ML070810696

Draft - Section C Operating Exam (Folder 2)

ML070810696
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Site:	Millstone
Issue date:	01/09/2007
From:	Minnich D Dominion Nuclear Connecticut
To:	Silk D M Operations Branch I
Sykes, Marvin D.
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h/ MILLSTONE POWER STATION SIMULATOR EXAM GUIDE APPROVAL SHEET Exam Title: Large Break LOCA 'L' Revision : 0 ID Number: 2K7 NRC-01 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. 1/11/07 Date Submitted by: 0. Minnich Developer - Date Validated by:

Tech nica I Reviewer t 114 (07 Date Approved by: Training Supervisor STOP THINK ACT REVIEW SECTION 2 SIMULATOR EXAM GUIDE TABLE OF CONTENTS SECTIONS LISTED IN ORDER 1. CoverPage

2. Table of Contents 3. Exercise/Exam Overview 4. Exam Guide L-' Attachments: - Shift Turnover Report - Validation Checklist - Scenario Outline (ES-D-1) - Attributes Checklist - Summary of Changes Page 2 of 82 SECTION 3 EXAM OVERVIEW Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision: - 0 1. 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 instrument 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. Once actions as specified in AOP 3571 are complete, the Digital Rod Position Indication system will develop a Data B failure on rod M4. AOP 3552, Malfunction of fhe Rod Drive System, will be used by the crew to mitigate the event. 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]. 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 Coolanf, 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.1, Response to high CTMT Pressure.

CDA Train "A" & "Bl' will fail to The Session will begin with the plant at 100% power and at end of life.

The "A EDG is out -----l When AOP 3552 actions are complete, the crew will experience a Loss of 125 Volt DC \--* Page 3 of 82 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 switches on MB2. The RHR pumps will start and provide flow. Once FR-Z.l is complete, the crew transitions back to E-?, the session can be terminated.

'4 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 4 of 82 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. "Review the Simulator Operating Limits (design limits of plant) and the Simulator Modeling Limitations and Anomalous Response List prior to performing this exam scenario on the Simulator.

The evaluators should be aware if any of these limitations may be exceeded." (NSEM 6.06) Page 5 of 82

.I -- 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 lnstructors 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 fauit, etc.) the Instructor should: I. 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 possibte 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 6 of 82 I 4- I Lesson Title:

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

0 1, START the Sun Workstation.

a. PLACE Recorder Power to ON. VERIFY that the current approved training load is loaded. REMOVE the step counter OVERRIDE and allow the counters to step out during the IC reset. RESET to IC XX (Based on IC 21) 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.

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

2. 3. 4. 5. 6. 7. PLACE Simulator to RUN. I 8. 9. If Necessary, RESET the Plant Calorimetric at the Instructor Station PPC by Pressing "SHIFT LEFT and "F6" simultaneously.

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 Garnmametrics (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. As needed, RESET Computer Terminals to At Power displays if 100% power IC. RESET Rad Monitor Screen to Status Grid. IO. 1 I. Page 7 of 82 I (. SEC't ,~PJ 4 ( Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 INITIAL SETUP INSTRUCTIONS IF placing equipment OOS, THEN perform the necessary switch manipulations and hang appropriate tags, as required, listed under "Equipment 00s." Ensure that the protected train and environmental placards are appropriately hung. 12. 13, 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 TapelCD 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 ME36 PLACE THE "B" TRAIN PROTECTED PLACARD ON ME34 Page 8 of 82 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 TYPE I Name MALF I FW2OA SE&I dN 4 Sev. Ramp I RSCU Boul I Description I "A" MDAFW pump fails to auto-start Revision:

0 MALF MALF MALF MALF MALF INITIAL SETUP INSTRUCTIONS FWZOB FW2OC RPO6A RPO6B RP07A "B" MDAFW pump fails to auto-start TD AFW pump fails to auto-start Failure of CDA (train A) to auto actuate Failure of CDA (train B) to auto actuate "A" Train Safety Injection fails to auto-actuate.

MALF MALF MALF MALF MALF TPOPC MS05B 80% 240 1 Tube Leak

'B' MSR RX1 OA 61.2% 2 3RCS*L459 fails as is RXI 4G 0% 3 "D" SG steam flow fails low (3MSS-FT542)

RDI 160 "C" TPCCW Pump fails to auto-start 4 Rod position indication failure, Data B (rod M4) MALF I RP07B I I I I I "6" Train Safety Injection fails to auto-actuate.

MALF I RC02C 1 0.15 I 60 MALF 1 EGO7A I I I I I EDG "A" Trip I BTI I Small break LOCA in CTMT (Loop 3 Hot Leg) I/O (EG) I/O (EG) I/O (EG) I/O (EG) MALF 1 EDOSD I I 151 I Loss of Battery Bus 4 - - - D/GABKRCNTL - - - D/GABKRCNTL lA3ENSACB-A-RED OFF 1A-3ENSACB-A-AMBER OFF 1-3EGO-P1A RED OFF D/G A Prelube Pump 1-3EGO-P1A GREEN OFF D/G A Prelube Pump I 100% I 161 I RPCCW leak into upper oil reservoir of 'Cy RCP I/O(EG) IlA3ENSACB-AGREEN I OFF I - I - I - I D/GABKRCNTL Page 9 of 82 i SECi.,r\l4 I/O(RP) I/O(Rp) Lesson Title:

ID Number: 3ADS-CDA PB1 OFF - - - CDA PBs fail to actuate CDA 3ADS-CDA PB2 OFF - - - Large Break LOCA 2K7 NRC-01 I/O (RP) Ann O/R Revision:

Q INITIAL SETUP INSTRUCTIONS 3ADS-CDA PI34 OFF MBSA 2-11 ON 34C Loss of Control Power I I/O (RP) I 3ADS-CDA PB3 I OFF I I I I I Page IO of 82

(\ Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 i SECTILI\I 4 Revision:

0 INITIAL SETUP INSTRUCTIONS Lead Examiner: Refer to the "Briefing Script for the Operational Exam" and brief the crew. Go over the Pla nt/sim ula tor differences, which follow. Commence recording Simulator Session 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. Booth instructor:

Booth Instructor: 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

1. 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 11 of 82 SEC?ld4 r: Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard EVENT I: Tube leak in 'B' MSR. T = I minute RSCU I (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 I 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 12 of 82 SEO, .JN 4 c Lesson Title:

Large Break LOCA Revision:

0 ID Number: 2K7 NRC-01 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard 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) The BOP will be expected to call up the BOP tube leak disdav on DCS for the "6" Identify MSR Tube Leaks Reheat steam flow during start of the reheaters is a function of many factors other than tube leaks. Reheat steam control valve position, reheat drain flow to the main 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 than 2.5% above the baseline curve on Attachments 3 through 8 is an indication of a tube leak. Attachment 3 through 8 are for use during steady state operation.

Limits on the graphs are expected to be exceeded during transients. PERFORM one of the following, as applicable:

Section 4.14 4.14.1 NOTE 4.14.1 NOTE 4.14.1 NOTE 4.14.1 I. Page 13 of 82 SEC? IJN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

Q Task instructor InformationlActivity Assign Expected Action Standard Time IDNMalf MSR Refer To MSR Leak Detection" displays on the Foxboro Digital Control System and IDENTIFY MSR tube leaks. 0 PERFORM the following (computer):

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

Refer To Attachments 6 through 8 and COMPARE MSS-F38B steam flow with CRS-PZ4B cross-around pressure.

MONITOR associated MSR drain tank level to ensure the Level Control System has not failed causing excessive steam flow through the high level dump.to the condenser.

4.14.2 The "B" MSR drain tank level will be normal. BOP The US should inform RE that steam flow verses cross-around pressure is greater than 5% above the baseline For "B". MSR. All turbine CIV valves are open.

US should go to Section 4.1 1 to remove MSR reheaters from service. IF the steam flow verses cross-around pressure plot is greater than 2.5% above the baseline curve on Attachments.

3 through 8, NOTIFY the Reactor Engineering Department.

IF the steam flow verses cross-around pressure plot is greater than 5% above the baseline curve on Attachments 3 through 8 AND all of the turbine CIV valves are open, 4.14.3 I 4.14.4 Page 14 of 82 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Refer To Section 4.1 1 and REMOVE MSR reheaters from service. INITIATE a CR. OP 3317 Reheater and Moisture Separator, Section 4.14. (rev 014-06) Remove MSR Reheaters From Service At Turbine Load Greater Than 30% (360 MWe) US should recognize that a downpower is required to establish the plant conditions necessary to remove the reheaters from service.

It is expected that the US inform the OMOC (OPS Manager on call) that a downpower is If manual control of reheater steam supply valves is taken at a location other than the Foxboro Digital Control System operator station, constant communications with the Control Room must be established. Turbine load is limited to approximately 90% (I 080 MWe) without MSR reheaters in service due to Condensate System flowrate increase.

With Reheat Steam isolated to the MSRs, Pimp is not an accurate reflection of Reactor Thermal Power. As a result, Tref is not accurate.

IF at turbine load of 100% (1200 MWe), REDUCE turbine load by approximately 10% (1 20 MWe). 4.14.5 Step 4.1 I Step 4.1 1 .I NOTE Step 4.11.1 NOTE Step 4.1 1 .I NOTE Step 4.11.1 Page 15 of 82 SECTLi.I 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDA/Malf Instructor Information/Activity Assign Expected Action Standard required and that there is a significant tube leak in the "B" MSR. T = When crew BOOTH discusses a downpower plan Reheaters from service. Reduce Call as OMOC and direct the US conduct a rapid downpower at 1% per minute in order to remove the 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. The US will enter AOP 3575, Rapid Downpower This will fail 3RCS-L459 "as is T = When RSCU 2 during the downpower 3575 (RXIOA) entered Evaluator Sometime during the downpower, 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) A CONVEX requested emergency AOP 3575 generation reduction as directed by C OP 200.8, "Response to IS0 New England I Convex Emergencies and Alerts", Should Step 1 NOTE Page 16 of 82

{' 'I,, Lesson Title:

Large Break LOCA .( SECTION 4 ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard be completed within 15 minutes of notification.

Evaluator NOTE: The crew has already been directed to use a power reduction rate of 1% per minute.

CREW us us us CREW us 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 - 4 ) annunciator is received, DO NOT goto AOP 3566, Immediate Boration.

Immediately perform step 1 I. Determine Power Reduction Rate

(%lrnin).

Check desired power reduction rate - EQUAL TO OR LESS THAN 5%/min. Check power reduction - CONVEX REQUESTED Proceed to Step 1.d. Determine power reduction rate using Table. Check Rod Control In AUTO. AOP 3575 Step I AOP 3575 Step ?.a AOP 3575 Step 1.b AOP 3575 Step 1.b RNO AOP 3575 Step 1.d AOP 357'5 Page 17 of 82 I' SEC'r .A 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time I DA/Ma If instructor Information/Activity Assign Expected Action Standard CREW us us BOP BOP The US should direct the BOP to select 1% per minute.

BOP USIRO RO Step 2 Align EHC Panel AOP 3575 Step 3 Check turbine OPERATING MODE - AOP 3575 MANUAL Step 3.a Check LOAD LIMIT LIMITING light - LIT AOP 3575 Step 3.b Intermittently Press DECREASE LOAD AOP 3575 pushbutton until LOAD LIMIT LIMITING light - Step 3.c NOT LIT 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 Select LOAD RATE LIMIT % MIN to required AOP 3575 power reduction rate

(% 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 I. NOTE Verify Power Reduction Rate AOP 3575 Step 4 Check power reduction rate 5% MIN AOP 3575 Step 4.a Perform the applicable action: AOP 3575 Step 4.a Page 18 of 82 Lesson Title: Large Break LOCA / SECTlbd 4 i ID Number: 2K7 NRC-01 Revision:

0 Task Time IDA/Malf Instructor Information/Activity Assign Expected Action Standard RNO 0 - IF power reduction rate is 3% min, THEN The US will proceed to step 6. us US / RO should determine a boric acid addition of 15% x 24(gal/%)

= =gal. US/RO RO us RO Proceed to step 5. 0 power reduction rate is LESS THAN 3% min, THEN Proceed to NOTE prior step 6. Align RCS Makeup System For Boration Check Rod Control - AVAILABLE FOR ROD INSERTION Step 6.a Determine required boric acid addition by AOP 3575 multiplying total power change (A%) by Step 6.b 24(gal/%)

= gal. Set the boric acid batch counter to the AOP 3575 required gallons of boric acid determined in Step 6.c step 6.b. Check power reduction rate-0.5%/min.

AOP 3575 Step 6.d Adjust boric acid blend flow controller pot AOP 3575 setting to the appropriate setpoint and Step 6.d Proceed to step 6.f.: RNO AOP 3575 Step 6 AOP 3575 Page 19 of 82 Lesson Title: Large Break LOCA SECTlud 4 ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard The RO should set the boric acid blend flow controller pot to 7.5. 0 rods available - 7.5 (30 gpm) 0 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 AOP 3575 Step 6.j Adjust Pzr Spray Valves to 50% setpoint RCS-PK4558 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 0 Tavg within 25°F of Tref 0 AFD within COLR limits RO If a unit shutdown is being performed, the AOP 3575 final MWe load should be approximately 230 Step 7 MWe. NOTE Page 20 of 82

(' i SE~I 4dN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

Q Task Instructor InformationlActivity Assign Expected Action Standard Time IDNMalf US/BOP BOP BOP The US should direct the RO to inform him when either Tavg, power or rod position changes as a result of the boration.

BOP The US should direct the BOP to adjust LOAD SET to 1020 Mwe (about 85% power). BOP BOP us initiate Load Reduction Check turbine OPERATING MODE - MANUAL Check either of the following:

0 Rapid or gravity boration - IN PROGRESS OR 0 WHEN Any of the following change due to boration: Turbine load reduction - REQUIRED TO STABILIZE PLANT Tavg 0 Reactor power 0 Control Rod position Proceed to step 7.d. THEN - Utilizing DECREASE LOAD pushbutton, Adjust LOAD SET to desired final MWe Check power reduction - CONVEX REQUESTED.

Inform CONVEX of load reduction rate AOP 3575 Step 7 AOP 3575 Step 7.a AOP 3575 Step 7.b AOP 3575 Step 7.b RNO AOP 3575 Step 7.d AOP 3575 Step 7.e AOP 3575 Page21 of 82 SECTtvrJ 4 Lesson Title:

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

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard (MWdmin) and final MWe level. Step 7.e RNO BOP Maintain initial MVAR loading during power AOP 3575 Step 7.f US/RO Check boration - IN PROGRESS AOP 3575 Step 7.g AOP 3575 reduction, unless directed otherwise.

Verify Final Desired Turbine Load (MWe) - LESS THAN 75% Step 8 Proceed to Step IO. AOP 3575 Step 8 RNO BOP The following step places one TD FW pump in manual while allowing the other TD FW pump to automatically unload during the down power.

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

Proceed to step 1 I US/RO Verify Rod Position AOP 3575 Step 10.a RNO AOP 3575 Step 11 RO Check ROD CONTROL BANKS LIMIT LO - AOP 3575 Page 22 of 82 SEC>,~N 4 Lesson Title:

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

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard USIRO RO us us RO us us BOP The US and BOP should recognize that perfect symmetrical operation of the MSR reheaters will not be possible because of the MSR tube leak. BOP BOP LO (MB4C 4 - 9) annunciator - LIT. Proceed to step ll.e and, E at any time, the annunciator is received, THEN Perform steps 1 1 .b, I I .c and I1 .d. Check ROD CONTROL BANKS LIMIT LO (MB4C 3 - 9) annunciator - LIT Proceed to NOTE prior to step 12 and, - IF the annunciator is received, THEN Perform step 1 1 .f and 11 .g. Restore From Rapid Boration.

Check rapid OR gravity boration - IN Proceed to Step 13. PROGRESS- Reduce Steam Supply To The MSRs. Check reheat steam flow controllers - IN AUTOMATIC.

Using the MSR Startup Pressure Display on the Foxboro DCS, Verify symmetrical operation of the MSR reheaters during power decrease.

Using OP 3317, "Reheat and Moisture Step 11 .a AOP 3575 Step 11 .a RNO AOP 3575 Step 11 .e AOP 3575 Step 11 .e RNO AOP 3575 step 12 AOP 3575 Step 12.a AOP 3575 Step 12.a RNO AOP 3575 Step 13 AOP 3575 Step 13.a AOP 3575 Step 13.b AOP 3575 Page 23 of 82 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

Q Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard us us us us us us Separator," Perform manual adjustment of moisture separator reheater steam flow control valves, as necessary.

Check If RCS Sample Is Required. Verify change in Reactor Power - GREATER THAN 15% IN ONE HOUR Request Chemistry sample the RCS for 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 power change.) Request Chemistry Department perform gaseous effluent samples and analysis (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 3HVR-REISB Verify Target Power Level - LESS THAN 50%. Continue power reduction to the finat desired target power level.

WHEN Final power level is reached, THEN Proceed to Step 22. Step 13.b RNO AOP 3575 Step 14 AOP 3575 Step 14.a AOP 3575 Step 14.b AOP 3575 Step 14.c AOP 3575 Step 15 AOP 3575 Step 15 RNO Page 24 of 82 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time I DNMa If Instructor InformationlActivity Assign Expected Action Standard Event 2: Failure of 3RCS-L459 T= When RXI OA This fails 3RCS-L459 "as is" during - identified by the downpower crew Sev= '(as is" Annunciater "CHARG PP FLOW HI/LO" 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 IF no charging pumps are operating, Go To AQP 3506, "Loss of All Charging Pumps."

MB3A step I us CHECK the following, (MB3): MB3A . 3CHS-FI 121A, charging flow (MB3), PZR level will not be on program. RO 55 to 100 gpm step 2 0 Pressurizer level on program: 3CHS-FI 132, letdown flow (MB3), 75 to 120 gpm 3RCS*LI 459, pressurizer 3RCS*Li 460, pressurizer level 3RCS*LI 461, pressurizer level bevel Page 25 of 82

/' SECTI'W 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard After the crew recognizes that the controlling channel of PZR level has failed, the US should go to AOP 3571. AOP 3571 Actions (rev 009-01)

The RO should place the Master PZR level controller or 3CHS*FCV121 in manual. The appropriate attachment for this failure is "C". The US should announce to the crew.

The US should give specific direction to the RO to restore PZR level to IF alarm is due to instrument failure, Go To AOP 3571, "Instrument Failure Response."

us Enter AOP 3571 to address Crew RO Determine the Initiating Parameter and Place the affected controller in MANUAL Stabilize the Plant Parameters Perform Corrective Actions Using Appropriate Attachment RO Defeat the failed channel input. Pressurizer Level Select - Control Pressurizer Level Select - Record - 3RCS-LS459D 0 - 3RCS-LS459E RO Restore PZR level to normal. MB3A step 3 3571 Entry Conditions AOP 3571 Step 1 AOP 3571 Step 2 AOP 3571 Step 3 AOP 3571 Attachment C Step I AOP 3571 Attachment Page 26 of 82 SECT~ 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard program for the present power level. Letdown should not have isolated.

RO RO RO RO us, I&C us The US should identify the applicable T/S and T/R which are:

pech Specs] 3.3.1, Functional Unit 11, Action 6 IF PZR level deviates from program level by -i- or - 6%, then also 3.4.3.1, Action b. SM If necessary, using OP 3304A, "Charging and Letdown,"

Restore letdown. Place PZR level controller in automatic.

Reset pressurizer heaters as necessary.

When conditions have stabilized, Observe MI3 annunciators and parameters.

Immediately report any unexpected or unexplained conditions to the SM. Trip the associated Reactor Protection System bistable(s); Place a check mark in the box above the appropriate channel that requires tripping on the last page of this Attachment.

Refer to Technical Specification 3.3.1, 3.3.3.5, and 3.3.3.6. C Step 2 AOP 3571 Attachment C Step 3 AOP 3571 Attachment CStep 4 AOP 3571 Attachment C Step 5 AOP 3571 Attachment C Step 6 AOP 3571 Attachment C Step 7 AOP 3571 Attachment C Step 7a AOP 3571 Attachment C Step 7b Page 27 of 82 SECl I~N 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Assign I n s t ru c t o r I n fo rm a t i o n/Ac t iv it y Expected Action Standard Time IDNMalf The RO should do a lamp check to ensure all bistable lights are functional.

NOTE: This is not the case. The channel has failed. The US should go to step 7.e. T=2 mins of RXRlO6 "OPEN" Protection Set 1 Door request RXR25 RXRI 06 PZR High Level Trip B/S "CLOSE" Protection Set 1 Door RO I&C RO us us Check the existing bistable status to ensure a reactor trip will not occur when the failed channel is tripped. The following step will distinguish whether the failure is within SSPS or the Protection channel. If bistable status light(s) ( MB4F) indicate that a single bistable input has tripped and channel indication is normal, PERFORM the following:

Request the I&C Department trip the appropriate bistables using Attachment C and Attachment S. Verify the appropriate bistable status lights are lit. If indicator 3RCS*LI 4596 is failed, Refer to TRM Table 7.4.1, Fire Related Safe Shutdown Components, "Reactor Coolant System." Request I&C Department perform corrective maintenance on failed instrument.

AOP 3571 Attachment C Step 7c AOP 3571 Attachment C Step 7d NOTE AOP 3571 Attachment C Step 7d AOP 3571 Attachment C Step 70 AOP 3571 Attachment C Step 7f AOP 3571 Attachment C Step 8 AOP 3571 Attachment CStep 9 Page 28 of 82 (1 Lesson Title: Large Break ID Number: 2K7 NRC-01 Time IDAIMalf SECI cdN 4 .OCA Revision:

0 Task Assign I ns t r u c t o r I n f o rm a t i o n IAc t iv i ty 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 I'D" Feed Reg Valve controller and the Feedwater Pump Master Speed Controller in manual. The appropriate attachment for this failure is "M". The US should announce to the crew. Crew Crew BOP BOP BOP Determine the initiating parameter and place the affected controller in MANUAL. AOP 3571 Step 1 Stabilize the plant parameters.

AOP 3571 Step 2 Perform Corrective Actions Using Appropriate Attachment Step 3 AOP 3571 If the failed steam flow channel is selected as the input to SG level control, Perform the following: Verify the affected SG feed regulating valve controller is in MANUAL. Verify feedwater pump A and B master speed control (3FWS-SK509A) in MANUAL and Restore feed pump differential pressure to normal operating band (Program:

40 to 140 psid). AOP 3571 Attachment M Step 1 AOP 3571 Attachment M Step 1.a AOP 3571 Attachment Step .b Page 29 of 82 i SECt'tvd 4 I Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard' BOP Restore SG level to normal. BOP Defeat the failed channel input by selecting the alternate channel on the steam flow selector (also selects the alternate SG pressure instrument input to SGWLC). When SG level is restored and feed/steam flow are matched, Perform the following:

BOP 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. When conditions have stabilized, Observe MB annunciators and parameters.

Immediately report any unexpected or unexplained conditions to the Shift Manager. The calorimetric program US/SM 0 There are no Technical Specifications automatically shifts to feed flow or bistables to be tripped associated based at 88%power. This instrument with the steam flow instruments.

failure should not cause a shift to an NI based output. 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- BOP/ Ro AOP 3571 Attachment M Step 1.c AOP 3571 Attachment M Step 1.d AOP 3571 Attachment M Step 1.e AOP 3571 Attach men t M Step 2 AOP 3571 Attach men t M Step 3 NOTE Page 30 of 82 i SECTIbi\I 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard tagged by the process computer If desired, using SP31002, "Plant Calorimetric," Select "FORCED FEED FLOW CALC" on the plant process computer.

US/SM Request I&C Department perform corrective maintenance on failed instrument.

AOP 3571 NhAnent M Step 3 AOP 3571 Attachment M Step 4 The US should call I&C and report the instrument failure. Event 4: Data 'By RPI Failure Rod position indication failure, Data B T = When RSCU 4 (rod M4) *OP 3571 (RDI 160) complete Annunciator "RPI NON URGENT FAILURE" will come in, and the 'general warning' light will flash for rod M4. The ARP will direct the crew to AOP 3552.

AOP 3552 Rev. 007-00 MALFUNCTION OF THE ROD DRIVE SYSTEM CREW Stabilize Plant Conditions AOP 3552 Step 1 Place control rod bank SEL switch in MAN AOP 3552 RO Step 1.a RO Verify - NO RODS MOVING AOP 3552 Step 1 .b Page 31 of 82 SECTlui\I 4 Lesson Title:

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

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard CREW Stop any power increase or decrease AOP 3552 evolutions in progress. Step 1.c us Check plant can be - MAINTAINED STABLE AOP 3552 AT CURRENT POWER LEVEL Step 1.d , us Verify Tavg - Tref deviation - LESS THAN OR EQUAL TO 1.5'F (MB4D 6-6) annunciator - NOT LIT Maintain Tavg within 1.5'F of Tref using boration or dilution as necessary AOP 3552 Step 1.e us Verify TURB LOAD REJECTION ARM C-7 AOP 3552 Step 1.f AOP 3552 step 1.g If, re-evaluation of plant conditions is desired, return to step 2. us Check No Rod Dropped us RO Check rod bottom lights - NONE LIT Verify RPI URGENT FAILURE (MB4C 4-1 0) annunciator - NOT LIT Check for Rod Control Failure Verify ROD CONTROL URGENT FAILURE (MB4C 4-8) annunciator - NOT LIT AOP 3552 step 2 NOTE AOP 3552 Step 2 AOP 3552 Step 2.a AOP 3552 Step 2.b AOP 3552 Step 3 Verify ROD CONTROL NON-URGENT FAILURE (MB4C 3-8) annunciator - NOT LIT Page 32 of 82 SEb . ,3N 4 (i Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard us Check No Rod Position Indication AOP 3552 Malfunction Step 4 Verify DRPl power available AOP 3552 Step 4.a NOTE: Annunciator IS LIT NOTE: US should transition to the Attachment C at this step NOTE: DATA B IS Flashing Any DRPl display light - LIT Verify status of following annunciators:

AOP 3552 Step 4. b RPI NON URGENT FAILURE (MB4C 3-10) annunciator - NOT LIT RPI URGENT FAILURE (MB4C 4-10) annunciator - NOT LIT us Using Attachment C, Determine rod position AOP 3552 indication malfunction.

Step 4, RNO Verify status of DRPl display alarms:

AOP 3552 Step 4.c URGENT ALARM - NOT FLASHING DATA A FAILURE - NOT FLASHING DATA B FAILURE - NOT FLASHING Rod GW - NONE FLASHING 0 CENTRAL CONTROL FAILURE lights - NONE LIT us Using Attachment C, Determine rod position AOP 3552 Page 33 of 82 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard AOP 3552, ATTACHMENT C indication malfunction.

Check DRPl Power Supply Step 4, RNO AOP 3552 Att C Step 1 RO Verify DRPl display lights - NONE LIT AOP 3552 Att C Step 1.a AOP 3552 Att C Step l.a, RNO d Proceed to Step 2. us RO A DRPl URGENT ALARM indicates one of the AOP 3552 following:

Attachment C Step 2, Note Error in both data A AND data B from detector/encoder cards. Codes from data A and data B differ by GREATER THAN I bit The binary sum of data A and data B data exceeds

38. Check For DRPl Urgent Alarm 0 AOP 3552 Att C Step 2 AOP 3552 Page 34 of 82 RO Verify DRPl display URGENT ALARM lights - FLASH I NG Att C Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard us us us us RO RO BOOTH NOTE: When the board operator is sent RO to DRPl cabinet report, "ACCURACY MODE switch is in A+B position" RO should identify the affected rod as rod M4 (CB D, group 2) RO Proceed to NOTE prior to Step 3 0 Loss of Data A will result in DRPl half- accuracy of +IO and -4 steps for affected rods. 0 Loss of Data E3 will result in DRPl half- accuracy of +4 and -10 steps for affected rods.

Check For DRPl Non-Urgent Alarm Verify RPI NON URGENT FAILURE (MB4C 3-1 0) annunciator - LIT Verify DRPl Display DATA A FAILURE DATA B FAILURE lights - FLASHING Verify ACCURACY MODE selector switch (back of DRPl cabinet) - A + B POSITION Identify affected rod(s) as follows: Flashing General Warning (GW) light Step 2.a AOP 3552 AttC Step 2.a, RNO AOP 3552 Att C Step 3, Note AOP 3552 Att C Step 3, Note AOP 3552 Att C Step 3 AOP 3552 Att C Step 3.a AOP 3552 Att C Step 3.b AOP 3552 Att C Step 3.c AOP 3552 Att C Step 3.6 Page 35 of 82 SECTION 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RO BOOTH NOTE: After notified as I&C inform the US that it is okay to return the rods to Automatic.

Once the rods are in auto then ... Proceed to Event 5 - us us RO us us Verify affected rod(s) indicates - WITHIN -C 12 STEPS OF ASSOCIATED GROUP STEP COUNTER DEMAND HEIGHT AOP 3552 Att C Step 3.e Proceed to Step 3.h Notify I & C A Central Control Card failure does not impair system operation since the three cards are redundant, handling both data A and data B. Check For Central Control Card Failure Verify DRPl display any CENTRAL CONTROL FAILURE 1 2 3 light - LIT Proceed to NOTE prior to Step 5. In "half accuracy" operation, the affected rod position will be indicated by every other LED AOP 3552 Att C Step 3.f AOP 3552 Att C Step 3.h AOP 3552 Att C Step 4, Note AOP 3552 Att C Step 4 AOP 3552 Att C Step 4.a AOP 3552 Att C Step 4.a, RNO AOP 3552 Att C Page 36 of 82 SECTtud 4 Lesson Title: Large Break LOCA (I ID Number: 2K7 NRC-01 Revision:

Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Event 5: Loss of Battery Bus 4 T = Rods in RSCU 5 Loss of Battery Bus 4 Or (EDOSD) examiner's cue Battery 4 trouble and inverter 4 trouble annunciators alarm. The Battery 4 trouble ARP will direct the crew to AOP 3563. as the rod is raised or lowered.

us Perform Foliow-up actions Step 5, Note AOP 3552 Att C Step 5 AOP 3563, Loss of DC Bus Power, Rev. 007-03 BOP Check The Following DC Busses - ENERGIZED Bus 301A-1 (Battery Bus I) Bus 301B-1 (Battery Bus 2) Bus 301C-I (Battery Bus 5) Bus 301D-I (Battery Bus 6) AOP 3563 step 1 Check Bus 301A-2 (Battery Bus 3) - AOP 3563 step 2 Page 37 of 82

,/" SECTlvrJ 4 Lesson Title: Large Break LOCA Revision:

Q ID Number: 2K7 NRC-01 Task Time IDAlMalf Instructor Information/Activity Assign Expected Action Standard ENERGIZED VIAC-4 will still be energized from us inverter 4 The US should contact Electrical Maintenance or the work week coordinator to initiate investigation and repair efforts.

alarm is in on Inverter 4. US/BOP /PEO T=5 BOOTH Report as PEO that the 'Low DC Bus' minutes from being dispatched

[Tech Specs] The following apply for a loss of DC bus 4: 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)

US Check Bus 301 B-2 (Battery Bus 4) - ENERGIZED Use Attachment D. Verify VIAC-4 is energized from inverter 4 or the alternate power supply. Restore normal DC power alignment using OP 33432, 125 Volt DC. Refer to the following technical specifications for required actions: AOP 3563 step 3 AOP 3563 step 3 RNO AOP 3563 Att.D step 1 AOP 3563 Att.D step 2 AOP 3563 Att. D step 3 3.8.2.1 D.C. Sources Modes 1-4 Page 38 of 82 Lesson Title:

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

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard 3.8.2.2 D.C. Sources modes 5 and 6 0 3.8.3.1 Onsite Power Distribution Modes 1-4 NOTE: If called, Electrical Maintenance reports a bus fault on Battery Bus 4. More investigation is necessary.

3.8.3.2 Onsite Power Distribution Modes 5 and 6 Continue With Normal Plant Evolutions Using Applicable Plant Procedures. AOP 3563 step 4 T= AOP 3563 RSCU 6 RC14C complete 100% EVENT 6: RPCCW Leak into RCP C Upper Oil Reservoir 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 been in about 3 minutes. level computer point, to confirm alarm. 3353.MB4 B Step 1 CREW MONITOR the following RCP C computer OP points: 3353.MB4 6 Step 2 0 RCS-T481A, RCP C upper thrust bearing temperature.

Page 39 of 82 Lesson Title: Large Break LOCA SECi'lud 4 i ID Number: 2K7 NRC-01 Revision:

Q Task Time IDNMaIf Instructor InformationlActivity Assign Expected Action Standard e RCS-T481 B, RCP C lower thrust bearing temperature.

RCS-T485A, RCP C upper thrust bearing temperature.

0 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 OP (37%), PERFORM the following: 3353.MB4 B Step 3.1 - IF reactor power is greater than P-8 0 TRIP reactor STOPRCPC e GO TO E-0 OP 3353.MB4 B Step 3.1.1 OP 3353.MB4 B Step 3.1.2 OP 3353. MB4 B Step 3.1.3 The US should refer to AOP 3554, which will direct him to reduce power. us Refer to AOP 3554, "RCP Trip or Stopping an OP RCP at Power", and REMOVE RCP C from 3353.MB4 service. B Step 3.2 us CHECK 3CCP-LI 20B, RPCCW surge tank OP level, for indication of RPCCW leakage. 3353. MB4 Page 40 of 82 SECTIUN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard B Step 4 us CREW us AOP 3554, Stopping an RCP at Power, Rev. 008-00 RO RO NOTE: The rate at which temperature is increasing should urge the crew to use the Rapid Downpower procedure.

However, the degrading oil reservoir condition will eventually either impel the Crew to manually trip the Reactor OR the RCP will seize and the Reactor will trip on RCP Low Speed. It is not expected that the The following step requires containment entry. OP 3353.MB4 B ALARA Step 5 IF directed by the SM/US CHECK for RPCCW OP to RCP C lube oil leak.

3353.MB4 B Step 5 Refer to Tech Specs and DETERMINE LCOs OP 3353.MB4 6 Step 6 Check RCP Status - ALL PUMPS RUNNING AOP 3554 Step 1 Check Reactor Power AOP 3554 Step 2 Verify THREE LOOP PERMISSIVE P-8 annunciator (MB4D 3-3) - LIT. AOP 3554 Step 2.a Using one of the following, reduce power as required:

AOP 3554 Step 2.a RNO Page 41 of 82 SECTkvd 4 Lesson Title: Large Break LOCA Revision:

0 ID Number: 2K7 NRC-01 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard crew will start the downpower.

0 AOP 3575, "Rapid Downpower" 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 bearing temperature computer point is greater than 195O F PERFORM the following: - IF reactor power is greater than P-8 (37%), PERFORM the following: RO TRIP reactor NOTE: US should go to "Master Silence" before ordering reactor trip . RO STOP affected RCPs (RCP "D") OP 3353.MB4 B Step 3 OP 3353. MB4 B Step 3.1 OP 3353.MB4 6 Step 3.1 .I OP 3353.MB4 B Step 3.1.2 Page 42 of 82 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Assign Time IDAlMalf I n s t r ucto r I n fo rm a t i o nlAc t iv it y Expected Action Standard CREW Go to E-0, Reactor Trip or Safety Injection.

OP 3353.MB4 B Step 3.1.3 T = Reactor Trip Event 7: "C" Hot Leg break (Inside CTMT)

NOTE: The small break LOCA will initiate upon the reactor trip. (MALF RC02C, 0.15% @ 60 sec ramp) E-0 (Rev. 22) STEPS Crew e Foldout page must be open 0 ADVERSE CTMT defined as GREATER THAN 180°F or GREATER THAN I o5 R/h, in containment. E-0, Step 1, NOTE Page 43 of 82 SECTlud 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 IDAlMalf Revision:

0 Task Assign Time I n s t r u c t o r I n f o r m a t i o nlAc t iv i t y Expected Action Standard RO RO BOP BOP us RO 0 The reactor can be interpreted as "tripped" when any two of three bulleted substeps of Step I .* are satisfied. Verify Reactor Trip 0 Check reactor trip and bypass breakers - OPEN 0 Check rod bottom lights - LIT 0 Check neutron flux - DECREASING TRIP the reactor. Verify Turbine Trip Check all turbine stop valves - CLOSED Verify Power to AC Emergency Busses Check busses 34C and 34D - BOTH ENERGIZED Check If SI Is Actuated Verify SAFETY INJECTION ACTUATION annunciator - (MB4D 1-6 or MB2B 5-9) - LIT E-0, Step 1 E-0, Step I, RNO E-0, Step 2 Step 2.a E-0, Step 3 E-0, E-0, Step 3.a E-0, Step 4 E-0, Step 4.a Page 44 of 82 SEC-hd 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

Q Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Critical Task - us Check if SI is required Crew should identify that SI did not actuate and it is required.

SI should be manually actuated.

0 CTMT pressure GREATER THAN 18 psia - 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 breakers - OPEN E-0 , Step 4.a, RNO [*I E-0, Step 4.c Page 45 of 82 SECTlud 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMaIf Instructor InformationlActivity Assign Expected Action Standard Critical Task - The BOP should identify that the AFW pumps failed to automatically start when required.

The BOP should manually start both MDAFW pumps and the TDAFW pump. Check Reactor trip and bypass breakers - OPEN RO Verify Service Water Pumps - AT LEAST ONE PER TRAIN RUNNING START pump(s) RO RO Verify ECCS Pumps Running Verify Two RPCCW Pumps - ONE PER TRAIN RUNNING e e e Check SI pumps - RUNNING Check RHR pumps - RUNNING Check two charging pumps - RUNNING BOP Verify AFW Pumps Running Check MD pumps - RUNNING START pump(s) E-0 , Step 4.c E-0, Step 5 E-0, Step 5, RNO E-0, Step 6 E-0, Step 7 E-0, Step 8 Step 8.a Step 8.a, RNO [*] E-0, E-0, Page 46 of 82 SECTlUN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDA/Malf Instructor Information/Activity Assign Expected Action Standard Check turbine - driven pump - RUNNING, IF NECESSARY OPEN steam supply valves.

Check turbine - driven pump - RUNNING, IF NECESSARY BOP Verify FW Isolation 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 E-0, Step 8. b Step 8.b, E-0, RNO r] E-0, Step 8.b E-0, Step 9 Page 47 of 02

{, SEC ij I ,AI 4 i Lesson Title:

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

0 Task Assign Time IDNMalf I n s tr u c to r I n f o r m a t io nlAc t ivi ty Expected Action Standard BOP RO CTMT pressure will ultimately reach the CDA setpoint.

The crew should recognize that CDA did not actuate. Manual component alignment is required.

US Check If Main Steam Lines Should Be Isolated Check Ctmt pressure GREATER THAN 18 psia - OR Any SG pressure LESS THAN 660 Psig Proceed to Step 11 Verify MSlVs and MSlV bypass valves Check ESF Group 3 lights - LIT. - CLOSED Check if CDA Required Check Ctmt pressure is GREATER THAN 23 psia - OR Ctmt spray - INITIATED Proceed to Step 12. E-0, Step 10 E-0 , Step 10.a E-0 , Step 10.a, RNO Step 10.b Step 1O.c E-0, Step 11 Step 1 I .a E-0 , E-0, E-0, E-0, Step1 1 ,a, RNO Page 48 of 82 Lesson Title: Large Break LOCA Revision:

0 ID Number: 2K7 NRC-01 Task Time IDAlMalf Instructor Information/Activity Assign Expected Action Standard BOP BOP BOP RO RO RO RO RO RO Verify CAR Fans Operating In Emergency Mode Check CAR fan status: 0 0 CAR fans A and B - RUNNING CAR fan C - STOPPED STARTETOP CAR fans as necessary.

Verify RPCCW Ctmt supply and return header isolations - OPEN Verify Train A and B RPCCW supply and return to chill water valves - OPEN Verify CIA Check ESF Group 2 status columns 2 through 10 - LIT Verify Proper ESF Status Panel Indication 0 0. Determine If ADVERSE CTMT Conditions Exist Verify ESF Group 1 lights - OFF Verify ESF Group 2 lights - LIT 0 Ctmt temperature GREATER THAN 180°F E-0, Step 12 E-0, Step 12.a E-0, Step 12.a, RNO Step 12.b Step 12.c E-0, Step 13 Step 13.a E-0, Step 14 E-0, E-0, E-0, E-0, Step 15 Page 49 of 82

( SECTtud 4 i Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time I DA/Malf Instructor Information/Activity Assign Expected Action Standard CREW should perform a short brief and come out of "Master Silence" at the completion of Step 16. - OR Ctmt radiation GREATER THAN lo5 *lh, RO Verify ECCS Flow Check charging pumps - FLOW INDICATED Check RCS pressure - GREATER THAN 1650 psia (1950 psia ADVERSE CTMT) RO us Proceed to Step 16.e Check PORV block valves - OPEN OPEN energized block valves. Proceed to step 17. Check SI pumps - FLOW INDICATED START pumps and Align valves. E-0, Step 16 Step 16.a E-0, E-0, Step 16.b E-0, Step 16.b, RNO Step 16.c Step 16.c RNO Step 16.d E-0 , E-0, E-0, E-0, Step 16.e Step 16.e RNO Page 50 of 82 E-0, SECTIVI~ 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard BOOTH NOTE When asked, REPORT that "all INST SLCRS doors indicate closed." BOP ' us BOP BOP RO us us Check RCS pressure - LESS THAN 300 psia (500 psia ADVERSE CTMT Proceed to step 17. Verify Adequate Heat Sink Check NR level in at least one SG - GREATER THAN 8% (42% ADVERSE CTMT) Proceed to Step 17.d. Verify Total AFW Flow - GREATER THAN 530 gpm Verify AFW Valve Alignment - PROPER EMERGENCY ALIGNMENT Verify ECCS Valve Alignment - PROPER EMERGENCY ALIGNMENT Check Plant Status Verify SLCRS doors - CLOSED Request Security Close all SLCRS doors. E-0 , Step 16.f Step 16.f RNO E-0, Step 17 Step 17.a E-0, E-0 , E-0, Step 17.a, RNO Step 17.d E-0, Step 18 E-0, Step 19 E-0, Step 20 Step 20.a Step 20.a, RNO E-0, E-0, E-0, Page 51 of 82 SECTIUN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard RO Check CONTROL BUILDING E-0, ISOLATION annunciator (MB4D 3-6) - LIT Step 20.b RO Check if CBI is required E-0, Step 20.b, RNO 0 Ctmt pressure GREATER THAN RO 18 psia - OR RO 0 Control Building radiation monitor in alarm - OR e SI manually actuated RO - IF CBI required, THEN Initiate CBI.

us - IF CBI is NOT required, THEN Proceed to Step 21. RO Verify ESF Group 2 CBI lights - LIT E-0, Step 20.c Page 52 of 82

/' SEC'I ,JN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMalf instructor InformationlActivity Assign Expected Action Standard T+ 5 min BOOTH Report the Control Building of request Pressure Boundary doors are closed & dogged or verified closed as directed.

RO Align HVAC components as necessary for minimum safety function.

BOP Verify control building purge supply fan and purge exhaust fan - NOT RUNNING Verify control building air bank isolation valves - OPEN BOP BOP STOP kitchen exhaust fan PEO CLOSE and DOG the following Control Building pressure boundary doors. 9 CB west 47'6 (C-47-IA) 9 CB east 64' 6" (C-64-1 B) Verify the following Control Building pressure boundary doors - CLOSED 9 CB west 47'6 (C-47-1) . CB north 64'6" chiller room door (C-64-4) CB north 64'6 chiller room door (C-64-5) CB west 49'6 (C-49-I) . E-0, Step 20.q RNO Step 20.d E-0, E-0 , Step 20.e Step 20.f Step 20.g E-0, E-0, E-0, Step 20.h Page 53 of 82 m

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

0 Task Expected Action Standard Time IDNMalf instructor InformationlActivity Assign us Perform the applicable action: - IF temperature is GREATER THAN 560"F, THEN Proceed to step 21 .c. IF temperature is LESS THAN 550°F __I_ THEN Proceed to step 21 .e. BOP Maintain total feed flow BETWEEN 530 and 600 gpm until NR level is ADVERSE CTMT) in at least one SG CLOSE SG atmospheric dump and dump bypass valves Check the following valves - CLOSED GREATER THAN 8% (42% BOP BOP . MSlVs . MSIV bypass valves RO Check PZR Valves Verify PORVs - CLOSED E-0 , Step 21 .a, RNO E-0, Step 21 .e E-0, Step 21.f Step 21 .g E-0, E-0, Step 22 E-0, Step 22.a Page 55 of 82 t., SECT~W 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

Q Task Time IDA/Malf Instructor InformationlActivity Assign Expected Action Standard Critical Task - RCS pressure will eventually lower to 1500 psia. Crew should identify this and trip all RCPs. RO RO CREW RO RO RO RO BOP/RO Verify normal PZR spray valves - CLOSED Verify PZR safety valves - CLOSED To prevent damage to the RCP seal(s), seal injection flow should be maintained to all RCPs. Check If RCPs Should Be Stopped Verify RCPs - ANY RUNNING Verify RCS pressure - LESS THAN 1500 psia (1 800 psia ADVERSE CTMT) Verify charging or SI pumps - AT LEAST ONE RUNNING STOP all RCPs Check if SG Secondary Boundaries Are Intact Check pressure in all SGs E-0 , Step 22.b Step 22.c Step 23, CAUTION E-0, Step 23 E-0, Step 23.a EOP 35 E-0, Step 23.b E-0, E-0, E-0, Step 23.c Step 23.d E-0, ["I E-0, Step 24 E-0, Step 24.a Page 56 of 82 i SEClLd 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMalf I nst ructo r I n fo rmat ionlActivi ty 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) 3. Request Chemistry obtain activity samples using HP coverage BOOTH Acknowledge the request to perform the S/G samples. Ensure crew request activity samples with HP coverage BOP Check steam generator levels - NO E-0, SG LEVEL INCREASING IN AN UNCONTROLLED MANNER Step 25.b Verify trend history and alarm status E-0 , of radiation monitors Step 25.c Main steam line - NORMAL Condenser air ejector - NORMAL SG blowdown - NORMAL Page 57 of 82 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard E-0, Step 26 RO Check If RCS Is intact . 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.

E-I (rev 021) Actions 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 or Secondary Coolant. RNO RO To prevent seal damage, seal E-I, Step 1 CAUTION injection flow should be maintained to all RCPs. E-I, Step 1 NOTE Note The US should remind the operators us Note: Foldout page must be open, to review their Foldout Page Books 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 la Page 58 of 82 SECL .4 tl' c Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Expected Action Standard Time I DAlMa If Instructor InformationlActivity Assign us us BOP/ RO us BOP BOP us Proceed to step 2 Check If SG Secondary Boundaries Are Intact Check pressures in all SGs. NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER NO SG COMPLETELY DEPRESSURIZED Check Intact SG Levels Verify NR level - GREATER THAN 8% (42% ADVERSE CTMT) Control feed flow to maintain NR level between 8% and 50% (42% and 50% ADVERSE CTMT) Check Secondary Radiation E-I Step la RNO E-1, Step 2 E-I, Step 2a E-I, Step 3 E-?, Step 3a E-I, Step 3b E-I, Step 4 Page 59 of 82

( SECTluN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard RO Sample all SGs for activity.

I) RESET SG blowdown sample

2) OPEN SG Blowdown sample

3) Request Chemistry obtain activity samples using HP coverage Verify trend history and alarm status of radiation monitors Main steam line - NORMAL Condenser air ejector - NORMAL SG blowdown - NORMAL If any PZR PORV opens because of high PZR pressure, step 5a should be' repeated after pressure decreases to LESS THAN 2350 psia. Check PZR PORVs and Block Valves isolation.

isolation valve(s) RO CREW us RO Verify PORVs - CLOSED RO Verify block valves - AT LEAST ONE OPEN E-I, Step 4.a E-I, Step 4.b E-I, Step 5 CAUTIO N E-I, Step 5 E-I, Step 5a E-I, Step 5b Page 60 of 82

(' SECTkA 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard us Subcooling should be <32"F and/or PZR level e 16%. RO BOP RO RO us us Check If ECCS Flow Should Be Reduced Verify RCS subcooling based on core exit TCs - GREATER THAN 32°F (1 15°F ADVERSE CTMT) Verify secondary heat sink Total feed flow to intact SGs - GREATER THAN 530 gpm - OR - Narrow range level in at least one intact SG - GREATER THAN 8% (42% ADVERSE CTMT) Verify RCS pressure - STABLE OR I NCREAS I NG Verify PZR level - GREATER THAN 16% (50% ADVERSE CTMT)

Proceed to CAUTION prior to step

7. To ensure adequate ECCS flow, do not stop any recirculation spray pumps used for core injection flow. E-I, Step 6 E-I, Step 6a E-1 Step6b E-I Step6c E-I Step6d E-I, Step 6, RNO E-I, Step 7 CAUTION Page 61 of 82

(, SECTION 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 (I Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard us The recirculation spray pumps are sequenced to automatically start I1 minutes after a CDA. RO Check if containment spray should be stopped. RO Verify quench spray pumps - RUNNING us Proceed to CAUTION prior to step 8. CREW If offsite power is lost after SI reset, manual actions to restart safeguards equipment may be required.

CREW To provide adequate ECCS flow, RCS pressure should be 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 Stopped us Check RHR pumps - ANY RUNNING IN SI MODE E-I, Step 7 NOTE E-I, step 7 E-I, Step 7a E-1 , Step 7a, RNO E-I, Step 8 CAUTION E-I, Step 8 CAUTl ON E-I, Step 8 E-I , Step 8.a Page 62 of 82 SEChud 4 Lesson Title:

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

0 Task Assign Expected Action Standard Time IDA/Malf I n s t r u c t o r I n f o r m a t i o n/Ac t iv i t y Depending on the speed of the crew, RCS pressure may still be going down very slowly. If the crew elects NOT to stop RHR pumps based on this trend, this is satisfactory.

RO Crew should reset SI RO - NOTE: This step will stop the RHR Pumps. If stopped, the pumps will need to be restarted when the LOCA becomes larger. RO us BOP RO us Check RCS pressure I) Verify pressure - GREATER THAN 300 psia (500 psia ADVERSE CTMT) 2) Verify pressure - STABLE OR INCREASING RESET SI, if necessary STOP RHR pumps and Place in Auto Check RCS and SG Pressures Check pressure in all SGs - INCREASING OR STABLE (consistent with plant cooldown)

DECREASING OR STABLE Do not reset CDA if the recirculation spray pumps are required and have NOT automatically started. Check If Diesel Generators Should Be Stopped Check RCS pressure - E-I, Step 8. b *-I, Step 8.c Step 8.d E-I, E-I, Step 9 E-I, Step 9 E-I, Step 10 CAUTION E-I Step 10 Page 63 of 82

(' SECTtvI\J 4 6' k Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time I D AIM a If Instructor InformationIActivity Assign Expected Action Standard BOOTH INSTRUCTOR:

BOP Verify AC emergency busses - BOTH ENERGIZED BY OFFSITE POWER Proceed to step 10.h. RESET SI and CDA, if required PEO Perform the following to energize Check Bus 34C -ENERGIZED MCC32-3T Using GA-1, Energize MCC 32-3T T=+8of EDRI 8 Energize MCClA3 (32-3T) request "RESET" EDR44 after 3T reset) "RES ET" Reset Batt/lnv 6 Trouble (- 5 min Check emergency diesel generators - BOTH RUNNING UNLOADED STOP unloaded diesel generator(s)

Locally perform the following for unloaded emergency diesel generators:

For EDG A, Place 3EGS*PNLlA control switch on MCC 32-IT-3H to START E-I Step 10a Step 10b Step 10h E-I Step 1Oi E- 1 E-I E- 1 Step 10.i.l Step 10.i.2 E-I E- I Step l0.j Step 10k E-I Step 101 E-I Page 64 of 82 SECTluN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard For EDG B, Place 3EGS*PNL1 B control switch on MCC 32-1U-3H to START us Initiate Evaluation Of Plant Status E-I Step 11 us Verify cold leg recirculation capability E-I BOP 1) Power to recirculation spray RO 2) Using Attachment A, Verify power Step 1 la pumps - AVAILABLE for cold leg recirculation valves - AVAILABLE T= RC02C This will increase the severity of the step 11 SBLOCA to a point where ADVERSE CTMT will occur and if stopped, the RHR pumps will need to be restarted.

sev = 100% Page 65 of 82 SECTId 4 Lesson Title: Large Break LOCA Revision:

0 ID Number: 2K7 NRC-01 Time IDAlMalf Task Instructor Information/Activity Assign Expected Action Standard The crew will need to recognize 3 items: 1- The rise in CTMT pressure will generate an orange path on CTMT, and require transition to FR-Z.l 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 has a higher priority us Go to FR-Z.l and restart the RHR pumps E-I, step 8 caution and OP3272 crew will perform FR-P.l first as it FR-P.1 (rev 01 3-01) Steps CREW If DWST level decreases to LESS FR-P.l Step 1 CAUTION THAN 80,000 gal, Shift AFW pump suction to the CST using 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. GA-4. Page 66 of 82 i:' SECTIWN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time I DA/Ma If Instructor InformationlActivity Assign Expected Action Standard RHR pumps may be started by the crew at this point. RHR Pump flow should be

> 1,000 gpm. The appropriate transition will be to FR-Z.l FR-Z.l (rev 013-00) STEPS Yes, CTMT pressure will be greater than 23 psia. "CONTAINMENT DEPRESS ACTUATION" will NOT be lit. The RO is expected to attempt to manually initiate CDA using the main board pushbuttons RO us RO RO USlRO Check RCS Pressure - GREATER THAN 300 psia (500 psia ADVERSE CTMT) Perform the applicable action: IF RHR pump flow is LESS THAN OR EQUAL TO 1000 gpm THEN Proceed to step 2. - - IF RHR pump flow is GREATER THAN 1000 gpm THEN Go to procedure and step in effect.

Check If CDA Required Check Ctmt pressure - GREATER THAN 23 psia Verify annunciator "CONTAINMENT DEPRESS ACTUATION' (MB2B 5-5) - LIT Initiate CDA. Verify CIA FR-P. 1, Step 1 FR-P. I, Step 1, RNO FR-Z. 1, Step 1 Step 1.a FR-Z. 1, FR-Z. 1, Step 1.b FR-Z. I, Step 1 .b RNO FR-Z. I, Step 2 Page 67 of 82 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 I DAlMalf Instructor InformationlActivity Assign Expected Action Task Standard Time CDA will have failed to Auto Actuate. CIB relays operated on Hi- 3 and realigned the RPCCW valves us RO RO RO The RPCCW pumps will have to be manually stopped.

RO RO us NIA us Check ESF Group 2 Status columns 2 Through 10- LIT Verify CIB Check RPCCW Ctmt supply and return header isolation valves - CLOSED CLOSE valves. Check RPCCW pumps - STOPPED STOP pumps. STOP all RCPs If ECA-1 .I, Loss of Emergency Coolant Recirculation, is in progress, Ctmt spray should be operated as directed in ECA-1 .I. Verify Quench Spray System Operation FR-Z. 1, Step 2.a FR-Z. 1, Step 3 FR-Z. 1, Step 3.a FR-Z. 1, Step 3.a, RNO FR-Z. 1 , Step 3. b Step 3.b, RNO FR-Z. 1, FR-Z. I, Step 3.c FR-Z. 1, Step 4 CAUTION FR-Z.1, Step 4 Page 68 of 82 I i i SECI idN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Critical Task - RO Check annunciator RWST EMPTY QSS PP OFF (69,331 gal) (MBZA 5-2) Verify quench spray pumps - RUNNING - NOT LIT RO RO START pumps. The RO must manually start the QSS pumps. Verify quench spray pump discharge valves - OPEN 3QSS*MOV34A 3QSS*MOV34B Critical Task - RO OPEN valves.

The RO must manually open the quench spray pump discharge valves. The BOP will have to manually stop Main Circulating Water Pumps. BOP STOP All Main Circulating Water Pumps Check Containment Ventilation FR-Z. 1, Step 4.a FR-Z. 1, Step 4.b FR-Z. 1, Step4. b, RNO r] FR-Z. 1, Step 4.c FR-Z. 1, Step 4.c, RNO r] FR-Z. I, Step 5 FR-Z. 1, Step 6 Page 69 of 82 SECTIuN 4 Lesson Title: Large Break LOCA Revision:

0 ID Number: 2K7 NRC-01 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard The BOP will have to manually stop BOP Verify CAR fans - the CAR and CRDM fans. STOPPED BOP 0 Verify CRDM fans - STOPPED Verify Recirculation Spray System Operation Check recirculation spray pump suction isolation valves - OPEN 3RSS*MOV23A 3RSS*MOV23B 3RSS*MOV23C 3RSS*MOV23D OPEN valves. Check annunciator CTMT RECIRC PUMP AUTO START SIGNAL (MB2B 1-8 lit) - LIT FR-Z.1, Step 7 Step 7.a FR-Z. 1, FR-Z. 1, Step 7.a RNO Step 7.b FR-Z. 1, Page 70 of 82 SECTiuN 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

0 Task Time I DNMa If Instructor Information/Activity Assign Expected Action Standard The RO must manually start the RSS pumps. Perform the applicable action: - IF QSS flow is indicated, 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 - ANY RUNNING Proceed to step 7.e Check Ctmt WR sump level GREATER THAN 1.5 feet START recirculation spray pumps (3RSS*L122A, 3RSS*L122B) - Verify recirculation spray pump spray header isolation valves - OPEN ON RUNNING PUMP (S) 0 0 For pump A - 3RSS*MOV20A For pump B - 3RSS*MOV20B FR-Z. 1, Step 7.b, RNO FR-Z. 1, Step 7.c FR-Z. 1, Step 7.c, RNO Step 7.e FR-Z. 1, FR-Z. 1, Step 7.f Step 7.g FR-Z. 1, Page 71 of 82 I SECl iclN 4 Lesson Title:

Large Break LOCA ID Number: 2K7 NRC-Of Revision:

0 Task Assign Time IDAlMalf I n s t r u c t o r I n f o r m a t i o n IAc t i v i t y Expected Action Standard '* For pump C - 3RSS*MOV20C For pump 0 - 3RSS*MOV20D Check recirculation spray - FLOW FR-Z. 1, INDICATED IN AT LEAST ONE TRAIN Step 7.h 1. 2. 3. FR-Z. 1, IF running pump amps, flow, or discharge pressure oscillate THEN Step 7.i RESET SI THEN LOP and CDA STOP affected pump(s). Emergency Coolant Recirculation GO to ECA-I .I, LOSS Of Proce-d to step 9. FR-Z. 1 , Step 7.j Verify ESF Status Panel Group 4 FR-Z. I, Lights - LIT Step 9 Operate components as necessary for minimum safety function.

FR-Z. I, Step 9, RNO Step 10 Verify Main Steam Line Isolation FR-Z. 1, Check MlSVs and MlSV bypass valves - CLOSED Check ESF Status Group 3 lights - LIT Page 72 of 82

(. SEC'i ,JN 4 (I. Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Revision:

Q Task Time IDA/Malf Instructor InformationlActivity Assign Expected Action Standard Verify Main Feedwater Isolation 0 0 0 Verify MD FW pumps - TRIPPED Verify TD RN 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 maintained available for RCS cooldown.

If all SGs are faulted, at least 100 gpm feed flow should be maintained to each SG. Check If Auxiliary Feedwater Flow Should Continue To All SGs Check pressure in all SGs 0 0 NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER FR-Z. 1, Step 11 FR-Z. 1, Step 12, CAUTION FR-Z. 1, Step 12 Step 12.a FR-Z. 1, Page 73 of 82

(' SECTiuN 4 Lesson Title: Large Break LOCA Revision:

0 ID Number: 2K7 NRC-01 Task Time IDNMaif Instructor InformationlActivity Assign Expected Action Standard NO SG COMPLETELY DEPRESSURIZED Go to Procedure and Step In Effect FR-Z. 1, Step 13 The scenario may be terminated upon completion of FR-Z.I. Page 74 of 82

__ SECTION 4 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 -LJ EVALUATION GUIDE Revision:

0 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@)

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)?

'c" ' 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 75 of 82 SECTION 4 EXAM GUIDE

SUMMARY

Title: Larqe Break LOCA ID Number: 2K7 NRC-01 \d Revision: - 0 11. Critical Tasks Note: Critical Tasks are not required for Progress Review Exams. TASK DESCRIPTION TASK # WA >i= 3.0 BASIS SELECTION Establish 530 gpm AFW E-O--F 3.9i4.0 Failure to establish flow to the S/Gs before transition out of E-0 unless transition to FR- H.1. Then before step 3. 061 000 GEN 14 minimum required AFW flow, under the postulated plant conditions, results in "adverse consequences." Trip all RCPs so that an E-I - Orange Path on Core Cooling based on core exit thermocouples (718°F) does not occur when forced circulation in the RCS stops (small break LOCA).

3.6/3.6 Failure to trip the RCPs 009 EA1.09 under the postulated plant 4.2/4.3 conditions leads to core 009 EK3.23 uncovery and to fuel cladding temperatures in excess of 2200"F, which is the limit specified in the ECCS acceptance criteria.

,-C '. I --..-= Manually actuate at least one train of SIS- actuated safeguards before completion of step 4 of E-0. Establish at least one Quench Spray train flow before completion of FR-Z. 1 step 4. E-O--D 4.5i4.8 006 030 A2.01 EO-E 026 000 AI .01 3.9/4.2 Failure to manually actuate SI represents a "demonstrated in-ability by the crew to take an action or combination of actions that would prevent a challenge to plant safety." Failure to establish at least one Quench Spray train flow under the postulated conditions constitutes a "demonstrated inability by the crew to recognize a failureiincorrect auto actuation of an ESF system or corn pone n t . I' Note: [*I Used to designate critical tasks. Should also be incorporated into column 3 or 4 of Instructor Guide.

Page 76 of 82 SHIFT TURNOVER REPORT I DATE-TIME PREPARED BY todav 0300 I PLANT STATUS: Mode: 1 RxPower: 9% Megawatts: Thermal: 341 1 MWTH PZR Pressure:

2250 psia Electric:

1205 MWe RCS T-AVE: 587 degF RCS Leakage:

Identified:

Omgprn Boron/Burnup 43 ppm / 19,000 MWDlMTU Unidentified:

mgpm Days on line 485 Datemime:

todav 0015 Protected Train/Facility:

B Purple PRNSDR: Green Intake: Green. LCO Action Date Action Requirement Time in LCO Time Left System TPCCW OD Compensatory Actions I Temp Logs OpenDate I ClassReason I Reason I Watch Position "C" TPCCW pump is out of service for an oil replacement. Cross Unit System Status I Surveillances I Evolutions in Progress I I I I 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 77 of 82 ATTACHMENT 2 VAL1 DATION CH ECKLl ST Title: Large Break LOCA ID Number: 2K7 NRC-01 Initial Conditions:

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

0 The scenario contained in the guide has been test run in part or whole on the simufator.

The simulator response is reasonable and as expected.

If a simulator guide revision does not affect original Test Run, then enter N/A. Simulatoi Operating Limits: ., U' The simulator guide has been evaluated for operating limits andlor anomalous response by reviewing the Simulator Modeling and Anomalous Response List.

Verified By: (Initials)

For Examination Scenario: The Scenario Attributes Checklist is complete and attached.

This is not required for Progress Review Exams. Etions Complete (Signature)

Page 78 of 82 Atmendix D Scenario Outline Form ES-D-1 Facility: Millstone 3 Scenario No.: 2K7 NRC-01 Op-Test No.: 2K7 Examiners: Operators:

Initial Conditions:

IC-21, 100% Dower, 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 maior maintenance.

The "C TPCCW pump is out of service for oil replacement.

RPOGNB Event C (RO) I Control rod Dosition indication failure.

Data B (rod M4). Loss of Battery Bus 4. RPCCW leak into upper oil reservoir of

'C' RCP. Small break LOCA inside CTMT. Safety Iniection fails C (RO) M (ALL) c (RO). C (BOP) C (RO) to auto-actuate.

AFW pumps fail to autb-start.

Large break LOCA inside CTMT. CDA fails to auto- 1 actuate. I I k (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 79 of 82 Lesson Title: Large Break LOCA ID Number: 2K7 NRC-01 Assessor:

Dave Minnich Id' , QUALITATIVE ATTRIBUTES Revision:

Q - Y-4. - NIA-7. - Y-IO. - Y-I I. Y 12. _. Y-13. 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.

The scenario consists mostly of related events. Each event description consists of - - - - - 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.

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. . The simulator modeling is not altered. 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. 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.

Level of difficulty is appropriate to support licensing decisions for each crew position. 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)

Page 80 of 82 Lesson Title:

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

Q Note: Following criteria list scenario traits that are numerical (QUANTITATIVE) in nature. Ll' 01 I 02. 03. 04. 05. 06. - -- 07. 08. 09. 10. Total Malfunctions (TM) - 5 to 8 required Total 10 (1) MSR Tube Leak, (2) PZR Level Failure, (3) Steam Flow Failure, (4) DRPl Failure, (5)

Loss of DC Bus Power (6) RCP Oil Reservoir Leak, (7) LOCA in CTMT, (8) ESF Auto Actuation Failure (SI), (9) AFW pumps fail to Auto Start, (10) ESF Auto Actuation Failure (CDA)

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) Abnormal Events (AE) - 2 to 4 required Total 6 (1) Rapid Downpower (AOP 3575), (2) PZR Level Failure (AOP 3571), (3)

Steam Flow Failure (AOP 3571), (4) DRPI Failure (AOP 3552), (5) Loss of DC Bus Power (AOP 3563), (6) RCP Oil Reservoir Leak Major Transients (MT) - 1 to 2 required Total 1 EOP's (EU) entered/requiring substantive actions -- 1 to 2 required EOP Contingencies requiring substantive actions [ECAs/FRs/I (EC) -- Total 1 0 to 2 required (1) LOCA inside CTMT Total 2 (1) E-1, (2) FR-Z.l (1) FR-2.1 Critical Tasks (CT) - 2 to 3 required Total 4 E-O- D *4 - F E E *4-C Manually actuate at least one train of SI before completion of step 4 of E-0. Establish 530 gpm of AFW flow before transitioning out of E-0. Establish at least one train of QSS spray before completion of step 4 of FR-Z.1. Trip all RCP's before an Orange Path on core cooling. Approximate Scenario Run Time: 60 to 90 min. Total smin EOP run time: Total 45 min Technical Specifications are exercised during the scenario. (Y/N 1-y- Page 81 of 82

-:-

SUMMARY

OF CHANGES Change Description Date of Change Page 82 of 82

.d MILLSTONE POWER STATION SIMULATOR EXAM GUIDE APPROVAL SHEET Exam Title: Four Faulted Steam Generators Revision:

0 ID Number: 2K7 NRC-02 I 1 This document is the property of the Millstone Power Station which controls its prohibited without the written consent of the Millstone Power Station. distribution.

Further transfer, copying, or modification of this document is strictly Submitted by: D. Minnich 1 It1 1/07 Developer Date ,tiYl, Date Validated by: flbi7.L Technical Reviewer I 124b-l Date Approved by: Tya i n i ng S u pe rviso r 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 u.' 4. Exam Guide Attachments: - Shift Turnover Report - Validation Checklist - Scenario Outline (ES-D-I) - Attributes Checklist - Summary of Changes Page 2 of 68 SECTION 3 L' EXAM OVERVIEW Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Exam Brief: Revision:

0 1. 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, Instrument Failure Response, to respond to the failure. The procedure should be completed up to and including addressing any required Technical Specifications. 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 VESSEL FLG LEAKOFF T*MP HI, to mitigate the event. Leakage will be in excess of the Tech Spec limit on Identified RCS leakage. The leak will be isolable.

The Session will begin with the plant at 100% power and at end of life. The "A" EDG is out After completion of AOP 3571, a feed flow instrument failure will occur on the "C" Steam After the crew has isolated the RCS leak, a narrow range Tc instrument will fail high. Rods ;x/ will begin stepping in. The crew will utilize AOP 3571, lnsfrurnenf 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 "A1 MSlV inside the Main Steam Valve Building.

Once the plant is tripped, the "A & "B" MSlVs will fail to close and the 'C" and "D" 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. 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.

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 3 of 68

3. Duration of Exam: 75 minutes Page 4 of 68 SECTION 4 EXAM GUIDE Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: - 0 All Control Room Conduct, Operations and Communications shall be in accordance with Master Manual 14 and applicable DNAP/DNOS standards. "Review the Simulator Operating Limits (design limits of plant) and the Simulator Modeling Limitations and Anomalous Response List prior to performing this exam scenario on the simulator. The evaluators should be aware if any of these [imitations may be exceeded." (NSEM 6.06) Page 5 of 68 SECTION 4 EXAM GUIDE Title: Four Faulted Steam Generators 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. tf 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 6 of 68

1. 2. 3. 4. 5. 6. 7. 8. 9. IO. 11. 12. (\ SEC I AN 4 Lesson Title: Four Faulted Steam generators ID Number: 2K7 NRC-02 INITIAL SETUP INSTRUCTIONS

(.' Revision:

0 START the Sun Workstation.

a. PLACE Recorder Power to ON. VERIFY that the current approved training load is loaded. REMOVE the step counter OVERRIDE and allow the counters to step out during the IC reset. RESET to IC XX (Based on IC 21) 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. PLACE Simulator to RUN. IF the Sun Workstation is running THEN go to SIM ACTIVE.

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

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. As needed, RESET Computer Terminals to At Power displays if 100% power IC. RESET Rad Monitor Screen to Status Grid. IF placing equipment OOS, THEN perform the necessary switch manipulations and hang appropriate tags, as required, listed under "Equipment 00s." Page 7 of 68

(' i SEt I ,3N 4 Lesson Title: Four Faulted Steam generators ID Number: 2K7 NRC-02 IN IT1 AL 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 Revision:

0 Page 8 of 68 Lesson Title: Four Faulted Steam generators TYPE 1 Name MALF 1 RP1 OA ID Number: 2K7 NRC-02 Sev. I Ramp 1 RSCU Boul I Description I Automatic Reactor Trip Failure (train A) SEC,, ,dN 4 MALF I RPIOB Revision:

0 I Automatic Reactor Trip Failure (train B) INITIAL SETUP INSTRUCTIONS MALF MALF RP08A RP08B MSI fails to auto actuate (train A) MSI fails to auto actuate (train B)

MALF I RPI 1 H I RPCCW components fail to position on an SI MALF MALF MALF MALF MALF MALF MALF MS12A "A" MSlV sticks open MS12B "B" MSIV sticks open RXOSA 100 30sec I RCS-PT455A fails high RXI 3E 0 2 "C" Feed Flow Channel fails low RCO4A 3 Reactor Vessel Flange Leakoff RC21 60% 3 Valve stem leakoff to the CDTT RX04A 100% RCS NR CL TE411B FAIL MALF Remote MALF MALF MALF MALF 110 (CV) I/O (EG) I/O (EG) 110 (EG) I/O (EG) I/O (EG) Ann O/R Page 9 of 68 ED1 0 75% 60 5 Degraded Grid Voltage EDROI +O.l 5 Grid Frequency shift EGO1 6 Main Generator Trip MSOPA 35 40 BTI "A" SG Fault into the MSVB MS07C 40 BTI "C" Safety Valve sticks open MSO7D 35 BTI "D" Safety Valve sticks open 3CHS*MV8104 - OPEN FALSE 3CHS*MV8104, Emerg. Boration Vv will not open. - - IA-3ENSACB-A GREEN OFF - DIG A BKR CNTL I A-3ENSACB-A-RED OFF - DIG A BKR CNTL 1 A-3E NS AC B-A-AM BE R OFF - - - DIG A BKR CNTL - - I-3EGO-PIA RED OFF DIG A Prelube Pump 1-3EGO-PIA GREEN OFF DIG A Prelube Pump MB8A 2-1 1 ON 34C Loss of Control Power I" (,' SEL I dN 4 Lesson Title: Four Faulted Steam generators INITIAL SETUP INSTRUCTIONS ID Number: 2K7 NRC-02 Revision:

0 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. P ANTISIMULATOR 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

1. 3333 or #3334 to reach the persotddepartrnent 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 10 of 68 (11' SEC I ,3N 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Event I : Failed Pzr Pressure Instrument P455A T+I min of RSCU=I This will fail Pzr Pressure Instrument crew Diagnose instrument failure turnover 455 high Activate us Enter AOP 3571 AOP 3571 Actions (rev 009-01) RO CREW RO As a result of the failed instrument, PZR spray valves will open and actual 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.

CREW Do not leave the rod selector switch in AUTO while diagnosing a related instrument failure unless the reason for rod movement is a turbine runback. If a reactor trip occurs, immediately go to E-0, Reactor Trip or Safety Injection. Determine the Initiating Parameter and Place the affected controller in MANUAL Stabilize the Plant Parameters AOP 3571 Entry Conditions AOP 3571 Step 1, CAUTION AOP 3571 Step 1, NOTE AOP 3571 Step 1 AOP 3571 Step 2 us It is desired that I&C personnel trip the bistables specified in this procedure. If, AOP 3571 Step 3, NOTE Page 11 of 68 SEC i ,dN 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

Q Task Time IDNMalf 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. Appropriate Attachment us Perform Corrective Actions Using Instrument Failure Pressurizer Pressure Channel Failure RO RO RO/ BOP Defeat the failed channel input. Pressurizer Press Select - Control Pressurizer Press Select - Record 3RCS-PS455F 3RCS-PS455G OT/OP AT Record Select - RCS- TS411 E Restore RCS pressure to normal, then Place PZR pressure control in automatic. When conditions have stabilized, Observe MB annunciators and AOP 3571 Step 3 Attach men t B AOP 3571 Attachment B Step 1 AOP 3571 Attachment B Step 2 AOP 3571 Attachment B Page 12 of 68 SEC 1 a3N 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Tech Specs - Log into 3.3.1 Action 6 (FU #7,9 &IO) and 3.3.2 Actions 20 and 21 (FU #I .d & 9.a). TRM - Log into TRM 3.3.2.1, Action 27..A. NOTE: If PZR pressure lowers to less than 221 8 psia, the US should enter T/S 3.2.5 Action b. for DNB Parameters.

NOTE: This is not the case. The us us SM /US RO parameters. Immediately report any unexpected or unexplained conditions to the Shift Manager. Trip the associated Reactor AOP 3571 Protection System bistable($):

Attachment B Step 4 Place a check mark in the box above the AOP 3571 appropriate channel that requires Attachment B Step 4.a tripping on pages 3 or 4 of this Attachment.

Refer to Technical Specification 3.3.1 AOP 3571 3.3.2, and3.3.3.5.

Attachment B Step 4. b Step 3 Refer to Technical Requirement 3.3.2.1 AOP 3571 Attachment B Step 4.c AOP 3571 Attachment B Step 4.d Check the existing bistable status to ensure a reactor trip will not occur when the failed channel is tripped. The following step will distinguish AOP 3571 whether the failure is within SSPS or the Attachment B Protection channel. Step 4.e NOTE If bistable status light(s) ( MB2D or AOP 3571 Page 13 of 68 SEC'I idN 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard T=2 mins of RXRIOG request RXR05 RXR34 RXR44 RXR4O RXR48 RXRI 20 - RPR40 RXRI 06 channel has failed.

The US should go to step 4.f. "OPEN" Protection Set 1 Door "TRIP" OTAT "TRIP" C3 "TRIP" Lo Pzr Press SI BIS "TRIP" Hi Pzr Press Rx Trip B/S "TRIP" Lo Pzr Press Rx Trip BIS "TRIP" P-11 PORV Logic B/S "CLOSE" Protection Set I Door SM /US RO SM /US MB4F) indicate that a single bistable input has tripped and channel indication is normal, PERFORM the following:

Request the I&C Department trip the appropriate bistables using Attachment B and Attachment S. Verify the appropriate bistable status lights are lit. If indicator 3RCS*PI 4558 is failed, Refer to TRM Table 7.4.1, Fire Related Safe Shutdown Components, "Reactor Coolant System." Request I&C Department perform corrective maintenance on failed instrument.

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- FT530 low. (RXl3E, 0%) tripped bistables and Attachment B Step 4.e AOP 3571 Attachment B Step 4.f AOP 3571 Attachment B Step 4.g. AOP 3571 Attachment B Step 5 AOP 3571 Attachment B Step 6 addressed Page 14 of 68 i < SEC I i3N 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) Actions Crew Crew When the feed flow channel fails low, first alarm will be SG (C) FLOW MISMATCH STM > FW, due to the "C" Feed Regulating Valve going closed. The BOP will take manual control of "C" FRV Controller and open the FRV. BOP BOP Do not leave the rod selector switch in AUTO while diagnosing a related instrument failure unless the reason for rod movement is a turbine runback. AOP 3571 Step 1 CAUTION If a reactor trip occurs, immediately go to AOP 3571 E-0, Reactor Trip or Safety Injection. Step 1 NOTE Determine the initiating parameter AOP 3571 and place the affected controller in step 1 MANUAL. Stabilize the plant parameters.

AOP 3571 step 2 Perform Corrective Actions Using AOP 3571 Appropriate Attachment Step 3 Instrument Failure Attachment Feed Flow Channel Failure L The following annunciators are symptoms of a failed feed flow instrument:

us Crew SG A (B) (C) (D) LEVEL DEVIATION SG A (B) (C) (D) FLOW MISMATCH FW MB5B 4- 11315,7 MBSB 5- > STM 1,3,5,7 Page 15 of 68

(' SE&. . J'N 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard SG A (6) (C) (D) FLOW MISMATCH If the failed feed flow channel is selected as the input to SG level control, Perform the following:

STM > FW BOP Verify the affected SG feed regulating valve controller is in MANUAL, BOP Restore SG level to normal. BOP Defeat the failed channel input by selecting the alternate channel on the feed flow selector.

When SG level is restored to normal and feedkteam flow are matched, Place the affected steam generator feed regulating valve controller in AUTO. There are no Technical Specifications or bistables to be tripped associated with the feed flow instruments.

BOP us When the plant calorimetric is based on feed flow, the program will automatically shift to an NI based output if any feed flow channel is X-tagged by the process computer.

RO /BOP When conditions have stabilized, MB5B 5- 2,41618 AOP 3571 Attachment L Step 1 AOP 3571 Attachment L Step 1.a AOP 3571 Attachment L Step 1.b AOP 3571 Attachment L Step 1.c AOP 3571 Attachment L Step 1.d AOP 3571 Attachment L Step 2 NOTE AOP 3571 Attachment L Step 2 NOTE AOP 3571 Attachment L Page 16 of 68 SEC.1 i3N 4 Lesson Title:

Four Faulted Steam Generators Revision:

Q ID Number: 2K7 NRC-02 Task Time IDNMaIf Instructor InformationlActivity Assign Expected Action Standard Observe MB annunciators and parameters.

Immediately report any unexpected or unexplained conditions to the Shift Manager. corrective maintenance on failed instrument.

Step 3 Step 2 US I SM Request I&C Department perform AOP 3571 Attachment L EVENT 3: RCS leak. Reactor Flange Leakoff leakoff into the CDTT. Flange leakoff to the CDTT increases to 20 gpm. T = AOP RSCU 3 (RC04A 3571 exited and RC21, 66%) 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-TEMP HI" MB4A-5-5 (rev 002-1 2), "RX VESSEL FLG LEAKOFF TEMP HI" 5-5, "RX VESSEL FLG LEAKOFF CORRECTIVE ACTIONS Page 17 of 68 ij SEC\l ,3N 4 (i Lesson Title: Four Faulted Steam Generators Revision:

0 ID Number: 2K7 NRC-02 I DNMa If Task Assign Time I n s t r u c t o r I n f o r rn at i o nlAc t iv i ty Expected Action Standard 3DGS-TI 401 will show temperature in excess of 140 degrees. CDTT level will be trending higher. Leak Rate is around 20 gpm. T = when called BOOTH inform the US that you will make notifications.

You will put together a team to make a CTMT entry to 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 identified leakage in excess of 10 gpm. 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> action statement.

Leakoff System is aligned to detect inner O-ring leakage.

T= REMOVE This will isolate the leakage. 3RCS*AV8032 MALF RO RO/BOP us us us us RO CONFIRM leakoff high temperature on OFF TEMP" (MB4). Step 1 MB4A 5-5 3DGS-TI 401, "RX FLANGE" "LEAK MONITOR 3DGS-LI 33, "GASEOUS MB4A 5-5 DRAINS" "CTMT DRAIN TK, "LVL", to determine leak rate (MBI). Step 2 IF RCS IDENTIFIED LEAKAGE is MB4A 5-5 greater than IO gpm, PERFORM the following: Step 3 NOTIFY the OMOC (Duty Officer). MB4A 5-5 Step 3.1 Refer To Technical Specification 3.4.6.2 and DETERMINE Limiting Condition for Operation. Step 3.2 MB4A 5-5 Closing 3RCS*AV8032, Rx flange MB4A 5-5 leakoff isolation, renders the Reactor Head Flange Leakoff System in capable of monitoring leakage per Surveillance Requirement 4.4.6.2.1 .e. Step 4 NOTE IF Reactor Flange Leakoff System is MB4A 5-5 aligned to detect inner O-ring leakage, ALIGN Leakoff System as follows: Step 4 CLOSE 3RCS*AV8032, "RX FLANGE MB~A 5-5 LEAK OFF ISOL" (MB4). Page I8 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard goes closed. RC21 Steps 4.2 and 4.3 must be carried out inside CTMT. 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 I narrow range Tc, isolated 3RCS*TE411 B (RXO4A) Step 4.1 CLOSE 3RCS*VlO4, reactor vessel MB4A 5-5 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 3DGS-TI 401, "RX FLANGE" "LEAK MB4A 5-5 OFF TEMP' (MB4). Step 4.5 Page 19 of 68 SEC I ION 4 (I Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

Q Task Time IDNMalf Instructor Information/Activity 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 The RO will place Rod Control in manual; PZR level control is already at 100% program. Steam Dumps not armed so no immediate impact us CREW Transition to AOP 3571, Instrument Failure Response Determine the initiating parameter and place the effective controller in manual. CREW Stabilize the plant parameters.

us Perform Corrective Actions Using Appropriate Attachment Instrument Failure RCS NR Temperature Channel Failure RO Defeat the failed channel input, Loop Temp Cutout - delta T Loop Temp Cutout - Tavg OT/OP delta T Record Select Check the following annunciators NOT LIT: TREF/AUCT TAVE DEVIATION MB4C 6-5 AOP 3571 Step 1 AOP 3571 Step 2 AOP 3571 Step 3 Attachment A AOP 3571 Att.A Step I AOP 3571 AKA Step 2 TAVE HI MB4C 5-6 Page 20 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard No action may be required depending on when crew placed rods in manual. RO Restore TAVE - TREF error to within 1 0 AKA Step 3 F and return rod control to automatic.

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

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

Observe ME3 annunciators and 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.

AOP 3571 Att.A Step 5 Note CREW When conditions have stabilized, AOP 3571 Att.A Step 5 Table 3.3.1 - FU 7, 8 Action 6 applies Table 3.3.2 - FU 5D Action 20 applies 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 bistables.

us/ Refer to Technical Specification 3.3.1 AOP 3571 SM Step 6b and 3.3.2. Att.A Page 21 of 68 i/ SEC.1 mJN 4 i Lesson Title: Four Faulted Steam Generators Revision:

0 ID Number: 2K7 NRC-02 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard RO Check the existing bistable status to AOP 357 Once the crew has determined T.S. requirements go to Event 5. BIS will not be tripped due to time considerations and that evolution was exercised during the PZR Pressure channel failure.

Att.A Step 6c ensure a reactor trip will not occur when the failed channel is tripped. 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 Do wnpo wer 0 A CONVEX reauested emergency AOP 3575 AOP 3575 Actions (Rev. 013) generation reduction as directed by C Step 1 NOTE OP 200.8, "Response to IS0 New England / 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 ) Page 22 of 68 i SEC; I I~N 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDA/Malf instructor InformationlActivity Assign Expected Action Standard CREW us us CREW us CREW us us BOP BOP annunciator is received, DO NOT go to AOP 3566, Immediate Boration. immediately perform step

9. Determine Power Reduction Rate (%/min). Check desired power reduction rate - EQUAL TO OR LESS THAN 5%/min. Check power reduction CONVEX REQUESTED Perform load reduction at 5%/min and Proceed to step 2 Check Rod Control In AUTO. Align EHC Panel Check turbine OPERATING MODE - MANUAL Check LOAD LIMIT LIMITING light - LIT Intermittently Press DECREASE LOAD pushbutton until LOAD LIMIT LIMITING light - NOT LIT Rotate LOAD LIMIT SET adjust knob at least one full turn in raise direction Select DECREASE LOADING RATE to ON AOP 3575 Step 1 AOP 3575 Step 1.a AOP 3575 Step 1.b AOP 3575 Step 1 .c AOP 3575 Step 2 AOP 3575 Step 3 AOP 3575 Step 3.a AOP 3575 Step 3.b AOP 3575 Step 3.c AOP 3575 Step 3.d AOP 3575 Step 3.e Page 23 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard T = initial 110 MALF EVENT 5: Emergency Boration Valve Fails to Open BOP Select LOAD RATE LIMIT Oh MIN to power reduction rate (Oh min) determined in step 1. If at any time the power reduction rate or final desired power level must be changed, Return to step 1. US/RO Verify Power Reduction Rate RO Check power reduction rate 5% MIN Check power reduction - REQUIRED TO STABILIZE PLANT Proceed to Step 5 If SI actuation occurs during this procedure, Go to E-0, Reactor Trip or safety Injection, and restore from rapid boration lineup.

initiate Rapid Boration Verify RCS makeup system in - AUTO START one boric acid transfer pump OPEN emergency boration valve (3CHS*MV8104). AOP 3575 Step 3.f AOP 3575 Step 4 NOTE AOP 3575 Step 4 AOP 3575 Step 4.a AOP 3575 Step 4.b AOP 3575 Step 4.b RNO AOP 3575 Step 5 CAUTION AOP 3575 Step 5 AOP 3575 Step 5.a AOP 3575 Step 5.b AOP 3575 Step 5.c Page 24 of 68

\ SEC I I~N 4 (. Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard 3CHS* MV8104, FALSE OPEN - RO Verify direct boric acid flow (3CHS-FI Perform the following to initiate gravity boration:

I. Place the charging line flow control valve in MAN. 2. OPEN at least one gravity feed boration valve. 183A) - INDICATED.

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 Time Energize all PZR heaters AOP 3575 Step 5.d AOP 3575 Step 5.d RNO AOP 3575 Step 5.f AOP 3575 Step 5.g Page 25 of 68 SEC, ,dN 4 Lesson Title:

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

0 Task Expected Action Standard Time I DAlMa If Instructor Information/Activity Assign Adjust Pzr Spray Valves to RO 50% setpoint RCS-PK455B RCS-PK455C AOP 3575 Step 5.h 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): min - Boration - - Total Power Change (A%) x I5 c Time BA Flow Rate Boration Time

= (25% x 15) / 75 gpm = 5.0 min us During power decrease, Modify boration time as necessary to maintain:

0 Rods above the Rod Insertion Limit 0 Tavg within to F of Tref AFD within COLR limits Check turbine load decrease - IN PROGRESS OR COMPLETED.

Proceed to NOTE prior to Step 7. us RO If a unit shutdown is being performed, the final Mwe load should be approximately 230 Mwe. AOP 3575 Step 5.k AOP 3575 Step 5.1 AOP 3575 Step 5.1 RNO AOP 3575 Step 7 NOTE Page 26 of 68 i SEI. .3N 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task instructor information/Activity Assign Expected Action Standard Time IDNMalf US/BOP BOP BOP BOP The BOP should adjust Load Set to 900 BOP MWe. BOP BOP US/RO Initiate Load Reduction.

Check turbine OPERATING MODE - MANUAL Check either of the following:

Rapid or gravity boration - IN PROGRESS OR Turbine load reduction - REQUIRED TO STABILIZE PLANT Check LOAD RATE LIMIT Oh MIN set at - 3% OR 5% Utilizing DECREASE LOAD pushbutton, Adjust LOAD SET to desired final Mwe Check power reduction - CONVEX REQUESTED.

Maintain initial MVAR loading during power reduction, unless directed otherwise.

Check boration - IN PROGRESS Verify Final Desired Turbine Load (Mwe) - LESS THAN 75% AOP 3575 Step 7 AOP 3575 Step 7.a AOP 3575 Step 7.b AOP 3575 Step 7.c AOP 3575 Step 7.6 AOP 3575 Step 7.e AOP 3575 Step 7.f AOP 3575 Step 7.g AOP 3575 Step 8 Page 27 of 68 Lesson Title:

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

0 Task Time I DAlMa f f Instructor Information/Activity Assign Expected Action Standard BOP US/BOP The US should recognize that 75% BOP power, two feedwater pumps will be required.

US/RO RO US/RO RO us Proceed to Step IO. The following step places one TD FW pump in manual while allowing the other TD FW pump to automatically unload during the downpower.

Align One Feedwater Pump For Automatic Unloading Verify removing a feedwater pump from service during the downpower - DESIRED Proceed to step 11. Verify Rod Position Check ROD CONTROL BANKS LIMIT LO - LO (MBBC 4 - 9) annunciator - LIT. Proceed to step ll.e and, E at any time, the annunciator is received, THEN Perform steps 1 1 .b, 1 1 .c and I 1 .d. Check ROD CONTROL BANKS LIMIT LO (MB4C 3 - 9) annunciator - LIT Proceed to NOTE prior to step 12 and, - IF the annunciator is received, THEN AOP 3575 Step 8 RNO AOP 3575 Step10 NOTE AOP 3575 Step 10 AOP 3575 Step 10.a AOP 3575 Step 1O.a RNO AOP 3575 Step 11 AOP 3575 Step ll.a AOP 3575 Step 1l.a RNO AOP 3575 Step 11 .e AOP 3575 Step 11 .e RNO Page 28 of 68 SECI 13N 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDAlMalf instructor InformationlActivity Assign Expected Action Standard Perform step I1 .f and I1 .g. us Restore From Rapid Boration.

AOP 3575 RO Check rapid OR gravity boration - IN AOP 3575 PROGRESS-Step 12.a US/RO 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 Step 12 Perform the following:

AOP 3575 Step 12.c RNO I. 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 Step 12.9 boron concentration as necessary to maintain: Rods above the Rod Insertion Limit Page 29 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Expected Action Standard Time IDAlMalf Instructor InformationlActivity Assign 0 0 AFD within COLR limits Tavg within 2 5°F of Tref us BOP BOP BOP us us us us Reduce Steam Supply To The MSRs.

Check reheat steam flow controllers - IN AUTOMATIC.

Using the MSR Startup Pressure Display on the Foxboro DCS, Verify symmetrical operation of the MSR reheaters during power decrease.

Using OP 3317, "Reheat and Moisture Separator," Perform manual adjustment of moisture separator reheater steam flow control valves, as necessary.

Check If RCS Sample Is Required. Verify change in Reactor Power - GREATER THAN 15% IN ONE HOUR Request Chemistry sample the RCS for iodine (between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> afler the power change.) Request Chemistry Department perform gaseous effluent samples and analysis (between 24 and 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> afler the power change) for the following process monitors : AOP 3575 Step 13 AOP 3575 Step 13.a AOP 3575 Step 13.b AOP 3575 Step 13.b RNO AOP 3575 Step 14 AOP 3575 Step 14.a AOP 3575 Step 14.b AOP 3575 Step 14.c Page 30 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time I DA/Malf Instructor InformationlActivity Assign Expected Action Standard . 3HVR-REIOB 3HVR-RE19B us Verify Target Power Level - LESS AOP 3575 us Continue power reduction to the final AOP 3575 THAN 50%. Step 15 desired target power level. WHEN Step 15 RNO 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 downpower (EDROI) 60.1 hz. corn p lete over 60 seconds. Freq will increase to T = 1 min after ED10 RSCU 5 EDROI Modify to 0.0, Modify to 58%, ramp 60 seconds. THEN REMOVE EDIO T = When RSCU 6 Generator Trip resulting in reactor Page 31 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

Q Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard the crew trip and four faulted SGs. identifies degraded grid voltage Generator trip results in turbine trip. The reactor will fail to automatically trip. 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 RO The BOP should identify the Main Generator and Turbine trip The RO should identify the 'first out' and automatic reactor trip failure and initiate a manual reactor trip from main board 4. The US should enter E-0 and direct the crew to carry out the immediate actions us 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 OP 3272 E-0 Entry Conditions E-0, Step 1, NOTE Page 32 of 68 SECI ,dN 4 (.' Lesson Title: Four Faulted Steam Generators Revision:

ID Number: 2K7 NRC-02 Time IDNMalf Task Instructor InformationlActivity Assign Expected Action Standard ADVERSE CTMT defined as GREATER THAN 180°F or GREATER THAN 1 o5 R/h, in containment.

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 Check reactor trip and bypass breakers - OPEN 0 Check rod bottom lights - LIT Check neutron flux - DECREASING E-0, Step 1, RNO [*I Critical Task - The RO needs to initiate a manual reactor trip from main board

4. p] RO TRIP the reactor. - IF reactor will NOT trip, THEN Verify Turbine Trip Check all turbine stop valves - CLOSED BOP Verify Power to AC Emergency E-0, Step 3 Busses BOP Check busses 34C and 34D - E-0, Step 3.a E-0, Step 2 E-0, Step 2.a Page 33 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard BOTH ENERGIZED Try to energize the affected buss(es) from its associated EDG. Check If SI Is Actuated ACTUATION annunciator - (MB4D 1-6 or MB2B 5-9) - LIT By observation of ESF Group 2 Status Panel lights, Verify both trains of SI - ACTUATED By observation of ESF Group 2 Status Panel lights, Verify both trains of SI - ACTUATED Check Reactor trip and bypass breakers Locally TRIP the reactor trip and bypass breakers.

RO Verify Service Water Pumps - AT LEAST ONE PER TRAIN RUNNING RO Verify Two RPCCW Pumps - ONE PER TRAIN RUNNING RO Verify ECCS Pumps Running us RO Verify SAFETY INJECTION - OPEN - - Check SI pumps - RUNNING Check RHR pumps - RUNNING E-0, Step 3.a, RNO E-0, Step 4 E-0, Step 4.a E-0, Step 4.b E-0, Step 4.b E-0, Step 4.12 E-0, Step 4.c RNO E-0, Step 5 E-0, Step 6 E-0, Step 7 Page 34 of 68 i/ SEL I dN 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard - Check two charging pumps - RUNNING BOP Verify AFW Pumps Running E-0, Step 8 Check MD pumps - RUNNING Check turbine - driven pump - RUNNING, IF NECESSARY E-0, Step 8.a E-0, Step 8.b BOP Verify FW Isolation E-0, Step 9 Check SG feed regulating valves Check SG feed regulating bypass valves - CLOSED Check FW isolation trip valves - CLOSED - CLOSED 0 0 Check TD FW pump - TRIPPED Check MD FW pumps - STOPPED 0 Check SG blowdown isolation valves - CLOSED 0 Check SG blowdown sample isolation valves - CLOSED 0 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 35 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard fuses early, the 10s are located on the page containing step 1 of E-2 in the exam plan. Yes Critical Task - The BOP needs to initiate a manual MSI from main board 5. The BOP should go to close on the A and B MSIV. ["I All ESF Group 3 lights will be lit except for the A and B MSIV. Isolated Check Ctmt pressure GREATER THAN 18 psia - OR Any SG pressure LESS THAN 660 psig Verify MSlVs and MSlV bypass valves - CLOSED BOP Initiate MSI. BOP - IF MSI will NOT actuate, THEN CLOSE the MSlVs and MSlV bypass valves. Check ESF Group 3 lights - LIT. RO Check if CDA Required Check Ctmt pressure is GREATER THAN 23 psia - OR Ctmt spray - INITIATED E-0, Step 10.a E-0, Step 10.b Step 10.b, RNO r] E-0, E-0, Step 1o.c E-0, Step 11 Step 11 .a E-0, Page 36 of 68

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

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard us BOP BOP BOP RO RO RO RO RO Several RPCCW components will need to be manually positioned as Proceed to Step 12. Verify CAR Fans Operating In Emergency Mode Check CAR fan status: CAR fans A and B - RUNNING CAR fan C - STOPPED STARTETOP CAR' fans as necessary.

Verify RPCCW Ctmt supply and return header isolations - OPEN Verify Train A and B RPCCW supply and return to chill water valves - OPEN Verify CIA Check ESF Group 2 status columns 2 through 10 - LIT Verify Proper ESF Status Panel Indication Verify ESF Group 1 lights - OFF 0 Verify ESF Group 2 lights - LIT E-0, Step1 1 .a, RNO E-0, Step 12 E-0 , Step 12.a E-0, Step 12.a, RNO Step 12.b Step 12.c E-0, Step 13 Step 13.a E-0, Step 14 E-0 , E-0, E-0, Page 37 of 68 SEC i ,dN 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard they failed to respond to the SI signal. CTMT will not be ADVERSE RO CREW RO RO us RCS has partially depressurized due to the faulted SGs. If pressure is greater than 1650 psia, the SI pump flow check is not necessary. The crew will check PORV block valves and proceed to step 17. Determine If ADVERSE CTMT Conditions Exist Ctmt temperature GREATER THAN 180°F - OR 0 Ctmt radiation GREATER THAN lo5 R/h, DO NOT use ADVERSE CTMT parameters.

Verify ECCS Flow Check charging pumps - FLOW INDICATED Check RCS pressure - GREATER THAN 1650 psia (1 950 psia ADVERSE CTMT)

Proceed to Step 16.e Check SI pumps - FLOW INDICATED E-0, Step 15 E-0, Step 15, RNO E-0, Step 16 Step 16.a E-0, E-0, Step4 6.b Step 16.b, RNO Step 16.e E-0, E-0, Page 38 of 68 r SECI idN 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard CREW should perform a short brief and come out of "Master Silence" at the completion of Step 16. BOP us With 4 faulted SGs, crew should not isolate flow to all SGs, and also should wait for procedural guidance before throttling less than 530 gpm total AFW flow. BOP BOP RO us T = When BOOTH When asked, REPORT, "all SLCRS SM/US Requested doors indicate closed, except for several Main Steam Valve Building doors, which indicate open." Check RCS pressure - LESS THAN 300 psia (500 psia ADVERSE CTMT)

Proceed to step 17. Verify Adequate Heat Sink Check NR level in at least one SG - GREATER THAN 8% (42% ADVERSE CTMT) Proceed to Step 17.d. Verify Total AFW Flow - GREATER THAN 530 gpm Verify AFW Valve Alignment - PROPER EMERGENCY ALIGNMENT Verify ECCS Valve Alignment - PROPER EMERGENCY ALIGNMENT Check Plant Status Verify SLCRS doors - CLOSED E-0, Step 16.f E-0, Step 16.f RNO E-0, Step 17 Step 17.a E-0, E-0, Step 17.a, RNQ Step 17.d E-0, E-0, Step 18 E-0, Step 19 E-0, Step 20 E-0, Step 20.a Page 39 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

Q Task Time IDAlMalf I n s t r u c t o r I n f o r m a t i o nlA c t i v i ty Assign Expected Action Standard RO RO BOP BOP BOP T = IO min BOOTH REPORT "All Control Building PEO from request pressure boundary doors are Closed and Dogged as applicable."

RO Check CONTROL BUILDING ISOLATION annunciator (MB4D 3-6) - LIT Verify ESF Group 2 CBI lights - LIT Verify control building purge supply fan and purge exhaust fan - NOT RUNNING Verify control building air bank isolation valves - OPEN (after 60 seconds) STOP kitchen exhaust fan CLOSE and DOG the following Control Building pressure boundary doors.

CB west 47'6" (C-47-1A)

CB east 64' 6 (C-64-1B) . Verify the following Control Building pressure boundary doors - CLOSED CB west 47'6" (C-47-1) 2. CB north 64'6" chiller room door (C- 64-4) 3. CB north 64'6" chiller room door (C- 4. CB west 49'6" (C-49-1) 64-5) Check RCS Temperature E-0 Step 20. b E-0, Step 20.c Step 20.d Step 20.e E-0, E-0, E-0, Step 20.f E-0, Step 20.9 E-0, Step 20.h E-0, Step 21 Page 40 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Task Revision:

0 Time IDNMalf instructor InformationlActivity Assign Expected Action Standard NO, RCS temperature is cold due to faulted SGs. Verify RCS cold leg WR temperature - BETWEEN 550°F AND 560°F. us Perform the applicable action: . - 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 and 600 gpm until NR level is GREATER THAN 8% (42% ADVERSE CTMT) in at least one SG CLOSE SG atmospheric dump and dump bypass valves Check the following valves - CLOSED BOP BOP MSlVs MSlV bypass valves us Perform the following:

E-0, Step 21 .a Step 21 .a, RNO E-0, E-0, Step 21 .e E-0, Step 21 .f E-0, Step 21 .g E-0, Step 21 .g, Page 41 of 68 SEC, .dN 4 il Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard BOP BOP us RO RO RO CREW RO us 1. Place both condenser steam dump interlock selector switches to OFF. 2. unexpected cooldown continues, - THEN CLOSE the MSlVs and MSlV bypass valves. Proceed to Step 22 Check PZR Valves Verify PORVs - CLOSED Verify normal PZR spray valves - CLOSED Verify PZR safety valves - CLOSED To prevent damage to the RCP seal(s), seal injection flow should be maintained to all RCPs. Check If RCPs Should Be Stopped Verify RCPs -ANY RUNNING Proceed to Step 24 RNO E-0, Step 21 .b E-0, Step 22 Step 22.a Step 22.b Step 22.c E-0, Step 23, CAUTION E-0, Step 23 Step 23.a Step 23.a, RNO E-0, E-0, E-0, E-0, E-0, Page 42 of 68 SECI i3N 4 (: Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Assign Expected Action Standard Time I DAlMa If Instructor InformationlActivity BOP/RO 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 transition to E-2. NO SG PRESSURE 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 NOTE: For E-2, step 1 RNO, the PEO should not be indiscriminately dispatched to do all of Attachment A. Some valves are in MSVB and some will isolate flow to the TDAFW Pump.

0 At least one SG must be maintained available for RCS cooldown.

0 Any faulted SG or secondary break should remain isolated during subsequent recovery actions unless needed for RCS cooldown or sampling is required.

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. 0 E-2 CAUTION Page 43 of 68 i:. Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard "A and "B" MSlVs are open and will not close. T=2min BOOTH 10s to simulate PEO removing fuses from being as needed to de energize "A and "B dispatched.

MSIVs, which will remain open.

If the crew elects to pull just one set then enter the Train A 10s only. 3MSS*CW27A_TRA Green "Off" 3MSS*CTV27A_TRA Red "Off" 3MSS*CTV27A_TRB Green "Off" 3MSS*CW27A_TRB Red "Off' 3MSS*CTV27B_TRA Green "Off" 3MSS*CTV27BeTRA Red "Off" 3MSS*CTV27B_TRB Green "Off' 3MSS*CTV27B-TRB Red "Off" All 4 SGs are depressurizing. Crew should transition to ECA-2.1, BOP us Check Main Steam Isolation And Bypass Valves - CLOSED BOP CLOSE valves. - IF flow path(s) can NOT be isolated, THEN Using Attachment A for guidance, Locally Close valvets).

us Check At Least One SG Secondary Boundary Is Intact ROI Check pressures in all SGs - AT LEAST BOP ONE STABLE OR INCREASING us - IF all SG pressures decreasing in an uncontrolled manner, THEN Go to ECA-2.1 , Uncontrolled Depressurization of All Steam Generators.

E-2, Step I E-2, Step I RNO E-2, step 2 E-2, step 2.a E-2, Step 2.a RNO ECA-2.1, Uncontrolled Depressurization of All Steam Generators (Rev 014-03). Page 44 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 a If any SG pressure increases at ECA 2.1 Step any time, except while 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.1, 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. 1 CAUTION

' . Crew Foldout page must be open. ECA 2.1 Step 1 NOTE Check Secondary Pressure Boundary ECA 2.1 Step 1 BOP Verify MSlVs and MSlV bypass valves - CLOSED I .a Initiate MSI. ECA 2.1 Step ECA 2.1 SteD Local actions of this step were initiated in E IF MSI will actuate, 1.a RNO - THEN Page 45 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard CLOSE the MSlVs and MSIV bypass valves - IF MSlVs NOT close, THEN MSIV bypass valves will - Using Attachment B, Pull the affected valve(s) fuse block. BOP Check SG isolation 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 Verify SG blowdown sample isolation valves - CLOSED 0 Verify SG chemical feed isolation valves - CLOSED ECA 2.1 Step 1.b 0 Using table, Verify main steam line Page46of68 1

SECTILJN 4 SG B SGC c SGD Lesson Title: Four Faulted Steam Generators 3 DTM*AOV29 B 3DTM*AOV61 B Revision:

0 ID Number: 2K7 NRC-02 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard 3DTM*AOV29C 3DTM*AOV29D 3DTM*AOV61 C 3DTM*AOV61 D ~ SG A 3DTM*AOV29A 3DTM*AOV61A 3DTM*AOV63A 3DTM*AOV63B 3 DTM*AOV64 B 3DTM*AOV63D 3DTM*AOV64D 3DTM*AOV64A BOP Check MD AFW pumps - TWO RUNNING The US should direct the steam supply valves to TD AFW pump be closed since the MD AFW pumps are running. 0 3MSS*MOV17A 0 3MSS*MOV17B e 3MSS*MOV17D US/BOP Verify steam SUPPlY valves to TD AFW pump - CLOSED BOP CLOSE valves. - IF valve(s) will NOT close, THEN Locally Close valve(s). To prevent inadvertent reactor criticality, the required shutdown margin must be maintained during RCS cooldown.

Verify Shutdown Margin ECA 2.1 Step 1 .c ECA 2.1 Step 1 .d ECA 2.1 Step 1.d RNO ECA 2.1 Step 2 NOTE ECA 2.1 Step Page 47 of 68 SECTiuN 4 i Lesson Title: Four Faulted Steam Generators Revision:

Q ID Number: 2K7 NRC-02 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard No, cooldown rate will be greater than 8O0F/hr. Critical Task - Control the AFW flowrate to at least 100 gpm per SG in order to minimize the RCS cooldown rate. PI us Request Chemistry sample the RCS for boron concentration Check RCS sample results - AVAl LABLE Proceed to CAUTION prior to step 3 and, WHEN Sample results become available, THEN Perform step 2.c Using OP 3209B, "Shutdown Margin,"

Check shutdown margin. A minimum feed flow of 100 gpm must be maintained to each SG with a NR level LESS THAN 8% (42% ADVERSE CTMT). Control Feed Flow To Minimize RCS Cooldown. Check cooldown rate in RCS cold legs - LESS THAN 80°F/hr. Decrease AFW flow to 100 gpm to each SG and Proceed to Step 3c. us us RO BOP 2 ECA 2.1 Step 2.a ECA 2.1 Step 2.b ECA 2.1 Step 2.b RNO ECA 2.1 Step 2.c ECA 2.1 Step 3 CAUTION ECA 2.1 Step 3 ECA 2.1 Step 3.a ECA 2.1 Step 3.a RNO [*3 Page 48 of 68 SECi *A 4 (\ Lesson Title:

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

0 . Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Check NR level in all SGs - LESS THAN 50%. Control feed flow to maintain NR level LESS THAN 50% in all SGs. Check RCS hot leg WR temperatures - STABLE OR DECREASING. NOTE: this is a continuous action step to prevent the RCS from heating back up after the initial cooldown from the faulted SGs. This assists in maintaining the plant stable. RO/BOP Control feed flow or Dump steam to stabilize RCS hot leg WR temperatures.

0 Seal injection flow should be maintained to all RCPs.

As RCS pressurizes due to faulted SGs completing blowdown and SI injecting, PORV will start to cycle. 0 Step 4 for stopping RCPs is applicable until SI is terminated in step 20. Check If RCPs Should Be Stopped.

RO Check RCPs - ANY RUNNING us Proceed to CAUTION prior to step 5. If any PZR PORV opens because of high PZR pressure, Step 5a must be repeated after pressure decreases to LESS THAN 2350 psia. ECA 2.1 Step 3.b ECA 2.1 Step 3.b RNO ECA 2.1 Step 3.c ECA 2.1 Step 3.c RNO ECA 2.1 Step 4 NOTE ECA 2.1 Step 4 ECA 2.1 Step 4.a ECA 2.1 Step 4.a RNO ECA 2.1 Step 5 CAUTION Page 49 of 68 SECTILJN 4 Lesson Title:

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

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RO Check PZR PORVs And Block Valves ECA 2.1 Step 5 RO RO us Verify PORVs - CLOSED. IF PZR pressure is LESS THAN 2350 psia, 5.a RNO THEN CLOSE PORVs. - IF any PORV can NOT be closed, THEN CLOSE its block valve. ECA2.1 Step 5.a ECA 2.1 Step - 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 1. RESET SG blowdown sample isolation

2. OPEN SG blowdown sample isolation valves 3. Request Chemistry obtain activity samples using HP coverage Page 50 of 68 c Lesson Title: Four Fablted Steam Generators Revision:

0 ID Number: 2K7 NRC-02 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RO Verify trend history and alarm status of radiation monitors 6.b Main steam line - NORMAL ECA 2.1 Step 0 0 Condenser air ejector - NORMAL SG blowdown - NORMAL ECA 2.1 Step ECA 2.1 Step RO Check If RHR Pumps Should Be Check RHR pumps - ANY RUNNING IN INJECTION MODE. 7.a Stopped. 7 Check RCS pressure.

ECA 2.1 Step 7.b Pressure - GREATER THAN 300 psia (500 psia ADVERSE CTMT) Pressure - STABLE OR INCREASING.

ECA 2.1 Step 7.b.l ECA 2.1 Step 7.b.2 RESET ESF actuation signals ECA 2.1 Step 7.c . SI . CDA LOP . CIA . CIB Page 51 of 68 SECTi4 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor Information/Activity Assign Expected Action Standard STOP RHR pumps and Place in AUTO. The recirculation spray pumps are sequenced to automatically start 11 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 ECA 2.1 Step 7.d ECA 2.1 Step 8 NOTE 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 - I .3, Transfer to Cold Leg Recirculation.

RO Check If Accumulators Should Be ECA 2.1 Isolated.

Step 10 ECA 2.1 Step 9 RNO RCS HL temperature should be < 380°F Verify at least two RCS hot leg WR temperatures - LESS THAN 380°F. ECA 2.1 Step 1O.a Proceed to Step 11. ECA 2.1 Step 1O.a RNO Page 52 of 68 SECTiuI\I 4 Lesson Title: !%J r Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard T= 5 min from being dispatched Remote Actions (if temperature is - LESS THAN 380°F). Using GA-7, Isolate SI accumulators SIRl5, RI SIRIG, RI SIR17, RI SIRl8, RI RO Check If ECCS Flow Should Be Reduced. Verify RCS subcooling based on core exit TCs - GREATER THAN 32°F (1 15°F ADVERSE CTMT). Verify RCS pressure - STABLE OR I NCREAS I NG. Verify PZR level - GREATER THAN 16% (50% ADVERSE CTMT).

m If offsite power is lost after SI reset, manual actions to restart safeguards equipment may be required.

DO NOT reset CDA if the recirculation spray pumps are required and have not auto mat ica I I y started . ECA 2.1 Step 10.b ECA 2.1 Step 11 ECA 2.1 Step 1l.a ECA 2.1 Step 11 .b ECA 2.1 Step 11 .c ECA 2.1 Step 12 CAUTION Page 53 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard RO BOP BOOTH INSTRUCTOR:

PEO T=+8of EDRl8 Energize MCClA3 (32-3T) request "RESET" EDR44 after 3T reset) "RESET" Reset Batt/lnv 6 Trouble (- 5 min RO w If any SG pressure increases, Complete Steps 12 through 27, then Go to E-2, Faulted Steam Generator Isolation. RESET ESF Actuation Signals SI = CDA LOP w CIA CIB Restore Power To MCC 32-3T. Check emergency bus 34C - ENERGIZED Using GA-1, Energize MCC 32-T Establish Instrument Air To Ctmt. Check instrument air compressors - AT LEAST ONE RUNNING. ECA 2.1 Step 12 ECA 2.1 Step 13 ECA 2.1 Step 13.a ECA 2.1 Step 13.b ECA 2.1 Step 14 ECA 2.1 Step 14.a Page 54 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Time I DAlMa If Instructor InformationlActivity Assign Expected Action Standard OPEN instrument air Ctmt isolation valves. STOP All But One Charging Pump And Place In AUTO. Check RCS Pressure - STABLE OR INCREASING . RO RO RO Establish Normal Charging Flow Path. Fully Open charging line flow control valve. Verify charging header loop isolation valves (3CHS*AV8146 or Re-position valves to establish only one open.

3CHS*AV8147) - ONE OPEN. OPEN charging header isolation valves 3CHS*MV8106 3CHS*MV8105 CLOSE the charging pump miniflow isolations to the RWST ECA 2.1 Step 14.b ECA 2.1 Step 15 ECA 2.1 Step 16 ECA 2.1 Step 17 ECA 2.1 Step 17.a ECA 2.1 Step 17.b ECA 2.1 Step 17.b RNO ECA 2.1 Step 17.c ECA 2.1 Step 17.d 3CHS*MV8511 A 0 3CHS*MV8511 B Page 55 of 68 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Time RO Step 19 Remove "C" Low Set SG Code Safety Valve RO commenced MS07C closes. Per NOTE prior to step I of ECA-2.1, If any SG pressure increases at any time, except while performing SI termination in Steps 12 through 27, GO to E-2. CLOSE the remaining charging pump cold 'leg injection valves 3SlH*MV880IA 3SIH*MV8801B OPEN the charging pump recirculation isolation valves 0 3CHS*MV8111A 0 3CHS*MV8111 B 3CHS*MV8111 C 3CHS*MV8110 Verify PZR Level Check PZR level - STABLE OR INCREASING Control charging flow to maintain PZR level. Check If SI Pumps Should Be Stopped. Check SI pumps - RUNNING. ECA 2.1 Step 17.e ECA 2.1 Step 17.f ECA 2.1 Step 18 ECA 2.1 Step 18.a ECA 2.1 Step 18.b ECA 2.1 Step I9 ECA 2.1 Step 19.a Page 56 of 68 SECbrId 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 IDNMalf Revision:

0 Task Assign Time I n s t r u c to r I n f o rm a t i o nlAc t iv i ty Expected Action Standard RO RO RO/BOP Check RCS pressure ' Pressure - GREATER THAN 1650 psia (1 950 psia ADVERSE CTMT).

Pressure - STABLE OR INCREASING. STOP SI pumps and Place in AUTO. At the completion of step 20 stopping RCPs based on the conditions of step 4 is NOT required.

STOP RHR Pumps and Place In AUTO. Verify ECCS Flow Not Required. Check RCS subcooling based on core exit TCs - GREATER THAN 32°F (I 15°F ADVERSE CTMT).

Check PZR level - GREATER THAN 16% (50% ADVERSE CTMT). Check RCS Hot Leg WR Temperatures - STABLE OR DECREASING.

ECA 2.1 Step 19.b ECA 2.1 Step 19.c ECA 2.1 Step 20 NOTE ECA 2.1 Step 20 ECA 2.1 Step 21 ECA 2.1 Step 21 .a ECA 2.1 Step 21.b ECA 2.1 Step 22 Page 57 of 68 SECt'td 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

Q Task Standard instructor InformationlActivity Assign Expected Action Time IDAlMaif BOP Control AFW flow OR Dump steam to stabilize RCS hot leg WR temperatures.

Check NR Level In All SGs - LESS THAN 50%. Control AFW flow to maintain NR level LESS THAN 50% in all SGs. BOP RO Check If Letdown Can Be Established.

Verify PZR level - GREATER THAN 25% (50% ADVERSE CTMT). Verify Train A RPCCW pump RUNNING. Using GA - 13, Establish normal letdown Proceed to step 25. RO Check RCS Makeup System. Adjust boric acid flow controller to pot setting 8.3. Check RCS makeup - ALIGNED FOR AUTO ECA 2.1 Step 22 RNO ECA 2.1 Step 23 ECA 2.1 Step 23 RNO ECA 2.1 Step 24 ECA 2.1 Step 24.a ECA 2.1 Step 24.b ECA 2.1 Step 24.c ECA 2.1 Step 24.d ECA 2.1 Step 25 ECA 2.1 Step 25.a ECA 2.1 Step 25.b Page 58 of 68 SECfidN 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

0 Task Expected Action Standard Time IDNMalf Instructor InformationlActivity Assign RO Align Charging Pump Suction to VCT. OPEN VCT to charging isolation valves. 0 3CHS*LCVl I28 0 3CHS*LCV112C CLOSE RWST to charging isolation valves. 3CHS*LCV112E RO Control PZR Pressure. Maintain pressure stable using PZR heaters and normal spray as necessary. - IF normal spray NOT available and letdown is in service, THEN Establish auxiliary spray: ECA 2.1 Step 26 ECA 2.1 Step 26.a ECA 2.1 Step 26.b ECA 2.1 Step 27 ECA 2.1 Step 27.a ECA 2.1 Step 27.a RNO 1) Unlock and OPEN auxiliary spray valve (3RCS*AV8145).

Page 59 of 68 SEC$wi\I 4 Lesson Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

Q Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard 2) CLOSE charging header loop isolation valves e 3CHS*AV8146 e 3C HS*AV8 I 47 Throttle charging flow controller to adjust and maintain auxiliary spray flow. - IF 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 Safetv closed and verbalizes their intention of transitioning to E-2 after the competion of step 27. Page 60 of 68 SECTION 4 I* Lesson Title:

Four Faulted Steam Generators

'*J ID Number: 2K7 NRC-02 EVALUATION GUIDE

1. Crew FOLLOW-UP QUESTIONS Revision:

Q 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 61 of 68 SECTION 4 EXAM GUIDE

SUMMARY

Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision: d 11. Critical Tasks Note: Critical Tasks are not required for Progress Review Exams. TASK DES C R I PT I 0 N Attempt to manually trip the reactor from the control room with either Main Board trip switch or by opening 328 and 32N supply breakers before completing step 1 of E-0. Manually actuate Main Steamline isolation or close MSlVs before a severe (orange path) challenge develops to either the subcriticality or the integrity CSF or before transition to ECA-2.1, whichever happens first TASK # WA >I= 3.0 BASIS FOR SELECTION E-0 -- A 029-EA1.08 (BASIS) Failure to manually trip the 4.514.5 029-EAI .

12 4.114.0 irreparably introduced by the reactor causes a challenge to the subcriticality CSF beyond that postulated conditions. Additionally, it constitutes an "incorrect performance that necessitates the crew taking 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." E-O-P El 2-EA;. 1 3.813.8 039-K4.05 3.713.7 Control the AFW flow rate to ECA- .3 at least 100 gpm per SG in 3.413.9 2.1 --A order to minimize the RCS cooldown rate before a severe (orange-path) challenge develops to the integrity CSF Note: [*I Used to designate critical tasks.

Should also be incorporated into column 3 or 4 of Instructor Guide.

Failure to close the MSlVs under the postulated plant conditions causes challenges to CSFs beyond those irreparably introduced by the postulated conditions. Such an omission constitutes a "demonstrated inability by the crew to recognize a failure of the auto actuation of an ESF system or component and to take an action that would prevent a challenge to plant safety." Failure to control the AFW flow rate to the SGs leads to an unnecessary and avoidable severe challenge to the integrity CSF and to the subcriticality and the containment CSFs beyond those irreparably introduced by the postulated plant conditions. Thus, failure constitutes "demonstrated inability by the crew to take an action or combination of actions that would prevent a challenge to plant safety." Page 62 of 68 SHIFT TURNOVER REPORT DATE-TIME today 0300 i/' PREPAREDBY SHIFT Unit Supervisor /"Night" Shift 1800-0600

-4' LCO Action Date Action Requirement Time in LCO Time Left PLANT STATUS: Mode: 1 RxPower: 100% System TPCCW Notes I "C" TPCCW ~urnt~ is out of service for an oil replacement.

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 /> /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 yesterday 1 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> I I 13 days OD Compensatory Actions I Temp Logs Reason I Watch Position OpenDate I ClassReason I I cross Unit System Status I I Surveillances I Evolutions in Progress I I 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.

I Page 63 of 68 ATTACHMENT 2 VALIDATION CHECKLIST Title: Four Faulted Steam Generators ID Number: 2K7 NRC-02 Revision:

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

0 Verified By: (Initials) 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 NIA . 0 +-- ~.&' 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 Examination Scenario : The Scenario Attributes Checklist is complete and attached. This is not n required fcr Progress Review Exams. Page 64 of 68 Appendix D Scenario Outline Form ES-D-1 Facility: Millstone 3 Scenario No.: 2K7 NRC-02 Op-Test No.: 2K7 Examiners: Operators:

Initial Conditions:

IC-21, 100% power, End of Life, Equilibrium Xe. Turn over:

The plant is at 100% power and at end of life. The "A" Emergency Diesel Generator is out of service for routine maintenance.

The "C" TPCCW pump is out of service for oil replacement.

RPlOAlB C (BOP) 7 MS02A M (ALL) MSO7C/D C (BOP) MS12A/B C(R0) ~ RP08 ~ RP11 H Event Description Controlling channel of PZR pressure fails high.

Controlling channel of "C" Steam Generator feed flow fails RCS leak. Reactor Vessel Flange leakoff. Loop 1 Tavg fails high (loop 1 narrow range Tc, 3RCS*TE411 B) CONVEX directed Emergency Load Reduction. AOP 3575, Rapid Downpower. Emergency Boration valve fails to open. P IOW (3MSS-FT530). Main Generator trip and automatic reactor trip failure. Four faulted Steam Generators. Main Steam Isolation fails to automatically actuate. Several RPCCW components fail to respond to a Safety Injection signal.

I I c (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 65 of 68 Lesson Title: Four Faulted Steam Generators Revision:

Q ID Number: 2K7 NRC-02 Assessor:

Dave Minnich -u QUALITATIVE ATTRIBUTES

-- Y 1. 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: - - - - - 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 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. 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. - Y-5. - Y-6. - NIA-7. -- Y 8. The simulator modeling is not altered. Y 9. The scenario has been validated.

Pursuant to IO 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.

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. w- -- -- Y 10. -- Y 11. - Y-12. AI1 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.

Level of difficulty is appropriate to support licensing decisions for each crew position.

-- Y 13. .I ...---- Page 66 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. s .,-' 01. 02. 03. 04. 05. 06. -- 07. 08. 09. Total Malfunctions (TM) - 5 to 8 required (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 St Malfunctions after EOP entry (EM'S) - 1 to 2 required (1) Four Faulted SGs. (2) MSI Auto Actuation Failure, (3) RPCCW Components Fail to Auto position on an SI Abnormal Events (AE) - 2 to 4 required (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) Major Transients (MT) - 1 to 2 required EOP's (EU) enteredkquiring substantive actions -- 1 to 2 required EOP Contingencies requiring substantive actions [ECAs/FRs/I (EC) -- 0 to 2 required Critical Tasks (CT) - 2 to 3 required (1) Four Faulted SGs (1) E-2, (2) ECA-2.1 (1) ECA-2.1 *4- A E-U - P the Subcriticality or Integrity CSFs. ECA-2.7 - A RCS cooldown rate. Manually trip the reactor from the control room before completion of step 1 of E-0. Manually actuate MSI or close the MStVs before a severe challenge develops to Control the AFW flowrate to at least 100 gpm per SG in order to minimize the Approximate Scenario Run Time: 60 to 90 min. EOP run time:

Total 9 Total 3 Total 5 Total 1 Total 2 Total 1 Total 3 Total amin Total 45 min IO. Technical Specifications are exercised during the scenario.

Page 67 of 68

SUMMARY

OF CHANGES Change Description Date of Change Page 68 of 68 d MILLSTONE POWER STATION SIMULATOR EXAM GUIDE APPROVAL SHEET Exam Title: Loss of All AC Power Revision:

0 ID Number: 2K7 NRC-03 (jp9,{k-)

/ 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. 4 Submitted by: Developer -y Date Date Validated by: Technical Reviewer Approved by: k Training Supervisor Date 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 i-' 4. Exam Guide Attachments: - Shift Turnover Report - Validation Checklist - Scenario Outline (ES-D-1) - Attributes Checklist - Summary of Changes Page 2 of 59 SECTION 3 EXAM OVERVIEW Title: ID Number: 2K7 NRC-03 Loss of All AC Power Revision: - 0 1. 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. The crew will take the shift with reactor power stable at the point of adding heat (reactor 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, F'ZR 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 lnstrument (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, lnstrument 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 RANG* 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 it's 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, 'U' transition to ECA 0.0, Loss of A// 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 3 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 "B" EDG will be able to be started locally using ECA-0.0, Attachment E. The "B" EDG 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 priorto step 6. Low pressurizer level will necessitate a transition to ECA 0.2, Loss ofAll AC Power- Recovery with SI Required.

The session will end when the crew announces the transition to ECA-0.2. - iJ' 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 Le-' Page 4 of 59 SECTION 4 EXAM GUIDE Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision: - 0 All Control Room Conduct, Operations and Communications shall be in accordance with Master Manual 14 and applicable DNAPIDNOS standards. "Review the Simulator Operating Limits (design limits of plant) and the Simulator Modeling Limitations and Anomalous Response List prior to performing this exam scenario on the simulator, The evaluators should be aware if any of these limitations may be exceeded." (NSEM 6.06) Page 5 of 59 SECTION 4 EXAM GUIDE Title: Loss of All AC Power ID Number: 2K7 NRC-03 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: I. 2. 3. 4. 5. 6. 7. Place the simulator in FREEZE if possible.

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

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

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 6 of 59

1. 2. 3. 4. 5. 6. 7. 8. 9. 7 0. (\. Lesson Title: Four Faulted Steam generators ID Number: 2K7 NRC-02 INlTlA SEC ,3N 4 , SETUP INSTRUCT10 Revision:

0 JS START the Sun Workstation.

a. PLACE Recorder Power to ON. VERIFY that the current approved training load is loaded. REMOVE the step counter OVERRIDE and allow the counters to step out during the IC reset. RESET to IC XX (Based on IC 07) 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. PLACE Simulator to RUN. If Necessary, RESET the Plant Calorimetric at the Instructor Station PPC by Pressing "SHIFT LEFT" and "F6" simultaneously. 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 M66. 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.

As needed, RESET Computer Terminals to At Power displays if 100% power IC. IF the Sun Workstation is running THEN go to SIM ACTIVE. 11. RESET Rad Monitor Screen to Status Grid.

Page 7 of 59 i SEC I ION 4 ( Lesson Title: Four Faulted Steam generators ID Number: 2K7 NRC-02 INITIAL SETUP INSTRUCTIONS Revision:

0 12. 13. IF placing equipment OOS, THEN perform the necessary switch manipulations and hang appropriate tags, as required, listed under "Equipment 00s." 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 pagelcall the Unit Tech. Initial Malfunctions/l Os/l DAS: PLACE GREEN PLACARDS FOR ALL INTAKE PARAMETERS ON Mi36 PLACE THE "B" TRAIN PROTECTED PLACARD ON MB4 ENSURE THE BORIC ACID POT SETTING IS ABOUT 5.9 Page 8 of 59 (1 Lesson Title: Four Faulted Steam generators Sev. SEC I ION 4 Ramp 1 RSCU Boul 1 Description 30 1 EDG "A" Load Limiter Failure B EDG Fails to Start ID Number: 2K7 NRC-02 INITIAL SETUP INSTRUCTIONS MALF MALF MALF MALF MALF Remote TYPE I Name MALF I EGO68 MALF I EG08A CCOIB RCO7A N109C CV13A ED1 0 EDROI I MALF 1 FW2OC 100% 6.5% 3 4 PRNI Channel 43 lower det fails high "A" RCP #I seal degrades 1 MALF I ED01 75% I 60 I 5 1 Degraded Grid Voltage Revision:

0 +0.1 I 5 1 Grid Frequency Degradation I I I I TD AFW pump Fails to automatically start I 6 I I1 I 1 "B"RPCCWpumptrip.

I I LOSS of Offsite Power I 1% I 121 I "A" PZR PORV Leak. Page 9 of 59 i' (\. SECi, 83N 4 Lesson Title: Four Faulted Steam generators ID Number: 2K7 NRC-02 INITIAL SETUP INSTRUCTIONS L Revision:

0 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

1. 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 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 IO of 59

(, SECTtbid 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 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 rods be used to raise reactor power us INCREASE reactor power to between 6% and OP 3203 RO WITHDRAW control rods at a rate not greater than approximately 2 stepdminute DILUTE RCS boron concentration at a rate not greater than approximately IO to 15 pcmlminute.

9% by one of the following:

Step 4.2.8 PERFORM the following:

OP 3203 a. b. WHEN desired, Refer To OP 3331A, Step 4.2.9 LOG MODE change to MODE 1, POWER OPERATION.

NOTIFY ISO-New England of the MODE change. OP 3203 Page 11 of 59 i SECTIVI\I 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard "Auxiliary Boiler, Steam and Condensate," and SHIFT auxiliary steam from auxiliary boiler (A or B) to main steam while continuing with this procedure.

PERFORM one of the following:

Step 4.2.10 OP 3203 Step 4.2.1 1 IF power increase desired, Go to Section 4.3 IF reactor shutdown desired, Go to OP 3206, "Plant Shutdown".

EVENT I (cont'd):

Running RPCCW pump trip, alignment and start of the standby RPCCW , pump. T= MODE I RSCU I B RPCCW Pump Trips CCOI B us AOP 3561 Actions (rev 009-00)

RO Yes the "A RPCCW pump is running. RO RO The US should recognize the entry conditions for AOP 3561 are met and announce entry.

The Foldout Page must be open. Verify RPCCW System Alignment.

Check RPCCW pumps - AT LEAST ONE RUNNING Check RPCCW pumps - ONLY ONE RUNNING. AOP 3561 Step 1, NOTE AOP 3561 Step 1 AOP 3561 Step 1.a AOP 3561 Step 1.b Page 12 of 59

[ i:: SECTIV~ 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Yes, the "C" RPCCW pump is aligned to the affected train.

RO Check the standby RPCCW pump - ALIGNED TO THE AFFECTED TRAIN AOP 3561 Step 1.c Step 1.d Step 1.e RO START the standby RPCCW pump AOP 3561 Yes, 3SWP*MOV50B will be open. RO Verify RPCCW heat exchanger SW inlet AOP 3561 isolation valves (3SWP*MOVSOA or 3SWP*MOVSOB) to the affected Train - OPEN T = When REMOTE SWR07 (for 3SWP*V38) and SWROG RO directed (for 3SWP*V66).

This will align service water from the "B" RPCCW HX to the SWRo6 to 'CLOSE' "C" RPCCW HX. SWR07 to 'OPEN' Yes, the "C" CDS chiller auto tripped and then auto started once RPCCW flow was reestablished.

RO RO RO Using OP 3330A, "Reactor Plant Component AOP 3561 Cooling Water,"

Shift from the affected Step 1.f RPCCW pump and heat exchanger to the standby RPCCW pump and heat exchanger.

Check the COS chiller on affected train - AUTO STARTED Step 1.g AOP 3561 Check RPCCW containment supply and return header isolation valves - OPEN Check RPCCW containment header cross- connect valves - CLOSED 3CCP*AOVl79A 3CCP*AOV1796 3CCP*AOV180A 3CCP*AOV1806 AOP 3561 Step 1.h AOP 3561 Step 1.1 Page 13 of 59

(: (: Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Time JDAlMalf Instructor InformationlActivity Assign Expected Action Standard Yes, service water flow to each operating RPCCW heat exchangers will be > 6200 gpm. RO RO Check Service Water to RPCCW Heat Exchangers Verify RPCCW heat exchanger SW inlet isolation valves (3SWP*MOV50A and 3SWP*MOVSOB) - OPEN. RPCCW SURGE TANK LEVEL LOW annunciator will not be lit. RO RO RPCCW surge tank level should be stable. RO RO Verify service water flow to each operating RPCCW heat exchangers - GREATER THAN 6200 gpm Check IF RPCCW System Is Intact Verify RPCCW SURGE TANK LEVEL LOW annunciator (MBIC 2-7B) - NOT LIT CLOSE surge tank fill valves: RPCCW (3CCP-LVZO) 0 SI Cooling (3CCP-LV61)

Chill Water (3CCP-LV74) Charging Pump Cooling (3CCP- Verify RPCCW surge tank level - STABLE OR INCREASING Place surge tank fill valves in AUTO: LV9 1 ) AOP 3561 Step 2 AOP 3561 Step 2.a AOP 3561 Step 2.b AOP 3561 Step 3 AOP 3561 Step 3.a AOP 3561 Step 3.b AOP 3561 Step 3.c AOP 3561 Step 3.d RPCCW (3CCP-LV20)

Page 14 of 59 i r, SECTI,,~ 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Time I DAlMa If Instructor InformationIActivity Assign Expected Action Standard TIS 3.7.3 applies until the "C" RPCCW pump and Heat Exchanger are placed in service, including service water alignment.

72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> action statement TIR 7.4.1. actions a.1 and a.3 apply. 14 and 30 day action statements respectively.

SI Cooling (3CCP-LV61) 0 Chill Water (3CCP-LV74) 0 Charging Pump Cooling (3CCP- Crew Allow Plant Conditions To Stabilize AOP 3561 LV91) Step 4 Determine Additional Actions AOP 356 us Using the following determine any additional AOP 356 required actions Step 5.a Step 5 Technical Specification 3.7.3, "Reactor Plant Component Cooling System" 3TRM-7.4.1, "Fire Related Safe Shutdown Components" RO/BOP Verify MB Annunciators And Parameters - AOP 3561 us Continue With Normal Plant Evolutions AOP 3561 ASEXPECTED Step 6 Using Applicable Plant Proceaures Step 7 Page 15 of 59 SECTI~I\I 4 Lesson Title: Loss of All AC Power Revision:

0 ID Number: 2K7 NRC-03 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard EVENT 2: Small leak develops through PZR PORV, 3RCS*PCV455A T = power RSCU 2 "A" PORV Leak (RC07A, stable between 6 and 9% I %) 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 "PORV OPEN" (MB4B 4-9) will not be lit. PRESSURIZER PRESSURE HI" (MB4A 3-4) will not be lit. 3RCS-TI 463 will confirm the alarm. CORRECTIVE ACTIONS RO - IF "PORV OPEN" (MB4B 4-9) is lit, Go to OP 3353.MB4B 4-9, "PORV OPEN." RO - IF "PRESSURIZER PRESSURE HI" (MB4A 3-4) is lit, Go To MB4A 3-4, "PRESSURIZER PRESSURE HI" CONFIRM high PORV outlet temperature on RO 3RCS-TI 463, "PORV " OUTLET TEMPS" (MB4) - IF 3RCS*PCV455A or 3RCS*PCV456, PORV, (MB4), is not fully closed, CLOSE PORVs. OP 3353 MB4A 3-5, ' Step 1 OP 3353 MB4A 3-5, Step 2 OP 3353 MB4A 3-5, Step 3 OP 3353 MB4A 3-5, Step 4 Page 16 of 59

\ Lesson Title:

Loss of All AC Power PORV SECTl"IJ 4 PORV BLOCK ID Number: 2K7 NRC-03 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard - IF 3RCS*PCV455A or 3RCS*PCV456, PORV, (MB4), fail to close, CLOSE associated PORV block (MB4): OP 3353 MB4A 3-5, Step 5 I I This will be the case.

3RCS*PCV456 I 3RCS*MV8000B I us - IF pressurizer pressure is not high AND both pressurizer power relief valves are closed, PERFORM the following to determine leaking PORV: OP 3353 MB4A 3-5, Step 6 Crew MONITOR PORV outlet temperatures on OP 3353 Give US/SM the Data logger readout. The readout is at the end of exam. It will show 3RCS*PCV455A is leaking. data logger. MB4A 3-5, Step 6.1 us - IF data logger indicates 3RCS*PCV455A, OP 3353 PORV, is leaking, TEST 3RCS*PCV455A, PORV, as follows: Step 6.2 RO CLOSE 3RCS*MV8000A, PORV block OP 3353 MB4A 3-5, (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 us - IF 3RCS*TI 463, "PORV' " OUTLET OP 3353 TEMPS" (MB4), decreases, Refer To the MB4A 3-5, following Technical Specifications and DETERMINE Limiting Condition for Operation:

Step 6.2.3 Page 17 of 59 r: SECTIwJ4 < Lesson Title:

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

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard Enter TIS 3.4.4 action a.

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.

NA NA US/RO 0 T/S 3.4.4, "Relief Valves" 0 T/S 3.4.6.2, "Operational Leakage" 0 T/S 3.4.9.3, "Overpressure protection Systems" TRM 3.4.1 1, "Reactor Coolant System Vents" - IF 3RCS-TI 463, "PORV' I' OUTLET OP 3353 MB4A 3-5, Step 6.2.4 TEMPS" (MB4), remains high, Refer To OP 3301 G, "Pressurizer Pressure Control," and OPEN 3RCS*MV8000A, "PORV BLOCK (MB4). After determining that the "A PORV is leaking, the crew should maintain the "A" Block valve closed.

Event 3: Power Range Nuclear Instrument (NI) Channel 43 Lower Detector fails high. 3571 Entry T= ARP is RSCU 3 PRNl 43 lower Fails High us The US should recognize the entry Conditions complete (N109C, conditions for AOP 3571 are met and 100%) announce entry.

Page 18 of 59 r" i.~ Lesson Title:

Loss of All AC Power j/ SEC?iu,nl4 ID Number: 2K7 NRC-03 Revision:

Q Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard AOP 3571 Actions (rev 009-01) The BOP should place all SG level Control Bypass Valve controllers in manual and stabilize steam generator level. The appropriate attachment for this failure is "D". The US should announce to the crew. RO Determine the Initiating Parameter and Place the affected controller in MANUAL Stabilize the Plant Parameters Perform Corrective Actions Using Appropriate Attachment instrument Failure Power Range Nuclear Instrument Channel Failure us Power Range Nuclear Instrument Channel Failure Failure of two or more channels of PR instrumentation may prevent P-I 0 from resetting when power is reduced below 10%. If P-10 fails to reset, the following automatic reactor trip signals are lost: 1. SR HIGH FLUX TRIP (I O5 CPS) 2. IR HIGH FLUX TRIP (25%) 3. PR HIGH FLUX LOW STPT TRIP (25%) The reactor operator must remain alert to any power increases which AOP 3571 Step 1 AOP 3571 Step 2 AOP 3571 Step 3 Attachment D AOP 3571 Attachment D Step 1 CAUTION Page 19 of 59 SECTtbi4 4 Lesson Title:

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

0 Task Time IDNMalf instructor InformationlActivity Assign Expected Action Standard RO There should be no error, since rod control was in manual RO would necessitate a manual reactor trip. Instrumentation System shall be used during the reactor shutdown in lieu of the source range channels.

The Gamma Metrics Nuclear Defeat the failed channel input.

At the detector current comparator drawer, Turn the following switches to the failed channel: Rod Stop Bypass Upper Section Lower Section Power Mismatch Bypass. At the comparator and rate drawer, Turn the following switch to the failed channel: Comparator Channel Defeat. Restore TAVE - TREF error to within I0F and Place rod control in automatic.

If the plant calorimetric source is Nl's, the failure of one NI channel will disable the calorimetric program. CREW When conditions have stabilized, observe MB board annunciators and AOP 3571 Attachment DStep 1 AOP 3571 Attachment D Step la AOP 3571 Attachment D Step lb AOP 3571 Attachment DStep 2 AOP 3571 Attachment D Step 3 NOTE AOP 3571 Attachment Page 20 of 59

(' SECTId 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard parameters and immediately report any unexpected or unexplained conditions to the Shift Manager. D Step 3 us [Tech Specs]

LCO 3.3.1 (FU2) 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.

This is not the case. The channel has failed. The US should proceed to step 4.e. REMOTE NOTE: When requested act as I&C Trip the associated Reactor Protection AOP 3571 System bistable(s):

Attachment DStep 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 Refer to Technical Specification 3.3.1. AOP 3571 Attachment D Step 4b 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 If bistable status light(s) ( MB4F or MB4G) AOP 3571 indicate that a single bistable input has Attachment tripped and channel indication is normal, D Step 4.d PERFORM the following:

Request the I&C Department trip the AOP 3571 Page 21 of 59

/' (\ Lesson Title: Loss of All AC Power SEC i 1ud4 ID Number: 2K7 NRC-03 Revision:

Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard See column 3 Technician and remove control power fuses and trip bistables.

REMOTES appropriate bistables using Attachment D and Attachment S. Attachment D Step 4e RXRI 07 Door Open RXR35 OTDT 421 C RXROG OTDT 421 D RXRI 07 Door Closed NOTE: If at any time during the performance of this procedure, if asked, as Reactor Engineering or Unit Management, advice that power should be used to determine reactor power. us Verify the appropriate bistable status lights are lit. Attachment AOP 3571 D Step 4f AOP 3571 Attachment D Step 5 Within one hour, Determine by observation of the associated permissive annunciator window (s) that the following interlocks are in their required state for the existing plant condition (Tech, Spec. 3.3.1, Action 8): 0 Rx or turbine not at power P-7 (MB4D 5-3) Three loop permissive P-8 (MB4D 3- 3) NIS power range P-9 permissive (MB4D 6-1) Reactor at power P-10 (MB4D 4-3). 0 0 Page 22 of 59 i Lesson Title: Loss of All AC Power (' SECTIUN 4 ID Number: 2K7 NRC-03 Revision:

Q Task Standard Time IDNMalf Instructor InformationlActivity Assign Expected Action The following step for removing the AOP 3571 Attachment D Step 6 NOTE failed PR channel from Program 3R5 restores OPERABILITY to the AFD Monitor Alarm and must be 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 peiformed.

• 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 SURVEILLANCE REQUIREMENTS 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 3577 NSSS menu, page 2. Attachment D Step 6a At the NSSS menu, Select "Tilting Factors" AOP 3571 Attachment D Step 6b AOP 3571 Attachment D Step 6c AOP 3571 Attachment F9). Press the key (F5 through F8) that corresponds to the channel to be removed. Refer to the following Technical Specifications and Perform any required actions: D Step 7 Page 23 of 59

(\, Lesson Title: Loss of All AC Power SECflud 4 c ID Number: 2K7 NRC-03 Revision:

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard us us EVENT 4: "A" RCP #I seal degradation T= 6.5% should correlate to a leak of Crew Bistables RSCU=4 -5.8 gpm. If needed slowly adjust tripped and T.S. CVI 3A @ the annunciator. the leakage to

-5.8 gpm to bring in Addressed 6.5% CORRECTIVE ACTIONS RO 0 Surveillance Requirement 4.2.1.1.1.

b TABLE 3.3-1, ACTION 2.c 0 Surveillance Requirement 4.2.4.1 .b 0 Surveillance Requirement 4.2.4.2 Request l&C Department perform corrective maintenance on failed instrument. Diagnose a problem with the

1. 2 RCP #I Seal and enter ARP MB3B 2-10 CHECK the following to confirm alarm and determine affected RCP: 3CHS-FR158 and 3CHS-FR160, high range RCP No. 1 seal leakoff flow recorders (MB3) CHS-F161*, RCP A No. 1 seal leakoff flow computer point CHS-F16O*, RCP B No. 1 seal leakoff flow computer point CHS-F159*, RCP C No. 1 seal leakoff flow computer point 0 AOP 3571 Attachment D Step 8 Entry conditions MB3B 2-10 step 1 Page 24 of 59

(~ Lesson Title:

Loss of All AC Power i SECTld 4 ID Number: 2K7 NRC-03 Revision:

0 Task Time IDWMalf Instructor InformationlActivity Assign Expected Action Standard The first time through the table Step 8 is applicable.

The leak will progress to a point to where step 7 then step 6 will apply. CHS-F158*, RCP D No. 1 seal leakoff flow computer point DISPLAY "RCP Status" NSSS, picture 15. RO us Verify leakage flow high indication by observing the following indications:

e Seal injection flow Affected RCO #I seal inlet temperatures VCT level Charging header flow Pressurizer level 3CHS-FR 158 and 3CHS-FR 160, high range RCP No. 1 seal leakoff flow recorders (MB3) 3CHS-PI 124, excess UD Hx outlet pressure Using Table 1, EVALUATE plant conditions for the affected RCP, and Go To indicated Step. MB3B 2-10 step 2 MB3B 2-10 step 3 MB3B 2-10 step 4 Page 25 of 59 Lesson Title:

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

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard RCP No. 1 Seal Leakoff RCP No. 2 Seal Leakoff Hi Alarm Temperatures No. 1 Seal Inlet Lit Increasing or > P-8 (37%) 5. >23O0F P-8 (37%) 6. Stable 7. Page 26 of 59 SEC$:u.d 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Time IDA/Malf Instructor InformationlActivity 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.

IF "VCT TEMP HI" (MB3A 5-10) is lit, refer OP 3353.MB3A 5-10, "VCT TEMP HI." step 8.1 MB3B 2-10 step 8.2 us SS/ US REQUEST Engineering Department MB3B 2-10 evaluate continued pump operation.

step 8.3 us I IF, at any time, affected RCP no. 1 seal MB3B 2-10 parameters degrade, IMPLEMENT steps as specified in Table 1. exceeds 16 gpm, Refer To 3TRM-7.4.1, "Fire Related Safe Shutdown Components," and PERFORM required ACTIONS. step 8.4 IF total seal return flow from all four RCPs MB3B 2-10 us - step 9 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 IE, reactor power is greater than 25%, Refer to OP 3204, "At Power Operation," and COMMENCE an orderly plant shutdown MB3B 2-10 step 7.1 Page 27 of 59

[' (: SECrIUI\I 4 Lesson Title: Loss of All AC Power c Revision:

Q ID Number: 2K7 NRC-03 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard T= Decision to shutdown made CVI3A @ 20% on a 30 sec ramp Once the crew makes a decision to commence a shutdown, Make the leak worse to the point that the crew will need to implement step 6 and remove the RCP from service immediately.

CREW CREW CREW 20% should correlate to a leak of -10gpm. If needed slowly adjust the leakage to >IO gpm to align the leakage with the need to perform step 6 while continuing with this step. 25%, refer to OP 3206, "Plant Shutdown," and COMMENCE an orderly plant shutdown while continuing with this step. - IF reactor power is less than or equal to MB3B 2-10 step 7.2 - IF, at any time, RCP No. 1 seal parameters MB3B 2- degrade, IMPLEMENT steps as specified in Table 1. step 7.3 0 MB3B 2-1 0 WHEN in MODE 3, refer to OP 3301 D, "Reactor Coolant Pump Operation", and STOP the affected reactor coolant pump.

step 7.4 us Go to AOP 3554, "RCP Trip or Stopping an RCP at Power," and INITIATE actions to perform an immediate RCP shutdown.

MB3B 2-10 step 6 AOP 3554 ACTIONS (rev 008-00) RO us Check RCP Status - ALL PUMPS RUNNING Check Reactor Power AOP 3554 Step 1 AOP 3554 Page 28 of 59

(: ' SECTlu,r\J 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Time IDNMalf Revision:

0 Task Instructor InformationlActivity Assign Expected Action Standard Step 2 RO Verify THREE LOOP PERMISSIVE P-8 AOP 3554 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 NOTE quickly as possible in order to isolate the affected pump No. 1 seal within the recommended 5 minutes. While removing the RCP from service, it is desirable to maintain feedwater flow to the affected steam generator, to ensure that the 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. Between 65% and 70% AOP 3554 Step 3 NOTE BOP Feed Affected Loop SG NR Level to AOP 3554 Step 3 RO Defeat Affected Loops Temperature Input AOP 3554 Step 4 Place loop temperature cutout switch for AT AOP 3554 to the affected loop and pull out. Step 4.a Place loop temperature cutout switch for AOP 3554 Tavg to the affected loop and pull out. Step 4. b Place OT/OP AT recorder select switch to AOP 3554 an unaffected loop. Step 4.c Remove Affected RCP From Service AOP 3554 Page 29 of 59 Loop 1 Loop 1 Loop 2,3,4 us i (i SECTIL~J 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Time I DNMa If Instructor Information/Activity Assign Expected Action Standard "B" Spray to manual and close RO Check RCP status - ALL PUMPS RUNNING. us Check the following conditions:

BOP Affected SG NR level - GREATER THAN 65%. RO THREE LOOP PERMISSIVE P-8 annunciator (MB4D 3-3) - LIT us Return to step 2. RO STOP affected RCP Verify affected S/G level- STABLE Stop feeding the affected S/G RO RO us us Check RCP 1 and 2 - BOTH RUNNING.

Place affected PZR Spray Controller in manual and CLOSE spray valve.

Check if RCP Seal Leakoff should be isolated Verify RCP - STOPPED AS A RESULT OF Step 5 AOP 3554 Step 5.a AOP 3554 Step 5.b AOP 3554 Step 5.b RNO AOP 3554 Step 5.c AOP 3554 Step 5.d AOP 3554 Step 5.e AOP 3554 Step 5.f AOP 3554 Step 5.f RNO AOP 3554 Step 6 AOP 3554 Page 30 of 59

(. Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 (' SECTI'W 4 Revision:

Q Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard RO Will need to return and perform. us RO RO BOP The "A" SG feed regulating valve will already be closed. 3FWS-MOV35A will already be closed. BOP BOP BOP us SEAL FAILURE REQUIRING lMMEDlATE Step 6.a SHUTDOWN Verify the affected RCP has been tripped - AOP 3554 AT LEAST 3 minutes Step 6.b 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 CLOSE the affected RCP No. 1 seal leakoff AOP 3554 isolation valve Step 6.c Verify affected RCP RPCCW thermal barrier AOP 3554 Step 6.d isolation valve - OPEN Shift affected SG to Main Feed Bypass AOP 3554 Flow Step 7 Close affected SG feed regulating valve. AOP 3554 Step 7.a CLOSE affected SG FW control isolation AOP 3554 valve Step 7.b 3 F WS-M OV35A 3FWS-MOV35B

3RNS-MOV35C

3FWS-MOV35D Using the SG feed regulating bypass valve, Maintain the affected SG level between 45% and 55%. AOP 3554 Step 7.c Perform Follow-up Actions. AOP 3554 Step 8 Page 31 of 59 SECftUi4 4 Lesson Title:

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

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard The crew should not trip bistables as this will cause a reactor trip. (An OTAT bistable was already tripped for the PRNl failure) Crew must diagnose this. If they do not diagnose this then trip the following bistables as directed:

T+ 1 min of RXRl07 Protection set 2 door request RXRI 15 RXRI 11 "TRIP" Lo Tave '6TRIP" LoLo Tave (P-I 2) RXR02 "TRIP" OPAT RXR31 "TRIP" C-4 This BIS will RXR31 "TRIP" OTAT trip the plant RXRI07 "CLOSE" Protection Set 2 Door us Using AOP 3571, Instrument Failure AOP 3554 Response, Attachment A, step 6, Trip the associated temperature bistables for the affected loop Step 8.a RO Verify MB annunciators and parameters - AOP 3554 ASEXPECTED Step 8.b Immediately Report any unexplained or AOP 3554 unexpected conditions to the Shift Manager. Step 8.b RNO Perform the following to be in HOT STANDBY (MODE 3) within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> AOP 3554 Step 8.c 1. Check reactor power - GREATER THAN 25%. Continue plant shutdown using OP AOP 3554 3206, Plant Shutdown. Step 8.c.l RNO EVENT 5: Loss of offsite power, "B" Emergency Diesel Generator (EDG) fails to start. T = AOP RSCU 5 Degraded Grid Voltage 3554 complete (ED1 0) (EDRol) 60.1 hz. Grid voltage will increase to 372 KV over 60 seconds. Freq will increase to T = 1 min after ED10 Modify to 25%, ramp 60 seconds. Page 32 of 59

{ SECTIW 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Assign Time IDNMalf I n s t r u c t o r I n f o rm a t i o nlAct iv it y 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 modification (EDOI) Loss of Offsite Power 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 Silence" before ordering reactor trip. E-0 (Rev. 22) STEPS RO Crew 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.

The reactor can be interpreted as "tripped" when any two of three bulleted substeps of Step 1 .* are Page 33 of 59 i/ SECTI~ 4 f \> Lesson Title:

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

Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RQ Rod bottom lights are out due to loss of power. The crew still meets two of three BOP BOP The BOP should attempt a manual start of the "By' EDG from MB8. The "B" EDG will not start. The "A" EDG will be exhibiting exhibit degraded frequency and speed. The US may decide to emergency shutdown the EDG. us T= Step 4 of MALF NOTE: Crew may have tripped EDG us E-0 if crew EG07A due to abnormal operations satisfied.

Verify Reactor Trip 0 Check reactor trip and bypass breakers - OPEN Check rod bottom lights - LIT 0 0 Check neutron flux - DECREASING Verify Turbine Trip Check all turbine stop valves - CLOSED Verify Power to AC Emergency Busses Check busses 34C and 340 - BOTH ENERGIZED Try to energize the affected buss(es) from its associated EDG. - IF power can NOT be restored to at least one AC emergency bus, THEN Go to ECA-0.0, Loss of All AC Power, Step 3. (Observe NOTE prior to step 1). Check If SI Is Actuated E-0, Step 1 E-0, Step 2 Step 2.a E-0, Step 3 Step 3.a E-0, Step 3.a, RNO E-0, E-0, E-0, Step 4 Page 34 of 59

< Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 SECk.4 4 Revision:

0 (- I Task Expected Action Standard Time IDAlMalf Instructor Information/Activity Assign 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 ECA-0.0 Rev 020-01 Actions CSF Status Trees should be monitored for information only. Functional Response procedures shall NOT be implemented while in this procedure.

ECA-0.0 Step 1 NOTE RO Check If RCS Is Isolated Verify PZR PORVs - CLOSED ECA-0.0 Step 3 Step 3.a ECA-0.0 CLOSE letdown orifice isolation valves. ECA-0.0 Step 3.b ECA-0.0 Step 3.c Step 4 Verify excess letdown and reactor head vent isolation valves - CLOSED Verify AFW Flow To All Intact SGs - GREATER THAN 530 gpm ECA-0.0 BOP Perform the following: ECA-0.0 Verify TD AFW pump running. Step 4.a. RNO Page 35 of 59 SECTtL1.I 4 c Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard CRTICAL TASK - The BOP will start the TD AFW pump by opening the steam supply valves ["I BOP - IF the TD ARN pump is NOT running, THEN I) Using Attachment J locally Reset the 2) OPEN steam supply valves.

turbine trip valve as necessary.

BOP BOP Verify the TD AFW flow control valves are open. - IF the valves are NOT open, THEN OPEN the TD AFW pump flow control valves. If power is NOT restored to Bus 34C within 30 minutes, Inverter 6 de-energizes and the process computer will be unavailable.

Use GA-12 as required to determine core cooling parameters.

Try To Restore Power To Any AC Emergency Bus START at least one EDG (MB8) NOTE>> If called, as IS0 NEKONVEX report BOP that the there has been a partial blackout of most northeast grid regions, Time to restoration unknown. Proceed to step 5.e ["I ECA-0.0 Step 4. b. RNO ECA-0.0 Step 5 CAUTION ECA-0 . 0 Step 5 Step 5.a ECA-0.0 ECA-0.0 Step 5.a Page 36 of 59 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Assign Time IDNMalf I n s t r u c t o r I n f o rm a t i o nlAc t iv i t y Expected Action Standard RNO Step 5.e Step 5.e RNO Check offsite power - AVAILABLE ECA-0.0 BOP us Proceed to CAUTION prior to step 6 and, ECA-0.0 - IF offsite power becomes available, THEN Using GA-3, Energize the AC emergency bus through the RSST or the NSST. Maintain one service water pump available to automatically load on its AC emergency bus to provide emergency 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 120OF due to a loss of ventilation.

The locking out of C02 protected areas which have spurious fire alarms is recommended, When power is restored to any AC emergency bus from offsite or an emergency diesel generator, recovery actions should continue starting with Step 26. , diesel generator cooling. ECA-0.0 Step 6 CA UTI 0 N ECA-0.0 Step 6 NOTE Page 37 of 59 i' SEC't idN 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Expected Action Standard Time IDAfMalf Instructor InformationlActivity Assign 0 ADVERSE CTMT is defined as Ctmt temperature GREATER THAN 180°F or Ctmt radiation level GREATER THAN I 0~~1hr. RO BOP BOP RO T=Service SWOIB or For the Service Water Pump left in Water Pump SWOID condition to Auto Start

[not in PTL] in PTL INSERT THE APPLICABLE TRIP. The goal is to have the RO need to manually start the pump that is currently in PTL. Block Automatic Loading Of AC EC. .-0.0 Emergency Busses Step 6 RESET the following if necessary ECA-0.0 Step 6.a SI 0 Aux RN Train A for Lo-Lo SG Level 0 Aux W Train B for Lo-Lo SG Level Place Following Control Switches In PULL- . Charging pumps 0 One service water pump per train (follow pumps preferred)

ECA-0.0 Step 6.b TO-LOCK 0 RPCCWpumps 0 Quench spray pumps 0 Recirculation spray pumps 0 SI pumps Page 38 of 59

(. SEC I iQN 4 Lesson Title:

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

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard RHRpumps BOP MDAFWpumps CARfans Control Building HVAC chillers CRDM cooling fans SLCRSfans Auxiliary Building filter exhaust fans Place CHG

& CCW PP area supply fans in OFF Locally Attempt To Restore AC Power BOP Verify emergency diesel generators - AT LEAST ONE RUNNING Perform the following:

US/PEO us Using Attachment E, Locally Start both EDGs. Proceed to step 8 and, - IF an EDG starts, Perform steps 7.b and 7 c. THEN ECA-0.0 Step 6.c Step 7 Step 7.a Step 7.a RNO ECA-0.0 ECA-0.0 ECA-0.0 Page 39 of 59 1 SECi UJN 4 Lesson Title: Loss of Ail AC Power ID Number: 2K7 NRC-03 Revision:

Q Task Time IDAlMalf Instructor I nformation/Activity Assign Expected Action Standard T=7 minutes from dispatching PEO CVR 94 to CLOSE' CVR 90 to CLOSE' CVR 91 to CLOSE' CVR 92 to CLOSE' CVR 93 to CLOSE' CCR 47 to CLOSE' CCR 48 to CLOSE' BOP Check emergency bus 34C or 34D - AUTOMATICALLY ENERGIZED us Proceed to step 26. US/PEO Isolate RCP Seals a. Locally Close the following valves: 1) RCP seal water return Ctmt outer isolation valve (3CHS*MV8100)

2) All RCP seal supply isolation valves: 3CHS*MV8109A 3CHS*MV8109B 3CHS*MV8109C 3CHS*MV8109D

3) RPCCW Ctmt return outer isolation valves: 3CCP*MOV49A 3CCP*MOV49B PEO Open Instrument Rack Room Cabinet Doors Using Attachment B. ECA-0.0 Step 7. b ECA-0.0 Step 7.c Step 8 ECA-0.0 ECA-0.0 Step 9 Page 40 of.59

(' SEC ,3N 4 Lesson Title:

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

Q Task Time I DNM a If Instructor InformationlActivity Assign Expected Action Standard T=5 minutes from being dispatched T=7 minutes from being dispatched T = When directed The US may decide to align the SBO to either Train "A or "B". The SBO diesel may be aligned to either bus ECA-0.0 pair 34A and 34C or 348 and 340. The Step 10 preferred bus pair is 34A and 34C. NOTE Energize Any AC Emergency Bus From ECA-0.0 The SBO Diesel Step IO BOP OPEN all SBO bus tie breakers:

ECA-0.0 Step 10.a For Bus 34A : 34A 1-2 For Bus 34B

348 1-2 For Bus 34E: A505 (Unit 2) us EDR33 to Operates SBO Synch Check USlPEO Using Attachment G locally Start SBO ECA-0.0 "ON" diesel. Step 10.b EGR08 to Starts SBO Diesel US/PEO Locally Align the selected AC bus pair using ECA-0.0 "START" one of the following attachments: Step 1O.c For Busses 34A and 34C: Attachment H For Busses 348 and 34D: Attachment I EDR32 to Closes SBO Output Breaker BOP OPEN the following breakers:

ECA-0 . 0 "CLOSE" Step 10.d EDG supply breaker for selected emergency ECA-0.0 Page 41 of 59 SECI idN 4 Lesson Title:

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

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard 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: For Bus 34B: NSSA-34A-2 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

1) Proceed to NOTE prior to ECA-0.0 step I1 and, Step 10.e RNO WHEN Attachment G completed, THEN Continue with step 10.e thru 10.q.

breaker PEO 1. Locally Close SBO diesel output Page 42 of 59

{ SECi ION 4 c Lesson Title:

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

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard BOP 32A 32B 32C 32D 32E 32F 32G 32H 32 J 32K 32L 32M 32N 32P 32Q OPEN the following load center supply breakers for the selected non-emergency AC bus: For Bus 34A: 32A-2 AND 32A-XFMR-2 32B-2 AND 32B-XFMR-2 32C-2 AND 32C-XFMR-2 32D-2 AND 32D-XFMR-2 32E-2 AND 32E-XFMR-2 32F-2 AND 32F-XFMR-2 326-2 AND 32G-XFMR-2 For Bus 34B: 32H-2 AND 32H-XFMR-2 32J-2 AND 32J-XFMR-2 32K-2 AND 32K-XFMR-2 32L-2 AND 32L-XFMR-2 32M-2 AND 32M-XFMR-2 32N-2 AND 32N-XFMR-2 32P-2 AND 32P-XFMR-2 32Q-2 AND 32Q-XFMR-2 ECA-0.0 Step j0.f Page 43 of 59

( SEC I ION 4 Lesson Title: of, II AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Instructor InformationlActivity Assign Expected Action Standard Time IDNMalf T=5 EGR08 to Stops SBO Diesel minutes "STOP" from SBO being started T = 1 minute from SBO being stopped Report as the PEO at the SBO that the SBO tripped on "Generator Ground Fault". "Engine Shutdown" is also in. BOP Align the selected non-emergency AC bus ECA-0.0 Step 10.g 1. Place the following switches in Pull- TO-LOCK 0 Screen wash pump 0 Circulating water pumps 0 TPCCW pump(s)

BOP 2. Place the following switches to STOP: CDS chiller(s) Heater drain pump(s) MSR drain pump ECA-0.0 us T = +5 min of EGR07 Clear EDG B Local Panel Trouble us being WHEN dispatched Verify local alignment of selected busses (Using Attachment H or I) - COMPLETED Proceed to NOTE prior to step 11 and, Attachment H or I completed, THEN Continue with step 10.h through 1O.q. Step 10.h Step IOh RNO ECA-0.0 Page 44 of 59 ii SECI tJN 4 Lesson Title:

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

Q Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard T = +9 min of EGROII EDG B Local Control being dispatched T = +I1 min EGRI4 of being Control EDG "B" Output Breaker to LOCAL Place the remaining service water pump on the selected emergency bus in PULL-TO-LOCK. selected emergency bus Step 1O.j ECA-0.0 Step 1O.i Reset the undervoltage block for the ECA-0.0 dispatched Remove Malfunction EGOGB (allows REMOVE auto start of EDG) EGOGB 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 and closed in to bus 34D, the US should proceed to step 26. 1. Verify annunciator For Bus 34C: BUS 34C UNDERVOLTAGE (MB8A 3- 12) - NOT LIT For Bus 34D: BUS 340 UNDERVOLTAGE (MB8C 3-2) - NOT LIT 2. Press undervoltage block BYPASS RESET LOP (MBZ) for the selected train pushbutton (MB8R) ECA-0.0 Step 10.k CLOSE SBO bus tie breaker (MB8) for ECA-0.0 Page 45 of 59 SE I ..3N4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Task Time IDAlMalf Instructor InformationlActivity Assign Expected Action Standard selected non-emergency AC bus For Bus 34A: 34A1-2 Step 10.1 For Bus 348: 3481-2 Place the synchronizing selector to ON for ECA-0.0 the selected emergency and non-emergency Step 1O.m busses For Bus 34A and 34C: SYNC SEL 34A-34C Tie For Bus 348 and 34D: SYNC SEL 34D-34B Tie selected emergency and non-emergency busses CLOSE the bus tie breaker between the ECA-0.0 Step 10.n For 34A and 34C: 34C*IT-2 For 348 and 34D: 34D*17-2 Place the synchronizing selector to OFF for the selected AC bus pair For Bus 34A and 34C: SYNC SEL 34A-34C Tie For Bus 348 and 34D: SYNC SEL 34D-348 Tie ECA-0.0 Step 10.0 Check any AC emergency bus - ENERGIZED ECA-0 . 0 Step 1O.p Page 46 of 59 SEC t ,3N 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

Q Task Time I DAlMa If Instructor InformationlActivity Assign Expected Action Standard us Proceed to NOTE prior to step 1 I. Go to ECA - 0.3, Loss of All AC Power - Recovery With The SBO Diesel The Note prior to Step 6 directs continuing recovery actions at Step 26 when power is restored to any NC emergency bus. Stabilize SG Pressures.

SG pressures may not need to be stabilized in that the depressurization has not been started. BOP Adjust the following:

SG atmospheric dump valves SG atmospheric dump bypass Verify Service Water System Operation For Each Energized Emergency Bus. OR valves. RO RESET LOP, if required.

RO Check diesel generator heat exchanger SW outlet isolation valves - OPEN. 3SWP*AOV39A 3SWP*AOV39B ECA-0.0 Step 1O.p RNO Step 10.q ECA-0.0 ECA-0.0 Step 26 Step 26.a ECA-0.0 ECA-0.0 Step 27 Step 27.a Step 27.b ECA-0.0 ECA-0.0 Page 47 of 59 SEC I ION 4 Lesson Title:

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

0 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard CRITICAL TASK - [*I T=5 SWR25 to Closes 3SWP*MOV71A minutes "0" from being dispatched RO Check service water pumps - ONE PER TRAIN RUNNING.

RO START one pump per train. RO RO Place service water pumps in PULL-TO- LOCK to AUTO. Check service water pump discharge valves For pump A (3SWP*MOV102A)

For pump B (3SWP*MOV102B) For pump C (3SWP*MOV102C)

For pump D (3SWP*MOV102D)

Check TPCCW heat exchanger SW supply isolation valves - CLOSED. 3SWP*MOV71A - OPEN FOR RUNNING PUMPS RO 3SWP*MOV71B PEO CLOSE valves. When placing loads on an energized emergency bus, DO NOT exceed the capacity of the power source.

ECA-0.0 Step 27.c Step 27.c ECA-0 . 0 RNO r1 ECA-0.0 Step 27.d Step 27.e ECA-0.0 ECA-0.0 Step 27.f ECA-0.0 Step 27.f RNO Step 28 CAUTION Page 48 of 59 ECA-0.0 Lesson Title:

Loss of All AC Power Revision:

0 ID Number: 2K7 NRC-03 IDAlMalf Task Assign Time I n s t r u c t o r I n fo rm a t i o nlAc t iv i ty Expected Action Standard BOP US/PEO BOP us Perform the Following For Each ECA-0.0 Energized AC Emergency Bus: Verify the following equipment is energized:

480 volt emergency busses 0 Battery chargers Energize previously de-energized DC loads ECA-0.0 Step 28.b (Attachment A). Perform the following to energize MCC 32- ECA-0.0 3T: Step 28.c

1. Verify Bus 34C - ENERGIZED Step 28 ECA-0.0 Step 28.a Proceed to step 28.d and, WHEN ECA-0.0 Step 28.c. 1 RNO Power is restored to bus 34C, THEN Perform step 28.c EN ERG I ZED. Verify communications console - ECA-0.0 Step 28.d If RCP seal cooling was previously isolated, further cooling of the RCP seals will be performed by RCS natural circulation cooldown as directed in subsequent procedures.

ECA-0.0 Step 29 NOTE Page 49 of 59 SE c .\. .JN 4 Lesson Title: Loss of All AC Power Revision:

Q ID Number: 2K7 NRC-03 Task Time IDNMalf Instructor InformationlActivity Assign Expected Action Standard Select Recovery Procedure.

RO Check RCS subcooling based on core exit ADVERSE CTMT) Go to ECA - 0.2, Loss of All AC Power Recovery With SI Required.

TCS - GREATER THAN 32°F (1 15°F PZR level will be less than 16%. RO us Check PZR level - GREATER THAN 16% (50% ADVERSE CTMT). Go to ECA - 0.2, Loss of All AC Power Recovery With SI Required. The US should announce the transition to ECA-0.2. Check SI equipment NOT actuated 0 Verify SI pumps - STOPPED Verify RHR pumps - NOT RUNNING IN SI MODE 0 Verify charging pump cold leg injection valves - CLOSED Go to ECA-0.2, Loss of All AC Power Recovery With SI Required.

ECA-0.0 Step 29 Step 29.a ECA-0.0 ECA-0.0 Step 29.a RNO Step 29. b Step 29.b RNO Step 29.c ECA-0.0 ECA-0.0 ECA-0.0 ECA-0.0 Step 29.c RNO Page 50 of 59 z 3 i: a, a E 3 Z 0 I- L S rn cn m II: 0 S 0 0 v) a, c -ci r .- E SECTION 4 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 LJ Revision:

Q EVALUATION GUIDE

1. Crew FOLLOW-UP QUESTIONS

1. What is the Emergency Classification for this event?

Site Area Emergency - Charlie Two, Loss of Voltage on Buses 34C and 34D > 15 minutes (EAL PSI). 2. Page 52 of 59 SECTION 4 EXAM GUIDE

SUMMARY

Title: Loss of All AC Power '-4 ID Number: 2K7 NRC-03 Revision: - 0 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 flow to the SlGs prior to the completion of step 4 Of ECA-0.0 Isolate RCP Seal Injection before a Charging Pump starts or is started ECA-0.0--H 003-000 A4.01 3.313.2 ECA-0.0--B 061-000 Failure to establish the A2.02 minimum required AFW flow 3.213.6 rate, under the postulated plant conditions, results in "adverse consequence(s) or a significant degradation in the mitigative capability of the plant." Failure to isolate RCP seal injection before starting a charging pump, under the 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 pump and verify SW F 3.5j3.7 flowpath before completing step 27 of ECA-0.0 such that the EDG does not fail because of damage caused by engine overheating.

Failure to restore SW flow means that the EDG is running without SW cooling which leads engine overheating. Failure to perform the critical task constitutes "mis-operation or incorrect crew 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 53 of 59 SHIFT TURNOVER REPORT DATE-TIME todav 0300 PREPAREDBY SHIFT Unit SuDervisor

/"Night" Shift 1800-0600 LCO ~' 1 I I I I Time in LCO Action Date Action Requirement Time Left I OD ComDensatorv Actions I TemD Loas Plant Systems APC Svstem Notes t I I Cross Unit System Status I I Surveillances I Evolutions in Progress I I Shift Orders Reactor power stable at the point of adding heat (reactor power 3%), following a reactor startup by the previous shift. This is the initial plant startup from a refueling outage.

OP 3203, Plant Starfup 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 ster, 4.2.8. Page 54 of 59 ATTACHMENT 2 VALIDATION CHECKLIST Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

Q Verified By: (Initials)

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 NIA. ..d' 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 Exa mi nat io n Scenario:

The Scenario Attributes Checklist is complete an# attached.

This is not required for Progress Review Exams. Actions Complete (Signaw Page 55 of 59 Appendix D Scenario Outline Form ES-D-1 Facility: Millstone 3 Scenario No.: 2K7 NRC-03 (spare) Op-Test No.: 2K7 Examiners:

Operators:

Initial Conditions:

IC-07 (modified), 3% Dower, Beginnina of Life, No Xe. Turnover: The crew will take the shift with reactor power stable at the point of addinn heat (reactor power 3%), followinn a reactor startup bv the previous shift. This is the initial plant startup from a refueling outage. OP 3203, Plant StartuR is in proqress.

EGOGB FW2OC (EDG) fails to automatically or manually start from the control room. "A" EDG trips resulting in a loss of all AC power. TDAFW pump fails to auto-start.

"B" EDG is started locally.

"B" service water pumps fail to auto-start after "B" EDG is successfully started locally.

Page 56 of 59 Lesson Title: Loss of All AC Power ID Number: 2K7 NRC-03 Revision:

0 Assessor:

Dave Minnich QUALITATIVE ATTRIBUTES

-- Y 1. -- Y 2. The scenario consists mostly of related events. - Y-3. 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.

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 shifl position) the event termination point (if applicable)

-- Y 4. - Y-5. - Y6. - N/A-7. 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.

Sequencinghming 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. - Y8. The simulator modeling is not altered. - Y-9. The scenario has been validated.

Pursuant to IO 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.

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-IO. - Y-I 1. _. Y-12. 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 57 of 59 Lesson Title:

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

0, Chanqe 2 L__ Note: Following criteria list scenario traits that are numerical (QUANTITATIVE) in nature.

u 01. 02. 03. 04. 05. 06. 08. Total Malfunctions (TM) - 5 to 8 required (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 Malfunctions after EOP entry (EM'S) - 1 to 2 required (1) TDAW Pump Fails to Auto Start, (2) EDG Faults, (3) Service Water Pump Failure Abnormal Events (AE) - 2 to 4 required (1) RPCCW Pump Trip (AOP 3561), (2) PORV Leak (ARP MB4A), (3) PRNl Channel Failure (AOP 3572), (4) RCP Seal FailurelRCP Trip (AOP 3554) Major Transients (MT) - 1 to 2 required (1) Loss of All AC Power EOP's (EU) enteredhequiring substantive actions -- 1 to 2 required EOP Contingencies requiring substantive actions

[ECAs/FRs/] (EC) -- 0 to 2 required (1) ECA-0.0 (1) ECA-0.0 Critical Tasks (CT) - 2 to 3 required ECA-0.04 0.0 ECA-0.0 -H ECA-0.04 step 27 of ECA-0.0.

Establish 530 gpm AFW flow to the SGs prior to completion of step 4 of ECA- Isolate RCP seal injection before a charging pump starts or is started. Manually start the service water pump and verify a flowpath before completing Approximate Scenario Run Time: 60 to 90 min. Total 8 Total 3 Total 4 Total 1 Total I Total 1 Total 3 Total amin 09. EOP run time: Total 45 min IO. Technical Specifications are exercised during the scenario. (Y/NLY- Page 58 of 59

SUMMARY

OF CHANGES Change Description Date of Change Page 59 of 59