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2012 LaSalle County Station Initial License Examination Proposed Scenarios
	ML12289A228
Person / Time
Site:	LaSalle
Issue date:	10/22/2012
From:	McNeil D R; NRC/RGN-III/DRS/OLB
To:	; Exelon Generation Co
References
	Download: ML12289A228 (123)
	v • d • e

SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

LaSalle County Station DYNAMIC SIMULATOR SCENARIO GUIDE ILT Class 11

-1 NRC Exam Turbine BPV Surveillance , RPIS Failure, VT Fan Trip, Power Ramp U p, FCV Fails Open, Loss of SAT, EHC Leak , Loss of UAT, 1A EDG Failure, Loss of HP Injection, TAF Blowdown 11-1-1 Rev. 0 8/3 1/2012

DEVELOPED BY:

Instructor Date VALIDATED BY:

SME/Instructor Date REVIEWED BY:

Shift Operations Supervisor Date APPROVED BY:

Operations Training Manager Date NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 2 of 31 Facility: LaSalle County Station

Scenario No.:

11-1-1 PURPOSE OF SCENARIO Examine the ILT candidate's ability to operate the plant in normal, abnormal, and emergency conditions.

SUMMARY

OF EVENTS Initial Conditions:

The plant is operating at 85%

power. RCIC is Out

-of-Service. C VT Exhaust fan is Out-of-Service. A partial LOS-TG-M 4 is needed for PMT. Suppression Pool Temperature is 93F. 1. Perform Turbine Bypass Valve Surveillance, LOS-TG-M4, for Turbine Bypass Valve #2.

2. Loss of a single fully-inserted rod position indicator. The ATC and SRO perform LOA

-RM-101. ATC gives the rod an insert signal but position indication is not recovered. SRO must determine T.S. 3.1.3 applies and declares the rod INOP. The ATC electrically disarms the rod. 3. SM call to SRO gives direction to crew to raise RR Flow to normal rated conditions. SRO directs ATC to raise power at 300 MWe/hour up to 100% power. 4. Loss of 1VT02CA. With only 1 TB Exhaust Fan operating, the BOP must secure one TB Supply Fan per LOA-VT-101. Response includes stack WGRM flow verification.

5. While raising power A RR FCV will continue to open until locked up by operator IAW LOA-RR-101. Resultant flow mismatch may require T.S. evaluation.

6. Loss of SAT. Crew responds IAW LOA

-AP-101. SRO references TS 3.8.1 For loss of an offsite source 7. Loss of EHC fluid pressure. An EO is dispatched to investigate. Discovery of a leak on the running EHC pump that can be isolated. EHC standby pump fails to auto start and BOP must take action to stop falling pressure per the LOR for EHC fluid tank low level.

8. Loss of UAT resulting in a Unit Scram. EDG 1A fails to start. The crew may restore power to 142Y with crosstie from Unit 2. One SRV will stick open after lifting, which results in a loss of RPV inventory.

9. Operator s start all available high pressure injection. The HPCS pump does not auto

-start. After it is started, its discharge piping breaks inside containment two minutes later. As a result, RPV water level lowers to TAF in approximately 13 minutes. 10. ADS Timers will fail to auto initiate.

The crew may recognize this failure. However, they must manually open the ADS SRVs.

When RPV Pressure lowers, the crew will inject with low pressure systems to restore RPV water level.

After Blowdown and RPV level has been restored, terminate scenario

. Critical Step s: 1) Take action to start HPCS to restore reactor water level to within specified bands.

2) If level cannot be restored and held above

-150" (inches) initiate ADS. APPROXIMATE SCENARIO RUN TIME 1.5 hour5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 3 of 31 SER 3-05 1. Monitoring Plant Conditions and Indications Closely

2. Controlling Plant Evolutions Precisely

3. Conservative Bias to Plant Operations

4. Effective Teamwork

5. Solid Understanding of Plant Design and Interrelationships SOER 10-2 1. Oversight ensures proper focus

2. Equipment restoration risk evaluation

3. Preparation for high risk evolution

4. Control Room resources adequate for EOP response

5. Sufficient engagement of other s in decision making

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 4 of 31 INITIAL SIMULATOR SETUP/REQUIRED DOCUM ENTATION 1. Reset to IC193, 100% power (NOTE: IC193 was saved from the 0 6/1 2/12 version of IC 81)

2. Place simulator in RUN.

3. Reduce Recirc Flow until Reactor Power is approximately 85%.

4. Adjust VARS to 100 Lagging.

5. Set CRD Drive Pressure 250

-260 psig. 6. Insert commands for this scenario

. (Commands in CAEP File: NRC Scenario 11 1.cae) ir f iatsp 9 3 ( Raises Suppression Pool Temperature to 9 3 F) irf iatlake 98.5 ( Raises Lake Temperature to 98.5 F) ior k1l28jcm close (RCIC Outbd Stm Isol F008 Switch to CLOSE) ior q1l28lrm off (RCIC Outbd Stm Isol F008 Red/Open light off

) ior k1l26jcm close (RCIC Stm Line Warmup F0 76 Switch to CLOSE) ior q126lgm off (RCIC Stm Line Warmup F0 76 Green/Closed light off

) ior k1l27jcm close (RCIC Inbd Stm Isol F0 63 Switch to CLOSE) ior q1l27lrm off (RCIC Inbd Stm Isol F0 63 Red/Open light off

) ior k1k29psm pushed (RCIC Turbine Trip Pushbutton pushed) ior k1m31jcm close (RCIC Steam Valve F0 45 Switch to CLOSE) ior q1m31lgm off (RCIC Steam Valve F0 45 Green/Closed light off

) ior q1m31rrm off (RCIC Steam Valve F0 45 Red/Open light off

) ior q1m30lrm off (RCIC Trip Throttle RCIC Trip Throttle Red/Open light off

) ior k1m30jcm close (RCIC Trip Throttle Switch to CLOSE) ior q1k30lrm off (RCIC Trip Throttle Valve Green/closed light off

) ior q1j25rgm off (RCIC Governor Valve Red/Open light off

) ior q1j24sam off (RCIC Red/Init Sig Present light off) ior k7d17wpg stop (C VT Exhaust Fan Switch Taken to STOP) ior q7d17lgg off (C VT Exhaust Fan Green/Off light off) ior q7d17mag off (C VT Exhaust Fan Amber/Trip light off)

Event 2 imf mrd157 (2) 0 (On Trigger 2, Loss of RPIS to rod 22-23) Event 4 ior k7d15wpg (4) stop (On Trigger 4 , A VT Exh Fan switch to stop

) ior q7d15lgg (4) off (On Trigger 4, A VT Exh Fan Green/Off light off) ior q7d15mag (4) on (On Trigger 4, A VT Exh Fan Amber Auto trip light on) imf r1479 (4) on (On Trigger 4, A VT Exhaust Fan trip Annunciator on) trgset 15 "d7d15wlg" (If A VT Exh Fan switch is placed in PTL) trgset 16 "d7d15wlg" (If A VT Exh Fan switch is placed in PTL) trgset 17 "d7d15wlg" (If A VT Exh Fan switch is placed in PTL) trg 15 "dor k7d15wpg" (A VT Exh Fan switch override deleted) trg 16 "dor q7d15mag" (A VT Exh Fan Amber Auto trip light override deleted) trg 17 "dmf r1479" (A VT Exh Fan trip annunciator malfunction deleted)

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 5 of 31 Event 5 ior k2k08pxi false (A HPU kill switch disabled)

(Enter malfunction for FCV opening from the Malfunction Input Screen)

Event 6 imf mee0 4 1 (6) (On Trigger 6 , Loss of SAT

) Event 7 ior k5h09w i 6 false (1B EHC Pump auto start disabled / switch Normal

-after-Stop false

) trgset 30 "k5h09wb6.eq.1" (When 1B EHC Pump switch is taken to START) trgset 27 "k5h09wb6.eq.1" (When 1B EHC Pump switch is taken to START) trg 30 "dor k5h09w i 6" (On Trigger 30, 1B EHC Pump is allowed to start / override delete d) trg 27 "dmf mms007

" (On Trigger 27, delete EHC Fluid leak) imf mms007 (7) 150 (On Manual Trigger 7, EHC oil leak)

Event 8 imf mee0 55 (8) (On manual trigger 8, Loss of UAT) imf mdg007 (8 0:05) (DG 1A trips and locks out when it starts) ior k1p18jbl (8 :12) start (Div 1 Water Leg Pump starts when 0 DG reenergizes bus) trg 18 "irf iau2tie2 close" (Unit 2 Div 2 XTIE Breaker ACB

-2424 closed) trgset 26 "q1k33rrl.eq.1" (When SRV U red/open light comes on) imf mnb038 (26) 0 (On trigger 26, SRV U setpoint lowers to 0 psig) Event 9 imf mnb078

-161 (HPCS auto start lowered to

-161 inches) trgset 29 "q1p06rrl.eq.1" (When HPCS red/ON light comes on) imf mes002 (29) 100 120 (On Trigger 29, HPCS discharge line break in containment at 100% severity on a 2 minute ramp

) Event 10 imf mes006 (ADS Timer K5A fails to count down) imf mes007 (ADS Timer K5B fails to count down)

7. Allow simulator to stabilize at higher Lake temperatures.

8. Place OOS Tags as required on the following components (as required):

RCIC is OOS: Tags on the following:1E51

-F076, 1E51

-F063, 1E51-F008, 1E51-F360. C VT Exhaust Fan in PTL and tagge d OOS. 9. Provide the following support paperwork:

Marked up copy of LOS

-TG-M4. A "Load Following" REMA.

10. Perform the pre

-scenario checklist.

11. Start Data Recording for Scenario Based Testing.

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 6 of 31 EVENT DESCRIPTION Facility: LaSalle Scenario No.: NRC 11-1-1 Op-Test No.:

2012301 Initial Conditions:

Unit 1 is operating at approximately 85% power. RCIC is Out

-of-Service. 1VT02CC is out of service.

LOS-TG-M4 is for PMT of #2 Turbine BV. Suppression Pool Temperature is 93 F. Turnover: Perform Turbine Bypass Valve Surveillance, LOS

-TG-M4, on BPV #2 for Post Maintenance testing. Return to rated power following completion.

Event No. Malf. No. Event Type*

Event Description

1. N/A (N) BOP Perform Turbine Bypass Valve Surveillance, LOS-TG-M4, for Turbine Bypass Valve #2.

2. mrd157 (I) (T) ATC SRO Loss of RPIS for one fully inserted rod on RCMS. Declare INOP, and electrically disarm. Tech Spec determination for LCO 3.1.3. (TS)(ABN)

3. N/A (R) ATC Commence ramp to full power using RR FCVs 4. k7d15wpg (C) BOP Loss of 1VT02CA. With only 1 TB Exhaust Fan operating, the BOP must secure one TB Supply Fan (ABN) 5. mrc039 k2k08pxi (I) ATC 1A Reactor Recirculation FCV controller fails open and HPU Trip button fails. (ABN)

6. mee041 (T) SR O Loss of SAT. Tech Spec determination for offsite sources of power. (TS)(ABN) 7. mms007 k5h09wl6 (C) BOP Loss of EHC fluid and failure of auto start feature for standby pump.

(ABN) 8. mee0 55 mdg007 m nb038 (M) Crew Loss of UAT. Division 2 EDG fails to start, crosstie to Unit 2 to restore power. One SRV sticks open, causing RPV level to lower to TAF.

9. mnb078 mes00 2 (M) Crew HPCS pump fails to auto start and then its discharge piping breaks inside containment after it has been manually started.

10. mes006&007 (M) Crew ADS will fail to auto initiate

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

ES-301-4 Quantitative attributes:

Total Malfunctions (5

-8): 7 Malfunction(s) after EOP (1

-2): 2 (E9&10) Abnormal Events (2

-4): 5 , (E2, 4, 5, 6, &7) Major Transient(s) /E

-Plan entry (1

-2): 1 (E 8) EOPs (1-2): 2 (LGA-001 and 003) EOP Contingencies (0

-2): 2 (ALC & Blowdown)

Critical Tasks (2

-3): 2 ES-301-5 Quantitative attributes:

BOP Normal:

E1 ATC Reactivity (1 per set):

E 3 BOP I/C (4 per set):

E 4&7 ATC I/C (4 per set):

E 2&5 SRO-I I/C (4 per set inc 2 as ATC):

E2,4, 5&7 SRO Tech Spec (2 per set):

2 (E2 & 6) ALL Major Transients (2 per set)

E 8 NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 7 of 31 GENERAL OBJECTIVE:

(USED THROUGHOUT THIS EXERCISE)

TASKS RO - ATC 47.012 Provided initial conditions, perform the main control room actions for Loss of Control Rod Position Information System IAW station procedures.

23.002 Provided initial conditions, respond to a Reactor Recirc Flow Control Valve failure to maximum demand IAW station procedures 300.040 Perform normal unit startup from main generator synchronization to full power operations 304.010 Perform actions for a reactor scram 413.010 Evaluate plant conditions and control RPV water level using CRD 414.010 Evaluate plant conditions and control RPV water level using SBLC, IAW LGA-SC-102. 414.000 Evaluate plant conditions and restore RPV water level to >

-150 inches on WR or >

-185 inches on FZ using preferred injection systems and if needed alternate injection systems RO - BOP/ASSIST 49.015 Perform actions to test operability of Main Turbine Valves and Controls 119.014 Respond to a Turbine Building ventilation abnormal condition 5.007 Respond to a Loss of the SAT 142 (242) during Power Operation 5.008 Provided initial conditions, respond to a loss of a 4.16 kvac ESS bus, IAW Station Procedures.

11.008 Provided initial conditions, perform the Control Room actions for a Diesel Generator start failure, per station procedures.

70.004 Perform Control Room actions for a stuck open SRV 414.000 Evaluate plant conditions and restore RPV water level to >

-150 inches on WR or >

-185 inches on FZ using preferred injection systems and if needed alternate injection systems 414.040 Evaluate plant conditions and control RPV water level using LPCI, IAW L GA-RH-103 428.000 Evaluate plant conditions and rapidly depressurize the RPV using SRVs via the ADS system, 61.013 Perform Control Room actions for a HPCS line break 421.000 Evaluate plant conditions and control and maintain suppression pool temperature less than HCTL

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 8 of 31 UNIT SUPERVISOR 49.015 Perform actions to test operability of Main Turbine Valves and Controls 47.012 Provided initial conditions, perform the main control room actions for Loss of Control Rod Position Information System IAW station procedures.

23.002 Provided initial conditions, respond to a Reactor Recirc Flow Control Valve failure to maximum demand IAW station procedures 300.040 Perform normal unit startup from main generator synchronization to full power operations 119.0 14 Respond to a Turbine Building ventilation abnormal condition 5.007 Respond to a Loss of the SAT 142 (242) during Power Operation 304.010 Perform actions for a reactor scram 5.008 Provided initial conditions, respond to a loss of a 4.16 kvac ESS bus, IAW Station Procedures.

11.008 Provided initial conditions, perform the Control Room actions for a Diesel Generator start failure, per station procedures.

304.010 Perform actions for a reactor scram 414.000 Evaluate plant conditions and restore RPV water level to >

-150 inches on WR or >

-185 inches on FZ using preferred injection systems and if needed alternate injection systems 413.010 Evaluate plant conditions and control RPV water level using CRD 414.010 Evaluate plant conditions and control RPV water level using SBLC, IAW LGA-SC-102. 70.004 Perform Control Room actions for a stuck open SRV 414.040 Evaluate plant conditions and control RPV water level using LPCI, IAW LGA-RH-103 61.013 Perform Control Room actions for a HPCS line break 421.000 Evaluate plant conditions and control and maintain suppression pool temperature less than HCTL 428.000 Evaluate plant conditions and rapidly depressurize the RPV using SRVs via the ADS system, NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 9 of 31 Event - 1 Description

Perform Turbine Bypass Valve Surveillance, LOS

-TG-M4 Initiation:

Following turnover Obj. Position EXPECTED OPERATOR RESPONSE 49.015 SRO May review LOS

-TG-M4 Prerequisites, Precautions and Limitations Supervises LOS

-TG-M4 49.015 BOP Setup to capture the "Valve position vs. time trace" Navigates to the Test Screen Navigates to the BV #2 Screen On the "BV #

2" screen, TEST Bypass Valve #

2 as follows:

PUSH the Test START pushbutton and OBSERVE:

Bypass Valve #

2 fully opens in approximately 10 seconds.

Bypass Valve #

2 exhibits Fast Open characteristics.

Approximately 10 seconds after reaching full open, Bypass Valve #2 FULLY CLOSES.

49.015 ATC Monitors reactor to ensure operations remain within established bands during expected fluctuations Monitors control room panels and notifies the SRO of any unusual or unexpected conditions.

Event - 1

Description:

. Perform Turbine Bypass Valve Surveillance, LOS

-TG-M4 Simulator Operator Actions None Simulator Operator Role Play None Floor Instructor Notes/OPEX/TR's N one NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 10 of 31 Event - 2

Description:

Loss of position indication for the selected rod, 22-23 Initiation:

At the direction of lead examiner, activate Manual Trigger 2.

Key Parameter Response:

On Full core Display, Rod 22-23 color changes to cyan and XX On RWM display, an INSERT ERROR and a WITHDRAW ERROR are displayed DATA FAULT is displayed on 3 separate screens Expected Annunciators:

On the Process Computer, DATA FAULT PRESENT ON ROD 22-23 (+Audible Alarm)

Automatic Actions

NONE Obj. Position EXPECTED OPERATOR RESPONSE 47.012 ATC Per LOA-RM-101, Section B.5 (B.5.1) Immediately:

Notify the SM Contact QNE Refer to TS 3.1.3 (B.5.2) Check control rod position indicates "XX" Select Rod (B.5.3) If rod is at position 00/FI prior to indication loss.

Apply an INSERT signal for 2 minutes to ensure rod is still fully inserted. Place CRD drive flow trip circuit bypass switch to bypass.

o May set RWM blocks to LPSP.

o May bypass the rod within RMCS per LOP

-RM-02. o May bypass the RWM Declare rod inoperable.

(B.5.8) Complete the following as required:

Refer to TS 3.1.3 Log the event Notify SOS Restore RWM blocks as necessary o Return RWM to Run (Probable) o May set RWM to Full Power o May u n-Bypass the rod within RCMS per LOP

-RM-02 Verify QNE contacted o Update Sequence o Placed OOS from RWM Per LOP-RM-02 o Electrically disarm per LOP

-RM-02 (B.5.9) Place CRD Drive Flow Trip Circuit Bypass Switch to Active

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 11 of 31 (Event 2 Continued) 47.012 SRO Per TS 3.1.3, Rod must be fully inserted and electrically disabled Initiates an IR Enter time on Time Clock she et BOP Monitors control room panels and notifies the SRO of any unusual or unexpected conditions.

Event - 2 Description

Loss of position indication for the selected rod, 22-23 Simulator Operator Actions Manual Trigger 2 Verify command associated with Manual trigger 2

imf mrd157 (2) 0 (On Trigger 2, Loss of RPIS to rod 22-23)

Simulator Operator Role Play Respond as required as QNE, SM, and SOS.

AS QNE: The sequence does not need to be changed The rod can be placed OOS Per LOP

-RM-02 Floor Instructor Notes/OPEX/TR's NONE NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 12 of 31 Event - 3

Description:

Commence ramp to full power using RR FCVs Initiation:

When directed by the Lead Examiner, contact the U S as the SM and direct the crew to raise power at 300 MWE/hr Obj. Position EXPECTED OPERATOR RESPONSE 300.040 ATC Per LGP-3-1: Increase power per REMA Raise power in a deliberate, carefully controlled manner while constantly monitoring:

APRMs MWe Core Thermal Power Secondary indications Recirculation flow changes shall be made per LOP

-RR-07. Per LOP-RR-07, Step E.4

Verify AUTO light on recirculation loop flow controller M/A station A/B is ON. STATION a second licensed Operator at 1DS001, or PPC display, to monitor FCV Pos Demand signals to allow for immediate recognition and communication of an abnormal response.

To adjust A and B Recirculation Loop Flow Controller Setpoint, DEPRESS the Ganged Flow Setpoint Station RAISE/LOWER pushbutton(s) as required. 300.040 SRO Directs actions above.

Enforces OPS expectations and standards Ensures RO monitors critical parameters carefully.

Stresses awareness of where operation is on the power to flow map.

Ensures operations are conducted within the bounds of Tech Specs and IAW Operations standards and approved procedures.

300.040 BOP Monitor FCV Pos Demand signals at 1DS001 or PPC display

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 13 of 31 Event - 3

Description:

Commence ramp to full power using RR FCVs Simulator Operator Actions NONE Simulator Operator Role Play NONE Floor Instructor Notes/OPEX/TR's When the ATC has completed this reactivity manipulation to the satisfaction of the Lead Examiner, proceed to Event 4.

Event 4 will take the BOP away from monitoring the FCV Position Demand and should halt the reactivity addition.

Event 5, the FCV failing open, must be initiated while the BOP is performing Event 4.

In order for the ATC to get 2 manipulations in Event 5, the FCV Lockup must be performed from the same computer that the BOP was using to monitor FCV Position Demand.

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 14 of 31 Event - 4

Description:

A VT Exhaust Fan Trip Initiation:

At the direction of L ead Examiner, activate Manual Trigger

4. Be prepared to initiate Event 5 during this event.

Key Parameter Response:

Vent Stack Flow indication on recorder VR

-019 at Panel 1PM06J Expected Annunciators:

1PM06J-B402, TB 1A EXH FAN AUTO TRIP 1PM06J-B304, TB DP HI 1PM06J-B303, TB SPLY AIR FLOW LO SS Automatic Actions:

TB Supply Fans may trip due to high DP Obj. Position EXPECTED OPERATOR RESPONSE 119.014 BOP Per LOR 1PM06J

-B402 Verify that 1A Turbine Building Supply Fan has tripped Start the idle TB Exhaust fan / Identifies only B Turbine Building Supply Fan is available and running Determine cause of the trip Initiate appropriate corrective action 119.014 BOP May enter LOA-VT-101 If only one Turbine Building Exhaust Fan is available:

VERIFY only 1 Turbine Building Supply Fan OPERATING / Trips one of the running TB Supply fans VERIFY Main Stack Flow is ISOKINETIC per LOP

-PR-04). (At 0PM14J) Verifies adequate sample flow to WRGM Monitors per LOP-PR-04 Check Turbine Building differential pressure between

- 2.0 and 0 in. H 2O by contacting an EO.

119.014 BOP May enter LOP

-VT-01, TB Ventilation Startup May perform Startup Steps E.1.1 through E.1.3 with an EO Starts/verifies running 1 TB Exhaust Fan Immediately starts 1 TB Supply Fan Verifies corresponding discharge check dampers are open 119.014 SRO May direct the BOP to stop one TB Supply Fan

. Supervises actions of LOR 1PM06J-B402 and LOA

-VT-101 Orders the 1A VT Exhaust Fan troubleshot by appropriate station personne l.

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 15 of 31 (Event 4 Continued)

ATC Suspends reactivity addition when the BOP cannot monitor FCV Position Demand Continues to monitor parameters for the power increase Event - 4 Description

A VT Exhaust Fan Trip Simulator Operator Actions Manual Trigger 4 Verify the following commands:

ior k7d15wpg (4) stop (On Trigger 4, A VT Exh Fan switch to stop) ior q7d15lgg (4) off (On Trigger 4, A VT Exh Fan Green/Off light off) ior q7d15mag (4) on (On Trigger 4, A VT Exh Fan Amber Auto trip light on) imf r1479 (4) on (On Trigger 4, A VT Exhaust Fan trip Annunciator on)

Event Triggers 15, 16, & 17 If the BOP takes the A VT Fan to PTL, verify Event Triggers 15, 16, and 17 go active and the following commands are deleted

(Override) k7d15wpg (A VT Exh Fan switch to stop) (Override) q7d15mag (A VT Exh Fan Amber Auto trip light on)

(Malfunction) r1479 (A VT Exhaust Fan trip Annunciator

) Simulator Operator Role Play If recovery is performed per LOA

-VT-101, Role Play EO: When contacted to check Turbine Building differential pressure, report Turbine Building DP at

-0.5 inches H 2O on 1PDI-VT006 at 1PL28J

. If recovery is performed per LOP

-VT-01, Role Play EO as necessary to support VT restart per the LOP

When directed, report local actions per Steps E.1.1 through E.1.3 completed satisfactorily

. When directed, verif y that the discharge check dampers for the running fans are ope n and verify that the non-running fan dampers closed When contacted to check Turbine Building differential pressure, report Turbine Building DP at -0.5 inches H 2O on 1PDI-VT006 at 1PL28J.

Floor Instructor Notes/OPEX/TR's Direct the SIMOP to initiate Event 5 during this event.

Event 5, the FCV failing open, must be initiated while the BOP is performing Event 4.

(In order for the ATC to get 2 manipulations in Event 5, the FCV Lockup must be performed from the same computer that the BOP was using to monitor FCV Position Demand.

)

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 16 of 31 Event - 5

Description:

A Reactor Recirculation FCV controller fails open and HPU Trip button fails.

Initiation: At the direction of the signal of lead examiner , fail the A RR FCV open from the Malfunction Input screen.

Key Parameter Response:

Jet Pump and Loop Flows rising, APRM readings rising steadily Expected Annunciators:

1H13-P602-A101, A RR FLOW CONTROL VALVE TROUBLE 1H13-P603-A108, APRM HI Automatic Actions:

None Obj. Position EXPECTED OPERATOR RESPONSE 23.002 ATC Announces condition and Locks up FCV.

Enters LOA

-RR-101 Section B.5

1. CHECK FCV position

-STABLE. If not, 1.1 Lock up FCV:

º PRESS 1A/1B HPU TRIP pushbutton.(Does Not Trip)

º Lockup solenoid valve at 1DS001.(will lockup)

º Select RRFC

º Select HPU Status A Loop

º Select HPU Shutdown

º Select CONFIRM

º Verify Annunciator

º Stop HPU Pump at 1DS001.(will stop)

2. PERFORM Subsection B.1, Core Instabilities

3. CHECK Recirc loop flows balanced

- less than T.S. mismatch Within 10.85 Mlbm/hr, if core flow is less than 75.95 Mlbm/hr.

23.002 SRO Directs actions per LOA

-RR-101. May enter Tech Spec 3.4.1 Condition B ATC Enters and performs LOA

-PWR-101 Checks RPS setpoints not exceeded CHECK Reactor Power is less than 100% RTP (3546 MWt)

CHECK Reactor Pressure is less than 1005 psig.

CHECK FCL is less than MELLLA (113.2% FCL)

SRO Directs LOA-PWR-101 BOP Monitors control room panels and notifies the SRO of any unusual or unexpected conditions.

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 17 of 31 Event - 5

Description:

The A Reactor Recirculation FCV controller fails open and HPU Trip button fails.

Simulator Operator Actions Manually enter this Malfunction from the Malfunction Input Screen (RR) mrc039 Ramp Start Value=As found Ramp Time = 300 seconds Severity Value = 100%

DO NOT access Malfunction Input Screen until ready to start the event in order to capture an accurate Ramp Start Value (i.e.: provide a smooth transition into this event)

Simulator Operator Role Play NONE Floor Instructor Notes/OPEX/TR's NONE NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 18 of 31 Event - 6

Description:

Loss of SAT.

Initiation:

At direction of Lead Examiner activate Manual Trigger 6

. Key Parameter Response

Busses 151, 152, 142Y and 142X supply breaker positions Expected Annunciators:

1PM01J-A107, SAT 6.9KV FEED BKR TRIP 1PM01J-A114, 4KV BUS141X/Y BKR TRIP 1PM01J-A317, SAT 142 TROUBLE Automatic Actions: Busses 151, 152, 142Y and 142X transfer to the UAT; the HPCS Diesel starts and loads Obj. Position EXPECTED OPERATOR RESPONSE 5.007 BOP Takes action per 1PM01J-A107, SAT 6.9KV FEED BKR TRIP Verify 6.9 KV busses 151and 152 are being supplied by the UAT May place the UAT supply breakers to busses 151 and 152 in CLOSE to bring up the RED target May place the SAT supply breakers to busses 151 and 152 in TRIP to bring up the GREEN target Reset 1PM01J-A107 5.007 BOP Takes action per LOA

-AP-101 for loss of the Unit 1 SAT, Section B.14 CHECKS 141Y Live (yes) CHECKS 142Y Live (yes)

CHECKS 143 Live (yes) May dispatch an EO to check on the HPCS Diesel 5.007 SRO Directs actions per LOR-1PM01J-A107 and LOA-AP-101 Enters Tech Spec 3.8.1 Condition A.1

- perform SR3.8.1.1 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and once ever 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter while Condition A is still in force.

Condition A.2 - 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to declare required features with no offsite power available inoperable when the required redundant features are inoperable (None inoperable)

Condition A.3

- 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to restore required offsite circuit to OPERABLE status ATC Monitors reactor to ensure operations remain within established bands Monitors control room panels and notifies the SRO of any unusual or unexpected conditions.

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 19 of 31 Event - 6

Description:

Loss of SAT.

Simulator Operator Actions Manual Trigger 6 Verify command:

imf mee041 (On Trigger 6, Loss of SAT, no deluge, Bus 13 fault)

Simulator Operator Role Play Role Play Unit 2 Supervisor: Inform the U1 Supervisor that you will perform the Independent Verification (IV) of Tech Specs when ready.

Role-play EO dispatched to investigate loss of the SAT.

Wait 10 minutes and then report a lockout on bus 13 Role-play EO dispatched to check the HPCS Diesel.

Wait 5 minutes and then report that the HPCS Diesel is running normally.

Floor Instructor Notes/OPEX/TR's NONE NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 20 of 31 Event -7

Description:

Loss of EHC fluid and failure of auto start feature for standby pump.

Initiation:

At direction of Lead Examiner, activate Manual Trigger 7

. Key Parameter Response:

EHC Fluid pressure below green band and lowering; 1A EHC pumps amps higher than normal and rising slowly Expected Annunciators:

1PM02J-B505 EHC MINOR TROUBLE EHC Workstation Alarm ID 315, EHC LEVEL DECREASING OVER TIME Automatic Actions

None; auto start of standby pump is failed Obj. Position EXPECTED OPERATOR RESPONSE None BOP Responds to annunciator 1PM02J-B505 EHC MINOR TROUBLE Checks EHC workstation alarm screen Refers to LOP

-EH-11 EHC Workstation Alarm Message Interpretation Per LOP-EH-11 EHC LEVEL DECREASING OVER TIME (Page 6 3), dispatch an EO to look for leaks Starts the 1B EHC pump and stops the 1A EHC Pump based on either:

o Recognizing the EHC pressure is below the auto start pressure for the 1B EHC Pump o The report from the EO

. Verifies EHC pressure is restored Verifies the leak has been stopped Non e SRO Directs crew actions per the annunciator and abnormal procedures May direct shifting to the standby EHC Pump None ATC Monitors reactor to ensure operations remain within established bands Monitors control room panels and notifies the SRO of any unusual or unexpected conditions.

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 21 of 31 Event - 7

Description:

Loss of EHC fluid and failure of auto start feature for standby pump.

Simulator Operator Actions Setup Commands ior k5h09w i 6 false (1B EHC Pump auto start disabled / switch Normal

-after-Stop false) Manual Trigger 7 Verify the following command:

imf mms007 (7) 150 (On Manual Trigger 7, EHC oil leak)

Event Trigger 30 Verify the 1B EHC pump starts/override is deleted based on Event Trigger 30: trgset 30 "k5h09wb6.eq.1" (When 1B EHC Pump switch is taken to START) k5h09w i6 override deleted Event Trigger 27 Verify the EHC Fluid leak malfunction is deleted based on Event Trigger 27:

trgset 27 "k5h09wb6.eq.1" (When 1B EHC Pump switch is taken to START) mms007 malfunction deleted Simulator Operator Role Play Role-play as the EO dispatched to the EHC Skid:

Wait 2 minutes, then report from the EHC skid:

There is an EHC fluid leak on the discharge of the 1A pump, between the pump and the discharge check valve. Recommend securing the 1A EHC Pump.

The tank level is 17.5 inches and lowering slowly When the 1B EHC pump has been started a nd the 1A pumps is stopped, call the control room to report that the leak has stopped.

Floor Instructor Notes/OPEX/TR's NONE NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 22 of 31 Event - 8

Description:

Loss of UAT, Division 2 EDG fails to start, and one SRV sticks open.

Initiation:

At the direction of lead examiner, activate Manual Trigger

8. Key Parameter Response:

Loss of UAT, Loss of 6.9 KV Busses, Loss of Bus 142Y, SRV U Red/Open indicating light on Expected Annunciators:

1PM01J A305, UAT 141 TROUBLE 1PM01J A207, 6.9KV BUS 151/152 UNDERVOLTAGE 1PM01J A314 , 4KV BUS 141X/Y UNDERVOLTAGE 1PM01J B302, 4KV BUS 142X/Y UNDERVOLTAGE Automatic Actions

Reactor Scram, Group 1 Isolation Obj. Position EXPECTED OPERATOR RESPONSE 304.010 ATC Responds to the reactor scram per LGP-3-2 Attachment E (hardcard):

ARM and DEPRESS Scram Pushbuttons PLACE Reactor Mode Switch in SHUTDOWN INSERT IRMs and SRMs CHECK Control Rods INSERTED and Power Decreasing INFORM Unit Supervisor Of Rod Status and Reactor Power REPORT to the Unit Supervisor the status of RPV Level and Pressure VERIFY Reactor Recirculation Pumps have downshifted VERIFY Main Turbine and Generator Trip STABILIZE Reactor Pressure <1020 psig REFER to LGP 2 5.008 11.008 BOP Reports the status of the Electric Plant Loss or UAT 1A DG has tripped 0 DG is carrying (Div. 1) Bus 141Y Verifies proper operation of 0 DG and observes load limits 413.000 414.000 SRO Enters and directs actions of LGA

-001 LEVEL LEG Establishes a RPV water level band of

-30 to +55 inches Direct actions to start all available high pressure injection When RPV water level cannot be maintained above 11 inches, directs actions to maintain level above

-150 inches

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 23 of 31 (Event 8 Continued)

Obj. Position EXPECTED OPERATOR RESPONSE 413.000 414.010414.000 ATC Monitors and reports RPV water level throughout When directed, starts a SBLC pump.

When directed, re

-starts a CRD pump.

414.000 BOP When directed, starts HPCS (See event 9) 70.004 SRO Enters and directs actions of LGA

-001 PRESSURE LEG STABILIZE Reactor Pressure below 1059 psig Identify SRV U stuck open and RPV pressure lowering When the stuck open SRV is identified, direct actions to close the SRV 70.004 BOP When directed, takes actions per LOA-SRV-101 for stuck open SRV:

May attempt to reset Low

-Low-Set Cycles the SRV U control switch from Auto to Open to Auto Monitor Suppression Pool Temperature Dispatch EO to remove fuses Determines that SRV is not closed 421.000 BOP Monitors containment parameters throughout Reports to the US when Suppression Pool temperature exceeds 105ºF, LGA-003 Entry Condition 421.000 SRO When Suppression Pool temperature exceeds 105ºF Enters and directs actions of LGA

-003 421.000 BOP When directed, starts all available Pool Cooling per LGA

-RH-103 Startup RHR Service Water as follows:

OPEN 1A/1B RHR Hx Service Water Outlet Valve:

1E12-F068A/B At approximately 9 to 10 seconds after taking the 1E12

-F068A/B switch to OPEN , START first RHR Service Water Pump

1A or 1B/C or D When indicated flow reaches 3000 gpm, START second RHR Service Water Pump.

Startup RHR Start 1A/1B RHR Pump Establish RHR flow of 1500 to 7450 gpm:

Throttle 1E12

-F024A/B (Test Valve) OPEN.

Close 1E12

-F048A/B (HX Bypass)

Place A/B HTX Bypass Throttle/Seal in switch to THROTTLE and THROTTLE CLOSED 1E12

-F048A/B. or Place A/B HTX Bypass Throttle/Seal in switch to SEAL IN and CLOSE 1E12

-F048A/B NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 24 of 31 Event - 8

Description:

Loss of UAT. Division 2 EDG fails to start, One SRV sticks open.

Simulator Operator Actions Manual Trigger 8 Verify the following commands on Manual Trigger 8:

imf mee055 (Loss of UAT) imf mdg007 (After 5 seconds, DG 1A trips and locks out when it starts) ior k1p18jbl start (Div 1 Water Leg Pump starts when 0 DG reenergizes bus in 12 seconds)

Event Trigger 26 Verify SRV U sticks open based on Event Trigger 26:

trgset 26 "q1k33rrl.eq.1" (When SRV U red/open light comes on) imf mnb038 (26) 0 (On trigger 26, SRV U setpoint lowers to 0 psig) Manual Trigger 1 8 When directed as the Unit 2 NSO to close in Div 2 XTIE ACB-2424 Activate Manual Trigger 18 Simulator Operator Role Play Role Play Unit 2 ANSO when directed to close in Div 2 XTIE ACB-2424 Activate Manual Trigger 18, verify the Div 2 XTIE, ACB-2424 , is closed, and then report that it is closed Role Play EO Dispatched to troubleshoot 1A DG Wait 5 minutes and then report that there is no apparent cause of the failure Role-play EO dispatched to the Aux Electric Room If directed to remove SRV U fuses. STALL as necessary, but DO NOT perform any commands to simulate fuse removal.

Floor Instructor Notes/OPEX/TR's NONE NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 25 of 31 Event - 9

Description:

HPCS pump fails to auto start and then degrades after it has been manually started.

Key Parameter Response:

HPCS Pump not running even though RPV water level is below Level 2; HPCS Pump Flow Indication; HPCS Pump Pressure indication, RPV water level not rising even with high HPCS flow Expected Annunciators:

1H13P601 A105, HPCS PMP DISCH FLOW HI

Automatic Actions: None Obj. Position EXPECTED OPERATOR RESPONSE 414.000 ATC Monitors and reports RPV water level throughout 414.000 61.013 BOP Identifies HPCS not running even though RPV water level is below Level 2 Verifies Div 3 D G is running Manually starts the HPCS Pump Verifies injection flow and pressure Monitors and reports RPV water level throughout Identifies that HPCS flow is not reaching the RPV Reports HPCS failure to SRO If directed, places the HPCS pump in PTL 414.000 SRO May identif y that HPCS flow is not reaching the RPV May direct shutdown of the HPCS system

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 26 of 31 Event - 9

Description:

HPCS pump fails to auto start and then degrades after it has been manually started.

Simulator Operator Actions Event Trigger 29 Verify HPCS fails based on Event Trigger 29:

trgset 29 "q1p06rrl.eq.1" (When HPCS red/ON light comes on) imf mes002 (29) 100 120 (On Trigger 29, HPCS discharge line break in containment at 100% severity on a 2 minute ramp)

Simulator Operator Role Play NONE Floor Instructor Notes/OPEX/TR's NONE NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 27 of 31 Event - 10

Description:

ADS will fail to auto initiate

/ RPV Water level recovery Key Parameter Response:

On 1H13P601 Annunciators F203 and E203 for ADS logic C&D are ON, but F202 and E202 for ADS logic A&B are NOT ON. ADS SRVs do not open as expected.

Expected Annunciators:

1H13P601 F202(&3) DIV 1 ADS LOGIC A(&C) INITIATED 1H13P601 E202(&3) DIV 2 ADS LOGIC B(&D) INITIATED Automatic Actions: None due to ADS time rs being faulted Obj. Position EXPECTED OPERATOR RESPONSE 414.000 CREW May identif y that ADS Timers have not started 428.000 SRO When RPV water level cannot be restored and held above

-150 inches, enters and directs LG A-004 o Verifies Suppression Pool level is greater than 18 ft.

o Directs a manual initiation of ADS o Verifies 7 ADS valves open 428.000 BOP Performs a manual initiation of ADS o Arms and depresses both Div 1 ADS MANUAL INITIATION pushbuttons o Arms and depresses both Div 2 ADS MANUAL INITIATION pushbuttons Verifies 7 ADS valves open 414.0 00 ATC Monitors and reports RPV water level throughout 414.040 SRO Per LGA-001 Directs the BOP to maximize injection into the RPV Directs restoration of RPV water level to maintain -30 inches to +50 inches 414.040 BOP Maximizes injection from LPCS and Div 1 RHR/LPCI If Div 1 RHR was placed in the Pool Cooling Mode, verify the Test Valve, 1E21-F024A, closes Verify LPCI and LPCS injection valves open fully When directed, controls LPCS Injection by throttling LPCS INJECTION VLV 1E21-F005 When directed, controls LPC1 Injection by throttling 1A LPCI INJ VLV 1E12

-F042A NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 28 of 31 Event - 10

Description:

ADS will fail to auto initiate

/ RPV Water level recovery Simulator Operator Action s NONE Simulator Operator Role Play NONE Floor Instructor Notes/OPEX/TR's TERMINUS When RPV level has been restored and/or at the discretion of the Lead Examiner, place the simulator in FREEZE. Collect Simulator Data for Scenario Based testing.

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 29 of 31 REFERENCES Procedure Title 1. LOS-TG-M4 Turbine Bypass valve Surveillance

2. LOA-RM-101 Unit 1 RMCS Abnormal Situations

3. LOP-RR-07 Operation of the Reactor Recirculation Flow Control System 4. LGP 3-1 Power Changes

5. LOA-RR-101 6. LOA-PWR-101 Unit 1 Reactor Recirculation System Abnormal Unit 1 Unplanned Reactivity Addition

7. LOA-VT-101 8. LOP-VT-01 9. LOA-AP-101 Turbine Building Ventillation Abnormal Turbine Building Ventillation system Startup Unit 1 AC Power Systems Abnormal 10. LOA-EH-101 Unit 1 EHC Abnormal

11. LOA-SRV-101 Unit-1 Stuck Open Safety Relief Valve

12. LOA-DG-101 DG Failure

13. LOR-1PM02J-B505 EHC Minor Trouble

14. LOR-1H13-P602-B407/408 1A/1B HPU Isolation Valve Closed

15. LGP-3-2 Reactor Scram

16. LGA-001 17. LGA-003 RPV Contro l Primary Containment Control

18. LGA-004 RPV Blowdown

19. LGA-RH-103 Unit 1 RHR operations in the LGAs

20. LPGP-PSTG-01S14 Plant Specific Technical Guidelines Section 14 LGA Related Hard cards

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 30 of 31 ATTACHMENT 04 Scenario Validation Checklist Page 1 of 1 Initi al 1 Verify with the Simulator Coordinator that the current training load is based on the current plant core.

2 The scenario performance objectives/tasks are listed in the scenario guide.

3 Simulator initial conditions are achievable.

4 The scenario guide clearly indicates the instructor station commands needed to achieve the performance objectives.

5 All malfunctions and other instructor station commands are entered in the sequence described in the scenario guide, and all items responded to support the performance objectives.

6 The simulator requires the operator to take the same action on the simulator as in the plant, using the reference plant operating procedures.

7 For annual exam scenarios, OBEs, and EP scenarios the scenario is validated in real time by an operating team consisting of SRO certified or licensed personnel using all referenced procedures and adhering to management expectations.

_____ 8 The responses of the simulator during the scenario were realistic, and observed changes correspond to expected plant response.

- Important / Critical Parameters (e.g., Flow, Power, Pressure, Radiation Level, Temperature, and Water Level)

- Annunciators

- System or component status indications 9 Tech Spec items / LCO declarations are correct. Appropriate documentation available.

10 Reportability requirements

/ Probabilistic Risk Assessments (if included) are correct. Appropriate documentation available.

Note: Wind speed and direction may be variable based on simulator modeling. ENSURE that these parameters are verified when validating the scenario.

11 Emergency Action Level classifications and PARs are identified, including whether or not there is a radiological release, the wind speed, and wind direction.

_____ 12 Critical tasks determined if applicable.

_____ 13 Shutdown scenarios include shutdown risk assessment, time to boil calculations and shutdown status board information.

14 Procedure steps that may be confusing or disagree with higher

-level procedures are discussed with operations management and expectations defined. Suggested enhancements are entered into the appropriate tracking system.

15 Management expectations are re

-enforced. 16 Scenario run time is in accordance with the stated quantitative attribute time.

17 Refer to EP

-AA-122-1001-F-07 for additional EP scenario validation criteria.

NRC 11-1-1 Revision 01 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 31 of 31 U1 SUPERVISOR TURNOVER Unit 1 power level Unit 2 power level 85% Power 100 % Power 30 20 MWt Some plant parameters stabilizing from power change 3532 MWt U1 Thermal Limit Issues /Power Evolutions U2 Thermal Limit Issues /Power Evolutions Holding for BPV test and per Power Team Return to full power when directed None Existing LCOs, date of next surveillance Existing LCOs, date of next surveillance RCIC, 12 days left, T.S. 3.5.3 None LOSs in progress or major maintenance LOSs in progress or major maintenance LOS-TG-M4 on Turbine BPV #2 for PMT following successful leak repair N one Equipment removed from service or currently unavailable 1VT02CC VT Exhaust Fan None Comments, evolutions, problems, etc.

Grid Status is Green Div 3 Workweek. OLR is Green Online Risk

- YELLOW PROTECTED:

o HPCS Cycle Fundamentals

New Operators/Crew Integration Supervisory Oversight/Feedback Core Fundamental Execution:

Weekly Focus

Tool Safety Oncoming U1 CRS:

No change in Medical status IRs turned over/reviewed Shiftly & Turnover reviewed Walkdown completed

___________________________

/ Name Date Shift: Days Date: Today Online Risk

Green Div 3 Workweek Next T/C: RCIC 12 days left OP-AB-300-1003 Revision 8 Attachment 1 Reactivity Maneuver Approval Cover Page Station: LaSalle Unit: 1 Valid Date(s):September 1, 2012 through December 3, 2012_Reactivity Maneuver Plan #: Are Multiple Activations Allowed: L1C15-05 YesPrepared by:

___ (If yes, US may make additional copies)

REACTOR ENGINEER__/__8/30/12____ Reviewed by: __

Qualified REACTOR ENGINEER /_8/30/12 Reactor Engineer / Date Qualified Nuclear Engineer / Date

_ Approved by:__

Rx. Enginneering Manager_/_8/30/12__ Authorized by:

__Senior Reactor Operato r____/_8/31/12 RE Manager/ Date Senior Reactor Operator/ Date

__ NF Review Declined: Y /

N NF Review by: ___

Nucelar Fuels_____/_8/30/12 NF Individual Contacted/Date

_____ ReMA Activated: __ Unit Supervisor _/__TODAY Unit Supervisor

/ Date Unit Supervisor / Date

_____ ReMA Terminated: ______________/______

Title of Evolution

L 1 C1 5 May 2012 Sequence Exchange and Quarterly Surveillances Purpose/Overview of Evolution: This ReMA provides instructions to: 1) Reduce power using flow to 9 55 MW e 2) Perform sequence exchange and 10% scram timing; 3) Perform MSIV, TCV, FW, and TBV surveillances and ramp to full power;

4) Perform channel distortion testing and maintain full power.

Maneuver Steps

1. Reduce reactor power using reactor recirculation flow to 9 55 MWe. 2. Perform Sequence exchange and 10% SCRAM time testing.

3. Raise reactor power with reactor recirculation flow and control rod withdrawal to full power while performing quarterly surveillances.

4. Perform channel distortion testing and maintain rated reactor power with RR flow and/or control rods. General Issues:

Rod movements and RWM operations will be performed IAW LOP

-RM-01 and LOP

-RM-02. FCL rises slightly as core flow lowers. During a fast flow reduction (300 Mwe/hr) to 70 Mlb/hr, FCL may rise on average 2.5% to 3.0%.

Per OP-AB-300-1003, section 4.2.11, QNE presence in the main control room is required for planned power changes greater than 20% CTP. QNE coverage is also required when margin to a fuel thermal limit is expected to be less than 3% and getting smaller.

This ReMA is written to perform LOS

-RP-Q3, LOS-RP-Q5, and LOS

-FW-SR1 in step 3. However, these surveillances may be performed in any step of the ReMA provided each is performed in accordance with the appropriate procedure requirements and reactor power limitation.

The leak on BPV #2 is planned to be repaired during this sequence exchange.

LOS-TG-M4 will need to be completed if the leak is successfully repaired. The performance of LOS

-TG-M4 has been written to be performed in step 3.

An RWM sequence that follows the sequence exchange and SCRAM time testing has been prepared for this maneuver.

The appropriate sequence will be loaded per LOP

-RM-02. However, if necessary and with QNE concurrence, the RWM blocks may be disabled by setting RWM blocks to LPSP only within RCMS.

The rods in the channel distortion population will be bypassed prior to moving and are expected to settle in less than 7 seconds

OP-AB-300-1003 Revision 8 2 CRDM flushing (LOP

-RD-19) may be performed during any step when time and resources permit. CRDM flushing and exercising of full out rods one notch may also be performed after this ReMA is completed. A ReMA is not required for CRDM flushing and exercising of full out rods one notch.

QNE will assist with monitoring the margin to thermal limits.

Fuel Conditioning thresholds are set per NF

-AB-440-1002. The QNE will assist with monitoring the nodal ramp rates IAW NF

-AB-440-1002. During rod pulls or xenon burnout, use a correlation of 10 MWe 1% FCL to estimate the margin to the MELLLA boundary.

When raising power with core flow, use a correlation of 20 MWe 0.20 kW/ft to estimate margin to fuel conditioning limits and a 12 MWe ch ange 0.01 change in LHGR to estimate the margin to MAPRAT , MFLPD, and MFDLRX thermal limits.

When in high RR pump speed, a change of 1.4 Mlbs/hr corresponds to a ~10 MWe change.

When above 100% FCL, core flow should remain above 65 Mlb/hr. This is a precaution/contingency in place due to the issue regarding the OPRM HI alarm received on Unit 1 (IR 945016).

The troubled rod list should be reviewed prior to this maneuver. Rods with issues with the potential to affect reactivity have been identified in the comments section on sequences prepared for this maneuver.

Reactivity

-related equipment issues have been evaluated for impact on this maneuver Unit 1 currently has five bypassed LPRM's (24-17B,16-57C, 16-41C,16-49D, 56-17D). This does not adversely impact core monitoring capability during the maneuver.

Below are the control rods that are on the troubled rod list that will be moved during this maneuver: Control Rod Problem Description IR/WR/WO 26-35 120 DCV Full Closed IR 1181562 34-27 120 DCV Full Closed IR 1280029 Plant procedures for Operations require that reactivity be changed only in a deliberate, carefully controlled manner while nuclear instrumentation and redundant indications of reactor power and neutron flux are constantly monitored. Primary indications of reactor power include the APRMs, Mwe, and CTP. Secondary indications include BEPM, FFWT, and Turbine First Stage Pressure. Additional information on the relationship between these and other secondary indications is discussed in LTP

-1600-10 and LOS-CX-S001. See the table below for more information on the sequences to be used in this maneuver:

Sequence Name RCMS Name RCMS cksum/keyword Description L1C15-r 1.1 SAr1.1b 58ca Old Shutdown Sequence L1C15 SM-SEQEX-0 5 SAr2.0se 7ef5 Sequence Exchange L1C15SM-ST-0 5 SAr2.0st 74 3e SCRAM Timing Sequence L1C15-r2.1 SAr2.1 53ef New Shutdown Sequence L1C15 SM-FLUSH-15 N/A N/A Flushing/Cycling Sequence L1C15 SM-CD T-15 N/A N/A Channel distortion testing of 2 peripheral rods

OP-AB-300-1003 Revision 8 3 OP-AB-300-1003 Revision 8 4 Attachment 2 Reactivity Maneuver Guidance Sheet STEP 1 of 4 Reactivity Maneuver Plan # Description of Step:

Reduce Reactor Power using reactor recirculation flow to 955 MWe. L1C15-05 1. PLACE Reactivity Change In

-Progress signs in their applicable plant locations prior to beginning this maneuver.

_CRS _____(initial when complete)

2. REDUCE reactor power by lowering core flow to 955 MWe, IAW LGP-3-1 and LOP-RR-07. _ CRSQNE presence required in the Control Room? Yes X No __ Onsite Only? Yes __ No X _____(initial when complete)

Initial Conditions (may be ranges) to be verified at the START of the Step Parameter Value or Range Init. Parameter Value or Range Init. FCL 108.2% MFLCPR 0.9 0 MAPRAT 0.80 MFDLRX 0.8 3 MFLPD 0.8 2 Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions High Low FCL Monitoring Frequency:

At least every 50 MWe via Heat Balance or P/F Map.

Contingency Actions:111.2% INSERT control rods per the approved sequence.

N/A MFLCPR Monitoring Frequency:

At least once every hour, at least once every 50 MWe when >0.90, and IAW Attachment 5 milestones via POWERPLEX case.

Contingency Actions:0.9 8 INSERT control rods per the approved sequence.

N/A ReMA Step Complete: _____

RO__________/_TODAY__ Verified by: ____

US_________/__ Reactor Operator/Date Unit Supervisor/DateTODAY OP-AB-300-1003 Revision 8 5 Attachment 2 Reactivity Maneuver Guidance Sheet STEP 2 of 4 Reactivity Maneuver Plan # Description of Step:

Perform sequence exchange and 10% SCRAM time testing.

L1C15-05 1. COMPLETE the sequence exchange, per L 1C15 SM-SEQEX-05 (SAr2.0se)

. _ CRS 2. PERFORM 10% Scram Timing per sequence L 1 C1 5 SM-ST-05 (SAr2.0st) and IAW LOS

-RD-SR12.__ __(initial when complete)

CRSQNE presence required in the Control Room? Yes X No __ Onsite Only? Yes __ No X __(initial when complete)

Initial Conditions (may be ranges) to be verified at the START of the Step Parameter Value or Range Init. Parameter Value or Range Init. FCL (%) 111.2% MFLCPR 0.98 MAPRAT MFDLRX 80 MFLPD 79 Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions High Low MFLCPR Monitoring Frequency:

At least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and every 50 MWe when >0.90 via POWERPLEX case.

Contingency Actions:0.98 INSERT CRAM rods per the approved sequence

. N/A Fuel Conditioning, Rod Pulls (P-PCS for nodes uncovered by control rod)

Monitoring Frequency:

At least once per hour via POWERPLEX case.

Contingency Actions:

REDUCE core flow and/or RETURN the rod(s) to its previous position per the guidance in NF

-AB-440-1002. (If core flow is reduced below 65 Mlb/hr ensure rod line is below 100% by inserting rods.)

0.00 kW/ft AREVA Fuel 0.35 kW/ft GNF Fuel N/A ReMA Step Complete: _____

RO__________/_TODAY__ Verified by: ____

US_________/__ Reactor Operator/Date Unit Supervisor/DateTODAY OP-AB-300-1003 Revision 8 6 Attachment 2 Reactivity Maneuver Guidance Sheet STEP 3 of 4 Reactivity Maneuver Plan # Description of Step:

Raise reactor power with reactor recirculation flow and control rod withdrawal to full power while performing quarterly surveillances.

L1C15-05 1. ADJUST power with control rods and/or RR flow to approximately 7 9% CTP. _ CRS 2. PERFORM LOS-RP-Q3. Maintain power by adjusting core flow so that CTP remains below 82% CTP. _

__(initial when complete)

CRS 3. RAISE reactor power to approximately 82% CTP with RR flow and PERFORM LOS-RP-Q5 and LOS

-FW-SR1. Maintain power by adjusting core flow so that CTP remains below 84% for LOS

-RP-Q5._ (initial when complete)

CRS 4. PERFORM LOS-TG-M4. ______ (initial when complete)

_(initial when complete) 5. RAISE reactor power to 100% CTP with rod pulls and/or RR flow per QNE.______(initial when complete)

QNE presence required in the Control Room? Yes X No __Initial Conditions (may be ranges) to be verified at the START of the Step Onsite Only? Yes __ No X Parameter Value or Range Init. Parameter Value or Range Init. Sequence Activated L1C15-r2.1 MFLCPR 0.80 MAPRAT 0.70 MFDLRX MFLPD Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions High Low MFLCPR Monitoring Frequency:

At least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and every 50 MWe when >0.90 via POWERPLEX case.

Contingency Actions:0.9 7 INSERT CRAM rods per the approved sequence

. N/A CTP Monitoring Frequency:

At least once hourly, after power changes before each surveillance via POWERPLEX case or Heat Balance.

Contingency Actions:82%: LOS-RP-Q3 ADJUST CTP with RR flow.

84%: LOS-RP-Q5 N/A FCL Monitoring Frequency:

At least once hourly, after power changes Heat Balance or P/F Map.

Contingency Actions:111.2% INSERT FCL rods per the approved sequence

. N/A Fuel Conditioning, Rod Pulls (P-PCS for nodes uncovered by control rod)

Monitoring Frequency:

At least once per hour via POWERPLEX case.

Contingency Actions:

REDUCE core flow and/or RETURN the rod(s) to its previous position per the guidance in NF

-AB-440-1002. (If core flow is reduced below 65 Mlb/hr ensure rod line is below 100% by inserting rods.)

0.00 kW/ft AREVA Fuel 0.35 kW/ft GNF Fuel N/A Fuel Conditioning, Ramp (for nodes where P

-PCS >0.00 kW/ft)

Monitoring Frequency:

At lea st once per hour via POWERPLEX case.

Contingency Actions:

SLOW DOWN the flow ramp or REDUCE core flow per the guidance in NF

-AB-440-1002. 0.25 kW/ft/hr (4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months avg) AREVA Fuel 0.30 kW/ft (overshoot) 0.35 kW/ft/hr (4 hr avg)

GNF Fuel 0.45 kw/ft (overshoot)

N/A ReMA Step Complete: ________________/______

Verified by: _____________/_______

Reactor Operator/Date Unit Supervisor/Date

OP-AB-300-1003 Revision 8 7 Attachmen t 2 Reactivity Maneuver Guidance Sheet STEP 4 of 4 Reactivity Maneuver Plan # Description of Step: Perform channel distortion testing and maintain rated reactor power with RR flow and/or control rods.

L1C15-05 1. ADJUST reactor power with RR flow and/or Control Rod Moves per L1 C1 5-r 2.1 to maintain 100% CTP. ______(initial when complete)

PERFORM channel distortion testing of 2 peripheral control rods per L1C15 SM-CD T-05 (SAr2.0cd) and LOS-RD-S7. ______(initial when complete)

2. REMOVE all Reactivity Change In

-Progress signs when full power is reached. ______(initial when complete)

3. CLOSE this ReMA Step with concurrence of the QNE when the core is near equilibrium conditions. ______(initial when complete)

QNE presence required in the Control Room? Yes X* No __ Onsite Only? Yes __ No *For FCL rod withdrawal only. QNE presence is not required for control rod flushing and subsequent rod cycling. See OP

-AB-300-1003, section 4.2.11, for QNE presence requirements X Initial Conditions (may be ranges) to be verified at the START of the Step Parameter Value or Range Init. Parameter Value or Range Init. FCL (%) 111.2% MFLCPR 0.9 4 MAPRAT 0.80 MFDLRX 85 MFLPD 85 Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions (if needed) High Low FCL Monitoring Frequency:

At least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and after each rod withdrawal via P/F Map or Heat Balance.

Contingency Actions:111.2% INSERT FCL rods per the approved sequence

. N/A MFLCPR Monitoring Frequency:

At least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months via POWERPLEX case.

Contingency Actions:0.98 INSERT CRAM rods per the approved sequence

. N/A Fuel Conditioning, Ramp (for nodes where P

-PCS >0.00 kW/ft)

Monitoring Frequency:

At least once per hour via POWERPLEX case.

Contingency Actions:

SLOW DOWN the flow ramp or REDUCE core flow per the guidance in NF

-AB-440-1002. 0.25 kW/ft/hr (4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months avg) AREVA Fuel 0.30 kW/ft (overshoot) 0.35 kW/ft/hr (4 hr avg)

GNF Fuel 0.45 kw/ft (overshoot)

N/A Fuel Conditioning, Rod Pulls (P-PCS for nodes uncovered by control rod)

Monitoring Frequency:

If predictors show less than 0.5 kW/ft margin to the limit, then monitor after each rod movement via POWERPLEX case.

Contingency Actions:

REDUCE core flow and/or RETURN the rod(s) to its previous position per the guidance in NF

-AB-440-1002. (If core flow is reduced below 65 Mlb/hr ensure rod line is below 100% by inserting rods.)

0.00 kW/ft AREVA Fuel 0.35 kW/ft GNF Fuel N/A ReMA Step Complete: _______________/______

Verified by: ___________/_______ Reactor Operator/Date Unit Supervisor/Date

OP-AB-300-1003 Revision 8 8 Attachment 5 Reactor Engineer's Evolution Plan/Guidance Reactivity Maneuver Plan # Station/Unit L1C15-05 LaSalle Unit 1Purpose: The purpose of this maneuver is to adjust the rod pattern in accordance with the Cycle Management Report and perform required Technical Specification surveillances.

Valid from:

9/1/12 Valid to:

12/0 1/12 Prepared by:

_REACTOR ENGINEER___/_8/30/12 Reviewed by:__QNE_____/__8/30/12 Reactor Engineer Date QNE Date __ Approved by:

__REM____/__8/31/12 RE Manager Date ______ Evolution Overview:

This ReMA provides instructions to reduce power to perform sequence exchange, 10% SCRAM timing, MSIV, TCV, and FW quarterly surveillances, channel distortion testing, and ramping to and maintaining full power.

Special Considerations:

Rod moves

- both order and position

- in this attachment have been provided for information only and reflect the predicted maneuver. Any changes to actual moves are governed by NF

-AB-720 and may not require an update to this attachment.

The final target pattern can be seen below. At steady state conditions, assuming a K

-eff of 1.0055, FCL will be

~103.8% and core flow ~102.6 Mlb/hr. 02 06 10 14 18 22 26 30 34 38 42 46 50 54 58 59

-- -- -- -- -- -- --

59 55

-- -- -- -- -- -- -- -- --

55 51

-- -- -- -- 18 -- 18 -- -- -- -- 51 47 -- -- --P -- -- -- -- -- -- -- D-- -- -- 47 43 -- -- -- -- 22 -- --*X-- M-- -- 22 -- -- -- -- 43 39 -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- 39 35 -- -- 18 -- -- -- 00 -- 00 -- -- -- 18 -- -- 35 31 -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- 31 27 -- -- 18 -- -- -- 00 -- 00 -- -- -- 18 -- -- 27 23 -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- 23 19 -- -- -- -- 22 -- -- -- -- -- 22 -- -- -- -- 19 15 -- -- -- -- -- -- -- -- -- -- -- -- -- 15 11

-- -- -- -- 18 -- 18 -- -- -- -- 11 07

-- -- -- -- -- -- -- -- --

07 03

-- -- -- -- -- -- --

03 02 06 10 14 18 22 26 30 34 38 42 46 50 54 58 If LOS-RP-Q5 does not pass, and EOCRPT is OOS, Combined EOOS Option 1(TL #5) should be used. Predictors show that if LOS

-RP-Q5 does notIf LOS-RP-Q5 does pass and the Combined EOOS Option 1 (TL #

5) must be implemented, MFLCPR will be 0.

9 86. Power ascension can be performed, as MFLCPR at the most limiting point is 0.9

86. However, if TL #5 is utilized, power should either be raised abo ve 85% or the 7B CRAM rods should be inserted.

If power is not raised to 85%, predictors show MFLCPR to be 0.9 83 at 85% CTP. Insertion of the 7B CRAM rods lowers MFLCPR to 0.

916. no t pass, and EOCRPT is NOT OOS, Combined EOOS Option 2 (TL #6) should be used. Predictors show that if LOS

-RP-Q5 does not Steps 4 d-4 h contain actions that all need to be performed after full power is reached, but are independent of one another other, so these steps can be performed in any order.

pass and the Combined EOOS Option 2 (TL #6) must be implemented, MFLCPR will be 0.9

19. Power ascension can be performed, as MFLCPR is 0

.9 19 at the most limiting point.

OP-AB-300-1003 Revision 8 9 Guidance: # Activity / Guidance Key Evaluation Results Activity Complete 1a 1. VERIFY QNE qualifications are current.

Pre-Maneuver QNE Guidance

2. ENSURE that the US completes Attachment 7 prior to ReMA activation.

3. ENSURE that the US authorizes the sequences to be used during the maneuver.

4. MAKE copies of the sequences for the QNE's reference during the maneuver. Operations should be given the originals of all sequences EXCEPT for the shutdown sequence.

5. MAKE a copy of the shutdown sequence after the US authorizes it to be implemented later in the maneuver.

ENSURE the Unit QNE retains the original.

6. ENSURE the Reactivity SRO has a copy of Attachment 5 to follow along with the maneuver.

7. PARTICIPATE in the Operations PJB/HLA.

N/A 1b 1. VERIFY that RCMS is loaded with the following sequences:

SAr1.1b (Old Shutdown) SAr 2.0se (Sequence Exchange)

SAr 2.0st (Scram Timing)

SAr2.1 (New Shutdown)

2. VERIFY sequence SAr1.1b is activated.

N/A 1c 1. TRIGGER monitor case prior to beginning power reduction.

2. VERIFY Step 1 Initial Conditions (ICs) are met and have been signed off by Operations.

3. RECOMMEND flow reduction.

4. COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

Keff = 1.0054 Initial conditions MFLCPR = 0.

853 MAPRAT = 0.736 MFDLRX = 0.775 MFLPD = 0.761 WT = 98.9 MLB/HR FCL = 106.2% 1d 1. EXECUTE predict case(s) to model the flow reduction to 70 Mlb/hr.

2. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

3. RECOMMEND flow reduction.

4. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 82.0% Wt = 70 Mlb/hr FCL = 109.2% Keff = 1.0049 MFLCPR = 0.928 MAPRAT = 0.625 MFDLRX = 0.737 MFLPD = 0.725 P-PC S = -2.34 kW/ft 2 STEP 2 GENERAL NOTE:

N/A If predicts show that a rod pull will result in P

-PCS > 0.00 kW/ft, enter NF

-AB-440-1002 Step 4.2.3

. Obtain a peer check prior to taking any action.

OP-AB-300-1003 Revision 8 10 # Activity / Guidance Key Evaluation Results Activity Complete 2a 1. VERIFY that sequence L1C15SM-SEQEX-05 (SAr2.0se) is activated.

2. EXECUTE predict case(s) to model steps 13 - 20 of L1C15SM

-SEQEX-05 (SAr2.0se). 3. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

4. RECOMMEND rod moves.

5. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 72.7%

Steps Completed FCL = 96.7%

Keff = 1.0050 MFLCPR = 0.841 MAPRAT = 0.616 MFDLRX = 0.773 MFLPD = 0.777 P-PCS = -1.99 2b 1. EXECUTE predict case(s) to model steps 21 - 32 of L1C15SM

-SEQEX-05 (SAr2.0se).

2. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

3. RECOMMEND rod moves.

4. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 54.3%

Steps Completed FCL = 72.4%

Keff = 1.0050 MFLCPR = 0.741 MAPRAT = 0.524 MFDLRX = 0.738 MFLPD = 0.741 P-PCS = -3.20 2c 1. EXECUTE predict case(s) to model steps 33 - 41 of L1C15SM

-SEQEX-05 (SAr2.0se).

2. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

3. RECOMMEND rod moves.

4. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 56.1%

Steps Completed FCL = 74.6%

Keff = 1.0051 MFLCPR = 0.748 MAPRAT = 0.538 MFDLRX = 0.755 MFLPD = 0.758 P-PCS = -2.96 2d 1. VERIFY that the "Rod Status Verified and Page Check Complete" and "RWM Loaded and Verified" is signed on the L1C15SM-ST-05 (SAr2.0st) sequence coversheet.

2. ACTIVATE sequence SAr 2.0st. 3. DELETE sequence SAr2.0se

4. EXECUTE predict case(s) to model the hold for scram timing. (2.5 hrs) 5. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

6. VERIFY Step 3 ICs will be met.

7. RECOMMEND continuing rod moves.

8. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 54.1%

After ST: FCL = 72.0%

Keff = 1.0049 MFLCPR = 0.726 MAPRAT = 0.519 MFDLRX = 0.744 MFLPD = 0.747 P-PCS = -3.16 kW/ft 3a 1. VERIFY that the "Rod Status Verified and Page Check Complete" and "RWM Loaded and Verified" is signed on the L1C15-r2.1 (SAr2.1) sequence coversheet.

2. ACTIVATE sequence SAr2.1. 3. DELETE sequence SAr 2.0s t. N/A OP-AB-300-1003 Revision 8 11 # Activity / Guidance Key Evaluation Results Activity Complete 3b 1. EXECUTE predict case(s) to model withdrawing the 7B rods to their target position (00

-22). 2. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

3. RECOMMEND continuing rod moves.

4. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 61.0% After 7B rods 00

- 22: FCL = 81.2

% Keff = 1.0050 MFLCPR = 0.8 04 MAPRAT = 0.538 MFDLRX = 0.736 MFLPD = 0.739 WT = 7 0.0 P-PCS = -2.91 kW/ft 3c 1. EXECUTE predict case(s) to model withdrawing the 7C rods to the position needed to hold through the xenon transient. Predictors were run with the 7C at

18. 2. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

3. RECOMMEND continuing rod moves.

4. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 75.7

% After 7C rods 00

- 18: FCL = 100.7

% Keff = 1.0048 MFLCPR = 0.

893 MAPRAT = 0.582 MFDLRX = 0.725 MFLPD = 0.729 WT = 70.0 MLB/HR P-PCS = -2.35 kW/ft 3d 1. EXECUTE predict case(s) to model raising flow and the hold for LOS-RP-Q3. 2. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

3. RECOMMEND adjusting flow. 4. MONITOR CTP to ensure that it does not exceed 82% during LOS

-RP-Q3. 1. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 81.3% After hold for LOS

-RP-Q3: FCL = 102.7

% Keff = 1.0051 MFLCPR = 0.

898 MAPRAT = 0.614 MFDLRX = 0.739 MFLPD = 0.742 WT = 76.0 MLB/HR P-PCS = -1.94 kW/ft 3e NOTE: If LOS-RP-Q5 fails and EOCRPT is OOS, EOOS #1 (TL set 5) should be implemented. If LOS

-RP-Q5 fails and EOCRPT is not OOS, EOOS #2 (TL set 6) should be used. If LOS

-RP-Q5 fails and power is below 85% CTP, predicts show MFLCPR increases to 0.9 86 when EOOS #1 is implemented.

Insertion of the 7B CRAM rods lowers MFLCPR to 0.

916. Increasing power to above 85% CTP lowers MFLCPR to 0.921. When EOOS #2 is implemented, MFLCPR increases to 0.919

. 1. EXECUTE predict case(s) to model the hold for LOS

-RP-Q5 and LOS-FW-SR1. 2. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

3. RECOMMEND adjusting flow and performing LOS

-RP-Q5 < 84% CTP. 4. MONITOR CTP to ensure that it does not exceed 8 4% during LOS

-RP-Q5. 5. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 8 4.0% After hold for LOS

-RP-Q5 and LOS

-FW-SR1 FCL = 106.0% Keff = 1.0051 MFLCPR = 0.9 19 MAPRAT = 0.632 MFDLRX = 0.745 MFLPD = 0.748 WT = 76.0 MLB/HR P-PCS = -1.75 kW/ft OP-AB-300-1003 Revision 8 12 # Activity / Guidance Key Evaluation Results Activity Complete 3f 1. EXECUTE predict case(s) to model the hold for LOS

-TG-M4. 2. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

3. RECOMMEND performing LOS

-TG-M4. 1. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

CTP = 8 5.0% After hold for LOS

-TG-M4 FCL = 107.0% Keff = 1.0051 MFLCPR = 0.9 21 MAPRAT = 0.632 MFDLRX = 0.745 MFLPD = 0.748 WT = 76.0 MLB/HR P-PCS = -1.60 kW/ft 3 g 1. EXECUTE predict cases to model the ramp to 100% CTP.

2. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

3. VERIFY Step 4 ICs will be met.

4. RECOMMEND ramp rate based on fuel conditioning.

5. TRIGGER POWERPLEX case and COMPARE results (Eigenvalue, FCL, Thermal Limits, etc.) with the predict results.

FCL = 105.7% After ramp, at 100% CTP Keff = 1.0055 MFLCPR = 0.

874 MAPRAT = 0.731 MFDLRX = 0.787 MFLPD = 0.790 WT = 99.8 Mlb/hr P-PCS = -0.50 kW/ft 4a GENERAL NOTE:

1. OPEN the electronic LOS

-RD-SR7 Excel spreadsheets with the correct rods listed to be tested.

Channel Distortion Testing will be performed at full power. ENSURE the PPC rod timing program is running in the background as a contingency in the case of a stopwatch timing error.

ENTER the date, time, insert stall flow, and withdraw settle time for each rod tested in LOS

-RD-SR7. When each page is complete, initial as preparer and have an SRO sign as reviewer.

2. COMPLETE Channel Distortion Testing Summary after the testing is complete.

3. VERIFY that an IR was issued to document the results of CDT.

4. SEND the CDT Summary and IR to the Operations Director, Engineering Director, Nuclear Fuels, and the listed people per LOS-RD-SR7. Settle Testing Issues:

4b 1. EXECUTE predict cases to model min Xe conditions at 100% CTP. (Initial predictors show minimum Xe is ~

6 hrs after full power is reached). FCL = 111.1% MIN Xenon:

Keff = 1.0056 MFLCPR = 0.907 MAPRAT = 0.756 MFDLRX = 0.797 MFLPD = 0.800 WT = 92.5 MLB/HR XE = -7.71% 4 c 2. VERIFY that the "Rod Status Verified and Page Check Complete" and "RWM Loaded and Verified" is signed on the L1C15-r2.1a (SAr2.1a) sequence coversheet.

3. VERIFY RCMS is loaded with SAr 2.1a 4. ACTIVATE shutdown sequence SAr 2.1a 5. DELETE sequence SAr 2.1 N/A OP-AB-300-1003 Revision 8 13 # Activity / Guidance Key Evaluation Results Activity Complete 4 d 1. INFORM unit supervisor to perform flushing of rods that were scram timed as time permits.

2. PROVIDE sequence L1C15SM-FLUSH-05 to unit supervisor to document cycling of rods after flushing.

N/A 4 e 1. COLLECT Post Critique comments from the Control Room Personnel. Remind the Shift Manager to perform EOS/FMS feedback on RE performance.

Comments: 4 f 1. SEND a copy of the predicted vs. actual results (load profile) to the NDO mailbox, and give a copy to the Operations Director.

4g 1. PERFORM a critique of the load profile performance within 3 days of reaching full power as required by step 4.6.3 of OP

-AA-102-101 and SEND to the NDO mailbox.

4h 1. PERFORM a critique of the load profile performance IAW OP

-AB-300-1003 within ~10 days.

4i 1. When the target rod pattern has been achieved and the core is near equilibrium conditions, then CLOSE this ReMA Step and the ReMA. FCL = 103.8% Steady State Xenon:

Keff = 1.0055 MFLCPR = 0.859 MAPRAT = 0.754 MFDLRX = 0.788 MFLPD = 0.791 WT = 102.6 Mlb/hr SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

LaSalle County Station DYNAMIC SIMULATOR SCENARIO GUIDE ILT Class 11

-1 NRC Exam Reactor Startup, Stuck Rod, SSE Pressure , V R Rad Mon INOP , FRV Controller Failure, 1N62-F057 isolation, Small Steam LOCA with Suppression Failure 11-1-2 Rev. 0 8/3 1/2012

DEVELOPED BY:

Instructor Date VALIDATED BY:

SME/Instructor Date REVIEWED BY:

Shift Operations Supervisor Date APPROVED BY:

Operations Training Manager Date NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 2 of 27 Facility: LaSalle County Station

Scenario No.:

11-1-2 PURPOSE OF SCENARIO Examine the ILT candidate's ability to operate the plant in normal, abnormal, and emergency conditions.

SUMMARY

OF EVENTS 1. The ATC will continue to pull control rods per the startup sequence packag e to 11/2 Turbine Bypass Valves per Step 5.1.

2. One control rod is determined to be stuck.

Attempts to free the rod using the normal operating procedure will fail. The LO A actions are used and the rod frees itself when CRD Drive pressure is raised. The startup can continue.

3. Steam Seal Evaporator Pressure Control Valve fails.

The PCV Bypass valve will not open. The BOP must line up to supply steam from the M ai n Steam header per LOA-G S-101. 4. The 1C Reactor Building Ventilation Fuel Pool Exhaust Radiation Monito r fails Downscale.

The Unit Supervisor is expected to make a Technical Specification 3.3.6.1 determination

. 5. Master FWLC setpoint fails to 45, causing RPV water level to rise above the high level alarm point

. The ATC responds per LOA

-FW-101 and maintains RPV water level in manual level control for remainder of scenario.

6. The Scenario starts with the 1A Off Gas Posttreat Monitor inoperable. Failure of the 1B Posttreat Rad Monitor results in closure of 1N62-F057. BOP installs jumper to reopen the valve. (ABN). 7. A steam leak from a Main Steam Line inside primary containment will develop coincident with a primary containment suppression failure.

The scenario can be terminated when the examinees have RPV and Containment Parameters stable and under control

. Critical Steps:

1. When Suppression Chamber pressure exceeds 2 psig, start suppression chamber spray.

2. Start drywell spray before exceeding the PSP curve.

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 3 of 27 SER 3-05 1. Monitoring Plant Conditions and Indications Closely

2. Controlling Plant Evolutions Precisel y

3. Conservative Bias to Plant Operations

4. Effective Teamwork

5. Solid Understanding of Plant Design and Interrelationships SOER 10-2 1. Oversight ensures proper focus

2. Equipment restoration risk evaluation

3. Preparation for high risk evolution

4. Control Room resources adequate for EOP response

5. Sufficient engagement of other s in decision making

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 4 of 27 INITIAL SIMULATOR SETUP/REQUIRED DOCUM ENTATION 1. Reset to IC197, 7% power with the mode Switch in RUN.

(NOTE: IC197 was saved from the 0 5/1 4/1 2 version of IC

72) 2. If necessary, IC197 can be re

-built as follows:

Reset to IC

-72 and go to RUN.

Place the Reactor Mode Switch in RUN.

Load a RWM Shutdown Sequence and insert the following control rods to position 12:

o 42-51, 42-11. 18-11, and 18-51 Then load a RWM Startup Sequence: SA15SU.d Establish normal Drywell Pressure Control.

Take 1 CP Demineralizer out of service.

Shift to the A Gland Exhauster condensate and blower

. Reduce CRD Drive Pressure to 250-260 psi. Take Main Turbine out of Chest Warming

3. Place simulator in RUN.

4. Raise B TDRFP Min Flow to bring CP D/P to 20psid.

5. Insert commands for this scenario. (Commands in CAEP File: NRC Scenario 11 2.cae) trgset 2 "g3f0 2g1d.gt.0.67" (When CRD Dr ive pressure >515 psig) imf mrd217 (Rod 18-11 Stuck) trg 2 "dmf mrd2 1 7" (On Event Trigger 2, Rod 18-11 malfunction deleted) ior q5h03lr1 (3) o ff (On Trigger 3, GS Header PCV Stop MOV

-GS-S1 Red/closed light off) ior q5h03rg1 (3) on (On Trigger 3, GS Header PCV Stop MOV

-GS-S1 Grn/Open light on) ior k5h03jc1 (3) close (On Trigger 3, GS PCV Stop MOV

-GS-S1 switch to close) ior k5h03jn1 (3) false (On Trigger 3, GS PCV Stop MOV

-GS-S1 Open position false) ior k5i04jc1 (3) close (On Trigger 3, PCV Bypass GS-S2 closed) ior k5i04jn1 (3) false (On Trigger 3, PCV Bypass GS-S2 Open position false) imf mrm0 21 (4) (On Trigger 4, C FP Vent PRM Downscale failure) imf mrm011 (A Off Gas Postreat Monitor failed downscale) imf mrm012 (On Trigger 6, B Off Gas Postreat Monitor fails downscale

) imf mnb105 (7) 10 0 (On Trigger 7, MSL Break inside DW at 10 0 lb/sec severity) imf mca015 (7) 100 (On Trigger 7, Primary Containment Bypass Path at 100% severity

) imf mms048 (7) 90 (On Trigger 7 with a 90 second delay, BPV #1 fails closed) imf mms049 (7) 90 (On Trigger 7 with a 90 second delay, BPV #

2 fails closed) imf mms050 (7) 90 (On Trigger 7 with a 90 second delay, BPV #

3 fails closed) imf mms051 (7) 90 (On Trigger 7 with a 90 second delay, BPV #

4 fails closed) imf mms052 (7) 90 (On Trigger 7 with a 90 second delay, BPV #

5 fails closed) imf r1444 off (1N62P600 B406 Adsorber Vessel Temp Annunciator off) imf r144 5 off (1N62P600 B406 Adsorber Train Diff Press Annunciator off) imf r144 6 off (1N62P600 B406 Adsorber Vault Temp Annunciator off) ior g9b05g1z 1 (Offgas Adsorber Train DP indicator overridden to 1 psid)

(Continued)

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 5 of 27 6. Make the following CAE File available for Event 5: NRC Scenario 11 2 Event 5.cae (At 2 seconds) ior k3k11p1y false (Master FRV Controller Lower Pushbutton Inoperable)

(At 4 seconds) ior g3k11002 45 (Master FRV Controller setpoint fails to 45)

(At 6 seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed)

(At 8 seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted)

(At 18 seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed)

(At 20 seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted)

(At 30 seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed)

(At 32 seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted) (At 42 seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed)

(At 44seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted)

(At 54 seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed) (At 5 6 seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted)

(At 1:0 6 seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed)

(At 1:0 8 seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted)

(At 1: 18 seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed)

(At 1: 2 0 seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted)

(At 1: 3 0seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed)

(At 1:3 2 seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted)

(At 1: 42 seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed)

(At 1:4 4 seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted)

(At 1: 5 4 seconds) ior k3k11p2y raise (Master FRV Controller Raise Pushbutton depressed)

(At 1:5 6 seconds) ior k3k11p2y (Master FRV Controller Raise Pushbutton override deleted)

7. Place robust barriers as required on the following components (as required): None 8. Provide a marked up copy of LGP 1 up to Step E.5

9. Provide a Startup REMA.

10. Provide a prefabricated jumper for Event 6.

11. Place ODCM 12.2.2 Timeclock on Timeclock Board.

12. Perform the p re-scenario checklist.

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 6 of 27 13. EVENT DESCRIPTION Facility: LaSalle Scenario No.: NRC 11-1-2 Op-Test No.:

2012301 Initial Conditions:

Startup in progress at approximately 8% power. At Step E.5

, withdrawing control rods to achieve 11/2 Bypass Valve s for Turbine Roll.

1A Off Gas Posttreat Monitor is inoperable.

Turnover: Continue Startup Event No. Malf. No. Event Type*

Event Description

1. N/A (R) ATC Pull control rods per the sequence package to obtain 11/2 Bypass Valves for Turbine Roll 2. mrd2 1 7 (C) ATC Stuck control rod, (18-1 1) moves after increasing Drive Water pressure (ABN) 3. k5h03jc1 (C) BOP Steam Seal Evaporator pressure control valve fails. LOR and LOA actions. (ABN) 4. mrm0 2 1 (T) (I) CRS 1C Fuel Pool Exhaust Radiation Monitor fails downscale. Technical Specification 3.3.6.1 Determination (TS) 5. g3k11p1y mcf089 (I) ATC Master FWLC setpoint fails to 45, requiring manual level control for remainder of scenario. (ABN) 6. mrm011 mrm012 (I) BOP Failure of the second Posttreat Rad Monitor results in closure of 1N62-F057. BOP installs jumper to reopen the valve. (ABN) 7. mnb105 mca015 (M) ALL Small Steam LOCA from MSL with primary containment pressure suppression function failure

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor (T)ech S pec APPROXIMATE SCENARIO RUN TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ES-301-4 Quantitative attributes:

Total Malfunctions (5

-8): 6 Malfunction(s) after EOP (1

-2): 1 (E-7) Abnormal Events (2

-4): 4 (E2 , 3, 5, & 6) Major Transient(s) /E

-Plan entry (1

-2): 1 (E7) EOPs (1-2): 2 (LGA-001 & LGA-003) EOP Contingencies (0

-2): None Critical Tasks (2

-3): 2 ES-301-5 Quantitative attributes:

BOP Normal: None ATC Reactivity (1 per set):

E1 BOP I/C (4 per set): E3&6 ATC I/C (4 per set):

E2&5 SRO-I I/C (4 per set inc 2 as ATC): E2,3, 5,&6 SRO Tech Spec (2 per set):

E4 ALL Major Transients (2 per set)

E7 NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 7 of 27 GENERAL OBJECTIVE:

(USED THROUGHOUT THIS EXERCISE) 769.00.01 During performance of tasks, dynamic learning activities, or formal evaluations, demonstrate applicable Human Performance behaviors IAW the appropriate procedures.

TASKS RO - ATC 31.014 Perform control room actions to respond to a failure of automatic RWLCS 47.001 Given Unit Supervisor authorization, Perform a Notch Withdrawal of a Control Rod IAW station procedures.

47.0 02 Provided initial conditions, Respond to a Failure of a Control Rod To Respond to an Insert or Withdrawal Signal IAW station procedures.

111.002 Given Unit Supervisor authorization respond to a Loss of Condenser Vacuum IAW station procedures. 410.000 Given entry in LGA

-001, RPV control, with the main turbine bypass valves unavailable, stabilize RPV pressure IAW station procedures 413.000 Given LGA-001, RPV control, in progress, evaluate plant conditions and control RPV water level +11 to +59.5 inches using preferred sources, IAW LGA

-001. 768.010 During performance of tasks demonstrate the following performance behaviors: Reactivity Management, IAW station procedures.

RO - BOP/ASSIST 51.001 Given Unit Supervisor permission, verify proper operation of the Main Control Room Area Radiation Monitoring Panels IAW station procedures 71.041 Provided initial conditions, perform Control Room actions for a Gland Seal Steam evaporator casualty, IAW station procedures 80.008 Given Unit Supervisor authorization, Perform the Main Control Room actions to startup the Off Gas System IAW station procedures 111.002 Given Unit Supervisor authorization respond to a Loss of Condenser Vacuum IAW station procedures.

419.000 Given L GA-003, Primary Containment Control, in progress Evaluate plant conditions and control and maintain Primary Containment Pressure to less than 1.93 psig, IAW station procedures 419.020 Given LGA-03, Primary Containment Control, in progress, spray the Suppression Pool, IAW station procedures.

419.030 Given LGA-03, Primary Containment Control, in progress, spray the Drywell, IAW station procedures.

768.010 During performance of tasks demonstrate the following performance behaviors: Reactivity Management, IAW station procedures.

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 8 of 27 UNIT SUPERVISOR 31.014 Perform control room actions to respond to a failure of automatic RWLCS 201.011 Given a set of plant conditions, identify and prepare the Technical Specification required actions, IAW Technical Specifications.

410.000 Given entry in LGA

-001, RPV control, with the main turbine bypass valves unavailable, stabilize RPV pressure IAW station procedures 413.000 Given LGA-001, RPV control, in progress, evaluate plant conditions and control RPV water level +11 to +59.5 inches using preferred sources, IAW LGA

-001. 419.000 Given LGA-003, Primary Containment Control, in progress Evaluate plant conditions and control and maintain Primary Containment Pressure to less than 1.93 psig, IAW station procedures 768.010 During performance of tasks demonstrate the following performance behaviors: Reactivity Management, IAW station procedures.

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 9 of 27 Event - 1 Description

Pull control rods per the sequence package.

Initiation:

Following turnover, at Lead Examiners direction.

Obj. Position EXPECTED OPERATOR RESPONSE 47.001 ATC Per LGP-1-1 Continue to increase CTP with control rod withdrawal.

Monitor IRM and APRM recorders. Verify Main Turbine BPVs open as reactor power increases.

Per LOP-RM-01: Verify Rod desired to be positioned is selected on the Rod Select Display or Status Display, if in control mode.

Verify rod position information is correct on the Rod Select Display/Status Display/Core Map Display.

Verify no insert or withdraw block indications on the Rod Select Display.

Verify CRD Drive Flow Trip Circuit Bypass Switch is in the NORMAL position DEPRESS rod WITHDRAW push-button and CHECK control rod withdrawal sequence begins:

Rod insert indication appears on the Rod Select or Status Display.

Rod withdraw indication appears on the Rod Select or Status Display Control Rod motion is indicated on the Rod Select or Status Display.

RELEASE rod WITHDRAW pushbutton and CHECK: Rod position indication on Rod Select Display, Status Display or Core Map shows new rod position.

Observe changes in nuclear instrumentation indications.

Rod settle light is lit for 2 seconds.

BOP Monitors control room panels and notifies the CR S of any unusual or unexpected conditions.

Peer checks rod movements CRS Directs actions above.

Enforces OPS expectations and standards Emphasizes need for caution and conservatism during the power change.

Ensures operations are conducted within the bounds of Tech Specs and IAW Operations standards and approved procedures.

Ensures OPS activities are completed as scheduled.

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 10 of 27 Event - 1 Description

Pull control rods per the sequence package Simulator Operator Actions None Simulator Operator Role Play None Floor Instructor Notes/OPEX/TR's N one NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 11 of 27 Event - 2

Description:

Stuck control rod Initiation:

When a withdraw of Rod 18

-11 is attempted Key Parameter Response:

Drive flow raises with no rod movement Expected Annunciators:

N o ne Automatic Actions:

N one Obj. Position EXPECTED OPERATOR RESPONSE 47.002 A TC Per LOA-RD-101 section B.4 Check control rod failed to move with drive water pressure

> 450 psig or using LOP-RM-01 CHECK control rod positions NORMAL VERIFY CRD Hydraulic system NORMAL (63 gpm flow

- 250 to 300 psid drive water pressure)

Response not obtained Throttle the following valves as required o 1C11-R600 (FCV 1C11

-F002A/B) o PCV 1C11-F003 Insert/Withdraw apparent stuck control rod (Observe RCMS indications for normal directional control valve sequencing

) Check directional control valve sequence normal Raise drive water pressure to 500 psid Insert/Withdraw control rod Check control rod moved Response not obtained Perform the following Raise drive water pressure in increments of 50 psid, from 550 to 750 psid After each incremental increase in drive water pressure up to 750 psid, return to step 7 and attempt control rod movement Return drive water pressure to normal Insert/Withdraw control rod to in sequence position Note any applicable information in Unit Log and LOP

-RM-01 Attachment A Closely monitor further movements of affected control rod and exit this procedure BOP Monitor BOP and peer check ATC actions as necessary US Direct and supervise crew actions in LOA

-RD-101 NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 12 of 27 Event - 2

Description:

Stuck control rod (18-11) Simulator Operator Actions Inserted at setup:

imf mrd217 (Rod 18-11 Stuck) Event Trigger 2 Verify the following commands associated with Event Trigger 2:

trgset 2 "g3f02g1d.gt.0.67" (When CRD Drive pressure >515 psig) trg 2 "dmf mrd217" (On Event Trigger 2, Rod 18

-11 malfunction deleted)

Simulator Operator Role Play N one Floor Instructor Notes/OPEX/TR's N one NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 13 of 27 Event - 3

Description:

Steam Seal Header Pressure CANNOT be maintained and must establish manual control.

Initiation:

At direction of Lead Examiner, activate Manual Trigger 3.

Key Parameter Response:

Steam Seal Header Pressure, Steam Seal Feed Pressure Expected Annunciators:

1PM02J A105, Gland Seal Steam Aux Feed Vlv Ope n & 1PM02J A205 , Gland Seal Steam HDR Press LO Automatic Actions: None Obj. Position EXPECTED OPERATOR RESPONSE 71.041 BOP Per LOR-1PM02J A105 CHECK Gland Seal Steam pressure is between 2 and 6 psig.

IF Gland Seal Steam pressure is decreasing, THROTTLE OPEN 1GS

-S2, Steam Seal Evaporator Outlet Steam PCV M.O. Bypass Valve, to re

-establish Gland Seal Steam Monitor Condenser Vacuum IF parameters indicate an inability to supply sealing steam from Steam Seal Evaporator, ESTABLISH Gland Sealing Steam per procedure LOP

-GS-03, Transfer to Backup Gland Seal Steam Supply Per LOR-1PM02J A205 Dispatch Operator to EL 768' in TB to INSPECT Gland Seal Steam Control Panel 1PL81J and Gland Seal Steam Evaporator Control Panel 1PA80J for proper operation.

Refer to LOA

-GS-101 Per LOA-GS-101 CHECK Stm Seal Header Press, 1PI

-GS026 at 1PM02J INDICATES BELOW 6 PSIG CHECK Feed Press, 1PI

-GS019 at 1PM02J

- INDICATES above 40 PSIG CHECK Level, 1LI

-GS018 at 1PM02J

- INDICATES 6 TO 8 inches CHECK Stm Seal Header Press, 1PI

-GS026 at 1PM02J INDICATES above 2 PSIG

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 14 of 27 (Event 2 Continued)

Obj. Position EXPECTED OPERATOR RESPONSE 74.041 BOP Response not obtained VERIFY 1GS

-S1, SSEVP Outlet PCV Upstrm Stop at 1PM02J fully open THROTTLE 1GS

-S2, SSEVP Outlet PCV Bypass Stop at 1PM02J to maintain 4 to 6 psig on Stm Seal Header Press, 1PI

-GS026 If pressure can not be maintained 4 to 6 psig, LINEUP main steam to seals VERIFY 1GS001, SSEVP Main Steam Supply Stop at 1PM02J Open OPEN 1GS002, SSEVP Bypass Stop at 1PM02J OPEN 1GS-S6, SSEVP Bypass PCV Upstrm Stop at 1PM02J CLOSE 1GS-S2, SSEVP Outlet PCV Bypass Stop at 1PM02J CLOSE 1GS-S1, SSEVP Outlet PCV Upstrm Stop at 1PM02J If Stm Seal Header Press, 1PI

-GS026 at 1PM02J indicates below 4 psig, THROTTLE 1GS

-S7, SSEVP Bypass PCV Bypass Stop at 1PM02J to maintain 4 to 6 psig.

S RO Direct Actions of LOR

-1PM02J A105 and LOR

-1PM02J A205 Sets Critical Parameters and Directs actions of LOA

-GS-101 NOTIFY RP of plant configuration change May refer to ODCM for Pretreat with elevated Off Gas flow May direct filling Off Gas Loop Seals ATC Monitor the Plant for Anomalies

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 15 of 27 Event - 3

Description:

Steam Seal Header Pressure CANNOT be maintained and must establish manual control.

Simulator Operator Actions Manual Trigger 3 Verify the following commands associated with Manual Trigger 3:

ior q5h03lr1 (3) off (On Trigger 3, GS Header PCV Stop MOV

-GS-S1 Red/closed light off) ior q5h03rg1 (3) on (On Trigger 3, GS Header PCV Stop MOV

-GS-S1 Grn/Open light on) ior k5h03jc1 (3) close (On Trigger 3, GS PCV Stop MOV

-GS-S1 switch to close) ior k5h03jn1 (3) false (On Trigger 3, GS PCV Stop MOV

-GS-S1 Open position false) ior k5i04jc1 (3) close (On Trigger 3, PCV Bypass GS

-S2 closed) ior k5i04jn1 (3) false (On Trigger 3, PCV Bypass GS

-S2 Open position false)

Simulator Operator Role Play Role Play:

If dispatched as an EO, wait 3 minutes and report: PCV has failed closed as it is demanding the valve be open but it is closed.

Floor Instructor Notes/OPEX/TR's N one NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 16 of 27 Event - 4

Description:

Failure of 1C Fuel Pool Exhaust Radiation Monitor downscale. Initiation:

At direction of Lead Examiner, activate Manual Trigger 4.

Key Parameter Response:

C Rad Monitor White low light lit and meter downscale Expected Annunciators:

LOR-1H13-P601-E305, DIV 2 Fuel Pool Rad Mon Downscale Automatic Actions

none Obj. Position EXPECTED OPERATOR RESPONSE ATC Monitor plant for abnormalities.

51.001 BOP Per LOR-1H13-P601-E305 Check which Div 2 Fuel Pool Radiation Monitors are reading less than or equal to alarm setpoint.

Identifies that 1C Fuel Pool Exhaust Radiation Monitor is downscale Check if monitors are energized.

Identifies that 1C Fuel Pool Exhaust Radiation Monitor has power 201.011 CRS Evaluate plant conditions and control secondary containment per LOR

-1H13-P60 1-E305 Refer to T.S. 3.3.6.1, 3.3.6.2, 3.6.1.3, and 3.6.4.2 Evaluate for entry into LGA

-002 NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 17 of 27 Event - 4

Description:

Failure of 1C Fuel Pool Exhaust Radiation Monitor downscale.

Simulator Operator Actions Manual Trigger 4 Verify the following commands associated with Manual Trigger 4:

imf mrm0 2 1 (On Trigger 4, C FP Vent PRM Downscale failure)

Simulator Operator Role Play None Floor Instructor Notes/OPEX/TR's N one NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 18 of 27 Event - 5

Description:

Master FWLC setpoint fails to 45, requiring manual level control for remainder of scenario.

Initiation:

At direction of Lead Examiner, run CAE File: NRC Scenario 11 2 Event 5.cae Key Parameter Response:

RWL reaches 45 inches Expected Annunciators:

1H13-P603-A309, Feed Water Control

- Reactor Water Level 7 Hi Automatic Actions: None Obj. Position EXPECTED OPERATOR RESPONSE 31.014 ATC Per LOA-FW-101 VERIFY all M/A Xfr Stations are in MANUAL IF Failed, PLACE backup controller in service STABILIZE reactor water leve l o ADJUST demand on M/A or Backup Stations o MATCH steam flow and feed flow o REDUCE reactor power with recirc flow CHECK Reactor Water Level greater than 11.0 inches CHECK Reactor Water Level less than Level 8 Alarm/Trip CHECK no Level Signal Failure condition BOP Monitor plant for abnormalities 31.014 CRS Establish critical parameters and manual scram criteria

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 19 of 27 Event - 5

Description:

Master FWLC setpoint fails to 45, requiring manual level control for remainder of scenario.

Simulator Operator Actions When directed, run CAE File:

NRC Scenario 11 2 Event 5.cae Simulator Operator Role Play Role-play: IF requested: Respond as WWM for response and/or request.

Floor Instructor Notes/OPEX/TR's none NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 20 of 27 Event - 6

Description:

Spurious Isolation of 1N62

-F057 Initiation:

At direction of Lead Examiner, activate Manual Trigger

6. Key Parameter Response:

1N62-F057 closed light energized Expected Annunciators:

1N62-P600-B204, OFF GAS OUTLET FLOW ABNORMA L 1N62-P600- B208, OFF GAS POST

-TRMT PNL 0PL99J RAD TROUBLE Automatic Actions:

None Obj. Position EXPECTED OPERATOR RESPONSE 111.002 ATC Per LOA-OG-101 Reduce power as needed to maintain condenser backpressure less than:

o 5 inches with reactor power less than 75%

o 6.5 inches with reactor power greater than 75%

80.008 BOP Per LOR-1N62-P600-B204 CHECK off gas flow recorder 1N62

-R604 to determine if flow is hi

-hi-hi or low VERIFY operation of:

o OG system per LOP

-OG-07 o HWC system per LOP

-HW-02 IF OG Hold

-up line outlet flow is low CHECK valve line

-up on train in operation CHECK for OG system ruptures upstream of after filters INITIATE air addition by opening 1N62

-F007A/B at panel 1N62

-P601 in order to maintain H2 Concentration <4% in OG Per LOA-OG-101 CHECK 1N62

-F057 isolated due to:

o Valid High Rad Signal o Loss of power o Loss of IA to the valve Response not obtained Take C/S for 1N62

-F057 to CLOSE GO TO Attachment C to defeat BOTH Off Gas Post Treatment Radiation Monitor isolation signals OPEN 1N62-F057 Refer to ODCM 12.2.2 Exit this procedure 80.008 111.002 CRS Direct actions per LOA

-OG-101 May establish Critical parameter for condenser backpressure Reference ODCM 12.2.2

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 21 of 27 Event - 6

Description:

Spurious Isolation of 1N62

-F057 Simulator Operator Actions Manual Trigger 6 Verify the following commands associated with Manual Trigger 6: ior k7c84bzz (6) false (On Trigger 6, Spurious isolation of 1N62

-F05 7) After jumpers are installed, per Floor Instructor, delete this override:

k7c84bzz Simulator Operator Role Play Role-play: IF requested: Respond as WWM/SOS for response and/or request.

Role-Play: If requested to check the fuse for 1B Posttreat Rad Monitor, report that the fuse is good Floor Instructor Notes/OPEX/TR's The following overrides/malfunctions are in place at the start of the scenario for more accurate Off Gas system status:

A dsorber delta pressure (R612 = 1 psid

) A dsorber temperature recorder pens 1 and 2 are down to 75 and annunciator LOR

-1N62-P600-B406, LOR-1N62-P 600-B407, and LOR

-1N62-P600-B506 are OFF.

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 22 of 27 Event - 7

Description:

Small Steam LOCA from MSL with primary containment pressure suppression function failure Initiation:

At direction of Lead Examiner, activate Manual Trigger 7.

Key Parameter Response: on 1PM13J: 1PR

-CM031 and 1PR

-CM029 indicate a rising DW pressure Expected Annunciators:

1H13-P603-B501, 1PM13J

-B302, and 1PM13J

-A204 Automatic Actions:

Rx Scram Obj. Position EXPECTED OPERATOR RESPONSE 304.010 410.000413.000 ATC Responds to the reactor scram per LGP 2 Attachment E (hardcard):

ARM and DEPRESS Scram Pushbuttons PLACE Reactor Mode Switch in SHUTDOWN INSERT IRMs and SRMs CHECK Control Rods INSERTED and Power Decreasing INFORM Unit Supervisor Of Rod Status and Reactor Power REPORT to the Unit Supervisor the status of RPV Level and Pressure VERIFY Reactor Recirculation Pumps have downshifted VERIFY Main Turbine and Generator Trip STABILIZE Reactor Pressure <1020 psig REFER to LGP 2 Manually controls level and pressure as directed May secure HPCS 421.000 CT CT SRO When Drywell Pressure exceeds 1.93 psig, enters and directs actions of LGA-003 May direct opening all Turbine Bypass Valves Before Drywell Pressure exceeds 12 psig, directs start of Suppression Chamber Sprays When Drywell Pressure exceeds 12 psig:

Verifies Containment Flood level below 723 ft.

Verifies Drywell Pressure and Temperature permit Drywell Sprays per Figure D. Verifies both Recirc Pumps are tripped

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 23 of 27 (Event 7 Continued)

Obj. Position EXPECTED OPERATOR RESPONSE 421.000 BOP When directed, starts all available Pool Cooling per LGA

-RH-103 Startup RHR Service Water as follows:

OPEN 1A/1B RHR Hx Service Water Outlet Valve:

1E12-F068A/B At approximately 9 to 10 seconds after taking the 1E12

-F068A/B switch to OPEN, START first RHR Service Water Pump:

1A or 1B/C or D When indicated flow reaches 3000 gpm, START second RHR Service Water Pump.

Startup RHR Start 1A/1B RHR Pump Establish RHR flow of 1500 to 7450 gpm:

Throttle 1E12

-F024A/B (Test Valve) OPEN.

Close 1E12

-F048A/B (HX Bypass)

Place A/B HTX Bypass Throttle/Seal in switch to THROTTLE and THROTTLE CLOSED 1E12

-F048A/B. or Place A/B HTX Bypass Throttle/Seal in switch to SEAL IN and CLOSE 1E12

-F048A/B 421.000 CT CT BOP To Establish Suppression Chamber Spray:

VERIFY 1A/1B RHR Pump is running.

OPEN 1E12-F027A/B. To Establish Drywell Spray:

VERIFY 1A/1B RHR Pump is running.

THROTTLE 1E12

-F024A/B CLOSED.

OPEN: 1E12-F016A/B. 1E12-F017A/B. To Prevent losing Chamber Spray/ECCS runout with DW Spray prior to 500 psig Place Div 1/2 Inj Override Switch to NON-ATWS Div I: With an ECCS signal present Verify White Manual Override light for 1E12-F042A AND 1E21-F005 Illuminated.

(NOTE: If level 1 is received LPCS override will clear and LPCS will Inject)

Div II: With an ECCS signal present Verify White Manual Override light for 1E12-F042B AND 1E12-F042C Illuminated.

(NOTE: If level 1 is received 1C RHR override will clear and 1C RHR will Inject)

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 24 of 27 Event - 7

Description:

Small Steam LOCA from MSL with primary containment pressure suppression function failure Simulator Operator Actions Manual Trigger 7 Verify the following commands associated with Manual Trigger 7:

imf mnb105 (7) 100 (On Trigger 7, MSL Break inside DW at 100 lb/sec severity) imf mca015 (7) 100 (On Trigger 7, Primary Containment Bypass Path at 100% severity) Simulator Operator Role Play N one Floor Instructor Notes/OPEX/TR's TERMINUS Suppression chamber spray has been established.

Drywell Spray established prior to exceeding PSP curve.

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 25 of 27 REFERENCES Procedure Title 1. LGP-1-1 NORMAL UNIT STARTUP

2. LGP-3-2 REACTOR SCRAM

3. LOP-RH-05 OPERATION of RHR SERVICE WATER SYSTEM

4. LOP-RH-13 SUPPRESSION POOL COOLING OPERATION

5. LOP-RM-201 REACTOR MANUAL CONTROL OPERATION

6. LOR-1PM02J-A104 GLAND SEAL STEAM EVAPORATOR LEVEL HI/LO 7. LOP-RM-01 ROD CONTROL MANAGEMENT SYSTEM

8. LOA-GS-101 U1 TURBINE GLAND SEAL STEAM SYSTEM ABNORMAL

9. LGA-001 RPV CONTROL

10. LGA-003 PRIMARY CONTAINMENT CONTROL

11. LOR-1PM02J A105 GLAND SEAL STEAM AUX FEED VLV OPEN

12. LOR-1PM02J A205 GLAND SEAL STEAM HDR PRESS LO 13. LOR-1H13-P601-E305 DIV 2 FUEL POOL RAD MON DOWNSCALE

14. LOR-1N62-P600-B204 OFF GAS OUTLET FLOW ABNORMAL

15. LOA-OG-101 UNIT1 OFF GAS SYSTEM ABNORMAL

16. LOR-1H13-P603-B501 PRIMARY CONTAINMENT PRESSURE HI AND LO

17. LOR-1PM13J-B302 TB, RB, AND RW BUILDING VENT EXH CAM LOW FLOW

18. LOR-1PM13J-A204 HI DRYWELL COOLER DRAIN FLOW TO DRYWELL FLOOR DRAIN

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 26 of 27 Crew Tasks ATTACHMENT 04 Scenario Validation Checklist Page 1 of 1 Initial 1 Verify with the Simulator Coordinator that the current training load is based on the current plant core.

2 The scenario performance objectives/tasks are listed in the scenario guide.

3 Simulator initial conditions are achievable.

4 The scenario guide clearly indicates the instructor station commands needed to achieve the performance objectives. 5 All malfunctions and other instructor station commands are entered in the sequence described in the scenario guide, and all items responded to support the performance objectives.

6 The simulator requires the operator to take the same action on the simulator as in the plant, using the reference plant operating procedures.

7 For annual exam scenarios, OBEs, and EP scenarios the scenario is validated in real time by an operating team consisting of SRO certified or licensed personnel using all referenced procedures and adhering to management expectations.

_____ 8 The responses of the simulator during the scenario were realistic, and observed changes correspond to expected plant response.

- Important / Critical Parameters (e.g., Flow, Power, Pressure, Radiation Level, Temperature, and Water Level)

- Annunciators

- System or component status indications 9 Tech Spec items / LCO declarations are correct. Appropriate documentation available.

10 Reportability requirements

/ Probabilistic Risk Assessments (if included) are correct. Appropriate documentation available.

Note: Wind speed and direction may be variable based on simulator modeling. ENSURE that these parameters are verified when validating the scenario.

11 Emergency Action Level classifications and PARs are identified, including whether or not there is a radiological release, the wind speed, and wind direction.

_____ 12 Critical tasks determined if applicable.

_____ 13 Shutdown scenarios include shutdown risk assessment, time to boil calculations and shutdown status board information.

14 Procedure steps that may be confusing or disagree with higher

-level procedures are discussed with operations management and expectations defined. Suggested enhancements are entered into the appropriate tracking system. 15 Management expectations are re

-enforced. 16 Scenario run time is in accordance with the stated quantitative attribute time.

17 Refer to EP

-AA-122-1001-F-07 for additional EP scenario validation criteria.

NRC 11-1-2 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 27 of 27 U1 SUPERVISOR TURNOVER Unit 1 power level Unit 2 power level Startup in progress Continue at Step E.5, withdrawing control rods to achieve 11/2 Turbine Bypass valves open 100 % Power 35 32 MWt U1 Thermal Limit Issues /Power Evolutions U2 Thermal Limit Issues /Power Evolutions Reactor Startup None Existing LCOs, date of next surveillance Existing LCOs, date of next surveillance A Off Gas Posttreat Monitor Inoperable, ODCM 12.2.2 None LOSs in progress or major maintenance LOSs in progress or major maintenance None non e Equipment removed from service or currently unavailable None None Grid Status is Green Online Risk

- Green Grid Status

- Green Comments, evolutions, problems, etc.

Div 3 Workweek. OLR is Green Cycle Fundamentals

New Operators/Crew Integration Supervisory Oversight/Feedback Core Fundamental Execution:

Weekly Focus

Tool Safety Oncoming U1 CRS:

No change in Medical status IRs turned over/reviewed Shiftly & Turnover reviewed Walkdown completed

___________________________

/ Name Date Shift: Days Date: Today Online Risk

Green Div 3 Workweek Next T/C: None OP-AB-300-1003 Revision 8 Page 1 of 19 Attachment 1 Reactivity Maneuver Approval Cover Page Page 1 of 2 Station: LaSalle Unit: 1 Valid Date(s): September 1, 20 1 2 through December 1, 20 1 2 Reactivity Maneuver Plan #: Are Multiple Activations Allowed (If yes, US may make additional copies): L 1 C1 5-01 Yes Prepared by:

___REACTOR ENGINEER__/__8/30/12____ Reviewed by: __

Qualified REACTOR ENGINEER /_8/30/12 Reactor Engineer / Date Qualified Nuclear Engineer / Date

_ Approved by:__

Rx. Enginneering Manager_/_8/30/12__ Authorized by:

__Senior Reactor Operator____/_8/31/12 RE Manager/ Date Senior Reactor Operator/ Date

__ NF Review Declined: Y /

N NF Review by: ___

Nucelar Fuels_____/_8/30/12 NF Individual Contacted/Date

_____ ReMA Activated:

___Unit Supervisor___/__Today Unit Supervisor / Date Unit Supervisor / Date

_ ReMA Terminated:

______________/______

Title of Evolution: Beginning of Cycle (BOC) Startup for Unit 1 Cycle 1 5 Purpose/Overview of Evolution: The purpose of this ReMA is to provide guidance for (1) pulling rods to criticality, heating up to rated pressure, and raising power to put unit online; (2) raising power to above 25% CTP and upshifting Reactor Recirculation Pumps; (3) performing plant systems testing and raising power to ~70% CTP; (4) ramping to rated power and continuing plant systems testing; and (5) maintaining rated power with core flow and/or control rods until steady

-state operation is achieved

. Maneuver Steps

1. Pull rods to criticality and continue through Mode 1 per LGP 1 to <25% CTP

. 2. Continue startup per LGP 1 to above 25% CTP and 3. Perform required testing and ramp power to ~70% CTP.

upshift Reactor Recirculation Pumps.

4. Continue required testing and ramp to rated power and possibly reduce core flow to withdraw more control rods

. 5. Maintain rated power using core flow and/or rods per QNE recommendation.

OP-AB-300-1003 Revision 8 Page 2 of 19 General Issues from ARI to <25% CTP:

Rod Movements and RWM operations will be performed IAW LOP

-RM-01. Station Activities related to the Unit Startup will be performed in parallel with this ReMA IAW LGP 1. Remain within the analyzed rod position sequence for CRDA and notch/step worth calculations concerns by following the startup sequence until > 10% CTP (LPSP). QNE will assist with monitoring the approach to criticality using the Count Rate Doubling Method.

Estimated Critical Position (ECP) and proximity to criticality after each SRM doubling should be communicated to the Reactivity SRO High Worth Control Rods are annotated on the Sequence If any control rods are to remain at 00 for the startup, the QNE should ensure that the startup sequence has been analyzed to address potential notch worth and step worth issues After achieving criticality, a delay in rod withdrawal during reactor heat

-up can result in the reactor becoming subcritical, as indicated by lowering SRM/IRM count rates.

Criticality should be anticipated whenever rods are being withdrawn. Use of all available indications of neutron flux AND reactor period is necessary to effectively monitor the approach to criticality.

If reactor becomes sub

-critical then ENSURE new ECP is performed prior to resuming rod withdrawals.

Ensure the RWM is loaded with the appropriate startup sequence.

Ensure Moderator Temperature effects are discussed including the potential for a positive moderator temperature coefficient.

Discuss status of Nuclear Instrumentation. If an SRM is inoperable then ensure sufficient time between rod pulls is taken to ensure proper SRM response.

Ensure any control rods with known deficiencies are identified and contingencies have been discussed.

Place "Reactivity Change In

-Progress" signs in their applicable plant locations as time allows.

OPEX a. OE15834, Rod Worth Minimizer Found Bypassed During Startup

b. OE22349, Mispositioned Control Rod During Startup

c. OE20268, Unexpected Half Scram due to Low RPV Water Level

d. SER 6-00, Cultural Contributors to Premature Criticality

e. OE24212, Unexpected OPRM

-Related Half

-Scram During Plant Start

-Up f. OE26672, Mis

-positioned Control Rods During Reactor Start

-up g. SEN 185, Recurring Event, Inappropriate Continuous Rod Withdrawal From Subcritical Conditions

h. SEN 209, Recurring Event, Unexpected Criticality and Short Period on a Continuous Rod Withdrawal

i. NER NC-10-046-Y, Unexpected Divergence of SRM Response During Startup (Quad Cities Unit 2) j. OE34037, Reactor SCRAM on IRM HI

-HI Setpoint During Startup Following a Refueling Outage (Pilgrim) k. SOER 88-02, Premature Citicality Events During Reactor Startup

OP-AB-300-1003 Revision 8 Page 3 of 19 Additional General Issues:

Remain within the analyzed rod position sequence for CRDA concerns by following the startup sequence (L 1 C1 5-r1.0) until > 10% CTP.

Core thermal power calculations and APRM calibrations at less than 25% CTP (until heat balance programs are validated), are performed IAW NF

-AB-763 and LTP

-1600-10. QNE hold points are established in OP

-AB-300-1003, Attachment 5 to allow for POWERPLEX predictions to be run.

QNE will assist with monitoring the margin to thermal limits.

For BOC startups (per NF

-AB-440-1002), Atrium-10 and GNF-2 fuel require s monitoring of the fuel

-conditioning threshold and ramp rates at all times. Thresholds are set per NF

-AB-440-1002. The QNE will assist with monitoring the nodal ramp rates IAW NF

-AB-440-1002. Thermal limits will not be listed as critical parameters for steps where 10% margin is expected. APRM GAFs must be checked continuously during power changes (Dresden IR 1328879, APRM GAFS out of tolerance)

When above 100% FCL, core flow should remain above 65 Mlb/hr. This is a precaution/contingency in place due to the issue regarding the OPRM HI alarm received on Unit 1 (IR 945016).

Observe the monitoring requirements specified in LGP 1 and LGP-3-1. When in high RR pump speed, a change of 1.4 Mlbs/hr corresponds to a ~10 M We change. Rod movements and RWM operations will be performed IAW LOP

-RM-01 and LOP

-RM-02. Per OP-AB-300-1003, section 4.2.11, QNE presence in the main control room is required for reactor startups from All Rods In to the Point Of Adding Heat, for all control rod withdrawals above 25% CTP, and for all RR flow increases greater than 5% per hour.

The troubled rod list should be reviewed prior to this maneuver. Rods with issues with the potential to affect reactivity have been identified in the comments section on sequences prepared for this maneuver.

The target startup rod pattern is ARO except for the 9A rod at 12, 9B rods at 00, 9C rods at 12 and 9D rods at 18. The limiting parameters in this maneuver are expected to be MFLPD, MFDLRX, MFLCPR, FCL, and fuel conditioning. It is expected that on the initial ramp to full power, the 10A rods will be at 24 and the 10B rods at 18, while the group 9A

-9D rods will be at 00. As Xenon and Samarium build in, the group 9 rods will be notched out.

The 10B and 10A rods will then be withdrawn to 48 after Samarium builds in during a load drop on ~April 8, 2012 using a new ReMa.

- However, these predictors were run without the input of LPRMs (since the unit has not started up) so there is a greater predictor uncertainty.** During rod pulls or xenon burnout, use a correlation of 10 MWe 1% FCL to estimate the margin to the MELLLA boundary.

When raising power with core flow, use a correlation of 20 MWe 0.20 kW/ft to estimate margin to fuel conditioning limits and a 12 MWe change 0.01 change in LHGR to estimate the margin to MAPRAT and MFDLRX thermal limits.

Startup testing and surveillances IAW NF

-AB-710 will be performed in parallel with the activities in this ReMA.

OP-AB-300-1003 Revision 8 Page 4 of 19 Reactivity

-related equipment issues have been evaluated for impact on this maneuver At the time the ReMA was prepared, Unit 1 was expected to have 1 LPRMOOS (56

-17D). This does not adversely impact core monitoring capability.

See the attached Troubled Rod List for issues related to CRD movement.

Plant procedures for Operations require that reactivity be changed only in a deliberate, carefully controlled manner while nuclear instrumentation and redundant indications of reactor power and neutron flux are constantly monitored. Primary indications of reactor power include the APRMs, M We, and CTP. Secondary indications include BEPM, FFWT, and Turbine First Stage Pressure. Additional information on the relationship between these and other secondary indications is discussed in LTP

-1600-10 and LOS

-CX-S001. The following sequences are planned to be used during this maneuver. Changes to sequences will be performed iaw NF

-AB-720. Sequence Name RCMS Name RCMS cksum/keyword Description L1C1 5-r 1.0 SAr1.0 7ABC All Rods in Startup Sequence L1C15-r1.0a SAr1.0a 7D98 Compressed Startup Sequence following groups 1-4 pulled L1C15-r1.0b SAr 1.0b 7BD1 Compressed Startup Sequence following groups 1

-6, 8 and 7 at 30 pulled L1C15-r1.1 SAr1.1 7405 Simplified Shutdown Sequence

OP-AB-300-1003 Revision 8 Page 5 of 19 Attachment 2 Reactivity Maneuver Guidance Sheet STEP 1 of 5 Reactivity Maneuver Plan #

L 1 C1 5-0Description of Step:

Pull rods to criticality and continue through Mode 1 per LGP 1 to <25% CTP 1 NOTE: The estimated critical prediction is contained in NF

-AB-715, Attachments 1 and

2. A range of predictions based on moderator temperature ha ve been developed.

1. PULL rods to criticality per sequence L 1 C1 5-r1.0 __CRS 2. HEAT UP and pressur ize IAW LGP-1-1 ____ (init. when complete)

__ (init. when complete)

3. CONTINUE startup per LGP 1 to < 25% CTP. If any control rods were not scram timed during the RPV hydro, then Scram

-time testing may be performed IAW LOS-RD-SR12 in this step. Scram timing needs to be performed above the RWM LPSP (10% CTP).

. ____ (init. when complete or N/A)

4. FLUSH and CYCLE from 00-08 then 08

-00 all of the control rods in groups 9 and 10 that have been scra m-timed during this step. ____ (init. when complete or N/A if full core Scram

-testing complete prior to this step)

QNE presence required in the Control Room? Yes _

X_ No __ Onsite Only? Yes __ No X Initial Conditions (may be ranges) to be verified at the START of the Step Parameter Value or Range Init. Parameter Value or Range Init. Estimated Critical Range Provided by QNE Sequence L1C15-r1.0 Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions (if needed)

High Low Reactor Period Monitoring Frequency and Method

During any control rod withdrawal below the point of adding heat using available instrumentation.

Contingency Actions:N/A INSERT last control rod notch withdrawn per the sequence and evaluate reactor period, insert additional notches if required. CONTACT QNE. 50 seconds Heat-up Rate Monitoring Frequency and Method

Continuously during heat

-up using available instrumentation.

Contingency Actions: 100 OF/hr INSERT last control rod notch withdrawn per the sequence and evaluate reactor period, insert additional notches if required. CONTACT QNE. 25 OF/hr from 200 OF for 1 st hour N/A OP-AB-300-1003 Revision 8 Page 6 of 19 CTP Monitoring Frequency:

Hourly and after power changes via POWERPLEX or PPC Heat Balance, calibrated APRMs or manual heat balance. Contingency Actions:

25% INSERT control rods.

N/A Reactor Coolant Temperature (°F)

Monitoring Frequency:

Monitor via 1H13

-P603 panel indications during rod pulls to criticality. Contingency Actions:Do not exceed 212 degrees F prior to achieving criticality Re-establish shutdown cooling or adjust reactor head vents. N/A ReMA Step Complete: _________________/______ Verified by: _______________/_______

Reactor Operator/Date Unit Supervisor/Date

OP-AB-300-1003 Revision 8 Page 7 of 19 Attachment 2 Reactivity Maneuver Guidance Sheet STEP 2 of 5 Reactivity Maneuver Plan #

L 1 C 1 5-0Description of Step: Continue startup per LGP 1 to above 25% CTP 1 and 1. RAISE power above 25% IAW LGP 1. ____ (init. when complete)

Upshift Reactor Recirculation Pumps

2. Before reaching 40% RTP, PERFORM SCRAM timing for all remaining rods IAW L OS-RD-SR12. ____ (init. when complete or N/A if full core Scram

-testing complete prior to this step)

3. FLUSH and CYCLE from 00-08 then 08

-00 IAW the approved sequence all of the control rods in groups 9 and 10 that have been scram

-timed during this step. ____ (init. when complete or N/A if full core Scram-testing complete prior to this step)

4. UP-SHIFT RR pumps. ____ (init. when complete)

QNE presence required in the Control Room? Yes _X_ No __ Onsite Only? Yes __ No X Initial Conditions (may be ranges) to be verified at the START of the Step Parameter Value or Range Init. Parameter Value or Range Init. Core Thermal Power (%)

< 25 MFLCPR 0 RR Pumps Low Speed MAPRAT FCL (%) < 6 3.7 MFDLRX 5 MFLPD 5 Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions (if needed)

High Low FCL (%) Monitoring Frequency:

Monitor every 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and after power changes 50 MWe using PPLX case, heat balance or P/F map.

Contingency Actions:64.7 INSERT control rods per the approved sequence.

N/A ReMA Step Complete: _________________/______ Verified by: _______________/_______

Reactor Operator/Date Unit Supervisor/Date

OP-AB-300-1003 Revision 8 Page 8 of 19 Attachment 2 Reactivity Maneuver Guidance Sheet STEP 3 of 5 Reactivity Maneuver Plan #

L 1 C1 5-0Description of Step: Perform required testing and ramp power to ~70% CTP.

1 RAMP to ~70% RTP at a rate allowed by the fuel conditioning guidelines per the QNE IAW NF

-AB-440-1002. This will involve a combination of control rod withdraws and RR flow adjustments. ____

(init. when complete)

PERFORM a TIP set while maintaining CTP at ~70% with RR flow. ____ (init. when complete)

Note: It may be necessary to raise flow to maintain power at ~70% as xenon builds in. The TIP set will fail if power changes by greater than 5% or if the rod pattern is changed during the TIP set.

LPRMs will not be adjusted based on this TIP set.

QNE presence required in the Control Room? Yes X No __ Onsite Only? Yes __ No X Initial Conditions (may be ranges) to be verified at the START of the Step Parameter Value or Range Init. Parameter Value or Range Init. RR Pumps High Speed MFLCPR MAPRAT MFDLRX MFLPD Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions (if needed)

High Low MFLCPR Monitoring Frequency:

MONITO R with POWERPLEX by evaluating a MON case at least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and, if > 0.90, after power changes 50 MWe. Contingency Actions:

ADJUST the rod pattern and/or core flow as necessary and/or revise the limit, then RE-EVALUATE subsequent ReMa steps

. 0.9 5 N/A MFLDRX Monitoring Frequency:

MONITOR with POWERPLEX by evaluating a MON case at least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and, if > 0.90, after power changes 50 MWe. Contingency Actions:

ADJUST the rod pattern and/or core flow as necessary and/or revise the limit, then RE-EVALUATE subsequent ReMa steps

. 0.9 6 N/A OP-AB-300-1003 Revision 8 Page 9 of 19 MFLPD Monitoring Frequency:

MONITOR with POWERPLEX by evaluating a MON case at least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and, if > 0.90, after power changes 50 MWe. Contingency Actions:

ADJUST the rod pattern and/or core flow as necessary and/or revise the limit, then RE-EVALUATE subsequent ReMa steps

. 0.9 6 N/A Fuel Conditioning, rod pulls Monitoring Frequency:

MONITOR after rod withdrawals with POWERPLEX.

Contingency Actions:

REDUCE core flow and/or RETURN the rod(s) to its previous position per the guidance in NF

-AB-440-1002. For nodes uncovered by control rod:

AREVA: P-PCS < 0.00 kW/ft GNF: P-PCS < 0.35 kW/ft N/A Fuel Conditioning, ramping

Monitoring Frequency:

MONITOR once per hour with POWERPLEX. Contingency Actions:For nodes where P-PCS > 0.00 kW/ft:

SLOW the flow ramp or REDUCE core flow per the guidance in NF

-AB-440-1002. AREVA: (4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months average)

(overshoot)

GNF: 35 kW/ft/hr (4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months average) 45 kW/f t (overshoot)

N/A ReMA Step Complete: ________________/______ Verified by: _____________/_______

Reactor Operator/Date Unit Supervisor/Date

OP-AB-300-1003 Revision 8 Page 10 of 19 Attachment 2 Reactivity Maneuver Guidance Sheet STEP 4 of 5 Reactivity Maneuver Plan #

L 1 C1 5-0Description of Step: Continue required testing and ramp to rated power and possibly reduce core flow to withdraw more control rods.

1 1. After performing the TIP set, RAISE reactor power to rated power using control rod withdrawals IAW sequence L 1 C1 5-r1.0 (as revised) and RR flow. ____ (init. when complete)

2. After achieving full power , MAINTAIN rated power using core flow and/or rods per QNE recommendation and INSTRUCT the QNE to evaluate the need for dropping flow (minimum of 6 5 Mlb/hr) to aid in achieving the target rod pattern for this ReMa. _______ (init. when complete)

REDUCE reactor power with RR flow to a minimum of 6 5 Mlb/hr, if desired. _____ (init. when complete or N/A)

RAISE reactor power to full power using control rod withdrawals IAW sequence L 1 C 1 5-r1.0 (as revised) and RR flow. ____ (init. when complete)

QNE presence required in the Control Room? Yes _X_ No

__Initial Conditions (may be ranges) to be verified at the START of the Step Onsite Only? Yes __ No X Parameter Value or Range Init. Parameter Value or Range Init. MFLCPR 2 MAPRAT MFDLRX 92 MFLPD 92 Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions (if needed)

High Low FCL Monitoring Frequency:

MONITOR at least once hourly and after power changes per POWERPLEX P/F map or PPC Heat Balance data.

Contingency Actions:

RETURN the rod(s) to its previous position.

11 1.2% N/A MFLCPR Monitoring Frequency:

MONITOR with POWERPLEX by evaluating a MON case at least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and, if > 0.90, after power changes Contingency Actions:

ADJUST the rod pattern and/or core flow as necessary and/or revise the limit, then RE-EVALUATE subsequent ReMa steps

. MFLCPR - 0.98 N/A OP-AB-300-1003 Revision 8 Page 11 of 19 MFLDRX Monitoring Frequency:

MONITOR with POWERPLEX by evaluating a MON case at least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and, if > 0.90, after power changes Contingency Actions:

ADJUST the rod pattern and/or core flow as necessary and/or revise the limit, then RE-EVALUATE subsequent ReMa steps

. MFLDRX - 0.9 6 N/A MFLPD Monitoring Frequency:

MONITOR with POWERPLEX by evaluating a MON case at least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and, if > 0.90, after power changes Contingency Actions:

ADJUST the rod pattern and/or core flow as necessary and/or revise the limit, then RE-EVALUATE subsequent ReMa steps

. MFLPD - 0.9 6 N/A Fuel Conditioning, rod pulls Monitoring Frequency:

MONITOR after rod withdrawals with POWERPLEX.

Contingency Actions:

REDUCE core flow and/or RETURN the rod(s) to its previous position per the guidance in NF

-AB-440-1002. For nodes uncovered by control rod:

AREVA: P-PCS < 0.00 kW/ft GNF: P-PCS < 0.35 kW/ft N/A Fuel Conditioning, ramping

Monitoring Frequency:

MONITOR once per hour with POWERPLEX.

Contingency Actions:For nodes where P-PCS > 0.00 kW/ft:

SLOW the flow ramp or REDUCE core flow per the guidance in NF

-AB-440-1002. AREVA: (4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months average)

(overshoot)

GNF: 35 kW/ft/hr (4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months average) 45 kW/ft (overshoot) N/A ReMA Step Complete: _______________/______ Verified by: ___________/_______

Reactor Operator/Date Unit Supervisor/Date

OP-AB-300-1003 Revision 8 Page 12 of 19 ATTACHMENT 2 Reactivity Maneuver Guidance STEP 5 of 5 Reactivity Maneuver Plan #

L 1 C1 5-0Description of Step: Maintain rated power using core flow and/or rods per QNE recommendation 1 1. Once rated power is reached and it is determined that no further load reductions to withdraw more rods will be performed using his ReMa , WITHDRAW FCL control rods per the sequence as allowed by thermal limit margins and the fuel conditioning guidelines to maintain rated power to offset the expected xenon build

-in. ____ (init. when complete

) 2. CLOSE this R eMA with the concurrence of the QNE when it is determined that it is no longer needed. ____ (init. when complete)

QNE presence required in the Control Room? Yes X (for CR Withdrawals only. QNE presence is not required for control rod flushing and subsequent rod cycling

)Initial Conditions (may be ranges) to be verified at the START of the Step No__; Onsite Only? Yes No _X_ Parameter Value or Range Init. Parameter Value or Range Init. FCL (%) < 1 08.2% MFLCPR < 0.9 5 MAPRAT < 0.82 MFDLRX < 0.88 MFLPD 87 Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions (if needed)

High Low FCL Monitoring Frequency:

MONITOR at least once hourly and after power changes per POWERPLEX P/F map or PPC Heat Balance data. Contingency Actions:

RETURN the rod(s) to its previous position.

11 1.2% N/A MFLCPR Monitoring Frequency:

MONITOR with POWERPLEX by evaluating a MON case at least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and, if > 0.90, after power changes MWe. Contingency Actions:

ADJUST the rod pattern and/or core flow as necessary and/or revise the limit, then RE-EVALUATE subsequent ReMa steps

. MFLCPR - 0.98 N/A OP-AB-300-1003 Revision 8 Page 13 of 19 MFLDRX Monitoring Frequency:

MONITOR with POWERPLEX by evaluating a MON case at least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and, if > 0.90, after power changes MWe. Contingency Actions:

ADJUST the rod pattern and/or core flow as necessary and/or revise the limit, then RE-EVALUATE subsequent ReMa steps

. MFLDRX - 0.95 N/A MFLPD Monitoring Frequency:

MONITOR with POWERPLEX by evaluating a MON case at least every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and, if > 0.90, after power changes MWe. Contingency Actions:

ADJUST the rod pattern and/or core flow as necessary and/or revise the limit, then RE-EVALUATE subsequent ReMa steps

. MFLPD - 0.95 N/A Fuel Conditioning, rod pulls Monitoring Frequency:

MONITOR after rod withdrawals with POWERPLEX.

Contingency Actions:

REDUCE core flow and/or RETURN the rod(s) to its previous position per the guidance in NF

-AB-440-1002. For nodes uncovered by control rod:

AREVA: P-PCS < 0.00 kW/ft GNF: P-PCS < 0.35 kW/ft N/A Fuel Conditioning, ramping

Monitoring Frequency:

MONITOR once per hour with POWERPLEX.

Contingency Actions:For nodes where P-PCS > 0.00 kW/ft:

SLOW the flow ramp or REDUCE core flow per the guidance in NF

-AB-440-1002. AREVA: (4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months average)

(overshoot)

GNF: 35 kW/ft/hr (4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months average) 45 kW/ft (overshoot)

N/A Step Complete: ___________________/______

Verified by: _________________/_______ Reactor Operator/Date Unit Supervisor/Date

OP-AB-300-1003 Revision 8 Page 14 of 19 Attachment 5 Reactor Engineer's Evolution Plan/Guidance Reactivity Maneuver Plan #

L 1 C1 5-01 Station/Unit LaSalle Unit 1 Purpose: Valid from: BOC Startup for L 1 C1 5 0 9/1/20 1 2 Valid to:

12/1/20 1 2 Prepared by:

_REACTOR ENGINEER___/_8/30/12 Reviewed by:__QNE_____/__8/30/12 Reactor Engineer Date QNE Date __ Approved by:

__RE M____/__8/31/12 RE Manager Date ______ Evolution Overview:

The purpose of this ReMA is to provide guidance for (1) pulling rods to criticality, heating up to rated pressure, and raising power to put unit online; (2) raising power to above 25% CTP and upshifting Reactor Recirculation Pumps; (3) performing plant systems testing and raising power to ~70% CTP; (4) ramping to rated power and continuing plant systems testing; and (5) maintaining rated power with core flow and/or control rods.

Special Considerations: The target startup rod pattern is ARO except for the 9A rod at 12, 9B rods at 00, 9C rods at 12 and 9D rods at 18. The limiting parameters in this maneuver are expected to be MFLPD, MFDLRX, MFLCPR, FCL, and fuel conditioning. It is expected that on the initial ramp to full power, the 10A rods will be at 24 and the 10B rods at 18, while the group 9A

-9D rods will be at 00. As Xenon and Samarium build in, the group 9 rods will be notched out.

The 10B and 10A rods will then be withdrawn to 48 after Samarium builds in during a load drop on ~April 8, 2012 using a new ReMa.

- However, these predictors were run without the input of LPRMs (since the unit has not started up) so there is a greater predictor uncertainty.** Rod moves

- both order and position - in this attachment have been provided for information only and reflect the predicted maneuver. Any changes to actual moves are governed by NF

-AB-720 and may not require an update to this attachment.

Predictors will also continue to be run throughout startup and rods will be withdrawn as conditions allow. Any changes to actual moves are governed by NF

-AB-720 and do not require a revision to this attachment.

APRM GAFs must be checked continuously during power changes (Dresden IR 1328879, APRM GAFS out of tolerance)

Steps 5b-5 h contain actions that all need to be performed after full power is reached, but are all independent of each other, so these steps can be performed in any order.

OP-AB-300-1003 Revision 8 Page 15 of 19 Guidance: # Activity / Guidance Key Evaluation Results Activity Complete 1a 1. VERIFY QNE qualifications are current.

Pre-Maneuver QNE Guidance

2. ENSURE that the US completes Attachment 7 prior to ReMA activation.

3. ENSURE ReMA Step 1 Initial Conditions (ICs) will be met prior to entering the step.

4. ENSURE that the US authorizes the sequences to be used during the maneuver.

5. MAKE copies of the sequences for the QNE's reference during the maneuver. After the sequences have been authorized, Operations should be given the originals of all sequences when implementing EXCEPT for the shutdown sequence.

6. MAKE a copy of the shutdown sequence after the US authorizes it to be implemented later in the maneuver, but BEFORE the Rod Status Verified and RWM Loaded lines are signed off. ENSURE the Unit QNE retains the original.

7. PARTICIPATE in the Operations PJB/HLA.

1b 1. ENSURE that RWM is loaded with the following sequences:

SAr1.0 SAr1.0a SAr1.0b SAr1.1 2. ACTIVATE sequence SAr1.0, keyword = 7ABC 1c VERIFY the shift has the ECP for the current temperature.

1 d 1. Following reactor critical, DETERMINE Shutdown Margin (SDM) IAW LTS-1100-1 to satisfy TS 3.1.1 within four (4) hours of initial criticality.

Since the R value for SDM is 0.00, this means that a BOC SDM of 0.38% (0.38 + 0.00) must be met. Thus, if the actual critical is earlier than 1.16 (1.54 - 0.38 = 1.16) from the ECP, the SDM will not be met.

2. Notify the Unit Supervisor of the SDM results.

Predicted SDM = 1.54%

OP-AB-300-1003 Revision 8 Page 16 of 19 # Activity / Guidance Key Evaluation Results Activity Complete 1 e 1. After reaching criticality, HEAT-UP to raise pressure and CONTINUE startup per LGP 1 to just less than 25% (~22

-24%) CTP. MAINTAIN power at less than 25% CTP by rod movements.

CTP = 880.6 MWth After ~1 0 hours0 days 0 hours 0 weeks 0 months at ~24.2% CTP (with TL set #3) grps 9 and 10 inserted and 7 A, 7C at 12/30 and 7B at 30) FCL = 4 9% Keff = 1.00 41 MFLCPR = 0.6 12 MAPRAT = 0

.2 48 MFLDRX = 0.

6 07 MFLPD = 0.6 10 P-PCS = - 7.21 kW/ft 1 f Note: At powers greater than 10%

(RWM LPSP), any control rods that were NOT scram timed during the hydro may be scram timed during Step 1. All scram timing must be completed prior to exceeding 40

% power (prior to upshift). Due to the high LHGRFAC penalties, it is preferred to perform any scram time testing below 25% CTP. Otherwise, predicts must be performed to ensure thermal limits are met. Also, if scram timing is performed below 25%, ensure 25% power will not be exceeded if rods at 00 need to be withdrawn to 48 prior to scram timing. After the scram time results are complete, Thermal Limit set 1 for Option B should be implemented.

1. INFORM unit supervisor to perform flushing and cycling of all of the control rods in groups 9 and 10 that have been scram timed in this step.

2. PROVIDE approved sequence to unit supervisor so as to document cycling of rods after flushing.

Note: During reactor heat-up and power ascension RE will perform numerous startup tests as outlined in NF

-AB-710. 2 a 1. RAISE power above 25% and CONTINUE power ascension to approximately 31

-32% RTP IAW LGP 1. CTP = 1068.5 MWth Prior to upshift grps 7A, 7B, and 7C at 30, all grp 9 and 10 rods at 00 FCL = 59.5% Keff = 1.00 3 8 MFLCPR = 0.6 58 MAPRAT = 0.2 74 MFLDRX = 0.672 MFLPD = 0.675 P-PCS = - 6.89 kW/ft WT = 36 Mlbs/hr XE(FULL POWER)

= -68.93%

OP-AB-300-1003 Revision 8 Page 17 of 19 # Activity / Guidance Key Evaluation Results Activity Complete 2 b NOTE: Predictors show at the point of RR upshift the sequence is at the point where all of the group 7 rods are at position 30 , and all other rods are either full in or full out. Consideration should be given to not withdrawing the shallow rods (group 7 in an A2 sequence) prior to upshift if predictors show this will cause a strong bottom peak. However, if xenon has built in to the bottom of the core due to delays in the schedule, it may be acceptable to withdraw some or all of the shallow rods in low speed if predictors show that a strong bottom peak (~5

-10% increase in MFDLRX/MFLPD) will not occur.

1. Prior to RR Up-shift, EXECUTE Powerplex predict cases to model core limits after up

-shift. CTP = 1 388.4 MWth After upshift grp 7 at 30, grp 9 and 10 at 00 FCL = 56.9% Keff = 1.00 41 MFLCPR = 0.6 12 MAPRAT = 0.3 28 MFLDRX = 0.527 MFLPD = 0.529 P-PCS = - 6.21 kW/ft XE(FULL POWER)

= -68.58% 2 c 1. Consider issuing a SHUTDOWN sequence that minimizes sequence steps by having sequence steps of 48

-00 for all rods already at 48, and LOAD it into the RWM and activate. 3a 1. After upshift, RAMP to ~70% RTP at a rate allowed by the fuel conditioning guidelines per the QNE IAW NF

-AB-440-1002. This will involve a combination of control rod withdraws and RR flow adjustments.

Prio r to going above 100% FCL, core flow should be raised above 65 Mlb/hr (IR 945016).

CTP = 2507.1 MWth At ~71% before TIP set, grp 9A, 9B, 9C at 00, 9E at 12, and grp 10B at 12 and 10A at 18. FCL = 94.1% WT = 70.0 Keff = 1.00 42 MFLCPR = 0.8 52 MAPRAT = 0.6 16 MFLDRX = 0.8 58 MFLPD = 0.877 P-PCS = -2.53 kw/ft XE(FULL POWER)

= -67.66% 3b 1. After reaching ~70% power, PERFORM a full core TIP set IAW LTP-1600-7. Note: It may be necessary to raise flow to maintain power at ~70% as xenon builds in. The TIP set will fail if power changes by greater than 5% or if the rod pattern is changed during the TIP set.

If necessary to raise flow, it should be done when a TIP scan is not in progress. LPRMs will not be adjusted.

Document the effect the TIP set has on thermal limits.

3c 1. Consider issuing a SHUTDOWN sequence that minimizes sequence steps, and LOAD it into the RWM

.

OP-AB-300-1003 Revision 8 Page 18 of 19 # Activity / Guidance Key Evaluation Results Activity Complete 4 1. After the TIP set, RAMP to rated power at a rate allowed by thermal limit margins and the fuel conditioning guidelines per the QNE IAW NF

-AB-440-1002. This will involve a combination of control rod withdrawals and RR flow adjustments over several hours. Note: The target startup rod pattern is ARO except for the 9A rod at 12, 9B rods at 00, 9C rods at 12 and 9D rods at 18. The limiting parameters in this maneuver are expected to be MFLPD, MFDLRX, MFLCPR, FCL, and fuel conditioning. It is expected that on the initial ramp to full power, the 10A rods will be at 24 and the 10B rods at 18, while the group 9A

-9D rods will be at 00. As Xenon and Samarium build in, the group 9 rods will be notched out.

The 10B and 10A rods will then be withdrawn to 48 after Samarium builds in during a load drop on ~April 8, 2012 using a new ReMa.

- However, these predictors were run without the input of LPRMs (since the unit has not started up) so there is a greater predictor uncertainty.

- CTP = 3546 MWth At rated power with 9A-9D at 00, 10A at 24 and 10B at 18 FCL = 107.8% Keff = 1.00 4 1 MFLCPR = 0.881 MAPRAT = 0.828 MFLDRX = 0.877 MFLPD = 0.902 P-PCS = 0.36 kW/ft XE(FULL POWER)

= -49.46% 5a 1. After reaching rated power , EXECUTE predict case(s) to assure sufficient margin exists to thermal limits and FCL and to allow termination of QNE coverage in the control room. COMPARE the new predict cases with the previous predict cases that were performed prior to the load drop.

2. WITHDRAW control rods to counteract xenon and Samarium CTP = 3546 MWth At 100%, Steady State Conditions

(~72 hours after reaching full power)

9A at 12, 9B at 08, 9C at 12, 9D at 18, 10A at 24, 10B at 24 Wt = 104.8 FCL = 102.3% Keff = 1.00 4 1 MFLCPR = 0.913 MAPRAT = 0.666 MFLDRX = 0.

7 29 MFLPD = 0.712 P-PCS = -1.56 kW/ft XE(FULL POWER)

= 0.04% 5b 1. INFORM unit supervisor to perform flushing and cycling of all remaining rod groups (grps 1-6 and 8 if not performed previously). PROVIDE approved sequence to unit supervisor so as to document cycling of rods after flushing.

5c COMFIRM a SHUTDOWN sequence that minimizes sequence steps has been issued and loaded into RWM.

5d When it is determined that it is no longer necessary, then CLOSE the REMA. 5e SEND a copy of the predicted vs. actual results (load profile) to the NDO mailbox immediately after full power is reached.

OP-AB-300-1003 Revision 8 Page 19 of 19 # Activity / Guidance Key Evaluation Results Activity Complete 5f COLLECT Post Critique comments from the Control Room Personnel 5g PERFORM a critique of the load profile performance within 3 days of reaching full power as required by step 4.6.3 of OP

-AA-102-101 and SEND to NDO mailbox.

5h PERFORM a critique of the ReMa performance IAW OP

-AB-300-1003 within ~10 days.

SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

LaSalle County Station DYNAMIC SIMULATOR SCENARIO GUIDE ILT Class 11

-1 NRC Exam VG Surveillance Failure, Reduce Power, CRD Flow Setpoint Drift, RR FCV runback, VO Exhaust Fan Trip , Group 1 , Leak between MSIVs, Second Area Above Max Safe , RHR Strainer Clog 11-1-3 Rev. 0 8/3 1/2012

DEVELOPED BY:

Instructor Date VALIDATED BY:

SME/Instructor Date REVIEWED BY:

Shift Operations Supervisor Date APPROVED BY:

Operations Training Manager Date NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 2 of 27 Facility: LaSalle County Station

Scenario No.:

11-1-3 PURPOSE OF SCENARIO Examine the ILT candidate's ability to operate the plant in normal, abnormal, and emergency conditions.

SUMMARY

OF EVENTS 1. LOS-VG-M1 about to start.

When the Primary Fan is started

, the VG Discharge Damper will fail to auto open. US will inform the Shift Manager that the Unit-1 Standby Gas Treatment Train has been declared inoperable due to failing the surveillance.

2. This is a normal reactivity change; the crew will be directed to lower reactor power using Reactor Recirculation Flow Control.

3. The CRD Flow Controller setpoint will fail low causing CRD cooling water flow to decrease. The crew is expected to follow LOA-RD-101 and take manual control of the controller to restore CRD flow. 4. The 1 B RR Flow Control Valve spuriously runs back. The crew is expected to lockup the valve and takes action per LOA-RR-101. The ATC will insert CRAM rods to exit Region 1.

5. The (Offgas Building) VO Exhaust fan trips, requiring a shift to the alternate train per the LOR for the tripped fan and the Offgas Ventilation LOP. 6. A MSL Leak in Steam Tunnel results in a Group 1. D Inbd MSIV fails to isolate fully, the crew performs actions of LGA 001, 002 and 003

. When the Reactor Building Ventilation system fails to automatically isolate, the crew may trip the VR fans and must dispatch an operator to close the isolation dampers locally

. 7. When the leak spreads to the RWCU area and a second area exceeds Max Safe Temperature, the crew will perform a RPV Blowdown per LGA

-004. 8. When Suppression Pool Cooling is started, the BOP operator will discover the RHR pump suction strainer is plugged.

The BOP operator will take actions per LOA-PC-101. Critical Task:

1. Take actions to terminate the release from the Reactor Building

. 2. When to two or more RB areas reach maximum safe values for the area, manually initiate ADS. APPROXIMATE SCENARIO RUN TIME 1.5 hour5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 3 of 27 SER 3-05 1. Monitoring Plant Conditions and Indications Closely

2. Controlling Plant Evolutions Precisely

3. Conservative Bias to Plant Operations

4. Effective Teamwork

5. Solid Understanding of Plant Design and Interrelationships SOER 10-2 1. Oversight ensures proper focus

2. Equipment restoration risk evaluation

3. Preparation for high risk evolution

4. Control Room resources adequate for EOP response

5. Sufficient engagement of other s in decision making

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 4 of 27 INITIAL SIMULATOR SETUP/REQUIRED DOCUM ENTATION 1. Reset to IC193, 100% power (NOTE: IC193 was saved from the 0 6/1 2/12 version of IC 81)

2. Place simulator in RUN.

3. Place A and B Recirc Flow controllers in MANUAL.

4. Verify 0VO03CB, 0B Off Gas Bldg. Exhaust Fan, in the STOP position. 5. Insert commands for this scenario. (Commands in CAEP File: NRC Scenario 11 3.cae) ir f iatsp 9 3 (Raises Suppression Pool Temperature to 93 F) irf iatlake 98.5 (Raises Lake Temperature to 98.5 F) imf mnb126 0.

0 5 (Fuel cladding failure at 0.05% severity) ior k3k02p1y false (RR Ganged Controller Raise PB false) ior k3k02p2y false (RR Ganged Controller Lower PB false) trg 1 "set vmsgv03r=1e6

" (On Manual Trigger 1, VG Discharge Damper Failed closed) ior p3e01a1d (3) 0 30 (On Manual Trigger 3, CRD Flow Cont fails dnscl on a 30 sec ramp

) imf mrc040 (4) 0 10 (On Manual Trigger 4, B FC V Fails Closed in 10 seconds

) ior q7d21mag (5) on (On Manual Trigger 5, A OG Bldg Exh Fan amber/auto trip light on

) ior q7d21rbg (5) off (On Manual Trigger 5, A OG Bldg Exhaust Fan red/on light off) imf r0414 (5) on (On Manual Trigger 5, A OG Bldg Exhaust Fan Trip annunciator on) ior k7d21jpg (5) stop (On Manual Trigger 5, A OG Bldg Exhaust Fan switch to stop

) imf mnb112 (Inboard MSIV D fails to close) imf mnb205 (6) 10 0 300 (On Manual Trigger 6, Steam line Break between D MSIVs at 100 lb/sec severity on a 5 min ramp

) ior gka02p21 (6 300) 230 300 (On Manual Trigger 6 with a 5 min delay, RWCU Demin Valve Room Ambient Temp Div 2 Override to 230

ºF on a 5 minute ramp) ior gma02p21 (6 300) 230 300 (On Manual Trigger 6 with a 5 min delay, RWCU Demin Valve Room Ambient Temp Div 1 Override to 230

ºF on a 5 minute ramp) trgset 30 "k1n15wbn" (When A RHR Pump switch is taken to START) imf mrh014 (30) 90 300 (On Trigger 30, RHR A Suction Strainer Plugged at 90% severity on a 5 min ramp) set vavr4yar=1e6 (RB Inlet Isol Damper 4A Stroke Time 1E6 seconds) set vavr4ybr=1e6 (RB Inlet Isol Damper 4B Stroke Time 1E6 seconds) set vavr5yar=

1e6 (RB Inlet Isol Damper 5AStroke Time 1E6 seconds) set vavr5ybr=

1e6 (RB Inlet Isol Damper 5A Stroke Time 1E6 seconds) trg 11 "set vavr4yar=5" (On Manual Trigger 11, RB Inlet Damper 4A Stroke Time 5 sec

) trg 12 "set vavr4ybr=5" (On Manual Trigger 12, RB Inlet Damper 4B Stroke Time 5 sec

) trg 13 "set vavr5yar=5" (On Manual Trigger 13, RB Inlet Damper 5A Stroke Time 5 sec

) trg 14 "set vavr5ybr=5" (On Manual Trigger 14, RB Inlet Damper 5B Stroke Time 5 sec

) (Continued)

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 5 of 27 6. Enter the VG discharge Damper and RB Isolation dampers on a Monitored Parameter list (Mon) and verify stroke times:

vmsgv03r=60 vavr4yar=1e6 vavr4yb r=1e6 vavr 5yar=1e6 vavr 5 y b r=1e6 7. Allow time for the plant to stabilize with higher Lake Temperatures

. 8. Ensure Gang button on RR FCV is tagged OOS and in turnover.

9. Provide the following procedures:

For LOS-VG-M1: o A Cover Sheet for LOS0VG

-M1 o A copy of LOS

-VG-M1 completed with Prerequisites, Precautions ,and Limitations signed off o IST data sheets o Stopwatch 10. Perform the pre

-scenario checklist.

11. Start Data Collection for Scenario Based Testing.

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 6 of 27 EVENT DESCRIPTION Facility: LaSalle Scenario No.: NRC 11-1-3 Op-Test No.:

2012301 Initial Conditions:

Unit 1 is operating at 100% power.

Suppression Pool Temperature is 93F. Recirc Ganged controller is Out

-O f-Service. Chemistry is monitoring a suspected fuel leak.

Turnover: Perform LOS

-VG-M1 on Unit 1 VG. Reduce power to 85% for Quarterly Surveillances.

Event No. Malf. No. Event Type*

Event Description

1. vmsgv03r (N) (T) BOP SRO Unit-1 VG failed surveillance. SRO makes Technical Specification determination 3.6.4.3. (TS)

2. N/A (R) ATC Reduce reactor power using RR

-FC Valves in manual control

. 3. p3e01a1d (I) ATC CRD Flow Controller setpoint fails low

. (ABN) 4. mrc0 40 (I) (T) ATC Inadvertent Runback of 1 B RR Flow Control Valve.

The SRO addresses Tech Spec for Recirc loop Flow mismatch. The ATC will insert CRAM rods to exit Region 1. (ABN) 5. k7d21jpg (C) BOP Offgas Building Exhaust Fan trip. The BOP swaps to the standby train.

(ABN) 6. mnb205 mnb112 vavr4/5ya/b (M) CREW MSL Leak in Steam Tunnel results in a Group 1. D Inbd MSIV fail s to isolate and the Reactor Building Ventilation fails to isolate. The crew performs actions of LGA 001, 002 and 003

. 7. gka02p21 gma02p21 (M) CREW When the leak spreads to the RWCU area and two areas are above Max Safe temperature the crew will perform a RPV Blowdown per LGA

-004 8. mrh014 (C) BOP 1A RHR suction strainer plugged. The BOP takes actions to mitigate and restore.

(ABN) * (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor (T)ech S pec ES-301-4 Quantitative attributes:

Total Malfunctions (5

-8): 7 Malfunction(s) after EOP (1

-2): 1 (E 8) Abnormal Events (2

-4): 4 (E3, 4, 5, &8) Major Transient(s) /E

-Plan entry (1

-2): 1 (E 6) EOPs (1-2): 3 (LGA-001, 003, & 002

) EOP Contingencies (0

-2): 1 (LGA-004) Critical Tasks (2

-3): 2 ES-301-5 Quantitative attribute s: BOP Normal:

E 1 ATC Reactivity (1 per set):

E2 BOP I/C (4 per set): E5&8 ATC I/C (4 per set): E3&4 SRO-I I/C (4 per set inc 2 as ATC): E3,4,5,& 8 SRO Tech Spec (2 per set):

E1&4 ALL Major Transients (2 per set)

E6 NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 7 of 27 GENERAL OBJECTIVE:

(USED THROUGHOUT THIS EXERCISE)

TASKS RO - ATC 30 3.0 2 0 Reduce power from 100% to 60 % power 23.003 Respond to a Reactor Recirc Flow Control System failure to minimum demand 25.048 Respond to a Control Rod Drive failures from the Main Control Room 304.010 Perform actions for a reactor scram 413.000 Evaluate plant conditions and control RPV water level +11 to +59.5 inches using preferred sources, IAW LGA

-001 612.030 Utilize and implement a ReMA RO - BOP/ASSIST 415.000 Evaluate plant conditions and control secondary containment by operation of the following ventilation systems: (a) VR (b) VG 426.000 Evaluate plant conditions and establish a monitored release path 427.000 Evaluate plant conditions and isolate all primary systems discharging outside primary and secondary containment not required for other LGA actions 428.000 Evaluate plant conditions and rapidly depressurize the RPV using SRVs via the ADS system 421.000 E valuate plant conditions and control and maintain suppression pool temperature less than HCTL 421.010 Cool the Suppression Pool 90.011 Respond to a Clogged Suppression Pool Suction Strainer

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 8 of 27 UNIT SUPERVISOR 303.020 Reduce power from 100% to 60 % power 612.030 Utilize and implement a ReMA 23.003 Respond to a Reactor Recirc Flow Control System failure to minimum demand 25.048 Respond to a Control Rod Drive failures from the Main Control Room 304.010 Perform actions for a reactor scram 413.000 Evaluate plant conditions and control RPV water level +11 to +59.5 inches using preferred sources, IAW LGA

-001 415.000 Evaluate plant conditions and control secondary containment by operation of the following ventilation systems: (a) VR (b) VG 426.000 Evaluate plant conditions and establish a monitored release path 427.000 Evaluate plant conditions and isolate all primary systems discharging outside primary and secondary containment not required for other LGA actions 428.000 Evaluate plant conditions and rapidly depressurize the RPV using SRVs via the ADS system 421.000 Evaluate plant conditions and control and maintain suppression pool temperature less than HCTL 90.011 Respond to a Clogged Suppression Pool Suction Strainer 615.001 Perform in plant actions to successfully operate the plant under normal, abnormal or emergency procedures

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 9 of 27 Event - 1 Description

Unit-1 VG failed surveillance Initiation:

Following turnover, perform LOS

-VG-M1 Obj. Position EXPECTED OPERATOR RESPONSE BOP Performs LOS

-VG-M1 Opens and times 1VG001, the U1 SBGT Inlet Isolation Valve Verifies Stroke Time within allowable limits Closes the Inlet Isolation Valve Opens and times 1VG003, the U1 SBGT Discharge Isolation Valve Verifies Stroke Time within allowable limits Verifies the U1 SBGT Discharge Isolation Valve auto closes Records elapsed run time for Unit 1 SBGT Primary Fan Opens 1VG001, the U1 SBGT Inlet Isolation Valve Starts the U1 SBGT Primary Exhaust fan Record start time and date Verify the following:

1VG003 opens Recognizes that 1VG003 has failed to open and notifies Unit Supervisor Suspends testing May secure the U1 SBGT Primary Exhaust Cooling Fan and close Inlet Isolation valve May attempt to open 1VG003 SRO Supervises LOS-VG-M1 Refers to Technical Specification LCO 3.6.4.3 Determines that with one SGT train inoperable, Required Action A.1, Restore SGT subsystem to OPERABLE status in the next 7 days is applicable.

Contacts Unit 2 for status of U

-2 VG Train Documents applicable Timeclocks ATC Monitors reactor to ensure operations remain within established bands Monitors control room panels and notifies the SRO of any unusual or unexpected conditions

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 10 of 27 Event - 1

Description:

Unit-1 VG failed surveillance Simulator Operator Actions Trigger 1 After the BOP has closed the discharge damper 1VG003 but before the Primary Fan is started activate Manual Trigger 1 and verify the (Monitored) stroke time for vmsgv03r change s to 1e6 Simulator Operator Role Play Role Play EO if dispatched to investigate 1VG003 failure: There is no apparent problem with 1VG003

. Role Play Unit 2 US/NSO if contacted for the status of U

-2 VG Train:

U-2 VG Train is operable.

Floor Instructor Notes/OPEX/TR's None NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 11 of 27 Event - 2

Description:

Reduce reactor power using RR

-FC Valves in manual control Initiation:

When directed by the Lead Examiner, contact the Unit Supervisor as the Shift Manager with the CUE to reduce reactor power.

Obj. Position EXPECTED OPERATOR RESPONSE ATC Per LGP-3-1 Step E.2 Lower reactor power per REMA Lower power in a deliberate, carefully controlled manner while constantly monitoring:

APRMs MWe Core Thermal Power Secondary indications Make Recirculation flow changes per LOP

-RR-07 Per LOP-RR-07, Step E.

1: Verify MANUAL light on recirculation loop flow controller M/A station A/B is ON. STATION a second licensed Operator at 1DS001, or PPC display, to monitor FCV Pos Demand signals to allow for immediate recognition and communication of an abnormal response PRESS the LOWER pushbutton s as necessary Observe flow indication to Flow Controller M/A Station(s)

Minimize the flow mismatch between Recirc loop SRO Directs actions above Enforces OPS expectations and standards Ensures RO monitors critical parameters carefully Stresses awareness of where operation is on the power to flow map BOP Monitor FCV Pos Demand signals at 1DS001 or PPC display Provides peer check of RR flow manipulations as required

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 12 of 27 Event - 2

Description:

Reduce reactor power using RR

-FC Valves in manual control Simulator Operator Actions None Simulator Operator Role Play Role Play As Shift Manager:

Direct the Unit supervisor to lower Reactor power by 200 MWe at 300 M We/hr. Floor Instructor Notes/OPEX/TR's None NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 13 of 27 Event - 3

Description:

CRD Flow Controller setpoint fails low Initiation:

At the direction of the L ead Examiner, activate Manual Trigger 3

. Key Parameter Response:

CRD Flow Controller Position Demand downscale; CRD System Flow, Cooling Water Pressure, and CRD Cooling Flow indications lowering Expected Annunciators:

1 H 13-P603-A403, CRD HYD TEMP HI Automatic Actions: None Obj. Position EXPECTED OPERATOR RESPONSE ATC Per LOR-1H13-P603-A403, CRD HYD TEMP HI:

Notifies the Unit Supervisor Verify CRD Cooling Water Flow is normal (no)

Recognizes downscale indications on CRD parameters with indications that the pump is still running Reports to the Unit Supervisor and enters LOA

-RD-101, CRD System Abnormal procedure Per LOA-RD-101, Step B.3 for CRD Flow Control Valve Failure:

Check no control rods drifting (yes)

Check CRD parameters normal (no)

Transfer s Flow Controller to Manual Adjust Flow Controller output to 63 gpm Check Flow Control Valve flow goes to 63 gpm (yes)

Verifies CRD parameters return to normal (yes)

SRO Directs actions above.

BOP At control room backpanel 1H22

-P007, CRD/Reactor Vessel Temperature Recorder, DETERMINES which of the CRDs are alarming.

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 14 of 27 Event - 3

Description:

CRD Flow Controller setpoint fails low Simulator Operator Actions Trigger 3 Verify the following command on Trigger 3:

ior p3e01a1d (3) 0 30 (CRD Flow Controller fails downscale on a 30 sec ramp) Simulator Operator Role Play None Floor Instructor Notes/OPEX/TR's None NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 15 of 27 Event - 4

Description:

Inadvertent Runback of 1 B RR Flow Control Valve Initiation:

At the direction of the L ead Examiner , activate Manual Trigger

4. Key Parameter Response:

Reactor power and MWE lower rapidly; the Power/Flow Map above 1H13

-P603 displays entry into Region 1 Expected Annunciators:

1H13-P602-B101, 1B RR FLOW CONTROL VLV TROUBLE Automatic Actions: None Obj. Position EXPECTED OPERATOR RESPONSE ATC Per LOP-RR-07 (during down

-power) If the FCV Pos Demand signal does not promptly stabilize at a new equilibrium following release of the FCV PB:

Recognizes 1 B FCV Position is NOT stable DEPRESS the opposite (Raise) FCV PB LOCK up the 1B FCV by DEPRESSING 1 B HPU Trip Pushbutton REVIEW LOA

-RR-101 and LOA

-PWR-101 promptly following an unexpected response of the RR Flow Control System Per LOA-RR-101 Section B.6 CHECK Jet Pump Flow Less than Technical Specification mismatch limit

- Within 10.85 Mlb/hr as read from 1B21

-R611A/B, if core flow is less than 75.95 Mlbm/hr GOTO step B.10 Within one hour either (discusses these options with Unit Supervisor):

o RESTORE flow mismatch within limits o REDUCE power rapidly per LGP 1 o TRIP the low

-flow RR pump SRO Directs entry into LOA

-RR-101 EVALUATE core performance (call QNE)

BOP Recognizes and reports unstable 1B FCV Demand signal When directed, at 1DS001, initiate TADS by DEPRESSING TDR icon Monitors balance of plant equipment

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 16 of 27 (Event 4 Continued)

ATC Identify operation in Region 1 Immediately exit Region 1 by inserting CRAM arrays SRO Initiate LOS

-RR-SR1 Supervises CRAM rod insertion START 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months time clock per Tech Spec 3.4.1 Required Action B.1.

Event - 4

Description:

Inadvertent Runback of 1 B RR Flow Control Valve Simulator Operator Actions Trigger 4 Verify the following command on Trigger 4:

imf mrc040 (4) 0 10 (B FCV Fails Closed in 10 seconds)

Simulator Operator Role Play Role Play as QNE:

when close to Region 1, contact the Unit Supervisor and recommend inserting at least 5 CRAM rods.

Floor Instructor Notes/OPEX/TR's None NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 17 of 27 Event - 5

Description:

Offgas Building Exhaust Fan Trip Initiation:

At the direction of the L ead Examiner , activate Manual Trigger

5. Key Parameter Response:

Offgas Building Exhaust Fan 0VO03CA indicating lights Expected Annunciators:

1PM06J-A106, OFFGAS BLDG 0A EXH FAN AUTO TRIP Automatic Action: Off Gas Building HVAC Exhaust Fan 0VO03CA trips Obj. Position EXPECTED OPERATOR RESPONSE BOP Responds to annunciator and informs Unit Supervisor Verify Off Gas Building HVAC Exhaust Fan 0A is tripped Start standby Off Gas Building HVAC Train per procedure LOP

-VO-01 SHUTDOWN the operating HVAC Train in accordance with LOP

-VO-02 Place the 0A Supply Fan in STOP Place the 0A Exhaust Fan in STOP Dispatch an EO to verify Train A supply and Exhaust dampers closed Direct the EO to deenergize the A Train heating units Direct the EO to open disconnects per step 3.1 Place the 0B Exhaust Fan in AUTO Place the 0B Supply Fan in START for 10 seconds and then release Verify the 0B Supply Fan starts Direct the EO in the Off Gas Building to:

Verify the Off Gas Bldg Supply Dampers open Verify all five LOW FLOW Alarms have cleared Verify the Off Gas Bldg Exhaust Dampers open Verify the 0B Off Gas Bldg Exhaust Fan starts Direct EO to check B Train differential pressures Direct EO to start the B Train heaters Dispatch operator to 480V MCC 134Y

-2 to investigate cause of alarm Inspect Off Gas Building HVAC Exhaust Fan for abnormalities Verify OGFB (Off Gas Filter Building) is at negative pressure SRO Supervises and verifies actions per the LOR and LOPs ATC Suspends Reactor downpower Monitors reactor to ensure operations remain within established bands

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 18 of 27 Event - 5

Description:

Offgas Building Exhaust Fan Trip Simulator Operator Actions Manual Trigger 5 Verify the following command s on Trigger 5: ior q7d21mag (5) on (On Manual Trigger 5, A OG Bldg Exh Fan amber/auto trip light on) ior q7d21rbg (5) off (On Manual Trigger 5, A OG Bldg Exhaust Fan red/on light off) imf r0414 (5) on (On Manual Trigger 5, A OG Bldg Exhaust Fan Trip annunciator on) ior k7d21jpg (5) stop (On Manual Trigger 5, A OG Bldg Exhaust Fan switch to stop)

Simulator Operator Role Play Role Play as EO dispatched to Off Gas Building:

When asked to investigate at 480V MCC 134Y-2: Wait 2 minutes, then report that the 0A Off Gas Exhaust Fan breaker is tripped

. During Shutdown of the A Train When asked, the A Train Supply and Exhaust dampers are closed.

When directed to deenergize A Train heaters, report them deenergized

. When directed to open disconnects

, report them open

. During startup of B Train When asked, the Off Gas Bldg Supply Dampers are open. When asked, all five LOW FLOW Alarms have cleared

. When asked, the Off Gas Bldg Exhaust Dampers are open. When asked, B Train differential pressures are normal

. When directed, report the B Train heaters have been started

. When asked, the Off Gas Filter Building is at a negative pressure

. Floor Instructor Notes/OPEX/TR's NONE NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 19 of 27 Event - 6

Description:

MSL leak in steam Tunnel; MSIV closure with D failing to isolate Initiation:

At the direction of the L ead Examiner , activate Manual Trigger

6. Key Parameter Response:

Steam Tunnel and RWCU Hx Area Temperatures; RB Isolation Dampers on 1PM06J continue to indicate Green/Ope n Expected Annunciators:

1N62P600-B401, RB VENT EXH RAD HI 1N62P600-B304, STA VENT STACK WIDE RANGE RAD HI 1H13P601-E (&F)204, DIV 2(&1) RB VENT RAD HI

-HI 1H13P601-F404, LD MSL PIPE TUNNEL AMB TEMP HI 1H13P601-F405, LD MSL PIPE TUNNEL DIFF TEMP HI Automatic Action s: Group 1 Isolation, Reactor Scram, (RB Vent Isol faulted)

Obj. Position EXPECTED OPERATOR RESPONSE BOP Responds to annunciators 1N62P600-B401, RB VENT EXH RAD HI and B304, STA VENT STACK WIDE RANGE RAD HI Determines alarms are valid Perform L OA-AR-101 Evacuate personnel from the Reactor Building Notify RP to survey and sample in the Reactor Building Attempt to determine the cause of the high rad condition

CT BOP Responds to Reactor Building Vent HI

-HI Rad annunciators 1H13P601-E&F204 At 1H13-P636, verifies Channels C & D have tripped Informs the Unit Supervisor of LGA

-002 entry conditions Verify automatic actions for trip of both channels Identify that the Reactor Building Ventilation Isolation Dampers , 1VR04YA & B, 1VR05YA & B, are NOT closed and informs the Unit supervisor Directs an EO to close the RB Isol Dampers locally using the local switches Verifies that the RB Isol Dampers get closed If directed, stops the Reactor Building Supply and Exhaust fans Contacts Unit 2 to verify: Unit 2 RB Vent Isol dampers have closed Unit 2 SBGT is running Unit 2 SBGT WRGM is in operation

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 20 of 27 (Event 6 Continued)

Obj. Position EXPECTED OPERATOR RESPONSE BOP Responds to Steam Tunnel high ambient and high differential temperature annunciators 1H13P601-F404 and 405 CHECK Main Steam Line Pipe Tunnel differential temperature is greater than or equal to alarm setpoint on Recorder 1E31

-R001A on panel 1H13

-P632. Reports Steam Tunnel temperatures throughout Monitors Reactor Building areas for rising Temperature and/or rad levels May place Turbine/Aux Bldg ARM toggle switch in BYPASS per LOR 1H13

-P601-B111 May place alarming Common Area ARM toggle switch(s) in ISOLATE per LOR 1H13-P601-B209 CT SRO Enters and directs LGA

-002 Verifies the RB Vent Isol Dampers get closed May direct tripping the Reactor Building Supply and Exhaust Fans Monitors release limits for potential entry into LGA

-009 Before Steam Tunnel reaches its Max Safe Temperature (212

º): Direct a manual reactor scram Enter and direct LGA-001 Attempt to isolate the primary system leak into the steam tunnel by directing operators to close the MSIVs Enters and directs actions of LGA

-001 LEVEL LEG Establishes a RPV water level band of

-30 to +55 inches ATC I f directed, manually scrams the reactor Responds to the reactor scram per LGP 2 Attachment E (hardcard):

ARM and DEPRESS Scram Pushbuttons PLACE Reactor Mode Switch in SHUTDOWN INSERT IRMs and SRMs CHECK Control Rods INSERTED and Power Decreasing INFORM Unit Supervisor Of Rod Status and Reactor Power REPORT to the Unit Supervisor the status of RPV Level and Pressure VERIFY Reactor Recirculation Pumps have downshifted VERIFY Main Turbine and Generator Trip STABILIZE Reactor Pressure <1020 psig BOP If directed, closes the MSIVs Verifies all MSIVs are closed and identifies that D Inbd MSIV remains open Stabilizes RPV pressure on SRVs as directed ATC Maintains RPV water Level as directed Stabilizes RPV pressure on SRVs as directed

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 21 of 27 Event - 6

Description:

MSL leak in steam Tunnel

MSIV closure with D failing to isolate fully Simulator Operator Actions Manual Trigger 6 Verify the following command on Trigger 6

imf mnb205 (6) 100 300 (Steam line Break between D MSIVs at 100 lb/sec severity on a 5 min ramp) ior gka02p21 (6 300) 230 300 (With a 5 min delay, RWCU Demin Valve Room Ambient Temp Div 2 Override to 230

ºF on a 5 minute ramp) ior gma02p21 (6 300) 230 300 (With a 5 min delay, RWCU Demin Valve Room Ambient Temp Div 1 Override to 230

ºF on a 5 minute ramp)

Manual Triggers 11, 12, 13,& 14 When dispatched to locally close the RB Isol Dampers:

Wait 6 minutes and then activate Manual Triggers 11, 12, 13, & 14

. Simulator Operator Role Play Role Play as Unit 2 ANSO when asked to verify the Reactor Building Vent Isolation:

RB Vent Isol dampers, 2VR04YA & B and 2VR05YA & B, are closed on Unit 2

. SBGT is running on Unit 2

. Role Play as an EO as necessary if sent to close the RB Isol Dampers

Use the Simulator Actions above to close the isolation dampers (6 minute wait). When the Manual Triggers have been activated, verify the Isolation Dampers have closed

. Then contact the control room to report completion of this task

. Floor Instructor Notes/OPEX/TR's None NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 22 of 27 Event - 7

Description:

Two areas are above Max Safe Key Parameter Response:

RWCU Hx Area Temperature Expected Annunciators:

1H13P601-C410, LD RWCU ROOMS AMB TEMP HI Automatic Action: RWCU isolation Obj. Position EXPECTED OPERATOR RESPONSE BOP Monitors Reactor Building areas for rising Temperature and/or rad levels Identifies Steam Tunnel temperatures exceed Max Safe Responds to LD RWCU ROOMS AMB TEMP HI annunciator Identifies RWCU Heat Exchanger Room temperatures exceed Max Safe Notifies Unit Supervisor of two area temperatures above Max Safe AT C Maintains RPV water Level as directed CT SRO When two area temperatures exceed Max Safe, enters and directs LGA

-004 Verifies Suppression Pool level greater than

-18 ft. Directs initiation of ADS CT BOP When directed, opens 7 ADS SRVs Event - 7

Description:

Two areas are above Max Safe Simulator Operator Actions At the direction of the Lead Examiner, place the Simulator in FREEZE

. Collect data for Scenario Based Testing

. Simulator Operator Role Play None Floor Instructor Notes/OPEX/TR's None NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 23 of 27 Event - 8

Description:

1A RHR suction strainer plugged Key Parameter Response:

Fluctuating flow and pressure on 1A RHR Pump Expected Annunciators:

None Automatic Actions: None Obj. Position EXPECTED OPERATOR RESPONSE 421.000 BOP Monitors containment parameters throughout Reports to the US when Suppression Pool temperature exceeds 105ºF, LGA-003 Entry Condition 421.000 SRO When Suppression Pool temperature exceeds 105ºF Enters and directs actions of LGA

-003 421.000 BOP When directed, starts all available Pool Cooling per LGA

-RH-103 Startup RHR Service Water as follows:

OPEN 1A/1B RHR Hx Service Water Outlet Valve:

1E12-F068A/B At approximately 9 to 10 seconds after taking the 1E12

-F068A/B switch to OPEN , START first RHR Service Water Pump:

1A or 1B/C or D When indicated flow reaches 3000 gpm, START second RHR Service Water Pump.

Startup RHR Start 1A/1B RHR Pump Establish RHR flow of 1500 to 7450 gpm:

Throttle 1E12

-F024A/B (Test Valve) OPEN.

Close 1E12

-F048A/B (HX Bypass)

Place A/B HTX Bypass Throttle/Seal in switch to THROTTLE and THROTTLE CLOSED 1E12

-F048A/B. or Place A/B HTX Bypass Throttle/Seal in switch to SEAL IN and CLOSE 1E12

-F048A/B ATC Maintains RPV water Level as directed Stabilizes RPV pressure on SRVs as directed BOP Recognizes fluctuating pressure and flow on 1A RHR Pump Refers to LOA

-PC-101 for plugged 1A RHR suction strainer Minimize 1A RHR Pump flow / attempt to stabilize 1A RHR Loop Shutdown 1A RHR Check other ECCS systems operating normally SRO Supervises actions of LO A-PC-101 NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 24 of 27 Event - 8

Description:

1A RHR suction strainer plugged Simulator Operator Actions Event Trigger 30 When A RHR Pump switch is taken to START, k1n15wbn, Verify the following malfunction becomes active:

imf mrh014 (30) 90 300 (On Trigger 30, RHR A Suction Strainer Plugged at 90% severity on a 5 min ramp)

Simulator Operator Role Play None Floor Instructor Notes/OPEX/TR's The scenario is complete when Blowdown has been performed and 1A RHR pump has been secured.

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 25 of 27 REFERENCES Procedure Titl e 1. LOS-VG-M1 SBGT System Operability and Inservice Test

2. LGP 3-1 Power Changes

3. LOP-RR-07 Operation of the Reactor Recirculation Flow Control System 4. LOR-1H13-P603-A403 CRD HYD TEMP HI

5. LOA-RD-101 Control Rod Drive Abnormal

6. LOR-1H13P602-B101 1B RR FLOW CONTROL VLV TROUBLE

7. LOA-RR-101 Reactor Recirculation System Abnormal

8. LOR-1PM06J-A106 OFFGAS BLDG 0A EXH FAN AUTO TRIP

9. LOP-VO-01 Startup and Operation of the Off Gas Building HVAC System 10. LOP-VO-02 Shutdown of an Off Gas Building HVAC Train

11. LOR-1N62P600-B 401 RB VENT EXH RAD HI

12. LOR-1H13P601-E(&F)204 DIV 2(&1) RB VENT RAD HI

-HI 13. LOR -H13P601-F404 LD MSL PIPE TUNNEL AMB TEMP HI

14. LGA-002 Secondary Containment Control

15. LGA-001 16. LOA-AR-101 17. LGP 3-2 18. LGA-003 19. LGA-RH-101 20. LOA-PC-101 21. LGA-004 RPV Control Area Radiation Monitoring System Abnormal Reactor Scram Primary Containment Control Unit 1 A & B RHR Operations in the LGAS and LSAMGs Primary Secondary Containment Trouble RPV Blowdown

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 26 of 27 ATTACHMENT 04 Scenario Validation Checklist Page 1 of 1 Initial 1 Verify with the Simulator Coordinator that the current training load is based on the current plant core.

2 The scenario performance objectives/tasks are listed in the scenario guide.

3 Simulator initial conditions are achievable.

4 The scenario guide clearly indicates the instructor station commands needed to achieve the performance objectives.

5 All malfunctions and other instructor station commands are entered in the sequence described in the scenario guide, and all items responded to support the performance objectives. 6 The simulator requires the operator to take the same action on the simulator as in the plant, using the reference plant operating procedures.

7 For annual exam scenarios, OBEs, and EP scenarios the scenario is validated in real time by an operating team consisting of SRO certified or licensed personnel using all referenced procedures and adhering to management expectations.

_____ 8 The responses of the simulator during the scenario were realistic, and observed changes correspond to expected plant response.

- Important / Critical Parameters (e.g., Flow, Power, Pressure, Radiation Level, Temperature, and Water Level)

- Annunciators

- System or component status indications 9 Tech Spec items / LCO declarations are correct. Appropriate documentation available.

10 Reportability requirements

/ Probabilistic Risk Assessments (if included) are correct. Appropriate documentation available.

Note: Wind speed and direction may be variable based on simulator modeling. ENSURE that these parameters are verified when validating the scenario.

11 Emergency Action Level classifications and PARs are identified, including whether or not there is a radiological release, the wind speed, and wind direction.

_____ 12 Critical tasks determined if applicable.

_____ 13 Shutdown scenarios include shutdown risk assessment, time to boil calculations and shutdown status board information.

14 Procedure steps that may be confusing or disagree with higher

-level procedures are discussed with operations management and expectations defined. Suggested enhancements are entered into the appropriate tracking system.

15 Management expectations are re

-enforced. 16 Scenario run time is in accordance with the stated quantitative attribute time.

17 Refer to EP

-AA-122-1001-F-07 for additional EP scenario validation criteria.

NRC 11-1-3 Revision 00 SRRS 3D.126/3D.111: Retain approved lessons for life of plant OR Life of Insurance Policy + 1 Yr for RP lesson plans. May be retained in department for two years, then forwarded to Records Management.

Page 27 of 27 U1 SUPERVISOR TURNOVER Unit 1 power level Unit 2 power level Unit 1 - 100% Power Unit 2 - 100% Power 11 3 8 MWe 1141 MWe 3 532 MWt 3 542 MWt 99.5 Mlbm/hr CORE FLOW 99.9 Mlbm/hr CORE FLOW Thermal Limit Problems/Power Evolutions When directed, drop 200 MWe at 300 MWe/hour None QNE will be monitoring the downpower from his remote monitor Existing LCOs, date of next surveillance Existing LCOs, date of next surveillance None None LOSs in progress or major maintenance LOSs in progress or major maintenance LOS-VG-M1 Prerequisite Steps complete N one Equipment removed from service or currently unavailable Gang button on RR Master FCV None Comments, evolutions, problems, etc.

Grid Status is Green Comments, evolutions, problems, etc.

Div 3 Workweek. OLR is Green Online Risk

- Green Grid Status

- Green Cycle Fundamentals

New Operators/Crew Integration Supervisory Oversight/Feedback Core Fundamental Execution:

Weekly Focus

Tool Safety Oncoming U1 CRS:

No change in Medical status IRs turned over/reviewed Shiftly & Turnover reviewed Walkdown completed

___________________________

/ Name Date Shift: Days Date: Today Online Risk

Green Div 3 Workweek Next T/C: None OP-AB-300-1003 Revision 8 Attachment 1 Reactivity Maneuver Approval Cover Page Station: LaSalle Unit 1 Valid Date(s):

Reactivity Maneuver Plan #: September 1 , 201 2 - December 9, 2012 Are Multiple Activations Allowed (If yes, US may make additional copies)

L 1 C1 5-0 3 Revision 1 Prepared by:

___Yes REACTOR ENGINEER__/__8/30/12____ Reviewed by: __

Qualified REACTOR ENGINEER /_8/30/12 Reactor Engineer / Date Qualified Nuclear Engineer / Date

_ Approved by:__

Rx. Enginneering Manager_/_8/30/12__ Authorized by:

__Senior Reactor Operator____/_8/31/12 RE Manager/ Date Senior Reactor Operator/ Date

__ NF Review Declined:

Y / N NF Review by: ____N/A____________/__N/A NF Reviewer

/ Date _ ReMA Activated:

______________/_______

ReMA Terminated:

______________/______

Unit Supervisor

/ Date Unit Supervisor

/ Date Title of Evolution: Power Reduction and Return to Full Power During L 1 C1 5 Purpose/Overview of Evolution: The purpose of this ReMA is to provide gui dance for a power reduction with core flow and/or control rods and the subsequent recovery to full power. The ReMA is applicable for both emergent and planned maneuvers.

Maneuver Steps:

1. Reduce power and maintain desired power level

. 2. Return to 100% RTP for load drops where the time from the initial drop is less than (or equal to) four (4) hours AND the load drop was ANDN/A step 3 if step 2 is completed the control rod pattern has not changed.

3. Return to 100% RTP for load drops where the time from the initial drop is greater than four (4) hours OR the load drop was >

ORN/A step 2 if step 3 is completed the control rod pattern has changed.

OP-AB-300-1003 Revision 8 General Issues:

This ReMA has been evaluated ONLY This ReMA has been prepared assuming a drop in core flow to 70 Mlb/hr. The initial conditions of Steps 2 and 3 may not bound all smaller load drops due to the reduction /MFLPD and MAPRAT.

with Thermal Limit Set 25 (Base Case, TSV/TCV in service, DLO, Option B , BOC to MOC). Check thThermal Limit Set being used. Alternatively, call QNE if another EOOS option is implemented to determine scope of EOOS impact and possible use of this ReMA with the OOS option implemented. The QNE will perform predictors for the EOOS option. If a change to TL set is required, enter step 1 of this ReMA prior to making change to TL set.

If the initial conditions are not met , NOTIFY FCL increases slightly as core flow decreases. During a fast flow reduction (300 hr) to 70 Mlb/hr, FCL may increase on average 2.5% to 3%.

a QNE to evaluate revising the initial conditions.

Per OP-AB-300-1003, Section 4.2.11, QNE presence in the main control room is required quired for emergency load drops, emergent drops to address plant equipment issues and load dispatch requests).

The QNE will revalidate this ReMA once a week using data from previous load drops to ensure the initial conditions and critical parameters are all still valid. The QNE will provide this validation as a signoff within Step 1 of the ReMA.

At some points in the cycle, return ramp to full power may not be fully achievable until Place "Reactivity Change In

-Progress" signs in their applicable plant locations as time allows. Revision Summary Rev. 0 - Initial version.

Rev. 1 - Updated for summer 2012 interval.

OP-AB-300-1003 Revision 8 Attachment 2 Reactivity Maneuver Guidance Sheet STEP 1 of 3 Reactivity Maneuver Plan # L1C1 5-0 3 Revision 1Description of Step: Reduce Power and maintain desired power level

. NOTE: This ReMA provides QNE approval of the load drop. LGP 1, Attachment B is not required. NOTE: If an LOA directed a load reduction, Step 1 will be entered as appropriate and the US will validate the parameters from the last case prior to the power reduction. This ensures that the initial parameters used in the Predictors to prepare this ReMA continue to be valid.

1. REDUCE 1 and LOP-RR-07 at with RR flow. ________ (initial when complete) o MAINTAIN reactor power level by adjusting core flow (if required)

. ________ (initial when complete)

2. PLACE "Reactivity Change In

-Progress" signs in their applicable plant locations at the earliest opportunity.

______ (init. when complete)

3. At least one (1) hour prior to the return to 100% RTP, NOTIFY QNE. The QNE will run predictors to ensure the ramp back is within the required critical parameters.______

(initial when complete)

QNE presence required in the Control Room? Yes __ No Onsite Only? Yes __ No -AB-300-1003, Section 4.2.11, for QNE presence requirements

) Initial Conditions (may be ranges) to be verified at the START of the Step Parameter Value or Range Init. Parameter Value or Range Init. FCL (%) MFLCPR 1 25 - see general notes and contact QNE )

TL set 25 MAPRAT 81 84 MFLPD 84 QNE's name, and date that the REMA was evaluated to be still valid:

Is QNE validation of REMA current, i.e., performed within the last 7 days?

Operator initial that initial condition is met: Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions (if needed)

High Low Core Flow (WT)

Monitoring Frequency:

Every (2) hours and after power changes e load , or PPC Heat Balance data.

Contingency Actions:N/A ADJUST RR flow. 6 5.0 Mlb/hr MFLCPR Monitoring Frequency

Every (2) hours and after power changes if MFLCPR > 0.900 via PO Contingency Actions:0.98 INSERT CRAM rods.

N/A FCL (%) Monitoring Frequency:

Every (2) hours and after power changes Contingency Actions:111.2% ADJUST RR flow or INSERT control rods per the sequence.

N/A ReMA Step Complete:

_________________/______

Verified by:

_______________/_______

Reactor Operator/Date Unit Supervisor/Date

Attachment 2 Reactivity Maneuver Guidance Sheet STEP 2 of 3 Reactivity Maneuver Plan # L1C15-03 Revision 1Description of Step:

Return to 100% RTP for load drops where the time from the initial drop is less than (or equal to) four (4) hours AND the load drop was AND 1. RETURN 1 and LOP-RR-07 using RR Flow. ______ (initial when complete) the control rod pattern has not changed.

2. MAINTAIN 100% RTP using RR Flow

. 3. REMOVE "Reactivity Change In

-Progress" signs. ______ (initial when complete)

4. When the core is near equilibrium conditions, CLOSE this ReMA Step with concurrence of the QNE.

5. N/A step 3 if step 2 is completed

______ (initial when complete)

QNE presence required in the Control Room? Yes __ No Onsite Only? Yes __ No -AB-300-1003, Section 4.2.11, for QNE presence requirements Initial Conditions (may be ranges) to be verified at the START of the Step Parameter Value or Range Init. Parameter Value or Range Init. Core Thermal Power MFLCPR Core Flow (Mlb/hr)

MAPRAT 0 FCL (%) % 77 Time Since Load Drop Initiated MFLPD 78 Control Rod pattern Same as Initial Pattern Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions (if needed)

High Low MFLCPR Monitoring Frequency

Every (2) hours and after power changes if MFLCPR > 0.900 via Contingency Actions:0.98 INSERT CRAM rods.

N/A FCL (%) Monitoring Frequency:

Every (2) hours and after power changes Contingency Actions:111.2% ADJUST RR flow or INSERT control rods per the sequence.

N/A ReMA Step Complete:

_________________/______

Verified by:

_______________/_______

Reactor Operator/Date Unit Supervisor/Date

Attachment 2 Reactivity Maneuver Guidance Sheet STEP 3 of 3 Reactivity Maneuver Plan # L1C1 5-0 3 Revision 1Description of Step: Return to 100% RTP for load drops where the time from the initial drop is greater than four (4) hours OR OR 1. RETURN 1 and LOP-RR-07 and QNE recommendations using RR flow and/or control rods. ______ (initial when complete) the control rod pattern has changed.

2. MAINTAIN 100% RTP using RR Flow

. 3. REMOVE "Reactivity Change In

-Progress" signs. ______ (initial when complete)

4. When the core is near equilibrium conditions, CLOSE this ReMA Step with concurrence of the QNE

. 5. N/A step 2 if step 3 is completed. ______ (initial when complete)

QNE presence required in the Control Room? Yes No _ Onsite Only? Yes __ No QNE presence in the Control Room is required when margin tlowering OR the load drop was > 20% RTP OR the control rod pattern has changed ORInitial Conditions (may be ranges) to be verified at the START of the Step FCL rods are planned to be moved.

Parameter Value or Range Init. Parameter Value or Range Init. Core Flow (Mlb/hr)

MFLCPR FCL (%) MAPRAT 0 ReMA Step 2 Not Completed 77 QNE Peer Check Yes MFLPD 78 Critical Parameters to be Verified During the Step Description including frequency, method of monitoring, and contingency actions (if needed)

High Low MFLCPR Monitoring Frequency

Every (2) hours and after power changes Contingency Actions:0.98 INSERT CRAM rods.

N/A FCL (%) Monitoring Frequency:

Every (2) hours and after power changes Contingency Actions:111.2% ADJUST RR flow or INSERT control rods per the sequence.

N/A Fuel Conditioning, flow ramp Monitoring Frequency

After a cumulative power increase of via Contingency ActionsFor nodes where P-PCS > 0.00 : SLOW the flow ramp (i.e. rod insertions may need to be spread out over several hours) or REDUCE core flow per the guidance in NF

-AB-440-1002. AREVA hour average) overshoot)

GNF: 0.3 hour3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months average) 0.45 10 overshoot)

N/A Fuel Conditioning, rod moves Monitoring Frequency:

If predictors show less than 0.5 kw/ft margin to limit, then MONITOR after each peripheral rod insertion or withdrawal, interior rod insertion, or for FCL movement after each sequence step, by evaluating a case. Contingency ActionsFor nodes uncovered by control rod: : RETURN rods to their initial positions or REDUCE core flow.

For nodes uncovered by control rods:

AREVA GNF: 0.3 N/A ReMA Step Complete:

_________________/______

Verified by:

_______________/_______

Reactor Operator/Date Unit Supervisor/Date

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