCS Leakage ID .14 gpm, UNID .05 gpm Until 0800 AI2B After 0800 C34D

• tW *Tfl- fl7W32 ..A .tV IAIRF I:IN1dWfr NONE

%aZ&Y inJ11i L:J-i Tech SpecActióps LCOITRM Eguipment INOP Time INOP Owner RTS I B-B EDG out of service for maintenance LCO 3.8.1.1 Action B 7

A Train 1_ 4-

,I1lI1 I riorades 4

GO-5 Section 5.4 Coastdown REDUCE turbine load slowly (less than 1% per hour) as necessary to maintain TAVG on program with TREE.

Review current TS/TRM/ODCM/FPR Current Qualification Status Required Actions Review the current controlling Reactivity Walkdown MCR Control Boards with off-going Management Plans Operator SR/PER reviews complete for previous Review Narrative Logs shift (SM/U S/STA) (previous day and carry-over items)

Relief Time:____________________ Relief Date:______________________

E Review Operator Workarounds, Burdens, E Review applicable ODMI actions and Challenges (applicable Unit/Station) (first shift of shift week)

LI Review changes in Standing/Shift orders El Review changes to TACEs issued since last shift worked) (since last shift worked)

LI Review Control Room Deficiencies LI Review Component Deviation Log (first shift of shift week) (Active Procedures)

Time: Now Date: Today Abnormal Equipment Lineup/Conditions:

1-RM-90-119 OOS SR 111623061. 1-RM-90-99 is in service.

AUXILIARY BUILDING (7775) (593-2469)

All equipment operating or operable.

All equipment operating or operable.

I B-B EDG out of service

Time: Now Date: Today Required Additional Monitoring and Contingencies (Updated and Maintained by SM)

Issue Required Action Expiration Date ODMI TACF Description TACF

UNIT ONE REACTIVITY BRIEF Date: Today Time: Now RCS Boron: 9 ppm Today BA Controller Setpoint: 1%

• RCS B-1O Depletion: 0 ppm Operable BAT: A BAT A Boron: 6850 BAT C Boron: 6850 RWST Boron: 2601 ppm ppm ppm Nominal Gallons per rod step from 228: nla gallons of acid, nla gallons of water Verify boric acid flow controller is set at Adjusted BA Controller Setting iaw 0-SO-62-7 section 5.1

[ ieivals i i Gallons of acid: 22 Gallons of water: nla Rod Steps: 10 Estimated rodslboron for emergency step power reduction ** -____ -.

(Assuming Xenon equilibrium and no reactivity effects due to Xenon. 2/3 total reactivity from rods. 1/3 from boron)

Power reduction amount Estimated Final Rod Estimated boron addition Position 10% 201 Steps on bank D 131 gallons 30% 168 Steps on bank D 375 gallons 50% 109 Steps on bank D 609 gallons These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or 50-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until one week from now.

Number of dilutions: 0 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 0 Gallons per boration: 0 Rod steps out: 0 Total amount diluted: 0 Total amount borated: 0 Net change: 0 In/Out Number of dilutions: 0 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 0 Gallons per boration: 0 Rod steps out: 0 Total expected dilution: 0 Total expected boration: 0 Net change: 0 In/Out Remarks:

Unit Supervisor:

Name/Date

Operations Chemistry Information Borq Resujts:

Sample Point Units Boron Date I Time Goal Limit Ui RCS ppm 9 Today I Now Variable Variable U2 RCS ppm 816 Today / Now Variable Variable UI RWST ppm 2601 Today I Now 2550 2650

- 2500 2700 U2 RWST ppm 2569 Today I Now 2550 2650

- 2500 2700 BAT A ppm 6850 Today I Now Variable Variable BAT B ppm 6850 Today I Now Variable Variable BAT C ppm 6850 Today I Now Variable Variable Ui CLA #1 ppm 2556 Today I Now 2470-2630 2400-2700 UI CLA #2 ppm 2575 Today I Now 2470-2630 2400-2700 UI CLA #3 ppm 2591 Today I Now 2470-2630 2400-2700 Ui CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today / Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA #3 ppm 2522 Today I Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today I Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today I Now 2050 2000 Ui RCS ppm 1.1 Today/Now >1 >1 U2 RCS ppm 2.43 Today! Now 2.18-2.48 2.33 tflLZate S °J!?LJ WEJL Indicator Units UI Date I Time U2 DatelTime SI 50 S/G Leakage? Yes/No No Today! Now No Today / Now SI 137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent cpm 1 15 Today! Now 85 Today / Now 30 gpd leak equivalent cpm 490 Today / Now 308 Today / Now 75gpd leakequivalent cpm 1165 Today/Now 710 Today/Now 100 gpd leak equivalent cpm 1540 Today / Now 933 Today / Now 150 gpd leak equivalent cpm 2290 Today! Now 1380 Today / Now CVE Air Inleakage cfm 10 Today / Now 12.5 Today / Now Bkgd on 99/1 19 cpm 50 Today / Now 40 Today! Now Correction Factor 99/119 cpmlgpd 64 Today / Now 14.13 Today / Now Steady state conditions are necessary for an accurate determination of leaK rate usina the CVE Rad Monitor

12LJ1-iU2 SU1 I Iiooth Instructions BOOTH OPERATOR INSTRUCTIONS Sim. Setup

1. Reset IC-17 100% power EOL time in core life

2. Perform switch check.

3. Verify control rod step counters reset.

4. Place simulator in RUN.

5. Place Mode 1 placard on panels.

6. Place B Train Week sign on the simulator.

7. Allow the simulator to run for at least 3 minutes before loading SCEN file or starting the exercise. This will initialize ICS.

8. Load SCENS: S-1211 NRC SCN I

9. Acknowledge any alarms, allow the plant to stabilize, and freeze the simulator.

10. Place 1-HS-57-73A (DIG Bkr) in the PTL.

11. Place 0-HS-82-48 (Mode sel switch) in the PULL FOR LOCAL position.

12. Place OOS tags on

• Breaker 1914, lB-B EDG to SD Bd IA-A

13. Place GO-16 tags on

• CCP lA-A

• Pzr heater lA-A

• Pzr heater IC

• SI Pump lA-A

• RHR Pump lA-A

• EGTS Train A-A

• Cntmt Spray Pump IA-A

• Motor Driven AFW Pump IA-A

• Unit 1 TDAFWP

• ERCW Pump J-A OR Q-A (circle one)

• ERCW Pump K-A OR R-A (circle one)

• Operable ERCW Pumps selected to auto start on 0-XS-67-286 and 0-XS-67-287

• Diesel Generator IA-A

14. Perform the SIMULATOR OPERATOR CHECKLIST

15. Place turnover sheets on the operators desks.

16. Place simulator in RUN before crew enters the simulator.

Page 1 of 6

1201-iIJ2 UI I Booth Instructions EVENT IC/MF/RF/OR # I DESCRIPTION/EXPECTED j ACTIONS/BOOTH FEEDBACK This override is IMF EGO3B f:1 These MFs, RFs, and ORs simulate lB-B DIG active when the IRE EGRI2 f:l being mop for maintenance and tripped to SCN file is local.

loaded. IMF EGCOHS5773A f:3 ICR ZLOHS5773A M26 GREEN f:0 Place 1-HS-57-73A (D/G Bkr) in the PTL lOR ZL0HS5773_GREEN F:0 position and PLACE H.O. ON HAND SWITCH.

IMF AN OV 905 f2 Place 0-HS-82-48 (Mode sel switch) in the PULL FOR LOCAL position.

IMF AN_OV_924 f:2 IMF AN_OV_936 f:2 IMF AN_OV_938 f:2 IME AN_OV_943 f:2 IMF AN_OV_945 f:2 IMF AN_OV_946 f:2 IMF AN_OV_950 f:2 IMF AN_OV_952 f:2 IMF AN_OV_953 f:2 This override is IMF RW19A f:1 FCV-67-68 fails to auto open.

active when the SCN file is loaded.

When directed by IMF CV25A f:l k:1 CVCS Letdown Pressure instrument PT-62-81 the Lead fails low Examiner, use Support staff:

KEY I to insert malfunction, If dispatched, after 5 minute, the AB AUO reports the valve is [position from MCB], no apparent problems or damage identified/observed locally.

When directed by IMF RXO7A f:l k:2 Controlling Pzr Pressure Transmitter PT 68-the Lead 340 Fails High Examiner, use Support staff:

KEY 2 to insert malfunction, When MSS is contacted, inform the crew that the IMs will report to the MCR in -25 minutes.

If asked, report Aux CR indication is normal.

When directed by IMF RDO7M2 f:l k:3 Dropped Rod: M2 SDB A rod.

the Lead Support staff:

Examiner, use MSS is notified to initiate maintenance, report KEY 3 to insert it will take approx. 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to assemble a team malfunction. to troubleshoot the dropped rod.

Reactor Eng. notified for power peaking, fuel failure, & xenon oscillation considerations, inform crew to proceed with rod retrieval using AOP-C.0l considerations (i.e.: <1 hour).

Page 2 of 6

1201-i132 SCI I Booth Instructions EVENT ICIMF/RF/OR # I DESCRIPTION/EXPECTED ACTIONS/BOOTH FEEDBACK When directed by IMF RX24 f:1 k:5 PT-3-1, IA, lB fail LOW the Lead IMF RX24A f:1 k:5 Support staff:

Examiner, use KEY 5 to insert IMF RX24B f:1 k:5 If directed to inspect PT-3-1, respond as the malfunction. TB AUO, wait 5 minutes and report no abnormal conditions noted.

When contacted, inform the crew that the l&C will report to the MCR in 45 minutes.

When directed by IMF EDO1 k:6 Total loss of offsite power with A EDG failure the Lead IMF EGO3A f:1 e:1 to AUTO START.

Examiner, use Support staff:

KEY 6 to insert malfunction. If dispatched wait 5 mm, report no relays actuated and no abnormalities noted.

When asked respond as Load Dispatcher and report that a system disturbance resulted in losing several substations. Time for recovery is undetermined.

The following reports are used ONLY if the crew fails to start the IA EDG WHEN requested IRF CVR36 f:0 k:7 Closes HCV-62-549, 550 and closes 70-90 by the crew to IRF CVR37 f:0 k:7 and 62-63 isolate RCP seals IRE CCRO6 f0 k:7 and Thermal IRF CV6263 f:0 k:7 When complete inform the crew that RCP Barriers (EA-68-1) seals are isolated.

then insert this remote function using KEY 7 If asked by the IRF 1A3172 f:1 k:8 Emergency air supply to TDAWP LCVs to crew to perform IRF 1A3173 f:1 k:8 emergency EA-3-4 then insert IRF 1A3174 f:1 k:8 this remote IRF 1A3175 f:1 k:8 When complete inform the crew that function using emergency air is supplying the TDAFWP KEYB LCVs.

If Requested If Requested during scenario to Hydrogen pressure is available on REQUAL during scenario to provide local value of Gen Hydrogen Parameter values table as variable:

provide local value Pressure, CST Level, or Hotwell rwpgenerator, Generator Hydrogen Pressure of Gen Hydrogen level. (Indications will be lost with in PSIA (Subrtract 15 psi and provide psig)

Pressure, CST power loss)

Level, or Hotwell CST and Hotwell Level are available on Simulator diagram Condensate in %.

level. (Indications will be lost with Wait five minutes then respond.

power loss)

If Dispatched to Wait five minutes then respond.

ensure DC Air Side Seal Oil Pump Running.

Page 3 of 6

12U1-i1i2 SCI4 I I$ooth Instructions EVENT IC/MFIRF/OR # DESCRIPTION/EXPECTED ACTIONS/BOOTH FEEDBACK If requested to IRE EGRI3 f:100 K:1 I MANUAL POSITION FOR GENERATOR H2 open Main Gen VENT BYPASS, FCV-35-568 Hydrogen vent bypass valve 35 568 then insert Wait five minutes then respond this remote function using KEY 11 If Dispatched to IRF CNRO8 f:0 k:12 VLV-2-5621563 MANUAL ISOL VLVS manually isolate AROUND FCV-2-35A FCV-2-35A then insert this remote function using Wait five minutes then respond KEY 12 If Requested to IRE CNRO1 f:1 k:13 ISOLATE HOTWELL MAKEUP FROM CST locally isolate CST from Hotwell (EA-2-I) then Wait five minutes then respond insert this remote function using KEY 13 If Requested to IRE ED25OB1 B527 25OVDC BAT BD I BKR 527 DC EOP IA open breakers in (MFPT)

AOP-P.01 25OVDC BAT BD I BKR 530 DC EOP lB IRE ED25OBIB53O Appendix G, (MFPT Open Bkrs individually as IRF ED250B1B529 25OVDC BAT BD I BRKR 529 TO PREF INV requested (All 1 may not be 25OVDC BAT BD 1 BKR 401 TO TSC INV I IRF ED25OB1 6401 opened) 25OVDC BAT BD I BKR 525 GEN AIR SIDE IRE ED250B1B525 SOB PMP UI NOR FEED 25OVDC BAT BD I BKR 404 TURB EOP UI IRE ED250B1B404 NOR FEED Wait five minutes then respond Page 4 of 6

12U1-U2 SUI I liootli Instructions EVENT IC[MFIRF/OR # DESCRIPTION/EXPECTED ACTIONS/BOOTH FEEDBACK If Requested to IRE FWR36A LCV-3-174 (LP 1) OPERATION (Place in mannualy IRF FWR37A Local) position TDAFW LCV-3-174 (LP I) POSITION (Set as directed)

LCVs locally, Modify remote functions as LCV-3-173 (LP 2) OPERATION (Place in directed. IRF FWR36B Local)

IRF FWR37B LCV-3-173 (LP 2) POSITION (Set as directed)

LCV-3-172 (LP 3) OPERATION (Place in Local)

LCV-3-172 (LP 3) POSITION (Set as directed)

IRE FWR36C IRE EWR37C LCV-3-175 (LP 4) OPERATION (Place in Local)

LCV-3-175 (LP 4) POSITION (Set as directed)

Wait five minutes then respond.

IRF EWR36D IRE FWR37D If requested to IRF ED25OBIALL f:0 k:14 OPEN 250 VOLT LOAD SHED BREAKERS.

shed 250 volt DC 25OVDC BATT BD 1, OPEN SBO BKRS Loads per EA- 401,527,529,530 250-2 then insert this remote IRF ED25OB2ALL f:0 k:14 function using 25OVDC BATT BD 2, OPEN SBO BKRS KEY 14 401,527,529,530 Wait five minutes then respond.

If requested to IRF ED250B1B525 f:0 k:15 25OVDC BATT BD 1 BREAKER 525 TO GEN open Unit I Gen AIR SIDE SOB PUMP UI NORMAL FEED Air Side Seal Oil Pmp 250 Volt Bkr per EA-250-2 IRF ED250B2B525 f0 k:15 25OVDC BATT BD 2 BREAKER 525 TO GEN then insert this AIR SIDE SOB PUMP UI ALTERNATE FEED remote function Wait five minutes then respond.

using KEY 15 If requested to IRE ED250B1B526 f:0 k:I6 25OVDC BATT BD I BREAKER 526 TO GEN open Unit 2 Gen AIR SIDE SOB PUMP U2 ALTERNATE FEED Air Side Seal Oil Pmp 250 Volt Bkr per EA-250-2 IRE ED250B2B526 f:0 k:16 25OVDC BATT BD 2 BREAKER 526 TO GEN then insert this AIR SIDE SOB PUMP U2 NORMAL FEED remote function Wait five minutes then respond.

using KEY 16 Page 5 of 6

1201-302 C1 I Booth Instructions EVENT IC/MFIRF/OR # DESCRIPTION/EXPECTED ACTIONS/BOOTH FEEDBACK If Requested to IRF ED12OB1ALL f:0 k:17 OPEN 120V & 125V VITAL DC LOAD SHED Shed l25vdc vital ;IRF ED125B1ALL f:0 k:17 BREAKERS.

loads per EA- Wait five minutes then respond.

250-1 then insert this remote IRE EDI2OB2ALLfO k:17 function using ;IRF ED125B2ALL f:0 k:17 KEY 17 IRF EDI2OB3ALL f:0 k:17

IRF ED125B3ALL f

0 k:17 IRF ED12OB4ALLf:0 k:17

IRF EDI25B4ALL f

0 k:17 Page 6 of 6

SIMULATOR SCENARIO 2

Appendix D Scenario Outline Attachment I Facility: Sequoyah Scenario No.: 2 Op Test No.: 2012-302 Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 1, 100% power, MOL Turnover: Maintain current conditions, currently in 0-GO-5 Section 5.2, At Power Conditions. 1 B EDG is OOS.

Target CTs: Manually trip the main turbine before an orange path challenge develops to either the subcriticality (S) or the Pressurized Thermal Shock (P) CSF or before transition to ECA-2.1, whichever happens first.

Manually trip all Reactor Coolant Pumps prior to completing step 4 of FR-H.1, LOSS OF SECONDARY HEAT SINK.

Initiate RCS bleed and feed so that the RCS depressurizes sufficiently for the Safety Injection pump flow to occur prior to completing step 19 of FR-HI.

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

1. RXO6A I-ATC/SRO The controlling pressurizer level channel LT 68-339 will fail low resulting in TS-SRO letdown isolation and de-energizing Pressurizer heaters. The ATC will remove the channel from service and restore Pressurizer heaters using AOP-I.04. The SRO will address Tech Specs and determines the instrument is INOPERABLE.

la N-ATC The ATC will restore letdown.

2. RXO2DI 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.

3. CNO9 C-BOP/SRO Main Condenser Vacuum degrades with the standby Condenser Vacuum Pump CN1 I B failing to start automatically. The BOP manually starts the standby Condenser Vacuum Pump using AOP-S.02.

4. R-ATC The crew reduces plant power using AOP-C.03 due to Condenser Vacuum N- BOP/SRO Leak.

5. EDO5 I-BOP/SRO During the power reduction a grid disturbance occurs that results in an increase of MVAR loading, the BOP will lower the main Generator Voltage Regulator to maintain MVAR loading within limits.

6. FW23D M-AII A Main Feed line break develops inside the Containment. The Reactor trips and the crew will transition to E-0.

7. TC1 1ALL C-BOP The Main Turbine will fail to trip when the Reactor Trips, the BOP will manually TC12ALL trip the Main Turbine.

8. EDO6D M-AlI While performing E-0 all AFW pumps become unavailable resulting in a severe FWO7C degradation of Heat Sink, the crew will transition to FR-H.1.

FW22A

9. CV22A Both Charging Pump suction strainers clog resulting in a loss of all Charging CV22B Pumps. The crew will turn off RCPs and transition to FR-H.1 step 17 to initiate bleed and feed to establish once through cooling.

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

Appendix D Scenario Outline Attachment I 201 2-302 Scenario 2 Summary EVENT I 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 2 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 3 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 4 The crew reduces plant power using AOP-C.03 due to Condenser Vacuum Leak.

EVENT 5 When directed by the lead examiner during the power reduction, a grid disturbance occurs that results in an increase of MVAR loading, the BOP will lower the main Generator Voltage Regulator to maintain MVAR loading within limits.

EVENT 6 When directed by the lead examiner, a Main Feed line break develops inside the Containment.

The Reactor trips and the crew will transition to E-0.

EVENT 7 - The Main Turbine will fail to trip when the Reactor Trips, the BOP will manually trip the Main Turbine.

EVENT 8 While performing E-0 all AFW pumps become unavailable resulting in a severe degradation of Heat Sink, the crew will transition to FR-H.1. Both Charging Pump suction strainers clog resulting in a loss of all Charging Pumps. The crew will turn off RCPs and transition to FR-H.1 step 17 to initiate bleed and feed to establish once through cooling.

EVENT 9 Both Charging Pump suction strainers clog resulting in a loss of all Charging Pumps. The crew will turn off RCPs and transition to FR-H.1 step 17 to initiate bleed and feed to establish once through cooling.

EOP flow: E-0, FR-H.1 The scenario terminates as directed by the Lead Examiner upon establishing RCS bleed and Feed.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 2 Event # 1 Page 1 of 51 Event

Description:

Pressurizer Level Channel LT 68-339 fails low Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event I Pressurizer Level LT 68-339 fails low IndicationslAlarms Annunciator:

1-M-5

. 5A C-3, PRESSURIZER LEVEL HIGH-LOW

. 5A E-3, 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-Fl-62-82, LETDOWN HX OUTLET FLOW indicates 0 flow 0-M-27

. O-XA-27B-B A-5, LETDOWN HX OUTLET FLOWITEMP ABNORMAL LS-68-335D1E PRESSURIZER LEVEL HIGH-LOW

[11 CHECK pressunzer lerel (1-LI-68-339A, 335A, 320)

[21 IF level is tigh, ThEN ENSURE bclcup heaters ON.

[31 ENSURE level control system is attempting to return level to program with: IetdOJdfl and charging.

[4] IF level thannel failed,, THEN GO TO AOP-t04, P e&cizar Instrument Ma1fanctior.

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 201 2-302 Scenario # 2 Event # 1 Page 2 of 51 Event

Description:

Pressurizer Level Channel LT 68-339 fails low Time Position Applicants Actions or Behavior 1 DIAGNOSE the failure:

lF..

GOTO SECTION PAGE I

Pressurizer Level Instrument Malfunction 2.4 20 2.4 Pressurizer Level Instrument Malfunction CAUTION Chemistry sampling of PZR Liquid Space may result in additional bistables actuating due to impact on 1-LT-68-320 or 2-LT-68-335.

NOTE Appendix M shows layout of PZR level control for operator reference.

t CHECK LI-68-339 NORMAL PERFORM the following:

a. ENSURE LEVEL CONTROL CHANNEL SELECTOR switch XS-68-339E in LT-68-335 & 320.

ATC b ENSURE I.EVEL REG CHANNEL SELECTOR switch XS-68-339B in LT-68-320 or LT-68-335, c GOTOStep4.

rices LtVL L.,L)LN I FUL L,I1MININtL LLtL I .rc SWItlI A-OO-33 III LI -DO-

• ATC 335 & 320.

4. CHECK letdown IN SERVICE. PERFORM the following:

a. EVALUATE manual control of charging flow USING the following:

. HIC-62-93A, Charging Flow Control ATC . HIC-62-85A, Charging Seal Water Flow Control.

b. RESTORE letdown USING EA-62-5, Establishing Normal Charging and Letdown.

Examiner note: The following are from EA-62-5, go to page 5 for AOP-l.-4 actions.

I EA-62-5 ESTABLISHING NORMAL CHARGING AND LETDOWN actions

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 2 Event# I Page 3 of 51 Event

Description:

Pressurizer Level 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 4.3.

4.3 Establishing Normal Letdown Flow NOTE EA-62-3, Estabhshing Excess Letdown, may be utilized if Normal Letdown cannot be established.

1. iF charging flow NOT established.

ATC THEN PERFORM Section 42.

ATC 2.. VERIFY pressurizer level greater than i7%

3.. ENSURE letdown orifice isolation valves CLOSED:

LETDOWN ORIFICE ISOLATION VALVES CLOSED ATC ECV-62-72 C FCV-62-73 C FCV-62-74 C 4 OPEN letdown isolation valves:

LETDOWN ISOLATION VALVES OPEN ATC FCV-62-69 LI FCV-52-70 Li FCV-62-77 Li ATC laces HS-62-70A to OPEN.

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 2 Event # I Page 4 of 51 Event

Description:

Pressurizer Level Channel LT 68-339 fails low Time Position Applicants Actions or Behavior 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 [HIC-62-78J in MANUAL. AND ATC OPEN [TCV70i 921  :

50%

ATC

7. ADJUST charging flow as necessary to prevent hashing n the letdown line.

W OPEN letdown orttice isolation ialves as needed:

LEIDOWN ORIFICE ISOLATION VALVES OPEN ATC D 1 FCV-62-73 LI ATC Places HS-62-73 (or 74) Letdown Orifice B (or C) Isol 75 gpm to OPEN.

NOTE Normal letdown pressure is 325 psig at normal operating temperature.

9 ADJUST letdown pressure controller IPCV-62-S1i output to obtain desired pressure.

10. ADJUST letdown pressure controller FF0V-6241] setpoint to match existing pressure.

11 PLACE letdown pressure controller IPCV-62-81] in AUTO.

ATC Plaóés letdowfl pressure controller HIC 81 in AUTO.. . .

Appendix D Scenario Outline Attachment I Op Test No.: NRC 2012-302 Scenario # 2 Event # 1 Page 5 of 51 Event

Description:

Pressurizer Level Channel LT 68-339 fails low Time Position Applicants Actions or Behavior NOTE Normal letdown temperature is -lOD°F.

12, ADJUST [iC42-78A1 to obtain desired letdown temperature, as indicated on ffl-S2-7S.

13. PLACE [HIC-62-78A1 in AUTO.

ATC Places Letdown Controller Hlc-62-78A in AUTO. . . . .

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-62-79B1A, which causes letdown temperature control valve TCV-70-192 to fully open.

Examiner note: AOP-l.04 actions recommence here.

5 EVALUATE the foflowingE Tech Specs for applicability:

SRO

• 3.3.1.1 (3.3.1), Reactor Trip System instrumentation

• 333.7 Accident Monitoring Instrumentation LiMNG GONOII1ON FOR OPERATION 3.3.1.1 Ass nrnum. the reacr irip system in jment cbanneis and: intedOS Cf Tab 3.3$

shall be OPERABLE.

.APPtiCABIIJTY Asshovm in Tahe 13-1.

ACTiON:

As shown in Table 3.31.

11. PressurizerWalerl.evei 3 2 2 1,2 8 High ACTION 8- Wrib the number Of OPERABLE channels one less than the Total Nwnberof Channels. STARTUP andkr POWER OPERATION may proceed provided the fOfowidg condihons e satisfied:

a. The inoperable channel is çlaced in the tripped condl4icn viihin 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

3.3.3.7 Theaccidetmiig tahoe annela shown s Table 3.3-10 shall be OPERASLE APPUCAaILITY: MODES 1,2 and 3.

ACTION: As shown in Table 3.3-18

Appendix D Scenario Outline Attachment I Op Test No.: NRC 201 2-302 Scenario# 2 Event# 1 Page 6 of 51 Event

Description:

Pressurizer Level Channel LT 68-339 fails low Time L Positionj Applicants Actions or Behavior

7. resszerLe3ng 3 3 2 In_e oop -32D.-3E.-S:

ACTION 2 NDTE

- .4io :o te ppce ao requirrnents m TaNes 3.3-1 snce ry conta n niore resrctve 3ccons.

3. Ith The rurr.berf c.ie es thar ie mn.murn channes reqie:.

the .rc bIec3r..ei to OPERABLE siatis 3ys or r. :.t C3 iY 2A.JDE . *n re next rs ar HOT DOW. w r.

the 6 SRO Enterá LCO 3.3.1.1 Action 6 and. LCQ 3.3.3.7 Action 2  :

6. ENSURE pressurizer heaters restored ATC to service.

CAUTION 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 I or 2..

ATC b MONITOR core thermal power far 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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> UNLESS affected loop is restored to operable status by resetting Eagle rack.

8. NOTIFY i&C to remove faded pressurizer level Channel: frOm service 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 Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 2 Page 7 of 51 Event

Description:

Loop #4 Cold Leg Instrument fails high Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 1, Loop #4 Cold Leg Instrument Fails High Indications available:

Annunciators:

M-5

• 5A A-6 TS-68-2MIN RC LOOPS T AVG /AUCT T AVG DEVN HIGH-LOW

. 5A B-6 TS-68-2A/B REACTOR COOLANT LOOPSAT DEVN HIGH-LOW

. 5A C-6 TS-68-2PIQ REAC COOL LOOPS T REF T AUCT HIGH-LOW

• 5A E-7 NARROW RANGE RTD FAILURE LOOP 4 Indications:

. Control Rods inserting.

. RCS Lp 4 Indicator, 1-TI-68-67E goes up;

. 1-XX-55-5, Reactor Trip Status Panel PROT. SET 4 TROUBLE Status light TS-68-2MIN RC LOOPS T AVG IAUCT T AVG DEVN HIGH-LOW

[Ii CHECK 1-XX-55-5, Tnp status panel for any bstabIes that may be 11t AND EVALUATE Reactor Tiip uiteria with SROty npanscn with rethmdant umentafion

[2J IF reactor trips, ThEN GO TO E0, eador Trip or Safely Inf ion.

[31 IF Tavg channel failed, THEN GO TO AOP-L02, RCS LOOP RTD INSTJMENT MALRJFICflON

[41 IF rod ctml system is maift dionir, THEN GO TO AOP-C.Oi, Rod Control System Ma1functions 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.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 2 Page 8 of 51 Event

Description:

Loop #4 Cold Leg Instrument fails high Time Position Applicants Actions or Behavior DIAGNOSE the failure:

GOTO lF.. SECTION PAGE Uncontrolled rod bank movement (rod movement NOT due to actual T-avglT-ref mismatch 2 1 4 or change in reactorlturbine power)

NOTE: Step I is an immediate action step.

t STOP uncontrolled rod motion:

a PLACE rod controt in MAN ATC

b. CHECK rod motion STOPPED.

ATC Places HS-85-51 10 ROD CONTROL MODE SELECTOR in MANUAL if not 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.

3. CHECK for instrumentation malfunction:

a. CHECK alt Vital Instrument Power Boards ENERGIZED:

. ViTAL POWER BOARD UV OR BREAKER TRIP alarms tM-IC windows A-7, 8-7, C7, and 0-71 DARK ATC Ii CHECK nuclear instrumentation OPERABLE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 2 Page 9 of 51 Event

Description:

Loop #4 Cold Leg Instrument fails high Time Position Applicants Actions or Behavior

c. CHECK RCS RTDs OPERABLE. c GO TO AOPL02, RCS Loop RTD ATC lnstniment Malfunction.

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

NOTE: Tavg must be within 1°F of Tref when restoring automatic rod controL ATC 1. PLACE rod control in MANUAL.

a RESTORE Tavg as necessary USING one of the following:

• manual rod control ATC OR

. RCS boration/ditution OR

. turbine load reduction

3. CHECK loop 1 temperature channel OPERABLE.

ATC 4. CHECK loop 2 temperature channel OPERABLE.

& CHECK loopS temperature channel ATC OPERABLE

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 2 Page 10 of 51 Event

Description:

Loop #4 Cold Leg Instrument fails high Time Position Applicants Actions or Behavior

& 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 AT CHANNEL DEFEAT switch XS-68-20 to LOOP 4 C. PLACE LOOP TAVG AT REISEL switch XS-68-28 in LOOP 1,2, or 3 L EVALUATE the following Tech Specs for applicabihty:

. 33:i1 (331), Reactor Trip System SRO Instrumentation

. 3321 (3.a2), Engineered Safet Feature Actuation System Instrumentation

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 2 Page 11 of 51 Event

Description:

Loop #4 Cold Leg Instrument fails high Time Position Applicants Actions or Behavior UMNG CONDfl1ON FOR OPERATION 3.31.1 As a ivan. the reactor trip sysiem hiabumentation channels and lutedodlls of Table 3.3-1 shall be OPERABLE.

APPUCABIIITY: As shown in Table 3.3-1.

ACflON:

As shown in Table 3.3-1.

7. OverternperatureiT Four 4 2 3 Loop Operahon

8. Overpower aT Four ioep 4 2 3 1,2 8 ACTION 8- WIth the nonther of OPERABLE channels one less than the Total Number of Channels. STARTUP andlor POWER OPERATION may auceed provIded the following condidons xe sa8sfle&

a The inoperable chanael is placed in the hoped conrihion WithIn 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

14. Man Steam Generator Water LevelLow-Low C. ROS Loop T 4 (lilcep) 3 1,2 10 ACTION 10- WIth the n beroFOPERI.JLE channels one less than the TOIOI Number of Channels, STARTUP andlor POWER OPERATION may proceed provided that within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. for the alfecled protectidn set the Trip Thne Delays (F and Tjthneshoid power level for zero seconds tItus delay Is ajustedto 0% RTP.

SRO LIMITING CONDITiON FOR OPERATION 3.32:1 The Engineered Safety Feature Actua8on System (ESFAS inslnjrnentabnn charWels and inteifoths shownii Table 3,3-3 shall be OPERABLE with their trip selpolrns sete itecitwllti the vatees shown in the Nominal Trip Seo4nt column of Table 3.34.

APPLICABILITY As shown in Table 33-3.

ACTION:

a. With an ESFAS instrumentation ch or interlock trip seipoirit less conservative than the value shown in the ABowable Values column of Table 3.3-4, declare the channel inoperable and apply the apphcable ACTION reo,uirement of Table 3.3-3 unt8 the channel Is restored to OPERABLE stalu with the trip seipoint adnted cowWient wIth the Nominal Trip Setpoint value.

8. AUXILIARY FEEDWATER

e. Man Strn.Gerr.

Water LevelLow-Low

1. Start Molor4)rrven Pumps C. RCS LoopaT 4(liIoop) 2 3 1,2,3 37 It. StatTwbrneDtiven Pump o RCS LOOp.ST 2 3 1,2,3 37

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 2 Page 12 of 51 Event

Description:

Loop #4 Cold Leg Instrument fails high Time Position Applicants Actions or Behavior ACTION 37 - Wth Je .iumber o CPERALE hns less ii the Tot D.n&s. STAI.TUP a.i*c- PW2 CPEATfO ia proc*E rov-e: :h 5 r.c.. c:ea roec:cr . e -T.r-. D.ys T thrhc p*e :et ecc-:s te eIa ajListe R.

SRO. .

Enters LCO 3.3.1.1 Action 6 and Action 10 and enters LCO .3.3.2.1 Action 37 NOTE: It performing AOP in conjunction with AOP-Li 1 for an Eagle LCP failure, then actions to hard trip bstables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> UNLESS affected loop is restored to operable status by resetting Eagle rack.

8. NOTIFY l&C to renoe failed TAVfl Tloop from service USING appropnnte Appcndix.

RCS INSTRUMENT PROT LOOP LOOP APPENDIX NUMBER CH T-8--2 I A (T-41/412 2 T-53-2 (T-421 i422 T-68-44 III C

([-431 432) 4 iv D (T-$-41144.l 9.. IF automatic rod control is available, THEN RESTORE rod control to AUTO USING 0-50-85-1

10. 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 addressed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 3 Page 13 of 51 Event

Description:

Condenser Vacuum Leak with Vacuum Pump auto start failure Time I Position 1 Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 3, Condenser Vacuum Leak Indications available:

. O-M-12A, D-4, 1-RA-90-99B COND VAC PMP LO RNG AIR EXH MON INSTR MALFUNC

. 1-M-1 Main Generator load decreasing.

. 1-AR-M2-C, C6, CONDENSER VACUUM LOW

• Condenser Vacuum degrading (Monitored on recorder or ICS), Air in leakage increasing P5-2-TB CONDENSER VACUUM Low

[1] VERIFY alarm iiia iTRI reccder.

[2] VERIFY requWed number of coW pumps are inserlce

[3] CHECK condenser vacun exhaust on ICS using either:

a. 1F2700A if 1-FCV-2-255 is dosed

b. 1F2263A If 1-FCV-2-25S is on.

[4] IF condenser vacuum exhaust flow >45 CFM, THEN ENSURE i-FCV-2-255 OPEN.

[5] IFalarmisvatld,ThEN GO TO AOP-SL0Z Loss of Conde,ser Vc,urn

[6] WHEN vacuum and air inleakage are returrd to nonnal, ThEN ENSURE i-FCV-2-.255 CLOSED and In PAUTO BOP Responds to ARP 1-AR-M2B C-6 Examiner Note: If the crew initiates a manual (or auto) Main Turbine/Reactor trip go to Event 6, page 38.

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 trip automatically when condenser pressure reaches 3.9 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 201 2-302 Scenario # 2 Event# 3 Page 14 of 51 Event

Description:

Condenser Vacuum Leak with Vacuum Pump auto start failure Time Position Applicants Actions or Behavior 1 MONITO.R condenser pressure for turbine tiip cilteria. [C.i]

a. CHECK turbine: Io3J greater BOP than or equal to 30%.

11 CHECK condenser pressure less than or equal to 21 psia

2. ENSURE all available condenser BOP vacuum pumps RUNNING.

EI condenser vacuum breaker BOP CLOSEO CAUTION: if CCW intake blockage has occurred restifting in pump cavitation (sWhging amps) or loss of suction to CCW pumps, continued CCW pump operation could result in pump damage.

4. MONITOR CCW Pump operation:

a. CHECK for any of the following: a. GO TO Step 5

• less than two CCW Pumps RUNNING on affected unit. [M-15}

BOP [c.11 OR

. Indication of severe intake blockage resulting in cavitation or imminent loss of CCW pump suction.

5. CHECK turbine gland seal steam supply GOP pressure between 120 psig and 130 psig

[M-2. P1-47-i 87J.

6 CHECK HP steam seal steam supply BOP between 16 psia and 2Opsia

[M-2, P1-47-i 891.

7. CHECK annunciator PIS-47-196

- TURBINE SEAL. STEAM PRESS.

U ABNORMAL DARK {M-2A. window A51.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O12-302 Scenario# 2 Event# 3 Page 15 of 51 Event

Description:

Condenser Vacuum Leak with Vacuum Pump auto start failure Time Position Applicants Actions or Behavior 8 DISPATCH an operator to perform the foflowwig:

a. CHECK loop seal on vacuum breaker [Turbine Bldg. 706 elevl.

b. CHECK the following components:

• Main Turbine rupture discs intact BOP

• Condenser shell intact

• Main Feeciwater Pump rupture discs intact

• Main Turbine exhaust hoods

c. VERIFY Main Steam Dump Drain Tank level control operating properly.

CHECK main turbinelgenerator on line.

BOP

10. CHECK condenser pressure STABLE or REDUCE tultine load as necessary DROPPING. to maintain condenser vacuum USING one of the following:

. AOP-C.03, Rapid Shutdown or Load BOP Reduction (preferred)

OR

. Valve Position Lirnrter

SRO Transitions to AOP-C.03 Rapid Shutdown Or Load Reduction.

1 1. ENSURE control rods controlling in ATC ALITO 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 sufficiently lowered power.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 16 of 51 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior Simulator Operator: No action required for Event 4, 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 Appendtx 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 tinal power level:______

. Reactivity Management expectations:

e Unit Supervisor shall concur with all reactivity manipulations

. Ensure reactor responding as expected using diverse indications

• Tavg-Tref Mismatch requirements:

. 3°F control band B 5°F 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

. Boration source:

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

. CRC) WILl stop secondary plant equipment using App. C.

. If time permits, review expected annunciators (ex. Computer Alarm, Upper and Lower Flux 13ev)

. 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 2012-302 Scenario # 2 Event# 4 Page 17 of 51 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

• :: 0 fchoosesapower reductioft rate of i%flnal power level of 90% and. BAT as the boration source.

2 NOTIFY following personnel of rapid shutilown or load reduction:

. Load Coordinator [C.1j CREW

• chemistry

• Radiation Protection

• Plant Management CREW Makes notifications as required.

3. MONITOR reactoriturbine trip NOT required CREW USING Appendix B, Reactor and Turbine Trip Criteria Examiner note: Appendix B reactor and turbine trip criteria see page 24.

NOTE: Step 4 should be handed cIT to opposite unit or extra operator (1 available).

If NO operator is available, notifications should be performed concurrently with subsequent steps when time permits)

4. ENSURE following personnel notified of rapid shutdown or load reduction: [C.11 a Balancing Authority (Load Coordinator)

(751-7547).

CREW a Chemistry

• Radiation Protection a Plant Management NOTE: Boration volumes and flowrates listed in this procedure are recommendations and may be adjusted as necessary

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 18 of 51 Event

Description:

Rapid Power Reduction Time Position fl Applicants Actions or Behavior

& INITIATE boration:

a. CHECK rod control AVAiLABLE:

ATC

• Control Bank D rods capable cit being moved

• NO dropped or misaligned rods ifl Control Banl D.

5 b CHECK Control Bank 0 group position greater than 200 steps.

ATC c CHECK boration capability from BAT AVAILABLE.

d DETERMINE recommended boration volume from BAT:

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

OR SRO

• logalforeach 1%powerreduction (from current power level)

OR

• volume recommended by Reactor Enqineering

• • *Detérmines 100 gal to reduce power from 100% tb 90%. : *.***

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

LOAD REDUCTION BORATION SRO RATE(%Imin) FLOWRATE 1% l5gpm 2% --3ogpm 3% 45gpm rduc rate.

if. ENSURE concurrence obtained from ATC STA for boration volume and flowrate.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 2 Event# 4 Page 19 of 51 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

g. CHECK the following conditions met:

. normal boration flowpath (blender)

AVAiLABLE ATC

. desired load reduction rate is less than 4% per minute

. time is available for normal boration.

h. INITIATE normal boration ATC USING Appendix H..

i. CONTROl. bomtion flow as required ATC to inject desired bonc acid volume.

Examiner note: Appendix H Actions are listed in the following steps.

APPENDIX H:

NORMAL BORATION

[1] RECORD desired boration volume and tlowrate: 0 ATC Volume (gal)

Flowrate (gpm Atc Reords 100 gal at 15 gpm ATC (2j PLACE [HS-62-140A] Makeup control to STOP position.

PLACE IHS-62-1408] Makeup mode selector switch in BORATE position..

NOTE Boric Acid conirollér setting is twke the desired flow rate..

MaxImum 8. ACid flow is -4gpm.

[4] ADJUST IFC-62-1391 BA flow controller setpoint for desired flow rate. 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 20 of 51 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

[5] ADJUST FFQ62-139l BA integrator (batch counter) to desired boric acid volume.

[6] PLACE 1KS42-140A1 Makeup Control Switch mode selector switch to START. El

[7] ENSURE boric acid transfer pump aligned to blender ATC in FAST speed. El

[8] IF desired boric acid flow rate NOT obtained, THEN ADJUST one or both of the following as necessary:

ATC

. IFC-62-1 391 BA flow controller El

. recirculation valve for BAT aligned to blender. El ATC Adjusts FIc-62-139 as required.

ATC ENSURE desired boric acid flow !nd!cated on Fl-62-139. F I

[10] RECORD time when boration flow established: El ATC Time:

. ATC . . Records time bération initiated. .

[11] WHEN required boric acid oiume has been added AND control rods are above low-low insertion limit, THEN ATC PERFORM the following:

[a] PLACE IUS-62-140A1, Makeup Control to STOP position. El

[b] ENSURE IFC-62-1421, Primary Water to Blender Flow Controller in AUTO with dial indicator set at 35%. El

[c] ADJUST IFC-62-1391, Boric Acid Flow Controller to desired blend solution USING TI-44 Boron Tables. El

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 21 of 51 Event

Description:

Rapid Power Reduction Time fl Position I Applicants Actions or Behavior

[d] PLACE YHS-62-140B1, Makeup Mode Selector ATC Switch in AUTO position. LI ATC Places HS-62-140B to AUTO.

ATC [e] PLACE rHS-62-140A1, Makeup Control to START. LI

[f] ENSURE boric acid transfer pumps running in SLOW speed.

CAUTION: If borating from the RWST, Turbine Load Reduction Rate greater than 2% per minute could result in violating Rod Insertion Limit.

Ii INITIATE 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% antI 3% per minute It borating via normal boration (App. H)

OR

• 2% per minute if borating from RWST

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 22 of 51 Event

Description:

Rapid Power Reduction Time I Position Applicants Actions or Behavior b ADJUST setter for desired power level:

BOP DESIRED RECOMMENDED RX POWER LEVEL SETTER VALUE 90% 76

6. c. VERIFY boration flow established.

BOP

d. INITIATE tuitine load reducton by depressing GO pushbutton.

BOP Depresses GO jushbutton.

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

7. MONITOR T-avgiT-ref mismatch:

a. CHECK T-ret indication a. PERFORM the following:

AVAILABLE.

1) MONITOR Program T-avg for current reactor power USING 11-28 Figure 3 or ICS (NSSS I BOP. Program Reactor Average Temperature) 2> USE program T-avg in place of T-ref.

3) MAINTAIN T-avg within 3F of program 7-avg USING manual rod ATC conliol.

4) ADJUST turbine load rate as necessary.

5) IF mismatch between 7-avg and program value CANNOT be maintained less than 5SF, THEN TRIP the reactor and GO TO EM, Reactor Tilpor Safety ftjection.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 23 of 51 Event

Description:

Rapid Power Reduction Time Position H Applicants Actions or Behavior BOP 8 MONLTOR automatic control at MEW pump speed AVAILABLE

9. STOP secondary plant equipment BOP USING Appendix C, SecondaiyP!an Equipment Examiner Note: Appendix C, Secondary Plant Equipment starts at page 25.

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 the Lead Examiner may go to the next event starting at page 35.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 24 of 51 Event

Description:

Rapid Power Reduction 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 P9 (50%) with one of the following:

Uncontrolled rod movement which CANNOT be

• high vibration on muluple bearings stopped by pladng rods in MANUAL tPo.P-c.o1)

OR Loss of SIG level control:

• abnormal noiselvibration apparent level dropping or rising toward trip setpoint and level CANNOT be restored (AOP-&ai)

More than one dropped rod o-coi>

T-avgIT-ref mismatch CANNOT be maintained less than 5°F (refer to Step 7 or App. E) 30% turbine load: <30% turbine load:

Condenser Pressure >27 psia AND CANNOT Condenser Pressure> 112 psia be restored within 5 minutes lAoP-ao2) (AOP-.&2)

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 Statar Cooling Water temp 90°C

• Safety injection OR Stator DIP 12 psig below normal

• Power Range high flux 109%

• Both MFPTs tripped

• Power Range flux rate +/-5% in 2 seconds a Low Auto Stop Oil pressure 45 psig

• Pressurizer high level 92%

• High SIC level 81% narrow range

• Pressurizer pressure 1cm 1970 psig

• Main Turb Bearing OH low pressure 7 psig

• Pressurizer pressure high 2385 psig

• Thrust Bearing Oil high pressure 60 psig

• RCS low flow 90% a Turbine Overspeed 1980 1pm

• RCP undervoltage &022 icilovofts a Loss of EHC pressure RP undertrequency 560 Hz

• Generator PCBs tripped

• OTAT 115% (variable)

• OPAT 1087% (variable)

• SIC low level 101% [15% EAMI

• SSPS general warning in both trains

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 25 of 51 Event

Description:

Rapid 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) D

• stopping secondary plant equipment 0 NOTE I If reactor power will be reduced below 50%., 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..

t2] 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: (NIA valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN q 1A 1-VLV-3-576 TB eL 706, Northeast corner of IA condenser C 18 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 C 28 2-VLV-3--577 TB ef. 706, Southeast corner of 2A condenser C

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 4 Page 26 of 51 Event

Description:

Rapid Power Reduction APPENDIX C

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

- power is being reduced as directed by AOP-SAJI (Main Feedwater Malfunctions) or AOP-S04 (Condensate or Heater Drain Malfunctions)

• leaving secondary pumps in service is desired 1

THEN GO TO Step [8j C

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

[a] ENSURE one Cond Demin Booster Pump STOPPED. C fb] ENSURE associated suction valve CLOSED:

COND DEMIN OR

{ B OR FCV-2--285 C FCV2-280

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 4 Page 27 of 51 Event

Description:

Rapid Power Reduction L63 WHEN turbine impulse pressure is approximately 70-75%,

THEN PERFORM the following:

[a] ENSURE one Condensate Booster Pump STOEPPED. 0

[b] ENSURE associated CBP suction valve CLOSED:

CONDENSATE BOOSTER PUMP SUCTION VALVE CLOSED I A FCV-2-94 U OR FCV-2-87 U OR FCV2-8i 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 necessa,y)

• 1-50-2/3-i Section 72 OR

• 2-S0-2/3-1 Section 7.3

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 28 of 51 Event

Description:

Rapid 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.

[b] ENSURE suction valves CLOSED:

COND DEMIN BOOSTER PUMP SUCTION VALVE CLOSED t A FCV-2-290 B FCV-2-285 U C FCV-2-280 U

[C] STOP one No. 3 Heater Drain pump. U

[d] STOP one No.7 Heater Drain pump. U

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 4 Page 29 of 51 Event

Description:

Rapid Power Reduction

[8] IF reactor power will be maintained greater than 50%,

THEN GO TO Notes prior to Step [1 i]

CAUTION Isolation of all three intermediate heater strings could occur if turbine is tripped prior to fully Opening LCV-6-105A and B using AppendIx J or K.

[9] WHEN reactor power IS ess than 60%

AND AtJO 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 Vlves

[C] CLOSE isolation valves from #3 l-ltr Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED I FGV-6-1 08 Htr Drain Tk Pump 3 to Htr String A El FGV-6-1 09 Htr Drain Tk Pump 3 to Htr String B El FCV-6-110 HtrDrainTk.Pump3toHtrStringC El

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 30 of 51 Event

Description:

Rapid 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 corttroller should remain in MANUAL to prevent undesired opening of bypass valve.

[IOJ 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. C

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

1) MAINTAIN MFW Bypass Req Valve in MANUAL for SIG with MFW Req valve in MANUAL C

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

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 4 Page 31 of 51 Event

Description:

Rapid 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)0165% (Unit 2)

NOTE 2 AFW start function on loss of both MFW pumps is inoperable when a MFW pump is RESET but NOT pumping forwarct LGO 3.32.1 (Unit 1) or 3.3.2 (Unit 2 allows AFW start channel to be inoperable for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> when shutting down a MFWR

[II] WHEN it is desired to remove one MFW pump from serv AND power level is less than applicable limit

• turbine impulse pressure less than approximately 45%

OR

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

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

UNIT MFWP VALVE LOCATION OPEN IA 1-VLV-3.576 TBeL7OS,NortheastcorneroflAcondenser C 18 1-VLV-3-577 TB et. 706, NortheastcomeroliA condenser C 2 2A 2-VLV4-576 TB eL 706, Southeast corner of 2A condenser C 28 2-VLV-3-577 TB el. 706, Southeast corner of 2A condenser C Eb] THROTTLE OPEN recirc valve in MANUAL 30-50% OPEN) for MFWP to be removed from service. C

[ci PLACE speed controller in WANUAL far MFWP to be removed from service LdI REDUCE speed gradually on MFWP to be removed from service. C

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 4 Page 32 of 51 Event

Description:

Rapid Power Reduction f ii] (Continued) fej ENSURE proper loading on remaining MFWP. U

[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 MFWP U OR

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

• OBTAIN SRO concurrence that MFWP flow is sufficiently low to allow tripping MFWR U

[g] WHEN MFWP is unloaded sufficiently, THEN TRIP affected MFWR U

[Ii] CLOSE recirc valve for MFWP removed from servica fi] CLOSE recirc valve Manual Isolation inlet valve for MFWP removed from servica U U] OPEN drain valves for MFWP removed from service: fM-3]

• [HS4S-14], MFWP A drain valves .

U OR

• 7 MFWP B drain valves.

fHS464fl U

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 2 Event# 4 Page 33 of 51

[vent

Description:

Rapid Power Reduction

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

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

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

VALVE DESCRIPTION CLOSED FCV-6143 Htr Drain Tk Pump 7 to Fltr String A 0 FCV-6-163 Htr Drain Tk Pump 7 to Htr String B U FCV-6-184 Htr Drain Tk Pump 7 to Htr Sthng C 0

]13] VThEN 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 [S] U

[c] STOP one of two remaining Condensate Booster Pumps U (steD continued on next paqe)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event# 4 Page 34 of 51 Event

Description:

Rapid Power Reduction L13] (Continued)

[d] ENSURE associated CBP Suction vaive CLOSED:

OR OR FCV-2-87 U J C FCV-2-81 I

[e] STOP one of three Hotwell Pumps. U

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

(may be assigned to another operator or delayed if necessary) 1-SO-213-i Section T2 OR

• 2-SO-2/3-i Section 7.Z

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 5 Page 35 of 51 Event

Description:

Grid Disturbance with MVAR Adjustment.

Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 5.

Indications available:

Annunciator:

1-M-6

. Main Generator MVAR increasing IA, A-6 GEN EXCITER FIELD OVERCURRENT

. ICS Alarm GEN EXCITER FIELD OVERCURRENT NOTES I) if Excitation Limiter (II) operation than Regulator will automatically reduce excitation (alarm annunciates and immediately clears when excitation is reduced).

2) If Overexcitation Relay 1(1 has operated then neither auto nor manual control of the base adjuster will be available.

Corrective 11 DISPATCH personnel to Exciter Cbide and check protective relay drawer for Action: alarm(s) (Forcing alarm is indicative of regulator failure).

121 IF either of the following conditions are reached with a rising trend or the condition is sustained:

e l1-EI-51-7l E.citerAmps 275 amps, OR

. 60kV Unit Board voltage 7800 volts, THEN PERFORM the following:

[213 IF Reactor Pawergreaterthan P4(50%). THEN TRIP Reactor. AND GO TO SO. Reactor Trip or Safefy lnjection

[221 IF Reactor Poweris less than P4 (50%), THEN TRIP the turbine, AND GO TO AOP-S08, TurbIne Tnp.

[3J ENSURE 11 ..EI-57-1 51 Generator Volts less than 24.8kV in accordance with GOI-6. Onaite Power System Voltage Limits.

[41 ENSURE I-EI-5741 Generator Vars less than or equal to 3110 MVARS outgoing.

.[5} ATTEMPT to manually reduce enerator Voltage to dear alarm.

(8[ CONTACT load dispatcherto determine if abnormal grid conditions may have.

caused alaxm.

BOP Responds to ARP 1-AR-MIA 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.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 5 Page 36 of 51 Event

Description:

Grid Disturbance with MVAR Adjustment.

Time fl Position Applicants Actions or Behavior Examiner Note: The crew may use guidance in GOI-6 to lower Main Generator MVARs.

Crew Performs a Crew Brief as time allows.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in th 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 Main Generator Voltage has been adjusted.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 6, 7, 8, 9 Page 37 of 51 Event

Description:

Loop #4 SIG Feed Line Break Inside Containment/Loss of AFW/RCS Bleed and Feed.

Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event, 6 SJG #4 Feed Line Break Inside Containment.

Indications available:

Annunicators:

1-M-3

• 3C C-6, LS-3-171D STM GEN #4 LEVEL LOW

• 3C E-6, LS-3-175D STM GEN #4 LEVEL LOW 1-M-5

• 5A A-7, FS-3-35A STEAM GEN FEEDWATER FLOW HIGH

• 5A B-7, LS-3-42D STEAM GEN LVL HIGH-LOW DEVIATION

• 5C B-3, MS-30-241 LOWER COMPT MOISTURE HI.

1-M-6

• GB D-1, LS-3-107D STM GEN LOOP 4 LOW FW FLOW LOW WATER LEVEL

• 68 D-4, LS-3-106B STEAM GENERATOR LOOP 4 LOW LOW WATER LEVEL

• 6E C-6, ZS-61-186 ICE CONDENSER LOWER INLET DOOR OPEN Indicators:

1-M-4

• 1-Fl-1-103A, 103B, SG-4 FW INLET FLOW CH-1 & 2: increasing feedwater flow

• 1-LI-3-11O, 107, 106, SG-4 NR LEVEL: decreasing level

Appendix D Reauired Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event# 6,7,8,9 Page 38 of 51 Event

Description:

Loop #4 SIG Feed Line Break Inside Containment/Loss of AFWIRCS Bleed and Feed.

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

1. VERIFY reactor TRIPPED:

Reactor tIi) breakers OPEN

• Reactor tiip bypass breakers DIS0NNECTED or OPEN ATC Rod bottom lights LIT

• Rod position indicators less than or equal to 12 steps.

• Neutron flux DROPPING

2. VERIFY turbine TRIPPED:

• 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-0.0, Loss of All AC Power.

4.. DETERMINE if SI actuated:

ATC

• ECCS pumps RUNNING.

• Any SI alarm UT [M-4Dl.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event# 6, 7,8,9 Page 39 of 51 Event

Description:

Loop #4 SIG Feed Line Break Inside ContainmenULoss of AFW/RCS Bleed and Feed.

Time I ...

Position Applicants Actions or Behavior an 1AMSIVSIG# d ce. S-3 71 A d 17 A AFW to G oC e

ctions. .

L ce 68-8A, 31A. 50A and 73A to STOP based on FOP actions.

5 PERFORM ES-O.5, Equipment BOP Verifications WHILE continuing in this procedure SRO/ATC Continue with the performance of E-O REACTOR TRIP OR SAFETY INJECTION BOP Performs ES-O.5, Equipment Verifications go to page 45 for details SRO Addresses foldout page, see next page for details.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # 6, 7, 8, 9 Page 40 of 51 Event

Description:

Loop #4 SIG Feed Line Break Inside ContainmentlLoss of AFW/RCS Bleed and Feed.

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

• Ptase B isolation, THEN STOP all RCP&

EVENT DIAGNOSTICS

• IF any SiC pressure is dropping uncontrolled, ThEN PERFORM the following:

a CLOSE MSIV5 and MSIV bypass vaive&

b. IF any S/C pressure continues to drop uncontrolled, THEN PERFORM the following:

1) ENSURE SI actuated.

2) IF at least one SIC is intact (S/C pressure controlled or rising).

THEN ISOLATE MW to faulted S/C(s):

• CLOSE AFW level control valves for faulted S/C(s)

• IF any AFW valve for faulted S/C CANNOT be CLOSED. THEN PERFORM Appendix E, Isolating AFW to Faulted S/C.

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

• total AFW flow greater than 44:Q gpm OR

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

• IF both trains of shutdown boards de-energized, ThEN GO TO ECA-(L0, Loss of All AC PoweE TANK SWITCHOVER SETPOINTS

• IF CST level less than 5%, THEN AUGN AFW suction to ERCW

• IF RWST level less than 27%, THEN GO TO ES-I A Transfer to RI-IR Containment Sump

I-kppenclix U Requhed Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # 6, 7, 8, 9 Page 41 of 51 Event

Description:

Loop #4 SIG Feed Line Break Inside Containment)Loss of AFW/RCS Bleed and Feed.

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% ADVj in all SIGs, THEN START AFW pumps and ALIGN valves as necessary to raise AFW flow greater than 4.40 gpm.

b CHECK narrow range level b. MAINTAIN total feed flow greater than 10% [25%ADV] greaterthan 440 gprn ATC hi at least one SIG UNTIL narrow range level greaterthan 10% [25%AD\

in at least one Sf0.

IF AFW flow greater than 440 gpm CANNOT be establlsbed, THEN PERFORM the following:

1) MONITOR status trees.

2> GOTOFR-N.1,Lossof Secondary Heat Sink.

Examiner Note: Crew should recognize Loss of Heat Sink entry conditions, total AFW flow less than 440 gpm due to a loss of all AFW pumps, and implement 1-FR-0 verification and transitions to FR-H.1.

SRO Transitions to FR-H.1, Loss of Secondary Heat Sink, go to next page.

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.: 2012-302 Scenario # 1 Event # 8 Page 42 of 51 Event

Description:

Loss ofAFW and Charging, FR-H.1 Bleed and Feed Time Position Applicants Actions or Behavior CAUTION Feeding an intact or Ruptured S!G is preferred to feeding a Faulted SIG.

Thermal stresses from feeding a Faulted SIG could rupture tubes, resulting in a Faulted-AND-Ruptured S!G.

SRQ Directs performance of FR-H.1.

i DETERMINE procedure app!;cabiht a CHECK the folloing: a GO TO Step 2.

• Total feed flow less than 440 gpm due to operator action SRO directed by another procedi:r AND

. Total feed flow capability of greater than 440 gpm AVAILABLE.

2. MONITOR RWST level ATC greater than 27%

I CHECK if secondary heat sink required:

a RCS pressure greater than any non-Faulted SIG pressure.

ATC

b. RCS temperature greater than 350°F

4. MONITOR at least one CCP available STOP all RCPs ATC GO TO Cauiion priorto Step 17

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2012-302 Scenario # 1 Event # 8 Page 43 of 51 Event

Description:

Loss of AFW and Charging, FR-H.1 Bleed and Feed Time Position Applicants Actions or Behavior CAUTION Any delay in completing Steps 17 through 20 could result in fuel damage.

ATC 11. ACTUATE SI.

1. VERIFY RCS feed path:

a. CHECK CCPIT flow established: a. PERFORM the following to establish ATC ccrr flow:

• CCPIT valves OPEN

• ALIGN valves as necessaiy

• CCPIT flow indicated.

• ENSURE CCPs RUNNING.

b. CHECK ALL CCPs and Si pumps b. PERFORM the following:

RUNNING.

• ENSURE ECCS valves aligned USING Appendix A.

• START CCPs and SI pumps.

ATC IF at least one CCP or SI pump is running.

THEN GO TO Step 19.

CREW Performs Appendix A. as required. see next_page SRO Transitions to step 19

19. ESTABLISH RCS bleed path:

a. CHECK power to pressurizer PORV block valves AVAILABLE.

ATC b CHECK pressurizer PORV block valves OPEN.

C. OPEN both pressurizer PORVs.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2012-302 Scenario # 1 Event # 8 Page 44 of 51 Event

Description:

Loss of AFW and Charging, FR-H.1 Bleed and Feed APPENDIX A ECCS VALVE ALIGNMENT

1. iF ES-i .3 Containment Sump Recirculation has NOT been performed, THEN PERFORM the following:

a ENSURE CCP suction aligned to RWSI:

LV-B2-135 or LC1-62-136 OPEN U

• LV-62-i 32 or LV-62-133 CLOSED U

b. ENSURE FCV-63-5 Si Pump suction OPEN. U

2. ENSURE CCPIT valves OPEN:

• FCV-63-.25 or FCV-63-26 U

• FCV-63-39 or FCV-63-40 U

3. ENSURE SI Pump suction valves OPEN:

o FCV-6341 (Train A) U

• FCV-63-48 (Train B) U

4. ENSURE Si Pump injection valves OPEN:

• FCV-63-.22 [1

• FCV-63-152 (Train A) U

° FGV4SISS (Train B) U END OF TEXT ATC Verifies Appendix valve alignment Lead Examiner may terminate the scenario the crew has completed FR-H.1 Step 19, Feed &

Bleed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event# ES-0.5 Page 45 of 51 Event

Description:

Equipment Verifications Time Position fi Applicants Actions or Behavior ES-O.5 Actions BOP t VERIFY D/GS RUNNING BOP 2. VERIFY DIG ERGW supply valves OPEN.

3:. VERIFY at least four ERCW pumps BOP RUNNING.

4.. VERIFY ccs pumps RUNNING:

• Pump IA-A t2A-A)

BOP

• Pump 1 B-B (2B-B)

• Purnpc-S.

BOP 5. VERIFY ECTS faiIS RUNNING.

BOP 6. VERIFY generator breakers OPEN.

7. NOTWY at least Iwo AUOs to report BOP to MR to be available for local actions.

8. VERIFY AFW pumps RUNNING:

BOP a. MDAFWpirnps Ii. TO AFW pUmp.

NOTE AFW level control valves 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 S/C.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 2 Event # ES-0.5 Page 46 of 51 Event

Description:

Equipment Verifications Time fl Position Applicants Actions or Behavior

9. CHECK AFW valve alignment:

a. VERIFY MD AFW LGVs in AUTO.

BOP b. VERIFY TO AFW LCVS. OPEN.

c. VERIFY MD AFW pump recirculation valves FCV-3-40c. and FcV3-4Oi CLOSED.

10. VERIFY MFW isolation:

a. CHECK MFW pumps TRIPPED.

b. ENSURE the following:

BOP MFW regulating valves CLOSED

• MEW regulating bypass valve controllers in MANUAL with output ZERO

• MFW isolation valves CLOSEIX ii. MONITOR EGGS operation:

a. VERIFY ECCS pumps RUNNING:

CCPs RHR pumps BOP

• Slpumps b VERIFY CCP flow through CCPJT.

c. CHECK RCS pressure less than 1500 psig.

Aendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 2 Event # ES-0.5 Page 47 of 51 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior d VERIFY SI pump 110w..

e. CHECK RCS pressure e. GO TO Step 12.

less than 300 psg

1. VERIFY RI-IR pump How..

12. VERIFY ESE systems ALIGNED:

a.. Phase A ACTUATED:

• PHASE A TRA!N A alarm LFF

[M-6C, 85]..

• PHASE A TRAIN 8 alarm UT

[M-.6C. 66]..

b. Cntmt Vent Isolation ACTUATED:

• CNTMT VENT ISOLATION TRAIN A alarm LIT [M-6C, CS].

• CNTMT VENT ISOLATION TRAIN B alarm UT [M-6C, C6].

c. Status monitor panels:

BOP

• GG DARK

• 60 DARK 6E LIT OUTSIDE outlined area

• 61-I DARK

• 6JL1T 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 201 2-302 Scenario # 2 Event # ES-0.5 Page 48 of 51 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 IN ITIATED:

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 fM-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 2012-302 Scenario # 2 Event# ES-0.5 Page 49 of 51 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior 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 reiief isolation valves sloulc be closed:

BOP a CHECK containment pressure a. GO TO Step 15.

greater than I 5 psig.

15. CHECK secondary and containment raci monitors USING the following:

BOP

• Appendix A, Secondary Rad Monitors

• Appendix B, Containment Rad Monitors.

APPENDIX A SECONDARY RAD MONITORS

1. IF SI occurred on Unit 1.

THEN CHECK following Tad monitors including available trends prior to isolation:

• Condenser exhaust recorder I -RR-90-1 19

• SIC blowdown recorder 1-RR-90-120

• Unit I Main steam line rad monitors [1-M-30]

• Post-Accident rad recorder 1-RR-90-2680 points 3 (blue). 4 (violet), 5 (black), and 6 (tUrquoise).

[1-M-31 (back of 14.1-30)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 201 2-302 Scenario # 2 Event # ES-0.5 Page 50 of 51 Event

Description:

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

1. IF SI occurred on Unit 1.

ThEN CHECK following rad monitors:

BOP

• Upper containment post-accident raci monitors i-RM-90-271A and 1-RM-90-272A NORMAL [1-M-30J a Lower containment post-accident rad monitors 1-RM-90-273A and 1-RM-90-274A NORMAL [1-M-30]

a Containment rad recorders 1-RR-90-112 and 1-RR-90-106 NORMAL fO-M-121 (prior to isolation).

16. WHEN directed by E-0, THEN B-s PERFORM Appendix I), Hydrogen Mitigation Actions.

17. CHECK poclet sunp pumps STOPPED:

IM-15, upper left comeij a HS-77-410. Rx Bldg. Aux Floor and BOP Equipment Drain Sump pump A a 1-15-77-411, Rx Bldg Aux Floor and Equipment Drain Sump pump B.

16. DISPATCH personnel to perForm BOP EA-0-1, Equipment Checks Foilowing ESF Actuation.

19. ENSURE plant announcement has been BOP made regarding Reactor Trip and SL

20. PERFORM Appendix E, Spent Fuel BOP C1:ing Actions, as time perTnit&

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-301 Scenario# 1 Event# Page 51 of 51 Event

Description:

Critical task Critical Tasks: Critical Task Statement

1. Manually trip the main turbine before an orange path challenge develops to either the subcriticality (5) or the Pressurized Thermal Shock (P) CSF or before transition to ECA 2.1, whichever happens first.

2. Manually trip all Reactor Coolant Pumps prior to completing step 4 of FR-H.1, LOSS OF SECONDARY HEAT SINK.

3. Initiate RCS bleed and feed so that the RCS depressurizes sufficiently for the Safety Injection pump flow to occur prior to completing step 19 of FR-H. 1.

Time: Now Date: Today Unit I MCR Checklist (751-6338 ID 950848) Then Press 2 1Revtew WrcnrShi!

Mode 1, 100% Power NRC phone Authentication Code PSA Risk: Green Grid Risk: Green RCS Leakage ID .14 gpm, UNID .05 gpm Until 0800 AI2B After 0800 C34D 1OItRM Epuipment1NOP Time INOP OWner NONE

!1 V iijc Aiqn O1TRM TI Eci,iine1it1NOP TmJ4OP I B-B EDG out of service for maintenance LCO 3.8.1.1 Action B A Train Maintain 100% steady state power.

4tje %tV !VW.

Review current TS/TRM/ODCM/FPR Current Qualification Status Required Actions Review the current controlling Reactivity Walkdown MCR Control Boards with off-going Management Plans Operator SR/PER reviews complete for previous Review Narrative Logs shift (SM/US/STA) (previous day and carry-over items)

Relief Time:________________ Relief Date:__________________

v Operators unds, Burdens, ii U LI Review . Ou.II actions and Challenges (applicable Unit/Station) (first shift of shift week)

L1 Review changes in Standing/Shift orders Review changes to TACFs issued since last shift worked) (since last shift worked)

Review Control Room Deficiencies El Review Component Deviation Log (first shift of shift week) (Active Procedures)

Time: f4 Date: Today Abnormal Equipment Lineup/Conditions:

1-RM-90-119 OOS SR 111623061. 1-RM-90-99 is in service.

I AUXILIARY BUILDING (7775) (593-2469)

All equipment operating or operable.

[ BtIØ777 VW W iV 2V N All equipment operating or operable.

I B-B EDG out of service

Time: Now Date: Today Required Additional Monitoring and Contingencies (UDdated and Maintained by SM Issue Required Action Expiration Date ODMI

UNIT ONE REACTIVITY BRIEF Date: Today Time: Now iAftio RCS Boron: 749 ppm Today BA Controller Setpoint: 18% RCS B-b Depletion: 40 ppm Operable BAT: A BAT A Boron: 6850 BAT C Boron: 6850 RWST Boron: 2601

• ppm ppm ppm Nominal Gallons per rod step from 219: 7 gallons of acid, 42 gallons of water Verify boric acid flow controller is set at Adjusted BA Controer Setting iaw 0-SO-62-7 section 5.1 r Estimated values foral° change in Tave I

. Gallons of acid: 32 Gallons of water: 227 Rod Steps: 5 F:.* .

Estimated rdslborn for emergency step powerreduction **

(Assuming Xenon equNibrium and noreactivity.effects.due to Xenon. 2/3 total reactivity.from rods,...1/3 from boron)

Power reduction amount Estimated Final Rod Estimated boron addition Position 10% 198 Steps on bank D 107 gallons 30% 175 Steps on bank D 312 gallons 50% 156 Steps on bank D 506 gallons These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until one week from now.

• Number of dilutions: 3 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 40 Gallons per boration: 0 Rod steps out: 0 Total amount diluted: 120 Total amount borated: 0 Net change: 0 IN/Out Number of dilutions: 3 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 40 Gallons per boration: 0 Rod steps out: 0 Total expected dilution: 120 Total expected boration: 0 Net change: 0 In/Out Remarks:

Next Unit I Flux Map is scheduled three weeks from now Unit Supervisor:

Name/Date

Operations Chemistry Information Sample Point Units Boron Date I Time Goal Limit UI RCS ppm 749 Today I Now Variable Variable U2 RCS ppm 816 Today / Now Variable Variable Ui RWST ppm 2601 Today / Now 2550 2650

- 2500 2700 U2 RWST ppm 2569 Today I Now 2550 2650

- 2500 2700 BAT A ppm 6850 Today / Now Variable Variable BAT B ppm 6850 Today / Now Variable Variable BAT C ppm 6850 Today I Now Variable Variable Ui CLA #1 ppm 2556 Today I Now 2470-2630 2400-2700 UI CLA #2 ppm 2575 Today / Now 2470-2630 2400-2700 Ui CLA #3 ppm 2591 Today I Now 2470-2630 2400-2700 Ui CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today I Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today I Now 2470-2630 2400-2700 U2 CLA #3 ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today I Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today I Now > 2050 > 2000 Ui RCS ppm 1.1 Today/Now >1 >1 U2 RCS ppm 2.43 Today! Now 2.18-2.48 2.33 Indicator Units UI Date!Time U2 DatelTime SI 50 SIG Leakage? Yes/No No Today / Now No Today / Now SI 137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today! Now 5 gpd leak equivalent cpm 115 Today! Now 85 Today I Now 30 gpd leak equivalent cpm 490 Today I Now 308 Today! Now 75 gpd leak equivalent cpm 1165 Today! Now 710 Today! Now 100 gpd leak equivalent cpm 1540 Today I Now 933 Today ! Now 150 gpd leak equivalent cpm 2290 Today I Now 1380 Today I Now CVE Air Inleakage cfm 10 Today! Now 12.5 Today! Now Bkgd on 99/119 cpm 50 Today I Now 40 Today! Now Correction Factor 99/119 cpmlgpd 64 Today I Now 14.13 Today / Now Steady state conditions are necessary for an rf leaK rate usino the CVE Rad Monitor

1201-302 SCN 2 Booth Instructions BOOTH OPERATOR INSTRUCTIONS Sim. Setup

1. Reset IC-30 100% power MOL time in core life

2. Perform switch check.

3. Verify control rod step counters reset.

4. Place simulator in RUN.

5. Place Mode I placard on panels.

6. Place B Train Week sign on the simulator.

7. Allow the simulator to run for at least 3 minutes before loading SCEN file or starting the exercise. This will initialize ICS.

8. Load SCENS: S-1211 NRC SCN 2

9. Acknowledge any alarms, allow the plant to stabilize, and freeze the simulator.

10. Place 1-HS-57-73A (DIG Bkr) in the PTL.

11. Place 0-HS-82-48 (Mode sel switch) in the PULL FOR LOCAL position.

12. Place OOS tags on

• Breaker 1914, lB-B EDG to SD Bd IA-A

13. Place GO-16 tags on

• CCP lA-A

• Pzr heater lA-A

• Pzr heater IC

• SI Pump lA-A

• RHR Pump lA-A

• EGTS Train A-A

• Cntmt Spray Pump lA-A

• Motor Driven AFW Pump lA-A

• Unit I TDAFWP

• ERCW Pump J-A OR Q-A (circle one)

• ERCW Pump K-A OR R-A (circle one)

• Operable ERCW Pumps selected to auto start on 0-XS-67-286 and 0-XS-.67-287

• Diesel Generator lA-A

14. Perform the SIMULATOR OPERATOR CHECKLIST

15. Place turnover sheets on the operators desks.

16. Place simulator in RUN before crew enters the simulator.

Page 1 of 4

1201-302 SCN 2 Booth Instructions EVENT IC/MFJRFIOR # DESCRIPTION/EXPECTED ACTIONS/BOOTH FEEDBACK This override is IMF EGO3B f:1 These MFs, RFs, and ORs simulate lB-B DIG active when the IRF EGRI2 f:1 being mop for maintenance and tripped to SCN file is loaded. local.

IMF EGCOHS5773A f:3 ICR ZLOHS5773A M26 GREEN f:0 Place 1-HS-57-73A (D/G Bkr) in the PTL ICR ZL0HS5773_GREEN F:0 position and PLACE H.O. ON HAND SWITCH.

IMF AN OV 905 f2 Place 0-HS-82-48 (Mode sel switch) in the PULL FOR LOCAL position.

IMF AN_OV924 f:2 IMF AN_CV_936 f:2 IMF AN_OV_938 f:2 IMF AN_OV_943 f:2 IMF AN_CV_945 f:2 IMF AN_CV_946 f:2 IMF AN_OV_950 f:2 IMF AN_OV_952 f:2 IMF AN_OV_953 f:2 This malfunction is IMF RPI6K616A f:1 MSIVs 1-4 and 1-11 fail to AUTO CLOSE active when the IMF RP16K616B f:1 SCN file is loaded This malfunction is IMF FWO7C f:1 e:1 The TD AFW pump trips due to overspeed.

active when the SCN file is loaded This malfunction is IMF FW22Af:1 d:60 e:1 lA-A MD AFW pump becomes airbound.

active when the SCN file is loaded This malfunction is IMF CV22A f:100 r:180 e:1 Charging Pumps suction become clogged.

active when the IMF CV22B f:100 r:180 e:1 SCN file is loaded This malfunction is IMF TC11ALL f:1 Main Turbine Auto trip failure.

active when the IMF TCI2ALL f:1 SCN file is loaded This malfunction is IMF EDO6D f:1 d:120 e:1 Loss of B 6.9 kv SD Board.

active when the SCN file is loaded After Crew IMF RXO6A f:1 k:1 CONTROLLING PZR LEVEL TRANSMITTER completes FAILS LOW CHNL LT 68-339 Reactivity brief, When contacted, inform the crew that the use KEY I to i&c will report to the MCR in 45 minutes.

insert malfunction.

If Dispatched to Aux Control Room, inform crew that pressurizer level indicator reading correctly.

Page 2 of 4

1201-302 SCN 2 Booth Instructions When directed by IMF RXO2D1 f:630 r:120 k:2 RC Loop #4 T-cold Fails High the Lead Support staff: When MSS is contacted to trip Examiner, use bistables, inform the crew that l&C will report KEY 2 to insert to the MCR in -25 minutes.

malfunction.

When directed by IMF CNO9 f:O.07 k:3 Loss of Condenser Vacuum- Leak the Lead [pre-insert] 1 B Condenser Vacuum Pump fails to start Examiner, use automatically; KEY 3 to insert IMF CN llBf:1 malfunction. MMF CNO9 f:O when the power Support staff:

reduction is started. When personnel are dispatched, wait -5 minutes and report that the vacuum breaker flange is leaking.

If requested, report the I B Condenser Vacuum Pump is running; post start-up checks are as expected; and MT gland sealing steam regulator is closed by local observation.;

If requested, respond when sent to look for vacuum leaks.

If requested call the CR as WCC after the main turbine load reduction has started, report a small leak was found on a vacuum breaker flange, Mech Maint has made a temporary repair and it appears to be holding.

When directed by IMF EDO5 f:95 k:5 Abnormal Grid Voltage the Lead Support staff:

Examiner, use KEY 5 to insert When dispatched wait 5 minutes and report malfunction. no problems noted at the Exciter Cubicle.

{zdihs5722lzdihs5723} mmf EDO5 Triggers the grid to respond when Main f:100 r:60 Generator MVAR adjustment is made.

Support staff:

When called as Transmission Operator report Grid Voltage as 164 kv on the 161 kv lines and 524 kv on the 525kv lines.

When directed by IMF FW23D f:100 r:60 k:6 FW Line Break inside Containment.

the Lead Examiner, use KEY 6 to insert malfunction.

Page 3 of 4

1201-302 SCN 2 Booth Instructions Triggered from IMF EDO6D f:1 d:120 e:1 Loss of B 6.9 kv SD Board.

reactor trip (e: 1) Support staff:

If contacted respond as the Transmission Operator, report there is a major grid disturbance and there is no estimated time for restoration.

Triggered from IMF CV22A f:100 r:180 e:1 Both Charging Pumps suction become reactor trip (e:1) IMF CV22B f:100 r:180 e:1 clogged.

Support staff:

If directed wait 5 minutes and respond, no problem found.

Triggered from IMF FW22A f:1 d:60 e:1 lA-A MD AFW pump becomes airbound.

reactor trip (e:l) Support staff:

If directed respond as an AUO, wait 15 minutes then report there restoring the pump is not successful.

Triggered from IMF FWO7C f:1 e:l The TD AFW pump trips due to overspeed.

reactor trip (e: 1)

Support staff:

WHEN personnel are dispatched, wait 7 mm THEN inform the crew that the overspeed trip has actuated and cannot be reset.

Page 4 of 4

ci) C)

C) m C z

00

Appendix D Scenario Outline Attachment I Facility: Sequoyah Scenario No.: 3 Op Test No.: 2012-302 Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 2, -P2% Reactor Power, A Main Feedwater Pump I/S Turnover: Continue Plant Startup. Currently at 0-GO-4, Section 5.1 Step 4. Place Feed Regulating valves in AUTO, then increase power to 13-15%.

Target CTs: Manually initiate a Phase B isolation pri6r to completing ES-0.5 step 13.

Manually stop one Containment Spray Pump prior to completing ES-I .3 step 2 Event No.

1.

[ Malf. No.

N/A Event Type*

R-ATC Event Description Continue Power Increase from 2%.

l.a N/A N-BOP/SRO Place feed Reg Valves in AUTO using 0-GO-4.Section 5.1 Step 4.

2. IMF NIO4B l-ATC/SRO lR Channel N-36 fails higher than normal, the crew will place N36 Level Trip switch in BYPASS. The SRO will address Tech Specs and enter LCO 3.3.1.1 TS SRO Action 3 and 3.3.3.7, Action 1.

3. THOIB C-ATC/SRO A Small RCS Leak (21 gpm) in Loop 2 Hot Leg will develop. The crew will respond using AOP-R.05. The ATC will raise charging flow to control pressurizer TS SRO level. The SRO will address Tech Specs and determine that RCS Leakage is in excess of LCO requirements.

4. IMF RX29 C-BOP/SRO PT-l-33 develops a ramp failure, the GOP will manually close the Steam Dumps using AOP-S.05.

5. THO1 B M-All The RCS leak increases to a LOCA, the crew will initiate a Reactor Trip and

. Safety Injection and transitions to E-0. During the performance of E-0, the Hi-Hi Pre-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.

6. ZDIHS6523A C-BOP The EGTS fans fail to AUTO-START, the BOP will manually start the EGTS fans using Prudent Operator Actions or guidance from ES-0.5.

7. 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, (l)nstrument, (C)omponent, (M)ajor

Appendix D Scenario Outline 201 2-301 Scenario 3 Summary EVENT I The crew will assume the shift, place the feed reg valves in AUTO using O-GO-4.Section 5.1 Step 4 and continue the power increase.

EVENT 2 When directed by the lead examiner, IR Channel N-36 fails higher than normal, the crew will place N36 Level Trip switch in BYPASS. The SRO will address Tech Specs and enter LCO 3.3.1.1 Action 3b and 3.3.3.7, Action Ia.

EVENT 3 When directed by the lead examiner, a Small RCS Leak (21 gpm) in Loop 2 Hot Leg will develop. The crew will respond using AOP-R.05. The ATC will raise charging flow to control pressurizer level. The SRO will address Tech Specs and determine that RCS Leakage is in excess of LCO requirements. The SRO will enter LCO 3.4.6.2.a or b action a.

EVENT 4 When directed by the lead examiner, PT-i -33 develops a ramp failure, the BOP will manually close the Steam Dumps using AOP-S.05.

EVENT 5 The RCS leak increases to a LOCA, the crew will initiate a Reactor Trip and Safety Injection and transitions to E-O. During the performance of E-O, 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 6 During performance of the EOPs, the EGTS fans fail to AUTO-START, the BOP will manually start the EGTS fans using Prudent Operator Actions or guidance in ES-O.5.

EVENT 7 During performance of the EOPs, the RWST b-b level will occur requiring the crew to transition from E-1 to 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, and when at least one Containment Spray pump has been stopped in ES-i .3..

EOP flow: E-O, E-1, FR-Z. i, FR-P. i, ES-i .3

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 1 Page 1 of 48 Event

Description:

Raise plant power to 13-15% RTP Time H Position fl Applicants Actions or Behavior Booth Operator: No action required for event I 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.

5I Actions To Be Performed Prior To Raising Reactor Power (continued)

NOTES

1) MFW Bypass valves will be using single element control, which means the desired SG level seipoirit will be compared to the actual SG level until adequate steam and feedwate.r flow are available. Single Element to Three Element control transition occurs at -13% RTP (.494E6 LBMIHR steam Row per loop).

2) MFW Req valves may have a positive deviation if reactor power is in the upper range of the control tand (1-4%) in the following step.

[41 PERFORM the following:

[41] ENSURE four MFW Bypass Req valves in AUTO

[4.2] ENSURE MFW Req.. valves have minimal controller deviation.

BOP ENSURE MFW Req. valves are CLOSED

[4-41 PLACE MFW Req. valves in AUTO.

[4.5] ENSURE MFW valve control moe in 3 Element Enabled (dick Iarget located in the center of each screen under the appropriate loop # Control button)

Direct a load increase in accordance with O-GO-4, Reactor Power Ascension To 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 201 2-302 Scenario # 3 Event # I Page 2 of 48 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 0-SO-62-7 requirements shall be adhered to for reactivity changes (i.e reactivity balance, amounts of boric acid or water) All appropriate verifications 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 1/2 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 slould 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] EC.71 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)

NOTE I If an excessive amount of dilution is required (plant startup), the pressurizer heaters should be energized to cause p essurizer spray operation for equalizing boron concentration 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 m:ode whenever conditions pemt 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)].

Examiner Note: use time compression as required to facilitate power increase.

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# I Page 3 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior ATC [2] ENSURE sufficient capacity available in the HUT selected to receive expected amounts of CVCS letdown: (NIA 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)

AT [6] PLACE IHS-62-i4OAl, Boric Acid Supply to Blender Flow Control Switch to e S P position.

2-1 a

• T [ . UREFHS-62-140D1, Boric Acid Valve to the Blen er IS CLOSED (Green tisLiT.

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 [12] VERIFY the following;

[a]_Inlet to_top_of VCT IFCV-62-1 281 is OPEN.

[b] Primary Water flow by IFI-62-142A] OR IFQ-62-1 421.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # I Page 4 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position 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. I 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-62-144] is desired, THEN ATC [a] CLOSE [FCV-62-1 281 with FHS-62-1 28].

ATC [b] OPEN [FCV-62-144] with [HS-62-1441.

ATC [c] VERIFY Primary Water flow by [Fl-62-142A] OR [FQ-62-1 421.

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 [LJ-62-129], 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

[b] IF rFCV-62-1441 was previously OPENED, THEN CLOSE [FCV-62-144]

with FHS-62-1441.

ATC [c] VERIFY no primary water flow on either [FI-62-142A1 OR FFQ-62-1 421.

ATC [d] ENSURE [FCV-62-1281 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 2012-302 Scenario # 3 Event # I Page 5 of 48 Event

Description:

Raise plant power to 13-15% RTP Unit______________ Date..

6.2 Dilute (Continued)

[171 IF power ascension in progress and additional dilutions will be required, THEN use this table to reperform steps [41 lhrouqh [181..

STEP -- --

1 2 3m

[41 RECORD the quantity of dilution water required to achieve desired boron concentration using Appendix 0. --

[51 PERFORM Appendix I, IVof Calculation for amount of BA orPW.

RO R(

[6J PLACE [HS-62-140A] Boric Aad Supply to Blender Flow Control Switch to the STOP pasition 4_

[7J PLACE [HS-62.440B], CVCS Makeup Selec or Switch to the DILUTE position. 0 0 0

[8J ENSURE [HS-62-140p] Boric Acid Valve to Blender is CLOSED (Green ght LII). [1 [1 [1

[9] SET [FQ42442], Batch Integrator for the desired quantity. L L... L

[10] ADJUST [FC-62-1421, Primary Makeup Water Flow Controller for the desired ftow rate

[11] PLACE IHS-62-140A1 BA Supply to Blender Flow Control Switch to START I I I

[121 VERIFY the following:

[a] Inlet to top of VCT fFCV-62-1281 is OPEN. U U 0

[b] Primary Water flow by [f42-142A] or [FQ42-142] U U ü

[131 IF PW addition to top of VCT [FCV-624 28] is not warranted, but PW addition to the bottom otthe VCT [FCV-624441 is desired, THEN

[a] CLOSE 1FCV424:281w1th [HS42428] U U 0

[b) OPEN IFCV-62-1441 with tHS42-144]. 0 U 0 fe] VERIFY Primary Water flow by [ft-62-142Aj or [FQ42*.442[ U U 0

[14] MONITOR nuclear instrumentation and reactor coolant temperature to ensure the proper response from dilution. U

[15] iF [L142-1291, VCT level, rises to 63 percent, THEN ENSURE

[LCV42-1 18],_VCT Divert Valve,_OPENS to divert excess water to the HUT& C] U 0

[16] WHEN dilution is complete, THEN

[a] PLACE [HS-62440A1, Boric Acid to Blender Flow Control Switch to STOP j I

[b] IF [FCV-62444] was previously OPENED, THEN CLOSE fFCV421441 with [HS624441. [1 U U

[C] VERIFY no primary water flow on either [62i42A1 OF [FQ42142j. U U 0

[dJ ENSURE [FCV-624 281 is CLOSED U U U

[18]IF Step [171 will be repeated THEN PERFORM the following:

[a] PLACE [HS42-140B1. GVCS Makeup Selector Switch to the AUTO position iz cv j1] PLACE [HS-62440A1 BA to Blender Flow Control Switch to START position LI Ic] ENSURE dilution is Jogged in Unit Narrative Log. LI

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 3 Event# I Page 6 of 48 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 48 Event

Description:

Raise pant 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 1, the operators will use a laminated copy of Sections 6.4 & 6.5 available on the book desk under the glass at 1-M-4. It has been verified as current, in-effect revision routinely to assure currency.

NOTES

1) A laminated copy of this section :C3fl be maintained in the Unit Control Room for repetitive use tar routine rod manipulations.

2) Defeating or restoring TavgiDelta T or NIS channel may cause step change in input to rod contro[ A delay of at least 3 minutes prior to returning rod control to automatic will allow lead/lag signal to decay oW

3) INs Section may be N/A it 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 TavglTref mismatch.

ATC [4] PLACE [HS-85-5110], Rod Control Mode Selector in the AUTO position.

ATC [5] VERIFY Rod Speed Indicator [Sl-412], 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 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or behavior Section 6.5, Transferring from Auto to Manual Rod Control NOTES I) 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 D C-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 [HS 85-5111], 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-85-5110], Rod Control Mode Selector to Automatic, THEN GO TO Section 6.4.

End of Section 6.5

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # I Page 9 of 48 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.

MODEl Examiner Note: Mode change call is made using Loop AT indications on the MCB and ICS, not Nis; Nls may be referred to during the MODE change determination Refer to O-GO-4 Section 3.1, Precaution C, specifically bullets 2 & 3 (below):

C During startup, 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 1 5% use average foopT (U0485)

• When reactor power is greater than 15% use LEFM core thermal power indication (U21 18) If LEFM is NOT available, then continue using average ioop 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 1 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 1 sign on 1-M-4 under the clock.

t**fl

[5] MAiNTAIN the SG levels on program by periodically adjusting 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 2012-302 Scenario # 3 Event # 1 Page 10 of 48 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, NIA 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 # I Page 11 of 48 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).

&1 Changing MFW Bypass Reg Valve Controller Setpoint With Hand Controller Using the JOG Method NOTES

1) With the MFW Bypass Reg Valve controller in auto S(3 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) SO setpoints can be changed from either the OCS Operator Display monitor or the hand controller station

4) Two handed operation will be required to change the SO controller setpoint, when using the hand controller.

5) Setpoint push button will change from gray to red on the Hand Controller and the DCS Operator Display monitor

[I] PRESS and HOLD SETPOINT push button for applicable Bypass Reg Valve (NIA valves not operated):

SIG UNID INITIALS I I -LIC-3-35 2 1-LIC-3-48 3 I-LIC-3-90 4 I-LIC-3-i03

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # I Page 12 of 48 Event

Description:

Raise plant power to 13-15% RTP NOTE The following method (JOG method) will cause the setpoint to change in 05% increments each time the button is pressec[ The push buttons are momentary contact dot ure type, so continuouslj 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 sepoint

[21 PRESS either the raise (>>)or the lower (<<) push buttons to obtain the desired setpoint (NIA valves not operated):

S!G UNID INITIALS I 1-LIC--3-35 2 1-LIC-3-48 3 I-LIC-3-90 4 I:L1C3103

[31 RELEASE the SETPOINT push buttort (NIA valves not operated)

[4] REPEAT Steps 61 [11-61 [3] as necessary to maintain SIG 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 48 Event

Description:

Raise plant power to 13-15% RTP 6.2 Changing MFW Bypass Reg Valve Controller Setpoint With OCS Operator Display Monitor NOTES

1) With the MFW Bypass Reg Valve controfler 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 1LlC-3-48 3 1 -LIC-3-90 4 1LlC-3-103

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O12-302 Scenario# 3 Event# 1 Page 14 of 48 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 INITIALS I I -LIC-3-35 2 I-LIC-3-48 3 i-LIC-3-90 4 I-LIC-3-103 NOTE Using the JOG method will cause the setpoint to change in 0.5% 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. El 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 (t) or the lower (11) push buttons will cause the setpoint to change at a rate of 1.67% per second. A change of 0%-i 00% would take approximately 1 minute.

[4] IF using the RAMP method, THEN SELECT the raise (lt) or the lower (41) push button to obtain the desired setpoint. C 5] WHEN the desired setpoint is obtained, THEN CONFIRM SETPOINT is correctly displayed on the screen. C

[6] SELECT the SETPOINT push button. C

[7] CONFIRM SETPOINT push button changes from red to gray. El End of Section

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event# 2 Page 15 of 48 Event

Description:

IR Channel B Instrument N-38 Fails Time Position I Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 2 lR Channel N-36 Fails Indications available:

• 4B B2 IPRS NIS Intermediate Range HI FLUX LVL ROD WITHDRAWAL STOP

. Control Rod motion stops, if in progress.

. Intermediate Range Instrument N-36 is greater than N-35 IRS INTERMED RANGE HI FLUX LVL ROD WITHDRAWAL STOP NOTE CO!*d rods wifl not withdraw in manual or automatic.

COflCtWe [1] CHECK reactor power level Actions

[2] REDUCE reactor power to < 20%.

[3] BLOCK intermediate range high flux trip and power range high flux trip (tow setpoint).

[4] IF IntermedIate Range channel failed. THEN GO TO AOP-L01. Nucear kifrumentMaffunction 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-M4B. B2

..  : ATC. May take action_using_ARP to block the Low Power PR and IR NI Trip.

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

1. DIAGNOSE the failure:

GO TO IF...

SEOTION PAGE intermediate Range Failure 22 9 SRO Directs actions using AOP-l.O1, Nuclear Instrument Malfunction.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event# 2 Page 16 of 48 Event

Description:

IR Channel B Instrument N-36 Fails Time 1 Position fl Applicants Actions or Behavior CAUTION t II reactor power is below P4 (1ff 4 %), Tech Specs require restoring inoperable channel pnor to raising power above P4.

CAUTION 2 11 reactor power is above P but below 5% power, Tech Specs require restoring inoperable channel prior to raising power above 5%.

NOTE I If Intermediate Range channel is failed high, reducing reactor power to less than PlU (10%) will result in a reactor trip. If control power is available, this condition Will be corrected when the channel is bypassed in Step 6.

NOTE 2 If any lR channe has failed high, then automatic re-enabling of Source Range indication may be disabled.. (SRMs may require manual reinstating in ES-UI.)

NOTE 3 Failure of Intermediate Range Channel may affect associated Source Range Channel.

I. lFunitisinMocle2, SRO THEN STABILIZE reactor power at current level.

2. EVALUATE the following Tech Specs for applicability:

. 3.3_I .1 (3.31), Reactor Trip System Instrumentation

. 3.33.5. Remote Shutdown SRO Instrumentation

• 3.3..37, Accident Monitoring Instrumentation

• 3.92, Refueling Operations Instrumentation ATC 3.. CHECK at least one Intermediate Range channel OPERABLE CAUTIONS:

• Loss of instrument OR control power will cause a single channel reactor trip signal.

• For loss of control power only, the reactor trip signal cannot be bypassed.

Reducing reactor power below P-b will result in a reactor trip.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event# 2 Page 17 of 48 Event

Description:

IR Channel B Instrument N-36 Fails Time Position Applicants Actions or Behavior NOTE: The follUwing table lists intermediate Range NIS power supplies:

NIS CHANNEL INSTRUMENT CONTROL POWER POWER VIPB i-I (2-I) VIPB I-I (2-1)

N-35 Bkr3 Bkr4 VIPB i-Il (2-11) VlPB 1-Il (2-il)

N 36 Bkr3 Bkr4

4. CHECK power available to failed Intermediate Range channel: [M-13]

• INSTRUMENT POWER ON indicator UT ATC AND

. CONTROL. POWER ON indicator UT 5 IF requiied to monitor IR channel on NR45 recorder, ATC THEN ENSURE OPERABLE IR channel selected on NR-45 Recorder [M-4]

& PLACE Level Trip switch for failed channel in BYPASS IM-13, N35tN36]..

7. IF control power is available, THEN PERFORM tlie following:

a, VERIFY NIS TRIP BYPASS annunciator LIT [M-6A, A-I].

Ii VERIFY appropriate annunciator LIT:

. INTERMEDIATE RANGE TRIP BYPASS CHANNEL I [M-4A, A-2]

OR a INTERMEDIATE RANGE TRIP BYPASS CHANNEL II [M-4A. 8-2]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event# 2 Page 18 of 48 Event

Description:

IR Channel B Instrument N-36 Fails Time Position Applicants Actions or Behavior

& CHECK associated Source Range Channel NOT affected..

a 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 N-36 Trip Level switch has been placed in bypass.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 3 Event# 4 Page 19 of 48 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 4 RCS Loop 2 Hot Leg Leak 21 gpm.

IndicationslAlarms Indications 1-M-5

• 1-LR-68-339, RCS PZR LEVEL actual level deviating low from program level indication

• 1-Fl-62-93A, CHARGING HDR FLOW increasing flow 1-M-6

• 1-LI-62-129, VCT LEVEL decreasing

• 1-PDIR-30-133, CNTMT ANN increasing trend O-M-12

• 1-RR-90-106A, CNTMT LOWER COMPT PARTICULATE RADMON recorder shows increasing trend

• 1-Rl-90-106B, CNTMT LOWER COMPT RADMON-TOTAL GAS increasing counts

• 1-RM-90-112B, CNTMT UPPER COMPT RADMON- TOTAL GAS increasing counts 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 NoV: NRC 2012-302 Scenario # 3 Event # 4 Page 20 of 48 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

Time I Position fl Applicants Actions or Behavior

1. IF leak results in radiological hazard or safety hazard, THEN EVACUATE unnecessary personnel from affected area&

2. DIAGNOSE the failure:

GOTO IF... SECTION PAGE ANY of the following indications wfth RCS temperature greater than 375°F:

a Pressurizer level droppffig :unexpted1y a Charging 11Gw rising unexpectedly with stable pzr level 2.1 4 a VCT level dropping with Aux Bldg or Containment radiation rising a High Energy Line Break recorder indicating unexpected rise in temperature a other indications of RCS leak (local or MCR)

1. CONTROL charging 110w using one CCP:

a ADJUST FCV-62-93 and FCV-62-89 as necessary to maintain pzr level ATC on prograni.

• MAINTAIN seal injection flow at least 6 gpm to each RCP.

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 PzrIRCS 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-D2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # 4 Page 21 of 48 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

Time I Position Applicants Actions or Behavior

2. MONITOR pressurizer level STABLE IF sufficient lime is available, or RISING. THEN ISOLATE normal and excess letdown:

a. ENSURE FcV-62-72., 73, and 74 CLOSEft

b. CLOSE FCV-62-69 and 70.

c. ENSURE FCV-62-54 and 55 CLOSED.

ATC IF loss of pressurizer level is imminent OR low pressure reactor trip (l7O psig) is imminent, THEN PERFORM the following:

a. TRIP the reactor.

b. INITIATE Safety Injection.

c. GO TO E-0, Reactor Trip or Safety Injection.

3. MONITOR containment pressure IF containment pressure is STABLE or DROPPING. approaching 1.5 psig, THEN PERFORM the following:

a. TRIP the reactor.

ATC Ii 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 RLSIN&

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario# 3 Event# 4 Page 22 of 48 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

Time Position I Applicants Actions or Behavior Examiner Note: RCS leak will progress into a LBLOCA. 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.

& 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: ii letdown was isolated in Step 2, The leak rate may have exceeded capacity of one CCP in the normal charging alignment (EAL 1.22P).

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

SRO 7 EVALUATE Tech Spec1TRM LCOs USING Appendix K, Evaluating Tech Specs and TRM.

3.4t2 Reactor Coolant System leakage shcll be limfted to:

a. No PRESSURE BOUNDARY LEAKAGE,

6. 1 6PM UNIDENTIFiED LEAKAGE

c. 150 :gaktas per day of pclmary-to-secortdaiy leakage thmt4 any one steam generator, and

d. 106PM IDENTIFIED LEAKAGE from the Reactor Coolant System.

SRO APpucAary: MODESI,.2,Sand4 ACTION:

a With any PRESSURE BOUNDARY lEAKAGE or with prlmary-to-seoondaiy leakage not within linda, be ii at least HOT STANDBY within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> and in COLD SHUTDOWN withhi the follcwfrig 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

6. With any Reactor Coolant System leakage greater than any one ofthe ahove rwnlts, excluding PRESSURE BOUNDARY LEAKAGE or primary-to-seoondawy leakage.

reduoe the leakage rale to within limits *ithin4 bows orbe hi at least HOT STANDBY within the next 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> and to COLD SHUTDOWN within the following 30:hows.

Lead Examiner may cue next event when Tech Specs have been addressed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 4 Page 23 of 48 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

SQN RCS LEAK AND LEAK SOURCE IDENTIFICATION I Rev.14 Page 1 of 1 APPENDIX I ESTIMATING RCS LEAK RATE USING CVCS FLOW BALANCE NOTE I This method is recommended when leak reqthres rise in charging flow greater than 1O gpnt Appendix J is more accurate for smaller leak rates.

NOTE 2 This appendix assumes RCS temperature and charging flow are approximately constant INI11AL FINAL CHANGE PZR Level [I]

(negatwe for leusi_decrease)

Time Charging Flow Letdown Flow Total RCP Sal Retrnii Flow Pressurizer Level Conversion Pressurizer level conversion lime Change Pzr Level Rate of Change change factor (posiuive for leysi rising)

% X 62ga11% mm = gpm step [1] above step [2] above [61 Leak Rate Calculation Charging Firm Letdown Flow SeaRum Instrument error RCS Leak Raange correction factor Rate

+ 3gpm = gpm step [3] above step [4] above step [5] step [6] above above Page 73 of 80

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 3 Event # 4 Page 24 of 48 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2)

SQN RCS LEAK AND LEAK SOURCE IDENTIFICA1ION AOP-R05 Rev. 14 Page 1 of I APPENDIX J EST1MATING 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 approxiniatety constant VCT LEVEL (%) PZR LEVEL (%) TIME (mm)

INIIIAL FINAL CHANGE [1] [21 [1 (positive for level decrease) (positive for level decrease VGT Level Conversion VCT level change conversion Time Change VCT Level factor Rate of Change (positive for level foweing)

% X 2OgaII%:  : mm = gpm step [Ii above step 131 above [4J Pressurizer Level Conversion Pressurizer level conversion Time Change Pzr Level change factor Rate of Change (positive for level lowering)

X 62ga11% ÷ mm = gpm step 121 above step [3] abcve 151 Leak Rate Calculation VCT Level Pzr Level RCS Leak Rate Rate of Change Rate of Change

+ gprn step [4] above step 151 above Page 74 of 80

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 3 Event # 3 Page 25 of 48 Event

Description:

PT-i -33 develops a slow failure, the BOP will manually close the the Steam Dumps using AOP-S.05 Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 3 PT-I -33 Slow Failure Alarms I-M-5

. 5A C-6 TS-68-2P!Q REAC COOL LOOPS T REF T AUCT HIGH-LOW Indications I-M-4 SG STEAM FLOW indicating increasing flow.

Time Position Applicants Actions or Behavior TS-68-2PIQ REAC COOL LOOPS TREFTAUCT HIGH-LOW

[1] COMPARE plant indicators to verify validity of aiarnt NOTE I IF annunciation is an expected response during the performance of l-RT-MOD-520-003.O, 20%

Load Step Change, rods should be lft in AUTO NOTE 2 IF a rapid load reduction is in progress and automatic rod control is functional, AOP-C.03 allows reducing turbine load rate prior to placing rod control in manual.

[2] IF AOP-C.03, Rapid Shutdown or Load rejection, is in progress, THEN

[a] REFER to AOP-C 03 guidance for rod control operation.

[b] GO TO step [4].

[3] IF controls are in AUTO when alarm occurs, THEN PLACE rod control system (1-HS-85-5110) in manual and match Tavg with Tref.

[4] IF rod control system is malfunctioning, or there is indication of a failure of the Tref signal to the rod control system, THEN GO TO AOP-C.01, Rod Control System Malfunctions.

[5] IF a boron concentration change is suspected, THEN GO TO AOP-C.02, Uncontrolled RCS Boron Concentration Changes.

[6] IF a steam line or feedwater line break or leak is suspected, THEN GO TO AOP-S.05. Steam Line or Feedwater Line Break,teak

[7] IF Tavg channel failed, THEN GO TO AOP-l.02, RCS Loop RTD Instrument Malfunction.

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 2012-302 Scenario # 3 Event # 3 Page 26 of 48 Event

Description:

PT-i -33 develops a slow failure, the BOP will manually close the the Steam Dumps using AOP-S.05 Time Position Applicants Actions or Behavior ATC Responds to alarm using ARP 1-AR-M5A, A6 or M-6A-E2 SRO Transitions to AOP-S.05, Steam Or Feedwater Leak t MONITOR personnel safety:

a. IF steam or feedwater lines need to SRO be immedately isolated to protect personnel, THEN PERFORM the following:

2. MONITOR steam generator levels BOP STABIE on program.

3. CHECK the following: IF any SIG atmospheric reIef valve or steam dump is leaking or failed open,

• SIG atmospheric rehef valves CLOSED THEN CLOSE valve(s) USING MCR switch.

• steam dumps CLOSED.

Lead Examiner may cue next event when Steam Dumps are closed or if the Reactor trips.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 5 Page 27 of 48 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 5 Loop #2 LOCA-To Require Rx Trip and Safety Injection.

Indications available:

1-M-4:

• 1-Ll-68-339A, 335A, 320A, RCS PZR LEVEL indicators trending down (<5%)

1-M-5:

• 1-PR-68-340, RCS PZR PRESS Recorder trending down;

• 1-LR-68-339, RCS PZR LEVEL Recorder trending down; 1-M-6:

• 1-LI-62-129, VCT LEVEL Indicator trending down wI VCT M-U in progress;

• 1-PI-68-62, RCS HL Press WR indicator trending to actuation pressure value.

• 1-Pl-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) r Ma Re or T an afety *ecti a o o f I i 0-C es an Iy rip th eactor and Initiate .

SRO Enter and Direct performance of E-O. Reactor Trip Or Safety Injection.

Examiner Note: following lOA 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 # 5 Page 28 of 48 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Position fl Applicants Actions or Behavior CREW Performs the first four steps of E-O unprompted.

SRO Directs performance of E-O NOTE I St)S 1 through 4 are immediate action steps.

NOTE 2 ThIS procedure has a loldout page.

I 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.

a. VERIFY at least one &9KV shutdown BOP board ENERGIZED on this unit.

4. DETERMINE if SI actuated:

ATC

• ECCS pumps RUNNING

• Any SI alarm LIT [M-4D1 5 PERFORM ESO.5. Equipment BOP Verifications WHILE continuing in this procedure.

Continue with the performance of E-O REACTOR TRIP OR SAFETY SROIATC INJECTION BOP Performs ES-O.5, Equipment Verifications go to page 42 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 # 5 Page 29 of 48 Event

Description:

Large Break LOCAIFailure 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 SiC pressure is dropping uncontrolled, THEN PERFORM the following:

a CLOSE MSIVs and MSIV bypass valves.

b. IF any SIC pressure continues to drop uncontrolled, ThEN PERFORM the following:

I) ENSURE SI actuated.

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

THEN ISOLATE ARM to faulted SIC(s):

• CLOSE AFW level control valves for faulted Sic(s)

• IF any ARM 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 man 44:Q gpm OR

• Narrow Range level greater than 10% [25% AD?] in at least one intact SIC.

• IF both trains of shutdown boards de-energized, THEN GO TO ECA-O.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-IS Transfer to RI-IR Containment Sump

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 5 Page 30 of 48 Event

Description:

Large Break LOCNFailure of Phase B to Actuate.

Applicants Actions or Behavior

6. DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpni.

b. CHECK narrow range level b. MAINTAIN total feed flow greater than 10% [25% ADV] greater than 440 gpm I--,

in at least one SIG. UNTIL narrow range level greater than 10% [25% ADVI in at least one SIG.

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

in intact or ruptured S/Gs.

7. CHECK if main steam lines should be isolated:

a. CHEcktfanyofthefollowing a. GOTOStep&

conditions have occurred:

Any S!G pressure less than 600 psig ATC OR

• My SIG pressure dropping UNCONTROllED OR

• Phase B actuation.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 5 Event # 5 Page 31 of 48 Event

Description:

Large Break LOCAIFailure of Phase B to Actuate.

Time b Position Applicants Actions or Behavior

8. CHECK RCP trip criteria:

a. CHECK the following:

• RCS pressure less than 1250 psig ATC AND

• Atleastone 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-colci 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 2012-302 Scenario # 5 Event # 5 Page 32 of 48 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position I Applicants Actions or Behavior J

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:

• CHECK all SIG pressures ATC CONTROLLED or RISING.

• CHECK all SIG pressures greater than 140 psig.

12. DETERMINE if SIG 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 ThIrACT: PERFORM the foIlo4ng:

a Containment pressure NORMAL

a. INITIATE ES-O.5 Appendix 0, a Containment sump level NORlvt4.L Hydrogen Mitigation Actions.

ATC

• LOWER COMPT TEMP HIGH alarm b. MONITOR statti trees.

DARK [M-5C, 611 a Containment radiation NORMAL c. GO TO E-i, Loss of Reactor or USING Appendix B, Containment COOiaflL Rad Monitors. (App. B performed in ES-U.5)

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 # 5 Page 33 of 48 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior When an ORANGE Path for Containment is evident on SPDS, the SRO will transition to FR-Z. 1, go to page 38 for details When a RED Path is for PTS evident on SPDS, the SRO will transition to FR-P. 1, go to page 40 for details E-1, LOSS OF REACTOR OR SECONDARY COOLANT NOT! 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.

a At least one CCP OR SI pump RUNNING ATC AND a RCS pressure less than 1250 psig.

b. STOP RCPs.

2. CHECK S/G secondary pressure boundaries INTACT:

BOP

• SIG pressures CONTROLLED or RISING

• SIG pressures greater than 140 psig.

3. MAINTAIN Intact SIG narrow range levels:

a. Greater than 10% [25% ADV].

BOP

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

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 5 Page 34 of 48 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% [20% 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 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 SIG 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 2012-302 Scenario # 5 Event# 5 Page 35 of 48 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-1 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 S!G blowdown.

a. 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 2012-302 Scenario # 5 Event # 5 Page 36 of 48 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 subcooiing based on core exit TICs a. GO TO Step 7.

greater than 40°F. IIIIIIIIIIIIIIIIIIIIIIIIIIII 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 fi] IF SIS has occurred with RWST level decreasing to 27%, THEN Actions PERFORM ES-i 3, Transfer to Ri-fR Containment Sump, as applicable SRO Transitions to ES-I .3 Transfer To RHR Containment Sump.

CREW - SUSPEND FR? irnplementatiow 2.. DETERMINE if containment spray should be stopped:

a CHECK any containment spray pump RUNNING.

IL ENSURE the following:

ATC

• one Cntmt Spray pump in PULLTO-LOcK

• remaining Cntmt Spray pump RUNNING.

cl MONITOR one cntmt spray pump RUNNING and flow.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 5 Event # 5 Page 37 of 48 Event

Description:

Large Break LOCAIFailure 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 2.0 psig.

1) RESET containment spray signal -

2> ENSURE bcth catmt spray pumps A -r STOPPED and I,-

PLACE in A-AUTO.

3) CLOSE cntrnt spray discharge valves FCV-72-39 and FCV-72-2

4) GO TO Step 3..

2. DETERMINE if containment spray should be stopped:

ATC d. MONITOR one cntmt spray pump RUNNING and delivering flow.

Scenario may be terminated when the crew completes ES-1.3 step 2 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 # 5 Page 38 of 48 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position I Applicants Actions or Behavior FR-Z.i Actions NOTE It this procedure has been entered for an orange path and performance of ECA-1 .1 (Loss of RHR Sump Recirculatbn) is required, FR-Zi may be performed concurrently with ECA-1 1. -

1 MONITOR RWST level ATC/BOP greater Than 27%

2. VERIFY Phase B valves CLOSED:

ATC/BOP Panel 6K PHASE 8 GREEN

• Panel 6L PHPSE B GREEN.

3. ENSURE RCPs STOPPED.

ATC/BOP

4. DETERMINE if this procedure should be exited:

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

ATC/BOP Any SIG pressure DROPPING in an uncontrolled manner OR

• Any SIC pressure lessthasi 140 psig.

5. VERiFY containment spray operation:

a. IF ECA-1 .1, Loss of RI-IR Sump Recirculatton, is IN EFFECT.

ThEN PERFORM the following:

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

2) GOTOStep6 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 201 2-302 Scenario # 5 Event # 5 Page 39 of 48 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position fl Applicants Actions or Behavior

5. d. VERIFY containment spray suction ALIGNED to RWST:

• FCV-72-22 OPEN FCY-72-21 OPEN.

e. VERIFY containment spray discharge valves OPEN:

a FCV-72-39 ATC/BOP

• FCV-72-2.

F. VERIFY containment spray recirc valves CLOSED:

• FCV-72-34 a FCV-72-13.

g. VERIFY containment spray flow greater than 4750 gpm on eacfl train.

6. MONITOR containment air return fans:

• WHEN at least 10 minutes ATC/BOP have elapsed from Phase 8, THEN ENSURE containment air return fans RUNNING.

7. VERIFY containment ventilation dampers CLOSED:

ATC/BOP Panel 6K CNTMT VENT GREEN

• Panel 6L 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 MANUALI ATC/BOP ECV-S0-46

• FCV-30-47

• FCV-S0-48,

10. VERIFY MSIVs and MSIV bypass valves ATC/BOP CLOSED.

Appendix D Required Operator Actions Form LS-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 5 Page 40 of 48 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position Applicants Actions or Behavior

11. DETERMINE any 510 Intact:

a. CHECK at least one Sf0 pressure:

ATC/BOP CONTROLLED or RISING AND

• Greater than 140 psig.

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

12. DETERMINE If any S!G Faulted:

a. CHECK 6/(3 pressures: a. GO TO Step 13.

My 51(3 pressure DROPPING ATC/BOP in an uncontrolled manner OR

• Any 6/S pressure lessthan 140 psig.

13. MONITOR ii RI-IR spray should be placed in service:

ATCIBOP 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 pstg.

I& RETURN TO procedure and step lii effect ATC/BOP END FR-P.1 Actions I MONITOR RWST leve4 ATC/BOP greater than 27%

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # 5 Page 41 of 48 Event

Description:

Large Break LOCA/Failure of Phase B to Actuate.

Time Position 1 Applicants Actions or Behavior ATC/BOP 2. MONITOR CST level greater than 5%..

& CHECK RCS pressure IF any of the following conditions exist greater than 300 psig.

• RIIR injection flow on Fl-63-91A p1 Fi-63-92A greater than 1000 gpm OR ATC/BOP

• both RHR PUFUPS STOPPED AND surnp recirc capability has been lost THEN RETURN TO procedure and step in effect

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # ES-0.5 Page 42 of 48 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior ES-O.5 Actions BOP I - VERIFY DIGS RUNNING BOP 2 VERIFY DIG ERCW Supply valves OPEN BOP VERIFY at least four EROW pumps RUNNING.

4. VERiFY ccs pumps RUNNING:

• Pump IA-A 24A)

BOP

• Pump 16-B (2B-B)

• Pump C-S.

BOP 5 VERIFY EGTS tans RUNNING BOP S. VERIFY generator breakers OPEN.

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. TOAFWpump.

NOTE AFW level control valves should NOT be reposItioned II manual action has been taken to control 51(3 levels, to estatlist 110w due to failure.

or to isolate a faulted S!G

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2012-302 Scenario # 5 Event # ES-0.5 Page 43 of 48 Event

Description:

Equipment Verifications L Time fi Position

[ Applicants Actions or Behavior

9. CHECK AFW valve alignment:

a. VERIFY MD AFW LGV5 in AUTO..

BOP b. VERIFY TD AFW LCVs OPEN.

c. VERIFY MD AFW pump recirculation valves FCV-3-400 and FGV-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..

11. MONITOR ECCS operation:

a.. VERIFY ECCS pumps RUNNING:

• CCPS RHR pumps BOP

• Slpumps b.. 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 2012-302 Scenario # 5 Event # ES-0.5 Page 44 of 48 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 t VERIFY RHR pump 110w.

12. VERIFY ESE systems AIJGNED:

a. FThase AACT1JATED:

• PHASE A TRAIN A alarm LIT

[M-6C, 65].

. PHASE A TRAIN B alarm LIT

[M-6C, 66].

b. Cntmt Vent isolation: ACTUATED:

• CNTMT VENT ISOLATION TRAIN A alarm LIT [M-6C, CS].

• CNTMT VENT ISOLATION TRAIN B alarm LIT [M-6C, 06].

c. Status monitor panels:

BOP

• 6C DARK

• 6D DARK

• 6E LIT OUTSIDE oullined area

• 611 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

Arnendix D Reauired Orerator Actions Form ES-D-2 Op Test No.: NRC 201 2-302 Scenario # 5 Event # ES-0.5 Page 45 of 48 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:

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, 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 GL 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 2012-302 Scenario # 5 Event # ES-0.5 Page 46 of 48 Event

Description:

Equipment Verifications 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 compfetetL 1& 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 a Appendix B, Containment Rad Monitors.

APPENDiX A SECONDARY RAD MONITORS

1. IF SI occurred on Unit 1.

THEN CHECK following lad monitors including available trends prior to isolation:

Condenser exhaust recorder i-RR-90-119

• SIG blowdown recorder l-RR9O-12O

• Unit I Main steam line lad monitors [1-M-30]

• Post-Accident rad recorder 1-RR-90-268B points 3 (blue) 4 (vIolet) 5 (black) and & (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 2012-302 Scenario # 5 Event # ES-0.5 Page 47 of 48 Event

Description:

Equipment Verifications

[ Time H Position I Applicants Actions or Behavior APPENDIX B CONTAINMENT RAD MONITORS

1. IF SI occurred on Unit t ThEN CHECK following rad monitors:

BOP

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

• Lower containment post-accident rad monitors i-RM-90-273A and i-RM-90-274A NORMAL [1-M-3O]

• Containment rad recorders 1-RR-90-112 and 1-RR-9O-iO6 NORMAL [O-M-121 (prior to isolation)

16. WHEN directed by E-O, B OP ThEN PERFORM Appendix D, Hydrogen Mitigation Actions.

IL CHECK pocket surnp pumps STOPPED:

IM-15, upper left corner]

BOP

• HS-77-410, Rx Bldg Aux i9oorand Equipment Drain Sump pump A

• HS-II-41 1, Rx Bldg Aux. floor and Equipment Drain Sump pump B.

1W DISPATCH personnel to perForm BOP EA-O-i, Equipment Checks Fdlowing ESF Aduatiow

19. ENSURE plant announcen ent 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 201 2-302 Scenario # 5 Event # Page 48 of 48 Event

Description:

Critical Task Critical Tasks: Critical Task Statement I. 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

Time: Now Date: Today

• Unit I MCR Checklist (751-6338 ID 950848) Then Press 2 Mode 2, -2% Power NRC phone Authentication Code PSA Risk: Green Grid Risk: Green Until 0800 XXXX RCS Leakage ID .02 gpm, UNID .02 gpm After 0800 YYYY

-- .mra4 CO1TRj Eiu âitJNOP 1um JNOP O*ner RTS -

NONE P

- V S Yr NONE J PfotcctidEguzpment NONE SI/Test in Progress/Planned: (Unit 2 Operator is performing)

• 0-SI-NUC-000-1 .0, Estimated Critical Conditions.

• 0-Sl-S)(X-068-1 27.0, Minimum Temp for Criticality.

Major Activities/Procedures in Progress/Planned:

• Place Feed Reg Valves in AUTO using 0-GO-4 Section 5.1, step 4.

• Continue with power increase using 0-GO-4 Section 5.2.

Radiological Changes in Plant During Shift:

• Containment dose rate increase with Rx power increase. Contact Rad Con for all RWP details.

Review current TS/TRM/ODCM/FPR 4.

Current Qualification Status Required Actions Review the current controlling Walkdown MCR Control Boards with off-going Operator Reactivity Management Plans SR/PER reviews complete for previous Review Narrative Logs shift (SM/US/STA) (previous day and carry-over items)

Relief Time:_______________________ Relief Date:_________________________

inj1iiw -

Review Operator Workarounds, Review applicable ODMI actions Burdens, and Challenges (applicable (first shift of shift week)

Unit/Station)

Review changes in Standing/Shift Review changes to TACFs issued orders since last shift worked) (since last shift worked)

Review Control Room Deficiencies Review Component Deviation Log first shift of shift week) (Active Procedures)

Time: Now Date: Today Abnormal Equipment Lineup/Conditions:

W N T1jOOM g690) (54k93 II1V f 1 Train B Week Feed Reg Valves in MANUAL 1-RM-90-119 OOS SR 111623061. 1-RM-90-99 is in service.

AUXILIARY BUILDING (7775) (593-2469) I All equipment operating or operable.

IUJtDING 7771 All equipment operating or operable.

J

• **QVTSP QZ*** J* *t* :**

All equipment operating or operable.

Time: Now Date: Today Required Additional Monitoring and Contingencies (Updated and Maintained by SM)

Issue Required Action Expiration Date ODMI TACF Description TACF .

UNIT ONE REACTIVITY BRIEF Date: Today Time: Now RCS Boron: 1570 ppm Today BA Controller Setpoint: 42 %

• RCS B-10 Depletion: 0 ppm Operable BAT: A BAT A Boron: 6850ppm BAT C Boron: 6850ppm RWST Boron: 2601 ppm Nominal Gallons per rod step from  : N/A gallons of acid, N/A gallons of water Verify boric acid flow controller is set at Adjusted BA Controller Setting iaw O-SO-62-7 section 5.1 Gallons of acid: N/A Gallons of water: NIA Rod Steps: NIA

[ .

Estimated rodslboroh for emergency step power rtuction **

(Assuming Xenon equilibrium and no. reactivity effects due to Xenon. 2/3 total reactivity from rods, 1/3 from boron)

Power reduction amount Estimated Final Rod Position Estimated boron addition 10% N/A Steps on bank D N/A gallons 30% NIA Steps on bank D NIA gallons 50% NIA Steps on bank D N/A gallons These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or S0-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago.

Data Valid until three weeks from now.

Number of dilutions: 0 Number of borations: Rod steps in:

Gallons per dilution: 0 Gallons per boration: Rod steps out:

Total amount diluted: 0 Total amount borated: Net change: IN/Out Number of dilutions: 0 Number of borations: Rod steps in:

Gallons per dilution: 0 Gallons per boration: Rod steps out:

Total expected dilution: 0 Total expected boration: Net change: In/Out Remarks:

Rx Power2% MWD/MTU 150 Xenon Samarium -971 pcm 0-SO-62-7 Appendix D was completed by the STA.

Next Unit I Flux Map is scheduled- 74% RTP mit Supervisor:

Name/Date

Operations Chemistry information Sample Point ThdiI!IIIIi1IIi1P Units Boron Date I Time Goal Limit UI RCS ppm 1570 Today I Now Variable Variable U2 RCS ppm 816 Today I Now Variable Variable UI RWST ppm 2601 Today/Now 2550-2650 2500-2700 U2 RWST ppm 2569 Today/Now 2550-2650 2500-2700 BATA ppm 6850 Today / Now Variable Variable BATB ppm 6850 Today / Now Variable Variable BATC ppm 6850 Today / Now Variable Variable Ui CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 Ui CLA #2 ppm 2575 Today I Now 2470-2630 2400-2700 Ui CLA #3 ppm 2591 Today I Now 2470-2630 2400-2700 Ui CLA #4 ppm 2589 Today I Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today I Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today I Now 2470-2630 2400-2700 U2 CLA #3 ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today I Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today I Now 2050 2000 Ui RCS ppm 1.1 Today/Now >1 >1 U2 RCS ppm 2.43 Today / Now 2.18-2.48 2.33 Indicator Units UI Date I Time U2 DatelTime SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now SI 137.5 CVELeakrate gpd <0.1 Today/Now <0.1 Today/Now 5 gpd leak equivalent cpm 115 Today / Now 85 Today / Now 30 gpd leak equivalent cpm 490 Today / Now 308 Today / Now 75 gpd leak equivalent cpm 1 165 Today / Now 710 Today / Now 100 gpd leak equivalent cpm 1540 Today / Now 933 Today/Now 150 gpd leak equivalent cpm 2290 Today / Now 1380 Today/Now CVE Air Inleakage cfm 10 Today / Now 12.5 Today / Now Bkgd on 99/119 cpm 50 Today / Now 40 Today / Now Correction Factor 99/119 cpmlgpd 64 Today /Now 14.13 Today/Now

Pa 1 1211 NRC 3 Rx Spdsi .xls DELTA REACTOF POWER ASSUMEIDINSERTEDEXPECTEEDELTA RHC BORON DELTA ECOMMENERECOMMEN[ IODINE TIME POWER DEFECT ROD HT WORTH XENON BORON CONC PPM DILUTION BORATION CONG (hrs) (%) (pcm) (steps) (pcm) (pcm) (pcm) (ppm) (ppm) (gal) (gal) (% eq) 0 2.0 38.6 159.0 -606.4 -54.7 --- 1570.0 --- --- --- 0.1 1 6.0 115.0 165.0 -551.9 -53.9 21.0 1566.6 -3.4 360 0 0.5 2 10.0 188.7 171.0 -494.6 -58.2 20.7 1563.3 -3.3 138 0 1.2 3 14.0 259.5 178.0 -426.5 -69.1 13.7 1561.2 -2.2 92 0 2.3 4 18.0 328.2 185.0 -355.3 -87.8 16.1 1558.6 -2.6 108 0 3.6 5 22.0 395.0 194.0 -263.1 -114.9 1.8 1558.3 -0.3 12 0 5.3 6 26.0 459.9 200.0 -199.7 -150.7 37.2 1552.4 -5.9 249 0 7.1 7 30.0 523.7 204.0 -157.1 -195.1 65.6 1541.9 -10.5 441 0 9.2 8 30.0 525.0 208.0 -119.8 -247.0 15.9 1539.4 -2.5 107 0 11.2 9 30.0 525.3 212.0 -82.6 -304.5 20.6 1536.1 -3.3 139 0 13.1 10 30.0 525.7 216.0 -50.7 -365.6 29.7 1531.3 -4.7 201 0 14.7 11 30.0 526.2 216.0 -50.5 -428.9 63.7 1521.2 -10.2 432 0 16.2 12 30.0 527.5 216.0 -50.3 -493.2 65.3 1510.8 -10.4 444 0 17.6 13 30.0 528.7 216.0 -50.1 -557.4 65.3 1500.4 -10.4 446 0 18.8 14 30.0 530.0 216.0 -49.9 -620.9 64.5 1490.1 -10.3 444 0 19.9 15 30.0 531.3 216.0 -49.7 -683.0 63.2 1480.0 -10.1 438 0 20.9 16 30.0 532.6 216.0 -49.4 -743.3 61.4 1470.3 -9.8 428 0 21.8 17 30.0 533.9 216.0 -49.2 -801.4 59.2 1460.8 -9.4 416 0 22.6 18 30.0 535.1 216.0 -49.0 -857.1 56.7 1451.8 -9.0 401 0 23.3 19 30.0 536.3 216.0 -48.8 -910.2 54.1 1443.2 -8.6 384 0 24.0 20 30.0 537.4 216.0 -48.7 -960.6 51.4 1435.0 -8.2 367 0 24.6 150 MWD/MTU Hold Tavg = Tref +1- 1 .5F Total 6047 0 6820 BAT ppm Small hourly boration/dilution volumes may be accumulated for larger single additions Reason for Maneuver Reactor/Plant restart following forced outage- 30% hold Date Today RxEng Name J. Sidekick Comments none

1201-302 SCN 3 Booth Instructions BOOTH OPERATOR INSTRUCTIONS Sim. Setup

1. Reset IC-9 2% power BOL time in core life

2. Perform switch check.

3. Verify control rod step counters reset.

4. Place simulator in RUN.

5. Place Mode 2 placard on panels.

6. Place B Train Week sign on the simulator.

7. Allow the simulator to run for at least 3 minutes before loading SCEN file or starting the exercise. This will initialize ICS.

8. Load SCENS: S-1211 NRC SCN 3

9. Select NR-45 to Startup Channels

10. Ensure 1-M-5 Tave-Tref Recorder re-scaled for MODE 2 values

11. Ensure IC Pzr B/U Htr Group energized

12. Provide an in-progress copy of O-GO-4.Section 5.1 Step 4

13. Acknowledge any alarms, allow the plant to stabilize, and freeze the simulator.

14. Perform the SIMULATOR OPERATOR CHECKLIST

15. Place turnover sheets on the operators desks.

16. Place simulator in RUN before crew enters the simulator.

Page 1 of 2

1201-302 SCN 3 Booth Instructions EVENT IC/MF/RF/OR # DESCRIPTION/EXPECTED ACTIONS/BOOTH FEEDBACK This override is IMF RPO7 f:1 Failure of Hi-Hi containment pressure logic to initiate Phase active when the B containment isolation.

SCN file is loaded.

This override is ICR ZDIHS6523A f:3 Prevents auto start of the EGTS fans.

active when the ICR SCN file is ZLOHS6523A GREEN loaded. f:1

{global95[2481]} DOR ZDIHS6523A

{global95[2481]} DOR ZLOHS6523A_GREEN ICR ZDIHS6542A f:3 ICR ZLCHS6542A_GREEN f: I

{global95[2494]} DOR ZDIHS6542A

{global95[2494]} DOR ZLCHS6542A_G REEN N/A Raise Power to 13-15% in preparation for Main Generator Synchronization When directed, IMF NIO4B f:91 k:2 IR Channel N-36 fails high use KEY 2 to Support staff: When contacted to evaluate and reset failure, insert inform the crew that a team will report to the MCR in 45 malfunction. minutes When directed IMF THO1 B f:O.003 k:3 RCS Loop 2 Hot Leg Leak 30 Gpm.

by the Lead Examiner, use KEY 3 to insert malfunction.

When directed IMF RX29 f:100 r:180 k:4 PT-1-33 slow failure by the Lead Examiner, use KEY 4 to insert malfunction.

When directed MMF THOIB f:12 r:600 Loop #2 LOCA-To Require Rx Trip and Safety Injection.

by the Lead

Examiner, modify the malfunction.

If directed, IRF RHR14 f:1 k:8 RWST To RHR Pp Flow Control Vlv Power, FCV-63-1.

insert the Support staff: if dispatched w/ EA-201 -1 requested, as remote function. AUO, wait 2 minutes respond that electric power is restored to FCV-63-1.

Page 2 of 2

[ SQN POWER ASCENSION FROM LESS OGO4

( Unit I & 2 THAN 5% REACTOR POWER TO 30% Rev. 0076 L REACTOR POWER Page 8 of 111 3.0 PRECAUTIONS AND LIMITATIONS 3.1 Precautions LAdh to Precautions and Limitatiohs erenced in NPG-SPP-01 .2.

Reactor Engineering shoul.d be contacted for guidance on core operating recommendations during unusual power maneuvers such as startup during end of core life. c.i 1]

TRM 3.3i.5 requires LEFM core thermal power (U21 18) to be used tO perform O-Sl-OPS-092-078.0 above 15% reactor power.

available if the following conditions are met: LEFM indication is

• LEFM status NORMAL on lOS Calorimetri.c Data scree n

• LEFM core thermal power (lOS point U21 18) shows good (green.> data.

• LEFM MFW header temp (ICS point T8502MA) grea ter than 250°F.

If LEFM indication is NOT available above 15% reactor pow er, then TR&.3.3.15 action must be entered.

During startup, MS power range indication may be reading i significantlyhigher than true power until calibration adjustments are made. The following should be used to determine the most accurate indication for com parison with NIS:

. When reactor power is less than or equal to. 15%, use average loop..T (U0485).

• When reactor power is greater than 15%, use LEFM core thermal pow er indication (U2118). If LEFM is NOT available, then continue, using aver age. loop T up to 40%. (UI 118 will be used above 40%. with LEFM unavailable).

The boron concentration in the pressurizer should be maintained within 50 ppm of the RCS. by use of pressurizer heaters and spray.

Pressurizer enclosure temperature should be maintained less than I 50°F Rapid changes In. pressurizer enclosure temperature may result in pressurizer safety valve simmer.

• SQN POWER ASCENSION FROM LESS Unit I & 2 0G04 THAN 5% REACTOR POWER TO 30% Revs 0076 REACTOR POWER Page9oflhl 3.1 Precautions (continued)

The. low pressure turbine steam inlet temperature shou when unit load is less than 10%. When reducing load ld be limited to 400°F

, the reheater control valves should be adjusted to limit reheater outlet temperature to a maximum of 400°F within approximately 15 minutes after reaching 10% load.

Do NOT pass steam through the turbine with the rotor at should be on turning gear anytime the main steam lines rest. The turbine.

turbine stop valves. are pressurized up to Change in load should be controlled in accordance with load changing curves, of Tl-28, Figures 6 and 7. TI-28, Figure 6 is designed to limit the maximum rotor stress during the entire program of acceleration, synchron izing, holding at mInimum load, followed by raising load to full capability

. The recommended time periods for each phase of the program are deter mined by the measured first-stage metal temperature at the time of starting.

The turbine should be operated in IMP OUT cont rol during normal unit operation. IMP IN operation results in system swin gs and should only be used during.the performance of valve tests. (W letter GP 89-155, RIMS 557 901-26 972)

The Predictive Maintenance Engineer (PDM) should unit trip sO that he may determine if Localvibratin be contacted following a mon Turbine-Generator, by the PDM staff should be perfo itoring of the rmed when the unit is restarted. Normally, monitoring Is necessary following a refueling oUtage a major maintenance outage on the turbine-generator,, or after a plant trip which was due to a turbine initiated trip or a generator elect rical initiated trip Two hours lead time. prior to the initial turbine roll is necessary to ensure that the PDM staff is. onsite to monitor the start-up. The Main tenance Shift Supervisor (MSS) has the telephone numbers and pager num bers for the Predictive Maintenance. Engineer and the Supervisor for the PDM staff.

Any off frequency turbine operation is to be reported to the Compone nt Engineering Group Vibration Engineer for record keeping. The repo rt.will include duration and maghitude.of off-frequency operation.

Operation, at off-frequencies is to be avoided in order to prevent the.proba ble.

occurrence of turbthe blade resonance. Prolonged periods of operation at certain off-design frequencies could cause excessive vibratory stresses which could eventually generate fatigue cracking in the blades Off-frequency operatiOn is permitted to the degree and time limit specified on the chart Off-Frequency Turbine. Operation, Figure 14 of Tl-28.

I j

SQN Unit I & 2 POWER ASCENSION FROM LESS O-GO-4 THAN 5% REACTOR POWER TO 30% Rev. 0076 L REACTOR POWER Page 10 of 111

.3.1 Precautions (continued)

The valve position limiter should be periodical ly positioned approximately 10%

above gOveino.r control indications (keeps gove rnor valves off of the limiter) as turbine load is raised. This prevents inadvertent valve opening and. allows a faster response of theload rises by limiting governor runback feature which ensures main feedwater system will supply the required amount of flow.

The position of.çontrol rod bank D should normally level is steady state at Or above 8% RTP. At stea be 215. steps when power dy state power levels belOw 85%, control bank D should normally be 165 steps.

than 2 steps below this guidance for long term, If rod position is more then an impact to safety analysis assumptions may occur. Long term will be defined/determined by Reactor Engineering and the Fuel Vendor.

At low power levels, the LP Heaters may be unb alanced in extraction steam supply use and heat pickup across the conden sate side of the heater string.

This condition should correct itself as the unit app roaches 45-50% Turbine Power. (REF. REF 99-003789-000) 0-PI-OPS-035-O01 .0 should be performed prior to turbine restart when recommended by engineering, following maintenanc e or plant atMties in which the generator was depressurized during a forced outage, or after a refueling outage 0-Pl-OPS-035-001 0 provides verif the Seal Oil System normal and backup regulator ication and adjustment of

s. (REF PER-04-24237-000).

The turbine should not be on hold at 1800 rpm for long er than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> when the generator is not synchronized to the grid. Longer than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> will cause overheating of the turbine blading (last row).

SON POWER ASCENSION FROM LESS 0-GO-4 Unit I &.2 THAN .5% REACTOR POWER TO 30% Rev. 0076 REACTOR POWER Page II of If I 31 Precautions (continued)

Voltage Control E

Failure to comply with the NERC VAR-002 requirement could result in a Utility Vilation and I or monetary penalties.

OperatiOn of the Main Generator without Automatic Volt age Control could impact grid voltage requirements. Refer to GOl-6 for MVAR limits.

When the Main Generator is connected to the grid, the volta ge regulator shall be operated in Automatic,. unless coordinated. with the Operator (SELD). Tran smission Main Generator operation outside of the Transmission Volt age Schedule requires coordination with the Transmission Operator, and operators Log of time, reason, and that the Transmis nota tion in the sion Operator notification was made.

When directed to modify voltage, the Generator Oper ator shall comply (within plant procedural requirements) or provide, an explanation of why the schedule cannot be met.

While, the Main Generator is tied to the grid perform thef ollowing:

The Transmission Operator (SELD) shall be notified of any Volt age RegulatOr automatic trips to Manual or urgent Manual Transfers between AUTO and Manual as soon as practical but notificati on shall be within 30 minutes.

72 The Transmission Operator (SELD) shall be notified prior to a planned

? Voltage Regulator transfers between Manual and Auto.

All position: changes (to and from Auto or Manual) of the Voltage Regulator shall be entered into the. Narrative Log along with the date, time of positIon change, reasons, anticipated .durtionarid notifications made.

SQN POWER ASCENSION FROM LESS Unit I & 2 0G0-4 TI-IAN 5% REACTOR POWER TO 30% Rev. 0076 REACTOR POWER Page 12 of 111 3.1 Precautions (continued)

Reliability Directives and Protective Relay/Equipm ent Failures t

Failure to comply with the NERC VAR-002 requ irement could resUlt in a Utility Violation and I or monetary penalties.

Plant Operations shall notify the Transmission Bala ncing AuthorIty (BA) or Transmission Operator of protective relay or equipme nt failures that creates a creditable risk to Plant Generation. A cred itable.

generation represents a potential reduction in transmiss risk to ion system reliability.:

Reliability Directives to the Generator Operator are via the Balancing Authority or*Transmission Operator. Required actio n time may range from immediate to no longer than 30 minutes Actions shall delay. The directives may be associated with preventinbe taken without g or clearing Local System issues, or neighboring system issues.

Plant operations shall take timely actions as direc ted Authority or Transmission Operator to mitigate critic by the Balancing al conditions to return the bulk electrical system to a reliable state Plant operations shall comply with Balancing Authority or Transmission Operator direc tives unless such actions would violate safety, equipment, or regulatory or statutory requirements.

Plant Operations shall immediately inform the Balancing Auth ority or Transmission Operator of the inability to. perform directIves so that the WA Reliability Entities may implement alternate remedial actions.

. SQN POWER ASCENSION FROM LESS Unit I & 2 0-GO4 THAN 5% REACTOR POWER TO 30% Rev. 0076 REACTOR POWER Page 13 of III 3.2 Limitations After refueling operations, the NIS indications may be calibration at higher power levels. The NIS calibratio inaccurate Until n procedures will adjust the .PRM trip setpoints to ensure that the excore detectors do not contribute to an overpower condition. Pribrto startup, the PRM high range. flux trip setpoint will be adjusted from 109 to 60%, with the rod stop fc2] (C-2) remaining 103%.

Preconditioned Power Levels and Maximum Allowabl e Rate specified in Tl-40, Determination of Preconditioned Reac s of Power Rise are, tor Power.

During initial startups, based on Westinghouse recomme ndations, a lower power ramp rate limit has been implemented for power levels above the Pfr intermediate power threshold. The Intermediate Power Threshold is unitlcycle dependent and is determined by the Vendor. Refe r to T1-40.

ICS will automatically monitor pre-conditioned pow er level as follows:

Point Ui 127 is reactor power in percent of RTP base d on either secondary calorimetric or RCS AT depending on power level.

Point U0103 is a 20 minute rolling average.ofreac tor power rate-of-change filled over? 20 minute period. UO1 03. is of %/hour power ramp rate and can be used in decid a leading indicator ing to speed up or slow down the ramp rate.

,-,) Point 1J0104 is a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> rolling average of reactor power rate-of-change

.* fitted over a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. period. UO1 04 is used in demonstrating compliance with fuel pre-conditining power ramp rate limits.

Point K005S is the currently qualified (or pre-conditioned) pow er level.

These points can all be monitored with the lCS group disp lay T140.

Appendix A may be used if the ICS. is unavailable.

4? Any Ti-40 power rise limit that is exceeded in any one hour is evaluated in accordance with NPG-SPP-03.1..

In the event of a change hi the, rated thermal power level exceedin g 15% in one hour, notify chemistry to initiate the conditional portions of 0-S1-CEM

-030-4072, O-Sl-CEM-000-050.2 and 0-Sl-CEM-030-41 5.0 due to the therm pow al er change.

The. main turbine shall be on turning gear at least one hour prior to rolling with steam.

Westinghouse should be contacted if the turbine is operated outside of its operating limits.

• SQN POWER ASCENSION FROM LESS Unit I & 2 0-G04 THAN 5% REACTOR POWER TO 30% Rev. 0076 REACTOR POWER Page 14 of 111 3.2 Limitations (continued)

To prevent high vibratory stresses. and fatigue dam blading, do NOT operate the turbine for even brief age to the last stage turbine periods outside of limits listed below: [W Ltr GP 86-02 (B44 861112 002)1 At loads less than or equal to 30% (35.0 MW), the maximum, permissible.

backpressUre is 1.72 psia. (3.5 Hg). The ICS Computer alarm point UP5007 which will identify the condition of con denser pressure> 112 psia in conjunction with MW being <350.

At loads greater than 30%, the maximum perm issible backpressure Is 2.7 psia (5.5 Hg) with a 5 minute limitation before tripping the turbine.

Generator voltage shall NOT exceed 24.8 kV.

The main generator field shall NOT be energized at less than 90%. rated speed.

Do NOT allow the generatorto become und.erexcited

fl this context is of conc . The term under excited ern when the generator is NOT synchronized to the OR operation outside the limits of GOl-6 and the Gen grid erator Capability Curve when synchronized to the grid.

The #3 Heater brain Tank should remain drained with LCV-6-105A and B failed open (per I ,2-SO-5-2) until reactor power exceed s 45-50% This will prevent intermediate heater string isolations if a turbine trip occ urs at tower power levels If a level is established in the #3 Heater Drai n Tank prior to exceeding P9 setpøint (50% power), a turbine trip will result in Intermediate Pressure Heater string isolation(s).

The fpllowing Main Turbine vibration limitations and actions should be adhered to:

Vibration levels whIch exceed 7 mils (alarm set-point) should be 7 verified by Predictive Maintenance Group.

Vibration levels greater than 7 mIls and less than 14 mils should be.

continuously monitored by Predictive Maintenance Group.

IF vibration level is greater than or equal to 14 mils, THEN TRIP the turbine,.

/5 Limit temperature differential between any condensers to less than 50°F Exceeding this limit results in improper bearing loading and misalignment, thus potentially raising main turbine vibration Limitation is based on the temperature as measured in th,é LP turbine exhaust hood. (PER 178439>

• SON POWER ASCENSION FROM LESS Unit I & .2 0-G04 THAN .5% REACTOR POWER TO 30% Rev. 0076 REACTOR POWER Page 15.. of 111 3.2 Limitations (continued)

IF temperature differential between the conden sers is greater than or equal to 50°F, based on the temperature as measured in hood, THEN TRIP the turbine.(FSAR 10.2.2, VTD the LP turbine exhaust

-W120-6510, PER 178439)

If Turbine seals have been in service with Turbine Turning Gear secured, and unit is to be returned to operation, then both of the following limitations apply:

Turbine is required to be placed on turning gear for .10 times as long as period it was stopped (up to a maximum of.4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> s).

If eccentricity is higher than normal, turbine is requiré dto be Left on turning gear until eccentricity indication has reached and has its,norrnal minimum valu been maintained at e for at least one hour.

If relying on the truth dial for determining eccentricity, eccentricity mUst be verified prior to each turbine roll. Verifying eccentric ity before each turbine roll is not required if the truth dial is only being used to verif y the installed instrumentation is working properly.

.SQN POWER ASCENSION FROM LESS Unit I & 2 O-GO-4 THAN 5% REACTOR POWER TO 30% Rev. 0076 REACTOR POWER Page 16 of III STARTUP )o> Unit I B.w Date 4.0 PREREQUISITES Throughout this instruction where an IF1THEN statement exists, the step should be NIAd if the condition does NOT exist.

ENSURE Instruction to be used is a copy of effective version..

ENSURE Precautions & Limitation of Section 3O have been reviewed.

ENSURE Reactor Power is between 1 and 4%

ENSURE each performer documents their name and initials:

Print Name Initials

SQN POWER ASCENSION FROM LESS Unit I & 2 0-GO-4 THAN 5% REACTOR POWER TO 30% Revs 0076.

REACTOR POWER Page 17 of Iii STARTUP Unit .1 Date

.5.0 INSTRUCTIONS 5.1 Actions To Be Performed Prior To Raising Rea ctor Power ENSURE Prerequisites complete.

Steps 51[2] through5i [1 2] can be performed out of sequence.

IF O-GO-4, Appendix A, Mode 2 to Mode I Revi ew And Approval is NOT current for this startup, THEN INITIATE Appendix A, while continuing with this instruction. C IFthe. Mode 3 to Mode 2 to Mode I surveillance checklists are NOT current for this startup for Mode I entry, pT1-iEN REQUEST Periodic Test Coordinator to issue the Mod Mode 2 Mode 1 surveillance checklists to the appl e 3 to icable departments.

Initials Time Date

• SQN POWER ASCENSION FROM LESS Unit I & 2 0-O4 THAN 5% REACTOR POWER TO 30% Rev. 0076 REACTOR POWER Page 18. of 111 STARTUP_______ unit____ Date_

5.1 Actions To Be Performed Prior To Raising Reactor Power (continued)

MFW 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 occurs at 13% RTP (.494E6 LBMIHR steam flow Three Element control transition per loop).

MEW Reg valves may have a positive deviation if of the control band (1-4%) in the following step. reactor power is in the upper range PERFORM the following:

4.i] ENSURE four MFW Bypass Reg valves in AUTO..

C

[4.2] ENSURE MFW Reg. valves have minimal controllerdeviation.

C i4.3] ENSURE MFW Reg. valves are CLOSED

. C 4.4] PLACE MFW Reg. valves in AUTO.

C 4.5] ENSURE MFW valve control mode in 3 Element.

Enabled (clicktarget located in the center of each screen under th.e appropriate Loop # Contror button).

C During start up after a cold shutdown the Condens ate DI normally will be aligned for full flow polishing until the MSRs are in service.

/J ENSURE Condensate Dl polishing operation in accordance with Chemistry recommendations.

CAUTION After refueling operation, NIS Indications may b.e inaccur ate until calibration at higher power levels has been performed. RTP shall NOT be.al low.ed to exceed 4%

prior .to thern verificatn of the proper (or conservative) lR and PR. setp oints..

W j- 1. IF startup is following a refueling, THEN J- MAINTAIN reactor. power between 3 tO 4%. C

• SQN POWER ASCENSID.N FROM LESS Unit I & 2 0-GQ4 THAN 5% REACTOR POWER TO 30% Rev. 0076 REACTOR POWER Page 19 of 111 STARTUP________ Unit____ Date 5.1 Actions To Be Performed Prior To Raising Reactor Power (continued) id VERIFY trip and permissive setpoints are with in limits in accordance with O-Pl-NUC-092-082.0.

tc.i ft Rx Engineering Date Time ENSURE P-I 0 actuation setpoint is less than the IO_ power level setpoint. [0.2] IR trip Rx Engineering Date Time ENSURE all applicable portions of :0-RT-NU:C00 0-O01 .0

\.- are complete.

,v?4 Rx Engineering Date Tirhe NOTES

1) The relationship between TAVO and reactor powe.r with Steam Dumps in Pressure Mode while maintaining Steam Pressure is O..52deg

.FI%

2) Due to instrument inaccuracies, the steam dum p or SG atmospheric relief valve setpoint of 84% or I 005 psig may be (+/-).I % or(+/-

)1 2 psig off, MAINTAIN TAVG stable with the steam dumps in the pre

L ssure mode or with the SG atmospheric relief valves set at 84%

or 1.005 psig.

ENSURE 0-Sl-NUC-000-03&0 shutdown margin calculat ion is complete .(NIA if NOT required)..

ENSURE containment air temperatures are within limits in accordance with 1 ,2-Sl-OPS-000-003.D, App. B.. (TS 3:61.5)

INITIATE Appendix E, Preparations for Turbine Roll. 0 INITIATE Appendix F, Preparations for Generator Synch 0

• SQN POWER ASCENSION FROM LESS Unit I & 2 THAN 5% REACTOR POWER TO 30%

0-GO-4 Rev 0076 REACTOR POWER Page 20 of 111 STARTUP >c,0 Unit I S Date_______

51 Actions To Be Pertormed Prior To Raising (continued) Reactor Power 4? REVIEW Tl-40 to determine applicable Pre f conditioned Power Levels and Maximum Allowable Rates of Pow er Rise.

VERIFY all applicable action steps n Section 5.1 or initiated. are complete ENSURE Appendix A,. Mode 2 to Mode I Review and Approval completed to verify all restraints to Mo de I entry have been resolved and approvals for mode cha nge granted.

-ro

/417 SM. Signature Date Time End of Section

SQN POWER ASCENSION FROM LESS Unit I & 2 0GO-4 THAN 5% REACTOR POWER TO 30% Rev. 0076.

REACTOR POWER .

Page 21 of 111.

STARTUP )Q?Q Unit I 5 - Date. 14-1 5.2 Reactor Power Ascension To Between 13% And 15% RTP The steam geherator level operator is in control of unit startup until the MFW Reg. valves are in AUTO and controlling level. fC.5 REVIEW plant parameters and indications, AND VERIFY stability prior to reactor power escalation.

Adjusting blowdown flow will provide an additional meth inventory. (Close blowdown isolation valves only if levelod of controlling SG water cannot be maintained)

Prior to raising reactor power above 5%, SG blow dov.n should be in service, Maximum blOwdown rate, is less than or equal to: 270 gpm. Each steam generator flow, up to 60 gpm is indicated on panel L-35 7 located in the A.B. Supply Fan Rm.

Minimum blowdown rate equals 5 gpm for each should be determined by chemical analysis. steam generator Final blowdown rate Computer points require a prefix 0, 1., or 2 be placed in front of the point number;, for example, I F2261A.

IF SG blowdown is in service, THEN ADJUST F1C-I5-43 as desired.

(plant computer pt. F2261 A)

[ SQN Unit 1 & 2 POWER ASCENSION FROM LESS OGO4 THAN 5% REACTOR POWER TO 30%

Rev. 0076 REACTOR POWER Page 22 of iii STARTUP > O Unit I ii - Bate 1D4 52 Reactor Power Ascension To Between 13% And 15% RTP (cc ntinued)

NOTES Actions effecting reactivity are directed in the following step. O-SO-62-7 requirements shall be adhered to for reactivity changes (he

. reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized during performance.

Recommended dilution rate is 50 to 75 gall

-t on batches every 12 to 1.5 minutes for a steady power rise. Rod movement should be limited to 112 step increments approximately every 1 1/2 minutes. Dilution and depending on 5G. level control stability. rod movement rates may be 37 Control Rod withdrawal and I or dilution req uire the change in core reactivity due to changing ments may be significantly impacted by Xenon concentration.

INITIATE a methodical and deliberate reac tor power ascent by manual adjustment of the control banks or by diluting the RCS. 0.

MODEl I

4] WHEN reactor power is above 5%,

THEN LOG Mode I entry in the Unit Narrative Log.

C

[51 MAINTAIN the SG levels on program by periodically adju sting the MFW Bypass controller level setpoints using Append ix B and 1, 2.SO-98-1, Distributed Control System

.0 t61 IF Turbine roll in parallel with power ascent is desired, THEN PERFORM Section .3 in parallel with the remainder of this section.

t71 IF the intermediate range rod stop setpdint is reached before P-b energizes, THEN

[7.1] STOP the power escalation. C

SQN POWER ASCENSION FROM LESS Uhit I & 2 O.-GO-4 THAN 5% REACTOR POWER TO 30% Rev 0076 REACTOR POWER Page 23 of Iii STARTUP Unit____ Date 5.2 Reactor Power Ascension To. Between 13% And (continued) 15% RTP

[7.2] CONTACT Reactor Engineering to evaluate power range calibration. tc.a Initials Time Date

[8j WHEN reactor power is greater than or equalto 10%

on.at least 2 out of 4 PRMs, THEN c.ij [0.3]

[8.1] VERIFY annunciator XA-55-4A, window D.-5:

P-i o NUCLEAR AT POWER is LT.

PERMISSIVE a

[8.2] VERIFY annunciator XA-55-4A, 6-5:

P-7 LOW POWER TRIP BLOCK is DARK.

a

[8.3] COMPARE the highest reading PRM with the highest reading loop T indication to be wIthin 5% of each other.

.tC.1J [C.3j

[8.4] IF the above conditional response. is NOT attained, THEN (8.4.1] STOP the power ascent. a

[8.4.2] NOTIFY the SRO Initials Date Time

SQN POWER ASCENSION FROM LESS Unit I & 2 0-00-4 THAN 5% REACTOR POWER TO 30% Rev 0076 REACTOR POWER Page 24 of 111 STARTUP________ Unit .

Date 5.2 Reacto.r Power Ascension To. Between 13%

(continued) And 15% RTP NOTE The following step will block both IR(25%

) and PR (25%) low power reactor trips.

191 BLOCK the IR HI FLUX reactor trip and PR LO Ran ge HI FLUX reactor trip by performing the following

[91] PLACE IRM TRIP BLOCK P-1O IHS-92-50031 AND IHS-92-50041 to BLOCK.

0 t2i VERIFY annunciator XA-55-4A, window Q-2:

INTERMED RANGE TRAINS A & B TRiP BLOCKED is LIT, C

[93] RELEASE IHS-92-50031 AND IHS-92-50041

[9.4] PLACE PRM LOW POWER TRIP BLOCK P-1O

[HS92-50051 AND FHS-92-50061 to BLOCK.

C

[95} VERIFY annunciator XA-55-4A, window D-1:

POWER RANGE LOW SETPOINT TRAINS A & B TRIP is LIT.

BLOCKED C

RELEASE 1HS-9200i1 AND FHS-92-50OJ. C

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit I & 2 THAN 5% REACTOR POWER TO 30% Rev. 0076 REACTOR POWER Page 25 of Iii STARTUP________ Unit____ Date 5.2 Reactor Power Ascension To BetweOn 13% And (continued) 15% RTP NOTES

1) SG MFW Bypass and MEW Rg. valve controllers are controlled by one of the following:

Single element control desired SG level setpoint will be SG level. Control is based only on SG level as the feed comfor pared to the actual back controlling the valve operation.

• Three element control uses SG LeVel, feedwater flow for controlling the MFW Bypass and MFW Reg. valv , and steam flow as inputs es. Desired mode, of operation.

2) The. change from single element to three element cont rol:

• Observed on the DCS Operator Display monitors by acce ssing the Feedwater Valve Control screen and looking below, the loop Main Feedwater Valve display.

The Control Status text will change from Single Elem ent to Three Element

• Uses Total Steam Flow demand sthe input for three element pontrol. The swap over to three element control may occur before or after the following step.

[101 WHEN reactor power is between 13 and 15%,

THEN

[10.1] STOP power ascent.

D

[10.2] STABILIZE the plant.

D

[1 033 PERFORM the following:

• MONITOR for swap over from single element to three element çØntrol in the DCS Feedwater System

• IF damping of SG level oscillations is required, THEN REFER TO 1, 2-SO-98-1 D

[11] IF rolling of second MFWP on recirc without pumping forward fortesting or maintenance is desired, THEN PLACE second MFPT in service by performing the following:

[11.11 RECORD which MFPT is to be tested.

[1 1.2 PLACE second MFPT in service in accordance with i2-SO-213-i. C

SON 0-SO-62-7 1,2 BQR0N CONCENTRATION CONTROL Rev. 62 Page? of 201 3.0 PREGAUTIONS AND LIMITATIONS The mode selector switch should be returned to the AUTO. makeup mode/

after any dilution or boration operation The control switch must be turne STAR d to T in orderforthe auto makeup to function.

At least one Reactor Coolant Pump or one RHR Pump must be in operation during dilution operations [C 6]

Maintain Pressurizer boron concentration within 50 ppm ofreadtrcolant loop boron concentration This can be accomplished by turning pressurize r heaters on and allowing sprays to maintain RCS pressure within program If Normal Spray is NOT available, then Auxiliary Spray should be used (1, 2-50-62-1) in conjunction with pressurizer backup heaters.

0 Axial flux difference should be maintained within limits by using the contro bank of rods hile changing boron boncéntration.

Prior to making a positive reactivity change, Tech Specs and TRM should l

be referenced to ensure the unit is not in a LCO action that prohibits positiv a e reactivity change. fC.1i A boron sample should be obtained whnever reactor/makeup wate r is added: to the VCT, unless the unit is at power and results of the makeup are as expe cted 0 When making an RCS dilution of 3000 gallons, it should be done in batch with an RCS boron concentration verification at the halfway point es (em 1500 gallons). Allow at least 15 minutes between batches 10.51 10.7]

Simultanepus makeup to..the RWST and the RCS should beavoided to prevent the possibility of injecting unborated (or under borated) water into the core [C 4]

[0.6] [cl]

Reactivity balance calculations are required for any power changes more than 1 %, except when immediate boration is required to maintain rods above the insertion limit or as required during an Rapid Shutdown or Load Reduction (AOP-C 03) or dropped/misaligned rod recovery (AOP-C 01) Although stated in the procedure that only one calculation is required for a major change in Reactor Power, calculations should be current and take into account the time dependency of parameters used in the calculation [e g one calculation to reduce RX power to 70% power to remove a MFP is acceptablel In the event of a large power manipulation (GO startup or shutdown) several calculations will be required A calculation should be performed for the ascension to 30% Reactor power, another for an ascension to 50%, and so on These calculations may be correlated. to GO plateaus I

SQN 0-SO-62-7 1,2 BORON CONCENTRATION CONTROL Rev 62 Page8of 201 3.0 PRECAUTIONS AND LIMITATIONS (CONTINUED)

Boric Acid Controller adjustment is required for B-i 0 depletion for autc..rnatic and manual makeup to improve the acc racy of the blend. The B-I 0 depletion valu.e for each unit can be obtained from the Rx Eng Information file located on the site intranet, Reactor Eng Information ICON can be found on the control room PCs.

An unanticipated power change greater than 5 MWT, rod motion greater than 1 .step (in or out), or TAVG greater than 0.5°F, require an SR and should be evaluated as a potential reactivity management event per NPG-SPP

-1 0.4, Reactivity Management Program.

Boron concentration measurement inaccuracies and integrator calibration tolerance may result in a small difference between RCS boro conc n entration and blend boron concentration. This may result in a rnail change in Tavg (114°F) and thermal power (by a few megawatts) after makeup.

Manual Makeup (Section 6.5) of approximately 200 gallons or less is preferred over allowing the system to automatically make up in Modes I and 2. Performing manual makeup and limiting the volume of makeup is prefe rred to reduce.th.e impact on reactivity, RCP seal performance (due to redu ced pressureltemperature.

transients) and RCS chemistry (due to reduced VCT press ure.changes). During transient conditions, emergencies, or during plant cooldow n, automatic makeup may be. used as. necessary (The potential exists that the blender piping contains primary water..

This will result in a dilUtion and a small reactivity addition.

0. Completely emptying the BATs for all valve work is not required to establish a safe work boundary. The valves on the lower portions the tanks require an empty 4tank to.. establish safe conditions. The tank drain, level instrument isolation and pump suction line are all at or near the bottom of the tank. These are listed in the table below:

BAT A BAT C BAT B I -VLV-62-1 049 0-VLV-62-I 049 *2-VLV-62-1 049 I -VLV-62-1 058 0-VLV-62-1 .058 2-VLV-62-1 058 1 -VLV-62-1 088 0-VLV-62-1 088 2-VLV-62-1 088 The. other valves associated with the Boric Acid Transfer Pumps can be worked with some level remaining in the tank. As a margin of safety, a maximum of 85%

should be. used to establish safe working conditions.

BORON CONCENTRATION CONTROL Page 9of 201 Unit____________

Date.___________

4.0 PREREQUISITE ACTIONS Throughout this Instruction whOre an IFITHEN statemen t

exists, the step should be NIA if condition does exist.

ENSURE the instruction to be usedis. a copy of the effective version.

ENSURE Precautions and Limitations, Section 3.0, has been reviewed.

c1 REVIEW the following Status Files for any off-normal alignments that may impact performance:

Status_File Uniti 5;Lt.

Unit2 D Radwaste D ENSURE Chemical and Volume Control System is in operation.

ENSURE the operating crew has been briefed for.any reactivity changes that will occur due to performance of the applicable procedure section.

p IF in modes 1, 2, or 3, THEN ENSURE requirements of TRM L.C.O. 3.1.2.6 are mete OR COMPLY with applicable actions.

IF in rnodes4, 5, or6, THEN

/1ENSURE requirements of TRM L.C.O. 31.2.5 are met, OR 1

COMPLY with applicable actions.

IF Primary Water required for the evolution to be perfOrrnec THEN ENSURE Primary Makeup Water system in service.

BORON CONCENTRATION CONTROL Page 10 of 201 Unit Date.

4.O PREREQUISITE ACTIONS (Continued)

N4E The following step is performed at the discretion of the RO and/or SRO.

WHEN performing a dIlution or horation, THEN IF Normal pressurizer spray Is available, THEN ENERGIZE pressurizer heaters so sprays can equalize the boron concentration, between the pressurizer and the RCS IF Normal pressurizer spray is NOT available, THEN PLACE Auxiliary Spray in service U (1, 2-SO-62-1) in conjunction with pressurizer backup heaters. (N/A if not applicablO)

NSURE appropriate Valve Checklist has been completed (NIA If not applicable).

VALVE CHECKLIST iNiTIALS 1-62-7.03 2-62-7.04 1

E NSUFE appropriate Power Checklist had been complete d

- (N!A if applicable).

POWER CHECKLIST INiTIALS 1-62-7.01 2-62-7.02 J3F Boric.Acid Tank is the borated water source, THEN.

ENSURE Boric acid pump aligned properly. .in accordance with 0-SO-62-1 0.

Fusing the RWST for the borated water source, THEN P/NSURE LCV-62-i35 and/or LCV-62-136 OPERABLE.

NOTE Step [l4 may be marked N/A if boration must be immediately initiated to maintain shutdown margin OR if performing a rapid boration using FCV-62-i 38 in preparation for RCS cooldown.

reactor is subcritical AND an RCS boration or dilution is required, THEN rr- PERFORM Appendix D

SQN BORON CONCENTRATION CONTROL 0SO-62-7 1,2 Rev. 62 Page 11 of 201 Unit_____________

Date iO44 4O PREREQUISITE ACTIONS (Continued)

Step [15] may be marked N/A for any of the following COfldtIOflS Minor power changes (Reference Section 3O)

• If boration must be immediately initiated to maintain control rods above the insertion limit

• During an emergency shutdown (AOP-C.03)

• Recovery of a dropped or misaligned rod (AOP-C.Q1).

If initiating a rapid bOrtion using FCV-62-i 38 immediately prior to.

reactor shutdown in preparation for RCS cooldown.

• During low power physics testing per O-RT-NUC-000-0O&O if.

boration/dilution values have been provided and verified by Reactor Engineering.

Appendix D and E may be used to verify data provided by Reactor Engineering. IV is not required if Appendices are perfOrme.d by an SRO to verity Rx. Engineering data 5F reactor is critical AND RCS boration or dilution will be performed, THEN I PERFORM the following:

[a Appendix E Reactivity balance calculation.

[b] Appendix D aJculation for amount of boric acid or prirnaiy water (Tl-44).

IF performing a Spent Fuel Pit boration, THEN.

M E NS.URE Chem Lab has provided sUpporting data.

jIF RCS boron concentration will be changed significantly,.

THEN

,NOTIFY Chem Lab to evaluate lithium impact and cation bød Use.

11

&1 4 6iaer.ty.

vi-( 1 0

i . L

BORON CONCENTRATION CONTROL 0-62-7 Page 12 of 201 Unit 3 Date.________

.4.0 PREREQUISITE ACTIONS (Continued) t1 8jREVIEW Unit and Radwaste Status Files for any off normal alignments that may impact performance.

7J3ENSURE each performerand verifier documents their name and. initials:

INDICATE below which performance section of this instruction will be used and the reason for this performance:

D 50 STARTUP/STANDBY READINESS O 6.0 NORMAL OPERATION o 7.0 SHUTDOWN Li 8.0 INFREQUENT OPERATION REASON:

End of Section 40

SQN CONTROL ROD DRIVE SYSTEM Unit 0 0-60-55-1 Rev,. 039 Page 6 of 91 3.0 PRECAUTIONS AND LIMITATIONS Rod thermal lok-up is NOT a concern when the react or OPEN. If reactor trip breakers are CLOSED and an RCS trip breakers are cooldown of greater than 50°F is planned, the shutdown and control bank s should be withdrawn at least 5 steps each. This will limit the possibility of thermal lock-up of the rods.

This does:not apply if performing sections 8.5 or 8.6.

If both MG sets are to be shutdown, the control rods and shutdown rods shall M)be inserted in the core and the reactor trip breakers QPEN prior down the MG sets. to shutting Reactor Trip Breakers shall NOT be closed while in compliance with LQO 3.4.1.2. Mode 3 unless in

( Failure to perform 1 .-Pl-IFT-099-OPtO, Verification r of P4 Contacts could result in the prevention of AUTO. SI if required.

Under normal conditions, the control rod banks mus in the prescribed sequence. For withdraWal the.

t be withdrawn and inserted sequence is Shutdown Bank A, Shutdown Bank B, Shutdown Bank C Shutdown Bank D, Control Bank A, Control Bank B, Control Bank C, and Control Bank is the reverse of the Withdrawal sequence. D. The. insettion sequence For manual bank sequencing, the prescribed, with drawal sequence. shoUld be followed. Rod motion of the corre and insertion ct bank should be monitored by observing the group step counters and therod position indicators.

(W5 During Control Rod withdrawal, the Control Banks shou r overlap.

ld be monitored for bank The control banks must. be maintained above their respe ctive insertion limits (Low-Low Alarm to ensure adequate shutdown in the event of a react ensure that maximum possible ejected rod reactivity limit or trip, tO s are maintained and to ensure. acceptable core power distributions.

js5 Before withdrawing any rod bank from the fully inserted position, the; grou Y p step counters and the rod pésition indicators for that bank must be at zero steps.

RPls and step counters shall be maintained within limits per TS 3.1.3.1 and 3.1.3.2.

The Control Rods shall NOT be stepped. or tripped unless the RCS pressure is at least 100 psig. This pressure eqsures the CRDM housing is filled..

& Rod moverrint without the.CRDM fans aligned to the Reactor Vessel shroud is fr allowed, provided that the RCS temperatures are less than 350°F.

3.0 PRECAUTIONS AND LIMITATIONS (continue d)

When RCS temperature is greater than 350°F, cont inuous rod motion shall.

comply with these restrictions:

CRDM OUTLET ROD MOTION LIMITS TEMPERATURE 190°F 10 minutes ON 20 minutes OFF 200°F 6 minutes ON 24 minutes OFF Time limitations are clue to a lower air flow rate of 48,0 combined with a highertemperature (Reference 00 cfm acrossthe shroud TSIR-97-BOP-30-636 and Westinghouse Letters RIMs #638931005806, 6389 30920800, and 638931005803).

(lJ The following failures will render the rod control system 7 and 1 or manual motion without any annunciation or indicincap ation:

able of automatic

1) Hand switch failure; 2) relay failure, and 3) failu re of both 1 OOv DC power supplies (PS3 and PS6) simultaneously.

Defeating or restoring Tavg/Delta T or NIS channel may cause step* chang* in input to rod control. A delay of at least 3 minutes prior to returning rod control to automatic will allow lead/lag sighal to. decay off.

Directional Overcurrent Relay Targets are reset by depr essing the. Relay Target Reset Pushbutton on the panel to break the target coil seal lifting the mechanical reset at the bottom of the relay in circuit and then cover.

3.0 PRECAUTlONS AND LIMITATIONS (contin ued)

US / SRO Oversight for control rod manipulation shall include:

Prior to Rod Movement

a. Ensure RPPs within T.S. range (+ or 12 steps)

b. Ensure delta flux will not be adversely affepted

c. Ensure Tavg and Rx Thermal power will not be adve rsely affected

d. Verify on target with Rx Eng reactivity balance sheet

e. Verify power change will not exceed hourly rate

f. Ensure no simultaneous reactivity manipulations In progress (i.e.: borations, dilutions or turbine load changes)

During Rod Movement

a. EnsureRO has. peer check

b. Ensure RO is following procedure Ensure RO understands how many steps they are moving rods

.d. Ensure RO has checked all the above mentioned items

e. Watch performance of rod manipulation while listening to audible indication of rod step

f. Ensure peer check is doing their job

g. Re-verify steps a d of initial evaluation h, Ensure. proóedure isfollowed placing rods back tO. auto (Tavg Tref mismatch)

i. Monitor plant for expected response

Unit____

Date l4 4.0 PREREQUISITE ACTIONS Throughout this instruction where an IFITHEN statemen t occurs, the step may be NIA if the condition does NOT exist, ENSURE the instruction to be. used is a copy of the effec thie.

version.

0 ENSURE Precautions and Limitations, Section 3.0 has reviewed been ENSURE each performerdocurnents his/her name, and initials:

Print Name Initials

& INDiCATE below which performance section of this. instr will be used and the reason for this performance:

uction D 5Q STARTUPISTANDBY READINESS 1 6.0 NORMAL OPERATION D 7.0 SHUTDOWN Q .8.0 INFREQUENT OPERATION REASON: