ML070990501

Final- Section C Operating Exam (Folder 3)

ML070990501
Person / Time
Site:	Millstone
Issue date:	01/24/2007
From:	Dominion Nuclear Connecticut
To:	David Silk Operations Branch I
Sykes, Marvin D.
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ML060800095	List: ML070600098 ML070810566 ML070810590 ML070810626 ML070810656 ML070810668 ML070810696 ML070950207 ML070990446 ML070990457 ML070990466 ML070990481 ML070990501 ML071220278 ML071350104 ML071350613
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Download: ML070990501 (206)

Text

MILLSTONE POWER STATION SIMULATOR EXAM GUIDE APPROVAL SHEET Exam

Title:

Large Break LOCA Revision: 0 chg 1 ID Number: 2K7 NRC-01 II 11 This document is the property of the Millstone Power Station which controls its distribution. Further transfer, copying, or modification of this document is strictly prohibited without the written consent of the Millstone Power Station.

Submitted by: D. Minnich 1/11/07 Developer Date Validated by: Ray Martin 1/24/07 Technical Reviewer Date Approved by: Tim Kulterman 1/24/07 Training Supervisor Date STOP THINK ACT REVIEW

MILLSTONE POWER STATION SIMULATOR EXAM GUIDE APPROVAL SHEET Exam

Title:

Large Break LOCA Revision: 0 ID Number: 2K7 NRC-01 I This document is the property of the Millstone Power Station which controls its distribution. Further transfer: copying, or modification of this document is strictly prohibited without the written consent of the Millstone Power Station. I Submitted by: D. Minnich 1/I1/07 Developer Date Validated by: -

Technical Reviewer Date Approved by:

Training Supervisor Date STOP THINK ACT REVlW

SUMMARY

OF CHANGES Change Description Date of Change Deleted the DRPl Malfunction event (event 4) from the scenario. Rev 0, chg 1 Renumbered subsequent events. Added a cue to allow the crew to initially choose the downpower rate. Added a report from the 2116/07 field with respect to noises coming from the B MSR. Subsequent to the downpower, added a report from the OMOC to temporarily keep the reheaters in service for evaluation. For the SG steam flow failure, added instruction for the booth operator to bypass Event 5 and go to the small break LOCA event, if the BOP loses control of feed and trips the plant. Added step 22 of AOP 3575 and the steps for GA-9, Aligning For RCS Makeup. In the interest of time, increased the severity of the small break LOCA. Moved up the large break LOCA to step 10 of E - I . SIH (safety Injection) pumps fail to auto-start were added as malfunctions.

STOP THINK ACT REVIEW

SECTION 2 SIMULATOR EXAM GUIDE TABLE OF CONTENTS SECTIONS LISTED IN ORDER

1. Cover Page

2. Table of Contents

3. Exercise/Exam Overview

4. Exam Guide Attachments:

- Shift Turnover Report

- Validation Checklist

- Scenario Outline (ES-D-1)

- Attributes Checklist

- Summary of Changes Page 3 of 76

SECTION 3 EXAM OVERVIEW

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0

1. The Session will begin with the plant at 100% power and at end of life. The A EDG is out of service for planned maintenance. The C TPCCW pump is out of service for an oil replacement. After taking the shift, a tube leak will occur in the B MSR. The crew will use OP 3317, Reheat and Moisture Separator, to identify the MSR leakage and determine required actions, which include a power reduction of 10% followed by taking the MSRs out of service.

Plant Management will direct the crew to lower power using AOP 3575, Rapid Downpower, @

1/2% per minute. During the downpower, controlling PZR Level transmitter, 3RCS-L459, will fail as is. The crew should respond by entering AOP 3571, Response to an lnstrument failure, to address the problem.

Once Tech Specs have been addressed, and bistables tripped, the SG steam flow channel, 3MSS*FT542, will fail low. Again, the crew should enter AOP 3571 Instrument Failure Response to address the failure.

When AOP 3571 actions are complete, the crew will experience a Loss of 125 Volt DC Bus 4 and will respond using AOP 3563, Loss of DC Bus Power. There are no Main Board actions other than verifying system response. The US should evaluate and enter the appropriate Tech Spec. If attempted, power cannot be restored to the Battery Bus.

Once Tech Specs have been addressed, a leak (tube failure) of Reactor Plant Component Cooling Water (CCP) into the Upper Oil Reservoir of the C RCP will occur. CCP Surge Tank level, though slight, will discernibly decrease and, after a few minutes of leakage, an Oil Reservoir high level alarm will sound. The crew should take action per the ARP and AOP 3554, RCP Trip or Stopping a RCP at Power to attempt to reduce reactor power and take the affected RCP out of service. The crew will not have the time to downpower prior to exceeding RCP motor bearing temperature limits and should elect to trip the plant and the affected RCP. If the crew takes no action the affected RCP will seize and the reactor will trip.

At the time of the reactor trip a small break LOCA on loop 3 occurs (simulating a break in the area of the affected RCP). The crew will carry out the immediate actions of E-0, Reactor Trip and Safety Injection, determine that automatic safety injection (SI) actuation has failed, and manually initiate SI [Critical Task]. The A and B SI pumps will fail to auto-start and will have to be manually started. While in E-0, the crew should recognize that the AFW pumps did not start and take action to start the pumps [Critical Task].

The crew should then transition to E-I Loss of Reactor or Secondary Coolant, and stop the RHR pumps when procedurally directed. After the crew trips the RHR pumps, the LOCA will rapidly increase in severity forcing the restart of the RHR pumps. As the break size increases an Orange Path will be generated based on CTMT pressure. The crew should respond by transitioning to FR-Z.l, Response to high CTMT Pressure. CDA Train A & B will fail to automatically or manually actuate. This will require the crew to manually manipulate individual components [Critical Task]. If the operator uses the pushbuttons to manually actuate CDA, the RHR pumps will not automatically start. The RHR pumps will need to be started using the hand Page 4 of 76

switches on MB2. The RHR pumps will start and provide flow. Once FR-Z.l is complete, the crew transitions back to E-I, the session can be terminated.

2. The US should classify the event as an ALERT - Charlie One based on failure of the RCS barrier.

3. Duration of Exam: 75 minutes Page 5 of 76

SECTION 4 EXAM GUIDE

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 All Control Room Conduct, Operations and Communications shall be in accordance with Master Manual 14 and applicable DNAP/DNOS standards.

Page 6 of 76

SECTION 4 EXAM GUIDE

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 SIMULATOR PROBLEMS DURING EXAMS It is the responsibility of the Instructors in the simulator to insure that training interruptions have a minimum negative impact on the Crew and the training we provide. Use your judgment on whether to stop the training and how the training should be commenced after the problem is corrected.

Be aware that at all times the Operators should treat the simulator as if it were the plant and you too should treat it as much like the plant as possible when they are in the simulator.

As soon as the Instructors are aware of a simulator problem that will adversely affect the training in progress (computer fault, etc.) the Instructor should:

1. Place the simulator in FREEZE if possible.

2. Announce to the Crew that there is a simulator problem.

3. Request that the Crew either standby (for minor trouble that can be handled quickly) or leave the simulator control room. (The Crew should leave the simulator for problems which involve major switch alignments).

4. Deal with the problem (reboot, close tripped breaker, call STSB, etc.)

5. After the Instructors believe the simulator is restored to service, the Crew should be told how training will continue. If it is possible and felt to be acceptable to the Instructors, training can begin where it left off with an update on plant parameters and each Crew member is prepared to restart. If training will not begin where it left off, the crew should be told how and where training will begin again.

6. Once the Crew has been told how and where training will begin, have the crew conduct a brief so that the Instructor can insure that the crew has all the necessary information to continue with the scenario.

7. Once all Crew members and Instructors are satisfied that they have the necessary information to continue the scenario, place the simulator in RUN and announce to the Crew that you have continued the training session.

Page 7 of 76

SEL I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: Q INITIAL SETUP INSTRUCTIONS

1. START the Sun Workstation.

a. IF the Sun Workstation is running THEN go to SIM ACTIVE.

2. PLACE Recorder Power to ON.

3. VERIFY that the current approved training load is loaded.

4. REMOVE the step counter OVERRIDE and allow the counters to step out during the IC reset.

5. RESET to IC 89 (Based on IC 21)

6. ADJUST the various pot settings to the valued specified by the chart in the simulator booth or Notepad for the selected IC. Pay particular attention to the Pzr spray valves and their setpoints.

7. PLACE Simulator to RUN.

8. If Necessary, RESET the Plant Calorimetric at the Instructor Station PPC by Pressing SHIFT LEFT and F6 simultaneously.

9. ENSURE Simulator fidelity items cleared.

a. CHECK the STEP COUNTERS at correct position for plant conditions.

b. PLACE tiles under the DEMINS IN SERVICE lamacord label on MB6.

c. PLACE the Main Turbine on the LOAD LIMITER and ENSURE Standby Load Set MATCHED if conditions require.

d. PLACE the Westronic (5) and Gammametrics (2) recorders in activehun by depressing up or down arrow for each.

e. For the RIL recorder: select printer to ON when command? appears select Autojog.

f. CLEAR DCS alarms on MB7 and BOP console.

g. VERIFY annunciator, COMPUTER FAILURE (MB4C, 1-1 I ) , is NOT LIT.

10. As needed, RESET Computer Terminals to At Power displays if 100% power IC.

11. RESET Rad Monitor Screen to Status Grid Page 8 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: Q INITIAL SETUP INSTRUCTIONS

12. IF placing equipment OOS, THEN perform the necessary switch manipulations and hang appropriate tags, as required, listed under I Equipme nt 00s.

13. Ensure that the protected train and environmental placards are appropriately hung.

Equipment 00s: A EDG (Yellow Tag on Start Switch, Output Breaker and Prelube pump)

C TPCCW pump (Yellow Tag on control switch)

Insert applicable Crew Training Tape/CD into the DVDNCR.

Verify the MONITOR Time Display the same as the digital time display on MB4. If not pagekall the Unit Tech.

Initial Malfunctions/lOs/lDAs:

PLACE GREEN PLACARDS FOR ALL INTAKE PARAMETERS ON MB6 PLACE THE B TRAIN PROTECTED PLACARD ON MB4 Go to Manual Bypass on the Bypass Status Panel for the A EDG.

Page 9 of 76

SEC; I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 INITIAL SETUP INSTRUCTIONS TYPE I Name Sev. I Ramp RSCU Boul 1 Description MALF FW20A A MDAFW pump fails to auto-start MALF FW2OB B MDAFW pump fails to auto-start MALF I FWZOC I I I I 1 TD AFW pump fails to auto-start ~

MALF RPO6A Failure o f CDA (train A) to auto actuate MALF RPO6B Failure of CDA (train B) to auto actuate MALF RP07A A Train Safety Injection fails to auto-actuate.

MALF 1 RP07B I I I I 1 BTrain Safety Injection fails t o auto-actuate.

MALF I EGO7A I I I I I EDG A Trip MALF I TPO2C I

t-t- -C TPCCW Pump fails t o auto-stas 1

~ _ _ _

MALF 1 S107A I A SIPump fails to auto-start.

MALF 1 SI076 I I I I 1 BSI Pump fails to auto-start.

MALF MS05B 80% 240 1 Tube Leak B MSR MALF R X I OA 61.2% 2 3RCS*L459 fails as is MALF RX14G 0Yo 3 D SG steam flow fails low (3MSS-FT542)

MALF 1 EDO9D I I I 5 1 1 Loss of Battery Bus 4 MALF RC14C 100% 6 RPCCW leak into upper oil reservoir o f C RCP MALF RC02C 0.20 60 BTI Small break LOCA in CTMT (Loop 3 Hot Leg)

Y T i E z E K m L

~~~

I/O (EG) 1A-3ENSACB-A GREEN OFF - -

1 / 0 (EG) lA3ENSACB-A-RED OFF - - - D/GABKRCNTL I/O (EG) 1A-3ENSACB-A-AMBER OFF - - - D/G A BKR CNTL UO (EG) 1-3EGO-PIA RED OFF D/G A Prelube Pump Page 10 of 76

SEL I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 INITIAL SETUP INSTRUCTIONS I/O (EG) 1-3EGO-P1A GREEN OFF D/G A Prelube Pump I/O(RP) 3ADS-CDA PB1 OFF - - - CDA PBs fail to actuate CDA I/O(RP) 3ADS-CDA PB2 OFF - - -

I/O (RP) 3ADS-CDA PB3 OFF UO (RP) 3ADS-CDA PB4 OFF Ann O/R MBSA 2-11 ON 34C Loss of Control Power Page 11 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 INITIAL SETUP INSTRUCTIONS Lead Examiner: Refer to the "Briefing Script for the Operational Exam" and brief the crew. Go over the Plantlsimulator differences, which follow.

Booth Instructor: Commence recording Simulator session Booth Instructor: Perform the crew turnover (Initial Conditions page at end of LP) with the SM . Have the SM brief his crew on plant conditions and any major equipment 00s.

PLANTlSlMULATOR DIFFERENCES:

Rad Monitor Historical Data--Simulator Rad Monitor historical data not valid prior to the beginning of this exercise.

If not using the speed dial option on the phone system, the operator must dial either #3333 or #3334 to reach the person/department they desire.

The following PPC programs do not function on the simulator 0 Samarium Follow 0 Xenon Follow 0 Sequence of Events 0 Flow indications 3SIH-F1917 (charging ECCS flow), 3SIH-F1918 (A SI pump flow) and 3SIH-F1922 (B SI pump flow) will show flow at low flow rates.

Page 12 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard EVENT 1: Tube leak in B MSR.

T = 1 minute RSCU 1 (MSOSB @ 80%)

after turnover The first indication will be a slow reduction in unit output of about 7 MWe and an increase in power from 341 1 to 3428 MWth. A computer point alarm on high reheat steam flow for B MSR will come in. 3MSS-F38B will show significantly higher flow to the B Reheater and 3MSS-P57B will show lower pressure (from 943 to 906 psig.)

Hot reheat steam temperature will go down slightly (less superheat) and a Delta T will develop between the hot reheat steam leaving the two MSRs of around 5 degrees.

The crew should take immediate actions to lower turbine load to lower thermal power to < 341 1 MWth IAW OP 3204, At Power Operation..

Based on the computer point alarm on high reheat steam flow for B MSR, the crew should verify symmetric operation of the MSRs, and check the MSR tube leakage displays on DCS. The tube leak display for B MSR will show Page 13 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDAlMalf Ins.;uctor InformationlActivity Assign ExpecteG -:tion Standarb steam flow verses cross-around pressure greater than 5% above the baseline curve. OP 3317, Reheat and Moisture Separator, will direct a power reduction and taking the MSRs out of service.

OP 3317 Reheater and Moisture Separator, Section 4.14. (rev 014-06)

Identify MSR Tube Leaks Section 4.14 Reheat steam flow during start of the T=4 BOOTH Report as PEO that loud banging reheaters is a function of many factors other 4.14.1 min Utes noises are coming form the B than tube leaks. Reheat steam control valve NOTE from being MSR. position, reheat drain flow to the main dispatched condenser and the transitory nature at a start should be analyzed before a tube leak is conclusively identified.

The steam flow verses cross-around pressure plot being greater 4.14.1 than 2.5% above the baseline curve on NOTE Attachments 3 through 8 is an indication of a tube leak.

Attachment 3 through 8 are for use during steady state operation. 4.14.1 Limits on the graphs are expected to be NOTE exceeded during transients.

PERFORM one of the following, as The BOP will be expected to call up the BOP applicable: 4.14.1 tube leak display on DCS for the B Page 14 of 76

SEC IION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Ins.. uctor InformationlActivity Assign Expec.dd Action Standard MSR Refer To MSR Leak Detection displays on the Foxboro Digital Control System and IDENTIFY MSR tube leaks.

PERFORM the following (computer):

o Refer To Attachments 3 through 5 and COMPARE MSS-F38A steam flow with CRS-P24A cross-around pressure.

0 Refer To Attachments 6 through 8 and COMPARE MSS-F38B steam flow with CRS-P24B cross-around pressure.

MONITOR associated MSR drain tank level to The B MSR drain tank level will be BOP ensure the Level 4.14.2 normal. Control System has not failed causing excessive steam flow through the high level dump to the condenser.

IF the steam flow verses cross-around The US should inform RE that steam pressure plot is greater than 2.5% above the 4.14.3 flow verses cross-around pressure is baseline curve on Attachments. 3 through 8, greater than 5% above the baseline For NOTIFY the Reactor Engineering B MS R . Department.

IF the steam flow verses cross-around All turbine CIV valves are open. pressure plot is greater than 5% above the 4.14.4 US should go to Section 4.11 to remove baseline curve on Attachments 3 through 8 MSR reheaters from service. AND all of the turbine CIV valves are open, Page 15 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Refer To Section 4.1 1 and REMOVE MSR reheaters from service.

INITIATE a CR.

4.14.5 OP 3317 Reheater and Moisture Separator, Section 4.14. (rev 014-06)

Remove MSR Reheaters From Service At Turbine Load Greater Than 30% (360 Step 4.1 1 MWe)

If manual control of reheater steam supply Step valves is taken at a location other than the 4.1 1.I Foxboro Digital Control System operator NOTE station, constant communications with the Control Room must be established.

Turbine load is limited to approximately 90% Step (1080 MWe) without MSR reheaters in service 4.1 1.I due to Condensate System flowrate increase. NOTE With Reheat Steam isolated to the MSRs, Step Pimp is not an accurate reflection of Reactor 4.1 1.I Thermal Power. As a result, Tref is not NOTE accurate.

US should recognize that a downpower IF at turbine load of 100% (1200 MWe), Step is required to establish the plant REDUCE turbine load by approximately 10% 4.1 1.I conditions necessary to remove the (120 MWe).

reheaters from service. It is expected that the US inform the OMOC (OPS Manager on call) that a downpower is Page 16 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard required and that there is a significant tube leak in the B MSR.

T = When crew BOOTH Call as OMOC and direct the US discusses a conduct a rapid downpower i n order down power to remove the Reheaters from plan service. Reduce power to 85%.

Engineering reports that it is not desirable to attempt to achieve symmetrical operation of the MSRs during the downpower, given the tube leak.

If the US chooses a downpower rate other than l%lmin, Call as OMOC and direct the US to use l%lminute.

The US will enter AOP 3575, Rapid Downpower T = When RSCU 2 This will fail 3RCS-L459 as is during the downpower 3575 entered (RXI OA)

Evaluator Sometime during the down power, NOTE: the crew should notice a failed PZR level transmitter staying at the 100%

program value. Page forward in the exam guide to AOP 3571 Actions when the crew responds to the failed transmitter AOP 3575 Actions (Rev 01 3-00)

Page 17 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instr ucto r I nfo rmat ion/Activity Assign Expected Action Standard A CONVEX requested emergency AOP 3575 generation reduction as directed by C OP Step 1 200.8, Response to I S 0 New England / NOTE Convex Emergencies and Alerts, Should be completed within 15 minutes of notification.

If a unit shutdown is required, the target power level should be between 20% and 25% reactor power.

If at any time ROD CONTROL BANKS LIMIT LO - LO (MB4C 4 - 9 ) annunciator is received, DO NOT go to AOP 3566, Immediate Boration. Immediately perform step 11.

CREW Determine Power Reduction Rate (%/min). AOP 3575 Step 1 us Check desired power reduction rate - EQUAL AOP 3575 TO OR LESS THAN 5%/min. Step 1.a us Check power reduction - CONVEX AOP 3575 REQUESTED Step 1.b us Proceed to Step 1.d. AOP 3575 Step 1.b RNO CREW Determine power reduction rate using Table. AOP 3575 Step 1.d Evaluator NOTE: The crew has already been directed to use a power reduction Page 18 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time I D N Ma If Instructor Information/Activity Assign Expected Action Standard rate of 1O h per minute us Check Rod Control In AUTO. AOP 3575 Step 2 CREW Align EHC Panel AOP 3575 Step 3 us Check turbine OPERATING MODE - AOP 3575 MANUAL Step 3.a us Check LOAD LIMIT LIMITING light - LIT AOP 3575 Step 3.b BOP Intermittently Press DECREASE LOAD AOP 3575 pushbutton until LOAD LIMIT LIMITING light - Step 3.c NOT LIT BOP Rotate LOAD LIMIT SET adjust knob at least AOP 3575 one full turn in raise direction Step 3.d Select DECREASE LOADING RATE to ON AOP 3575 Step 3.e The US should direct the BOP to select BOP Select LOAD RATE LIMIT % MIN to required AOP 3575 1% per minute. power reduction rate (Oh min) determined in Step 3.f step 1.

If at any time the power reduction rate or final AOP 3575 desired power level must be changed, Return Step 4 to step 1. NOTE US/RO Verify Power Reduction Rate AOP 3575 Step 4 Page 19 of 76

SEC CION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 cha 1 Task Time IDNMalf Inst ructor InformationlActivity Assign Expected Action Standard RO Check power reduction rate 5% MIN AOP 3575 Step 4.a Perform the applicable action: AOP 3575 Step 4.a RNO 0 IF power reduction rate is 3% min, THEN Proceed to step 5.

The US will proceed to step 6 IF power

- reduction rate is LESS THAN 3%

min, THEN Proceed to NOTE prior step 6.

us Align RCS Makeup System For Boration AOP 3575 Step 6 Check Rod Control -AVAILABLE FOR ROD AOP 3575 INSERTlON Step 6.a US / RO should determine a boric acid US/RO Determine required boric acid addition by AOP 3575 addition of 15% x 24(gal/%) = =gal. multiplying total power change (A%) by Step 6.b 24(gal/%) = gal.

RO Set the boric acid batch counter to the AOP 3575 required gallons of boric acid determined in Step 6.c step 6.b.

us Check power reduction rate- O.5%/min. AOP 3575 Page 20 of 76

SEC; I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDAlMalf Instructor Information/Activity Assign Expected Action Standard Step 6.d RO Adjust boric acid blend flow controller pot AOP 3575 setting to the appropriate setpoint and Step 6.d Proceed to step 6.f.: RNO The RO should set the boric acid blend 0 rods available - 7.5 (30 gpm) flow controller pot to 7.5.

no rods available - 10.0 (40 gpm)

RO Select BORATE on the reactor coolant AOP 3575 makeup select switch. Step 6.f RO Select START on the reactor coolant makeup AOP 3575 start switch. Step 6.g RO Verify boric acid flow - INDICATED AOP 3575 Step 6.h RO Energize all PZR heaters. AOP 3575 Step 6.i Adjust Pzr Spray Valves to 50% setpoint AOP 3575 Step 6.j RCS-PK455B RCS-PK455C Adjust boric acid flow rate and total volume as AOP 3575 necessary to maintain: Step 6.k Rods above the Rod Insertion Limit Tavg within +5OF of Tref 0 AFD within COLR limits Page 21 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RO If a unit shutdown is being performed, the AOP 3575 final MWe load should be approximately 230 Step 7 MWe. NOTE US/BOP Initiate Load Reduction AOP 3575 Step 7 BOP Check turbine OPERATING MODE - AOP 3575 MANUAL Step 7.a BOP Check either of the following: AOP 3575 Step 7.b 0 Rapid or gravity boration - IN PROGRESS OR Turbine load reduction - REQUIRED TO STABILIZE PLANT WHEN The US should direct the RO to inform BOP AOP 3575 him when either Tavg, power or rod Any of the following change due to boration: Step 7.b position changes as a result of the RNO boration. Tavg Reactor power Control Rod position THEN Proceed to step 7.d The US should direct the BOP to adjust BOP Utilizing DECREASE LOAD pushbutton, AOP 3575 LOAD SET to 1020 Mwe (about 85% Adjust LOAD SET to desired final MWe Step 7.d power).

Page 22 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time I DAlMalf Instructor Information/Activity Assign Expected Action Standard BOP Check power reduction - CONVEX AOP 3575 REQUESTED. Step 7.e us Inform CONVEX of load reduction rate AOP 3575 (MWe/min) and final MWe level. Step 7.e RNO BOP Maintain initial MVAR loading during power AOP 3575 reduction, unless directed otherwise. Step 7.f US/RO Check boration - IN PROGRESS AOP 3575 Step 7.g Verify Final Desired Turbine Load (MWe) - AOP 3575 LESS THAN 75% Step 8 Proceed to Step 10 AOP 3575 Step 8 RNO BOP The following step places one TD FW pump AOP 3575 in manual while allowing the other TD FW Step 10 pump to automatically unload during the NOTE downpower.

US/BOP Align One Feedwater Pump For Automatic AOP 3575 Unloading Step 10 The US should recognize that 85% BOP Verify removing a feedwater pump from AOP 3575 power, two feedwater pumps will be service during the downpower - DESIRED Step 10.a required.

Proceed to step 11 AOP 3575 Step 10.a RNO Page 23 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard US/RO Verify Rod Position AOP 3575 Step 11 RO Check ROD CONTROL BANKS LIMIT LO - AOP 3575 LO (MB4C 4 - 9) annunciator - LIT. Step 1 l . a US/RO Proceed to step l l . e and, E at any time, the AOP 3575 annunciator is received, THEN Step 11.a RNO Perform steps 11.b, 11.c and 11.d.

RO Check ROD CONTROL BANKS LIMIT LO AOP 3575 (MB4C 3 - 9) annunciator - LIT Step 11.e us Proceed to NOTE prior to step 12 and, AOP 3575 Step 11.e IF the annunciator is received, THEN RNO Perform step 11.f and 11.g.

us Restore From Rapid Boration. AOP 3575 Step 12 RO Check rapid gravity boration - IN AOP 3575 PROGRESS. Step 12.a us Proceed to Step 13. AOP 3575 Step 12.a RNO us Reduce Steam Supply To The MSRs. AOP 3575 Step 13 BOP Check reheat steam flow controllers - IN AOP 3575 AUTOMATIC. Step 13.a The US and BOP should recognize that BOP Using the MSR Startup Pressure Display on AOP 3575 perfect symmetrical operation of the the Foxboro DCS, Verify symmetrical Step 13.b Page 24 of 76

SEC IlON 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard MSR reheaters will not be possible operation of the MSR reheaters during power because of the MSR tube leak. decrease.

BOP Using OP 3317, Reheat and Moisture AOP 3575 Separator, Perform manual adjustment of Step 13.b moisture separator reheater steam flow RNO control valves, as necessary.

us Check If RCS Sample Is Required. AOP 3575 Step 14 us Verify change in Reactor Power - GREATER AOP 3575 THAN 15% IN ONE HOUR Step 14.a us Request Chemistry sample the RCS for iodine AOP 3575 (between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after the power Step 14.b change.)

us Request Chemistry Department perform AOP 3575 gaseous effluent samples and analysis Step 14.c (between 24 and 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after the power change) for the following process monitors:

3HVR-REIOB 0 3HVR-RE199 us Verify Target Power Level - LESS THAN AOP 3575 50%. Step 15 us Continue power reduction to the final desired AOP 3575 target power level. Step 15 RNO WHEN Final power level is reached, Page 25 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard THEN Proceed to Step 22.

NOTE: PZR level channel failure event US Check Plant Status AOP 3575 follows the steps for GA-9, Aligning for Step 22 RCS Makeup.

us Verify - A T TARGET POWER LEVEL. AOP 3575 Step 22.a BOOTH If the crew begins to take actions to US/RO Borate or Dilute as necessary to maintain AOP 3575 remove the reheaters from service, AFD as close to the target value as possible Step 22.b call as the OMOC and direct the while maintaining rods above the Rod reheaters be left temporarily in Insertion Limit.

service for evaluation.

T = When BOOTH Acknowledge as Chemistry the request US Request Chemistry obtain RCS boron AOP 3575 Called to obtain RCS boron samples. samples. Step 22.c RO Using GA - 9, Align for auto makeup AOP 3575 Step 22.d GA-9, Aligning For RCS Makeup (rev 000-01)

Check Aligning For Auto Makeup RO GA-9 step1

- DESIRED Boric acid flow of 0 to 40 gpm corresponds to GA-9 step 0 to 10 turns on 3CHS-FKZ 10, boric acid 2 NOTE makeup flow controller as determined on page 8.

RO Align For Auto Makeup GA-9 step 2

Page 26 of 76

SEL I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDAlMalf Instructor ,,iformation/Activity Assign Expected ,ction Standard Check pot setting for boric acid flow rate - GA-9 step DETERMINED BY EOP IN EFFECT 2.a Determine pot setting for boric acid flow for GA-9 step current conditions using the B.A. Flow Rate 2.a RNO table on page 8.

Adjust boric acid blended flow controller GA-9 step (3CHS-FK1 IO) to determined pot setting 2.b Verify total makeup flow controller (3CHS- GA-9 step FKI 11) pot - SET FOR 80 gpm 2.c Check boric acid transfer pumps (3CHS*P2A GA-9 step or 3CHS*P2B) - ONE PUMP IN AUTO 2.d Place total makeup flow controller (3CHS- GA-9 step FKI 11) in AUTO 2.e Place boric acid blended flow controller GA-9 step (3CHS-FK1 IO) in AUTO 2.f Place REAC CLNT MAKEUP SELECT SW in GA-9 step AUTO 24 Place REAC CLNT MAKEUP START SW in GA-9 step START 2.h Verify batch counters - RESET TO "000000" GA-9 step 0 Boric acid batch counter 2.i (3CHS-FYI 1OS)

Primary water batch counter (3CHS-FYI 11B)

Page 27 of 76

SEC; I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDAlMalf Instru c to r Inf ormat ion/Act iv ity Assign Expected Action Standard Go to procedure and step in effect GA-9 step 2.j Event 2: Failure of 3RCS-L459 T= When RX?OA This fails 3RCS-L459 as is during identified by the downpower Sev= as crew is Annunciater CHARG PP F L O W HVLO eventually comes in on low flow. The ARP will direct the crew to AOP 3571, if the cause is an instrument failure.

OP 3353.MB3A 4-9 (rev 002-04)

CORRECTIVE ACTIONS us IF no charging pumps are operating, Go To MB3A AQP 3506, Loss of All Charging Pumps.

step 1 CHECK the following, (MB3): MB3A PZR level will not be on program. RO 0 3CHS-FI 121A, charging flow (MB3),

55 to 100 gpm step 2 0 3CHS-FI 132, letdown flow (MB3), 75 to 120 gpm 0 Pressurizer level on program:

3RCS*LI 459, pressurizer bevel 0 3RCS*Li 460, pressurizer level 0 3RCSLI 461, pressurizer level Page 28 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard After the crew recognizes that the us IF alarm is due to instrument failure, Go To MB3A controlling channel of PZR level has AOP 3571, "Instrument Failure Response."

step 3 failed, the US should go to AOP 3571.

Crew Enter AOP 3571 to address 3571 Entry Conditions AOP 3571 Actions (rev 009-01)

The RO should place the Master PZR RO Determine the Initiating Parameter and AOP 3571 level controller or 3CHS*FCV121 in Place the affected controller in MANUAL Step 1 manual.

Stabilize the Plant Parameters AOP 3571 Step 2 The appropriate attachment for this Perform Corrective Actions Using AOP 3571 failure is "C". The US should announce Appropriate Attachment Step 3 to the crew.

RO Defeat the failed channel input. AOP 3571 Attachment C Step 1 0 Pressurizer Level Select - Control

- 3RCS-LS459D Pressurizer Level Select - Record

- 3RCS-LS459E The US should give specific direction RO Restore PZR level to normal. AOP 3571 to the RO to restore PZR level to Attachment Page 29 of 76

SEC rlON 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard program for the present power level. C Step 2 Letdown should not have isolated. RO If necessary, using OP 3304A, Charging and AOP 3571 Letdown, Restore letdown. Attachment C Step 3 RO Place PZR level controller in automatic. AOP 3571 Attachment C Step 4 RO Reset pressurizer heaters as necessary. AOP 3571 Attachment C Step 5 RO When conditions have stabilized, Observe AOP 3571 MB annunciators and parameters. Attachment Immediately report any unexpected or C Step 6 unexplained conditions to the SM.

US, Trip the associated Reactor Protection AOP 3571 I&C System bistable(s); Attachment C Step 7 us Place a check mark in the box above the AOP 3571 appropriate channel that requires tripping on Attachment the last page of this Attachment. C Step 7a The US should identify the applicable SM Refer to Technical Specification 3.3.1, AOP 3571 TIS and T/R which are: 3.3.3.5, and 3.3.3.6. Attachment C Step 7b r e c h Specs] 3.3.1, Functional Unit 11, Action 6 IF PZR level deviates from program level by + or - 6%, then also 3.4.3.1, Action b.

Page 30 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDAIMalf Instructor InformationIActivity Assign Expected Action Standard The RO should do a lamp check to RO Check the existing bistable status to ensure a AOP 3571 ensure all bistable lights are reactor trip will not occur when the failed Attachment functional. channel is tripped. C Step 7c The following step will distinguish whether the AOP 3571 failure is within SSPS or the Protection Attachment channel. C Step 7d NOTE NOTE: This is not the case. The If bistable status light(s) ( MB4F) indicate that AOP 3571 channel has failed. The US should go a single bistable input has tripped and Attachment to step 7.e. channel indication is normal, PERFORM the C Step 7d following:

T=2 mins of RXRIO6 OPEN Protection Set 1 Door I &C Request the I&C Department trip the AOP 3571 request appropriate bistables using Attachment C and Attachment Attachment S. C Step 7e RXR25 PZR High Level Trip BIS RO Verify the appropriate bistable status lights AOP 3571 are lit. Attachment RXRI 06 CLOSE Protection Set 1 Door C Step 7f us If indicator 3RCS*LI 459C is failed, Refer to AOP 3571 TRM Table 7.4.1, Fire Related Safe Attachment Shutdown Components, Reactor Coolant C Step 8 System.

us Request I&C Department perform corrective AOP 3571 maintenance on failed instrument. Attachment C Step 9 Page 31 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 cha 1 Task Time IDA/Ma If Instructor InformationlActivitv Assign Expected Action Standard Event 3: D Steam Generator steam flow instrument fails low T = When RSCU 3 D Steam Generator steam flow instrument fails low (3MSS-FT542) 3571 (RX14G) complete AOP 3571 Actions (rev 009-01)

The BOP should place the D Feed Crew Determine the initiating parameter and AOP 3571 Reg Valve controller and the place the affected controller in MANUAL. Step 1 Feedwater Pump Master Speed Controller in manual.

Crew Stabilize the plant parameters. AOP 3571 Step 2 The appropriate attachment for this Perform Corrective Actions Using AOP 3571 failure is M. The US should announce Appropriate Attachment Step 3 to the crew.

BOP If the failed steam flow channel is selected AOP 3571 as the input to SG level control, Perform Attach ment the following: M Step 1 BOP Verify the affected SG feed regulating valve AOP 3571 controller is in MANUAL. Attachment M Step 1.a BOOTH If the BOP causes a trip on LO LO BOP Verify feedwater pump A and B master speed AOP 3571 SG level, bypass the RCP oil control (3FWS-SK509A) in MANUAL and Attachment reservoir leak event (Event 5) and Restore feed pump differential pressure to M Step 1.b ensure the small break LOCA normal operating band (Program: 40 to 140 (RC02C) went active on BTI. psid).

Page 32 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDAlMalf lnstru t- lnformatio /Activity Assign Expected Action Standard BOP Restore SG level to normal. AOP 3571 Attach ment M Step 1.c BOP Defeat the failed channel input by selecting AOP 3571 the alternate channel on the steam flow Attachment selector (also selects the alternate SG M Step 1.d pressure instrument input to SGWLC).

BOP When SG level is restored and feed/steam AOP 3571 flow are matched, Perform the following: Attachment M Step 1.e Restore feed pump speed control to normal DP (Program: 40 to 140 psid) and Place the feed pump master speed controller in automatic.

Place the affected steam generator feed regulating valve controller in AUTO.

BOP/ When conditions have stabilized, Observe AOP 3571 MB annunciators and parameters. Attachment Ro Immediately report any unexpected or M Step 2 unexplained conditions to the Shift Manager.

The calorimetric program US/S M There are no Technical Specifications AOP 3571 automatically shifts to feed flow or bistables to be tripped associated Attach ment based at 88%power. This instrument with the steam flow instruments. M Step 3 failure should not cause a shift to an NCTE NI based output. 0 When the plant calorimetric is based on steam flow, the program will automatically shift to an NI based output if any steam flow channel is X-Page 33 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Inst ructor Info rmat ion/Activity Assign Expected Action Standard tagged by the process computer.

If desired, using SP31002, Plant A O P 3571 CaI o rimet ric, SeIect IF0RCED FEED FLOW Attachment CALC on the plant process computer. M Step 3 The US should call l&C and report USEM Request I&C Department perform A O P 3571 the instrument failure. corrective maintenance on failed Attachment instrument. M Step 4 Event 4: Loss of Battery Bus 4 T = AOP RSCU 5 Loss of Battery Bus 4 3571 com plete (EDOSD)

Battery 4 trouble and inverter 4 trouble annunciators alarm. The Battery 4 trouble ARP will direct the crew to AOP 3563.

AOP 3563, Loss of DC Bus Power, Rev. 007-03 BOP Check The Following DC Busses - AOP 3563 ENERGIZED step 1 Bus 301A-1 (Battery Bus 1)

Bus 301 B-I (Battery Bus 2)

Bus 301C-I (Battery Bus 5)

Page 34 of 76

SEC rlON 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Bus 301D - I (Battery Bus 6)

Check Bus 301A-2 (Battery Bus 3) - AOP 3563 ENERGIZED step 2 Check Bus 301B-2 (Battery Bus 4) - AOP 3563 ENERGIZED step 3 Use Attachment D. AOP 3563 step 3 RNO VIAC-4 will still be energized from us Verify VIAC-4 is energized from inverter 4 or AOP 3563 inverter 4 the alternate power supply. Att.D step 1

The US should contact Electrical USlBOP Restore normal DC power alignment using AOP 3563 Maintenance or the work week /PEO OP 3345C, 125 Volt DC. Att.D step coordinator to initiate investigation and 2 repair efforts.

T=5 BOOTH Report as PEO that the Low DC Bus minutes alarm is in on Inverter 4.

from being dispatched

[Tech Specs] The following apply for a US Refer to the following technical specifications AOP 3563 loss of DC bus 4: for required actions: Att. D step 3

3.8.2.1 Action b (24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> action statement) 3.8.3.1 Actions b, c. (2 and 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> action statements respectively)

Page 35 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard 0 3.8.2.1 D.C. Sources Modes 1-4 0 3.8.2.2 D.C. Sources modes 5 and 6 0 3.8.3.1 Onsite Power Distribution Modes 1-4 0 3.8.3.2 Onsite Power Distribution Modes 5 and 6 NOTE: If called, Electrical Maintenance Continue With Normal Plant Evolutions AOP 3563 reports a bus fault on Battery Bus 4. Using Applicable Plant Procedures. step 4 More investigation is necessary.

T= AOP 3563 RSCU 6 EVENT 5: RPCCW Leak into RCP C complete Upper Oil Reservoir RC14C 100%

OP 3353.MB4B 4-6A Actions (rev 004-05)

NOTE: The reservoir high level alarm RO Check RCS-L477A, RCP C upper oil reservoir OP will sound after the malfunction has level computer point, to confirm alarm. 3353.MB4 been in about 3 minutes. B Step 1 CREW MONITOR the following RCP C computer OP points: 3353.MB4 B Step 2 Page 36 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 cha 1 Task Time IDNMalf Inst ruct o r I nf ormat i o nlAct ivity Assign Expected Action Standard 0 RCS-T481A, RCP C upper thrust bearing temperature.

RCS-T481B, RCP C lower thrust bearing temperature.

RCS-T485A, RCP C upper thrust bearing temperature.

RO IF at any time RCP B thrust bearing or radial OP bearing temperature computer point is greater 3353.MB4 than 195 F PERFORM the following: B Step 3 IF reactor power is greater than P-8 OP (37%), PERFORM the following: 3353.MB4 B Step 3.1 0 TRIP reactor OP 3353.MB4 B Step 3.1.1 0 STOPRCPC OP 3353.MB4 B Step 3.1.2 GOTO E-0 OP 3353.MB4 B Step 3.1.3 The US should refer to AOP 3554, us Refer to AOP 3554, RCP Trip or Stopping an OP which will direct him to reduce power. RCP at Power, and REMOVE RCP C from 3353.MB4 service. B Step 3.2 Page 37 of 76

SEC; I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard us CHECK 3CCP-LI 20B, RPCCW surge tank OP level, for indication of RPCCW leakage. 3353.MB4 B Step 4 us The following step requires containment entry. OP 3353.MB4 B ALARA Step 5 CREW IF directed by the SM/US CHECK for RPCCW OP to RCP C lube oil leak. 3353.MB4 B Step 5 us Refer to Tech Specs and DETERMINE LCOs OP 3353.MB4 B Step 6 AOP 3554, Stopping an RCP at Power, RO Check RCP Status - ALL PUMPS RUNNING AOP 3554 Rev. 008-00 Step 1 RO Check Reactor Power AOP 3554 Step 2 Verify THREE LOOP PERMISSIVE P-8 AOP 3554 annunciator (MB4D 3-3) - LIT. Step 2.a NOTE: The rate at which temperature Using one of the following, reduce power as AOP 3554 is increasing should urge the crew to required: Step 2.a use the Rapid Downpower procedure. RNO However, the degrading oil reservoir condition will eventually either impel the Crew to manually trip the Reactor OR the RCP will seize and Page 38 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard the Reactor will trip on RCP Low Speed. It is not expected that the crew will start the downpower.

0 AOP 3575, Rapid Downpower 0 OP 3204, At Power Operation At the time RCP C thrust bearing or radial bearing temperature reaches 195O F it is expected the US will direct the reactor be tripped and then C RCP.

RO IF at any time RCP B thrust bearing or radial OP bearing temperature computer point is greater 3353.MB4 than 195 F PERFORM the following: B Step 3 IF reactor power is greater than P-8 (37%), OP PERFORM the following: 3353.MB4 B Step 3.1 NOTE: US should go to Master RO TRIP reactor OP Silence before ordering 3353.MB4 reactor trip . B Step 3.1.1 RO STOP affected RCPs (RCP D) OP 3353.MB4 B Step 3.1.2 Page 39 of 76

SEC (ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time I DA/MaIf Inst ru cto r Informat ion/Act ivity Assign Expected Action Standard CREW Go to E-0, Reactor Trip or Safety injection. OP 3353. MB4 B Step 3.1.3 Event 6:

C Hot Leg break (Inside CTMT)

NOTE:

T = Reactor The small break LOCA will initiate Trip upon the reactor trip. (MALF RCOZC, 0.20% @ 60 sec ramp)

E-0 (Rev. 22) STEPS Crew 0 Foldout page must be open E-0, Step 1, NOTE ADVERSE CTMT defined as GREATER THAN 180°F or GREATER THAN 1o5R/h, in containment.

Page 40 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 cha 1 Task Time IDNMalf Inst ruct o r Info rmat io n/Act ivity Assign Expected Action Standard 0 The reactor can be interpreted as "tripped" when any two of three bulleted substeps of Step 1.* are satisfied.

RO Verify Reactor Trip E-0, Step 1 0 Check reactor trip and bypass breakers - OPEN 0 Check rod bottom lights - LIT 0 Check neutron flux -

DECREASI NG RO TRIP the reactor. E-0, Step 1, RNO Verify Turbine Trip E-0, Step 2 Check all turbine stop valves - E-0, CLOSED Step 2.a BOP Verify Power to AC Emergency E-0, Step 3 Busses BOP Check busses 34C and 34D - E-0, Step 3.a BOTH ENERGIZED us Check If SI Is Actuated E-0, Step 4 RO Verify SAFETY INJECTION E-0, ACTUATION annunciator - (MB4D 1-6 Step 4.a or MB2B 5-9) - LIT Page 41 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDA/Malf I nst ruct o r I nfo rmat ion/Activity Assign Expected Action Standard Critical Task - us Check if SI is required E-0, Step 4.a, Crew should identify that SI did not actuate and it is required. SI RNO [I should b e manually actuated.

The A and B SI pumps will fail to 0 CTMT pressure GREATER THAN auto-start. The RO will need to 18 psia manually start the pumps.

OR 0 PZR pressure LESS THAN 1890 psia OR 0 PZR level LESS THAN 9%

OR 0 RCS subcooling LESS THAN 32°F OR 0 SG pressure LESS THAN 660 Psig IF SI is required, THEN Initiate SI and Proceed to step 4.c.

Check Reactor trip and bypass E-0, breakers - OPEN Step 4.c Page 42 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDA/Malf Instructor InformationlActivity Assign Expected Action Standard Check Reactor trip and bypass E-0, breakers - OPEN Step 4.c RO Verify Service Water Pumps - AT E-0, Step 5 LEAST ONE PER TRAIN RUNNING START pump(s) E-0, Step 5, RNO RO Verify Two RPCCW Pumps - ONE E-0, Step 6 PER TRAIN RUNNING RO Verify ECCS Pumps Running E-0, Step 7 0 Check SI pumps - RUNNING 0 Check RHR pumps - RUNNING 0 Check two charging pumps -

RUNNING BOP Verify AFW Pumps Running E-0, Step 8 Check MD pumps - RUNNING E-0, Step 8.a Critical Task - START pump(s) E-0, Step 8.a, The BOP should identify that the AFW pumps failed to automatically RNO r]

start when required. The BOP should manually start both MDAFW pumps and the TDAFW pump.

Page 43 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 cha 1 Task Time IDA/Ma If Instructor InformationlActivity Assign Expected Action Standard Check turbine - driven pump - E-0, RUNNING, IF NECESSARY Step 8.b OPEN steam supply valves. E-0, Step 8. b, RNO [*I Check turbine - driven pump - E-0, RUNNING, IF NECESSARY Step 8.b BOP Verify FW Isolation E-0, Step 9 Check SG feed regulating valves -

CLOSED 0 Check SG feed regulating bypass valves - CLOSED 0 Check FW isolation trip valves -

CLOSED 0 Check TD FW pump - TRIPPED 0 Check MD FW pumps -

STOPPED Check SG blowdown isolation valves - CLOSED 0 Check SG blowdown sample isolation valves - CLOSED 0 Check SG chemical feed isolation valves - CLOSED Page 44 of 76

SEC IION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDAlMalf Inst ruc t or Inf ormat ionlAct iv itv Assian ExDected Action Standard BOP Check If Main Steam Lines Should E-0, Step 10 Be Isolated Check Ctmt pressure GREATER E-0, THAN 18 psia Step 10.a Any SG pressure LESS THAN 660 Psig Proceed to Step 11 E-0, Step 10.a, RNO Verify MSlVs and MSlV bypass valves E-0,

- CLOSED Step 10.b Check ESF Group 3 lights - LIT. E-0, Step 1O.c RO Check if CDA Required E-0, Step 11 CTMT pressure will ultimately reach Check Ctmt pressure is GREATER E-0, the CDA setpoint. The crew should THAN 23 psia Step 11.a recognize that CDA did not actuate.

Manual component alignment is required.

OR Ctmt spray - INITIATED us Proceed to Step 12. E-0, Step11,a, RNO Page 45 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard BOP Verify CAR Fans Operating In E-0, Step 12 Emergency Mode BOP Check CAR fan status: E-0, Step 12.a 0 CAR fans A and B - RUNNING 0 CAR fan C - STOPPED BOP STARTETOP CAR fans as E-0, necessary. Step 12.a, RNO RO Verify RPCCW Ctmt supply and return E-0, header isolations - OPEN Step 12.b RO Verify Train A and B RPCCW supply E-0, and return to chill water valves - OPEN Step 12.c RO Verify CIA E-0, Step 13 RO Check ESF Group 2 status columns 2 E-0, through 10 - LIT Step 13.a RO Verify Proper ESF Status Panel E-0, Step 14 Indication 0 Verify ESF Group 1 lights - OFF The A and B SI pumps will fail to 0 Verify ESF Group 2 lights - LIT auto-start. The RO will need to manually start the pumps.

RO Determine If ADVERSE CTMT E-0, Step 15 Conditions Exist Page 46 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDA/Malf Inst r ucto r Info rmat ion/Act ivity Assign Expected Action Standard 0 Ctmt temperature GREATER THAN 180°F 0 Ctmt radiation GREATER THAN i o 5R~h, RO Verify ECCS Flow E-0, Step 16 Check charging pumps - E-0, Step 16.a FLOW INDICATED RO Check RCS pressure - GREATER E-0, THAN 1650 psia (1950 psia Step 16.b ADVERSE CTMT) us Proceed to Step 16.e E-0, Step 16.b, RNO Check PORV block valves - OPEN E-0, Step 16.c OPEN energized block valves. E-0, Step 16.c RNO CREW should perform a short brief Proceed to step 17 E-0, and come out of "Master Silence" at Step 16.d the completion of Step 16.

Check SI pumps - FLOW INDICATED E-0, Step 16.e Page 47 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDAlMalf Inst ructo r Inf o rmationlActivity Assign Expected Action Standard START pumps and Align valves. E-0, Step 16.e RNO Check RCS pressure - LESS THAN E-0, 300 psia (500 psia ADVERSE CTMT) Step 16.f Proceed to step 17 E-0, Step 16.f RNO BOP Verify Adequate Heat Sink E-0, Step 17 Check NR level in at least one SG - E-0, GREATER THAN 8% (42% ADVERSE Step 17.a CTMT) us Proceed to Step 17.d E-0, Step 17.a, RNO BOP Verify Total AFW Flow - GREATER E-0, THAN 530 gpm Step 17.d BOP Verify AFW Valve Alignment - E-0, Step 18 PROPER EMERGENCY ALIGNMENT RO Verify ECCS Valve Alignment - E-0, Step 19 PROPER EMERGENCY ALIGNMENT CJS Check Plant Status E-0, Step 20 BOOTH NOTE When asked, REPORT that "all Verify SLCRS doors - CLOSED E-0, I NST SLCRS doors indicate closed." Step 20.a Page 48 of 76

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-I

SEC I-ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard RO Verify ESF Group 2 CBI lights - LIT E-0, Step 20.c RO Align HVAC components as necessary E-0, for minimum safety function. Step 20.c, RNO BOP Verify control building purge supply E-0, fan and purge exhaust fan - NOT Step 20.d RUNNING BOP Verify control building air bank E-0, isolation valves - OPEN Step 20.e BOP STOP kitchen exhaust fan E-0, Step 20.f T+ 5 min BOOTH Report the Control Building PEO CLOSE and DOG the following E-0, of request Pressure Boundary doors are Control Building pressure boundary Step 20.9 closed & dogged or verified doors.

closed as directed.

a CB west 476 (C-47-1A)

. CB east 64 6 (C-64-1B)

Verify the following Control Building E-0, pressure boundary doors - CLOSED Step 20.h CB west 476 (C-47-1)

. CB north 646 chiller room door (C-64-4)

Page 50 of 76

Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 cha 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard CB north 646 chiller room door (C-64-5)

. CB west 496 (C-49-1)

RO Check RCS Temperature E-0, Step 21 Verify RCS cold leg WR temperature - E-0, BETWEEN 550°F AND 560°F. Step 21 .a Page 51 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard us Perform the applicable action: E-0, Step 21 .a, RNO

. -IF temperature is GREATER THAN 560°F, THEN Proceed to step 21 .c.

IF temperature is LESS THAN 550°F THEN Proceed to step 21 .e.

BOP Maintain total feed flow BETWEEN E-0, 530 and 600 gpm until NR level is Step 21 .e GREATER THAN 8% (42%

ADVERSE CTMT) in at least one SG BOP CLOSE SG atmospheric dump and E-0, dump bypass valves Step 21 .f BOP Check the following valves - CLOSED E-0, Step 21 .g

' MSlVs MSlV bypass valves RO Check PZR Valves E-0, Step 22 Verify PORVs - CLOSED E-0, Step 22.a Page 52 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RO Verify normal PZR spray valves - E-0, CLOSED Step 22.b RO Verify PZR safety valves - CLOSED E-0, Step 22.c CREW To prevent damage to the RCP E-0, seal(s), seal injection flow should be Step 23, maintained to all RCPs. CAUTION RO Check If RCPs Should Be Stopped E-0, Step 23 Verify RCPs - ANY RUNNING E-0, Step 23.a RO Verify RCS pressure - LESS THAN EOP 35 E-0, 1500 psia (1800 psia ADVERSE Step 23.b CTMT)

RO Verify charging or SI pumps - AT E-0, LEAST ONE RUNNING Step 23.c Critical Task - RO STOP all RCPs E-0, Step 23.d RCS pressure will eventually lower to < 1500 psia. Crew should identify this and trip all RCPs.

[I BOP/RO Check If SG Secondary Boundaries E-0, Step 24 Are Intact Check pressure in all SGs E-0, Step 24.a Page 53 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard

= NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER

. NO SG COMPLETELY DEPRESSURIZED BOP Check If SG Tubes Are Intact E-0, Step 25 RO Sample all SGs for activity E-0, Step 25.a

1. RESET SG blowdown sample isolation

2. OPEN SG blowdown sample isolation valve(s)

BOOTH Acknowledge the request to 3. Request Chemistry obtain activity perform the S/G samples. Ensure samples using HP coverage crew request activity samples with HP coverage BOP Check steam generator levels - NO E-0, SG LEVEL INCREASING IN AN Step 25.b UNCONTROLLED MANNER Verify trend history and alarm status E-0, of radiation monitors Step 25.c 0 Main steam line - NORMAL 0 Condenser air ejector - NORMAL 0 SG blowdown - NORMAL Page 54 of 76

SEC rlON 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RO Check If RCS Is Intact E-0, Step 26

. Verify Ctmt radiation using 3CMS*RE22 (pre-trip) -

NORMAL

. Verify Ctmt radiation using radiation monitoring group histogram (CTMT) -

NORMAL CTMT pressure will not be normal. Verify Ctmt pressure -

NORMAL

. Verify Ctmt recirculation sump level - NORMAL us Initiate monitoring of CSF Status E-0, Step 26 Trees and Go to E-I, Loss of Reactor RNO or Secondary Coolant.

NOTE: Depending on CTMT pressure, the crew may go to FR-2.1 if the CTMT CSF is ORANGE, since status trees are now in effect.

E - I (rev 021) Actions RO To prevent seal damage, seal E - I , Step 1 injection flow should be maintained to CAUTION all RCPs.

Note The US should remind the operators us Note: Foldout page must be open. E-I, Step 1 to review their Foldout Page Books NOTE Page 55 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RCP's should have been stopped in us Check If RCPs Should Be Stopped E-I, Step 1 E-0 RO Verify RCP's - ANY RUNNING E - I Step l a us Proceed to step 2 E - I Step l a RNO us Check If SG Secondary Boundaries E-I, Step 2 Are Intact BOP/ Check pressures in all SGs. E-I, Step 2a RO NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER NO SG COMPLETELY DEPRESSURIZED us Check Intact SG Levels E-I, Step 3 BOP Verify NR level - GREATER THAN E - I , Step 3a 8% (42% ADVERSE CTMT)

BOP Control feed flow to maintain NR level E-I, Step 3b between 8% and 50% (42% and 50%

ADVERSE CTMT) us Check Secondary Radiation E-I, Step 4 Page 56 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDA/Malf Instructor InformationlActivity Assign ExDected Action Standard RO Sample all SGs for activity. E-I, Step 4.a

1) RESET SG blowdown sample isolation.

2) OPEN SG Blowdown sample isolation valve(s)

3) Request Chemistry obtain activity samples using HP coverage RO Verify trend history and alarm status E-I, of radiation monitors Step 4. b Main steam line - NORMAL Condenser air ejector - NORMAL SG blowdown - NORMAL CREW If any PZR PORV opens because of E-I, Step 5 high PZR pressure, step 5a should CAUTION be repeated after pressure decreases to LESS THAN 2350 psia.

us Check PZR PORVs and Block E-I, Step 5 Valves RO Verify PORVs - CLOSED E-I, Step 5a RO Verify block valves - AT LEAST ONE E-I, Step 5b OPEN Page 57 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 cha 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard us Check If ECCS Flow Should Be E-I, Step 6 Reduced Subcooling should be ~ 3 2 ° and/or F RO Verify RCS subcooling based on core E-I, Step 6a PZR level c 16%. exit TCs - GREATER THAN 32°F (1 15°F ADVERSE CTMT)

BOP Verify secondary heat sink E-I Step 6b Total feed flow to intact SGs

- GREATER THAN 530 gpm

. Narrow range level in at least one intact SG - GREATER THAN 8% (42% ADVERSE CTMT)

RO Verify RCS pressure - STABLE OR E - I Step 6c I NCREASI NG RO Verify PZR level - GREATER THAN E - I Step 6d 16% (50% ADVERSE CTMT) us Proceed to CAUTION prior to step 7. E-I, Step 6, RNO us To ensure adequate ECCS flow, do E - I , Step 7 not stop any recirculation spray CAUT I0N pumps used for core injection flow.

Page 58 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time I DAIM a If Instructor Information/Activity Assign Expected Action Standard us The recirculation spray pumps are E-I, Step 7 sequenced to automatically start 11 NOTE minutes after a CDA.

RO Check if containment spray should be E-I, step 7 stopped.

RO Verify quench spray pumps - E-I, Step 7a RUNNING us Proceed to CAUTION prior to step 8. E-I, Step 7a, RNO CREW If offsite power is lost after SI E-I, Step 8 reset, manual actions to restart CAUTION safeguards equipment may be required.

CREW To provide adequate ECCS flow, E-I, Step 8 RCS pressure should be CAUTION monitored to ensure that the RHR pumps are manually restarted if pressure decreases to LESS THAN 300 psia (500 psia ADVERSE CTMT) us Check If RHR Pumps Should Be E-I, Step 8 Stop ped us Check RHR pumps - ANY RUNNING E-I ,

IN SI MODE Step 8.a Page 59 of 76

SEC i ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Inst r uc to r Inf ormat ionlAct iv ity Assign Expected Action Standard Depending on the speed of the RO Check RCS pressure E-I, crew, RCS pressure may still be Step 8.b going down very slowly. If the 1) Verify pressure - GREATER crew elects NOT to stop RHR THAN 300 psia (500 psia pumps based on this trend, this ADVERSE CTMT) is satisfactory.

2) Verify pressure - STABLE OR I NCREASI NG Crew should reset SI RO RESET SI,if necessary E-I, Step 8.c NOTE: This step will stop the RHR RO STOP RHR pumps and Place in Auto E-I, Pumps. If stopped, the pumps will Step 8.d need to be restarted when the LOCA becomes larger.

us Check RCS and SG Pressures E-I, Step 9 BOP Check pressure in all SGs -

INCREASING OR STABLE (consistent with plant cooldown)

RO Check RCS pressure - E-I, Step 9 DECREASING OR STABLE Do not reset CDA if the recirculation E-I, Step 10 spray pumps are required and have CAUTION NOT automatically started.

Page 60 of 76

SEL I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard T= RCOZC This will increase the severity of the us Check If Diesel Generators Should E-I Step 10 step 10 SBLOCA to a point where Be Stopped sev = ADVERSE CTMT will occur and if 100% stopped, the RHR pumps will need to be restarted.

The crew will need t o recognize 3 items:

1- The rise in CTMT pressure will generate an orange path on CTMT, and require transition t o FR-Z.1 2- CDA has failed to actuate.

3- If stopped, RHR pumps will need to be restarted.

Note FR-P.l may come in first. If so the us Go to FR-Z.l and restart the RHR E-I, step 8 crew will perform FR-P.l first as it Pumps caution and has a higher priority OP3272 Page 61 of 76

SEC; I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDAlMalf Instructor Information/Activity Assign Expected Action Standard FR-P.l (rev 013-01) Steps CREW If DWST level decreases to LESS FR-P.l Step THAN 80,000 gal, Shift AFW 1 CAUTION pump suction to the CST using GA-4.

If RWST level decreases to LESS THAN 520,000 gal, Go to ES-1.3, Transfer to Cold Leg Recirculation, to align the ECCS system.

RHR pumps may be started by the RO Check RCS Pressure - GREATER FR-P.1, crew at this point. THAN 300 psia (500 psia ADVERSE Step 1 CTMT) us Perform the applicable action: FR-P. 1, Step 1, RNO IF RHR

- pump flow is LESS THAN OR EQUAL TO 1000 gpm THEN Proceed to step 2.

RHR Pump flow should be > 1,000 IF RHR

- pump flow is GREATER gpm. The appropriate transition will THAN 1000 gpm THEN Go to be to FR-Z.l procedure and step in effect.

FR-Z.l (rev 013-00) STEPS Check If CDA Required FR-Z.1 ~

Step 1 Yes, CTMT pressure will be greater RO Check Ctmt pressure - GREATER FR-Z.1, than 23 psia. THAN 23 psia Step 1.a Page 62 of 76

SEL I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDAlMalf I nst ruct or Info rmat io n/Act iv ity Assign Expected Action Standard CONTAINMENT DEPRESS Verify annunciator C0NTA INMENT FR-Z.1, ACTUATION will NOT be lit. DEPRESS ACTUATION (MB2B 5-5) Step 1.b

- LIT The RO is expected to attempt to RO Initiate CDA FR-Z.1, manually initiate CDA using the Step 1.b main board pushbuttons RNO USlRO Verify CIA FR-Z.1, Step 2 Check ESF Group 2 Status columns FR-Z.1, 2 Through IO- LIT Step 2.a CDA will have failed to Auto us Verify CIB FR-Z.1, Actuate. CIB relays operated on Hi- Step 3 3 and realigned the RPCCW valves RO Check RPCCW Ctmt supply and FR-Z.1, return header isolation valves - Step 3.a CLOSED RO CLOSE valves FR-Z.1, Step 3.a, RNO RO Check RPCCW pumps - STOPPED FR-Z.1, Step 3.b The RPCCW pumps will have to be RO STOP pumps. FR-Z.1, manually stopped. Step 3.b, RNO Page 63 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RO STOP all RCPs FR-Z.1, Step 3.c N/A us If ECA-1.I, Loss of Emergency FR-Z.1, Coolant Recirculation, is in progress, Step 4 Ctmt spray should be operated as CAUTION directed in ECA-1.1.

us Verify Quench Spray System FR-Z.1, Operation Step 4 RO Check annunciator RWST EMPTY FR-Z.1, QSS PP OFF (69,331 gal) (MB2A 5-2) Step 4.a

- NOT LIT RO Verify quench spray pumps - FR-Z.1, RUNNING Step 4.b Critical Task - RO START pumps. FR-Z.1, Step4.b, The RO must manually start the QSS pumps.

RNO ["I Verify quench spray pump discharge FR-Z.l, valves - OPEN Step 4.c 3QSS*MOV34A 3QSS*MOV34B Page 64 of 76

SEC rlON 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMaif instructor information/Activity Assign Expected Action Standard Critical Task - RO OPEN valves. FR-Z. 1, Step 4.c, The RO must manually open the quench spray pump discharge RNO ["I valves.

The BOP will have to manually stop BOP STOP All Main Circulating FR-Z.1, Main Circulating Water Pumps. Step 5 Water Pumps Check Containment Ventilation FR-Z. 1, Step 6 The BOP will have to manually stop BOP Verify CAR fans -

the CAR and CRDM fans. STOPPED BOP Verify CRDM fans -

STOPPED Verify Recirculation Spray System FR-Z.1, Operation Step 7 Check recirculation spray pump FR-Z. I, suction isolation valves - OPEN Step 7.a 0 3RSS*MOV23A 0 3RSS*MOV23B 0 3RSS*MOV23C 3RSS*MOV23D OPEN valves. FR-Z. 1, Step 7.a RNO Page 65 of 76

SEC; I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard Check annunciator CTMT RECIRC FR-Z. 1, PUMP AUTO START SIGNAL Step 7.b (MB2B 1-8 lit) - LIT Perform the applicable action: FR-Z. 1, IF QSS

- flow is indicated, Step 7. b, RNO THEN Proceed to step 9 and, WHEN The annunciator actuates OR 11 minutes elapse since CDA initiation, THEN Return to step 7.c Check recirculation spray pumps - FR-Z. 1, ANY RUNNING Step 7.c Proceed to step 7.e FR-Z 1, Step 7.c, RNO Check Ctmt WR sump level FR-Z 1, (3RSS*L122A, 3RSS*L122B) - Step 7.e GREATER THAN 1.5 feet The RO must manually start the RSS START recirculation spray pumps FR-Z.1, pumps. Step 7.f Verify recirculation spray pump spray FR-Z.1, header isolation valves - OPEN ON Step 7.g RUNNING PUMP (S)

Page 66 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard For pump A - 3RSS*MOV20A For pump B - 3RSS*MOV20B For pump C - 3RSS*MOV20C For pump D - 3RSS*MOV20D Check recirculation spray - FLOW FR-Z.1, INDICATED IN AT LEAST ONE Step 7.h TRAl N IF running pump amps, flow, or FR-Z.1, discharge pressure oscillate THEN Step 7.i

1. RESET SI THEN LOP and CDA

2. STOP affected pump(s).

3. GOto ECA-1.I, LOSSof Emergency Coolant Recirculation Proceed to step 9. FR-Z.1, Step 7.j Verify ESF Status Panel Group 4 FR-Z.1, Lights - LIT Step 9 Operate components as necessary for FR-Z.1 ~

minimum safety function. Step 9, RNO Verify Main Steam Line Isolation FR-Z.1, Step 10 Check MlSVs and MlSV bypass valves - CLOSED Page 67 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Task Time IDAlMalf Instructa I formati n/Activity Assign Ex cted Action Stand rd Check ESF Status Group 3 lights -

LIT Verify Main Feedwater Isolation FR-Z. 1, Step 11 0 Verify MD FW pumps - TRIPPED Verify TD FW pumps - TRIPPED Verify FW isolation trip valves -

CLOSED Verify SG feed regulating valves -

CLOSED Verify SG feed regulating bypass valves - CLOSED Verify SG chemical feed isolation valves - CLOSED At least one SG must be FR-Z.1, maintained available for RCS Step 12, cooldown. CAUTION 0 If all SGs are faulted, at least 100 gpm feed flow should be maintained to each SG.

Check If Auxiliary Feedwater Flow FR-Z.1 ,

Should Continue To All SGs Step 12 Check pressure in all SGs FR-Z.1, Step 12.a Page 68 of 76

SEC I ION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 cha 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER NO SG COMPLETELY DEPRESSURIZED Go to Procedure and Step In Effect FR-Z.l, Step 13 The scenario may be terminated upon completion of FR-Z.I.

Page 69 of 76

SECTION 4 Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 EVALUATION GUIDE I. Crew FOLLOW-UP QUESTIONS

1. What is the Emergency Classification for this event?

ALERT - Charlie One based on failure of the RCS barrier. (RCB4)

2. What plant condition(s) is(are) of greatest concern for (this event)?

Reactor coolant release to the CTMT.

4. What actions did the crew take to directly mitigate (this event)?

Carried out the actions of E-0 and E-I. Identified, the need for a Safety Injection and the restart of the RHR Pumps with CTMT Spray

5. Which safety function(s) were challenged or had the greatest potential for challenge? Describe why.

CTMT Integrity as the CDA required a manual actuation Page 70 of 76

SECTION 4 EXAM GUIDE

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 II. Critical Tasks Note: Critical Tasks are not required for Progress Review Exams.

TASK DESCRIPTION TASK # KIA >I= 3.0 BASIS SELECTION Establish 530 gpm AFW E-O--F 3.914.0 Failure to establish flow to the SIGs before 061 000 GEN 14 minimum required AFW transition out of E-0 flow, under the postulated unless transition to FR- plant conditions, results in H. 1. Then before step 3. "adverse consequences."

Trip all RCPs so that an 3.613.6 Failure to trip the RCPs Orange Path on Core E-' --' 009 EA1.09 under the postulated plant Cooling based on core 4.214.3 conditions leads to core 009 EK3.23 uncovery and to fuel exit thermocouples (718°F) does not occur cladding temperatures in when forced circulation excess of 22OO0F, which is in the RCS stops (small the limit specified in the break LOCA). ECCS acceptance criteria.

Manually actuate at E-O--D 4.514.8 Failure to manually actuate least one train of SIS- 006 030 SI represents a actuated safeguards A2.01 "demonstrated in-ability by before completion of the crew to take an action step 4 of E-0. or combination of actions that would prevent a challenge to plant safety."

Establish at least one EO-E 026 000 Failure to establish at least Quench Spray train flow A I .01 one Quench Spray train before completion of 3,914.2 flow under the postulated FR-Z.l step 4. conditions constitutes a "demonstrated inability by the crew to recognize a fai Iurelincorrect auto actuation of an ESF system or cornponent , 'I Note: [*I Used to designate critical tasks. Should also be incorporated into column 3 or 4 of Instructor Guide.

Page71 o f 7 6

SHIFT TURNOVER REPORT DATE-TIME PREPAREDBY today 0300 Unit Supervisor /Night Shift PLANT STATUS:

Mode: 1 RxPower: 100%

Megawatts: Thermal: 341 1 MWTH PZR Pressure: 2250 psia Electric: 1205 MWe RCS T-AVE: 587 degF RCS Leakage: Identified: 0.005gpm Boron/Burnup 43 ppm / 19,000 MWD/MTU Unidentified: m g p m Days on line 485 DateITime: today 0015 Protected Train/Facility: B Purple PRA/SDR: Green Intake: Green

~ ~~ ~

I Active Trackina Records and Action Statements - 1 Time in LCO Action Date Action Requirement Time Left LCO 3.8.1.1 I b.1, b.2, b.3, b.4, b.5 I yesterday I 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> ISR4.8.1.1.l.a due in 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> 7.4.1 I a.1, a.3 I yesterday I 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> I OD Compensatory Actions / Temp Logs OpenDate 1 ClassReason I Reason I Plant Svstems APC I Svstem Notes I TPCCW I CTPCCW pump is out of service for an oil replacement.

~ ~ ~ ~~~~~

Cross Unit System Status I

Surveillances I Evolutions in Progress I

Shift Orders The A EDG is out of service for a planned 2 year overhaul maintenance outage. The C TPCCW DumD is out of service for an oil redacement.

Page 72 of 76

ATTACHMENT 2 VAL IDATl0N C HECKLI ST

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Verified By:

(I nitiaIs)

Initial Conditions:

The initial condition(s) contained in the guide are certified or have been DM developed from certified ICs.

Test Run:

The scenario contained in the guide has been test run in part or whole on -

DM the simulator. The simulator response is reasonable and as expected. If a simulator guide revision does not affect original Test Run, then enter N/A.

Simulator Operating Limits:

The simulator guide has been evaluated for operating limits and/or DM anomalous response by reviewing the Simulator Modeling and Anomalous Response List.

ten D. L. Minnich 1/24/07 Actions Complete (Signature) Date Page 73 of 76

Appendix D Scenario Outline Form E S - D-

-1 Facility: Millstone 3 Scenario No.: 2K7 NRC-01 Op-Test No.: 2K7 Examiners: Operators:

Initial Conditions: IC-21, 100% power, End of Life, Equilibrium Xe. -

Turnover:

The plant is at 100% power and at end of life. The A Emergency Diesel Generator is out of service for rnaior maintenance. The C TPCCW pump is out of service for oil replacement.

Event Malf. No Event Event

~~~~

No. Type* Description 1 MS05B C (BOP) Moisture Separator Reheater tube leak and subsequent N (SRO) procedurally required downpower. AOP 3575, Rapid R (RO) Downpower.

R (SRO)

N (BOP) -

2 RXIOA 1 (RO) Controlling channel of PZR level fails as is (3RCS*L459) in conjunction with downpower. -

3 RX14G I (BOP) D Steam Generator steam flow instrument fails low (3MSS-FT542). -

4 EDO9D Loss of Battery Bus 4. -

5 RC14C C (RO) RPCCW leak into upper oil reservoir of C RCP. -

6 RC02C M (ALL) Small break LOCA inside CTMT. Safety Injection fails RPO7A/B C (RO) to auto-actuate. AFW pumps fail to auto-start. SIH FW20 C (BOP) pumps fail to auto-start.

S107A/B 7 RC02C C (RO) Large break LOCA inside CTMT. CDA fails to auto-RPOGAIB actuate.

I I I

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page -74 of 76

Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chg 1 Assessor: Dave Minnich QUALITATIVE ATTRIBUTES

-Y-I. The initial conditions are realistic, in that some equipment and/or instrumentation may be out of service, but it does not cue the crew into expected events.

-Y-2. The scenario consists mostly of related events.

Y 3. Each event description consists of:

- the point in the scenario when it is to be initiated

- the malfunctions(s) that are entered to initiate the event

- the symptoms/cues that will be visible to the crew

- the expected operator actions (by shift position)

- the event termination point (if applicable)

Y 4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario without a credible preceding incident such as a seismic event.

-Y-5. The events are valid with regard to physics and thermodynamics.

-Y-6. Sequencingltiming of events is reasonable, and allows for the examination team to obtain complete evaluation results commensurate with the scenario objectives.

-NIA-7. If time compression techniques are used, scenario summary clearly so indicates. Operators have sufficient time to carry out expected activities without undue time constraints. Cues are given.

_ .Y-8. The simulator modeling is not altered.

-Y-9. The scenario has been validated. Pursuant to 10 CFR 55.46(d), any open simulator performance deficiencies or deviations from the referenced plant have been evaluated to ensure functional fidelity is maintained while running the planned scenario.

-Y-IO. Every operator will be evaluated using at least one new or significantly modified scenario All other scenarios have been altered IAW Section D.5 of ES-301.

-Y-I 1. All individual operator competencies can be evaluated, as verified using form ES-301-6.

-Y-12. Each operator will be significantly involved in the minimum number of transients and events specified on Form ES-301-5.

-Y-I 3. Level of difficulty is appropriate to support licensing decisions for each crew position.

Page 75 of 76

Lesson

Title:

Large Break LOCA ID Number: 2K7 NRC-01 Revision: 0 chq 1 Note: Following criteria list scenario traits that are numerical (QUANTITATIVE) in nature

01. Total Malfunctions (TM) - 5 to 8 required Total 9 (1) MSR Tube Leak, (2) PZR Level Failure, (3) Steam Flow Failure, (4) Loss of DC Bus Power (5) RCP Oil Reservoir Leak, (6) LOCA in CTMT, (7) ESF Auto Actuation Failure (SI), (8) AFW pumps fail to Auto Start, (9) ESF Auto Actuation Failure (CDA)

02. Malfunctions after EOP entry (EM'S)- 1 to 2 required Total 3 (1) ESF Auto Actuation Failure (SI), (2) AFW pumps fail to Auto Start, (3) ESF Auto Actuation Failure (CDA)

03. Abnormal Events (AE) - 2 to 4 required Total 5 (1) Rapid Downpower (AOP 35754, (2) PZR Level Failure (AOP 3571), (3) Steam Flow Failure (AOP 3571), (4) Loss of DC Bus Power (AOP 3563), (5) RCP Oil Reservoir Leak

04. Major Transients (MT) - 1 to 2 required Total 1 (1) LOCA inside CTMT

05. EOP's (EU) enteredhequiring substantive actions -- 1 to 2 required Total 2 (1) E-I, (2) FR-Z.l

06. EOP Contingencies requiring substantive actions [ECAs/FRs/] (EC) -- Total 1 0 to 2 required (1) FR-Z 1

07. Critical Tasks (CT) - 2 to 3 required Total 4 E D Manually actuate at least one train of SI before completion of step 4 of E-0 4- F Establish 530 gpm of AFW flow before transitioning out of E-0 4- E Establish at least one train of QSS spray before completion of step 4 of FR-Z 1

, 5 7 4 Trip all RCP's before an Orange Path on core cooling

08. Approximate Scenario Run Time: 60 to 90 min. Total a m i n

09. EOP run time: Total 45 min IO. Technical Specifications are exercised during the scenario. (Y/N)--Y-Page 76 of 76

MILLSTONE POWER STATION SIMULATOR EXAM GUIDE APPROVAL SHEET Exam

Title:

Four Faulted Steam Generators Revision: 0 chg 1 ID Number: 2K7 NRC-02 II II This document is the property of the Millstone Power Station which controls its distribution. Further transfer, copying, or modification of this document is strictly prohibited without the written consent of the Millstone Power Station.

Submitted by: D. Minnich 1/I1107 Developer Date Validated by: Ray Martin 1/24/07 Technical Reviewer Date Approved by: Tim Kulterman 1/24/07 Training Supervisor Date STOP THINK ACT REVIEW

MILLSTONE POWER STATION SIMULATOR EXAM GUIDE APPROVAL SHEET Exam

Title:

Four Faulted Steam Generators Revision: .o ID Number: 2K7 NRC-02 I P I

This document is the property of the Millstone Power Station which controls its distribution. Further transfer, copying, or modification of this document is stnctly prohibited without the written consent of the Millstone Power Station.

R II Submitted by: D. Minnich I 1/11/07 Developer Date Validated by: p%iiL 1/&/7 Technical Reviewer Date I Approved by:

Tyaining Supervisor I I24107 Date STOP THINK ACT REVIEW

SUMMARY

OF CHANGES Change Description Date of Change Added an additional critical task, which reads as follows: Trip all 02115/07 RCPs so that an Orange Path on Core Cooling based on core exit thermocouples (718°F) does not occur when forced circulation in rev 0, chg 1 the RCS stops. Added Manual Bypass on the Bypass Status Panel for the " A EDG as part of setup. Allowed for scenario termination to be initiated by the examiner's cue.

STOP THINK ACT REVIEW

SECTION 2 SIMULATOR EXAM GUIDE TABLE OF CONTENTS SECTIONS LISTED IN ORDER

1. Cover Page

2. Table of Contents

3. Exercise/Exam Overview

4. Exam Guide Attachments:

- Shift Turnover Report

- Validation Checklist

- Scenario Outline (ES-D-1)

- Attributes Checklist

- Summary of Changes Page 3 of 68

SECTION 3 EXAM OVERVIEW

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 cha 1 Exam Brief:

1. The Session will begin with the plant at 100% power and at end of life. The A EDG is out of service for planned maintenance. The C TPCCW pump is out of service for an oil replacement. Shortly after turnover is complete a Pressurizer Pressure Instrument will fail high.

This failure will require the use of AOP 3571, lnstrument Failure Response, to respond to the failure. The procedure should be completed up to and including addressing any required Technical Specifications.

After completion of AOP 3571, a feed flow instrument failure will occur on the C Steam Generator. Again, the crew should enter AOP 3571 Instrument Failure Response to address the failure.

Once feed control has been regained and C SG water level stable, RCS leak of about 20 gpm will occur from the reactor vessel flange inner O-ring. VCT level will decrease, CDTT level will increase and the annunciator for high flange leakoff temperature will alarm. The crew will enter the annunciator response procedure for RX VSSL FLG LEAKOFF TEMP HI, to mitigate the event. Leakage will be in excess of the Tech Spec limit on Identified RCS leakage. The leak will be isolable.

After the crew has isolated the RCS leak, a narrow range Tc instrument will fail high. Rods will begin stepping in. The crew will utilize AOP 3571, Instrument Failure Response to mitigate the failure.

When AOP 3571 is complete, CONVEX will direct the crew to begin an Emergency Load Reduction decreasing unit electrical output by 300 MWe. The crew will use AOP 3575, Rapid Downpower to accomplish this down power. The emergency boration valve, 3CHS*MV8104, will fail to open and the RO will have to use the RNO steps to achieve boration flow.

Once the crew has completed the downpower, the electrical grid will become unstable resulting in a main generator trip. The reactor will fail to automatically trip [Critical Task],

resulting in SG pressures increasing. A steam break will occur upstream of the A MSlV inside the Main Steam Valve Building. Once the plant is tripped, the A & B MSlVs will fail to close and the C and ID SG low set safety valves will stick open. Main Steamline Isolation (MSI) will fail to automatically actuate, necessitating the crew to manually initiate MSI [Critical Task].

Additionally, several RPCCW components will fail to respond as required to the safety injection signal and will have to be manually positioned by the crew. Also, RCP trip criteria will be met, requiring the crew to trip RCPs. The crew should proceed through E-0 to E-2 to ECA-2.1. After progressing into the SI Termination steps of ECA-2.1, the C low set safety valve will close. The scenario will end when the crew identifies the safety valve closure and pressure increasing in the C SG, and discusses the transition to E-2, once SI termination is complete, or the examiners cue.

2. The SM/ US should classify this event as an ALERT based on failure of automatic reactor trip (EAI). The event is also classifiable at the ALERT level based on Unisolable Steam Line Break outside CTMT (BA2).

Page 4 of 68

3. Duration of Exam: 75 minutes Page 5 of 68

SECTION 4 EXAM GUIDE

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 cha 1 All Control Room Conduct, Operations and Communications shall be in accordance with Master Manual 14 and applicable DNAPIDNOS standards.

Page 6 of 68

SECTION 4 EXAM GUIDE

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 cha 1 SIMULATOR PROBLEMS DURING EXAMS It is the responsibility of the Instructors in the simulator to insure that training interruptions have a minimum negative impact on the Crew and the training we provide. Use your judgment on whether to stop the training and how the training should be commenced after the problem is corrected.

Be aware that at all times the Operators should treat the simulator as if it were the plant and you too should treat it as much like the plant as possible when they are in the simulator.

As soon as the Instructors are aware of a simulator problem that will adversely affect the training in progress (computer fault, etc.) the Instructor should:

1. Place the simulator in FREEZE if possible.

2. Announce to the Crew that there is a simulator problem.

3. Request that the Crew either standby (for minor trouble that can be handled quickly) or leave the simulator control room. (The Crew should leave the simulator for problems which involve major switch alignments).

4. Deal with the problem (reboot, close tripped breaker, call STSB, etc.)

5. After the Instructors believe the simulator is restored to service, the Crew should be told how training will continue. If it is possible and felt to be acceptable to the Instructors, training can begin where it left off with an update on plant parameters and each Crew member is prepared to restart. If training will not begin where it left off, the crew should be told how and where training will begin again.

6. Once the Crew has been told how and where training will begin, have the crew conduct a brief so that the Instructor can insure that the crew has all the necessary information to continue with the scenario.

7. Once all Crew members and Instructors are satisfied that they have the necessary information to continue the scenario, place the simulator in RUN and announce to the Crew that you have continued the training session.

Page 7 of 68

SEC; (ION 4 Lesson

Title:

Four Faulted Steam generators ID Number: 2K7 NRC-02 Revision: 0 chq 1 INITIAL SETUP INSTRUCTIONS

1. START the Sun Workstation.

a. IF the Sun Workstation is running THEN go to SIM ACTIVE.

2. PLACE Recorder Power to ON.

3. VERIFY that the current approved training load is loaded.

4. REMOVE the step counter OVERRIDE and allow the counters to step out during the IC reset.

5. RESET to IC 90 (Based on IC 21)

6. ADJUST the various pot settings to the valued specified by the chart in the simulator booth or Notepad for the selected IC. Pay particular attention to the Pzr spray valves and their setpoints.

7. PLACE Simulator to RUN.

8. If Necessary, RESET the Plant Calorimetric at the Instructor Station PPC by Pressing SHIFT LEFT and F6 simultaneously.

9. ENSURE Simulator fidelity items cleared.

a. CHECK the STEP COUNTERS at correct position for plant conditions.

b. PLACE tiles under the DEMINS IN SERVICE lamacord label on MB6.

c. PLACE the Main Turbine on the LOAD LIMITER and ENSURE Standby Load Set MATCHED if conditions require.

d. PLACE the Westronic (5) and Gammametrics (2) recorders in active/run by depressing up or down arrow for each.

e. For the RIL recorder: select printer to ON when command? appears select Autojog.

f. CLEAR DCS alarms on MB7 and BOP console.

g. VERIFY annunciator, COMPUTER FAILURE (MB4C, 1-1 I ) , is NOT LIT.

10 As needed, RESET Computer Terminals to At Power displays if 100% power IC.

11 RESET Rad Monitor Screen to Status Grid.

12 IF placing equipment OOS, THEN perform the necessary switch manipulations and hang appropriate tags, as required, listed under I Equipme nt 0OS.

Page 8 of 68

SEL I ION 4 Lesson

Title:

Four Faulted Steam generators ID Number: 2K7 NRC-02 Revision: 0 chq 1 INITIAL SETUP INSTRUCTIONS

13. Ensure that the protected train and environmental placards are appropriately hung.

Equipment 00s: A EDG (Yellow Tag on Start Switch, Output Breaker and Prelube pump)

C TPCCW pump (Yellow Tag on control switch)

Insert applicable Crew Training Tape/CD into the DVDNCR.

Verify the MONITOR Time Display the same as the digital time display on MB4. If not page/call the Unit Tech Initial Malfunctions/lOs/lDAs:

PLACE GREEN PLACARDS FOR ALL INTAKE PARAMETERS ON MB6 PLACE THE B TRAIN PROTECTED PLACARD ON MB4 Go t o Manual Bypass on the Bypass Status Panel for the A EDG.

Ensure DGS-TI401 is o n scale.

Page 9 of 68

SEC I ION 4 Lesson

Title:

Four Faulted S t e a m generators ID Number: 2K7 NRC-02 Revision: 0 cha 1 INITIAL SETUP INSTRUCTIONS TYPE 1 Name Sev. I Ramp I RSCU Boul I Description MALF 1 RP1OA I Automatic Reactor Trip Failure (train A)

MALF RP1OB Automatic Reactor Trip Failure (train B)

MALF RP08A MSI fails t o auto actuate (train A)

MALF RP08B MSI fails to auto actuate (train B)

MALF RP11H RPCCW components fail to position on an SI MALF MS12A A MSlV sticks open MALF MS12B 6 MSlV sticks open MALF RXOSA 100 30 sec 1 RCS-PT455A fails high MALF RX13E 0 2 C Feed Flow Channel fails low MALF RC04A 3 Reactor Vessel Flange Leakoff MALF RC21 60% 3 Valve stem leakoff t o the CDTT MALF I RX04A I 100% I - I 4 I - I RCS N R C L TE411B FAIL Page 10 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam generators ID Number: 2K7 NRC-02 Revision: 0 chq 1 INITIAL SETUP INSTRUCTIONS Lead Examiner: Refer to the "Briefing Script for the Operational Exam" and brief the crew. Go over the PIa nusimulat or d iffe rences , w hic h f o I Iow.

Booth Instructor: Commence recording Simulator session Booth Instructor: Perform the crew turnover (Initial Conditions page at end of LP) with the US . Have the US brief his crew on plant conditions and any major equipment 0 0 s .

PLANT/SIMULATOR DIFFERENCES:

. Rad Monitor Historical Data--Simulator Rad Monitor historical data not valid prior to the beginning of this exercise.

. If not using the speed dial option on the phone system, the operator must dial either #3333 or #3334 to reach the person/department they desire.

. The following PPC programs do not function on the simulator:

0 Samarium Follow Xenon Follow Sequence of Events Flow indications 3SIH-F1917 (charging ECCS flow), 3SIH-F1918 (A SI pump flow) and 3SIH-F1922 (B SI pump flow) will show flow at low flow rates.

Page 11 of 68

SEC I-lON4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDAlMalf Instructor Information/Activity Assign Expected Action Standard Event 1: Failed Pzr Pressure Instrument P455A T+l min of RSCU=I This will fail Pzr Pressure Instrument Crew Diagnose instrument failure turnover 455 high Activate us Enter AOP 3571 AOP 3571 Entry Conditions AOP 3571 Actions (rev 009-01)

RO Do not leave the rod selector switch in AOP 3571 AUTO while diagnosing a related Step 1, instrument failure unless the reason for CAUTION rod movement is a turbine runback.

CREW If a reactor trip occurs, immediately go AOP 3571 to E-0, Reactor Trip or Safety Injection. Step 1, NOTE RO Determine the Initiating Parameter AOP 3571 and Place the affected controller in Step 1 MANUAL As a result of the failed instrument, CREW Stabilize the Plant Parameters AOP 3571 PZR spray valves will open and actual Step 2 PZR pressure will go down. The RO will take manual control of the Master PZR Pressure Controller and raise output to close the spray valves.

us It is desired that I&C personnel trip the AOP 3571 bistables specified in this procedure. If, Step 3, NOTE Page 12 of 68

SECTION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time I DA/Malf Instructor InformationlActivity Assign Expected Action Standard during off - hours, I&C personnel are not able to trip the necessary bistables within the time limitations required by the Technical Specifications, Operations Department personnel may trip the bistables using the guidance provided within this procedure.

us Perform Corrective Actions Using AOP 3571 Appropriate Attachment Step 3 Instrument Failure Attachment Pressurizer Pressure Channel Failure B RO Defeat the failed channel input. AOP 3571 Attachment B Step 1 Pressurizer Press Select - Control 3RCS-PS455F Pressurizer Press Select - Record 3RCS-PS455G OT/OP AT Record Select - RCS-TS411E RO Restore RCS pressure to normal, then AOP 3571 Place PZR pressure control in Attachment 6 automatic. Step 2 RO/ BOP When conditions have stabilized, AOP 3571 Observe MB annunciators and Attachment B Page 13 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard parameters. Immediately report any Step 3 unexpected or unexplained conditions to the Shift Manager.

US Trip the associated Reactor AOP 3571 Protection System bistable(s): Attachment B Step 4 US Place a check mark in the box above the AOP 3571 appropriate channel that requires Attachment B tripping on pages 3 or 4 of this Step 4.a Attachment.

Tech Specs - SM /US Refer to Technical Specification 3.3.1 ~ AOP 3571 3.3.2. and 3.3.3.5 Attachment B Log into 3.3.1 Action 6 (FU #7,9 &IO) Step 4. b and 3.3.2 Actions 20 and 21 (FU #I .d

& 9.a)

TRM - Refer to Technical Requirement 3.3.2.1 AOP 3571 Attachment B Log into TRM 3.3.2.1, Action 27..A. Step 4.c NOTE: If PZR pressure lowers to less RO Check the existing bistable status to AOP 3571 than 2218 psia, the US should enter ensure a reactor trip will not occur when Attachment B T/S 3.2.5 Action b. for DNB the failed channel is tripped. Step 4.d Parameters.

The following step will distinguish AOP 3571 whether the failure is within SSPS or the Attachment B Protection channel . Step 4.e NOTE NOTE: This is not the case. The -

If bistable status light(s) ( MB2D or AOP 3571 Page 14 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDAlMalf Inst ruc to r Info rmat ion/Act iv ity Assign Expected Action Standard channel has failed. The US should go MB4F) indicate that a single bistable Attachment B to step 4.f. input has tripped and channel indication Step 4.e is normal, PERFORM the following:

T=2 mins of RXRIOG OPEN Protection Set 1 Door SM /US Request the I&C Department trip the AOP 3571 request appropriate bistables using Attachment Attachment B B and Attachment S. Step 4.f RXR05 TRIP OTAT RO Verify the appropriate bistable status AOP 3571 lights are lit. Attachment 6 RXR34 TRIP C3 Step 4.g.

RXR44 TRIP Lo Pzr Press SI B/S If indicator 3RCS*PI 4556 is failed, AOP 3571 Refer to TRM Table 7.4.1, Fire Related Attachment B RXR40 TRIP Hi Pzr Press Rx Trip BIS Safe Shutdown Components, Reactor Step 5 CooIant System.

RXR48 TRIP Lo Pzr Press Rx Trip BIS SM /US Request I&C Department perform AOP 3571 corrective maintenance on failed Attachment B RXRI 20 TRIP P-I 1 instrument. Step 6 RPR4O PORV Logic B/S RXRI 06 CLOSE Protection Set 1 Door EVENT 2: Controlling channel of C Steam Generator feed flow fails low (3MSS-FT530)

T= Crew has RSCU 2 Activate RSCU 2. This will fail 3MSS-tripped FT530 low.

(RXI3E, 0%)

bistables and addressed Page 15 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard TSs.

AOP 3571 Att L (Rev 009-01) Crew Do not leave the rod selector switch in AOP 3571 Actions AUTO while diagnosing a related Step 1 instrument failure unless the reason for CAUTION rod movement is a turbine runback.

Crew If a reactor trip occurs, immediately go to AOP 3571 E-0, Reactor Trip or Safety Injection. Step 1 NOTE When the feed flow channel fails low, BOP Determine the initiating parameter AOP 3571 first alarm will be SG (C) FLOW and place the affected controller in step 1 MISMATCH STM > FW, due to the MANUAL.

C Feed Regulating Valve going closed. The BOP will take manual control of C FRV Controller and open the FRV.

BOP Stabilize the plant parameters. AOP 3571 step 2 us Perform Corrective Actions Using AOP 3571 Appropriate Attachment Step 3 Instrument Failure Attachment Feed Flow Channel Failure L Crew The following annunciators are symptoms of a failed feed flow instrument:

SG A (B) (C) (D) LEVEL DEVIATION MB5B 4-1,357 SG A (B) (C) (D) FLOW MISMATCH FW MB5B 5-

> STM 1,3,5,7 Page 16 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMaIf I nst ructo r I nformat io nlAct ivity Assign Expect d Action Standard SG A (B) (C) (D) FLOW MISMATCH MB5B 5-STM > FW 2,4,6,8 If the failed feed flow channel is AOP 3571 selected as the input to SG level Attachment L control, Perform the following: Step 1 BOP Verify the affected SG feed regulating AOP 3571 valve controller is in MANUAL. Attachment L Step 1.a BOP Restore SG level to normal AOP 3571 Attachment L Step 1.b BOP Defeat the failed channel input by AOP 3571 selecting the alternate channel on the Attachment L feed flow selector. Step 1.c BOP When SG level is restored to normal and AOP 3571 feedkteam flow are matched, Place the Attachment L affected steam generator feed regulating Step 1.d valve controller in AUTO.

There are no Technical Specifications or us bistables to be tripped associated with AOP 3571 the feed flow instruments. Attachment L Step 2 NOTE When the plant calorimetric is based on AOP 3571 feed flow, the program will automatically Attachment L shift to an NI based output if any feed Step 2 NOTE flow channel is X-tagged by the process computer.

RO /BOP When conditions have stabilized, AOP 3571 Attachment L Page 17 of 68

SEC rlON 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor Information/Ac ivity Assign Expectec Action S .andarc -

Observe MB annunciators and Step 2 parameters. Immediately report any unexpected or unexplained conditions to the Shift Manager.

US / SM Request I&C Department perform AOP 3571 corrective maintenance on failed Attachment L instrument. Step 3 EVENT 3: RCS leak. Reactor Flange Leakoff leakoff into the CDTT.

T = AOP RSCU 3 Flange leakoff to the CDTT 3571 exited increases to 20 gpm.

(RC04A and RC21, 60%)

Symptoms: VCT level will lower, CDTT level will increase. VCT pressure will lower slowly bringing in the VCT pressure low alarm.

Charging flowrate will be slowly increasing and PZR level will be slowly lowering.

The crew will utilize the Annunciator Response Procedure, OP3353.MB4A-5-5, RX VESSEL FLG LEAKOFF TEMP HI MB4A-5-5 (rev 002-12), RX VESSEL FLG LEAKOFF TEMP HI CORRECTIVE ACTIONS Page 18 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDA/Ma If Instructor InformationlActivitv Assign Expected Action Standard 3DGS-TI 401 will show temperature in RO CONFIRM leakoff high temperature on MB4A 5-5 excess of 140 degrees. 3DGS-TI 401, RX FLANGE LEAK OFF TEMP (MB4). Step 1 CDTT level will be trending higher. RoBoP MONITOR 3DGS-LI 33, GASEOUS MB4A 5-5 DRAINS CTMT DRAIN TK LVL, to determine leak rate (MBI). Step 2 Leak Rate is around 20 gpm. us IF RCS IDENTIFIED LEAKAGE is MB4A 5-5 greater than 10 gpm, PERFORM the following: Step 3 T = when BOOTH Inform the US that you will make us NOTIFY the OMOC (Duty Officer). MB4A 5-5 called notifications. You will put together a team to make a CTMT entry to Step 3.1 align the outer O-ring. Expect CTMT entry in 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />.

TS 3.4.6.2 action b applies for us Refer To Technical Specification 3.4.6.2 MB4A 5-5 identified leakage in excess of 10 gpm. and DETERMINE Limiting Condition for 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> action statement. Operation. Step 3.2 NOTE: Based on the estimated leak us Closing 3RCS*AV8032, Rx flange MB4A 5-5 rate, the US may refer to the EAL leakoff isolation, renders the Reactor Tables and classify the event as an Head Flange Leakoff System in capable Step 4 NOTE Unusual Event. (BU2, Identified of monitoring leakage per Surveillance Leakage > 25 gpm) Requirement 4.4.6.2.1.e.

Leakoff System is aligned to detect IF Reactor Flange Leakoff System is MB4A 5-5 inner O-ring leakage. aligned to detect inner O-ring leakage, ALIGN Leakoff System as follows: Step 4 T= REMOVE This will isolate the leakage. RO CLOSE 3RCS*AV8032, RX FLANGE MB4A 5-5 LEAK OFF ISOL (MB4).

3RCS*AV8032 MALF Page 19 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf I nst ru cto r I nfo rmat ionlAct ivity Assign Expected Action Standard goes closed. RC21 and RCO4A Step 4.1 Steps 4.2 and 4.3 must be carried out CLOSE 3RCS*V104, reactor vessel MB4A 5-5 inside CTMT. flange inner O-ring leakoff.

Step 4.2 OPEN 3RCS*V103, reactor vessel MB4A 5-5 flange outer O-ring leakoff.

Step 4.3 OPEN 3RCS*AV8032, "RX FLANGE MB4A 5-5 LEAK OFF ISOL" (MB4).

Step 4.4 VERIFY decreasing temperature on MB4A 5-5 3DGS-TI 401, "RX FLANGE" "LEAK OFF TEMP" (MB4). Step 4.5 Once the leak rate is determined and the Tech Spec entered, move on to the next event.

EVENT 4: Loop 2 Tavg fails high T = Leak RSCU 4 Loop 1 narrow range Tc, isolated 3RCS*TE411 B (RX04A)

Page 20 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDAlMalf Inst ruc t or Inf o r m at ion/Act iv ity Assign Expected Action Standard Tave will fail high. Rods will drive in.

Delta T for "A" Loop will go low.

AOP 3571 (Rev. 009-01) Actions us Transition to AOP 3571, Instrument Failure Response The RO will place Rod Control in CREW Determine the initiating parameter and AOP 3571 manual; PZR level control is already place the effective controller in manual. Step 1 at 100% program. Steam Dumps not armed so no immediate impact CREW Stabilize the plant parameters. AOP 3571 Step 2 us Perform Corrective Actions Using AOP 3571 Appropriate Attachment Step 3 Instrument Failure Attachment RCS NR Temperature Channel Failure A RO Defeat the failed channel input. AOP 3571 Att.A Step 1 Loop Temp Cutout - delta T Loop Temp Cutout - Tavg OTlOP delta T Record Select Check the following annunciators NOT AOP 3571 LIT: Att.A Step 2 TREF/AUCT TAVE DEVIATION MB4C 6-5 TAVE HI MB4C 5-6 Page 21 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard No action may be required depending RO Restore TAVE - TREF error to within 1 AOP 3571 on when crew placed rods in manual. Att.A Step 3 O F and return rod control to automatic.

RO Monitor PZR level until stable. If PZR AOP 3571 level controller is in manual, Restore Att.A Step 4 pressurizer level to program level and Place PZR level controller in automatic.

NA If RCS loop 3 cold leg narrow range AOP 3571 temperature channel computer point Att.A Step 5 (RCS-T431 E) is X-tagged, the plant Note calorimetric program will automatically shift to an NI based output.

CREW When conditions have stabilized, AOP 3571 Observe MB annunciators and Att.A Step 5 parameters. Immediately report any unexpected or unexplained conditions to the Shift Manager.

us Trip the associated Reactor Protection AOP 3571 System bistable(s): Att.A Step 6 us Place a check mark in the box above the AOP 3571 appropriate channel that requires tripping Att.A Step 6a on page 4 of the Attachment.

Table 3.3.1 - FU 7, 8 Action 6 applies us/ Refer to Technical Specification 3 3.1 AOP 3571 Table 3.3.2 - FU 5D Action 20 applies and 3.3.2 AttA SM Step 6b These are 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> requirements to trip bistabies.

Page 22 of 68

SEC.IION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Inst ru ctor Informat ion/Act iv ity Assign Expected Action Standard Once the crew has determined T.S. requirements go to Event 5. BIS will not be tripped due to time RO Check the existing bistable status to AOP 3571 ensure a reactor trip will not occur Att.A considerations and that evolution was exercised when the failed channel is tripped. Step 6c during the PZR Pressure channel failure.

EVENT 5: CONVEX directed Emergency Load Reduction. AOP 3575,Rapid Downpower.

Emergency Boration valve fails to open.

T = I&C BOOTH Call as CONVEX and request called Millstone Unit 3 to perform an Emergency Load Reduction of 300 MwE in the next 15 minutes due to Grid Instabilities. Maintain current VAR loading, us The US will enter AOP 3575, Rapid Downpower AOP 3575 Actions (Rev. 01 3) A CONVEX requested emergency AOP 3575 generation reduction as directed by C Step 1 NOTE OP 200.8, Response to I S 0 New England / Convex Emergencies and Alerts, Should be completed within 15 minutes of notification.

0 If a unit shutdown is required, the target power level should be between 20% and 25% reactor power.

0 If at any time ROD CONTROL BANKS LIMIT LO - LO (MB4C 4 - 9 )

Page 23 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDA/Malf I nst r ucto r I n format ion/Act ivity Assign Expected Action Standard annunciator is received, DO NOT go to AOP 3566, Immediate Boration.

Immediately perform step 9.

CREW Determine Power Reduction Rate AOP 3575

(%/m in). Step 1 us Check desired power reduction rate - AOP 3575 EQUAL TO OR LESS THAN 5%/min. Step 1.a us Check power reduction CONVEX AOP 3575 REQUESTED Step 1.b CREW Perform load reduction at 5%/min and AOP 3575 Proceed to step 2 Step 1.c us Check Rod Control In AUTO. AOP 3575 Step 2 CREW Align EHC Panel AOP 3575 Step 3 us Check turbine OPERATING MODE - AOP 3575 MANUAL Step 3.a us Check LOAD LIMIT LIMITING light - LIT AOP 3575 Step 3.b BOP Intermittently Press DECREASE LOAD AOP 3575 pushbutton until LOAD LIMIT LIMITING Step 3.c light - NOT LIT BOP Rotate LOAD LIMIT SET adjust knob at AOP 3575 least one full turn in raise direction Step 3.d Select DECREASE LOADING RATE to AOP 3575 ON Step 3.e Page 24 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard BOP Select LOAD RATE LIMIT % MIN to AOP 3575 power reduction rate (% min) determined Step 3.f in step 1.

If at any time the power reduction rate or AOP 3575 final desired power level must be Step 4 NOTE changed, Return to step 1.

US/RO Verify Power Reduction Rate AOP 3575 Step 4 RO Check power reduction rate 5% MIN AOP 3575 Step 4.a Check power reduction - REQUIRED TO AOP 3575 STABILIZE PLANT Step 4. b Proceed to Step 5 AOP 3575 Step 4.b RNO If SI actuation occurs during this AOP 3575 procedure, Go to E-0, Reactor Trip or Step 5 safety Injection, and restore from rapid CAUTION boration lineup.

Initiate Rapid Boration AOP 3575 Step 5 Verify RCS makeup system in - AUTO AOP 3575 Step 5.a START one boric acid transfer pump AOP 3575 Step 5.b T = initial 110 EVENT 5: Emergency Boration Valve OPEN emergency boration valve AOP 3575 MALF Fails to Open (3CHS*MV8104). Step 5.c Page 25 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Inst ructo r I nformat io n/Act ivity Assign Expected Action Standard 3CHS*

MV8104, OPEN -

FALSE RO Verify direct boric acid flow (3CHS-FI AOP 3575 183A) - INDICATED. Step 5.d Perform the following to initiate gravity AOP 3575 boration: Step 5.d RNO

1. Place the charging line flow control valve in MAN.

2. OPEN at least one gravity feed boration valve.

3. CLOSE at least one VCT outlet isolation valve.

4. Limit net charging flow to the RCS to LESS THAN 75 gpm (charging + seal injection - RCP seal return).

5. Adjust charging line flow control valve as required.

6. Proceed to step 5.f.

Record time boration started AOP 3575 Step 5.f Time Energize all PZR heaters AOP 3575 Step 5.g Page 26 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Adjust Pzr Spray Valves to RO 50% setpoint AOP 3575 RCS-PK455B Step 5.h RCS-PK455C Check Rod Control -AVAILABLE FOR AOP 3575 ROD INSERTED Step 5.i Using formula, Determine required AOP 3575 boration time (If gravity borating, use net Step 5.j charging flow for BA flow rate):

I Boration - Total Power Change (A%) x 15 -

- min Time BA Flow Rate Boration Time = (25% x 15) / 75 gpm = 5.0 min us During power decrease, Modify boration AOP 3575 time as necessary to maintain: Step 5.k Rods above the Rod Insertion Limit Tavg within +O F of Tref AFD within COLR limits Check turbine load decrease - IN AOP 3575 PROGRESS OR COMPLETED. Step 5.1 us Proceed to NOTE prior to Step 7. AOP 3575 Step 5.1 RNO RO If a unit shutdown is being performed, AOP 3575 the final Mwe load should be Step 7 NOTE approximately 230 Mwe.

Page 27 of 68

SEC'I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard US/BOP Initiate Load Reduction. AOP 3575 Step 7 BOP Check turbine OPERATING MODE - AOP 3575 MANUAL Step 7.a BOP Check either of the following: AOP 3575 Step 7.b 0 Rapid or gravity boration - IN PROGRESS OR 0 Turbine load reduction -

REQUIRED TO STABILIZE PLANT BOP Check LOAD RATE LIMIT YOMIN set at - AOP 3575 3% OR 5% Step 7.c The BOP should adjust Load Set to 900 BOP Utilizing DECREASE LOAD pushbutton, AOP 3575 MWe. Adjust LOAD SET to desired final Mwe Step 7.d BOP Check power reduction - CONVEX AOP 3575 REQUESTED. Step 7.e BOP Maintain initial MVAR loading during AOP 3575 power reduction, unless directed Step 7.f otherwise.

US/RO Check boration - IN PROGRESS AOP 3575 Step 7.g Verify Final Desired Turbine Load AOP 3575 (Mwe) - LESS THAN 75% Step 8 Page 28 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Proceed to Step I O . AOP 3575 Step 8 RNO BOP The following step places one TD FW AOP 3575 pump in manual while allowing the other Step10 NOTE TD FW pump to automatically unload during the downpower.

US/BOP Align One Feedwater Pump For AOP 3575 Automatic Unloading Step 10 The US should recognize that 75% BOP Verify removing a feedwater pump from AOP 3575 power, two feedwater pumps will be service during the downpower - Step 10.a required. DESIRED Proceed to step 11. AOP 3575 Step 10.a RNO US/RO Verify Rod Position AOP 3575 Step 11 RO Check ROD CONTROL BANKS LIMIT AOP 3575 LO - LO (MB4C 4 - 9) annunciator - LIT. Step 11.a USlRO Proceed to step 11.e and, at any time, AOP 3575 the annunciator is received, THEN Step 1 l . a RNO Perform steps 11.b, 11.c and 11.d RO Check ROD CONTROL BANKS LIMIT AOP 3575 LO (MB4C 3 - 9) annunciator - LIT Step 11.e us Proceed to NOTE prior to step 12 and, AOP 3575 Step 11.e IF the annunciator is received, THEN RNO Page 29 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Perform step 11.f and 11.g us Restore From Rapid Boration. AOP 3575 Step 12 RO Check rapid OR gravity boration - IN AOP 3575 PROGRESS- Step 12.a USlRO Check boration performed for the AOP 3575 required time determined in Step 5.i and Step 12.b 5.j.

RO Check rapid boration - IN PROGRESS AOP 3575 Step 12.c Perform the following: AOP 3575 Step 12.c RNO

1. OPEN both VCT outlet isolation valves.

2. CLOSE both gravity feed boration valves.

3. Proceed to step 12.f.

RO Restore PZR level to program value and AOP 3575 Place charging line flow control valve in Step 12.f AUTO.

us Using normal makeup, Adjust RCS AOP 3575 boron concentration as necessary to Step 12.g maintain:

0 Rods above the Rod Insertion Limit Page 30 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Tavg within 2 5°F of Tref AFD within COLR limits us Reduce Steam Supply To The MSRs. AOP 3575 Step 13 BOP Check reheat steam flow controllers - IN AOP 3575 AUTOMATIC. Step 13.a BOP Using the MSR Startup Pressure Display AOP 3575 on the Foxboro DCS, Verify symmetrical Step 13.b operation of the MSR reheaters during power decrease.

BOP Using OP 3317, Reheat and Moisture AOP 3575 Separator, Perform manual adjustment Step 13.b of moisture separator reheater steam RNO flow control valves, as necessary.

us Check If RCS Sample Is Required. AOP 3575 Step 14 us Verify change in Reactor Power - AOP 3575 GREATER THAN 15% IN ONE HOUR Step 14.a us Request Chemistry sample the RCS for AOP 3575 iodine (between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after the Step 14.b power change.)

us Request Chemistry Pepartrnent perform AOP 3575 gaseous effluent samples and analysis Step 14.c (between 24 and 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after the power change) for the following process monitors:

Page 31 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf I nst ruc t o r I nformat ion/Act iv ity Assign Expected Action Standard 3HVR-REIOB 3HVR-RE19B us Verify Target Power Level - LESS AOP 3575 THAN 50%. Step 15 us Continue power reduction to the final AOP 3575 desired target power level. Step 15 RNO WHEN Final power level is reached, THEN Proceed to Step 22.

EVENT 6: Main Generator trip and automatic reactor trip failure T = AOP RSCU 5 Degraded Grid Voltage 3571 and (EDIO) Grid voltage will increase to 372 KV rapid over 60 seconds. Freq will increase to downpower (EDROI) 60.1 hz, complete T = 1 min after ED10 Modify to 58%, ramp 60 seconds.

RSCU 5 EDROI Modify to 0.0, THEN REMOVE ED10 T = When RSCU 6 Generator Trip resulting i n reactor Page 32 of 68

SEC IUON 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard the crew trip and four faulted SGs.

identif ies Generator trip results in turbine trip.

degraded The reactor will fail to automatically trip.

grid voltage Secondary pressure rise will result in SG safety valves opening and A SG faulting. The A and B MSlVs will not close, and the C and ID SGs will have a safety valve stick open.

BOP The BOP should identify the Main Generator and Turbine trip RO The RO should identify the first out and OP 3272 automatic reactor trip failure and initiate a manual reactor trip from main board 4.

us The US should enter E-0 and direct the E-0 Entry crew to carry out the immediate actions Conditions of E-0.

EVENT 7: Four faulted SGs. MSI fails to automatically actuate. Several RPCCW components fail to respond to an SI signal.

NOTE: US should go to Master Silence before ordering reactor trip.

E-0 (Rev. 022-00) STEPS Crew Foldout page must be open E-0, Step 1, NOTE Page 33 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf I nstructor I nf ormationlActivity Assign Expected Action Standard ADVERSE CTMT defined as GREATER THAN 180°F or GREATER THAN Io5R/h, in containment.

The reactor can be interpreted as "tripped" when any two of three bulleted substeps of Step 1.* are satisfied.

RO Verify Reactor Trip E-0, Step 1 Check reactor trip and bypass breakers - OPEN Check rod bottom lights - LIT Check neutron flux -

DECREASING Critical Task - The RO needs to RO TRIP the reactor E-0, Step 1, initiate a manual reactor trip from RNO [*I main board 4. [*I IF reactor will

- NOT trip, THEN Verify Turbine Trip E-0, Step 2 Check all turbine stop valves - CLOSED E-0, Step 2.a BOP Verify Power to AC Emergency E-0, Step 3 Busses BOP Check busses 34C and 34D - E-0, Step 3.a Page 34 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard BOTH ENERGIZED Try to energize the affected buss(es) E-0, Step 3.a, from its associated EDG. RNO us Check If SI Is Actuated E-0, Step 4 RO Verify SAFETY INJECTION E-0, Step 4.a ACTUATION annunciator - (MB4D 1-6 or MB2B 5-9) - LIT By observation of ESF Group 2 Status E-0, Step 4.b Panel lights, Verify both trains of SI -

ACTUATED By observation of ESF Group 2 Status E-0, Step 4.b Panel lights, Verify both trains of SI -

ACTUATED Check Reactor trip and bypass breakers E-0, Step 4.c

- OPEN Locally TRIP the reactor trip and bypass E-0, Step 4.c breakers. RNO RO Verify Service Water Pumps - AT E-0, Step 5 LEAST ONE PER TRAIN RUNNING RO Verify Two RPCCW Pumps - ONE PER E-0, Step 6 TRAIN RUNNING RO Verify ECCS Pumps Running E-0, Step 7

- Check SI pumps - RUNNING

- Check RHR pumps - RUNNING Page 35 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard

- Check two charging pumps -

RUNNING BOP Verify AFW Pumps Running E-0, Step 8 Check MD pumps - RUNNING E-0, Step 8.a Check turbine - driven pump - E-0, Step 8.b RUNNING, IF NECESSARY BOP Verify FW Isolation E-0, Step 9 Check SG feed regulating valves

- CLOSED Check SG feed regulating bypass valves - CLOSED Check FW isolation trip valves -

CLOSED Check TD FW pump - TRIPPED Check MD FW pumps -

STOPPED Check SG blowdown isolation valves - CLOSED Check SG blowdown sample isolation valves - CLOSED Check SG chemical feed isolation valves - CLOSED BOOTH Note: if the crew chooses to pull MSlV BOP Check If Main Steam Lines Should Be E-0, Step 10 Page 36 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDAlMalf I nst ructor I nf ormat ion/Act ivity Assign Expected Action Standard fuses early, the 10s are located on the Isolated page containing step 1 of E-2 in the exam plan.

Check Ctmt pressure GREATER THAN E-0, 18 psia Step 10.a Yes Any SG pressure LESS THAN 660 psig Verify MSlVs and MSIV bypass valves - E-0, CLOSED Step 1 0 . b Critical Task - The BOP needs to BOP Initiate MSI. E-0, initiate a manual MSI from main Step 10.b, board 5. The BOP should go to RNO [*I close on the A and B MSIV. ["I BOP IF MSI will NOT actuate, THEN CLOSE the MSlVs and MSlV bypass valves.

All ESF Group 3 lights will be lit except Check ESF Group 3 lights - LIT. E-0, for the A and B MSIV. Step 1O.c RO Check if CDA Required E-0, Step 11 Check Ctmt pressure is GREATER E-G, THAN 23 psia Step 11.a OR Ctmt spray - INITIATED Page 37 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard us Proceed to Step 12. E-0, Step1 1.a, RNO BOP Verify CAR Fans Operating In E-0, Step 12 Emergency Mode BOP Check CAR fan status: E-0, Step 12.a 0 CAR fans A and B - RUNNING 0 CAR fan C - STOPPED BOP STARTKTOP CAR fans as necessary. E-0, Step 12.a, RNO RO Verify RPCCW Ctmt supply and return E-0, header isolations - OPEN Step 12.b RO Verify Train A and B RPCCW supply and E-0, return to chill water valves - OPEN Step 12.c RO Verify CIA E-0, Step 13 RO Check ESF Group 2 status columns 2 E-0, through 10 - LIT Step 13.a RO Verify Proper ESF Status Panel E-0, Step 14 Indication Verify ESF Group 1 lights - OFF Several RPCCW components will 0 Verify ESF Group 2 lights - LIT need to be manually positioned as Page 38 of 68

SEC; I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDAlMalf Inst ructo r Info rmat ion/Act ivity Assign Expected Action Standard they failed to respond to the SI signal.

CTMT will not be ADVERSE RO Determine If ADVERSE CTMT E-0, Step 15 Conditions Exist

. Ctmt temperature GREATER THAN 180°F OR Ctmt radiation GREATER THAN Io5 R/h, CREW DO NOT use ADVERSE CTMT E-0, Step 15, para meters. RNO RO Verify ECCS Flow E-0, Step 16 Check charging pumps - E-0, Step 16.a FLOW INDICATED RO Check RCS pressure - GREATER THAN E-0, 1650 psia (1 950 psia ADVERSE CTMT) Step 16.b us Proceed to Step 16.e E-0, Step 16.b, RNO RCS has partially depressurized due to Check SI pumps - FLOW INDICATED E-0, the faulted SGs. If pressure is greater Step 16.e than 1650 psia, the SI pump flow check is not necessary. The crew will check PORV block valves and proceed to step 17.

Page 39 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time I DAlMa If I nst ruc tor I nf orm at ionlActivity Assign Expected Action Standard Check RCS pressure - LESS THAN 300 E-0, Step 16.f psia (500 psia ADVERSE CTMT)

CREW should perform a short brief Proceed to step 17 E-0, Step 16.f and come out of "Master Silence" at RNO the completion of Step 16.

BOP Verify Adequate Heat Sink E-0, Step 17 Check NR level in at least one SG - E-0, GREATER THAN 8% (42% ADVERSE Step 17.a CTMT) us Proceed to Step 17.d E-0, Step 17.a, RNO With 4 faulted SGs, crew should not BOP Verify Total AFW Flow - GREATER E-0, isolate flow to all SGs, and also should THAN 530 gpm Step 17.d wait for procedural guidance before throttling less than 530 gpm total AFW flow.

BOP Verify AFW Valve Alignment - E-0, Step 18 PROPER EMERGENCY ALIGNMENT RO Verify ECCS Valve Alignment - E-0, Step 19 PROPER EMERGENCY ALIGNMENT us Check Plant Status E-0, Step 20 T = When BOOTH When asked, REPORT, "all SLCRS SM/US Verify SLCRS doors - CLOSED E-0, Requested doors indicate closed, except for Step 20.a several Main Steam Valve Building doors, which indicate open."

Page 40 of 68

SEC; I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDAlMalf Instructor Information/Activity Assign Expected Action Standard RO Check CONTROL BUILDING E-0, ISOLATION annunciator (MB4D 3-6) - Step 20.b LIT RO Verify ESF Group 2 CBI lights - LIT E-0, Step 20.c BOP Verify control building purge supply fan E-0, and purge exhaust fan - NOT RUNNING Step 20.d BOP Verify control building air bank isolation E-0, valves - OPEN (after 60 seconds) Step 20.e BOP STOP kitchen exhaust fan E-0, Step 20.f T = 10 min BOOTH REPORT All Control Building PEO CLOSE and DOG the following Control E-0, from request pressure boundary doors are Closed Building pressure boundary doors. Step 20.g and Dogged as applicable.

. CB west 476 (C-47-1A)

CB east 64 6 (C-64-1B)

Verify the following Control Building E-0, pressure boundary doors - CLOSED Step 20.h

. CB west 476 (C-47-1)

2. CB north 646 chiller room door (C-64-4)

3. CB north 646 chiiier room door (C-64-5)

4. CB west 496 (C-49-1)

RO Check RCS Temperature E-0, Step 21 Page 41 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Acti n Standa d __

NO, RCS temperature is cold due to Verify RCS cold leg WR temperature - E-0, faulted SGs. BETWEEN 550°F AND 560°F. Step 21 .a us Perform the applicable action: E-0, Step 21 .a, RNO IF temperature

- is GREATER THAN 560"F, THEN Proceed to step 21 .c.

IF temperature is LESS THAN 550°F THEN Proceed to step 21 .e.

BOP Maintain total feed flow BETWEEN 530 E-0, and 600 gpm until NR level is GREATER Step 21 .e THAN 8% (42% ADVERSE CTMT) in at least one SG BOP CLOSE SG atmospheric dump and E-0, Step 21 .f dump bypass valves BOP Check the following valves - CLOSED E-0, Step 21 .g MSlVs w MSlV bypass valves us Perform the following: E-0, Step 21 .g, Page 42 of 68

SECTION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard RNO BOP 1. Place both condenser steam dump interlock selector switches to OFF.

BOP 2. unexpected cooldown continues, THEN CLOSE the MSlVs and MSlV bypass valves.

us Proceed to Step 22 E-0, Step 21 .b RO Check PZR Valves E-0, Step 22 Verify PORVs - CLOSED E-0, Step 22.a RO Verify normal PZR spray valves - E-0, CLOSED Step 22.b RO Verify PZR safety valves - CLOSED E-0, Step 22.c CREW To prevent damage to the RCP seal(s), E-0, Step 23, seal injection flow should be maintained CAUTIO N to all RCPs.

RO Check If RCPs Should Be Stopped E-0, Step 23 Verify RCPs - ANY RUNNING E-0, Step 23.a RO Verify RCS pressure - LESS THAN 1500 EOP 35 E-0, psia (1800 psia ADVERSE CTMT) Step 23.b Page 43 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor InformationlActivity Assign ExDected Action Standard RO Verify charging or SI pumps - AT E-0, LEAST ONE RUNNING Step 23.c Critical Task - RO STOP all RCPs E-0, Step 23.d RCS pressure will eventually lower to 1500 psia. Crew should identify this and trip all RCPs.

BOPlRO Check If SG Secondary Boundaries E-0, Step 24 Are Intact Check pressure in all SGs E-0, Step 24.a All 4 SGs are faulted. The crew should NO SG PRESSURE transition to E-2. DECREASING IN AN UNCONTROLLED MANNER 0 NO SG COMPLETELY DEPRESSURIZED us Initiate monitoring of CSF Status Trees E-0, and Go to E-2, Faulted Steam Generator Step 24.a Isolation. RNO E-2 FAULTED STEAM GENERATOR ISOLATION Rev 010-00 0 At least one SG must be E-2 maintained available for RCS CAUTION cooldown.

0 Any faulted SG or secondary break should remain isolated during Page 44 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf I nstructo r I nf ormat ion/Act ivity Assign Expected Action Standard subsequent recovery actions unless needed for RCS cooldown or sampling is required.

NOTE: For E-2, step 1 RNO, the PEO If RWST level decreases to LESS should not be indiscriminately THAN 520,000 gal, Go to ES-1.3, dispatched to do all of Attachment A. Transfer to Cold Leg Recirculation, Some valves are in MSVB and some to align the ECCS system.

will isolate flow to the TDAFW Pump.

A and B MSlVs are open and will BOP Check Main Steam Isolation And E-2, Step 1 not close. Bypass Valves - CLOSED us T = 2 min BOOTH 10s to simulate PEO removing fuses BOP CLOSE valves. E-2, Step 1 from being as needed to de energize A and B RNO MSIVs, which will remain open. If the IF flow path(s) can NOT be isolated, dispatched.

crew elects to pull just one set then THEN enter the Train A 10s only.

Using Attachment A for guidance, 3MSS*CTV27A_TRA Green Off Locally Close valve(s).

3MSS*CTV27A_TRA Red Off 3 MSS*CTV27A_TRB Green Off 3MSS*CTV27A_TRB Red Off 3MSS*CTV27B_TRA Green Off us Check At Least One SG Secondary E-2, step 2 3MSS*CTV27B_TRA Red Off Boundary Is Intact 3MSS*CTV27B_TRB Green Off 3MSS*CTV27BWTRB Red Off RO/ Check pressures in all SGs - AT LEAST E-2, step 2.a BOP ONE STABLE OR INCREASING us -

IF all SG pressures decreasing in an E-2, Step 2.a All 4 SGs are depressurizing. Crew uncontrolled manner, RNO Page 45 of 68

SEC; I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDAlMalf I nst ructor Informat io n/Act iv ity Assign Expected Action Standard should transition to ECA-2.1 THEN Go to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

ECA-2.1, Uncontrolled Depressurization of All Steam Generators (Rev 014-03).

. If any SG pressure increases at any time, except while ECA 2.1 Step 1 CAUTION performing SI termination in Steps 12 through 27, Go to E-2, Faulted Steam Generator Isolation.

If, during the performance of the procedure, the capability to feed SGs at GREATER THAN 530 gpm is NOT available, Go to FR-H.l, Response to Loss of Secondary Heat Sink.

. If the TD AFW pump is required to maintain feed flow to any SG, a steam supply to the TD AFW pump must be maintained from at least one SG.

Crew Foldout page must be open. ECA 2.1 Step 1 NOTE Check Secondary Pressure Boundary ECA 2.1 Step 1

Page 46 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDAlMalf In st ructor I nf o rmat ion/Act iv ity Assign Expected Action Standard BOP Verify MSlVs and MSlV bypass valves - ECA 2.1 Step CLOSED 1.a Local actions of this step were initiated Initiate MSI. ECA 2.1 Step in E-2 1.a RNO IF MSI will NOT actuate, THEN CLOSE the MSlVs and MSlV bypass valves IF MSlVs MSlV bypass valves will NOT close, THEN Using Attachment B, Pull the affected valve(s) fuse block.

BOP Check SG isolation ECA 2.1 Step 1.b

' Verify SG feed regulating valves - CLOSED

' Verify SG feed regulating bypass valves - CLOSED

' Verify FW isolation trip valves -

CLOSED

' Verify the SG atmospheric relief and bypass valves - CLOSED

' Verify SG blowdown isolation valves - CLOSED Page 47 of 68

SEC IION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Verify SG blowdown sample isolation valves - CLOSED Verify SG chemical feed isolation valves - CLOSED 0 Using table, Verify main steam line drains upstream of MSlVs and TD AFW pump - CLOSED SG A SG B SGC SGD 3DTM*AOV29A 1 3DTM*AOV29B 1 I

3DTM*AOV29C 1I 3DTM*AOV29D 3DTM*AOV61A II 3DTM"AOVGI B 1I 3DTM*AOV61C I I

3DTM*AOV61D 3 DTM*AOV63A I 3DTM*AOV63B I 3DTM*AOV63D I 3DTM*AOV64A I 3DTM*AOV64B I I 3DTM*AOV64D I BOP Check MD AFW pumps - TWO ECA 2.1 Step RUNNING 1.c The US should direct the steam supply US/BOP Verify steam SUPPlY valves to TD AFW ECA 2.1 Step valves to TD AFW pump be closed pump - CLOSED 1.d since the MD AFW pumps are running. 0 3MSS*MOV17A 0 3MSS*MOV17B 3MSS*MOV17D BOP CLOSE valves ECA 2.1 Step 1.d RNO IF valve(s) will NOT close, THEN Page 48 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Locally Close valve(s).

To prevent inadvertent reactor criticality, ECA 2.1 Step the required shutdown margin must be 2 NOTE maintained during RCS cooldown.

Verify Shutdown Margin ECA 2.1 Step 2

us Request Chemistry sample the RCS for ECA 2.1 Step boron concentration 2.a Check RCS sample results - ECA2.1 Step AVAILABLE 2.b us Proceed to CAUTION prior to step 3 ECA 2.1 Step and, 2.b RNO WHEN Sample results become available, THEN Perform step 2.c Using OP 3209B, Shutdown Margin, ECA 2.1 Step Check shutdown margin. 2.c us A minimum feed flow of 100 gpm must ECA 2.1 Step be maintained to each SG with a NR 3 CAUTION level LESS THAN 8% (42% ADVERSE CTMT).

Control Feed Flow To Minimize RCS ECA 2.1 Step Cooldown. 3 Page 49 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time I DAIMa If Instructor InformationIActivity Assign Expected Action Standard No, cooldown rate will be greater than RO Check cooldown rate in RCS cold legs - ECA 2.1 Step 8O0F/hr. LESS THAN 8O0F/hr. 3.a Critical Task - Control the AFW BOP Decrease AFW flow to 100 gpm to each ECA 2.1 Step flowrate to at least 100 gpm per SG in order to minimize the RCS cooldown rate.

SG and Proceed to Step 3c. 3.a RNO ["I

["I Check NR level in all SGs - LESS THAN ECA 2.1 Step 50%. 3.b Control feed flow to maintain NR level ECA 2.1 Step LESS THAN 50% in all SGs. 3.b RNO NOTE: this is a continuous action step RO/BOP Check RCS hot leg WR temperatures - ECA 2.1 Step to prevent the RCS from heating back STABLE OR DECREASING. 3.c up after the initial cooldown from the faulted SGs. This assists in maintaining the plant stable.

Control feed flow or Dump steam to ECA 2.1 Step stabilize RCS hot leg WR temperatures. 3.c RNO Seal injection flow should be ECA 2.1 Step maintained to all RCPs. 4 NOTE Step 4 for stopping RCPs is applicable until SI is terminated in step 20.

Check If RCPs Should Be Stopped. ECA 2.1 Step 4

RO Check RCPs -ANY RUNNING ECA 2.1 Step 4.a Page 50 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDAlMalf Inst ructo r I nf o rmat io nlAct ivity Assign Expected Action Standard us Proceed to CAUTION prior to step 5. ECA 2.1 Step 4.a RNO As RCS pressurizes due to faulted SGs If any PZR PORV opens because of ECA 2.1 Step completing blowdown and SI injecting, high PZR pressure, Step 5a must be 5 CAUTION PORV will start to cycle. repeated after pressure decreases to LESS THAN 2350 psia.

RO Check PZR PORVs And Block Valves ECA 2.1 Step 5

Verify PORVs - CLOSED ECA 2.1 Step 5.a IF PZR pressure is LESS THAN 2350

- ECA 2.1 Step psia, 5.a RNO THEN CLOSE PORVs.

IF any PORV can NOT be closed, THEN CLOSE its block valve.

Verify block valves - AT LEAST ONE ECA 2.1 Step OPEN. 5.b Check Secondary Radiation. ECA2.1 Step 6

Sample all SGs for activity ECA 2.1 Step 6.a RO 1. RESET SG blowdown sample Page51 of68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor InformationlActivity Assign ExDected Action Standard isolation RO 2. OPEN SG blowdown sample isolation valves us 3. Request Chemistry obtain activity samples using HP coverage RO Verify trend history and alarm status of ECA 2.1 Step radiation monitors 6.b Main steam line - NORMAL Condenser air ejector -

NORMAL SG blowdown - NORMAL RO Check If RHR Pumps Should Be ECA 2.1 Step Stopped. 7 Check RHR pumps - ANY RUNNING IN ECA 2.1 Step INJECTION MODE. 7.a Check RCS pressure. ECA 2.1 Step 7.b Pressure - GREATER THAN 300 psia ECA 2.1 Step (500 psia ADVERSE CTMT) 7.b.l Pressure - STABLE OR INCREASING. ECA 2.1 Step 7.b.2 RESET ESF actuation signals ECA 2.1 Step 7.c SI Page 52 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard

. CDA

. LOP CIA

. CIB STOP RHR pumps and Place in AUTO. ECA 2.1 Step 7.d The recirculation spray pumps are ECA 2.1 Step sequenced to automatically start 11 8 NOTE minutes after CDA actuation.

RO Check If Containment Spray Should ECA 2.1 Step Be Stopped. 8 Verify quench spray pumps - RUNNING. ECA 2.1 Step 8.a Proceed to Step 9. ECA 2.1 Step 8.a RNO RO Check RWST Level - GREATER ECA 2.1 THAN 520,000 gal. Step 9 Go to ES - 1.3, Transfer to Cold Leg ECA 2.1 Recirculation. Step 9 RNO RO Check If Accumulators Should Be ECA 2.1 Isolated. Step 10 RCS HL temperature should be < Verify at least two RCS hot leg WR ECA 2.1 380°F temperatures - LESS THAN 380°F. Step 10.a Page 53 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Inst r ucto r Inf o rmat ion/Act ivity Assign Expected Action Sta rd Proceed to Step 11. ECA 2.1 Step 10.a RNO T= 5 min Remote Actions (if temperature is - Using GA-7, Isolate SI accumulators ECA 2.1 from being LESS THAN 380°F). Step 10.b dispatched SIR15, RI SIR16, RI SIR17, RI SIR18, RI RO Check If ECCS Flow Should Be ECA 2.1 Reduced. Step 11 Verify RCS subcooling based on core ECA 2.1 exit TCs - GREATER THAN 32°F Step 11.a (1 15°F ADVERSE CTMT).

Verify RCS pressure - STABLE OR ECA 2.1 INCREASING . Step 1 l . b Verify PZR level - GREATER THAN ECA 2.1 16% (50% ADVERSE CTMT). Step 11.c If offsite power is lost after SI ECA 2.1 reset, manual actions to Step 12 restart safeguards equipment CAUTION may be required.

Page 54 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard DO NOT reset CDA if the recirculation spray pumps are required and have not automaticalIy started.

. If any SG pressure increases, Complete Steps 12 through 27, then Go to E-2, Faulted Steam Generator Isolation.

RO RESET ESF Actuation Signals ECA 2.1

. SI Step 12

. CDA LOP CIA BOP Restore Power To MCC 32-3T. ECA 2.1 Step 13 Check emergency bus 34C - ECA 2.1 ENERGIZED Step 13.a BOOTH INSTRUCTOR: PEO Using GA-1, Energize MCC 32-T ECA 2.1 Step 13.b T=+8of EDRl8 Energize MCClA3 (32-3T) request RESET Reset Battllnv 6 Trouble (- 5 min EDR44 after 3T reset)

RESET Page 55 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDA/Malf Inst ruct or Info rmat io n/Act ivity Assign Expected Action Standard RO Establish Instrument Air To Ctmt. ECA 2.1 Step 14 Check instrument air compressors - AT ECA 2.1 LEAST ONE RUNNING. Step 14.a OPEN instrument air Ctmt isolation ECA 2.1 valves. Step 14.b RO STOP All But One Charging Pump ECA 2.1 And Place In AUTO. Step 15 RO Check RCS Pressure - STABLE OR ECA 2.1 INCREASING. Step 16 RO Establish Normal Charging Flow ECA 2.1 Path. Step 17 Fully Open charging line flow control ECA 2.1 valve. Step 17.a Verify charging header loop isolation ECA 2.1 valves (3CHS*AV8146 or Step 17.b 3CHS*AV8147) - ONE OPEN.

Re-position valves to establish only ECA 2.1 one open. Step 17.b RNO OPEN charging header isolation valves ECA 2.1 Step 17.c 3CHS*MV8106 3CHS*MV8105 Page 56 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDA/Malf I nst ructo r I nformat ion/Activity Assign Expected Action Standard CLOSE the charging pump miniflow ECA 2.1 isolations to the RWST Step 17.d 3CHS*MV8511A 3CHS*MV8511 B CLOSE the remaining charging pump ECA 2.1 cold leg injection valves Step 17.e 3SIH*MV8801A 3SIH*MV8801 B OPEN the charging pump recirculation ECA 2.1 isolation valves Step 17.f 3CHS*MV8111A 3CHS*MV8111 B 3CHS*MV8111C 3CHS*MV8110 RO Verify PZR Level ECA 2.1 Step 18 Check PZR level - STABLE OR ECA 2.1 INCREASING Step 18.a Control charging flow to maintain PZR ECA 2.1 level. Step 18.b Step 19 Remove "C" Low Set SG Code Safety Valve RO Check If SI Pumps Should Be ECA 2.1 commenced MS07C closes. Stopped. Step 19 Page 57 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard Per NOTE prior to step 1 of ECA-2.1, Check SI pumps - RUNNING. ECA 2.1 If any SG pressure increases at any Step 19.a time, except while performing SI termination in Steps 12 through 27, GOto E-2.

Check RCS pressure ECA 2.1 Step 19.b Pressure - GREATER THAN 1650 psia (1950 psia ADVERSE CTMT).

. Pressure - STABLE OR INCREASING.

STOP SI pumps and Place in AUTO. ECA 2.1 Step 19.c At the completion of step 20 stopping ECA 2.1 RCPs based on the conditions of step Step 20 4 is NOT required. NOTE RO STOP RHR Pumps and Place In ECA 2.1 AUTO. Step 20 RO Verify ECCS Flow Not Required. ECA 2.1 Step 21 Check RCS subcooling based on core ECA 2.1 exit TCs - GREATER THAN 32°F Step 21 .a (I 15'F ADVERSE CTMT).

Check PZR level - GREATER THAN ECA 2.1 16% (50% ADVERSE CTMT). Step 21 .b Page 58 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard RO/BOP Check RCS Hot Leg WR ECA 2.1 Temperatures - STABLE OR Step 22 DECREASlNG .

BOP Control AFW flow Dump steam to ECA 2.1 stabilize RCS hot leg WR Step 22 temperatures. RNO BOP Check NR Level In All SGs - LESS ECA 2.1 THAN 50%. Step 23 Control AFW flow to maintain NR level ECA 2.1 LESS THAN 50% in all SGs. Step 23 RNO RO Check If Letdown Can Be ECA 2.1 Established. Step 24 Verify PZR level - GREATER THAN ECA 2.1 25% (50% ADVERSE CTMT). Step 24.a Verify Train A RPCCW pump ECA 2.1 RUNNING. Step 24.b Using GA - 13, Establish normal ECA 2.1 letdown Step 24.c Proceed to step 25. ECA 2.1 Step 24.d RO Check RCS Makeup System. ECA 2.?

Step 25 Adjust boric acid flow controller to pot ECA 2.1 setting 8.3. Step 25.a Page 59 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time I DNMalf Instructor InformationlActivity Assign Expected Action Standard Check RCS makeup -ALIGNED FOR ECA 2.1 AUTO Step 25.b RO Align Charging Pump Suction to ECA 2.1 VCT. Step 26 OPEN VCT to charging isolation ECA 2.1 valves. Step 26.a 0 3CHS*LCV112B 0 3CHS"LCVllZC CLOSE RWST to charging isolation ECA 2.1 valves. Step 26.b 3CHS*LCV112D 0 3CHS*LCV112E RO Control PZR Pressure. ECA 2.1 Step 27 Maintain pressure stable using PZR ECA 2.1 heaters and normal spray as Step 27.a necessary.

IF normal spray NOT available and

- ECA 2.1 letdown is in service, Step 27.a RNO THEN Establish auxiliary spray:

1) Unlock and OPEN auxiliary spray valve (3RCS*AV8145).

Page 60 of 68

SEC I ION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Task Time IDNMalf Instructor I nformation/Activity Assign Expected Action Standard

2) CLOSE charging header loop isolation valves e 3CHS*AV8146 e 3CHS*AV8147

3) Throttle charging flow controller to adjust and maintain auxiliary spray flow.

4) at any time, REGEN HX LETDOWN TEMP HI (395°F)

(MB3A 5-4) annunciator actuates, THEN OPEN one charging header loop isolation valve.

IF auxiliary

- spray can NOT be established, THEN Use one PZR PORV.

Terminate the scenario when crew identifies the C Low Set Code Safety closed and verbalizes their intention of transitioninq to E-2 after the competion of step 27 OR Examiners cue.

Page 61 of 68

SECTION 4 Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 EVALUATION GUIDE I. Crew FOLLOW-UP QUESTIONS

1. What is the Emergency Classification for this event?

ALERT - Charlie One based on failure of automatic reactor trip manual trip successful. (RCB4)

ALERT - Charlie One based on an unisolable steam break outside CTMT. (BA2) 2 Page 62 of 68

SECTION 4 EXAM GUIDE

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 II. Critical Tasks Note: Critical Tasks are not required for Progress Review Exams.

TASK DESCRIPTION TASK # KIA >I =

3.0 BASIS F O R SELECTION Attempt to manually trip the E-0 -- A 029-EA1.08 Failure to manually trip the reactor causes a reactor from the control room 4.514.5 challenge to the subcriticality CSF beyond that with either Main Board trip 029-EAI . 12 irreparably introduced by the postulated switch or by opening 32B and 4.114.0 conditions. Also, it constitutes an "incorrect 32N supply breakers before performance that requires the crew taking completing step 1 of E-0. compensating action which complicates the event mitigation strategy and demonstrates the inability by the crew to recognize a failure of the automatic actuation of the RPS."

Manually actuate Main E-0-p E l 2-EAI . 1 Failure to close the MSlVs under the Steamline isolation or close 3.813.8 postulated plant conditions causes challenges MSlVs before a severe (orange 039-K4.05 to CSFs beyond those irreparably introduced path) challenge develops to 3.713.7 by the postulated conditions. Such an either the subcriticality or the om iss ion constitutes a "demonstrated i nabiIity integrity CSF or before transition by the crew to recognize a failure of the auto to ECA-2.1, whichever happens actuation of an ESF system or component and first. to take an action that would prevent a challenge to plant safety."

Trip all RCPs so that an Orange Path on Core Cooling based on E-1 --' 3.613.6 009 EA1.09 4.214.3 Failure to trip the RCPs under the postulated plant conditions leads to core uncovery and to core exit thermocouples (718°F) fuel cladding temperatures in excess of 009 EK3.23 does not occur when forced 22OO0F,which is the limit specified in the circulation in the RCS stops. ECCS acceptance criteria.

E12.EA1.3 Failure to control the AFW flow rate to the SGs Control the AFW flow rate to at ECA-2.1 leads to an unnecessary and avoidable severe least 100 gpm per SG in order -- A 3.413.9 challenge to the integrity CSF and to the to minimize the RCS cooldown subcriticality and the containment CSFs beyond rate before a severe those irreparably introduced by the postulated (orange-path) challenge plant conditions. Thus, failure constitutes develops to the integrity CSF "demonstrated inability by the crew to take an action or combination of actions that would prevent a challenge to plant safety."

Note: [*I Used to designate critical tasks. Should also be incorporated into column 3 or 4 of Instructor Guide.

Page 63 of 68

SHIFT TURNOVER REPORT DATE-TIME PREPARED BY SHIFT todav 0300 Unit Supervisor /Night Shift 1800-0600 I PLANT STATUS:

Mode: 1 RxPower: 100%

Megawatts: Thermal: 341 1 MWTH PZR Pressure: 2250 psia Electric: 1205 MWe RCS T-AVE: 587 degF RCS Leakage: Identified: 0.005gpm Boron/Burnup 43 ppm / 19 000 MWD/MTU Unidentified: 0.03 gpm Days on line 485 Date/Time: todav 0015 Protected Train/Facility: B Purple PRA/SDR: Green Intake: Green Active Tracking Records and Action Statements EauiDmentlReason Time in LCO Action Date Action Requirement Time Left LCO 3.8.1.1 I b.1, b.2, b.3, b.4, b.5 I yesterday I 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> I SR 4.8.1.1.1.a due in 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> I 13 days 7.4.1 I a.1. a.3 I vesterdav I 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> I I 13 davs OD Compensatory Actions / Temp Logs OpenDate I ClassReason I Reason I I Plant Systems APC Notes System TPCCW I cTPCCW wmr> is out of service for an oil reDlacement.

Cross Unit System Status I Surveillances I Evolutions in Proaress Shift Orders The A EDG is out of service for a planned 2 year overhaul maintenance outage. The C TPCCW pump is out of service for an oil replacement.

Page 64 of 68

ATTACHMENT 2 VAL1DATION CHECKLlST

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

Verified By:

(Init iaIs)

Initial Conditions:

The initial condition(s) contained in the guide are certified or have been developed from certified ICs.

Test Run:

The scenario contained in the guide has been test run in part or whole on the simulator. The simulator response is reasonable and as expected. If a simulator guide revision does not affect original Test Run, then enter N/A.

Simulator Operating Limits:

The simulator guide has been evaluated for operating limits and/or DM anomalous response by reviewing the Simulator Modeling and Anomalous Response List.

D. L. Minnich 1/24/07 Actions Complete (Signature) Date Page 65 of 68

Appendix D Scenario OutIine Form ES-D-I--

Facility: Millstone 3 Scenario No.: 2K7 NRC-02 Op-Test No.: 2K7 Examiners: Operators:

I Initial Conditions: IC-21, 100% power, End of Life, Equilibrium Xe.

Turnover:

The plant is at 100% power and at end of life. The A Emerqencv Diesel Generator is out of service for routine maintenance. The IC TPCCW pump is out of service for oil replacement.

Event Malf. No Event Event No. Type* Description 1 RXOSA I (RO) Controlling channel of PZR pressure fails high.

2 R X I 3E I (BOP) Controlling channel of C Steam Generator feed flow f a x IOw (3MSS- FT530).

3 RC04A C (RO) RCS leak. Reactor Vessel Flange leakoff.

4 RX04A I (RO) Loop 1 Tavg fails high (loop 1 narrow range Tc, 3RCS*TE411B) 5 IO CHS- R (RO) CONVEX directed Emergency Load Reduction. AOP MV8104 R (SRO) 3575, Rapid Downpower. Emergency Boration valve fails N (BOP) to open.

CjROj 6 EGO1 C (RO) Main Generator trip and automatic reactor trip failure.

RPIOA/B C (BOP) 7 MS02A M (ALL) Four faulted Steam Generators. Main Steam Isolation f%

MS07C/D C (BOP) to automatically actuate. Several RPCCW components fail MS12A/B C (RO) to respond to a Safety Injection signal.

RP08 RP11H I I I

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 66 of 68

Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: Q Assessor: Dave Minnich QUALITATIVE ATTRIBUTES The initial conditions are realistic, in that some equipment andlor instrumentation may be out of service, but it does not cue the crew into expected events.

Y 2. The scenario consists mostly of related events.

-Y-3. Each event description consists of:

- the point in the scenario when it is to be initiated

- the malfunctions(s) that are entered to initiate the event

- the symptomslcues that will be visible to the crew

- the expected operator actions (by shift position)

- the event termination point (if applicable)

No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario without a credible preceding incident such as a seismic event.

Y 5. The events are valid with regard to physics and thermodynamics.

Y 6. Sequencingltiming of events is reasonable, and allows for the examination team to obtain complete evaluation results commensurate with the scenario objectives.

If time compression techniques are used, scenario summary clearly so indicates. Operators have sufficient time to carry out expected activities without undue time constraints. Cues are given.

Y 8. The simulator modeling is not altered.

Y 9. The scenario has been validated, Pursuant to 10 CFR 55.46(d), any open simulator performance deficiencies or deviations from the referenced plant have been evaluated to ensure functional fidelity is maintained while running the planned scenario.

Y IO. Every operator will be evaluated using at least one new or significantly modified scenario. All other scenarios have been altered IAW Section D.5 of ES-301.

Y 11. All individual operator competencies can be evaluated, as verified using form ES-301-6.

Y 12. Each operator will be significantly involved in the minimum number of transients and events specified on Form ES-301-5.

-Y-I 3. Level of difficulty is appropriate to support licensing decisions for each crew position.

Page 67 of 68

Lesson

Title:

Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: 0 Note: Following criteria list scenario traits that are numerical (QUANTITATIVE) in nature.

01. Total Malfunctions (TM) - 5 to 8 required Total 9 (1) PZR Pressure Failure, (2) SG Feed Flow Instrument Failure, (3) RCS Leak, (4) Tavg Channel Failure (5) Emergency Boration Valve Fails, (6) Automatic Reactor Trip Failure, (7)

Four Faulted SGs, (8) MSI Auto Actuation Failure, (9) RPCCW Components Fail to Auto position on an SI

02. Malfunctions after EOP entry (EMS)- 1 to 2 required Total 3 (1) Four Faulted SGs, (2) MSI Auto Actuation Failure, (3) RPCCW Components Fail to Auto position on an SI

03. Abnormal Events (AE) - 2 to 4 required Total 5 (1) PZR Pressure Failure (AOP 3571), (2) SG Feed Flow Instrument Failure (AOP 3571), (3)

RCS Leak (ARP MB4A), (4) Tavg Channel Failure (AOP 3571), (5) Rapid Downpower (AOP 3575)

04. Major Transients (MT) - 1 to 2 required Total 1 (1) Four Faulted SGs

05. EOPs (EU) enteredkequiring substantive actions -- 1 to 2 required Total 2 (1) E-2, (2) ECA-2.1

06. EOP Contingencies requiring substantive actions [ECAs/FRs/] (EC) -- Total 1 0 to 2 required (1) ECA-2.1

07. Critical Tasks (CT) - 2 to 3 required Total 4 4- A Manually trip the reactor from the control room before completion of step 1 of E-0.

E P Manually actuate MSl or close the MSlVs before a severe challenge develops to the Subcriticality or Integrity CSFs.

E-1-C Trip all RCPs so that an Orange Path on Core Cooling does not occur.

ECA-5.1- A Control the AFW flowrate to at least 100 gpm per SG in order to minimize the RCS cooldown rate.

08. Approximate Scenario Run Time: 60 to 90 min. Total a m i n

09. EOP run time: Total 45 min

10. Technical Specifications are exercised during the scenario. (Y/N)-Y-.

Page 68 of 68

MILLSTONE POWER STATION SIMULATOR EXAM GUIDE APPROVAL SHEET Exam

Title:

Loss of All AC Power Revision: 0 chg 2 ID Number: 2K7 NRC-03 This document is the property of the Millstone Power Station which controls its distribution. Further transfer, copying, or modification of this document is strictly prohibited without the written consent of the Millstone Power Station.

7 Submitted by: D. Minnich 111 1/07 Developer Date Validated by: Ray Martin 1/24/07 Technical Reviewer Date Approved by: Tim Kulterman 1/24/07 Training Supervisor Date Page 1 of 59

MILLSTONE POWER STATION SIMULATOR EXAM GUIDE APPROVAL SHEET Exam

Title:

Loss of All AC Power Revision: 0 ID Number: 2K7 NRC-03 [5p@<F)

/

This document is the property of the Millstone Power Station which controls its distribution. Further transfer, copying, or modification of this document is strictly prohibited without the written consent of the Millstone Power Station.

b J)

Submitted by: D. Minnich 1/I 1/07 Developer c-' Date Validated by:

Technical Reviewer Date Approved by: -

Training Supervisor Date STOP THINK ACT REVINV

SUMMARY

OF CHANGES Change Description Date of Change Added the severity of malfunction EG08A, as it was omitted in Rev 0 chg 1 error. Corrected several remote function designators for instrument bistables. DLM 2/5/07 Modified the turnover sheet to change thermal power to 0 Rev chg 2 MWth, days on line to 0 and added the status of feed control.

Added to the simulator setup page to verify the 18% Lo Lo SG 2115/07 level trip placard is displayed at MB5. Added a cue to provide a second Data logger readout if requested. Separated the running RPCCW pump trip event from event 1, and made it a stand alone event (event 2). Renumbered subsequent events.

Added a cue to the crew to maintain reactor power stable using control rods once the power ascension is complete. Added a cue for the crew that a different RO will perform the Tavg Monitoring surveillance if required. Removed Point of Adding Heat from the turnover, exam overview and scenario outline, and replaced with low in the power range.

Page 2 of 59

SECTION 2 SIMULATOR EXAM GUIDE TABLE OF CONTENTS SECTIONS LISTED IN ORDER

1. Cover Page

2. Table of Contents

3. Exercise/Exam Overview

4. Exam Guide Attachments:

- Shift Turnover Report

- Validation Checklist

- Scenario Outline (ES-D-1)

- Attributes Checklist

- Summary of Changes Page 3 of 59

SECTION 3 EXAM OVERVIEW

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 2

1. The crew will take the shift with reactor power stable, low in the power range (reactor power 3%), following a reactor startup by the previous shift. This is the initial plant startup from a refueling outage. OP 3203, Plant Startup is in progress and complete up through step 4.2.7. The crew is to raise reactor power from 3% to 6 to 9% in accordance with step 4.2.8. The US should facilitate a brief of the evolution prior to taking the shift. The MP3 simulator briefing room may be used for this purpose.

During the power ascension, the B RPCCW pump will spuriously trip and will not restart.

The crew will use AOP 3561, Loss of RPCCW, to verify alignment and start the C RPCCW pump on the B Train.

Once the reactor is in MODE 1 (6 to 9%) and the primary plant stable, a small leak will develop through pressurizer PORV, 3RCS*PCV455A. The crew should use ARP MB4A 3-5, PZR RELIEF VALVE DIS TEMP HI, to respond. Correct actions will include closing the A PORV Block valve to isolate the leaky PORV. This event will exercise the US in Tech Spec and TRM use.

Once the reactor is 6 to 9% and the primary plant stable, Power Range Nuclear Instrument (NI)

Channel 43 Lower Detector will fail high and the appropriate annunciators will alarm. Rod control is in manual so no rod motion will occur, but the auctioneered high PRNl channel inputs to the control circuitry for the FRV Bypass valves. The FRV Bypass valve controllers should be placed in manual and the crew should respond using AOP 3571, Instrumenf Failure Response. Tech Specs will need to be addressed.

Once Tech Specs are addressed for the failed NI, A RCP # I seal will slowly degrade.

The crew should address the RCP seal degradation using the Main Board 4 Annunciator Response Procedure for RCP HI RANGE LKG FLOW HI. The procedure requirements will have the operator transition to AOP 3554, RCP Trip or Removing a RCP from Service At Power, to stop the affected RCP. The procedure will then direct the crew to commence a plant and reactor shutdown.

After the RCP is tripped and a downpower plan discussed, transmission grid instabilities will result in a loss of offsite power. The B EDG will not start due to its inability to respond to signals from the Sequencer or MB8. Though the A EDG will initially start it will not load and will exhibit degraded frequency due to damaged governor linkage. The crew may conservatively decide to shutdown the EDG; if not the A EDG will trip at step 4 of E-0 and will not be able to be re-started. Also, at the time of the loss of power, an RCS leak will occur (A RCP # I seal catastrophically fails).

The crew should enter E-0, Reactor Trip and Safety Injection, and once the A EDG trips, transition to ECA 0.0, Loss ofAll AC Power. Prior to or at step 4 of ECA-0.0, the crew should diagnose that the TDAFW pump failed to auto-start and manually start the TDAFW [Critical Page 4 of 59

Task]. Plant assistance (a PEO/NLO, Maintenance, Engineering, etc.) should be dispatched to both EDGs to ascertain the reason for the start failures. The 6 EDG will be able to be started locally using ECA-0.0, Attachment E. The BEDG local start attempts will succeed when the crew is aligning the selected train busses for the Station Blackout Diesel. Service Water will need to be restored to the running EDG [Critical Task]. The crew should then Go To step 26 as per the note prior to step 6. Low pressurizer level will necessitate a transition to ECA 0.2, Loss of All AC Power - Recovery with SI Required, The session will end when the crew announces the transition to ECA-0.2.

2. The SM should classify the event as an Site Area Emergency - Charlie Two, Loss of Voltage on Buses 34C and 34D > 15 minutes (EAL PSI).

3. Duration of Exam: 120 minutes Page 5 of 59

SECTION 4 EXAM GUIDE

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 2 All Control Room Conduct, Operations and Communications shall be in accordance with Master Manual 14 and applicable DNAPIDNOS standards.

Page 6 of 59

SECTION 4 EXAM GUIDE

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 2 SIMULATOR PROBLEMS DURING EXAMS It is the responsibility of the Instructors in the simulator to insure that training interruptions have a minimum negative impact on the Crew and the training we provide. Use your judgment on whether to stop the training and how the training should be commenced after the problem is corrected.

Be aware that at all times the Operators should treat the simulator as if it were the plant and you too should treat it as much like the plant as possible when they are in the simulator.

As soon as the Instructors are aware of a simulator problem that will adversely affect the training in progress (computer fault, etc.) the Instructor should:

1. Place the simulator in FREEZE if possible.

2. Announce to the Crew that there is a simulator problem.

3. Request that the Crew either standby (for minor trouble that can be handled quickly) or leave the simulator control room. (The Crew should leave the simulator for problems which involve major switch alignments).

4. Deal with the problem (reboot, close tripped breaker, call STSB, etc.)

5. After the Instructors believe the simulator is restored to service, the Crew should be told how training will continue. If it is possible and felt to be acceptable to the Instructors, training can begin where it left off with an update on plant parameters and each Crew member is prepared to restart. If training will not begin where it left off, the crew should be told how and where training will begin again.

6. Once the Crew has been told how and where training will begin, have the crew conduct a brief so that the Instructor can insure that the crew has all the necessary information to continue with the scenario.

7. Once all Crew members and Instructors are satisfied that they have the necessary information to continue the scenario, place the simulator in RUN and announce to the Crew that you have continued the training session.

Page 7 of 59

SEC I ION 4 Lesson

Title:

Four Faulted Steam generators ID Number: 2K7 NRC-02 Revision: 0 chq 1 INITIAL SETUP INSTRUCTIONS

1. START the Sun Workstation.

a. IF the Sun Workstation is running THEN go to SIM ACTIVE.

2. PLACE Recorder Power to ON.

3. VERIFY that the current approved training load is loaded.

4. REMOVE the step counter OVERRIDE and allow the counters to step out during the IC reset.

5. RESET to IC 91 (Based on IC 07)

6. ADJUST the various pot settings to the valued specified by the chart in the simulator booth or Notepad for the selected IC. Pay particular attention to the Pzr spray valves and their setpoints.

7. PLACE Simulator to RUN.

8. If Necessary, RESET the Plant Calorimetric at the Instructor Station PPC by Pressing SHIFT LEFT and F6 simultaneously.

9. ENSURE Simulator fidelity items cleared.

a. CHECK the STEP COUNTERS at correct position for plant conditions.

b. PLACE tiles under the DEMINS IN SERVICE lamacord label on MB6.

c. PLACE the Main Turbine on the LOAD LIMITER and ENSURE Standby Load Set MATCHED if conditions require.

d. PLACE the Westronic (5) and Gammametrics (2) recorders in activehun by depressing up or down arrow for each.

e. For the RIL recorder: select printer to ON when command? appears select Autojog.

f. CLEAR DCS alarms on MB7 and BOP console.

g. VERIFY annunciator, COMPUTER FAILURE (MB4C, 1-1I ) , is NOT LIT.

IO. As needed, RESET Computer Terminals to At Power displays if 100% power IC.

11. RESET Rad Monitor Screen to Status Grid.

Page 8 of 59

SEC I ION 4 Lesson

Title:

Four Faulted Steam generators ID Number: 2K7 NRC-02 Revision: 0 chq 1 INITIAL SETUP INSTRUCTIONS

12. IF placing equipment OOS, THEN perform the necessary switch manipulations and hang appropriate tags, as required, listed under Equipment 00s.

13. Ensure that the protected train and environmental placards are appropriately hung.

Equipment 00s: NONE Insert applicable Crew Training Tape/CD into the DVDNCR.

Verify the MONITOR Time Display the same as the digital time display on MB4. If not page/call the Unit Tech.

InitiaI Malfunctions/lOs/l DAs:

PLACE GREEN PLACARDS FOR ALL INTAKE PARAMETERS ON MB6 PLACE THE B TRAIN PROTECTED PLACARD ON MB4 ENSURE THE BORIC ACID POT SETTING IS ABOUT 5.9 Ensure the 18% lo lo SG level trip placard is on MB5.

Page 9 of 59

SEC IION 4 Lesson

Title:

Four Faulted Steam generators ID Number: 2K7 NRC-02 Revision: 0 chq 1 INITIAL SETUP INSTRUCTIONS MALF CCOl B 1 B RPCCW pump trip.

MALF RC07A 1Yo 2 A PZR PORV Leak.

MALF N109C 100% 3 PRNI Channel 43 lower det fails high MALF CV13A 6.5% 4 A RCP # I seal degrades MALF ED10 75% 60 5 Degraded Grid Voltage Remote EDROI +0.1 5 Grid Frequency Degradation MALF ED01 6 Loss of Offsite Power Page 10 of 59

SEC I ION 4 Lesson

Title:

Four Faulted Steam generators ID Number: 2K7 NRC-02 Revision: 0 chq 1 INITIAL SETUP INSTRUCTIONS Lead Examiner: Refer to the "Briefing Script for the Operational Exam" and brief the crew. Go over the PIa nt/s im uIato r d iffe rences , w hic h f o IIow.

Booth Instructor: Perform the crew turnover (Initial Conditions page at end of LP) with the SM . Have the SM brief his crew on plant conditions and any major equipment 00s.

PLANTlSlM ULATOR DIFFERENCES:

9 Rad Monitor Historical Data--Simulator Rad Monitor historical data not valid prior to the beginning of this exercise.

. If not using the speed dial option on the phone system, the operator must dial either #3333 or #3334 to reach the person/department they desire.

. The following PPC programs do not function on the simulator:

0 Samarium Follow Xenon Follow 0 Sequence of Events 0 Flow indications 3SIH-F1917 (charging ECCS flow), 3SIH-F1918 (A SI pump flow) and 3SIH-F1922 (B SI pump flow) will show flow at low flow rates.

Page 11 of 59

SECTIUN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard EVENT 1: Power ascension from 3% to 8% power using OP 3203.

OP 3203, Plant Startup is in progress and complete up through step 4.2.7.

The crew is to raise reactor power from 3% to 6 to 9% in accordance with step 4.2.8. The US should facilitate a brief of the evolution prior to taking the shift.

OP 3303, Plant Startup (rev 018-05)

The reactivity plan specifies control us INCREASE reactor power to between 6% and OP 3203 rods be used to raise reactor power. 9% by one of the following: Step 4.2.8 RO 0 WITHDRAW control rods at a rate not greater than approximately 2 stepdminute 0 DILUTE RCS boron concentration at a rate not greater than approximately 10 to 15 pcm/minute.

PERFORM the following: OP 3203 Step 4.2.9

a. LOG MODE change to MODE 1, POWER OPERATION.

b. NOTIFY ISO-New England of the MODE change.

Evaluator If the Tavg - Tref Deviation alarm WHEN desired, Refer To OP 3331A, OP 3203 Page 12 of 59

SECTluN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDAlMalf Instructor I nformation/Activity Assign Expected Action Standard comes in, report that another RO will "Auxi Iiary BoiIer , Steam and Condensate," Step 4.2.10 perform SP 3601G.3, Tavg Monitoring and SHIFT auxiliary steam from auxiliary boiler (A or B) to main steam while continuing with this procedure.

T = When BOOTH Report as RE to maintain reactor power PERFORM one of the following: OP 3203 requested stable using control rods A reactivity Step 4.2.11 plan is forthcoming. IF power increase desired, Go to Section 4.3 IF reactor shutdown desired, Go to OP 3206, "Plant Shutdown".

EVENT 2: Running RPCCW pump trip, alignment and start of the standby RPCCW pump.

T= MODE 1 RSCU 1 B RPCCW Pump Trips CCOl B us The US should recognize the entry conditions for AOP 3561 are met and announce entry.

AOP 3561 Actions (rev 009-00) The Foldout Page must be open. AOP 3561 Step 1, NOTE RO Verify RPCCW System Alignment. AOP 3561 Step 1 Yes the "A" RPCCW pump is running. RO Check RPCCW pumps - A T LEAST ONE AOP 3561 RUNNING Step 1.a RO Check RPCCW pumps - ONLY ONE AOP 3561 Page 13 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDA/Malf I nst ructo r Informat ion/Act iv ity Assign Expected Action Standard RUNNING. Step 1.b Yes, the IC RPCCW pump is aligned RO Check the standby RPCCW pump - AOP 3561 to the affected train. ALIGNED TO THE AFFECTED TRAIN Step 1.c RO START the standby RPCCW pump AOP 3561 Step 1.d Yes, 3SWP*MOV50B will be open. RO Verify RPCCW heat exchanger SW inlet AOP 3561 isolation valves (3SWPMOVSOA or Step 1.e 3SWP*MOVSOB) to the affected Train -

OPEN T = When REMOTE SWR07 (for 3SWP*V38) and SWROG RO Using OP 3330A, Reactor Plant Component AOP 3561 directed (for 3SWP*V66). This will align service Cooling Water, Shift from the affected Step 1.f SWRo6 to water from the B RPCCW HX to the RPCCW pump and heat exchanger to the CLOSE C RPCCW HX. standby RPCCW pump and heat exchanger.

SWRO7 to OPEN Yes, the C CDS chiller auto tripped RO Check the CDS chiller on affected train - AOP 3561 and then auto started once RPCCW AUTO STARTED Step 1.g flow was reestablished.

RO Check RPCCW containment supply and AOP 3561 return header isolation valves - OPEN Step 1.h RO Check RPCCW containment header cross- AOP 3561 connect valves - CLOSED Step 1.I 3CCPAOVI 79A 3CCP*AOV179B 3CCP*AOV180A Page 14 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard 3CCP*AOV180B RO Check Service Water to RPCCW Heat AOP 3561 Exchangers Step 2 Verify RPCCW heat exchanger SW inlet AOP 3561 isolation valves (3SWP*MOV50A and Step 2.a 3SWP*MOV50B) - OPEN.

Yes, service water flow to each RO Verify service water flow to each operating AOP 3561 operating RPCCW heat exchangers will RPCCW heat exchangers - GREATER Step 2.b be > 6200 gpm. THAN 6200 gpm Check IF RPCCW System Is Intact AOP 3561 Step 3 RPCCW SURGE TANK LEVEL LOW RO Verify RPCCW SURGE TANK LEVEL LOW AOP 3561 annunciator will not be lit. annunciator (MBI C 2-78) - NOT LIT Step 3.a RO CLOSE surge tank fill valves: AOP 3561 Step 3.b RPCCW (3CCP-LV20)

SI Cooling (3CCP-LV61)

Chill Water (3CCP-LV74)

Charging Pump Cooling (3CCP-LV91)

RPCCW surge tank level should be RO Verify RPCCW surge tank level - STABLE AOP 3561 stable. OR INCREASING Step 3.c RO Place surge tank fill valves in AUTO: AOP 3561 Step 3.d Page 15 of 59

SECl IUN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDA/Malf Instructor Information/Activity Assign Expected Action Standard RPCCW (3CCP-LV20)

SI Cooling (3CCP-LV61)

Chill Water (3CCP-LV74)

Charging Pump Cooling (3CCP-LV91)

Crew Allow Plant Conditions To Stabilize AOP 3561 Step 4 Determine Additional Actions AOP 3561 Step 5 us Using the following determine any additional AOP 3561 required actions Step 5.a T/S 3.7.3 applies until the C RPCCW Technical Specification 3.7.3, pump and Heat Exchanger are placed Reactor Plant Component Cooling in service, including service water System alignment.

72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> action statement T/R 7.4.1. actions a.1 and a.3 apply. 3TRM-7.4.1, Fire Related Safe Sh utdown Co mponents 14 and 30 day action statements respectively.

ROIBOP Verify MB Annunciators And Parameters - AOP 3561 ASEXPECTED Step 6 us Continue With Normal Plant Evolutions AOP 3561 Using Applicable Plant Procedures Step 7 Page 16 of 59

SECTluN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Inst ructo r I nf o rmat ionlAct ivity Assign Expected Action Standard EVENT 3: Small leak develops through PZR PORV, 3RCS*PCV455A T = power RSCU 2 "A" PORV Leak stable between 6 (RCO'IA, and 9% 1%)

The crew will utilize the Annunciator Response Procedure, OP3353.MB4A-3-5, PZR Relief Valve Dis Temp Hi.

MB4A-3-5 (rev 002-12), PZR Relief Valve Dis Temp Hi CORRECTIVE ACTIONS "PORV OPEN" (MB4B 4-9) will not be RO IF "PORV

- OPEN" (MB4B 4-9) is lit, Go to OP 3353 lit. OP 3353.MB4B 4-9, "PORV OPEN." MB4A 3-5, Step 1 PRESSURIZER PRESSURE HI" (MB4A RO IF "PRESSURIZER

- PRESSURE HI" (MB4A OP 3353 3-4) will not be lit. 3-4) is lit, Go To MB4A 3-4, MB4A 3-5, "PRESS URIZ ER PRESSURE HI" Step 2 3RCS-TI 463 will confirm the alarm. RO CONFIRM high PORV outlet temperature on OP 3353 3RCS-TI 463, "PORV' OUTLET TEMPS"

'I MB4A 3-5, (MB4) Step 3 IF 3RCS*PCV455A or 3RCS*PCV456,

- OP 3353 PORV, (MB4), is not fully closed, CLOSE MB4A 3-5, PORVs. Step 4 Page 17 of 59

SECTtUN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDA/Malf Instructor ,,iformation/Activity Assign Expected Action Standard IF 3RCS*PCV455A

- or 3RCS*PCV456, OP 3353 PORV, (MB4), fail to close, CLOSE MB4A 3-5, associated PORV block (MB4): Step 5 I

PORV PORV BLOCK 3RCS*PCV455A 3RCS*MV8000A 3RCS*PCV456 I 3RCS*MV8000B This will be the case. us IF pressurizer

- pressure is pcJ high AND both OP 3353 pressurizer power relief valves are closed, MB4A 3-5, PERFORM the following to determine Step 6 leaking PORV:

Give US Data logger readout #I.

Crew MONITOR PORV outlet temperatures on OP 3353 The readout is at the end of exam. It data logger. MB4A 3-5, will show 3RCS*PCV455A is leaking. Step 6.1 us -

IF data logger indicates 3RCS*PCV455A, OP 3353 PORV, is leaking, TEST 3RCS*PCV455A, MB4A 3-5, PORV, as follows: Step 6.2 RO CLOSE 3RCS*MV8000A, PORV block OP 3353 (MB4). MB4A 3-5, Step 6.2.1 RO MONITOR 3RCS-TI 463, PORV OUTLET OP 3353 TEMPS (MB4). MB4A 3-5, Step 6.2 2 T = If a znd BOOTH Give US Data logger readout #2. US -

IF 3RCS*T! 463, PORV OUTLET OP 3353 readout is The readout is at the end of exam. It TEMPS (MB4), decreases, Refer To the MB4A 3-5, Requested will show 3RCS*PCV455A tailpiece following Technical Specifications and Step 6.2.3 temperatures decreasing. DETERMINE Limiting Condition for Operation:

Page 18 of 59

SECTIUN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Inst ructo r Info rmat io nlAct iv ity Assign Expected Action Standard Enter T/S 3.4.4 action a.

T/S 3.4.4, Relief Valves 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> action statement to close the associated block valve with power maintained.

0 T/S 3.4.6.2, Operational Leakage NA 0 T/S 3.4.9.3, Overpressure protection Systems NA 0 TRM 3.4.1 1, Reactor Coolant System Vents US/RO 3RCS-TI 463, PORV OUTLET OP 3353 TEMPS (MB4), remains high, Refer To OP MB4A 3-5, 3301G, Pressurizer Pressure Control, and Step 6.2.4 OPEN 3RCS*MV8000A, PORV BLOCK (MB4).

After determining that the A PORV is leaking, the crew should maintain the A Block valve closed.

Event 4: Power Range Nuclear Instrument (NI) Channel 43 Lower Detector fails high.

T= ARP is RSCU 3 PRNl 43 lower Fails High us The US should recognize the entry 3571 Entry complete (N109C, conditions for AOP 3571 are met and Conditions 100%) announce entry.

Page 19 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard AOP 3571 Actions (rev 009-01)

The BOP should place all SG level RO Determine the Initiating Parameter and AOP 3571 Control Bypass Valve controllers in Place the affected controller in MANUAL Step 1 manual and stabilize steam generator level.

Stabilize the Plant Parameters AOP 3571 Step 2 The appropriate attachment for this Perform Corrective Actions Using AOP 3571 failure is D. The US should announce Appropriate Attachment Step 3 to the crew.

Instrument Failure Attachment Power Range Nuclear Instrument Channel D Failure us Power Range Nuclear Instrument Channel Failure Failure of two or more channels of PR AOP 3571 instrumentation may prevent P-I 0 from Attachment resetting when power is reduced below D Step 1 10%. If P-I 0 fails to reset, the following CAUTION automatic reactor trip signals are lost:

1. SR HIGH FLUX TRIP (IO5CPS)

2. IR HIGH FLUX TRIP (25%)

3. PR HIGH FLUX LOW STPT TRIP (25%)

Page 20 of 59

SECTiuN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard The reactor operator must remain alert to any power increases which would necessitate a manual reactor trip.

The Gamma Metrics Nuclear Instrumentation System shall be used during the reactor shutdown in lieu of the source range channels.

RO Defeat the failed channel input. AOP 3571 Attachment D Step 1 At the detector current comparator drawer, AOP 3571 Turn the following switches to the failed Attachment channel: D Step l a Rod Stop Bypass Upper Section Lower Section Power Mismatch Bypass.

At the comparator and rate drawer, Turn the AOP 3571 following switch to the failed channel: Attachment D Step I b Comparator Channel Defeat.

There should be no error, since rod RO Restore TAVE- TREFerror to within I 0 F and AOP 3571 control was in manual Place rod control in automatic. Attachment D Step 2 If the plant calorimetric source is Nls, the AOP 3571 failure of one NI channel will disable the Attachment calorimetric prog ram. D Step 3 NOTE Page 21 of 59

SECTiuN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Inst r uc tor Inf ormatio n/Act ivity Assign Expected Action Standard CREW When conditions have stabilized, AOP 3571 observe MB board annunciators and Attachment parameters and immediately report any D Step 3 unexpected or unexplained conditions to the Shift Manager.

us Trip the associated Reactor Protection AOP 3571 System bistable(s): Attachment D Step 4 Place a check mark in the box above the AOP 3571 appropriate channel that requires tripping on Attachment the last page of this Attachment. D Step 4a p e c h Specs] Refer to Technical Specification 3.3.1. AOP 3571 Attachment LCO 3.3.1 (FU2) D Step 4b 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> action statement to trip bistables.

Check the existing bistable status to ensure AOP 3571 a reactor trip will not occur when the failed Attachment channel is tripped. D Step 4c The following step will distinguish whether AOP 3571 the failure is within SSPS or the Protection Attachment channel. D Step 4.d NOTE This is not the case. The channel has If bistable status light(s) ( MB4F or MB4G) AOP 3571 failed. The US should proceed to step indicate that a single bistable input has Attachment 4.e. tripped and channel indication is normal, D Step 4.d PERFORM the following:

Page 22 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard REMOTE NOTE: When requested act as I&C Request the I&C Department trip the AOP 3571 See Technician and remove control power appropriate bistables using Attachment D Attachment column 3 fuses and trip bistables. and Attachment S. D Step 4e REMOTES RXRl08 Door Open RXR36 OTDT 431C RXR07 OTDT 431 D RXRI 08 Door Closed Verify the appropriate bistable status lights AOP 3571 are lit. Attachment D Step 4f NOTE: If at any time during the us Within one hour, Determine by AOP 3571 performance of this procedure, if observation of the associated permissive Attachment asked, as Reactor Engineering or annunciator window (s) that the D Step 5 Unit Management, advice that following interlocks are in their required power should be used to determine state for the existing plant condition reactor power. (Tech, Spec. 3.3.1, Action 8):

0 Rx or turbine not at power P-7 (MB4D 5-3) 0 Three loop permissive P-8 (MB4D 3-3) 0 NIS power range P-9 permissive (MB4D 6-1)

Page 23 of 59

SECTIUN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Reactor at power P-10 (MB4D 4-3).

The following step for removing the AOP 3571 failed PR channel from Program 3R5 Attachment restores OPERABILITY to the AFD D Step 6 Monitor Alarm and must be NOTE completed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or SURVEILLANCE REQUIREMENT 4.2.1.1.1. b must be performed.

The following step for removing the failed PR channel from Program 3R5 does NOT restore OPERABILITY to the QPTR Alarm Monitor; therefore, TABLE 3.3-1, ACTION 2.c and S URVEILLANC E REQUI REMENTS 4.2.4.1.b and 4.2.4.2 are in effect.

us / Perform the following to remove the AOP 3571 CREW affected power range input to the AFD Attachment and QPTR monitor alarm (Program 3R5): D Step 6 On the plant process computer, Select the AOP 3571 NSSS menu, page 2. Attachment D Step 6a At the NSSS menu, Select Tilting Factors AOP 3571 F9). Attachment D Step 6b Press the key (F5 through F8j that AOP 3571 corresponds to the channel to be removed. Attachment D Step 6c Refer to the following Technical AOP 3571 Page 24 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Specifications and Perform any required Attachment actions: D Step 7 Surveillance Requirement 4.2.1.1.1.b TABLE 3.3-1, ACTION 2.c 0 Surveillance Requirement 4.2.4.1. b us SurveiIlance Requirement 4.2.4.2 us Request I&C Department perform AOP 3571 corrective maintenance on failed Attachment instrument. D Step 8 EVENT 5 : A RCP #seal I degradation T= 6.5% should correlate to a leak of Crew Diagnose a problem with the #2 RCP # I Entry Bistables -5.8 gpm. If needed slowly adjust Seal and enter ARP MB3B 2-10 conditions tripped and RSCU=4 I .a.

the leakage to -5.8 gpm to bring in CV13A @ the annunciator.

Addressed 6.5%

CORRECTIVE ACTIONS RO CHECK the following to confirm alarm and MB3B 2-10 determine affected RCP:

step 1 3CHS-FR158 and 3CHS-FR160, high range RCP No. 1 seal leakoff flow recorders (MB3j CHS-F161*, RCP A No. 1 seal leakoff flow computer point 0 CHS-FlGO*, RCP B No. 1 seal leakoff Page 25 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chn 1 Task 1 Time IDNMalf Assign Expected Action Standard flow computer point 0 CHS-F159*, RCP C No. 1 seal leakoff flow computer point 0 CHS-F158*, RCP D No. 1 seal leakoff flow computer point RO DISPLAY "RCP Status" NSSS, picture 15. MB3B 2-10 step 2 us Verify leakage flow high indication by MB3B 2-10 observing the following indications:

step 3 0 Seal injection flow 0 Affected RCO # I seal inlet temperatures 0 VCT level 0 Charging header flow 0 Pressurizer level 3CHS-FR 158 and 3CHS-FR 160, high range RCP No. 1 seal leakoff flow recorders (MB3) 0 3CHS-PI 124, excess L/D Hx outlet pressure The first time through the table Step 8 Using Table 1, EVALUATE plant conditions MB3B 2-10 is applicable. The leak will progress for the affected RCP, and Go To indicated to a point to where step 7 then step 6 Step. step 4 will apply.

Page 26 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard

/I I

RCP No. 1 Seal Leakoff I

RCP No. 2 Seal Leakoff Hi Alarm I

No. 1 Seal Inlet TemDeratures I

Reactor Power 1

Lit Increasing or > P-8 (37%) 5.

>23OoF < P-8 (37%) 6.

Stable 7.

Page 27 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Inst ructor Inf o rmationlActivity Assign Expected Action Standard CREW PERFORM the following: MB3B 2-10 step 8 SSI us NOTIFY OMOC (Duty Officer) of alarm MB3B 2-10 condition.

step 8.1 us IF VCT TEMP HI (MB3A 5-1 0) is lit, refer MB3B 2-10 E OP 3353.MB3A 5-10, VCT TEMP HI. step 8.2 SSI us REQUEST Engineering Department MB3B 2-10 evaluate continued pump operation.

step 8.3 us -

IF, at any time, affected RCP no. 1 seal MB3B 2-10 parameters degrade, IMPLEMENT steps as specified in Table 1. step 8.4 us -

IF total seal return flow from all four RCPs MB3B 2-10 exceeds 16 gpm, Refer To 3TRM-7.4.1, Fire Related Safe Shutdown Components, and step 9 PERFORM required ACTIONS.

Step 9 @ 8% should correlate to a leak of 7 complete 8% gpm. If needed slowly adjust the leakage to 6.5 gpm to align the leakage with the need to perform step 7 CREW PERFORM the following to removed MB3B 2-10 affected RCP from service within 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />s:

step 7 CREW IF reactor power is greater than 25%, Refer MB3B 2-10 E OP 3204, At Power Operation, and step 7.1 COMMENCE an orderly plant shutdown Page 28 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard while continuing with this step.

Once the crew makes a decision to CREW -

IF reactor power is less than or equal to MB3B 2-10 commence a shutdown, Make the 25%, refer to OP 3206, "Plant Shutdown,"

and COMMENCE an orderly plant shutdown step 7.2 leak worse to the point that the crew will need to implement step 6 while continuing with this step.

and remove the RCP from service immediately.

CREW -

IF, at any time, RCP No. 1 seal parameters MB3B 2-10 degrade, IMPLEMENT steps as specified in Table 1. step 7.3 CREW WHEN in MODE 3, refer to OP 3301D, MB3B 2-10 "Reactor Coolant Pump Operation", and STOP the affected reactor coolant pump. step 7.4 T= Decision CV13A @ 20% should correlate to a leak of 20% on a -10gpm. If needed slowly adjust the to shutdown 30 sec leakage to >IO gpm to align the made ramp leakage with the need to perform step 6 us Go to AOP 3554, "RCP Trip or Stopping an MB3B 2-10 RCP at Power," and INITIATE actions to perform an immediate RCP shutdown. step 6 AOP 3554 ACTIONS (rev 008-00) RO Check RCP Status - A L L PUMPS AOP 3554 RUNNING Step 1 us Check Reactor Power AOP 3554 Step 2 RO Verify THREE LOOP PERMISSIVE P-8 AOP 3554 Page 29 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDA/MaIf Inst ruct or Inf ormat ionlAct ivity Assign Expected Action Standard annunciator (MB4D 3-3) - LIT. Step 2.a CREW If stopping the RCP due to No. 1 seal failure, AOP 3554 steps 3 through 5 should be completed as Step 3 quickly as possible in order to isolate the NOTE affected pump No. 1 seal within the recommended 5 minutes.

While removing the RCP from service, it is AOP 3554 desirable to maintain feedwater flow to the Step 3 affected steam generator, to ensure that the NOTE reactor does not trip on low-low steam generator level from the shrink that will occur. Approximately 0.5 MPPH excess flow is sufficient. Feedwater flow to the affected steam generator should be stopped once shrink has stopped.

BOP Feed Affected Loop SG NR Level to AOP 3554 Between 65% and 70% Step 3 RO Defeat Affected Loops Temperature Input AOP 3554 Step 4 Loop 1 Place loop temperature cutout switch for AT AOP 3554 to the affected loop and pull out. Step 4.a Loop 1 Place loop temperature cutout switch for AOP 3554 Tavg to the affected loop and pull out. Step 4. b Loop 2, 3 , 4 Place OT/OP AT recorder select switch to AOP 3554 an unaffected loop. Step 4.c us Remove Affected RCP From Service AOP 3554 Step 5 RO Check RCP status -ALL PUMPS RUNNING. AOP 3554 Page 30 of 59

SECl I ~ 4N Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard Step 5.a us Check the following conditions: AOP 3554 Step 5.b BOP Affected SG NR level - GREATER THAN 65%.

RO THREE LOOP PERMISSIVE P-8 annunciator (MB4D 3-3) - LIT us Return to step 2. AOP 3554 Step 5.b RNO RO STOP affected RCP. AOP 3554 Step 5.c Verify affected S/G level- STABLE AOP 3554 Step 5.d Stop feeding the affected S/G AOP 3554 Step 5.e RO Check RCP 1 and 2 - BOTH RUNNING. AOP 3554 Step 5.f loop 1 Spray to manual and close RO Place affected PZR Spray Controller in AOP 3554 manual and CLOSE spray valve. Step 5.f RNO us Check if RCP Seal Leakoff should be AOP 3554 isolated Step 6 us Verify RCP - STOPPED AS A RESULT OF AOP 3554 SEAL FAILURE REQUIRING I M M E D I A E Step 6.a SHUTDOWN Page 31 of 59

SECTiuN 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDAlMa If Instructor ,,iformation/Activity Assign Expected Action Standard RO Verify the affected RCP has been tripped - AOP 3554 AT LEAST 3 minutes Step 6.b Will need to return and perform. us Proceed to step 7 and, WHEN The RCP AOP 3554 has been tripped at least 3 minutes, THEN Step 6.b, Perform step 6.c. RNO RO CLOSE the affected RCP No. 1 seal leakoff AOP 3554 isolation valve Step 6.c RO Verify affected RCP RPCCW thermal barrier AOP 3554 isolation valve - OPEN Step 6.d BOP Shift affected SG to Main Feed Bypass AOP 3554 Flow Step 7 The "A" SG feed regulating valve will BOP Close affected SG feed regulating valve. AOP 3554 already be closed. Step 7.a 3FWS-MOV35A will already be closed. BOP CLOSE affected SG FW control isolation AOP 3554 valve Step 7.b 3FWS-MOV35A 3FWS-MOV35B 3FW S-MOV35C 3FWS-MOV35D BOP Using the SG feed regulating bypass valve, AOP 3554 Maintain the affected SG level between 45% Step 7.c and 55%.

us Perform Follow-up Actions. AOP 3554 Step 8 Page 32 of 59

SECl ic>N 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard The crew should not trip bistables as this will us Using AOP 3571, Instrument Failure AOP 3554 cause a reactor trip. (An OTAT bistable was Response, Attachment A, step 6, Trip Step 8.a already tripped for the PRNl failure) Crew must the associated temperature bistables diagnose this. If they do not diagnose this then for the affected loop trip the following bistables as directed:

T+ 1 min of RXRIO6 Protection set 1 door RO Verify MB annunciators and parameters - AOP 3554 request ASEXPECTED Step 8.b RXRI 14 TRIP LoLo Tave (P-I 2) Immediately Report any unexplained or AOP 3554 unexpected conditions to the Shift Manager. Step 8.b RXRI I O TRIP Lo Tave RNO RXROI TRIP OPAT Perform the following to be in HOT AOP 3554 STANDBY (MODE 3) within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Step 8.c RXR34 TRIP C-3 1. Check reactor power - GREATER THAN 25%.

RXR31 TRIP C-4 This B/S will RXR05 TRIP OTAT Continue plant shutdown using OP AOP 3554 trip the plant 3206, Plant Shutdown. Step 8.c. 1 RXRI06 CLOSE Protection Set 2 Door RNO EVENT 6: Loss of offsite power, B Emergency Diesel Generator (EDG) fails to start.

T = AOP RSCU 5 Degraded Grid Voltage 3554 Grid voltage will increase to 372 KV (EDIO) complete over 60 seconds. Freq will increase to (EDRol) 60.1 hz.

T = 1 min after ED10 Modify to 25%, ramp 60 seconds.

Page 33 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard RSCU 5 EDROI Modify to -0.2 Will cause grid voltage to decrease to 328 KV and freq to lower to 59.8 hz.

T = 1 min after RSCU 6 Loss of Offsite Power modification (EDOI)

CV13A Increase the severity of CV13A to 100% to simulate the catastrophic failure of the seal package associated with 'A' RCP.

NOTE: US should go to "Master RO Silence" before ordering reactor trip.

E-0 (Rev. 22) STEPS Crew 0 Foldout page must be open E-0, Step 1, NOTE ADVERSE CTMT defined as GREATER THAN 180°F or GREATER THAN I O5 R/h, in containment.

0 The reactor can be interpreted as "tripped" when any two of three bulleted substeps of Step 1.* are Page 34 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard satisfied.

RO Verify Reactor Trip E-0, Step 1 Check reactor trip and bypass breakers - OPEN Rod bottom lights are out due to loss of Check rod bottom lights - LIT power.

The crew still meets two of three Check neutron flux - DECREASING Verify Turbine Trip E-0, Step 2 Check all turbine stop valves - CLOSED E-0, Step 2.a BOP Verify Power to AC Emergency Busses E-0, Step 3 The BOP should attempt a manual BOP Check busses 34C and 34D - E-0, start of the By EDG from MB8. The Step 3.a BOTH ENERGIZED B EDG will not start.

The A EDG will be exhibiting Try to energize the affected buss(es) from E-0, degraded frequency and speed. The its associated EDG. Step 3.a, US may decide to emergency shutdown RNO the EDG.

us IF power

- can NOT be restored to at least one AC emergency bus, THEN Go to ECA-0.0, Loss of Aii AC Power, Step 3. (Observe NOTE prior to step 1).

T= Step 4 of MALF NOTE: Crew may have tripped EDG us Check If SI Is Actuated E-0, Step 4 E-0 if c r e w EG07A due to abnormal operations Page 35 of 59

SECl ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard has not tripped A EDG RO Verify SAFETY INJECTION ACTUATION EOP 35 E-annunciator - (MB4D 1-6 or MB2B 5-9) - LIT 0, Step 4.a us Check if SI is required E-0, Step 4, RNO EVENT 7: A EDG Trip. Loss of all AC power.

ECA-0.0 Rev 020-01 Actions CSF Status Trees should be monitored for ECA-0.0 information only. Functional Response Step 1 procedures shall NOT be implemented while NOTE in this procedure.

RO Check If RCS Is Isolated ECA-0.0 Step 3 Verify PZR PORVs - CLOSED ECA-0.0 Step 3.a CLOSE letdown orifice isolation valves. ECA-0.0 Step 3.b Verify excess letdown and reactor head vent ECA-0.0 isolation valves - CLOSED Step 3.c BOP Verify AFW Flow To All Intact SGs - ECA-0.0 GREATER THAN 530 gpm Step 4 Page 36 of 59

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 cha 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Perform the following: ECA-0.0 Step 4.a.

Verify TD AFW pump running. RNO CRTICAL TASK - The BOP will start BOP -

IF the TD AFW pump is NOT running, the TD AFW pump by opening the THEN r1 steam supply valves ["I

1) Using Attachment J locally Reset the turbine trip valve as necessary.

BOP 2) OPEN steam supply valves BOP Verify the TD AFW flow control valves are ECA-0.0 open. Step 4.b.

RNO IF the valves are NOT open, THEN OPEN the TD AFW pump flow control valves.

If power is NOT restored to Bus 34C within ECA-0.0 30 minutes, Inverter 6 de-energizes and the Step 5 process computer will be unavailable. Use CAUTION GA-12 as required to determine core cooling parameters.

Try To Restore Power To Any AC ECA-0.0 Emergency Bus Step 5 NOTE>> If called, as IS0 NE/CONVEX report BOP START at least one EDG (MB8) ECA-0.0 that the there has been a partial Step 5.a blackout of most northeast grid regions. Time to restoration Page 37 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard unknown.

Proceed to step 5.e ECA-0.0 Step 5.a RNO BOP Check offsite power - AVAILABLE ECA-0.0 Step 5.e us Proceed to CAUTION prior to step 6 and, ECA-0.0 Step 5.e IF offsite

- power becomes available, THEN RNO Using GA-3, Energize the AC emergency bus through the RSST or the NSST.

Maintain one service water pump ECA-0.0 available to automatically load on its AC Step 6 emergency bus to provide emergency CAUTION diesel generator cooling.

If a SI signal is actuated during this procedure, it must be reset to permit manual loading of equipment on an AC emergency bus.

Spurious fire alarms may occur in areas where the temperatures exceed 12OoF due to a loss of ventilation. The locking out of C02 protected areas which have spurious fire alarms is recommended.

0 When power is restored to any AC ECA-0.0 emergency bus from offsite or an Step 6 Page 38 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDAlMalf Inst ru c to r I nf ormat i onlAct ivity Assign Expected Action Standard emergency diesel generator, recovery NOTE actions should continue starting with Step 26.

ADVERSE CTMT is defined as Ctmt temperature GREATER THAN 180°F or Ctmt radiation level GREATER THAN I05R/hr.

Block Automatic Loading Of AC ECA-0.0 Emergency Busses Step 6 RESET the following if necessary ECA-0.0 Step 6.a RO SI BOP Aux FW Train A for Lo-Lo SG Level BOP Aux FW Train B for Lo-Lo SG Level Place Following Control Switches In PULL- ECA-0.0 TO-LOCK Step 6.b RO . Charging pumps T=Service SWOIB or For the Service Water Pump left in One service water pump per train (follow Water Pump SWOID condition t o Auto Start [not in PTL] pumps preferred) in PTL INSERT THE APPLICABLE TRIP.

The goal is to have the RO need to manually start the pump that is currently in PTL.

0 RPCCWpumps Quench spray pumps Page 39 of 59

SEC IION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Recirculation spray pumps SI pumps RHRpumps BOP MDAFWpumps CARfans 0 Control Building HVAC chillers CRDM cooling fans Auxiliary Building filter exhaust fans 0 SLCRSfans Place CHG & CCW PP area supply fans in ECA-0.0 OFF Step 6.c Locally Attempt To Restore AC Power ECA-0.0 Step 7 BOP Verify emergency diesel generators - AT ECA-0.0 LEAST ONE RUNNING Step 7.a Perform the following: ECA-0.0 Step 7.a RNO USlPEO Using Attachment E, Locally Start both EDGs.

us Proceed to step 8 and, IF an EDG starts, Page 40 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Inst ructor I nformat io n/Act iv ity Assign Expected Action Standard THEN Perform steps 7.b and 7 c BOP Check emergency bus 34C or 34D - ECA-0.0 AUTOMATICALLY ENERGIZED Step 7.b us Proceed to step 26. ECA-0.0 Step 7.c US/PEO Isolate RCP Seals ECA-0.0 Step 8

a. Locally Close the following valves:

T=7 minutes CVR 94 to CLOSE 1) RCP seal water return Ctmt outer from isolation valve (3CHS*MV8100) dispatching PEO

2) All RCP seal supply isolation valves:

CVR 90 to CLOSE 3CHS*MV8109A CVR 91 to CLOSE 3CHS*MV8109B CVR 92 to CLOSE 3CHS*MV8109C CVR 93 to CLOSE 3CHS*MV8109D

3) RPCCW Ctmt return outer isolation valves:

Page 41 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard CCR 47 to CLOSE 3CCP*MOV49A CCR 48 to CLOSE 3CCP*MOV49B PEO Open Instrument Rack Room Cabinet ECA-0.0 Doors Using Attachment B. Step 9 The US may decide to align the SBO to The SBO diesel may be aligned to either bus ECA-0.0 either Train A or B. pair 34A and 34C or 34B and 34D. The Step 10 preferred bus pair is 34A and 34C. NOTE Energize Any AC Emergency Bus From ECA-0.0 The SBO Diesel Step 10 BOP OPEN all SBO bus tie breakers: ECA-0.0 Step 10.a For Bus 34A : 34A 1-2 For Bus 34B : 34B 1-2 us For Bus 34E: A505 (Unit 2)

T=5 EDR33 to Operates SBO Synch Check US/PEO Using Attachment G locally Start SBO ECA-0.0 minutes ON diesel. Step 10.b from being dispatched T=7 EGR08 to Starts SBO Diesel US/PEO Locally Align the selected AC bus pair using ECA-0.0 minutes START one of the following attachments: Step 1O.c from being For Busses 34A and 34C:

dispatched Attachment H Page 42 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard For Busses 34B and 34D:

Attachment I T = When EDR32 to Closes SBO Output Breaker BOP OPEN the following breakers: ECA-0.0 directed CLOSE Step 10.d EDG supply breaker for selected emergency ECA-0.0 AC bus Step 10.d.l For Bus 34C:

DGA*34C-2 For Bus 34D:

DGB*34D-2 NSST feeder breaker for selected non- ECA-0.0 emergency AC bus Step 10.d.2 For Bus 34A:

NSSA-34A-2 For Bus 34B:

NSSA-34B-2 Close SBO diesel output breaker as follows: ECA-0.0 Step 10.e us 1. Verify local start of SBO diesel (Using Attachment G) -

COMPLETED 1j Proceed to NOTE prior to ECA-0.0 step 11 and, Step 10.e RNO WHEN Page 43 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Inst ructo r Inf ormat io n/Act iv ity Assign Expected Action Standard Attachment G completed, THEN Continue with step 10.e thru 10.q.

PEO 1. Locally Close SBO diesel output breaker BOP OPEN the following load center supply ECA-0.0 breakers for the selected non-emergency Step 10.f AC bus:

For Bus 34A:

32A 32A-2 AND 32A-XFMR-2 32B 32B-2 AND 32B-XFMR-2 32C 32C-2 AND 32C-XFMR-2 32D 32D-2 AND 32D-XFMR-2 32 E 32E-2 AND 32E-XFMR-2 32F 32F-2 AND 32F-XFMR-2 32G 326-2 AND 32G-XFMR-2 For Bus 34B:

32H 32H-2 AND 32H-XFMR-2 32J 32J-2 AND 32J-XFMR-2 32K 32K-2 AND 32K-XFMR-2 32L 32L-2 AND 32L-XFMR-2 Page 44 of 59

SEC [ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 cha 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard 32M 32M-2 AND 32M-XFMR-2 32N 32N-2 AND 32N-XFMR-2 32P 32P-2 AND 32P-XFMR-2 32Q 32Q-2 AND 32Q-XFMR-2 Align the selected non-emergency AC bus ECA-0.0 Step 10.g T=5 EGR08 to Stops SBO Diesel BOP 1. Place the following switches in Pull-minutes STOP TO-LOCK from SBO being started T = 1 minute Report as the PEO at the SBO that Screen wash pump from SBO the SBO tripped on Generator being Ground Fault. Engine Shutdown stopped is also in.

Circulating water pumps TPCCW pump(s)

BOP 2. Place the following switches to STOP:

CDS chiller(s)

Heater drain pump(s)

MSR drain pump us Verify local alignment of selected busses ECA-0.0 (Using Attachment H or I) - COMPLETED Step 10.h Page 45 of 59

SEC; I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 1 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard T = +5 min of EGR07 Clear EDG B Local Panel Trouble us Proceed to NOTE prior to step 11 and, ECA-0.0 being WHEN Step 10h dispatched RNO Attachment H or I completed, THEN Continue with step 10.h through 10.q.

T = +9 min of EGROII EDG B Local Control Place the remaining service water pump on ECA-0.0 being the selected emergency bus in PULL-TO- Step 10.i dispatched LOCK.

T = + I 1 min EGR14 EDG "Bl' Output Breaker to LOCAL Reset the undervoltage block for the ECA-0.0 of being Contro I selected emergency bus Step l0.j dispatched Remove Malfunction EGO6B (allows REMOVE auto start of EDG)

EGO6B Call as PEO. Inform SMlUS that local start of the "B" EDG is completed and the EDG output breaker automatically closed in on the emergency bus. No apparent reason the B EDG would not start automatically.

NOTE: Once the 'B' EDG is started 1. Verify annunciator and closed in to bus 34D, the US For Bus 34C:

should proceed to step 26.

BUS 34C UNDERVOLTAGE (MB8A 3-

12) - NOT LIT For Bus 34D:

BUS 34D UNDERVOLTAGE (MB8C 3-2)

Page 46 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard

- NOT LIT

2. Press undervoltage block BYPASS pushbutton (MB8R)

RESET LOP (MB2) for the selected train ECA-0.0 Step 10.k CLOSE SBO bus tie breaker (MB8) for ECA-0.0 selected non-emergency AC bus Step 10.1 For Bus 34A: 34A1-2 For Bus 34B: 34B1-2 Place the synchronizing selector to ON for ECA-0.0 the selected emergency and non-emergency Step 10.m busses For Bus 34A and 34C:

SYNC SEL 34A-34C Tie For Bus 34B and 34D:

SYNC SEL 34D-34B Tie CLOSE the bus tie breaker between the ECA-0.0 selected emergency and non-emergency Step 10.n busses For 34A and 34C: 34C*IT-2 For 34B and 34D: 34D*IT-2 Place the synchronizing selector to OFF for ECA-0.0 the selected AC bus pair Step 10.0 For Bus 34A and 34C:

SYNC SEL 34A-34C Tie Page 47 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 cha 1 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard For Bus 34B and 34D:

SYNC SEL 34D-34B Tie Check any AC emergency bus - ECA-0.0 ENERGIZED Step 1O.p us Proceed to NOTE prior to step 11. ECA-0.0 Step 1O.p RNO Go to ECA - 0.3, Loss of All AC Power - ECA-0.0 Recovery With The SBO Diesel Step 10.q The Note prior to Step 6 directs continuing recovery actions at Step 26 when power is restored to any N C emergency bus.

Stabilize SG Pressures. ECA-0.0 Step 26 SG pressures may not need to be BOP Adjust the following : ECA-0.0 stabilized in that the depressurization Step 26.a has not been started. 0 SG atmospheric dump valves OR 0 SG atmospheric dump bypass valves.

Verify Service Water System Operation ECA-0.0 For Each Energized Emergency Bus. Step 27 RO RESET LOP, if required. ECA-0.0 Step 27.a Page 48 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDNMalf I nst ructo r In I 3 rmat ion/Act ivity Assign Expected Action Standard RO Check diesel generator heat exchanger SW ECA-0.0 outlet isolation valves - OPEN. Step 27.b 0 3SWP*AOV39A 0 3SWP*AOV39B RO Check service water pumps - ONE PER ECA-0.0 TRAIN RUNNING. Step 27.c CRITICAL TASK - r] RO START one pump per train. ECA-0.0 Step 27.c RNO [I RO Place service water pumps in PULL-TO- ECA-0.0 LOCK to AUTO. Step 27.d RO Check service water pump discharge valves ECA-0.0

- OPEN FOR RUNNING PUMPS Step 27.e For pump A (3SWP*MOV102A)

For pump B (3SWP*MOV102B)

For pump C (3SWP*MOV102C)

For pump D (3SWP*MOV102D)

T=5 SWR25 to Closes 3SWP*MOV71A RO Check TPCCW heat exchanger SW supply ECA-0.0 minutes 0 isolation valves - CLOSED. Step 27.f from being 3SWP*MOV71A dispatched 3SWP*MOV71B PEO CLOSE valves. ECA-0.0 Step 27.f Page 49 of 59

SEC (ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDAlMaIf I nst ructor Inf ormat ion/Act ivity Assign Expected Action Standard RNO When placing loads on an energized ECA-0.0 emergency bus, DO NOT exceed the Step 28 capacity of the power source. CAUTION Perform the Following For Each ECA-0.0 Energized AC Emergency Bus: Step 28 BOP Verify the following equipment is energized: ECA-0.0 Step 28.a 0 480 volt emergency busses 0 Battery chargers USlPEO Energize previously de-energized DC loads ECA-0.0 (Attachment A). Step 28.b Perform the following to energize MCC 32- ECA-0.0 3T: Step 28.c BOP 1. Verify Bus 34C - ENERGIZED us Proceed to step 28.d and, ECA-0.0 Step 28.c. 1 WHEN RNO Power is restored to bus 34C, THEN Perform step 28,s Verify communications console - ECA-0.0 ENERGIZED. Step 28.d Page 50 of 59

SEC I ION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 1 Task Time IDA/Malf Instructor Information/Activity Assign Expected Action Standard If RCP seal cooling was previously isolated, ECA-0.0 further cooling of the RCP seals will be Step 29 performed by RCS natural circulation NOTE cooldown as directed in subsequent procedures.

Select Recovery Procedure. ECA-0.0 Step 29 RO Check RCS subcooling based on core exit ECA-0.0 TCS - GREATER THAN 32°F (1 15°F Step 29.a ADVERSE CTMT)

Go to ECA - 0.2, Loss of All AC Power ECA-0.0 Recovery With SI Required. Step 29.a RNO PZR level will be less than 16%. RO Check PZR level - GREATER THAN 16% ECA-0.0 (50% ADVERSE CTMT). Step 29.b us Go to ECA - 0.2, Loss of All AC Power ECA-0.0 Recovery With SI Required. Step 29.b RNO Check SI equipment NOT actuated ECA-0.0 Step 29.c Verify SI pumps - STOPPED Verify RHR pumps - NOT RUNNING IN SI MODE Verify charging pump cold leg injection valves - CLOSED The US should announce the transition Go to ECA-0.2, Loss of All AC Power ECA-0.0 to ECA-0.2. Recovery With SI Required. Step 29.c Page 51 of 59

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-I

SECTION 4 Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 2 EVALUATION GUIDE I. Crew FOLLOW-UP QUESTIONS

1. What is the Emergency Classification for this event?

Site Area Emergency - Charlie Two, Loss of Voltage on Buses 3 4 C and 34D > 15 minutes (EAL PSI).

2.

Page 53 of 59

SECTION 4 EXAM GUIDE

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 cha 2 II. Critical Tasks Note: Critical Tasks are not required for Progress Review Exams.

TASK DESCRIPTION TASK # KIA >I= 3.0 1

BASIS SELECTION Establish 530 gpm AFW ECA-0.0--B 061-000 Failure to establish the flow to the SIGs prior to A2.02 minimum requrred AFW flow the completion of step 4 3.213.6 rate, under the postulated of ECA-0.0 plant conditions, results in adverse consequence(s) or a significant degradation in the mitigative capability of the plant.

Isolate RCP Seal ECA-0.0-H 003-000 Failure to isolate RCP seal Injection before a A4.01 injection before starting a Charging Pump starts 3.313.2 charging pump, under the or is started postulated plant conditions, can result in unnecessary and avoidable degradation of the RCS fission-product barrier, specifically at the point of the RCP seals, especially if RCPs are subsequently started.

Manually start the SW ECA-0.0 -- 076-A2.01 Failure to restore SW flow pump and verify SW F 3.513.7 means that the EDG is flowpath before running without SW cooling completing step 27 of which leads engine ECA-0.0 such that the overheating. Failure to EDG does not fail perform the critical task because of damage constitutes mis-operation caused by engine or incorrect crew overheating. performance that leads to degraded emergency power capacity .

Note: [*I Used to designate critical tasks. Should also be incorporated into column 3 or 4 of Instructor Guide.

Page 54 of 59

SHIFT TURNOVER REPORT DATE-TIME PREPARED BY today 0300 Unit Supervisor /Night Shift PLANT STATUS:

Mode: 1 RxPower: 3%

Megawatts: Thermal: 0 MWth PZR Pressure: 2250 psia Electric: 0 MWe RCS T-AVE: 557 degF RCS Leakage: Identified: 0.005gpm Boron/Burnup 2032 ppm / 0 MWD/MTU Unidentified: U g p m Dayson line 0 Date/Time: todav 0015 Protected TraidFacility: B Purple PRNSDR: Green Intake: Green Active Tracking Records and Action Statements EauiDment/Reason LCO Action Date Time in LCO Action Requirement I Time Left I OD Compensatory Actions / Temp Logs Open Date 1 Class Reason I Reason I Watch Position Plant Systems APC Notes System Cross Unit System Status I I Surveillances I Evolutions in Progress I I I Shift Orders Reactor power is stable low in the power range (reactor power 3%), following a reactor startup by the previous shift. This is the initial plant startup from a refueling outage. OP 3203, Plant Startup is in progress and complete up through step 4.2.7. The crew is to raise reactor power from 3% to 6 to 9% in accordance with step 4.2.8. Feed Control is on the FRV Bypass Valves in automatic, with the ATD MFP in service.

I I Page 55 of 59

ATTACHMENT 2 VALIDATION CHECKLIST

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chg 2 Verified By:

(I nitiaIs)

Initial Conditions:

The initial condition(s) contained in the guide are certified or have been DM developed from certified ICs.

Test Run:

The scenario contained in the guide has been test run in part or whole on the simulator. The simulator response is reasonable and as expected. If a simulator guide revision does not affect original Test Run, then enter NIA.

Simulator Operating Limits:

The simulator guide has been evaluated for operating limits and/or anomalous response by reviewing the Simulator Modeling and Anomalous Response List.

For Ex rio:

D. L. Minnich 1124107 Actions Complete (Signature) Date Page 56 of 59

Appendix D Scenario Outline Form E S - D -

-1 Facility: Millstone 3 Scenario No.: 2K7 NRC-03 (spare) Op-Test No.: 2K7 Examiners: Operators:

Initial Conditions: IC-07 (modified), 3% power, Beginning of Life, No Xe.

Turnover:

The crew will take the shift with reactor power stable and low in the power range (reactor power 3%), following a reactor startup by the previous shift. This is the initial plant startup from a refueling outage. OP 3203, Plant Startup is in progress.

Event Event No. Description Power ascension from 3% to 8% power using OP 3203, R (SRO) Plant Startup.

Running RPCCW pump trip. Alignment and start of the standby RPCCW pump.

3 Small leak develops through pressurizer PORV, 3RCS*PCV455A.

---I---

7 N109C I (BOP)

N (BOP)

Power Range Nuclear Instrument (NI) Channel 43 Lower Detector fails high requiring FRV Bypass valve controllers to be placed in manual.

A RCP #I seal degradation resulting in high RCP seal leakoff. RCP is tripped using AOP 3554, RCP Trip or Removing a RCP from Service At Power.

I 6 M (ALL) Loss of offsite power, B Emergency Diesel Generator EGO6B (EDG) fails to automatically or manually start from the EDol control room.

7 EG08A C(B0P) AEDG trips resulting in a loss of all AC power. TDAFW EG07A C(R0) pump fails to auto-stah. B EDG is started locally. B FW2OC service water pumps fail to auto-start after B EDG is successfuIIy st arted locaIIy .

• N)ormal., (R)eactivitv.

\ I , (I)nstrument, (C)omponent, (M)ajor Page 57 of 59

Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 chq 2 Assessor: Dave Minnich QUALITATIVE ATTRIBUTES

-Y-I. The initial conditions are realistic, in that some equipment and/or instrumentation may be out of service, but it does not cue the crew into expected events.

The scenario consists mostly of related events.

Each event description consists of:

- the point in the scenario when it is to be initiated

- the malfunctions(s) that are entered to initiate the event

- the symptomslcues that will be visible to the crew

- the expected operator actions (by shift position)

- the event termination point (if applicable)

-Y 4 . No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario without a credible preceding incident such as a seismic event.

The events are valid with regard to physics and thermodynamics.

Sequencing/timing of events is reasonable, and allows for the examination team to obtain complete evaluation results commensurate with the scenario objectives.

-N/A-7. If time compression techniques are used, scenario summary clearly so indicates. Operators have sufficient time to carry out expected activities without undue time constraints. Cues are given.

Y 8. The simulator modeling is not altered.

_ .Y-9. The scenario has been validated. Pursuant to 10 CFR 55.46(d), any open simulator performance deficiencies or deviations from the referenced plant have been evaluated to ensure functional fidelity is maintained while running the planned scenario.

-Y-I 0. Every operator will be evaluated using at least one new or significantly modified scenario. All other scenarios have been altered IAW Section D.5 of ES-301.

All individual operator competencies can be evaluated, as verified using form ES-301-6.

Each operator will be significantly involved in the minimum number of transients and events specified on Form ES-301-5.

-Y-13. Level of difficulty is appropriate to support licensing decisions for each crew position.

Page 58 of 59

Lesson

Title:

Loss of All AC Power ID Number: 2K7 NRC-03 Revision: 0 Chanqe 1-Note: Following criteria list scenario traits that are numerical (QUANTITATIVE) in nature.

01. Total Malfunctions (TM) - 5 to 8 required Total 8 (1) RPCCW Pump Trip, (2) PORV Leak, (3) PRNl Channel Failure, (4) RCP Seal Failure, (5)

Loss of Offsite Power, (6) TDAFW Pump Fails to Auto Start, (7) EDG Faults, (8) Service Water Pump Failure

02. Malfunctions after EOP entry (EMS)- 1 to 2 required Total 3 (1) TDAFW Pump Fails to Auto Start, (2) EDG Faults, (3) Service Water Pump Failure

03. Abnormal Events (AE) - 2 to 4 required Total 4 (1) RPCCW Pump Trip (AOP 3561), (2) PORV Leak (ARP MB4A), (3) PRNl Channel Failure (AOP 3571), (4) RCP Seal Failure/RCP Trip (AOP 3554)

04. Major Transients (MT) - 1 to 2 required Total 1 (1) Loss of All AC Power

05. EOPs (EU) enteredlrequiring substantive actions -- 1 to 2 required Total 1 (1) ECA-0.0

06. EOP Contingencies requiring substantive actions [ECAs/FRs/] (EC) -- Total 1 0 to 2 required (1) ECA-0.0

07. Critical Tasks (CT) - 2 to 3 required Total 3 ECA-0.043 Establish 530 gpm AFW flow to the SGs prior to completion of step 4 of ECA-0.0 ECA-0.0 -H Isolate RCP seal injection before a charging pump starts or is started.

ECA-0.0 -F Manually start the service water pump and verify a flowpath before completing step 27 of ECA-0.0.

08. Approximate Scenario Run Time: 60 to 90 min. Total 120 min

09. EOP run time: Total 45 min IO. Technical Specifications are exercised during the scenario. (Y/N)-Y-Page 59 of 59