ML102300438

WC-2009-12-Draft Operating Test

ML102300438
Person / Time
Site:	Wolf Creek
Issue date:	08/18/2010
From:	Apger G W Operations Branch IV
To:	Wolf Creek
References
Download: ML102300438 (139)

Text

1 Appendix D Scenario Outline Form ES-D-1 Facility: __Wolf Creek

________________ Scenario No.: ___1____ Op-Test No.: _____

Examiners: ____________________________ Operators: _______________________ ____________________________ _____________________________

____________________________ _____________________________

Initial Conditions: ___

_100% power,_EOL_______________________________________

Turnover: EDG "B" out of service for Maintena nce PM's - expected back in six hours. TS 3.8.1 conditions A & B entered; STS NB-005, Breaker Alignment Verification has been completed - due in seven hours.

MDAFW pump "B" tagged out/out of service due to Emergent work (SM Concern). Expected return is six hours. TS 3.7.5 condition B entered.

Event No. Malf. No. Event Type* Event Description 1 t+2 mBB22 A I -- ATC, SRO PZR level channel BB LI-459A failure high. OFN SB-008, Instrument Malfunctions, Attachment J 2 t+8 bkrDPA D01A R - ATC

C -

BOP, SRO Condensate pump "A" trip

OFN AF-025, Unit Limitations, Attachment A OFN MA-038, Rapid Plant Shutdown 3 t+25 mSG01 mSF15A mSF15B M - All Seismic event followed by a Reactor trip occurs. EMG E-0, Reactor Trip or Safety Injection This event series sets up the scenario for the Major event EMG FR-H1, Response to Loss of Secondary Heat Sink.

2 4 t+25 mNB01 mNB02 (Post Reactor trip) NB01 & NB02 trip mNE02 A C -- ATC, SRO (Post reactor trip) EDG "A" au tostart feature disabled - manual available

(CT - start EDG "A" in order to energize NB01 bus)

Recall NB02 bus unavailable because EDG "B" out of service

as part of Turnover item.

5 t+25 mAL02 mtrDPA L01A

mBG13 A TDAFW pump trip (broken linkage)

MDAFW pump "A" trip (shaft seizure)

CCP "A" trips due to overcurrent M - All Loss of all Auxiliary Feedwater EMG FR-H1, Response to Loss of Secondary Heat Sink

(CT - Establish RCS bleed and feed before Steam Generators dr y out)* (N)ormal, (R)eactivit y , (I)nstru m ent, (C)om p onent, (M)a j o r

3 Appendix D Scenario Outline Form ES-D-1 Scenario summary:

Plant is at 100% power, End of life (EOL). Emergency Diesel Generator (EDG) "B" is tagged out/out of service for Maintenance - Preventative Maintenance (P M). Expected return is six hours. Technical Specifications (TS) 3.8.1 condition A & B entered. STS NB-005, Breaker Alignment Verification, comple te (due in seven hours).

Motor Drive Auxiliary Feedwater Pump (MDAFWP) "B" is tagged out/out of service due to Emergent work (SM Concern). Expected retu rn is six hours. T echnical Specification 3.7.5 condition B entered.

Pressurizer (PZR) controlling le vel channel BB LI-459A fails hi gh. Crew responds using OFN SB-008, Instrument Malfunctions, Attachment J. Attachment J: Select an alternate level channel as the controlling channel. Crew stabilizes the plant.

Condensate pump "A" trips. The crew responds by entering OFN AF-025, Unit Limitations. Attachment A will require a downpower evolution.

Downpower guidance per OFN AF-025: If one condensate pump is lost, reduce power as necessary to maintain Main Feed Pump (MFP) suction pressure greater than 340 psig on AEP0006 for "A" MFP and AEP0005 for "B" MFP. Crew responds by performing a downpower. Crew stabilizes the plant.

A seismic event occurs resulting in an inadvertent reactor trip. EMG E-0, Reactor Trip or Safety Injection is entered. (Major event)

Post trip, both NB01 and NB02 busses trip. Due to the Maintenance PM's (see Turnover item), Emergency Diesel Generator "B" will not start and load onto NB02 bus. The Control Room must manually start Emergency Diesel Genera tor "A" and then it will load onto NB01 bus.

As the scenario progresses, the Turbine Driven Auxiliary Feedwater Pump (TDAFWP) trips due to broken linkage and the Motor Driven Auxiliary Feedwater Pump "A" will trip due to shaft seizure and BOTH cannot be restarted. Motor Driven Auxiliary Feedwater Pump "B" cannot be started (see Turnover item). No Auxiliary Feedwater (AFW) to the Steam Generators is available. Note that the running CCP (CCP "A") trips off due to overcurrent.

The crew enters EMG FR-H1, Response to Loss of Secondary Heat Sink (Major event). Mitigation strategy: the crew uses the Fo ldout page of EMG FR-H1, Bleed and Feed.

EMG FR-H1, Response to Loss of Secondary Heat Sink, Major Actions: Attempt restoration of RCS bleed and feed flow to the S/Gs Initiation of RCS bleed and feed heat removal Restore and verify s econdary heat sink 4 Termination of RCS bleed and feed heat removal Scenario has two Critical Tasks (CT):

1. Starting the EDG "A" to re-energize NB01 bus before placing safeguards equipment in pull-to-lock or prior to any needless Orange or Red path entry conditions.

2. Establish RCS bleed and feed before Steam Ge nerators (SG) dry out establishing a heat sink for the core.

Probabilistic Risk Analysis for this scenario includes:

Top 10 Human Action Failures by the Importance Measure Rankings (Reference PSA-07-0001)

F-V Rank RRW Rank Total Rank Event Name Description Point Est. F-V RAW RRW Birnbau m 1 8 34 OPA-OD1-EXE FAILURE OF RCS COOL DOWN &

DEPRESSURIZE -

SGR EVENT - EXE 4.89E-03 2.61E-02 6.32 1.027 9.64E-052 39 OPA-OD2-EXE FAILURE OF RCS COOL DOWN &

DEPRESSURIZE AFTER OVERFIL-

EXE 5.00E-02 2.49E-02 1.47 1.026 8.97E-063 9 40 OPA-RRI1-EXE FAILURE TO ALIGN & START 1 SI OR CCP PUMP - EXE 4.68E-03 2.45E-02 6.2 1.025 9.43E-054 41 OPA-OFB-EXE FAILURE TO ESTABLISH FEED

& BLEED COOLING - EXE 2.97E-02 2.40E-02 1.78 1.025 1.46E-05

Technical Specifications exercised:

Event 1: TS 3.3.1, Reactor Trip System Instrumentation, Table 3.3.1-1 FU 9 Cond A: Required function inoperable - enter condition per Table (immediately)

Cond M: One channel inoperable - place channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />)

TS 3.3.4, Remote Shutdown Instruments, Table 3.3.4-1 FU 12 Minimum channels met - no action required

TS 3.3.3. Accident Monitoring Instrumentation, Table 3.3.3-1, FU 11 Minimum channels met - no action required

5 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 1 Page 5 of 29 Event

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Description:==

PZR level channel BB LI-459 failure high BOOTH INSTRUCTIONS: Set up simulator in IC 49, RBU at 229, CWP enabled, Blue placard on "B" CCP. Run files etc.

When directed, INITIATE Event 1 by activating KEY 1.

INDICATIONS: Meter BB LI-459 indication high Main Control Board alarms:

00-032D, PZR HI LEV DEV HTRS ON

00-083C, RX PARTIAL TRIP Bistable PZR HI WTR LEV LB459A Time Position Applicant's Actions or Behavior CREW Respond to Main Control Board (MCB) alarms and board indications.

Actions taken prior to procedure entry may include: Identifies BB LI-459 failure, Select MANU AL on PZR LEVEL CONTROLLER (BB LK-459) CREW ENTER OFN SB-008, rev 25, Instrument Malfunctions CREW 1.Check if Secondary System instrument channel is malfunctioning. a. Determine appropriate attachment for malfunctioning channel or controller

a. RNO: If secondary system c hannel is NOT malfunctioning, then go to step 2.

6 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 1 Page 6 of 29 Event

==

Description:==

PZR level channel BB LI-459 failure high Time Position Applicant's Actions or Behavior CREW 2. Check if RCS instrument channel or controller is malfunctioning a. Determine appropriate attachment for malfunctioning channel or controller From Table determine: BB LI-459, Go to Att. J, PZR Level Channel Malfunction b. Go to appropriate attachment for malfunctioning RCS channel or controller CRS ENTER Attachment J, PZR Level Channel Malfunction RO J1. Identify failed instrument channel a. Compare Pressurizer level indi cations to confirm a Pressurizer level channel failure:

o BB LI-459A RO J2. Check failed Pressurizer le vel channel selected on PZR level control Selector switch.

o BB LS-459D RO J3. Select alternate Pressurizer level channel for level control.

o BB LS-459D switch Selection options: L461/L460 or L459/L460 or L459/L461

RO should select L461/L460

7 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 1 Page 7 of 29 Event

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Description:==

PZR level channel BB LI-459 failure high Time Position Applicant's Actions or Behavior NOTE Letdown flow is isolated and Pressurizer control heaters are deenergized if the controlling level falls below 17%. Both must be manually r ealigned once level control is re-established. RO J4. Check letdown flow - ESTABLISHED RO J5. Manually control charging a nd letdown to stabilize Pressurizer level at level appropria te for plant power. RO J6. Ensure PZR control heaters - ON RO J7. Place charging/letdown flow control in automatic RO J8. Monitor PZR level res ponse to ensure proper control CRS J9. Check failed PZR level channel - NOT USED FOR RECORDER 8 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 1 Page 8 of 29 Event

==

Description:==

PZR level channel BB LI-459 failure high Time Position Applicant's Actions or Behavior CRS J10. Monitor the following T echnical Specification LCO's and comply with Action Statements as appropriate:

TS 3.3.1, Reactor Trip System Instrumentation, Table 3.3.1-1 FU 9 Cond A: Required function inoperable - enter condition per Table (immediately)

Cond M: One channel inoperable -

place channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />) (FYI: TS 3.3.4, Remote Shutdown Instruments, Table 3.3.4-1 FU 12; Minimum channels me t - no action required TS 3.3.3. Accident Monitoring Instrumentation, Table 3.3.3-1, FU 11; Minimum channels met - no action required) Lead Examiner may direct in itiation of the next event at his discretion

9 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 9 of 29 Event

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Description:==

Condensate pump "A" trip.

BOOTH INSTRUCTIONS: When directed, INITIATE Event 2 by activating KEY 2.

INDICATIONS: AD HIS-1, CNDS Pump A, light indication change from RED to GREEN and AMBER (pump stopped / tripped)

AD FIK-7B, CNDS Pump A Recirc CTRL, from AUTO to MAN (0 % output to 100% output)AD ZL-7B, CNDS Pump A Recirc Valve, light indication from GREEN to RED AD PI-25, CNDS Pumps Disch Press, indicates decr easing pressure

Main Control Board alarms: ALR 00-107C, CNDS PMP SUCT STR P HI ALRs 00-120B / 123B, MFP A/B SUCT PRESS LO Time Position Applicant's Actions or Behavior CREW Responds to MCB alarms and board indications. Identify "A" Condensate pump is tripped. CREW ENTER OFN AF-025, rev 28, Unit Limitations CRS 1.Determine applicable step: a. Check Stator Cooling Water System - NORMAL

b. Check Generator Hydrogen System - NORMAL

c. Check Main Transformers - NORMAL

d. Check all the following transformers - NORMAL o Start-up transformer o XNB01 transformer o XNB02 transformer o Unit Auxiliary transformer e. Check Condenser Vacuum - NORMAL

f. Go to step 7.

10 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 10 of 29 Event

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Description:==

Condensate pump "A" trip Time Position Applicant's Actions or Behavior CRS 7. Check Westar Transmission Services (WETS) has reported an actual or predicted switchyard voltage degradation -- NO RNO: go to step 9 CRS 9. Check for conditions re quiring Unit Load reduction: a. Determine maximum unit load using Attachment A, Unit Load Limits b. Reduce unit load, as necessary, to satisfy load limits using the appropriate procedure GEN 00-004, Power Operation OR GEN 00-005, Minimum Load to Hot Standby OR OFN MA-038, Rapid Plant Shutdown OR Attachment D, Turbine/Gene rator Load Decrease using Steam Dumps CRS Attachment A, Unit Load Limits, Feed & Conde nsate section:

Condition requiring load reduction Maximum Unit Load One Condensate pump out of service see NOTE (2)

Note 2: If one condensate pump is lost, reduce power as necessary to maintain MFP suction pressure greater than 340 psig on AEP0006 for A MFP and AEP0005 for B MFP.

11 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 11 of 29 Event

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Description:==

Condensate pump "A" trip Time Position Applicant's Actions or Behavior BOOTH Cue: Call as Shift Manager or Call Superintendent to direct use of OFN MA-038, Rapid Plant Shutdown.

If contacted as System OPS Generation or System Transmission, acknowledge Wolf Creek Turbine/Generator load reduction. CREW ENTER OFN MA-038 rev 11, Rapid Plant Shutdown NOTES o Foldout page shall be monito red throughout this procedure.

o Steps 1-4 may be performed in any order.

o Load reduction at greater than 5% / minute will arm condenser steam dumps.

o When reducing load with Decrease Loading Rate on, the difference between load set and actual load should be less than 200MW. Prior to depressing the Hold or Off pushbuttons or establishing Load Limit control, ensure the At Set Load light is on to prevent an uncontrolled load decrease.

12 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 12 of 29 Event

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Description:==

Condensate pump "A" trip Time Position Applicant's Actions or Behavior CRS/BOP 1. () Reduce turbine load

a. Check desired unloading rate - 5% / minute

b. Place control valves in their operating range as necessary by slowly decreasing load limit pot until a 1-2 MWe load decrease is noted

c. Slowly decrease Load Set MW until AT SET LOAD light is on and LOAD LIMIT LIMITING light extinguishes

d. Raise Load Limit pot slightly

e. Set Loading/Unloading Rate Limit to desired value and adjust as necessary during decrease to maintain desired rate f. Select Decrease Loading Rate - ON

g. Decrease Load Set MW toward desired load

h. Continue with this procedure while reducing turbine load BOOTH Cue: If called as Work Week Manager (WWM), ac knowledge request to re pair "A" Condensate Pump & will form a team for the repairs. If asked, repairs shouldn't take more than a few hours. CRS/RO 2. () Borate RCS and adjust control rods as necessary to maintain the following:

o Target Tavg/Tref temperature error between 0 F and +5 F o Control rods above the rod insertion limits 13 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 13 of 29 Event

Description:

Condensate pump "A" trip -

RO actions to Borate (Operator Aid)

Time Position Applicant's Actions or Behavior RO SYS BG-200 rev 35, Attachment B, Boration for Temperature Adjustment in Mode 1 and 2 NOTE A licensed operator shall peer check reactivity manipulations.

B.1 Setup to borate the RCS:

B.1.1 () Turn on PZR HTR B/U GROUP A & B, as directed by CRS, to mix Reactor Coolant System with Pressurizer water BB HIS-51A for group A - ON BB HIS-52A for group B - ON

B.1.2 BG HS-26 to Normal-After-Stop B.1.3 BG HS-25 to Borate B.1.4 BG FK-110 in Auto at desired rate B.1.5 BG FY-110B, BA counter, set to desired gallons

B.2 Commence Boration B.2.1 BG HS-26 to Normal-After-Run B.2.2. Verify:

1. One BORIC ACID TRANSFER PUMP running

2. BG HIS-110B open

3. BG HIS-110A throttles open

4. BG FR-110 red pen at proper flowrate

B.3 Ensure boration stops at BG FY-110B setpoint NOTE Pressurizer Backup Heaters are normally placed in auto.

B.4 As directed by CRS, place PZR HTR B/U GROUP A & B in desired position after sufficient time for mixing as elapsed.

o BB HIS-51A for group A - ___________________

o BB HIS-51B for group B - ___________________

B.5 Realign for auto operation:

B.5.1 BG HS-26 to Normal-After-Stop B.5.2 BG HS-25 to Auto B.5.3 BG FK-110 set for Auto makeup B.5.4 BG HS-26 to Normal-After-Run B.5.5 If desired, then perform Attach ment C, Boric Acid Potentiometer Adjustment 14 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 14 of 29 Event

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Description:==

Condensate pump "A" trip (OFN MA-038 procedure steps continued)

Time Position Applicant's Actions or Behavior RO 3. Energize PZR backup heaters o BB HIS-51A o BB HIS-52A BOP 4. () Check AE HV Open o AE HIS-38 CLOSED RO 5. Check PZR PORVs:

a. RCS pressure - 2335 psig

b. PZR PORVs - CLOSED

c. RCS pressure - 2185 psig

d. PORV block valves - OPEN RO 6. Check PZR pressure - stable at or trending to 2235 psig RO 7. Check PZR level - stable at or trending to program level BOP 8. Check SG levels - controlling between 45% and 55%

15 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 15 of 29 Event

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Description:==

Condensate pump "A" trip Time Position Applicant's Actions or Behavior CRS 9. Check reactor power - less than 60% -- NO, perform RNO RNO: a. If final desired power level is greater than or equal to 60% then go to step 35

b. If final desired power level is less than 60% then do not continue until reactor power is less than 60%

Lead Examiner may direct in itiation of the next event at his discretion.

16 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 3 Page 16 of 29 Event

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Description:==

Seismic ev ent and reactor trip BOOTH INSTRUCTIONS: When directed, INITIATE Event 3 by activating KEY 3, inserting seismic event and inadvertent reactor trip.

INDICATIONS: Main Control Board alarms:

98D, OBE 98B, SSE Reactor trip occurs - DRPI indicates all rods on bottom, MCB alarms annunciate Time Position Applicant's Actions or Behavior CREW Respond to MCB indications. CRS ENTER and Direct OFN SG-003 rev 16, Natural Events. CRS 1. Determine appropriate attachment for Natural Event: Attachment A, Earthquake Response CRS 2. Go to appropriate attachment CRS Directs Attachment A, Earthquake Response BOOTH Cue:

Report as Security that an Earthquake has been felt.

CRS A1. Check EQ magnitude - GREAT ENOUGH TO START SEISMIC RECORDER CRS/CREW A2. Stabilize Plant Conditions 17 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 3 Page 17 of 29 Event

Description:

Seismic ev ent and reactor trip Time Position Applicant's Actions or Behavior CREW ENTER EMG E-0, rev 22, Reactor trip or Safety Injection FOLDOUT PAGE FOR EMG E-0 1. RCP TRIP CRITERIA IF all conditions listed below occur, THEN trip all RCPs:

o RCS pressure - LESS THAN 1400 PSIG o CCPs or SI pumps - AT LEAST ONE RUNNING o Operator controlled cooldown - NOT IN PROGRESS 2. SI ACTUATION CRITERIA IF either condition listed below occurs, THEN actuate SI and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION, Step 1: RCS subcooling - LESS THAN 30°F [45°F]

OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6% [33%] 3. FAULTED S/G ISOLATION CRITERIA IF any S/G pressure decreasing in an uncontrolled manner OR any S/G completely depressurized, THEN the following may be performed:

a. Close main steam isolation valves.

b. Isolate feed flow to faulted S/G(s).

c. Maintain total feed flow greater than 270,000 lbm/hr until narrow range level in at least one S/G is greater than 6% [29%].

4. RUPTURED S/G ISOLATION CRITERIA IF any S/G level increases in an uncontrolled manner OR any S/G has abnormal radiation, AND narrow range level in affected S/G(s) is greater than 6% [29%], THEN the following may be performed.

a. Close ruptured S/G AFW flow control valves.

b. IF any ruptured S/G AFW flow control valve cannot be closed AND total AFW flow to intact S/Gs can be maintained greater than 270,000 lbm/hr without associated AFW Pump, THEN perform the following:

1) Stop associated MD AFWP and place in PTL OR decrease TDAFWP speed to 2000 rpm.

2) Dispatch an Operator to locally isolate affected AFW flow control valve.

3) WHEN affected AFW flow control valve is isolated, THEN restart MD AFWP OR Restore TD AFWP speed as necessary. 5. COLD LEG RECIRCULATION CRITERIA IF RWST level decreases to less than 36%, THEN go to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION, Step 1. 6. AFW SUPPLY SWITCHOVER CRITERIA IF CST suction pressure decreases to less than 2.6 psig, THEN switch to alternate AFW suction supply. CAUTION: Accident conditions can cause higher than normal radiation levels. Health Physics monitoring may be required while performing local operator actions. NOTES o Steps 1 through 4 are immediate action steps.

o Foldout page shall be monitored throughout this procedure.

18 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 18 of 29 Event

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Description:==

NB01 & NB02 trip. EDG A autostart feature disabled - manual start available.

Time Position Applicant's Actions or Behavior BOOTH INSTRUCTIONS

Event 4 is preloaded (EDG A autostart feature disabled). INDICATIONS: Various MCB alarms No WHITE light LIT, NB ZL-5, 4.16 KV bus NB01 No WHITE light LIT, NB ZL-6, 4.16 KV bus NB02 CRS ENTER EMG E-0, rev 22, Reactor Trip or Safety Injection RO 1. Verify Rx trip. a. Check all rod bottom lights lit

b. Ensure reactor trip break ers and bypass breakers open

c. Check neutron flux decreasing BOP 2. Verify turbine trip.

a. Check the following: Main Stop valves - all closed OR Turbine auto stop bistable light - at least two lit RO 3. Check AC emergency busses - at least one energized; NO , perform RNO NB01 voltage- normal NB02 voltage - normal

19 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 19 of 29 Event

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Description:==

NB01 & NB02 trip. EDG A autostart feature disabled - manual start available.

Time Position Applicant's Actions or Behavior NB01 & NB02 trip. EDG A autostart feature disabled - manual start available Recall: NB02 bus unavailable because EDG "B" out of service as part of Turnover item RO 3.RNO Perform the following

(CT) CT: Starting the EDG "A" to re-energize NB01 bus before placing safeguards equipment in pull-to-lock or prior to any needless Orange or Red path entry conditions.

Success: Start EDG A using KJ HS-8A

a. Depress the Start/reset pushbut ton for any stopped Diesel Generator o KJ HS-8A for EDG A o KJ HS-108A for EDG B

b. If at least one AC emergency bus is now energized, then go to step

4. c. Direct operator to monito r Critical Safety Functions for information only using EMG F-0, Critical Safety Function Status Trees (CSFST).

d. Go to EMG C-0, Loss of all AC Power, step 1 NOTE: Bus NB01 is energized by the EDG "A" once the Control Room starts the EDG.

20 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 3, 4 Page 20 of 29 Event

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Description:==

Seismic event, Reactor trip, EDG A autostart feature disabled (started From Control Room)

Time Position Applicant's Actions or Behavior RO 4. Check if Safety Injection is actuated:

a. Check any indication SI is actuated - lit Ann. 00-030A/00-0031A, NF039A/B LOCA SEQ ACTUATED - lit OR ESFAS status panel SIS section - any white lights lit OR Partial trip status Permissive

/ Block status panel - SI red light lit

b. Check both trains of SI actuated o Ann. 00-030A/00-031A, NF 039A/B LOCA SEQ ACTUATED - lit RNO Perform the following:

1. Check SI required: RCS pressure 1830 psig OR Any SG 615 psig OR CTMT pressure 3.5 psig OR RCS subcooling 30 F OR PZR level 6%

21 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.:3, 4 Page 21 of 29 Event

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Description:==

Seismic/reactor trip event continued Time Position Applicant's Actions or Behavior RO RNO 4 cont.

2. If SI is required, then manually actuate SI and go to step 6.

3. If SI is not required, then perform the following:

a. Direct operator to monitor CSF using EMG F-0, Critical Safety Function Status Trees.

b. Go to EMG ES-02, Reactor Trip Response, step 1 Examiner Note: If an SI occurred, the Crew will continue, if No SI occurs, the Crew may transition to EMG ES-02 then transition to EMG FR-H1, Response to Loss of Secondary Heat Sink.

22 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 5 Page 22 of 29 Event

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Description:==

Loss of all Auxiliary Feedwater TDAFW pump trip (broken linkage), MDAFW pump "A" trip (shaft seizure) and CCP "A" pump trip.

Time Position Applicant's Actions or Behavior BOOTH INSTRUCTIONS: Event 5 failures are preloaded BOOTH Cue:

If contacted as Building watches to investigate pump trips, respond: I will investigate.

INDICATIONS: Main Control Board alarms:

00-128A, AFP DISCH PRESS LO; 00-128E, TDAFP SPD HILO; 00-129A, MDAFP A TROUBLE; 00-042E, C HARGING PMP TROUBLE CRS ENTER and Direct EMG FR-H1, rev 20, Response to Loss of Secondary Heat Sink CAUTIONS o If total feed flow is less than 270,000 lbm/

hr due to operator action, this procedure shall not be performed.

o If a non-faulted S/G is available, feed flow shall not be reestab lished to any faulted S/G. NOTE: Foldout page shall be monitored throughout this procedure.

23 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 5 Page 23 of 29 Event

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Description:==

Loss of all Auxiliary Feedwater TDAFW pump trip (broken linkage), MDAFW pump "A" trip (shaft seizure) and CCP "A" pump trip.

Time Position Applicant's Actions or Behavior FOLDOUT PAGE FOR EMG F R-H11. BLEED AND FEED CRITERIA IF RCS bleed and feed has NOT been establis hed AND RCS pressure is greater than any non-faulted S/G pressure AND any condition list ed below occurs, THEN OBSERVE CAUTION PRIOR TO STEP 29 and go to Step 29. Wide range level in any 3 S/Gs - LESS THAN 26% [47%] OR RCS pressure - GREATER THAN 2335 PSIG DUE TO LOSS OF SECONDARY HEAT SINK OR CCPs - NONE AVAILABLE

2. COLD LEG RECIRCULATION CRITERIA IF RWST level decreases to less than 36%, THEN go to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION, Step 1.

3. AFW SUPPLY SWITCHOVER CRITERIA IF CST suction pressure decreases to less th an 2.6 psig, THEN switch to alternate AFW suction su pp l y. Examiner Note

Crew diagnoses No CCPs ava ilable and goes to step 29.

24 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 5 Page 24 of 29 Event

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Description:==

Loss of Auxiliary Feedwater (AFW)

Time Position Applicant's Actions or Behavior BOOTH Cue: If dispatched to investigate CCP "A pump trip, report: I will investigate.

If dispatched to CCP pump breaker, re port an Overcurrent flag is dropped.

CRS 1. Check if Secondary heat sink is required

a. RCS pressure - any non-faulted S/G pressure b. RCS hot leg temp - 350 F CREW 2. Verify RCS Bleed and Feed - not required a. Check WR level in all S/Gs - 26% [47%]

b. Check RCS press - 2335 psig RO 3. Check CCP status - at least one available (NO, perform RNO) RNO: Observe CAUTION prior to step 29 and go to step 29

25 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 5 Page 25 of 29 Event

Description:

Loss of Auxiliary Feedwater.

Time Position Applicant's Actions or Behavior CAUTION: Steps 29 through 33 must be performed quickly in order to establish heat removal by RCS bleed and feed.

CT: Establish RCS bleed and feed before Steam Generators dry out establishing a heat sink for the core.

Success: SI actuated a nd PORV Block valves OPEN RO 29. Reduce heat input to RCS

a. Stop all RCPs o BB HIS-37 for RCP A o BB HIS-38 for RCP B o BB HIS-39 for RCP C o BB HIS-40 for RCP D b. Turn off all PZR heaters o BB HIS-50 o BB HIS-51A o BB HIS-52A RO 30. Actuate SI (CT - see above) o SB HS-27 o SB HS-28 26 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 5 Page 26 of 29 Event

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Description:==

Loss of Auxiliary Feedwater

Time Position Applicant's Actions or Behavior CRS 31. Verify ECCS feed path

a. Check high pressure ECCS pumps CCPs - at least one running OR SI pumps - at least one running b. Verify SI feed path alignment: Check CCP to BIT flow mete rs - flow indicated OR o EM FI-917A o EM FI-917B Check SI pump discharge flow me ters - flow indicated OR o EM FI-918 o EM FI-922 Check ESFAS status SIS section - System level white lights all lit o Red train o Yellow train

27 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 5 Page 27 of 29 Event

Description:

Loss of Auxiliary Feedwater Time Position Applicant's Actions or Behavior CREW 32. Establish RCS bleed path: a. Check power to block valves - AVAILABLE o BB HIS-8000A o BB HIS-8000B b. Place both cold overpressure Block/Arm switch in ARM position o BB HS-8000A o BB HS-8000B

c. Check PZR PORV block valves - BOTH OPEN (CT - see page

27) RNO: OPEN both block valves O BB HIS-8000A O BB HIS-8000B

d. Open both PZR PORVs o BB HIS-455A o BB HIS-456A CREW 33. Verify adequate RCS bleed path:

o PZR PORV block valves - both open o PZR PORV's - both open CRS 34. Perform steps 1-7 of EMG E-0, Reactor Trip or Safety Injection, while continuing with this procedure.

28 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 5 Page 28 of 29 Event

==

Description:==

Loss of Auxiliary Feedwater Time Position Applicant's Actions or Behavior CRS 35. Maintain RCS heat removal:

o Maintain ECCS flow to RCS o Maintain PZR PORVs - Both OPEN CAUTION: If offsite power is lost after SI reset, manual action may be required to restore safeguards equipment to the required configuration. RO 36. Reset SI o SB HS-42A o SB HS-43A RO 37. Reset Containment Isolation Phase A and Phase B o SB HS-56 for phase A o SB HS-53 for phase A o SB HS-55 for phase B o SB HS-52 for phase B BOP 38. Establish Instrument Air to Containment

29 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 5 Page 29 of 29 Event

Description:

Loss of Auxiliary Feedwater Time Position Applicant's Actions or Behavior CRS 39. Continue attempts to estab lish Secondary heat sink in at least one SG When Bleed and Feed is established, Lead Examiner may terminate scenario at his discretion.

1 Appendix D Scenario Outline Form ES-D-1 Facility: __Wolf Creek

________________ Scenario No.: ___2____ Op-Test No.: _____

Examiners: ____________________________ Operators: ________________________ ____________________________ _____________________________

____________________________ _____________________________

Initial Conditions: 65% power

Turnover: Load reduction in progress per GEN 00-004, Power Operations, section 6.2, in order to remove "A" Main Feed pump from serv ice due to high vibration. Main Feed Pump "A" is not expected to be out of service very long.

Use SYS AE-320, Turbine Driven Main Feedwater Pump Shutdown.

Event No. Malf. No. Event Type* Event Description 1 t+1 R - ATC N - BOP, SRO Reduce power using GEN 00-004, Power Operations and remove "A" Main Feed Pump from service using SYS AE-

320, Turbine Driven Main Feedwater Pump Shutdown (crew may reference / enter OFN AF-025, Unit Limitations, also) 2 t+15 mBB01 D I - ATC, SRO Primary Loop D Thavg (BB TI-441) high failure

OFN SB-008, Instrument Malfunctions, Attachment L 3 t+20 mAE15 C4 I - BOP, SRO S/G C level AE LI-553 failure high OFN SB-008, Instrument Malfunctions, Attachment F ALR 00-110C, SG C Flow Mismatch

ALR 00-110B, SG C Lev Dev ALR 00-110A, SG C Lev Hi/Lo

2 4 t+27 mBG13 C C - ATC, SRO Normal Charging Pump (NCP) trip; a Centrifugal Charging Pump must be started, letdown restored etc

ALR 00-042A, Charging Line Flow HiLo (SYS BG-120, CVCS Startup or SYS BG-201, Shifting Charging Pumps - either may be used to restore letdown)

ALR 00-042E, Charging Pump Trouble (Step 7 re-establishes letdown) 5 t+35 mBB02 B M - All 500 gpm Steam Genera tor Tube Rupture on S/G A OFN BB-07A, Steam Generator Tube Leakage (eventually EMG E-0, Reactor Trip or Safety Injection & EMG E-3, Steam Generator Tube Rupture) 5 EMG E-3, Steam Generator Tube Rupture actions: CT - Isolate feed flow to the ruptured SG before Steam Generator overfills.

CT - Cooldown & Depressurize RCS to minimize RCS inventory leakage into the ruptured Steam Generator.

6 t+43 mSA27 EM01 and mSA27 EM02 C - ATC, SRO Post trip: BIT outlet valves (EM HIS-8801A and EM HIS-8801B) do not open. Manual open available

CT - Open BIT outlet valves (EM HIS-8801A and EM HIS-8801B) before the end of the scenario or before

needless Red or Orange path occurs.

EMG E-0, Reactor Trip or Safety Injection, Attachment F or allowed post Immediate Action completion

• (N)ormal, (R)eactivit y , (I)nstrument, (C)om p onent, (M)a j o r

3 Appendix D Scenario Outline Form ES-D-1 Scenario summary Plant is at 65% power with a lo ad reduction in progress to remove "A" Main Feed Pump (MFP) from service due to high vibration. GEN 00-004, Power Operations, section 6.2 in progress for load reduction. Crew will use SYS AE-320, Turbine Driven Main Feedwater Pump Shutdown, to remove "A" MFP from service.

Crew reduces power per GEN 00-004, Power Oper ations, section 6.2, Power Decrease. Crew may reference OFN AF-025, Unit Limitations, Attachment A (one main feedwater pump from

service requires plant at 62%

power). Crew removes "A" MFP from service using SYS AE-320, Turbine Driven Main Feedwater Pump S hutdown (see step 6.2.12 of GEN 00-004). Crew stabilizes unit at lower power and removes pump from service.

Primary Loop D Thavg failure high - BB TI-441 fails high. Control rods begin to step inward.

Crew responds by placing rods into manual control and performing OFN SB-008, Instrument Malfunctions. OFN SB-008, Instrument Malfunctions, Attachment L. Crew stabilizes the plant.

Steam Generator (S/G) C level channel AE LI-553 failure high. Crew responds by performing OFN SB-008, Instrument Malfunctions, Attachment F.

An alternate level channel is selected for control. ALR 00-110A, SG C Lev Hi/Lo, may be used prior to entry of OFN SB-008, Instrument Malfunctions. Crew stabilizes the plant.

Normal Charging Pump (NCP) trip. Crew re sponds using ALR guidance. A Centrifugal Charging Pump is started. Normal letdown must be restored. ALR 00-042A, Charging Line Flow HiLo ALR 00-042E, Charging Pump Trouble Crew stabilizes the plant.

Major event: A 500 gpm Steam Generator Tube Rupture (SGTR) on S/G A is diagnosed per OFN BB-07A, Steam Generator Tube Leakage.

SGTR requiring a manual Reactor trip and Safety Injection Signal actuation per Foldout page criteria of OFN BB-07A. Mitigation procedure will be EMG E-3, Steam Generator Tube Rupture. 1. Crew responds using OFN BB-07A, Steam Generator Tube Leakage.

2. Crew responds using EMG E-0, Reactor Trip or Safety Injection.

3. Crew responds using EMG E-3, St eam Generator Tube Rupture.

4 EMG E-3, Steam Generator Tube Rupture, Major Actions: Identify and isolate ruptured S/Gs Cooldown and establish RCS subcooling margin Depressurize RCS to restore inventory Terminate SI to stop primary to secondary leakage Prepare for cooldown to cold shutdown

Scenario has three Critical Tasks (CT):

1. Open BIT outlet valves (EM HIS-8801A a nd EM HIS-8801B) before the end of the scenario or before needless Red or Orange path occurs.

2. Isolate feed flow to ruptured Steam Generator before Steam Generator overfills.

3. Cooldown & Depressurize RCS to minimize RC S inventory leakage into the ruptured Steam Generator.

Probabilistic Risk Analysis for this scenario includes:

Top 10 Human Action Failures by the Importance Measure Rankings F-V Rank RRW Rank Total Rank Event Name Description Point Est.F-V RAWRRWBirnbaum1 8 34 OPA-OD1-EXE FAILURE OF RCS COOL DOWN & DEPRESSURIZE -

SGR EVENT - EXE 4.89E-03 2.61E-02 6.32 1.0279.64E-05 Core Damage Frequency by Initiating Event and by Event Tree Event Tree Core Damage Frequency (/yr)

Percent Contribution Station Blackout 6.46E-06 35.79% Small LOCA 5.35E-06 29.65% Interfacing Systems LOCA 1.93E-06 10.68% Very Small LOCA 1.27E-06 7.05% Steam Generator Tube Rupture 8.77E-07 4.86%

Technical Specifications exercised:

Event 2 TS 3.3.1, Reactor Trip System Instrumentation, Table 3.3.1-1, FU 6 and 7

Cond. A: Function / channel inoperable - enter conditi on per table (immediately)

Cond. E: One channel inoperable - place channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />)

Event 3 TS 3.3.1, Reactor Trip System Instrumentation, Table 3.3.1-1, FU 14 Cond A: Function / channel inoperable - enter condition per table (immediately) Cond E: One channel inoperable - place channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />)

TS 3.3.2, Engineered Safety Features Actuation System Instrumentation, Table 3.3.2-1, FU 5c and 6d Cond A: Function / channel inoperable - enter condition per table (immediately)

Cond D: One channel inoperable - place channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />) 5 Cond I: One channel inoperable - place channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />)

NOTE: Event 4 TR 3.1.9, Boron Injection System - Operating -- may be looked at 6 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _1____ Page 6 of 57 Event

Description:

Reduce power using GEN 00-004, Power Operations and remove "A" Main Feed Pump from service using SYS AE-320, Turbine Driven Main Feedwater Pump Shutdown Time Position Applicant's Actions or Behavior CREW Using Gen 00-004, rev 61, Power Operations, section 6.2.2.2, continue power reduction.

Examiner Note: These steps have already been performed, the crew may review them to ensure completeness and begin at 6.2.12.2 BOP 6.2.2.2 If MTC is negative or zero, then perform the following:

a. If automatic Turbine unloadi ng is desired, then control turbine load using automatic turbine-generator unloading selected to 1/2% per minute OR as directed by SM/CRS.

b. If automatic Turbine unloading is NOT desired, then perform Turbine load decrease using load limit potentiometer or the standby potentiometer in a slow controlled manner.

c. () Adjust control rods as necessary to maintain Tavg within 1.5 F of Tref. CRS/RO 6.2.3 () During power reduction, use boration, dilution, or control rods, as necessary, to maintain the axial flux difference within the target band and control rods above the rod insertion limit. RO uses Operator Aid for Boration - see next page. CRS/RO 6.2.4 Ensure AE HV-38, HP FW HEATERS BYPASS VALVE, is closed using SYS AE-125, HP FW HEATER BYPASS THROTTLING OPERATIONS. CRS/RO 6.2.5 Ensure one set of PZ R backup heaters is energized.

7 NOTE: 6.2.6 is N/A. Crew determines which method to use for Turbine unloading. Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _1____ Page 7 of 57 Event

Description:

RO actions for Bora tion using Operator Ai d, SYS BG-200, rev 35, Attachment B, Boration for Temperature Adjustment in Mode 1 and 2 Time Position Applicant's Actions or Behavior

8 RO NOTE A licensed operator shall peer check reactivity manipulations.

B.1 Setup to borate the RCS:

B.1.1 () Turn on PZR HTR B/U GROUP A & B, as directed by CRS, to mix Reactor Coolant System with Pressurizer water BB HIS-51A for group A - ON BB HIS-52A for group B - ON

B.1.2 BG HS-26 to Normal-After-Stop B.1.3 BG HS-25 to Borate B.1.4 BG FK-110 in Auto at desired rate B.1.5 BG FY-110B, BA counter, set to desired gallons

B.2 Commence Boration B.2.1 BG HS-26 to Normal-After-Run B.2.2. Verify:

1. One BORIC ACID TRANSFER PUMP running

2. BG HIS-110B open

3. BG HIS-110A throttles open

4. BG FR-110 red pen at proper flowrate

B.3 Ensure boration stops at BG FY-110B setpoint NOTE Pressurizer Backup Heaters are normally placed in auto.

B.4 As directed by CRS, place PZR HTR B/U GROUP A & B in desired position after sufficient time for mixing as elapsed.

o BB HIS-51A for group A - ___________________

o BB HIS-51B for group B - ___________________

B.5 Realign for auto operation:

B.5.1 BG HS-26 to Normal-After-Stop B.5.2 BG HS-25 to Auto B.5.3 BG FK-110 set for Auto makeup B.5.4 BG HS-26 to Normal-After-Run B.5.5 If desired, then perform Attach ment C, Boric Acid Potentiometer Adjustment

9 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _1____ Page 8 of 57 Event

Description:

Reduce power using GEN 00-004, Power Operations and remove "A" Main Feed Pump from service using SYS AE-320, Turbine Driven Main Feedwater Pump Shutdown Time Position Applicant's Actions or Behavior CRS/BOP 6.2.7 If automatic Turbine unloading is desired, then place EHC control on load set as follows:

1. () If desired to position Control Valves in their controlling range, then slowly decrease load limit pot until a 1-2 MWe load decrease is noted.

2. Slowly decrease load set MW until the following conditions are met:

o At set load light - LIT AND o Load limit limiting light - NOT LIT

3. Raise load limit pot slightly.

4. Select 1/2% / minute loading rate.

5. Select decrease loading rate - ON CRS/BOP 6.2.8 () Decrease Turbine load as desired while continuing with this procedure CRS 6.2.9 Ensure Chemistry is promptly notified of each power change that is greater than or equal to 15% RTP within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period so that RCS DEI can be verified to satisfy SR 3.4.16.2. CRS 6.2.10 When SM or CRS desires to stop one heater drain pump, THEN stop one heater dr ain pump using SYS AF-121, HEATER DRAIN PUMP OPERATION.

NA - not desired to remove a Heater Drain Tank pump.

CRS 6.2.11 If operating with a positive MTC and reactor power is less than 65%, then open Steam Dumps as follows:

NA - operating with a negative MTC

10 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _1____ Page 9 of 57 Event

Description:

Reduce power using GEN 00-004, Power Operations and remove "A" Main Feed Pump from service using SYS AE-320, Turbine Driven Main Feedwater Pump Shutdown Time Position Applicant's Actions or Behavior Examiner Note: Unit Limitations OFN allows one MFP to be secured at 62 % power. Turnover item: continue power reduction in order to remove the Main Feed Pump. CRS 6.2.12.2. If two Main Feedwater Pumps are running, then secure one using SYS AE-320, Turbine Driven Main feedwater Pump

Shutdown CRS/CREW Direct SYS AE-320, (rev 21), Turbine Driven Main feedwater Pump Shutdown, section 6.1 CAUTION: If a secondary cooldown is in progre ss, ensure a flowpath for feed to SGs can be maintained.

NOTE: At 62% power, two MFPs at 4400 rpm will equate to one MFP at 5400 rpm. BOP 6.1.1 Place MFP turb A speed control in manual.

o FC SK-509B - MANUAL CAUTION: Monitor feedwater flow and SG levels, during performance of the following steps. BOP 6.1.2 Place MFP A recirc ctrl valve in manual and open o AE FIC-2B - MANUAL AND o AE FIC-2B - OPEN

11 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: ___1__ Page 10 of 57 Event

Description:

Remove "A" Main Feed Pump from service using SYS AE-320, Turbine Driven Main Feedwater Pump Shutdown

Time Position Applicant's Actions or Behavior BOP 6.1.3 Slowly decrease MFP tu rb A speed ctrl to 3800 rpm o FC SK-509C - OUTPUT DECREASED o FC SI 3800 rpm BOP 6.1.4 Adjust MFP turb A man speed ctrl pot, to achieve a zero indication on MFP Turb A man/auto sig match indicator o FC HK SETTING ADJUSTED o FC EI ZERO BOP 6.1.5 Depress MFP turb A speed ctrl transfer switch manual pushbutton o FC HIS manual BOP 6.1.6 Slowly decrease MFP turb A man speed ctrl pot to 1100 rpm o FC HK SETTING DECREASED o FC SI 1100 rpm NOTE: ESFAS should not be blocked, unless both Main feedwater pumps are being secured.

12 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _1____ Page 11 of 57 Event

Description:

Remove "A" Main Feed Pump from service using SYS AE-320, Turbine Driven Main Feedwater Pump Shutdown

Time Position Applicant's Actions or Behavior BOP 6.1.7. To prevent a spurious AFW system actuation, ensure one of the following conditions is met: MFP turb B trip/test switch is reset o FC HIS-118 - RESET Ensure AFP ESFAS block train A & B switches are in the block position o FC HS BLOCK o FC HS BLOCK BOP 6.1.8 Depress MFP turb A trip

/reset switch trip pushbutton o FC HIS TRIPPED BOP 6.1.9 Ensure MFP A disch vlv closes o AE HIS CLOSED BOP 6.1.10 Close MFP A recirc ctrl valve o AE FIC-2B - CLOSED BOP 6.1.11 When MFP A coasts down to zero speed, then ensure MFP turb A Turn gear engage light illuminated o FC ZL-82A - LIT 13 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _1____ Page 12 of 57 Event

Description:

Remove "A" Main Feed Pump from service using SYS AE-320, Turbine Driven Main Feedwater Pump Shutdown

Time Position Applicant's Actions or Behavior BOP 6.1.12 Open the following MFP turbine A drains:

1. MFP turb A 1 st stg S/U drn vlv o FC HIS OPEN

2. MFP turb A HPSV above seat drn valve o FC HIS OPEN

3. MFP turb A HPSV below seat drn valve o FC HIS OPEN BOP 6.1.13 Open MFP A disch valve o AE HIS OPEN BOP 6.1.14 If MFP A will be shutdown for a prolonged period, then close the following valves, to prevent seal water flow from overfilling the Miscellaneous Condensate Drain Tank:

1. SG FWP A seal water supply reg vlv PDV-58 inlet iso vlv o AE-V995 - CLOSED

2. SG FWP A seal water s upply reg vlv PDV-58 bypass vlv o AE-V994 - CLOSED BOOTH CUE:

If called as building watch to cl ose valves AE-V995 and AE-V994, report back in ~ four minutes that the valves are closed. These valves are not modeled. BOP 6.1.15 If desired to secure MFP A lube oil system, then perform section 6.3, Shutdown of MFP A lube oil system.

NA - not required 14 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _1____ Page 13 of 57 Event

Description:

Remove "A" Main Feed Pump from service using SYS AE-320, Turbine Driven Main Feedwater Pump Shutdown

Time Position Applicant's Actions or Behavior BOOTH CUE: If called as Call Supt./WWM, the MFP A lube oil system does not need to be shutdown. CREW Section 6.1. Shutdown of Main Feedwater Pump A, complete. When Main Feedwater Pump A is shutdown and at Lead Examiner direction, activate Event 2 by inserting KEY 2.

15 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _2____ Page 14 of 57 Event

Description:

Primary Loop D Thavg (BB TI-441) high failure.

Time Position Applicant's Actions or Behavior INDICATIONS: Main Control Board alarms: 65C , 65E, 66B, 66D, 67B, 67D, 68B, 68D, 81C, 81D, 82B, 82C, 83C Partial Trip Status Panel (SB069): bistable lights TB 441C (OTT L4) and TB441G (OPT L4) are illuminated Control rods step in.

Loop 4 T meter BB TI-441 is pegged high. CRS/CREW Actions may be taken be fore procedure entry: Once no runback/load rejection is determine d, the Control rods are taken to manual. CREW ENTER OFN SB-008, rev 25, Instrument Malfunctions CRS 1. Check if Secondary system instrument channel is malfunctioning a. Determine appropriate attachment for malfunctioning channel from table below; NO perform RNO RNOa. If secondary system channel is not malfunctioning, then go to step 2 CRS/RO 2. Check if RCS instrument channel or controller is malfunctioning: a. Determine appropriate attachment for malfunctioning channel or controller from table below:

Variable Channels Attachment RCS temperature (BB) T-411, T-421, T-431, T-441 Attachment L b. Go to appropriate attachment for malfunctioning RCS system channel or controller 16 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _2____ Page 15 of 57 Event

Description:

Primary Loop D Thavg (BB TI-441) high failure.

Time Position Applicant's Actions or Behavior CREW Performs OFN SB-008, Attachment L, Narrow Range RTD Malfunctions BOP L1. Check load rejection - NOT in progress o Generator load MW - STABLE o Generator load set MW - STABLE RO L2. Switch rod control bank selector switch (SE HS-9) to - MANUAL BOP L3. Check steam dumps

a. Check steam dumps in Tavg mode (handswitch AB US-500Z) b. Check steam dumps - CLOSED (meter AB ZL-34/35) RO L4. Identify failed instrument

a. Compare loop Tavg and T indications to confirm a Narrow Range RTD failure RO identifies Loop 4 failure (BB TI-441A, BB TI-442) 17 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _2____ Page 16 of 57 Event

Description:

Primary Loop D Thavg (BB TI-441) high failure.

Time Position Applicant's Actions or Behavior RO L5. Remove failed temperature channel from Tavg and T auctioneering circu its, using Tavg and T defeat switches o BB TS-411F o BB TS-412T Examiner Note: MCB alarms clear and 69A and 69C actuate. RO L6. Check (Tavg/Tref) error signal within 1F; NO, perform RNO RNO: () Manually adjust control rod position, to maintain Tavg within 1 F of Tref. NOTES o Several minutes must be allowed for power and temperature rate circuitry outputs to return to normal before switching back to automatic rod control.

o Control Rods should be restored to their parked position when plant conditions allow at the direction of the CRS. RO L7. Switch rod control ba nk selector switch to - AUTO o SE HS-9 RO L8. Monitor Rod Control System response to ensure proper control RO L9. Check C-7 Loss of Load Interlock - NOT LIT 18 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _2____ Page 17 of 57 Event

Description:

Primary Loop D Thavg (BB TI-441) high failure.

Time Position Applicant's Actions or Behavior BOP L10. Check Steam Dump Bypass Interlock switches in - ON (AB HS-63 and AB HS-64) BOP L11. Monitor steam dump control system to ensure proper operation RO L12. Check failed temperature channel not used for OPT and OTT recorders RNO: Select alternate temperature channel for OPT and OTT recorders (SC TS-411E) CRS L13. Monitor the following T echnical Specification LCOs and comply with Action Statements as appropriate:

o 3.3.1, Reactor Trip System Instrumentation, Table 3.3.1.-1, function 6 and 7

Cond. A: Function / channel inoper able - enter condition per table (immediately)

Cond. E: One channel inoperable - place channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />) Once Technical Specifications are identified and at Lead Examiner discretion, initiate Event 3 by activating KEY 3.

19 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _3____ Page 18 of 57 Event

Description:

S/G C le vel AE LI-553 failure high.

Time Position Applicant's Actions or Behavior BOOTH INSTRUCTIONS: At Lead Examiner discretion, activate Event 3 by inserting KEY 3. INDICATIONS:

Meter indication AE LI-553 increasing, Main Control Board alarms: 00-110C, SG C Flow Mismatch; 00-110B, SG C Lev Dev; 00-110A, SG C Lev Hi/Lo CRS/BOP Actions may be taken before procedure entry: Identify failed instrument, AE LI-533 failure; Place MFW Reg Valve in Manual (AE FK-530) and match steam and feed flow. CREW May enter ALR 00-110A rev 5, or go directly to OFN SB-008, rev 25, Instrument Malfunctions CRS/CREW ENTER ALR 00-110A, rev 5, SG C Lev Hi/Lo

1. Check SG C controlling level channel Less than 30% OR Greater than 70%

20 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: __3___ Page 19 of 57 Event

Description:

S/G C le vel AE LI-553 failure high.

Time Position Applicant's Actions or Behavior BOP 2. Check for Instrument failure:

o SG C controlling level channel - WITHIN 7% OF REMAINING SG C LEVEL CHANNELS --

NO AE LI-539 AE LI-553 RNO: Perform the following:

a. Place Feedwater Reg Valve (FRV) or Feedwater Reg Bypass Control Valve (FRBV) in manual AE FK-530 AE LK-570 b. Adjust FRV or FRBV as necessary to establish SG level at program value AE FK-530 AE LK-570

c. Select alternate channel for control AE LS-539C

d. Return FRV or FRBV to automatic AE FK-530 AB LK-570

e. Go to OFN SB-008, Instrument Malfunctions step 1, 21 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _3____ Page 20 of 57 Event

Description:

S/G C le vel AE LI-553 failure high.

Time Position Applicant's Actions or Behavior CRS/CREW ENTER OFN SB-008, Instrument Malfunctions (rev 25) BOP 1. Check if Secondary System instrument channel is malfunctioning: a. Determine appropriate attachment for malfunctioning channel from table below:

VARIABLE CHANNELS ATTACHMENT Steam level (AE)

L-553 Attachment F CRS Directs Attachment F, SG Level Channel Malfunction NOTE: If crew performed the ALR first, it may alter how they proceed through the OFN attachment. BOP F1. Identify failed narrow range SG level instrument channel:

a. Compare narrow range SG level indication to confirm a narrow range SG level channel failure o SG "C": AE-LI-537 AE LI-538 AE LI-539 AE LI-553

22 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _3____ Page 21 of 57 Event

Description:

S/G C le vel AE LI-553 failure high.

Time Position Applicant's Actions or Behavior BOP F2. Check failed SG level channel selected on level selector switch AE LS-539C (others are also listed in the procedure), RNO F2. Go to Step F7 BOP F3. Place affected SG feed reg control valve - in MANUAL AE FK-530 (other FRVs are listed in the procedure) BOP F4. Adjust affected feedwater re g valve, as necessary, to establish SG level at program (AE FK-530) BOP F5. Select alternate SG level channel for feedwater control AE LS-539C CRS F6. Restore affected SG f eed reg valve controller to - AUTO BOOTH Cue: If called as Call Sup /WWM, respond: I will assemble a team.

23 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _3____ Page 22 of 57 Event

Description:

S/G C le vel AE LI-553 failure high.

Time Position Applicant's Actions or Behavior CRS F7. Monitor the following TS for LCO's and comply with appropriate Action Statem ents as appropriate:

TS 3.3.1, Reactor Trip System Instrumentation, Table 3.3.1-1, FU

14 Cond A: Function / channel inoperable - enter condition per table (immediately)

Cond E: One channel inoperable - place channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />)

TS 3.3.2, Engineered Safety Features Actuation System Instrumentation, Table 3.3.2-1, FU 5c and 6d

Cond A: Function / channel inoperable - enter condition per table (immediately)

Cond D: One channel inoperable - place channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />)

Cond I: One channel inoperable - pl ace channel in trip (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />) BOOTH INSTRUCTIONS: At Lead Examiner discreti on, initiate Event 4 by activating KEY 4.

24 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _4____ Page 23 of 57 Event

Description:

Normal Charging Pump (NCP) trip. (ALR 00-042A, rev 14, CHG LINE FLOW HILO)

Time Position Applicant's Actions or Behavior INDICATIONS:

NCP indication (BG HIS-3) goes from Red light LIT to Green light LIT Various MCB Alarms:

00-042A, Charging Line Flow HiLo and 00-042E, Charging Pump trouble 00-041A, Seal Inj to RCP Flow Lo and 00-038A, LTDN Regen HX Temp Hi BOOTH Cue:

If dispatched to investigate NCP tri p, respond: I will investigate. If dispatched to NCP breaker, respond

Overcurrent flag is tripped. If contacted as WWM, respond : I will assemble a team.

If contacted as Electr ical Maintenance (MTN): I will assemble a team-.overcurrent flag is dropped. CRS ENTER and directs ALR 00-042A, re v 014, Charging Line Flow HiLo CRS/RO 1. Check charging header flow - 150 gpm o BG FI-121A, RNO1. Go to step 5. CRS/RO 5. Check charging header flow - 45 gpm o BG FI-121A CAUTION: If gas binding or pumps is suspected, performance of OFN BG-045, Gas Binding of CCPs or SI Pumps, should be considered.

25 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _4____ Page 24 of 57 Event

Description:

Normal Charging Pump (NCP) trip. (ALR 00-042A, rev 14, CHG LINE FLOW HILO)

Time Position Applicant's Actions or Behavior CRS/RO 6. Check charging pumps - ANY RUNNING BG HIS-1A for CCP A BG HIS-2A for CCP B BG HIS-3 for NCP

RNO6. Perform the following:

6RNOa. Close letdown orifice isolation valves o BG HIS-8149AA o BG HIS-8149BA o BG HIS-8149CA

6RNOb. Start any ava ilable charging pump BG HIS-1A for CCP A BG HIS-2A for CCP B BG HIS-3 for NCP RO 7. Check PZR level - at program value o BB LR-459 RNO7. Perform the following:

a. Place running charging pump flow controller in manual and adjust charging flow as necessary to establish PZR level at program value. BG FK-121 for CCP BG FK-462 for NCP

26 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: __4___ Page 25 of 57 Event

Description:

Normal Charging Pump (NCP) trip.

Time Position Applicant's Actions or Behavior RO 8. Check letdown isolated RO 9. Reestablish letdown

a. Check RCS letdown to regen HX valves open.

o BG HIS-459 o BG HIS-460 b. Place Letdown HX outlet pressure control in manual o BG PK-131

c. Open Letdown HX outlet pres sure control between 90% and 100% o BG PK-131

d. Open desired Letdown orifice isolation valve(s) BG HIS-8149AA BG HIS-8149BA BG HIS-8149CA

e. Adjust Letdown HX outlet pressu re control to es tablish Letdown HX outlet pressure between 340 psig and 360 psig o BG PI-131 f. Place letdown HX outlet pressure control in auto o BG PK-131 RO 10. Check letdown heat exchanger outlet temperature - 130 F o BG TI-130 27 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _4____ Page 26 of 57 Event

Description:

Normal Charging Pump (NCP) trip.

Time Position Applicant's Actions or Behavior RO 11. Check charging header flow and letdown flow - BALANCED RNO11. Adjust charging & letdown as necessary to maintain PZR level at program CAUTION: Total pump flow should be maintained above 175 gpm to minimize the effects of low flow cavitation. RO 12. Verify CCP adequate flow: a. Check CCPs - ANY RUNNING BG HIS-1A for CCP A BG HIS-2A for CCP B

b. Check CCP recirc valve - OPEN BG-HIS-8110 for CCP A BG HIS-8111 for CCP B CRS 13. Return to proce dure and step in effect.

28 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _4____ Page 27 of 57 Event

Description:

Normal Charging Pump (NCP) trip.

Time Position Applicant's Actions or Behavior CRS ENTER and directs ALR 00-042E, rev 10, Charging Pump Trouble RO 1. Check previously running charging pump - tripped o BG HIS-1A for CCP A o BG HIS-2A for CCP B o BG HIS-3 for NCP CRS 2. Contact Electrical Maintenance to determine cause of pump trip BOOTH Cue:

If dispatched as building watch to investigate NCP trip, respond: I will investigate. If dispatched to NCP breaker , respond: Overcurren t flag is tripped. If contacted as WWM, respond: I will assemble a team.

If contacted as Electrical MTN: I will assemble a team

-.overcurrent flag is dropped. RO 3. Check charging pumps - none running o BG HIS-1A for CCP A o BG HIS-2A for CCP B o BG HIS-3 for NCP RO 4. Close letdown orifice isolation valves.

o BG HIS-8149AA o BG HIS-8149BA o BG HIS-8149CA CAUTION: If gas binding of pumps is suspected, performance of OFN BG-045, Gas Binding of CCPs or SI Pumps, should be performed.

29 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _4____ Page 28 of 57 Event

Description:

Normal Charging Pump (NCP) trip.

Time Position Applicant's Actions or Behavior RO 5. Establish charging flow a. Check RCS temperature - 350 F b. Start CCP aligned for normal charging. BG HIS-1A for CCP A BG HIS-2A for CCP B 5c. Go to step 6 RO 6. Ensure RCP seal injection - between 8 gpm and 13 gpm to each RCP o BG FR-157 for RCP A o BG FR-156 for RCP B o BG FR-155 for RCP C o BG FR-154 for RCP D (Step 7 on next page.)

30 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _4____ Page 29 of 57 Event

Description:

Normal Charging Pump (NCP) trip.

Time Position Applicant's Actions or Behavior RO 7. Reestablish letdown

a. Check RCS letdown to regen HX valves open o BG HIS-459 o BG HIS-460 b. Place letdown HX outlet pressure control in manual o BG PK-131 c. Open letdown HX outlet pressure control between 90% and 100%

o BG PK-131

d. Open desired letdown orifice isolation valve(s). BG HIS-8149AA BG HIS-8149BA BG HIS-8149CA

e. Adjust letdown HX outlet pressure control to establish letdown HX outlet pressure between 340 psig and 360 psig o BG PI-131 f. Place letdown HX outlet pressure control in auto o BG PK-131 RO 8. Check charging header flow and letdown flow - BALANCED RNO8. Adjust charging & letdown as necessary to maintain PZR level at program value.

31 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _4____ Page 30 of 57 Event

Description:

Normal Charging Pump (NCP) trip.

Time Position Applicant's Actions or Behavior NOTE Total pump flow should be maintained above 175 gpm to minimize the effects of low flow ii RO 9. Verify CCP adequate flow:

a. Check CCPs - any running BG HIS-1A for CCP A BG HIS-2A for CCP B

b. Check CCP recirc valve - open BG HIS-8110 for CCP A BG HIS-8111 for CCP B CRS 10. Ensure compliance with T echnical Specifications and TRM:

a. Check plant - in Modes 1, 2, or 3

b. Refer to TR 3.1.9 and Technical Specification 3.5.2 CRS/CREW 11. Return to pro cedure and step in effect. BOOTH INSTRUCTIONS: At Lead Examiner discretion, initiate Event 5 by activating KEY 5.

32 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: __5___ Page 31 of 57 Event

Description:

500 gpm Steam Generator Tube Rupture on Steam Generator A (OFN BB-07A, Steam Generator Tube Leakage)

Time Position Applicant's Actions or Behavior INDICATIONS:

Decreasing level PZR MCB annunciators 00-061B, Process Rad Hi , followed by 00-061A, Process Rad HiHi RM-11R (SP056A) shows and alarms increasing radiation on process radiation monitor GE RE-92, Condenser Air Discharge Monitor CREW/CRS Begin diagnostics for Steam Generator Tube Rupture (SGTR) and ENTER OFN BB-07A, rev 9, Steam Generator Tube Leakage FOLDOUT PAGE FOR OFN BB-07A

1. SI ACTUATION CRITERIA IF any condition listed occurs, THEN trip the reactor, actuate SI , and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION Step 1. RCS subcooling based on subcooling monitor - LESS THAN 30°F SUBCOOLING WITH REACTOR TRIPPED OR Pressurizer pressure - CANNOT BE MAINTAINED OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6% OR All of the following conditions exist:

o Normal charging is maximized from one pump.

AND o Letdown is isolated.

AND o Pressurizer level is decreasing.

CAUTION If reactor trip or safety injection actuates during this procedure, go to EMG E-0, Reactor Trip or Safety Injection, step 1.

33 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 32 of 57 Event

Description:

500 gpm Steam Generator Tube Rupture on Steam Generator A Time Position Applicant's Actions or Behavior RO 1. Check PZR level - 6% RO 2. Check PZR level - 17% RO 3. Check PZR level - stable or increasing --

NO RNO3 If PZR level program, then perform the following: a. Control charging flow as necessary to maintain PZR level

b. If PZR level cannot be maintained, then close letdown orifice isolation valves as necessary to stabilize PZR level BG HIS-8149AA BG HIS-8149BA BG HIS-8149CA CREW 4. Try to identify the leaking SG Unexpected increase in any SG narrow range level OR Radiation from any SG steam line radiation monitor OR Radiation from any SG steam line survey OR Radiation from any SG sample RNO4. Try to identify leaking SG: a. Direct HP to survey steamlines & blowdown lines as necessary to determine leaking SG BOOTH Cue: Respond as HP: I will survey the steam lines & blowdown lines.

34 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 33 of 57 Event

Description:

500 gpm Steam Generator Tube Rupture on Steam Generator A (EMG E-0, Reactor Trip or Safety Injection)

Time Position Applicant's Actions or Behavior NOTES o If VCT level cannot be maintained, the Rx is tripped since after swapover to the RWST the high boron injection flowrate makes an orderly shutdown difficult.

o If the leak rate is still within the capacity of a charging pump, after swapover to the RWST, it is not desirable to actuate SI and go to EMG E-3. CREW 5. Check VCT level - BEING MAINTAINED BY NORMAL MAKEUP CRS/CREW Use OFN BB-07A FOLDOUT page criteria to direct Reactor trip and Safety Injection. CRS Direct reactor trip and safety injection actuation. CRS ENTER EMG E-0, rev 22, Reactor Trip or Safety Injection 35 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 34 of 57 Event

Description:

500 gpm Steam Generator Tube Rupture on Steam Generator A (EMG E-0, Reactor Trip or Safety Injection)

Time Position Applicant's Actions or Behavior FOLDOUT PAGE FOR EMG E-01. RCP TRIP CRITERIA IF all conditions listed below occur, THEN trip all RCPs:

o RCS pressure - LESS THAN 1400 PSIG o CCPs or SI pumps - AT LEAST ONE RUNNING o Operator controlled cooldown - NOT IN PROGRESS

2. SI ACTUATION CRITERIA IF either condition listed below occurs, THEN actuate SI and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION, Step 1: RCS subcooling - LESS THAN 30°F [45°F]

OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6% [33%]

3. FAULTED S/G ISOLATION CRITERIA IF any S/G pressure decreasing in an uncontrolled manner OR any S/G completely depressurized, THEN the following may be performed:

a. Close main steam isolation valves.

b. Isolate feed flow to faulted S/G(s).

c. Maintain total feed flow greater than 270,000 lbm/hr until narrow range level in at least one S/G is greater than 6% [29%].

4. RUPTURED S/G ISOLATION CRITERIA IF any S/G level increases in an uncontrolled manner OR any S/G has abnormal radiation, AND narrow range level in affected S/G(s) is greater than 6% [29%], THEN the following may be performed. a. Close ruptured S/G AFW flow control valves.

b. IF any ruptured S/G AFW flow control valve cannot be closed AND total AFW flow to intact S/Gs can be maintained greater than 270,000 lbm/hr without associated AFW Pump, THEN perform the following:

1) Stop associated MD AFWP and place in PTL OR decrease TDAFWP speed to 2000 rpm.

2) Dispatch an Operator to locally isolate affected AFW flow control valve.

3) WHEN affected AFW flow control valve is isolated, THEN restart MD AFWP OR Restore TD AFWP speed as necessary.

5. COLD LEG RECIRCULATION CRITERIA IF RWST level decreases to less than 36%, THEN go to EMG ES-12, TRANSFER TO COLD LEG

RECIRCULATION, Step 1.

6. AFW SUPPLY SWITCHOVER CRITERIA IF CST suction pressure decreases to less than 2.6 psig, THEN switch to alternate AFW suction supply.

36 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 35 of 57 Event

Description:

500 gpm SGTR, EMG E-0, rev 22, Reactor Trip or Safety Injection Time Position Applicant's Actions or Behavior CAUTION Accident conditions can cause higher than normal radi ation levels. Health Physics monitoring may be required while performing local operator actions.

NOTES o Steps 1 through 4 are immediate action steps.

o Foldout page shall be monito red throughout this procedure. RO/CRS 1. Verify reactor trip a. Check all rod bottom lights - LIT

b. Ensure reactor trip

& bypass breakers - OPEN

c. Check IR neutron flux - DECREASING BOP/CRS 2. Verify turbine trip

a. Check the following: Main stop valves - ALL CLOSED OR Turbine auto stop bistab les - AT LEAST TWO LIT RO/CRS 3. Check AC emergency busses - at least one energized NB01 voltage - NORMAL NB02 voltage - NORMAL 37 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 36 of 57 Event

Description:

500 gpm SGTR, EMG E-0, rev 22, Reactor Trip or Safety Injection Time Position Applicant's Actions or Behavior RO/CRS 4. Check if Safety Injection is Actuated:

a. Check any indication SI is actuated - LIT 00-030A, NF039A LOCA Seq Actuated - LIT OR 00-031A, NF039B LOCA Seq Actuated - LIT OR ESFAS status panel SIS section - any white lights LIT OR Partial Trip Status Permissive s/Block status panel - SI red light lit

b. Check both trains of SI actuated o 00-030A, NF039A LOCA Seq Actuated - LIT o 00-031A, NF039B LOCA Seq Actuated - LIT CAUTIONIf offsite power is lost after SI reset, manual action may be required to restore safeguards equipment to the required configuration. CRS 5. Check if SI is required: SI was manually actuat ed AND was required OR RCS pressure is currently or has been - 1830 psig OR Any SG pressure is currently or has been - 615 psig OR Containment pressure is currently or has been - 3.5 psig OR RCS subcooling is currently or has been - 30F [45F] OR PZR level is currently or has been - 6% [33%]

38 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 37 of 57 Event

Description:

500 gpm SGTR, EMG E-0, rev 22, Reactor Trip or Safety Injection Time Position Applicant's Actions or Behavior BOP 6. Check Main Generator Breakers & Exciter Breaker - open o MA ZL-3A o MA ZL-4A o MB ZL-2 CRS 7. Verify Automatic Actions using Attachment F, Automatic Signal Verification Attachment F, Automatic Signal Verification RO/BOP F1. Verify Feedwater Isolation F2. Verify Containment Isolation Phase A F3. Verify AFW Pumps running

F4. Verify ECCS pumps running F5. Verify CCW alignment F6. Check ESW pumps - both running F7. Check Containment fan cool ers - running in slow speed F8. Verify Containment purge isolation F9. Verify both trains of Control Room ventilation isolation

F10. Verify Main Steamlin e isolation not required F11. Verify Containment Spray not required

39 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _6____ Page 38 of 57 Event

Description:

BIT outlet valves EM HIS-8801A & EM HIS-8801B do not open upon SI actuation - manual open available.

Time Position Applicant's Actions or Behavior INDICATION: No ECCS flow indication on EM FI-917A or EM FI-917B. BIT outlet valves EM HIS-8801A/B indicate closed (Green lights are LIT). RO/BOP Determine BIT outlet valves EM HIS-8801A and EM HIS-8801B are not open. (EMG E-0, Att F, step F12) RO/BOP CT: Open BIT outlet valve s (EM HIS-8801A and EM HIS-8801B) before the end of the scenario or before needless Red or Orange path occurs. Success: Opens BIT outlet valv es EM HIS-8801A and EM HIS-8801B after completion of Immediate Action steps OR they may be opened using Attachment F of EMG E-0 (F12). RO/BOP F12. Verify ECCS flow:

(CT) a. Check CCP to BIT flow meters -

NO flow indicated o EM FI-917A o EM FI-917B RNOa. Perform the following 1) If BIT valves have not been closed by operator action then manually start pumps and align valves

NOTE: EM HIS 8801A and EM HIS-8801B are depressed OPEN, Red lights LIT, flow indicated on EM FI-917A/B

2) If BIT valves are closed by operator action, then go to step 13

40 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 39 of 57 Event

Description:

500 gpm SGTR, EMG E-0, rev 22, Reactor Trip or Safety Injection Time Position Applicant's Actions or Behavior RO/BOP F13. Verify AFW valves - properly aligned RO/BOP F14. Verify SI valves - properly aligned RO/BOP F15. Check is NCP should be stopped:

a. CCPs - any running

b. Stop NCP o BG HIS-3 RO/BOP F16. Return to pro cedure and step in effect. BOP 8. Check total AFW flow - 270,000 lbm/hr

41 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 40 of 57 Event

Description:

500 gpm SGTR, EMG E-0, rev 22, Reactor Trip or Safety Injection Time Position Applicant's Actions or Behavior FOLDOUT PAGE ITEM4.: RUPTURED S/G ISOLATION CRITERIA IF any S/G level increases in an uncontrolled manner OR any S/G has abnormal radiation, AND narrow range level in affected S/G(s) is greater than 6% [29%], THEN the following may be performed.

a. Close ruptured S/G AFW flow control valves. (CT - see below)

b. IF any ruptured S/G AFW flow control valve cannot be closed AND total AFW flow to intact S/Gs can be maintained greater than 270,000 lbm/hr without associated AFW Pump, THEN perform the following:

1) Stop associated MD AFWP and place in PTL OR decrease TDAFWP speed to 2000 rpm. 2) Dispatch an Operator to locally isolate affected AFW flow control valve.

3) WHEN affected AFW flow control valve is isolated, THEN restart MD AFWP OR Restore TD AFWP speed as necessary.

CRS/BOP Directs Foldout Item #4, Ruptured SG Isol ation Criteria when level in ruptured SG 6% [29%] CT: Isolate feed flow to ruptured Steam Generator before Steam Generator overfills. Success: Close ruptured steam generator AFW flow control valves, AL HK-8A and AL HK-7A.

42 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 41 of 57 Event

Description:

500 gpm SGTR, EMG E-0, rev 22, Reactor Trip or Safety Injection Time Position Applicant's Actions or Behavior RO 9. Check RCS cold leg temperatures Stable at to trending to 557F for condenser steam dumps, NO Stable at or trending to 561F for SG ARVs RNO9. Perform the following:

a. If temp. is setpoint and decreasing, then perform the following: 1) Stop dumping steam 2) If any MSIV is open, then cl ose Main Turbine Stop & Control Valves Startup Drains (AC HIS-134) 3) If cooldown continues then control total feed flow to limit RCS cooldown. Maintain total feed flow 270,000 lbm/hr until NR level 6% [29%] in at least one SG 4) If cooldown continues due to excessive steam flow, then close MSIVs, bypass valves and drain valves

b. If temperature is setpoint and increasing, then perform one of the following: Dump steam to condenser Dump steam using SG ARVs

43 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: __5___ Page 42 of 57 Event

Description:

500 gpm SGTR, EMG E-0, rev 22, Reactor Trip or Safety Injection Time Position Applicant's Actions or Behavior BOP 10. Establish SG pressure control a. Check condenser - AVAILABLE o C-9 lit o MSIV - OPEN o Circ water pumps - RUNNING b. Place steam header pressure control in manual o AB PK-507 c. Manually set steam header pre ssure control output to zero o AB PK-507 d. Place steam dump select switch to STEAM PRESS position o AB US-500Z e. Place steam header pressure control in Automatic o AB PK-507 RO 11. Check PZR PORVs a. Check PZR PORVs - CLOSED o BB HIS-455A o BB HIS-455B b. Power to block valves- AVAILABLE

c. RCS pressure - 2185 psig RO 12. Check normal PZR spray valves - CLOSED o BB ZL-455B o BB ZL-455C 44 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 43 of 57 Event

Description:

500 gpm SGTR, EMG E-0, rev 22, Reactor Trip or Safety Injection Time Position Applicant's Actions or Behavior RO 13. Check PZR safety valves - CLOSED o BB ZL-8010A o BB ZL-8010B o BB ZL-8010C NOTE: Seal injection flow shall be maintained to all RCPs. RO 14. Check if RCPs should be stopped:

a. Check RCPs - any running

b. Check RCS pressure - 1400 psig RNOb. Go to step 15

c. Check ECCS pumps - at least one running CCP or SI pump d. Check operator controlled cooldown - not in progress

e. Stop all RCPs CRS 15. Direct Operator to monitor Critical Safety Fu nctions using EMG F-0, Critical Safety Function Status trees (CSFST) 45 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 44 of 57 Event

Description:

500 gpm SGTR, EMG E-0, rev 22, Reactor Trip or Safety Injection Time Position Applicant's Actions or Behavior BOP 16. Check is SGs are not faulted:

a. Check pressures in all SGs -

o No SG pressure decreasing in an uncontrolled manner o No SG completely depressurized BOP 17. Check if SG tubes are intact: Direct HP to survey steam lines in Area 5 of the Aux Building Condenser air discharge radiation - Normal before isolation o GEG 925 -

NO , perform RNO RNO17. Perform the following:

a. Ensure BIT inlet and outlet valves are open o EM HIS-8803A o EM HIS-8803B o EM HIS-8801A o EM HIS-8801B

b. Go to EMG E-3, Steam Generator Tube Rupture, step 1 BOOTH Cue: Respond as HP: I will survey the steam lines in Area 5. Later, call back with a report of higher than normal radiation on SG "A" mainsteam line.

46 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: __5___ Page 45 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR)

Time Position Applicant's Actions or Behavior CRS Crew transitions from EMG E-0 to EMG E-3 CREW ENTER and Direct EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR) FOLDOUT PAGE FOR EMG E-3 1. SI REINITIATION CRITERIA IF following performance of Step 31, either c ondition listed below occurs, THEN start ECCS pumps as necessary to reestablish RCS subc ooling and PZR level and go to EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED, Step 1. RCS subcooling - LESS THAN 30°F [45°F] OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6% [33%]

2. SECONDARY INTEGRITY CRITERIA IF all conditions listed below are sati sfied, THEN go to EMG E-2, FAULTED STEAM GENERATOR ISOLATION, Step 1:

o Any S/G pressure is decreasing in an uncontrolled manner OR any S/G has completely depressurized o Affected S/G has NOT been isolat ed using EMG E-2, FAULTED STEAM GENERATOR ISOLATION o Affected S/G is NOT needed for RCS cooldown

3. MULTIPLE TUBE RUPTURE CRITERIA IF any intact S/G level increases in an uncontrolled manner OR any intact S/G has abnormal radiation, THEN stop any RCS cooldown and depre ssurization in progress, stabilize the plant, and go to EMG E-3, STEAM GENERATOR TUBE RUPTURE, Step 1.

4. COLD LEG RECIRCULATION CRITERIA IF RWST level decreases to less than 36%, THEN go to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION, Step 1. 5. AFW SUPPLY SWITCHOVER CRITERIA IF CST suction pressure decreases to less th an 2.6 psig, THEN switch to alternate AFW suction supply.

47 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 46 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR)

Time Position Applicant's Actions or Behavior NOTES o Foldout page shall be monito red throughout this procedure.

o Personnel should be available for sampling during this procedure.

o Seal injection flow shall be maintained to all RCPs. CRS 1. Check if RCPs should be stopped: a. Check RCPs - ANY RUNNING

b. Check RCS pressure - 1400 psig; NO, perform RNO c. Check ECCS pumps - AT LEAST ONE RUNNING CCP or SI pump d. Check operator controlled cooldown - NOT IN PROGRESS

e. Stop all RCPs RNO for a-d: Observe CAUTION prior to step 2 and go to step 2 CAUTION If steamlines are not intact, extreme caution will be necessary when performing local surveys. CRS 2. Identify ruptured SGs: Level increasing in an uncontrolled manner OR High turbine driven AFW exhaust radiation OR High radiation from any SG steamline radiation monitor OR High radiation from any SG steamline survey OR High radiation from any SG sample 48 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 47 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR)

Time Position Applicant's Actions or Behavior BOOTH CUE: If contacted as HP to survey steam lines in Area 5: respond I will perform the survey. CAUTION If the turbine driven AFW pump is the only avai lable source of feed flow, steam supply to the turbine driven AFW pump must be maintained from at least one S/G. RO/BOP 3. Isolate flow from ruptured SGs:

a. Adjust ruptured SG ARV c ontroller setpoint to 1160 psig

b. Check ruptured SG ARV - CLOSED

c. Locally close steam supply to turbine driven AFW pump from ruptured SG(s)

NA for SG A AB-V085 for SG B AB-V087 for SG C d. Locally isolate main steamline low point drain valve from ruptured SG(s) Close AB-V062 for SG A Close AB-V072 for SG B Close AB-V082 for SG C Close AB-V052 for SG D BOOTH INSTRUCTION: AB-V062 not modeled; wait ~ two minutes and report that AB-V062 is closed.

49 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 48 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR) Time Position Applicant's Actions or Behavior BOP 4. Verify blowdown & upper samp ling isolated on ruptured SGs: a. SG blowdown containment isolation valves - CLOSED BM HIS-1A for SG A BM HIS-2A for SG B BM HIS-3A for SG C BM HIS-4A for SG D b. SG upper sample isolation valves - CLOSED BM HIS-19 for SG A BM HIS-20 for SG B BM HIS-21 for SG C BM HIS-22 for SG D CAUTION At least one SG shall be mainta ined available for RCS cooldown.

50 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 49 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR)

Time Position Applicant's Actions or Behavior CRS 5. Isolate steamline on ruptured SGs: a. Close main steamline isolation valve AB HIS-14 for SG A AB HIS-17 for SG B AB HIS-20 for SG C AB HIS-11 for SG D b. Ensure main steamline isolation bypass valves - CLOSED o AB ZL-15A for SG A o AB ZL-18A for SG B o AB ZL-21A for SG C o AB ZL-12A for SG D CAUTION If any ruptured S/G is also faulted and the affected S/G is not needed for RCS cooldown, feed flow to that S/G shall remain isolat ed during subsequent recovery actions. BOP 6. Check if feed flow should be isolated to ruptured SG(s): a. Check ruptured SG(s) narrow range level - 6% [29%]

51 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 50 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR)

Time Position Applicant's Actions or Behavior CT: Isolate feed flow to ruptured Steam Generator before Steam Generator overfills. Success: Close ruptured steam generator AFW flow control valves, AL HK-8A and AL HK-7A. (May have been performed using Fo ldout page criteria of EMG E-0) BOP 7. Stop feed flow to ruptured SG(s) (CT) a. Close affected SG(s) MD AFP flow control valve(s) AL HK-7A for SG A AL HK-9A for SG B AL HK-11A for SG C AL HK-5A for SG D b. Close affected SG(s) TD AF WP flow control valve(s) AL HK-8A for SG A AL HK-10A for SG B AL HK-12A for SG C AL HK-6A for SG D BOP 8. Establish SG pressure control: a. Check condenser available

b. Place steam header pressure control in manual

c. Manually set steam header pr essure control output to zero d. Place steam dump select switch in STEAM PRESS position

e. Place steam header pressure control in automatic 52 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: ___5__ Page 51 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR)

Time Position Applicant's Actions or Behavior CRS 9. Verify ruptured SG(s) isolation

a. Check ruptured SG(s) - not needed for RCS cooldown

b. Verify ruptured SG(s) steamline has been isolated from at least one intact SG: Main steam isolation valve, bypa ss valve, and drain valve on ruptured SG - CLOSED OR Attachment A, Main Steam header isolation - Control Room - completed c. Verify steam supply to turbine driven AFW pump from ruptured SG(s) - CLOSED NA FOR SG A AB-V085 for SG B AB-V087 for SG C CAUTION At EOL, if a control rod is stuck or SI flow is reduced, an inadvertent restart may occur. Symptoms for subcriticality red path and transition to EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS, shall be closely monitored during subsequent steps. CREW 10. Check ruptured SG(s) pressure - 275 psig 53 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: __5___ Page52 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR) Time Position Applicant's Actions or Behavior NOTE If high steam pressure rate set point (100 psi/50 sec) is exceeded after low steamline pressure SI signal is blocked, main steamline isolation will occur. RO 11.Check if low steamline pr essure SI should be blocked: a. Check RCS pressure - 1970 psig o P-11 light - LIT b. Block low steamline pressure SI o SB HS-9 o SB HS-10 RNOa. When RCS pressure is 1970 psig then block low steamline pressure SI. Continue with step 12.

CREW 12. Determine target plant conditions from table below:

LOWEST RUPTURED S/G PRESSURE (PSIG) TARGET CORE EXIT TEMPERATURE

(°F) TARGET INTACT S/G PRESSURE (PSIG) TARGET CONDENSER STEAM DUMP CONTROLLER SETPOINT >1200 519 [504] 791 [691] 5.27 [4.61] 1100 TO 1199 508 [493] 717 [624] 4.78 [4.16] 1000 TO 1099 496 [481] 642 [557] 4.28 [3.71] 900 TO 999 484 [469] 573 [495] 3.82 [3.30] 800 TO 899 470 [455] 500 [430] 3.33 [2.87] 700 TO 799 455 [440] 430 [367] 2.87 [2.45] 600 TO 699 438 [423] 359 [304] 2.39 [2.03] 500 TO 599 420 [405] 294 [247] 1.96 [1.65] 400 TO 499 398 [383] 227 [188] 1.51 [1.25] 300 TO 399 372 [357] 163 [133] 1.09 [0.89] 275 TO 299 364 [350] 147 [118] 0.98 [0.79]

54 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: __5___ Page 53 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR) Time Position Applicant's Actions or Behavior CAUTION If RCPs are NOT running, the cooldown and depressurization steps may cause a red or orange path condition on the integrity status tree for the ruptured loop. Step 48 shall be completed before reevaluating the red or orange path condition and transition to EMG FR-P1, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK CONDITIONS, if required

. NOTES o After operator initiated RCS cooldown has been started, RCP trip criteria no longer applies.

o When RCS average temperature is less than 550°F, the condenser steam dump low temperature interlock must be bypassed to keep cooldown valves open.CT: Cooldown & Depressurize RCS to mi nimize RCS inventory leakage into the ruptured Steam Generator. Success: Initiate Maximum rate RCS Cooldown (see step

13) CRS 13. Initiate RCS cooldown (CT) a. Dump steam to condenser at maximum rate:

1) Ensure STM HDR PRESS CTRL in manual o AB PK-507 2) Set STM HDR PRESS CTRL potentiometer to target setpoint value o AB PK-507

3) Manually adjust STM HDR PRESS CTRL to slowly open a maximum of 3 cooldown valves o AB PK-507 4) When P-12 interlock actuates, then place both STEAM DUMP BYPASS INTERLOCK switches to BYP/INTLK o AB HS-63 o AB HS-64 5) Place STM HDR PRESS CTRL in auto to continue cooldown at maximum rate o AB PK-507 55 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: __5___ Page 54 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR) Time Position Applicant's Actions or Behavior CREW 14. Check intact SG levels: a. Check NR level in at least one SG - 6% [29%]

b. Control feed flow to maintain NR level in all SGs between 29%

[29%] and 50%

CAUTION If any PZR PORV opens because of high PZR pressure, the PORV shall be monitored to ensure it recloses after pressure decreases to less than 2335 psig. CREW 15. Check PZR PORVs and block valves: a. Power to block valves - AVAILABLE o BB HIS-8000A o BB HIS-8000B

b. PZR PORVs - CLOSED o BB HIS-455A o BB HIS-456A

c. RCS pressure - 2185 psig CREW 16. Check PZR Safety valves - CLOSED o BB ZL-8010A o BB ZL-8010B o BB ZL-8010C Terminate scenario at Le ad Examiner's discretion.

56 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: __5___ Page 55 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR) Time Position Applicant's Actions or Behavior CAUTION If offsite power is lost after SI reset, manual action may be required to restore safeguards equipment to the required configuration. RO 17. Reset SI o SB HS-42A o SB HS-43A RO 18. Reset Containment Isolation Phase A & Phase B o SB HS-56 for phase A o SB HS-53 for phase A o SB HS-55 for phase B o SB HS-52 for phase B CREW 19. Establish Instrument Air to Containment a. Ensure ESW to air compressor valves - OPEN o EF HIS-43 o EF HIS-44 b. Reset and close air compressor breaker reset switches o KA HIS-2C o KA HIS-3C c. Check instrument air pressure - 105 psig o KA PI-40 d. Check PZR pressure master controller - 50% output signal o BB PK-455A e. Open instrument air supply containment isolation valve o KA HIS-29 57 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 56 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR) Time Position Applicant's Actions or Behavior CAUTION After RHR pumps have been stopped, RCS pressure shall be monitored for RHR pump restart criteria. CRS 20. Check if RHR pump s should be stopped: a. Check RHR pumps - any running b. Check RHR system - aligned for injection c. Check RCS pressure - 325 psig d. Stop RHR pumps and place in standby o EJ HIS-1 o EJ HIS-2 e. Check RCS pressure 325 psig during subsequent recovery actions RNOe. If RCS pressure decrea ses in an uncontrolled manner to 325 psig, then manually restart RHR pumps to provide injection to the RCS. CREW 21. Check if RCS cooldown should be stopped: a. Check RCS temperatures - target temperature Core Exit TCs or RCS hot leg RTDs b. Ensure steam dump valves - CLOSING o Condenser steam dumps o ARVs c. Adjust steam dump controllers, as necessary, to automatically maintain RCS temperature stable below target temperature AB PK-507 or Intact ARVs 58 Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: _____ Scenario No.: __2

___ Event No.: _5____ Page 57 of 57 Event

Description:

500 gpm SGTR, EMG E-3, rev 22, Steam Generator Tube Rupture (SGTR) Time Position Applicant's Actions or Behavior CREW 22. Check ruptured SG Pre ssure - stable or increasing CREW 23. Check RCS subcooling - 50 F [65 F] CREW 24. Depressurize RCS using normal Spray to minimize break flow and refill PZR a. Verify normal PZR spray - available RCP D running RCPs A, B, and C running All RCPs running b. Spray PZR with maximum available spray until any of the following conditions Are satisfied: PZR level - 75% [61%] or RCS subcooling - 30 F [45 F] or Both of the following

1) RCS pressure - ruptured SGs pressure

2) PZR level - 6% [33%] c. Close normal spray valves o BB PK-455B o BB PK-455C d. Observe CAUTION prior to step 30 and go to step 30 Terminate scenario at Le ad Examiner's discretion.

1Appendix D Scenario Outline Form ES-D-1 Facility: __Wolf Creek

_______ Scenario No.: ___3____

Op-Test No.: _______

Examiners: ____________________________ Operators: __________________________ ____________________________ _____________________________

____________________________ _____________________________

Initial Conditions: 100% pow er, Middle of Life

Turnover:

CCP "B" tagged out for preventative maintenance. TS 3.5.2 entered (Run file Tag B CCP)

Event No. Malf. No. Event Type* Event Description 1 t+2 mBB21B I - ATC, SRO Pressurizer pressure cha nnel BB PI-457 failure low.

OFN SB-008, Instrument Malfunctions, Attachment K, PZR Pressure Malfunction, entered.

2 t+10 mAB01A 1 I - BOP, SRO Steam pressure detector on "A" loop high failure (AB PI-514A)

OFN SB-008, Instrument Malfunctions, Attachment C, SG Pressure Channel Malfunction, entered.

3 t+23 mBB31D C - All RCP "D" develops frame vibration greater than 5 mils.

RCP secured per OFN BB-005, RCP Malfunctions, Attachment B, RCP Shutdown.

OFN BB-005, RCP Malfunctions, entered.

4 t+35 mBB05D M - All Loss of Coolant (LOCA) - 1 inch (~1200 gpm) on Hot Leg "D" loop

EMG E-0, Reactor Trip or Safety Injection EMG ES-02, Reactor Trip Response EMG E-1, Loss of Reactor or Secondary Coolant

EMG ES-11, Post LOCA Cooldown and Depressurization

2 5 t+35 mBG27A

mEM01A mEM01B C - ATC, SRO Autostart failure of CCP "A" upon receipt of Safety Injection Signal. Crew can start pump manually using handswitch BG HIS-1A.

Upon Safety Injection Signal actuation, both Safety Injection pumps will trip. Recall CCP "B" is out of service - see Turnover.

CT: Establish flow from at least one Centrifugal Charging Pump before a needless red or orange path condition exists OR before the end of the scenario.

6 t+35 mSA23A mSA23B C - ATC, SRO Upon actuation of Safety Injection Signal, the automatic actuation of Containment Purge Isolation Signal does not occur. Manual actuation from Control Room is successful.

CT: Close Containment isol ation valves such that at least one valve is closed on each critical phase-A

penetration before the end of the scenario.

• (N)ormal, (R)eactivit y , (I)nstrument, (C)om p onent, (M)a j o r 3Appendix D Scenario Outline Form ES-D-1 Scenario Summary:

Plant is 100% MOL. Centrifugal Charging Pu mp "B" is out of service for preventative maintenance. Technical Specification 3.5.2 Condition A entered. Expected return is ten hours.

Pressurizer (PZR) pressure controlling channel BB PI-457 fails low. Crew responds using OFN SB-008, Instrument Malfunctions, Attachment K, PZR Pressure Malfunction. Attachment K: Select an alternate pressure channel as the controlling channel. Crew stabilizes the plant.

Steam Generator "A" controlling steam pressure channel (AB PI-514A) fails high. Crew responds using OFN SB-008, Instrument Malfunctions, Attachment C, Pressure Channel Malfunctions. ALR 00-108C, SG A Flow Mismatch, annunciates. Attachment C: Select an alternate pressure channel as the controlling channel. Crew stabilizes the plant.

Reactor Coolant Pump (RCP) "D" develops high frame vibration (greater than 5 mils).

Crew responds by entering OFN BB-005, RCP Malfunctions. The crew determines that the Immediate Shutdown criteria for an RCP are met. Attachment B, RCP Shutdown, is performed. ALR 00-070B, RCP VIB/SYS Alert and ALR 00-070A, RCP VIB Danger, annunciate. From OFN BB-005, Attachment B, the Reactor is tripped and EMG E-0, Reactor Trip or Safety Injection, is entered. RCP "D" is secured. Crew stabilizes the plant.

EMG E-0, Reactor Trip or Safety Injection, is performed. Major actions of EMG E-0: Verify automatic actions as initiated by the protection and safeguard systems. Identify appropriate optimal recovery guideline. Shutdown unnecessary equipment and continue trying to identify optimal recovery guideline.

EMG ES-02, Reactor Trip Response, is entered from EMG E-0, Reactor Trip or Safety Injection, RNO step 4. Major Actions of EMG ES-02: Ensure the primary system stab ilizes at no-load conditions Ensure the secondary system st abilizes at no load conditions Ensure the necessary compone nt have power available Maintain/Establish forced circulation of the RCS Maintain the plant in a stable condition

4Major event: As the crew proceeds through EMG ES-02, the one-inch LOCA occurs.

RCS pressure begins to decrease and Pressurizer level will not be able to be maintained greater than 6% - this is im portant as EMG ES-02 Foldout pa ge criteria #1 SI Actuation will be utilized to actuate Safety Injection and return to EMG E-0, Reactor Trip or Safety Injection. Unexpected Main Control Board alarms aid in diagnosing the LOCA.

o ALR 00-032C, PZR LO LEV DEV o ALR 00-060F, CTMT SUMP C/D LEV HI o ALR 00-060E, CTMT SUMP A/B LEV HI o ALR 00-032B, PZR 17% HTRS OFF LTDN ISO o ALR 00-062B, AREA RAD HI

EMG E-0, Reactor Trip or Safety Injection is entered a second time. The LOCA has been diagnosed. All RCP's will be tripped. EMG E-1, Loss of Reactor Coolant, will be entered.

EMG E-1, Loss of Reactor or Secondary Coolant, is performed. Major actions of EMG E-1: Monitor plant equipment for optimal mode of operation Check for subsequent failure Determine optimal method of long term plant recovery EMG ES-11, Post LOCA Cooldown and Depressurization, is performed as the procedure for optimal recovery. Major actions include: Prepare for and initiate RCS cooldown Depressurize RCS to refill PZR Start one RCP/Stop all but one RCP Reduce RCS injection flow Depressurize RCS to minimize RCS subcooling Perform other long term recovery actions Scenario has two Critical Tasks (CT):

1. Establish flow from at least one Centrifugal Charging Pump before a needless red or orange path condition exists OR before the end of the scenario.

2. Close Containment isolation valves such that at least one valve is closed on each critical phase-A penetration before the end of the scenario 5 Probabilistic Risk Assessment for this scenario includes:

Core Damage Frequency (CDF) By Event Tree (Reference PSA 08-0002)

Event Tree Core Damage Frequency (/yr)

Percent Contribution Station Blackout 6.46E-06 35.79% Small LOCA 5.35E-06 29.65%

Core Damage Frequency By Initiating Event (Reference PSA 08-0002)

Event Tree Core Damage Frequency (/yr)

Percent Contribution Station Blackout 6.46E-06 35.79% Small LOCA 5.35E-06 29.65% Interfacing Systems LOCA 1.93E-06 10.68% Very Small LOCA 1.27E-06 7.05%

Top Ten Accident Sequences by CDF (Reference PSA-07-0001)

Number Sequence Identifier Sequence Frequency

(/yr) Percent Contribution Sequence Description 5 VLOS07 1.27E-06 7.05% Very Small LOCA Initiating Event Occurs; High Pressure Safety Injection function fails; Auxiliary Feedwater Supply function is successful; RCS Cooldown and Depressurization function is successful; Low Pressure Safety Injection function fails. 6 SLOS13 9.37E-07 5.19% Small LOCA Initiating Event occurs; High Pressure Safety Injection function fails; Auxiliary Feedwater Supply function is successful; RCS Cooldown and Depressurization function is successful; Low Pressure Safety Injection function fails.

6 Top 10 Human Action Failures by the Importance Measure Rankings (Reference PSA-07-0001)

F-V Rank RRW Rank Total Rank Event Name Description Point Est. F-V RAW RRWBirnbaum 3 9 40 OPA-RRI1-EXE FAILURE TO ALIGN &

START 1 SI OR CCP

PUMP - EXE 4.68E-03 2.45E-02 6.2 1.0259.43E-05

Technical Specifications exercised:

Event 1 TS 3.3.1, Reactor Trip System Instrumentation (RTS), Table 3.3.1-1, FU 6 & 8 (Cond A

and M - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to trip bistables)

TS 3.3.2, Engineered Safety Feature Actuation System Instrumentation (ESFAS), Table 3.3.2-1, FU 1d, 5d, 6e, 8b (Cond A, D, and L entered - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to trip bistables; 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />

to verify P-11 in the correct state)

Others listed in Attachment K will be looked at, but no conditions apply.

Event 2 TS 3.3.2, Engineered Safety Feature Actuation System Instrumentation (ESFAS), Table 3.3.2-1, FU 1e and 4e (Cond A and D - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to trip bistables)

Others listed in Attachment C will be looked at, but no conditions apply.

Op Test No.: NRC Scenario # 3 Event # 1 Page 7 of 48 Event

Description:

Pressurizer pressure channel BB PI-457 fails low Time Position Applicant's Actions or Behavior 7BOOTH INSTRUCTIONS:

IC 30; 100%, insert files, prepare simulator per Setup document.

At Lead Examiner direction, acti vate Event 1 by inserting KEY 1. INDICATIONS: Pressure meter BB PI-457 decreases. PZR sp ray valves close. RCS pressure increases.

Partial trip/bistable panel (SB069) bistables LIT: OTT L3 TB431C, PZR LP PB457D, PZR LP PB457C and PZR LP PORV BLOC PS457E At SC066W panel: OTT Ch III Input to C3 LIT Main Control Board alarm: 00-033C, PZR PRESS LO HTRS ON CREW Respond to Main Control Board alarm and panel indications.

Actions prior to procedure entry may include: Identifies BB PI-457 failure, select MANUAL on Master PZR Pressure Controller BB PK-455A.

CREW ENTER OFN SB-008, rev 25, Instrument Malfunctions CREW 1. Check is Secondary System instrument channel is malfunctioning.

a. Determine appropriate attachment for malfunctioning channel or controller; NO, perform RNO Perform RNO: If Secondary System channel is NOT

malfunctioning, then go to step 2.

CREW 2. Check if Reactor Coolant System instrument channel of controller is malfunctioning.

a. Determine appropriate attachment for malfunctioning channel or controller from table

From Table determine:

BB PI-457 , Attachment K , PZR Op Test No.: NRC Scenario # 3 Event # 1 Page 8 of 48 Event

Description:

Pressurizer pressure channel BB PI-457 fails low Time Position Applicant's Actions or Behavior 8

Pressure Malfunction

b. Go to appropriate attachment for malfunctioning RCS channel of controller.

CRS ENTER Attachment K, PZR Pressure Malfunction

RO K1. Identify failed instrument channel

a. Compare Pressurizer pressure indications to confirm a Pressurizer pressure channel failure o BB PI-455A o BB PI-456 o BB PI-457 o BB PI-458

RO K2. Check failed Pressurizer pre ssure channel selected on PZR Pressure Control Selector Switch o BB PS-455F

RO K3. Place Pressurizer pressure master controller in manual and control pressure o BB PK-455A

RO K4. Select alternate Pressurizer pressure channel for pressure control o BB PS-455F

RO K5. Take following actions, as a ppropriate to stop pressure control transient:

a. Check Pressurizer spray valves - RESPONDING CORRECTLY

b. Check PZR control heaters - OPERABLE

c. Ensure PZR PORV - CLOSED Op Test No.: NRC Scenario # 3 Event # 1 Page 9 of 48 Event

Description:

Pressurizer pressure channel BB PI-457 fails low Time Position Applicant's Actions or Behavior 9 BOOTH CUE: If contacted as Work Week Manager, respond, "I will assemble a team."

If contacted as Call Superintendent, re spond by repeating back the information.

RO K6. Return Pressurizer pressure control to automatic o Spray valves o Control heaters o Backup heaters o Open PORV block valves o Pressurizer pressure control RO K7. Monitor Pressurizer pressure response to ensure proper control

RO K8. Check failed pressure cha nnel not used for Pressurizer pressure recorder o BB PS-455G

RO K9. Check failed pressure channel not used for OPT / OTT temperature recorder o SC TS-411E Examiner Note

Loop one is already selected. No action required.

CRS K10. Monitor the following Techni cal Specification LCOs and comply with Action Statements, as appropriate:

TS 3.3.1, Reactor Trip System Instrumentation (RTS), Table

3.3.1-1, FU 6 & 8 (Cond A and M - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to trip bistables)

TS 3.3.2, Engineered Safety Feature Actuation System Instrumentation (ESFAS), Table 3.3.2-1, FU 1d, 5d, 6e, 8b Op Test No.: NRC Scenario # 3 Event # 1 Page 10 of 48 Event

Description:

Pressurizer pressure channel BB PI-457 fails low Time Position Applicant's Actions or Behavior 10

(Cond A, D, and L entered - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to trip bistables; 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to verify P-11 in the correct state)

Others listed in Attachment K will be looked at, but no

conditions apply. At Lead Examiner's direction, acti vate Event 2 by inserting KEY 2.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 11 of 48 Event

Description:

Steam Generator pressure channel AB PI-514 fails high Time Position Applicant's Actions or Behavior 11BOOTH INSTRUCTIONS:

At Lead Examiner's direction, acti vate Event 2 by inserting KEY 2.

INDICATIONS:

Steam Generator "A" pressure meter AB PI-514A increases Steam Generator "A" steam flow meter AB FI-512A increasing Main Control Board alarm: 00-108C, SG A FLOW MISMATCH

CREW Respond to panel indications.

Actions prior to procedure entry may include: Identifies AB PI-514A failure, select MANUAL on Steam Generator "A" Main Feed Reg Valve (AE FK-510) and match steam and feed flows.

CREW ENTER OFN SB-008 rev 25, Instrument Malfunctions

CREW 1. Check is Secondary System instrument channel is malfunctioning.

a. Determine appropriate attachment for malfunctioning channel or controller

Steam Generator Pressure /

AB PI-514 failure Attachment C b. Go to appropriate attachment for malfunctioning secondary system channel.

Go to Attachment C, SG Pressure Channel Malfunction

Examiner Note: The crew may diagnose the instrument malfunction as being steam flow AB FI-512A. If this happens, Attachment A is entered. However, at step A5, steam generator Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 12 of 48 Event

Description:

Steam Generator pressure channel AB PI-514 fails high Time Position Applicant's Actions or Behavior 12 pressure is checked and the crew is redirected to Attachment C. CRS ENTER Attachment C, SG Pressure Channel Malfunction NOTE SG pressure is an input to the thermal power program. A failed steam generator pressure channel could cause the thermal power program to be inaccurate.

BOP C1. Identify failed instrument channel:

o Compare S/G pressure indications to confirm S/G pressure channel failure o AB PI-514A for S/G A o AB PI-515A for S/G A o AB PI-516A for S/G A (Indications are listed for other steam generators)

BOP C2. Check if failed S/G pressure channel used for feedwater control:

a. Identify steam flow channel compensated by failed pressure channel from table be low: (only partial table)

S/G Steam Pressure Channel Associated Steam Flow Channel A P-514 P-515 F-512 F-513 b. Check steam flow channel associated with failed steam pressure channel selected on Steam Flow Selector Switch Examiner Note

Switch AB FS-512C has F512 selected as the controlling channel.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 13 of 48 Event

Description:

Steam Generator pressure channel AB PI-514 fails high Time Position Applicant's Actions or Behavior 13

BOP C3. Place affected S/G feed reg control valves - MANUAL AE FK-510

BOP C4. Adjust affected feed wate r reg valve, as necessary, to establish steam generator level at program:

AE FK-510

BOP C5. Select alternate steam flow channel for feedwater control:

o AB FS-512C

Examiner Note: F513 will be selected BOP C6. Restore affected S/G f eed reg valve controller (AE FK-510) to - AUTO BOOTH CUE: If contacted as Work Week Manager, respond, "I will assemble a team."

If contacted as Call Superintendent, re spond by repeating back the information.

CRS C7. Monitor the following Technical Specification LCO's and comply with Action Statements, as appropriate:

TS 3.3.2, Engineered Safety Feature Actuation System Instrumentation (ESFAS), Table 3.3.2-1, FU 1e and 4e (Cond A

and D - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to trip bistables)

Others listed in Attachment C will be looked at, but no

conditions apply.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 14 of 48 Event

Description:

Steam Generator pressure channel AB PI-514 fails high Time Position Applicant's Actions or Behavior 14 At Lead Examiner's direction, acti vate Event 3 by inserting KEY 3.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 15 of 48 Event

Description:

RCP "D" frame vibration high Time Position Applicant's Actions or Behavior 15BOOTH INSTRUCTIONS:

At Lead Examiner's direction, acti vate Event 3 by inserting KEY 3.

INDICATIONS: Increasing vibration displayed on Vibration Monitoring System for Reactor Coolant Pumps (BB YI-471) Main Control Board alarms: 00-070B, RCP VIB/SYS ALERT and 00-070A, RCP VIB DANGER CREW Determine RCP "D" high vibration.

CRS ENTER ALR 00-070A rev 9A, RCP VIB DANGER (or Crew may enter OFN BB-005 rev 16, RCP Malfunctions, directly)

CRS/RO 1. Check RCP Vibration Monitor OK LEDs - ALL LIT

RO 2. Check RCP frame and shaft vibration readings: Any VERT or HORIZ frame vibration reading 5 mils OR Any VERT or HORIZ shaft reading 20 mils Examiner Note: Vibration Monitoring System for Reactor Coolant Pumps (BB YI-471) will display 5 mils on RCP "D" frame vibration monitor. Both the ALERT and DANGER lights are RED LIT Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 16 of 48 Event

Description:

RCP "D" frame vibration high Time Position Applicant's Actions or Behavior 16 CRS 3. Go to OFN BB-005, RCP Malfunctions CRS ENTER OFN BB-005 rev 16, RCP Malfunctions FOLDOUT PAGE FOR OFN BB-005

1. IMMEDIATE RCP SHUTDOWN CRITERIA IF any of the following occurs, THEN Immediately go to ATTACHMENT B, Step B1: Number 1 seal and bearing water temperature - GREATER THAN 230°F OR RCP motor bearing temperature - GREATER THAN 195°F OR RCP motor stator winding temp erature - GREATER THAN 299°F OR Frame vibration - GREATER THAN 5 MILS OR Shaft vibration - GREATER THAN 20 MILS OR A value for Number 1 seal leakoff OR total #1 seal leakoff on attachment E which directs you to go to Attachment B OR Number 1 seal leakoff - LESS THAN 0.8 GPM AND Number 1 seal inlet temperature - INCREASING OR Number 1 seal P - LESS THAN 200 PSID NOTE Foldout Page shall be monito red throughout this procedure.

CRS 1. Monitor RCP temperatures Turn on Code BB3 on the NPIS computer OR BB TR-500 CRS 2. Check if RCPs can remain running:

a. Check number 1 seal and bearing water temperatures -

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 17 of 48 Event

Description:

RCP "D" frame vibration high Time Position Applicant's Actions or Behavior 17

< 230 F b. Check motor bearing temperatures - < 195 F o Upper radial bearing o Upper thrust bearing o Lower radial bearing o Lower thrust bearing

c. Check motor stator winding temperatures - < 299 F d. Frame vibration - < 5 mils--.

NO, Perform RNO

e. Shaft vibration - < 20 mils Step 2 RNO: Go to Attachment B, Step B1

Examiner Note: Attachment B can be entered via #1 Immediate RCP Shutdown Criteria Foldout Page criteria or via Step 2RNO.

CRS ENTER Attachment B, RCP Shutdown

CRS B1. Check if reactor should be tripped:

a. Check reactor - CRITICAL

b. Check RCP's running - ONLY ONE BEING SHUTDOWN c. Check reactor power - > 48% Examiner Note: CRS may delegate remainder of OFN BB-005 Attachment B and then direct performance of EMG E-0, Reactor Trip or Safety Injection.

CRS/RO/BOP B2. Manually trip reactor and stabilize plant using EMGs while continuing with this procedure.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 18 of 48 Event

Description:

RCP "D" frame vibration high Time Position Applicant's Actions or Behavior 18

RO/BOP B3. Shutdown affected RCP(s):

a. Check RCP A being stopped -

NO , RNO: Go to step B3.c.

c. Check RCP B being stopped -

NO , RNO: Go to step B3.e.

e. Defeat Tavg and T for RCS loop with affected RCP o BB TS-412T for Tavg o BB TS-411F for T

f. Stop affected RCP(s) (RCP "D" only)

g. Number 1 seal leakoff was 6 gpm prior to securing RCP

h. Number 1 seal leakoff was within the limits of FIGURE 1 and RCP number 1 seal inlet temperature was stable and within limits prior to securing RCP

RO/BOP B4. Check if plant shutdown is required:

a. Check reactor - CRITICAL

b. Refer to Technical Specification 3.4.4

c. Place plant in Hot Standby within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> using appropriate plant procedures: GEN 00-004, Power Operation GEN 00-005, Minimum Load to Hot Standby

RO/BOP B5. Return to procedure and step in effect.

Examiner Note: RO/BOP is reintegrated into crew as performance of EMG E-0 continues. At Lead Examiner's direction, proceed to next Event.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 19 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

CRS ENTER EMG E-0 rev 22, Reactor Trip or Safety Injection

Examiner Note: EMG E-0 first time through FOLDOUT PAGE FOR EMG E-0 1. RCP TRIP CRITERIA IF all conditions listed below occur, THEN trip all RCPs:

o RCS pressure - LESS THAN 1400 PSIG o CCPs or SI pumps - AT LEAST ONE RUNNING o Operator controlled cooldown - NOT IN PROGRESS 2. SI ACTUATION CRITERIA IF either condition listed below occurs, THEN actuate SI and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION, Step 1: RCS subcooling - LESS THAN 30°F [45°F]

OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6% [33%] 3. FAULTED S/G ISOLATION CRITERIA IF any S/G pressure decreasing in an uncontrolled manner OR any S/G completely depressurized, THEN the following may be performed:

a. Close main steam isolation valves.

b. Isolate feed flow to faulted S/G(s).

c. Maintain total feed flow greater than 270,000 lbm/hr until narrow range level in at least one S/G is greater than 6% [29%].

4. RUPTURED S/G ISOLATION CRITERIA IF any S/G level increases in an uncontrolled manner OR any S/G has abnormal radiation, AND narrow range level in affected S/G(s) is greater than 6% [29%], THEN the following may be performed.

a. Close ruptured S/G AFW flow control valves.

b. IF any ruptured S/G AFW flow control valve cannot be closed AND total AFW flow to intact S/Gs can be maintained greater than 270,000 lbm/hr without associated AFW Pump, THEN perform the following:

1) Stop associated MD AFWP and place in PTL OR decrease TDAFWP speed to 2000 rpm.

2) Dispatch an Operator to locally isolate affected AFW flow control valve.

3) WHEN affected AFW flow control valve is isolated, THEN restart MD AFWP OR Restore TD AFWP speed as necessary. 5. COLD LEG RECIRCULATION CRITERIA IF RWST level decreases to less than 36%, THEN go to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION, Step 1. 6. AFW SUPPLY SWITCHOVER CRITERIA IF CST suction pressure decreases to less than 2.6 psig, THEN switch to alternate AFW suction supply.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 20 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 CAUTION: Accident conditions can cause higher than normal radiati on levels. Health Physics monitoring may be required while performing local operator actions.

NOTES o Steps 1 through 4 are immediate action steps.

o Foldout page shall be monito red throughout this procedure.

CREW 1. Verify Rx trip: a. Check all rod bottom lights - LIT

b. Ensure reactor trip breaker s and bypass breakers - OPEN c. Check neutron flux - DECREASING

CREW 2. Verify turbine trip:

a. Check the following: Main Stop valves - ALL CLOSED OR Turbine auto stop bistable light - AT LEAST TWO LIT

CREW 3. Check AC emergency busses - AT LEAST ONE ENERGIZED NB01 voltage- NORMAL NB02 voltage - NORMAL

CREW 4. Check if Safety Injection is actuated:

a. Check any indication SI is actuated - LIT; NO, perform RNO Annunciators 00-030A /

00-0031A, NF039A/B LOCA SEQ ACTUATED - LIT OR ESFAS status panel SIS section - ANY WHITE LIGHTS LIT OR Partial trip status Permissive

/ Block status panel - SI RED LIGHT LIT 4a RNO Perform the following:

1. Check SI required: RCS pressure 1830 psig OR Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 21 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

Any SG 615 psig OR CTMT pressure 3.5 psig OR RCS subcooling 30 F OR PZR level 6% 2. If SI is required, then manua lly actuate SI and go to step

6. 3. If SI is not required, then perform the following:

a. Direct operator to monitor CSF using EMG F-0, Critical Safety Function Status Trees.

b. Go to EMG ES-02, Reactor Trip Response, step 1 Examiner Note

A Transition Brief should be led by the CRS prior to performance of EMG ES-02, Reactor Trip Response.

CRS ENTER EMG ES-02 rev 18, Reactor Trip Response FOLDOUT PAGE FOR EMG ES-02

1. SI ACTUATION CRITERIA IF either condition listed below occurs , THEN actuate SI and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION, Step 1:

RCS subcooling - LESS THAN 30°F OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6%

2. AFW SUPPLY SWITCHOVER CRITERIA IF CST suction pressure decreases to less th an 2.6 psig, THEN switch to alternate AFW suction supply.

NOTE Foldout page shall be monito red throughout this procedure.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 22 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

RO 1. Check RCS cold leg temperatures Stable at or trending to 557 F for condenser steam dumps Stable at or trending to 561F for SG ARV's RO 2. Check RCS cold leg temperatures - 550 F BOP 3. Check Main generator breaker s and Exciter breaker - OPEN BOOTH INSTRUCTIONS At Lead Examiner's direction, activate Even t 4 by inserting KEY 4 at step 4 in EMG ES-02, Reactor Trip Response.

EXAMINER NOTE: One inch (~

1200 gpm) break inserted.

INDICATIONS: As the crew proceeds through EMG ES-02, Containment pressure and humidity increase. Pressurizer level will decrease.

RCS pressure will decrease.

The Crew uses EMG ES-02 Foldout page #1 criteria, SI Ac tuation: PZR level cannot be maintained > 6% to actuate Safety Injection and return to EMG E-0, step 1.

Main Control Board alarms:

ALR 00-032C, PZR LO LEV DEV ALR 00-060F, CTMT SUMP C/D LEV HI ALR 00-060E, CTMT SUMP A/B LEV HI ALR 00-032B, PZR 17% HTRS OFF LTDN ISO ALR 00-062B, AREA RAD HI

BOP 4. Check feedwater status

a. Check RCS average temperature - 564 F b. Check main feedwater pumps - TRIPPED o 00-120A, MFP A TRIP - LIT o 00-123A, MFP B TRIP -LIT c. Check main feedwater isolation valves - CLOSED o AE HIS-39 for SG A o AE HIS-40 for SG B Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 23 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

o AE HIS-41 for SG C o AE HIS-42 for SG D

d. Check total feed flow to SGs - 270,000 lbm/hr

BOP 5. Verify Instrument Air to Containment a. Ensure ESW to air compressor valves - OPEN o EF HIS-43 o EF HIS-44 b. Check air compressor breaker reset switches - CLOSED o KA HIS-2C o KA HIS-3C c. Check Instrument air pressure - 105 psig o KA PI-40 d. Check Instrument Air supply Containment isolation valve -

OPEN o KA HIS-29 RO 6. Check charging pumps - AT LEAST ONE RUNNING CCP A or CCP B or NCP

RO 7. Check Charging System aligned for normal injection a. Check CCPs - ANY RUNNING; NO, perform RNO RNO a. Go to step 7.d.

7.d. Check Charging pumps to regenerative heat exchanger Containment isolation valves - OPEN o BG HIS-8105 o BG HIS-8106 7.e. Check Regenerative heat exch anger to loop cold leg valves - ONLY ONE OPEN BG HIS-8146 for loop 1 OR BG HIS-8147 for loop 4 Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 24 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

RO 8. Check charging flow - ESTABLISHED o BG FI-121A RO 9. Check all Control Rods - FULLY INSERTED

RO 10. Check PZR level - GREATER THAN 17%

Examiner's note: PZR level may be > 17% at this time, but it has been decreasing since inse rtion of the 1 inch break. Examiner's note:

PZR level has been decreasing; RCS pressure has been decreasing; Containment pressure and humidity are increasing. Main Control Board alarms are actuating.

ALR 00-032C, PZR LO LEV DEV ALR 00-060F, CTMT SUMP C/D LEV HI ALR 00-060E, CTMT SUMP A/B LEV HI ALR 00-032B, PZR 17% HTRS OFF LTDN ISO ALR 00-062B, AREA RAD HI

Crew diagnoses a LOCA, and uses FOLDOUT PAGE FOR EMG ES-02 1. SI ACTUATION CRITERIA IF either condition listed below occurs , THEN actuate SI and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION, Step 1:

RCS subcooling - LESS THAN 30°F OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6%

Crew actuates Safety Injection and transitions back to EMG E-0, Reactor Trip or Safety Injection, step 1.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 25 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

CRS ENTER EMG E-0 rev 22, Reactor Trip or Safety Injection

Examiner Note: EMG E-0 second time through, LOCA identified. FOLDOUT PAGE FOR EMG E-0 1. RCP TRIP CRITERIA IF all conditions listed below occur, THEN trip all RCPs:

o RCS pressure - LESS THAN 1400 PSIG o CCPs or SI pumps - AT LEAST ONE RUNNING o Operator controlled cooldown - NOT IN PROGRESS 2. SI ACTUATION CRITERIA IF either condition listed below occurs, THEN actuate SI and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION, Step 1: RCS subcooling - LESS THAN 30°F [45°F]

OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6% [33%] 3. FAULTED S/G ISOLATION CRITERIA IF any S/G pressure decreasing in an uncontrolled manner OR any S/G completely depressurized, THEN the following may be performed:

d. Close main steam isolation valves.

e. Isolate feed flow to faulted S/G(s).

f. Maintain total feed flow greater than 270,000 lbm/hr until narrow range level in at least one S/G is greater than 6% [29%].

4. RUPTURED S/G ISOLATION CRITERIA IF any S/G level increases in an uncontrolled manner OR any S/G has abnormal radiation, AND narrow range level in affected S/G(s) is greater than 6% [29%], THEN the following may be performed.

c. Close ruptured S/G AFW flow control valves.

d. IF any ruptured S/G AFW flow control valve cannot be closed AND total AFW flow to intact S/Gs can be maintained greater than 270,000 lbm/hr without associated AFW Pump, THEN perform the following:

1) Stop associated MD AFWP and place in PTL OR decrease TDAFWP speed to 2000 rpm.

2) Dispatch an Operator to locally isolate affected AFW flow control valve.

3) WHEN affected AFW flow control valve is isolated, THEN restart MD AFWP OR Restore TD AFWP speed as necessary. 5. COLD LEG RECIRCULATION CRITERIA IF RWST level decreases to less than 36%, THEN go to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION, Step 1. 6. AFW SUPPLY SWITCHOVER CRITERIA IF CST suction pressure decreases to less than 2.6 psig, THEN switch to alternate AFW suction supply.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 26 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 CAUTION: Accident conditions can cause higher than normal radiati on levels. Health Physics monitoring may be required while performing local operator actions.

NOTES o Steps 1 through 4 are immediate action steps.

o Foldout page shall be monito red throughout this procedure.

CREW 1. Verify Rx trip: a. Check all rod bottom lights - LIT

b. Ensure reactor trip breaker s and bypass breakers - OPEN c. Check neutron flux - DECREASING

CREW 2. Verify turbine trip:

a. Check the following: Main Stop valves - ALL CLOSED OR Turbine auto stop bistable light - AT LEAST TWO LIT

CREW 3. Check AC emergency busses - AT LEAST ONE ENERGIZED NB01 voltage- NORMAL NB02 voltage - NORMAL

RO 4. Check if Safety Injection is actuated:

a. Check any indication SI is actuated - LIT Annunciators 00-030A /

00-0031A, NF039A/B LOCA SEQ ACTUATED - LIT OR ESFAS status panel SIS section - ANY WHITE LIGHTS LIT OR Partial trip status Permissive

/ Block status panel - SI RED LIGHT LIT

b. Check both trains of SI actuated o 00-030A, NF039A LOCA SEQ ACTUATED - LIT o 00-031A, NF039B LOCA SEQ ACTUATED - LIT Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 27 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 CAUTION If offsite power is lost after SI reset, manual action may be required to restore safeguards equipment to the required configuration.

CREW 5. Check if SI is required: SI was manually actuat ed AND was required OR RCS pressure is currently or has been 1830 psig OR Any S/G pressure is currently or has been 615 psig OR CTMT pressure is currently or has been 3.5 psig OR RCS subcooling is currently or has been 30 F PZR level is currently or has been 6% Examiner Note:

As RCS pressure decreases to < 1400 psig, Foldout Page item #1, RCP Trip Criteria will be used to tr ip the running RCP's (A, B and C).

BOP 6. Check Main Generator breakers & Exciter breaker - OPEN o MA ZL-3A and 4A o MB ZL-2 CRS 7. Verify automatic actions using Attachment F, Automatic Signal Verification CRS Directs performance of EMG Attachment, F, Automatic Signal Verification RO/BOP EMG Attachment, F, Automatic Signal Verification RO/BOP F1. Verify feedwater isolation Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 28 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 Critical Task: Close Containment isolation valves such that at least one valve is closed on each critical phase-A penetration before the end of the scenario.

Success: Use of SB HS-47 and SB HS-48 to actuate CISA. ESFAS status panel CISA lights - WHITE LIGHTS LIT

RO/BOP F2. Verify CISA (CT) a. Check ESFAS status panel CISA section - ALL WHITE LIGHTS LIT; NO, perform RNO o Red train o Yellow train RNO Perform the following:

1.If Containment Isolation Phase A has not actuated, then

manually actuated Containm ent Isolation Phase A.

o SB HS-47 o SB HS-48 2. If any CISA valve not closed, then manually close valve. If valve(s) cannot be closed, th en manually or locally isolate affected Containment penetration. Refer to Attachment B, Valves Closed by Containment Isolation Signal Phase A.

RO/BOP F3. Verify AFW pumps running Critical Task: Establish flow from at le ast one Centrifugal Charging Pump before a needless red or orange path condition exists OR before the end of the scenario.

Success: Recognize both SIPs have tripped. Recognize that CCP "A" is not running No BIT flow on meter EM FI-917A. There is no High Head /Intermediate Head ECCS injection. (Recall CCP "B" is not available.)

Using handswitch BG HIS-1A, start CPP "A". Pumps starts and BIT flow can be verified on EM FI-917A.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 29 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

RO/BOP F4. Verify ECCS pumps running (CT) a. Check CCPs - BOTH RUNNING; NO: Perform RNO F4a RNO F4a: Manually start pumps o BG HIS-1A (CCP A handswitch) o BG HIS-2A (CCP B handswitch - currently in PTL)

b. Check SI pumps - BOTH RUNNING; NO, Perform RNO F4b RNO F4b: Manually start pumps. Determine pumps are tripped and unable to be started.

Dispatch building watch to investigate.

c. Check RHR pumps - BOTH RUNNING BOOTH CUE: If dispatched as building watch to investigate SIP pumps, respond "I will investigate."

Additional cues: If dispatched to SIP breakers: At SIP breakers - an overcurrent flag is dropped.

If contacted as WWM, respond, "I will assemble a team."

RO/BOP F5. Verify CCW alignment RO/BOP F6. Check ESW pumps both running RO/BOP F7. Check CTMT fan c oolers running in slow speed RO/BOP F8. Verify CPIS RO/BOP F9. Verify CRVIS RO/BOP F10. Verify main steamline isolation not required RO/BOP F11. Verify CTMT spray not required RO/BOP F12. Verify ECCS flow Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 30 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 RO/BOP F13. Verify AFW valve alignment.

RO/BOP F14. Verify SI valves Properly aligned RO/BOP F15. Check if NCP should be stopped RO/BOP F16. Return to procedure & step in effect BOP 8. Check total AFW flow - > 270,000 lbm/hr

BOP 9. Check RCS cold leg temperature Stable at or trending to 557 F for condenser steam dumps; NO, perform RNO Stable at or trending to 561F for SG ARVs RNO a. If temperature is less than setpoint and decreasing, then perform the following:

1.Stop dumping steam.

2. If any MSIV is open, then close Main Turbine Stop and

Control Valves Startup Drains o AC HIS-134 3. If cooldown continues, then control total feed flow to limit RCS cooldown, maintain total feed flow > 270,000 lbm/hr until

narrow range level > 6% [29%] in at least one SG. 4. If cooldown continues die to excessive steam flow then close

main steamline isolation valves, bypass valves, and drain valves.

b. If temperature is greater t han setpoint and increasing, then perform one of the following: Dump steam to condenser Dump steam using S/G ARVs

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 31 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

RO/BOP 10. Establish SG pressure control

a. Check condenser - AVAILABLE o C LIT o MSIV - OPEN o Circulating water pumps - RUNNING

b. Place steam header pressure control in Manual o AB PK-507

c. Manually set steam header pressu re control output to zero o AB PK-507

d. Place steam dump select switch in STEAM PRESS position o AB US-500Z

e. Place steam header pressure control in Automatic o AB PK-507

RO 11. Check PZR PORVs a. Check PZR PORVS - CLOSED o BB HIS-455A o BB HIS-456A b. Power to block valves - AVAILABLE o BB HIS-8000A o BB HIS-8000B

c. RCS pressure - <2185 psig

RO 12. Check normal PZR spray valves - CLOSED o BB ZL-455B o BB ZL-455C

RO 13. Check PZR safety valves - CLOSED o BB ZL-8010A o BB ZL-8010B o BB ZL-8010C NOTE Seal injection flow shall be maintained to all RCPs. RO/BOP 14. Check is RCPs should be stopped:

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 32 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

a. Check RCPs - ANY RUNNING, NO, perform RNO

b. Check RCS pressure - < 1400psig

c. Check ECCS pumps - AT LEAST ONE RUNNING CCP or SI pump d. Check operator controlled cooldown - NOT IN PROGRESS e. Stop all RCPs RNO: Go to step 15 CRS 15. Direct operator to monitor Cr itical Safety Functions using EMG F-0, Critical Safety Function Status Trees (CSFST)

BOP 16. Check if SG are not faulted: a. Check pressure in all SGs -

o No SG pressure decreasing in an uncontrolled manner o No SG completely depressurized

CREW 17. Check is SG tubes are intact: Direct Health Physics to survey steamlines in Area 5 of the Auxiliary Building Condenser air discharge radiation - NORMAL BEFORE ISOLATION

o GEG 925 SG blowdown and sample radiation - NORMAL BEFORE ISOLATION o BML 256 o SJL 026 Turbine driven auxiliary feedwater pump exhaust radiation - NORMAL o FCT 381 Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 33 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 SG steamline radiation - NORMAL o ABS 114 for SG A o ABS 113 for SG B o ABS 112 for SG C o ABS 111 for SG D BOOTH CUE: If called to survey the steam lines in Area 5, respond: I will survey the steam lines in Area 5.

BOP 18. Check SG levels - IN CREASING IN A CONTROLLED MANNER o Narrow range o Wide range

CREW 19. Check if RCS is intact in Containment: a. Containment radiation - NORMAL BEFORE ISOLATION o GTP 311 o GTI 312 o GTG 313 o GTP 321 o GTI 322 o GTP 323 o GTA 591 o GTA 601 b. Containment pressure - NORMAL; NO , perform RNO o GN PI-934 o GN PI-935 o GN PI-936 o GN PI-937 o GT PDI-40 o GN PR-934 c. Containment sump level - NORMAL; NO, perform RNO o EJ LI-7 o EJ LI-8 o EJ LR-6 o LE LI-9 o LF LI-10 Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 34 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

RNO, Perform the following:

1. Ensure BIT inlet and outlet valves are open o EM HIS-8803A o EM HIS-8803B o EM HIS-8801A o EM HIS-8801B

2. Go to EMG E-1, Loss of Reactor or Secondary Coolant, step

1. Examiner Note

A Transition Brief should be led by the CRS prior to performance of EMG E-1, Loss of Reactor or Secondary Coolant.

CRS ENTER EMG E-1 rev 18A, Loss of Reactor or Secondary Coolant Examiner Note: EMG E-1 continued on next page.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 35 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 FOLDOUT PAGE FOR EMG E-1 1. SI REINITIATION CRITERIA IF either condition listed below occurs, THEN start ECCS pumps as necessary to reestablish RCS subcooling and PZR level. RCS subcooling - LESS THAN 30°F [45°F] OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6% [33%] 2. RCP TRIP CRITERIA IF all conditions listed below occur, THEN trip all RCPs:

o RCS pressure - LESS THAN 1400 PSIG o CCPs or SI pumps - AT LEAST ONE RUNNING o Operator controlled cooldown - NOT IN PROGRESS 3. SECONDARY INTEGRITY CRITERIA IF all conditions listed below are satisfied, THEN go to EMG E-2, FAULTED STEAM GENERATOR ISOLATION, Step 1:

o Any S/G pressure is decreasing in an uncontrolled manner OR any S/G has completely depressurized o Affected S/G has NOT been isolated using EMG E-2, FAULTED STEAM GENERATOR ISOLATION o Affected S/G is NOT needed for RCS cooldown 4. EMG E-3 TRANSITION CRITERIA IF any S/G level increases in an uncontrolled manner OR any S/G has abnormal radiation, THEN start ECCS pumps as necessary and go to EMG E-3, STEAM GENERATOR TUBE RUPTURE, Step 1. 5. COLD LEG RECIRCULATION CRITERIA IF RWST level decreases to less than 36%, THEN go to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION, Step 1.

6. AFW SUPPLY SWITCHOVER CRITERIA IF CST suction pressure decreases to less than 2.6 psig, THEN switch to alternate AFW suction supply. NOTES o Foldout page shall be monito red throughout this procedure.

o Seal injection flow shall be maintained to all RCPs.

RO 1. Check if RCP's should be stopped: a. Check RCPs - ANY RUNNING, NO , perform RNO RNO: Go to step 2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 36 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

BOP 2. Check if SGs are not faulted:

a. Check pressures in all SGs -

o No SG pressure decreasing in an uncontrolled manner o No SG completely depressurized

BOP 3. Check intact SG levels:

a. Check narrow range level in at least one SG - > 6% [29%]

b. Control feed flow to maintain narrow range level in all SGs between 6% [29] and 50% CAUTION If offsite power is lost after SI reset, manual action may be required to restore safeguards equipment to the required configuration.

RO 4. Reset SI o SB HS-42A o SB HS-43A

RO 5. Reset Containment Isolation Phase A and B o SB HS-56 for phase A o SB HS-53 for phase A o SB HS-55 for phase B o SB HS-52 for phase B CAUTION If steamlines in Area 5 of Auxiliary Building are not intact, extreme caution will be necessary when performing local surveys.

CREW 6. Determine secondary radiation levels: a. Direct Health Physics to survey steamlines in Area 5 of Aux

Bldg

b. Check SG sampling - ISOLATED

c. Ensure SI - RESET

d. Check instrument air header pressure - > 105 psig o KA PI-40 e. Open CCW to Radwaste System isolation valves o EG HS-69 Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 37 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

o EG HS-70 d. Open all SG sample isolation valves o BM HIS-65 for SG A o BM HIS-35 for SG A o BM HIS-66 for SG B o BM HIS-36 for SG B o BM HIS-67 for SG C o BM HIS-37 for SG C o BM HIS-68 for SG D o BM HIS-38 for SG D g. Direct Chemistry to sample all SGs for activity BOOTH CUE: If called as Health Physics, respond I will survey the Area 5 steamlines.

CREW 7. Check secondary radiation - NORMAL:

a. Condenser air discharge radiation - NORMAL BEFORE ISOLATION o GEG 925 b. SG blowdown radiation - NORMAL BEFORE ISOLATION o BML 256 c. SG sample radiation o SJL 026 o Sample results d. Turbine driven auxiliary feedwater pump exhaust radiation - NORMAL o FCT 381 e. SG steamline radiation - NORMAL o ABS 114 for SG A o ABS 113 for SG B o ABS 112 for SG C o ABS 111 for SG D o Local surveys

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 38 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 CAUTION If any PZR PORV opens because of high PZR pressure, the PORV shall be monitored to ensure it recloses after pressure decreases to less than 2335 psig.

RO 8. Check PZR PORVs and block valves: a. Power to block valves - AVAILABLE o BB HIS-8000A o BB HIS-8000B b. PZR PORVs - CLOSED o BB HIS-455A o BB HIS-456A c. RCS pressure - LESS THAN 2185 psig

RO/BOP 9. Establish Instrument Air to Containment: a. Ensure ESW to air compressor valves - OPEN o EF HIS-43 o EF HIS-44

b. Reset and close air compressor breaker reset switches o KA HIS-2C o KA HIS-3C c. Check Instrument Air pressure - > 105 psig o KA PI-40 d. Check PZR pressure master c ontroller - < 50% output signal o BB PK-455A e. Open Instrument Air supply Containment isolation valve o KA HIS-29

RO 10. Check if ECCS flow should be reduced:

a. RCS subcooling - > 30 F [45F]; NO , perform RNO

b. Secondary heat sink Total feed flow to intact SGs - > 270, 000 lbm/hr OR Narrow range level in at l east one intact SG - > 6%

[29%] c. RCS pressure - stable or increasing

d. PZR level - > 6% [33%]

RNO d Perform the following:

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 39 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

1. Try to stabilize RCS pressure using normal PZR spray.

2. Go to step 11.

RO 11. Check if Containment Spray should be stopped: a. Check spray pumps - ANY RUNNING; NO perform RNO RNO a. Observe CAUTION prior to step 12 and go to step 12. CAUTION After RHR pumps have been stopped, RCS pressure shall be monitored for RHR pump restart criteria.

RO 12. Check if RHR pump s should be stopped: a. Check RHR pumps - ANY RUNNING

b. Check RCS pressure:

1. Pressure - > 325 psig

2. Pressure - STABLE or INCREASING c. Check RHR system - ALIGNED FOR INJECTION

d. Stop RHR pumps and place in standby o EJ HIS-1 o EJ HIS-2 e. Check RCS pressure >325 psig during subsequent recovery actions RNO 12. a. Go to step 10 RNO 12.b. 2 If RCS pressure is ex pected to decrease below 325 psig within 2.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />, then go to Step 10.

RNO 12.e. If RCS pressure decreases in an uncontrolled manner to less than 325 psig, then manually restart RHR pumps to provide injection to the RCS.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 40 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

RO/BOP 13. Check RCS and SG pressures:

a. Check RCS pressure - STABLE OR DECREASING

b. Check pressure in all SGs - STABLE OR DECREASING

RO/BOP 14. Check if Diesel Generators should be stopped:

a. Check NB01 - ENERGIZED BY OFFSITE POWER

b. Depress START/RESET pushbutton for diesel generator

NE01 o KJ HS-8A c. Depress STOP pushbutton fo r diesel generator NE01 o KJ HS-8A d. Check NB02 - ENERGIZED BY OFFSITE POWER

e. Depress START/RESET pushbutton for diesel generator

NE02 o KJ HS-108A

f. Depress STOP pushbutton fo r diesel generator NE02 o KJ HS-108A

g. Place all previously running diesels in standby using SYS KJ-121, Diesel Generator NE01 and NE02 Lineup for Automatic Operation, while cont inuing with this procedure BOOTH CUE: If contacted as building watch, respond "I will place diesels in standby using SYS KJ-121."

BOOTH INSTRUCTION

At KJ-121 Soft Panel for EDG "A", acknowledge any local alarms. At NE107, depress ENGINE SHUTDOWN RESET pushbutton KJ HS-12.

At KJ-12 Soft Panel for EDG "B", acknowledge any local alarms. At NE106, depress ENGINE SHUTDOWN RESET pushbutton KJ HS-112.

Report back to Control Room when tasks completed.

RO 15. Load equipment on energized AC emergency busses: a. Locally reset and close boric acid transfer pump breakers o NG01AHF4 for pump A o NG02AAF4 for pump B

b. Locally reset and close em ergency borate valve breaker Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 41 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 o NG04CPF2 for BG HV-8104 BOOTH CUE / INSTRUCTION

CUE: Respond as building watches: "I will reset and close (boric acid and transfer pump breakers) NG01AHF4 and NG02AAF4. I will reset and close (emergency borate valve breaker) NG04CPF2."

INSTRUCTIONS: Insert Key 5 When actions completed, report to Control Room (breaker s are reset etc)

RO/BOP 16. Close Non - Class 1E battery charger breakers o PK HIS-2 for PK-21 o PK HIS-3 for PK-22 o PK HIS-4 for PK-23 o PK HIS-5 for PK-24 RO/BOP 17. Check all non-class 1E AC busses and load centers - ENERGIZED BY OFFSITE POWER

RO/BOP 18. Place Hydrogen Analyzers in service: a. On RL011, place power lockout switches for Containment sample valves in NON-ISO position o GS HIS-40 o GS-HIS-41 o GS-HIS-42 o GS HIS-43

b. On RL011, open one Hydrogen Analyzer supply inner Containment isolation valve per train o GS HIS-13 or GS HIS-14 for red train o GS HIS-4 or GS HIS-5 for yellow train c. On RL011, open remaining Hydrogen Analyzer Containment

isolation valves o GS HIS-12 o GS HIS-17 o GS HIS-18 Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 42 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

o GS HIS-3 o GS HIS-8 o GS HIS-9 d. On RL020, place Containment Hydrogen Analyzer control switches in ANALYZE position o GS HIS-16A o GS HIS-11A

f. On RL020, monitor Containmen t Hydrogen concentration o GS AI-19 o GS AI-10

RO 19. Verify Cold Leg Recirculation capability

a. Check ESFAS status panel SIS section - NO AMBER LIGHTS LIT o Red train o Yellow train

RO/BOP 20. Check Fuel/Auxiliary Building radiation - NORMAL a. Shift Fuel/Auxiliary Building exhaust sample to

EMERGENCY o GG HIS-27 o GG HIS-28

b. Direct Health Physics to surv ey Fuel and Auxiliary Buildings with priority being pipe pene tration areas and piping tunnels c. Check Fuel/Auxiliary Building radiation monitors - NONE

ALARMING o GGP 271 o GGI 272 o GGG 273 o GGP 281 o GGI 282 o GGG 283 o GLP 604 o Area radiation monitors Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 43 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 BOOTH CUE: Respond as Health Physics, "I will survey Fuel and Auxiliary Buildings with priority being pipe penetr ation areas and piping tunnels."

CRS 21. Obtain samples: a. Request Chemistry to obtain boron and activity samples for the following:

o RCS o PZR liquid space BOOTH CUE: Respond as Chemistry, "I will obtain boron and activity samples for the RCS and PZR liquid space."

CRS 22. Initiate Evaluation of plant status: a. Evaluate plant equipment to ensure availability

b. Start additional plant equipment as necessary to assist in recovery BOOTH CUE: Call as Shift Manager and report that the Shift Manager will complete EMG E-1, step 22.

CRS 23. Check if RCS cooldown and Depressurization is required:

a. Check RCS pressure - > 325 psig

b. Go to EMG ES-11, Post LOCA Cooldown and

Depressurization, step 1 Examiner Note

A Transition Brief should be led by the CRS prior to performance of EMG ES-11, Post LOCA Cool down and Depressurization.

CRS ENTER EMG ES-11, rev 17, Post LOCA Cooldown and Depressurization Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 44 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 FOLDOUT PAGE FOR EMG ES-11 1. SI REINITIATION CRITERIA IF either condition listed below occurs, TH EN start ECCS pumps as necessary to reestablish RCS subcooling and PZR level. RCS subcooling - LESS THAN 30°F [45°F] OR Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6% [33%] 2. SECONDARY INTEGRITY CRITERIA IF all conditions listed below are sati sfied, THEN go to EMG E-2, FAULTED STEAM GENERATOR ISOLATION, Step 1:

o Any S/G pressure is decreasing in an uncontrolled manner OR any S/G has completely depressurized o Affected S/G has NOT been isolat ed using EMG E-2, FAULTED STEAM GENERATOR ISOLATION o Affected S/G is NOT needed for RCS cooldown 3. EMG E-3 TRANSITION CRITERIA IF any S/G level increases in an uncontrolled manner OR any S/G has abnormal radiation, THEN start ECCS pumps as necessary and go to EMG E-3, STEAM GENERATOR TUBE RUPTURE, Step 1. 4. COLD LEG RECIRCULATION CRITERIA IF RWST level decreases to less than 36%, THEN go to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION, Step 1. 5. AFW SUPPLY SWITCHOVER CRITERIA IF CST suction pressure decreases to less th an 2.6 psig, THEN switch to alternate AFW suction supply.

CAUTION If offsite power is lost after SI reset, manual action may be required to restore safeguards equipment to the required configuration. NOTE Foldout page shall be monitored throughout this procedure.

CRS 1. Reset SI, step previously performed CRS 2. Reset Containment Isolation Phase A and B , step previously performed Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 45 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

CRS 3. Establish Instrument Air to Containment, step previously performed CRS 4. Check if Diesel Generators should be stopped, step previously performed CAUTION PZR heaters shall not be energized until PZR water level indicates greater than minimum recommended by the TSC to ensure heaters are covered.

CRS/RO 5. Align PZR heaters: a. Place PZR B/U heater switches in trip and PZR CTRL heaters in PTL position o BB HIS-51A o BB HIS-52A o BB HIS-50

b. Close supply breaker for PG 21 o PG HIS-19

c. Close supply breaker for PG 22 o PG HIS-21 d. Direct TSC to determine minimum PZR water level that will

ensure heaters are covered.

BOOTH CUE: If contacted as Shift Manager or TSC, respond, "Direct the TSC to determine the minimum PZR water level that will ensure the PZR heaters are covered."

CRS 6. Load equipment on energized AC emergency busses, step previously performed

CRS 7. Close Non-Class 1E battery charger breakers, step previously performed Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 46 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

CRS 8. Check all Non-Class 1E AC busses and load centers - ENERGIZED BY OFFSITE POWER, step previously performed CAUTION After RHR pumps have been stopped, RCS pressure shall be monitored for RHR pump restart criteria

CRS 9. Check if RHR pumps should be stopped a. Check RHR pumps - ANY RUNNING

b. Check RCS pressure:

1. Pressure - > 325 psig

2. Pressure - STABLE or INCREASING c. Check RHR system - ALIGNED FOR INJECTION

d. Stop RHR pumps and place in standby o EJ HIS-1 o EJ HIS-2 e. Check RCS pressure >325 psig during subsequent recovery actions RNO 9. a. Go to step 10 RNO 9.b. 2 If RCS pressure is exp ected to decrease below 325 psig within 2.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />, then go to Step 10.

RNO 9.e If RCS pressure decreases in an uncontrolled manner

to less than 325 psig, then m anually restart RHR pumps to provide injection to the RCS.

CRS 10.Check intact SG levels, step previously performed

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 47 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9

CREW 11. Check if Condenser Air Removal should be returned to normal:

a. Check the following:

o Main steamline isolation valves - AT LEAST ONE OPEN o Condensate pumps - AT LEAST ONE RUNNING o Circulating water pumps - AT LEAST ONE RUNNING o Condenser vacuum - ESTABLISHED b. Open Condenser Air Removal fan discharge dampers o GE HIS-103 o GE HIS-104 c. Start desired number of Condenser Vacuum Pumps CG HIS-1 CG HIS-2 CG HIS-3 d. Open Condenser Air Removal Filtration System supply dampers o GE HIS-101 o GE HIS-102 e. Ensure one Condenser Air Removal fan is running GE HIS-82 GE HIS-83 NOTE If high steam pressure rate setpoint (100psi / 50sec) is exceeded after low steamline pressure SI signal is blocked, main steamline isolation will occur.

RO 12. Check if low steamline pressu re SI should be blocked:

a. Check RCS pressure - < 1970 psig o P-11 light - LIT b. Block low steamline pressure SI o SB HS-9 o SB HS-10 Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # NA Page 48 of 48 Event

Description:

Automa tic Signal Verification Time Position Applicant's Actions or Behavior Appendix D NUREG 1021 Revision 9 NOTE Shutdown margin shall be monitored during RCS cooldown.

RO 13. Initiate RCS cooldown to Cold Shutdown:

a. Maintain cooldown rate in RCS cold legs - < 100 F/ hr b. Check RHR system - IN SHUTDOWN COOLING MODE;

NO , perform RNO 13b RNO 13b. Go to step 13.d 13.d. Dump steam to condenser from intact SG (If NO , perform RNO 13.d.)

RNO 13.d. Dump steam using intact SG ARVs 13.d.1. Ensure STM HDR PRESS CRTL in manual o AB PK-507 13.d.2. Adjust STM HDR PRESS CRTL to achieve desired

cooldown rate o AB PK-507 13.d.3. Check P-12 interlock - ACTUATED (If NO , perform RNO)

RNO13.d.3. When P-12 interlock actuates, then do step 13.d.4. Continue with step 14.

13.d.4. Place both STEAM DUMP BYPASS INTERLOCK switches to BYP/INTLK o AB HS-63 o AB HS-64 Terminate scenario once Cooldown is started or at Lead Examiner's direction.

________________________

______________________________________________ ES-301 Transient and Event Checklist Form ES-301-5 Facility: Wolf Creek Date of Exam: 12-15-09 Operating Test No.:

A P P L I C A N T E V E N T T Y P E Scenarios 1 2 3 (Backup) 4 T O T A L M I N I M U M(*)

CREW POSITION CREW POSITION CREW POSITION CREW POSITION S R O A T C B O P S R O A T C B O P S R O A T C B O P S R O A T C B O P R I U RO SRO-I SRO-U RX 2 0 0 0 0 1 1 1 0 NOR 0 1 0 0 0 1 1 1 1 I/C 14 2346 1235 6 135623 6 4 4 2 MAJ 35 5 4 4 4 3 2 2 1 TS 0 23 12 0 0 2 0 2 2 RO SRO-I SRO-U RX 1 1 0 NOR 1 1 1 I/C 4 4 2 MAJ 2 2 1 TS 0 2 2 RO SRO-I SRO-U RX 1 1 0 NOR 1 1 1 I/C 4 4 2 MAJ 2 2 1 TS 0 2 2 RO SRO-I SRO-U RX 1 1 0 NOR 1 1 1 I/C 4 4 2 MAJ 2 2 1 TS 0 2 2 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the "at-the-controls (ATC)" and "balance-of-plant (BOP)" positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position.

If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicant's competence count toward the minimum requirements specified for the applicant's license level in the right-hand columns.

________________________

______________________________________________ ES-301 Competencies Checklist Form ES-301-6 Facility: Wolf Creek Date of Examination: 12-15-09 Operating Test No.

Competencies APPLICANTS RO (ATC)

SRO-I SRO-U RO SRO-I (CRS)

SRO-U RO SRO-I SRO-U RO SRO-I SRO-U SCENARIO SCENARIO SCENARIO SCENARIO 1 2 3 4 1 2 3 4 1 2 3 4 1 2 3 4 Interpret/Diagnose Events and Conditions 1 245 6 1456 allallall Comply With and Use Procedures (1) 12 124 13456 allallall Operate Control

Boards (2) 123 45 124 6 1456 Communicate and Interact 123 5 124 56 13456 allallall Demonstrate Supervisory Ability (3) allallall Comply With and Use Tech. Specs. (3) 1 2312 Notes: (1) Includes Technical Specification compliance for an RO.

(2) Optional for an SRO-U.

(3) Only applicable to SROs.

Instructions:

Check the applicants' license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.