Text

Aug. 2006 Exam - Draft - Section C Operating Exam (Folder 2)
	ML062970334
Person / Time
Site:	Calvert Cliffs
Issue date:	07/26/2006
From:	Caruso J; Operations Branch I
To:	; Constellation Energy Group
	Sykes, Marvin D.
References
	50-317/06-301, 50-318/06-301, NUREG-1021, Rev 9 50-317/06-301, 50-318/06-301
	Download: ML062970334 (91)
	v • d • e

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Appendix D Attachment 1 Facility: Calvert Cliffs 1 & 2 Scenario No.: 1 Op-Test No.: 2006 Examiners: Operators:

Initial Conditions: 80% Rated Thermal Power, BOL, Equilibrium Conditions Turnover: Unit 1 is at 80% power returning from a 7 day shutdown to repair a steam leak in containment on 11 Feed Line Check Valve 1-FW-133. The following equipment is out of service:

1A EDG for governor maintenance (70 hours8.101852e-4 days 0.0194 hours 1.157407e-4 weeks 2.6635e-5 months remaining on 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO 3.8.1 Action C because EDG 2B also OOS), 11 HPSI Pump to repair bearing oil leak (68 hours7.87037e-4 days 0.0189 hours 1.124339e-4 weeks 2.5874e-5 months remaining on 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO 3.5.2.a). Maintenance on both components (EDG 1 A, 11 HPSI PP) expected to be completed 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months from now. All required surveillances are complete. Weather conditions are normal. Unit 2 is at 100% power with EDG 2B declared 00s 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago due to discovery of burned wiring in EDG 2B local control cabinet. Shift orders are to raise Unit 1 power to 90% at 1.9% per hour (<2% per hour). OP-3 Step 6.1.1.2 is complete.

Event Event Event Malf. No.

No. I Description 1 1 N (ALL) Raise Reactor Power to 90%

2 RF ccw05 OR HS-2520 1 C (RO)

Letdown Non-Regen Heat Exchanger TCV Fails Closed, IX Bypass Valve CVC-520 Fails to Transfer to Bypass 3 RCS004-02 I ----------

Tcold lnst 112CB RTD Short Circuit (Temp Fails Low)

(TS CRS) 4 Turbine Bypass Valve 3940 Fails Open 5 12 SG Tube Leak (TS CRS) 6 High Main Turbine Vibration - Rapid Power Decrease TG017 RPS005 Turbine Trip, ATWT, PORV Fails to Fully Reseat, Turbine 7 RCSO21 C (ALL)

Valves CV-4 & SV-4 Fail to Close, 12 MSlV Auto Close Failure OR 1C05 PB MS017-02 MS002 8 (3 tubes) M (ALL) 12 SG Tube Rupture, SlAS Channel A Auto Failure ESFA001 Terminate after affected SG isolated in EOP-6

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2006 Scenario #l Page 1 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 SCENARIO OVERVIEW The scenario will begin with Unit 1 at 80% power returning from a 7 day shutdown to repair a steam leak in containment on 11 Feed Line Check Valve 1-FW-133. DG 1A is 0 0 s for governor maintenance and 11 HPSI PP is 0 0 s to repair a bearing oil leak. Unit 2 at is 100% power with DG 2B declared inoperable 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago due to discovery of burned wiring in DG 2B local control cabinet. Shift orders are to raise reactor power to 90% at 1.9% per hour. Several minutes after the crew begins the power increase, the letdown non-regenerative heat exchanger temperature control valve disk separates from its stem, stopping CC flow from the heat exchanger. The crew will respond IAW 1C07 ALM and isolate letdown. Next, Tcold Instrument 112CB RTD will short circuit, failing temperature indication low. The crew will need to trip Channel B RPS Trip Units for Delta T Power and TM/LP per Tech Spec 3.3.1 requirements within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . After the Tech Specs are addressed, Turbine Bypass Valve 3940 will fail open. The crew will respond per AOP-7K, lowering turbine load and directing local manual isolation of the valve. A tube leak (0.1 gpm) will develop in 12 SG. The crew will respond per 1C03 ALM and AOP-2A and will determine TS shutdown to Mode 3 is required within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months based on leakage exceeding 100 gpd limit. Shortly thereafter, AOP-7E will be implemented for high turbine vibration. The crew will commence a rapid power decrease. During the power decrease turbine vibration will increase, resulting in an automatic turbine trip. The reactor will not automatically trip and will have to be tripped from 1C15 pushbuttons. ERV-402 will lift and fail to fully reseat, requiring closure of the block valve.

Turbine valves CV-4 and SV-4 will fail to close, and 12 MSIV will not auto close, requiring manual closure. After stabilization actions in EOP-0, the tube leak will develop into a SG tube rupture event. SIAS Channel A will not automatically actuate. SIAS will be manually actuated and EOP-6 will be implemented. The scenario is terminated after isolation of 12 SG in EOP-6.

INSTRUCTOR SCENARIO INFORMATION

1. Reset to IC-19,80%, BOC.

2. Perform switch check.

3. Place simulator in CONTINUE, advance charts and clear alarm display.

4. Place 11 HPSI Pump in PTL, align 12 HPSI Pump for operation.

5. Place simulator in FREEZE.

6. Enter Triggers

a. Clear overrides on CV-520 T1: Activate when HS-2520 taken to bypass

7. Enter Malfunctions

a. Tcold 112CB fails low rcsOO4-02 to LOW on F3 2006 Scenario #1 Page 2 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1

b. Turbine Bypass Valve 3940 fails open ms009-01 on F4 C. 12 SG tube leak ms001-02 to 0.1 ramped over 2 minutes on F5

d. High turbine vibration tg017 for U1 to 9 mils, ramped over 4 minutes on F6

e. Turb trip, ATWT, PORV fails to reseat, CV-4,SV-4,12 MSIV fail to close rps005 on F7 rcsO21 to 5%, 8 second time delay on F7 tg017 to 20 mils, 2 second time delay on F7

f. 12 SG tube rupture, SIAS Ch A auto failure esfaOO1 on F8 ms002 at 3 tubes, 2 second time delay on FS

8. Enter Panel Overrides

- a. CVCS IX Bypass CV-520 handswitch to IX and handswitch auto white light on (to simulate HS 2520 contact 3-4 not opening on high letdown temperature).

b. 1C05 reactor trip pushbutton NOT depressed on F7

9. Enter Remote Functions / Administrative

a. Caution tag 1A DG output bkr in PTL and caution tag its start pushbutton.

b. Caution tag 11 HPSI pump in PTL.

c. Caution tag 2B DG output bkr in PTL and caution tag its start pushbutton.

d. Place a protected equipment green tag on 2B DG.

- 10. Set simulator time to real time, then place simulator in CONTINUE.

11 Give crew briefing.

a. Present plant conditions: 80% load at BOC xxxx MWD/MTU.

b. Power history: Startup in progress from 7 day shutdown to repair steam leak in containment on 11 Feed Line Check Valve 1-FW-133.

c. Equipment out of service: 1A DG removed from service to repair governor (70 hrs left on 72 hr LCO, expected back in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ) 11 HPSI 0 0 s due to bearing oil leak (68 hrs left on 72 hr LCO, expected back in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ) 2006 Scenario #I Page 3 of 18 NUREG-I 021, Revision 9

Appendix D Attachment 1 2B DG removed from service 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago because of discovered burned wiring in control cabinet

d. Abnormal conditions: None

e. Surveillances due: None

f. Instructions for shift: Following turnover, raise power to 90% at 1.9%per hour ( ~ 2 % ) .

OP-3 completed up through Step 6.1J.2. The brief for raising power has been completed. '

12. Allow crew 3-5 minutes to acclimate themselves with their positions.

13. Instructions for the Booth Operator.

a. Insert RF CCWOS, to simulate steddisk separation on L/D HX TCV-223, on lead examiner's cue.

b. Activate F3, Tcold failure on lead examiner's cue.

C. Activate F4, TBV-3940 failure open on lead examiner's cue.

d. Activate F5, 12 SG tube leak on lead examiner's cue.

e. Activate F6, high turbine vibration on lead examiner's cue.

f. Activate F7, turbine trip, ATWT, PORV fails to reseat, turbine valves and 12 MSIV fail to close on lead examiner's cue.

g. Activate FS, 12 SGTR on lead examiner's cue.

e. Collect trend data on the following for examiners:

0 Reactor Power 0 Turbine Generator Load ( M W )

0 VCT Temperature 0 Pressurizer Pressure 0 Pressurizer Level 0 Steam Generator Levels 2006 Scenario #1 Page 4 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 RESPONSES TO CREW REOUEST If a request and response is not listed, delay response until reviewed with the examiner. If one request is dependent upon completion of another, then subsequent actions should not be responded to until the appropriate time delay has been observed. Responses to routine requests, which have no effect the scenario, do not require examiner clearance.

REQUEST RESPONSE

1. Investigate failure of letdown temperature Acknowledge request After 2 minutes, control valve CC-223-CV report that valve stem indicates valve is open.

2. TBO isolate TBV-3940 by closing 1-MS- After 2 minutes, close MS- 120 with RF' 120 MS006. Report that 1-MS-120 is closed.

3. Chemistry sample for activity in steam After 5 minutes, report elevated activity in 12 generators. SG. After 10 minutes report estimated leak rate of approximately 0.1 gpm primary to secondary in 12 SG.

REFERENCES Developmental:

Event 2 SD-041, Chemical and Volume Control Sys Descr, Rev 4 (Table 5.9)

Event 3 LOI-064A2-0, RCS Instrumentation Lesson Plan (Slide 14)

Procedures:

Event 1 OP-3 Section 6.1 .A.7 Event 2 1C07 Alarm Manual (Windows F-05, F-10)

Event 3 TS LCO 3.3.1, RPS Instrumentation - Operating, Amendment 227

. Event 4 AOP-7K, Overcooling Event in Mode 1 or 2, Rev 2 Event 5 1C03 Alarm Manual (Window C-47), TS LCO 3.4.13, AOP-2A Event 6 AOP-7E, Main Turbine Malfunction, OP-3 Event 7 EOP-0, Post Trip Immediate Actions Event 8 EOP-6, Steam Generator Tube Rupture CRITICAL TASKS 2006 Scenario #1 Page 5 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 1 Event No.: 1 r

Event

Description:

Raise Reactor Power to 90%

Time Position Applicants Actions or Behavior CRS Orders RO / CRO to commence power increase and informs Chemistry.

RO Energizes all pressurizer backup heater banks.

RO Adjusts the setpoint of PIC-1OOX to maintain 2250 psia pressurizer pressure.

Clicks on <Control>cload> Load Set, Ramr, Rate and enters the desired Load CRO Ramp Rate of 1.9%

Increases turbine load by one of the three following methods:

1. Clicks on cControlxload> Load Set, Load AND enters the desired Load Ref Cmd CRO

-OR-

2. Clicks on cControlxload> Load Set, Manual Adi, Raise

-0R-

3. Adjusts Turbine Load Set, 1-CS-80 Adjusts the Load Limit Setpoint to maintain it approximately 1O k ) % above CRO generator load by clicking on Load Limit, Setpoint AND entering the desired value.

Performs dilution per 01-26 to maintain Tc within 2°F of program per OP-3 RO Figure 1, Temperature Program Curve.

RO Withdraws CEAs as desired to maintain temperature and ASI.

2006 Scenario #1 Page 6 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 1 Event No.: 2 Event

Description:

Letdown Non-Regen Heat Exchanger TCV Fails Closed, IX Bypass Valve CVC-520 Fails to Transfer to Bypass 1 Time I Position I Applicant's Actions or Behavior Ro I Acknowledges UD HX Out Temp Hi alarm on 1C07. Informs CRS. Refers to ALM.

RO Places 1-TIC-223 in MANUAL and attempts to adjust UD HX outlet temp.

RO Observes UD temperature on 1-TIC-224at >145"F and CVC-520-CV still in IX position. Informs CRS.

I RO I Manually positions CVC-520-CVto BYPASS.

ir I Verifies CVC-521-CV is shut.

RO Observes UD temperature continues to increase. Informs CRS.

CRS Directs field inspection of CVC-223-CV locally.

CRS Determines that letdown temperature cannot be maintained e1 80°F. Orders RO to secure charging and letdown per OI-2A. Informs Chemistry.

RO Refers to OI-2A, Section 6.6 for securing charging and letdown.

RO Shifts 1-HIC-I 10 to MANUAL.

RO Places second backup charging pump handswitch in PTL.

handswitch in PTL and immediately places 2006 Scenario #1 Page 7 of 18 NUREG-1021 Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Event

Description:

Tcold lnst 112CB RTD Short Circuit (Temp Fails Low) (TS CRS) 1 Time I Position Applicants Actions or Behavior I Announces Plant Computer alarm indicating Tc 112CB has failed low.

Refers to TS 3.3.1, RPS Instrumentation- Operating. Determines need to place affected trip units in TRIP. Orders CRO to place RPS Channel B Trip Units for Delta-T Power and TM/LP in TRIP.

Places RPS Channel B Trip Units for Delta-T Power and TM/LP in TRIP.

Informs CRS.

CRS Enters TS LCO 3.3.1 Action A.

2006 Scenario #1 Page 8 of 18 NUREG-1021, Revision 9

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Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 1 Event No.: 4 Event

Description:

Turbine Bypass Valve 3940 Fails Open T T m , r w

Position Applicants Actions or Behavior CRO I RO Observes indications of valve opening (stm flow incr, Tc decrease, delta-T pwr incr). Informs CRS.

Identifies failed open turbine bypass valve. Informs CRS.

I CRS Refers to AOP-7K, Overcooling Event in Mode 1 or 2.

Directs RO to control power as necessary by either inserting CEAs or borating through MOV-514 with one BA pump and one Charging Pump.

Performs CEA insertion or boration as needed.

I CRS Directs CRO to lower Turbine load as needed to maintain Tc on program.

i 1 CRO Lowers turbine load as directed to maintain Tc on program.

I/ I CRS Directs TBO to isolate TBV-3940 by closing 1-MS-120.

Verifies parameters trending to normal (Tc, Pzr Press, Pzr Level, SG Level)

Refers to Tech Specs as needed for DNB, CEA Insertion Limits.

2006 Scenario #1 Page 9 of 18 NUREG-1021, Revision 9

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Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 1 Event No.: 5 Event

Description:

12 SG Tube Leak (TSCRS)

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I Time CRO / RO Respond to 1C03 MAIN STM EFFL RAD MON 2C26 alarm on increasing secondary activity. Refer to ALM. Inform CRS.

CRS Implements AOP-2A, Excessive RCS Leakage.

CRS Contacts Plant Chemistry for steam generator activity samples.

CRS Directs CRO / RO to determine affected SG and estimate leakrate.

CRS 1 Refers to TS 3.4.13. Determines leakage in excess of TS limit based on input from Plant Chemistry.

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Makes preparations for a shutdown to <50% within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and into Mode 3 within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

2006 Scenario #1 Page 10 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: I Event No.: 6 Event

Description:

High Main Turbine Vibration - Rapid Power Decrease Time Position Applicants Actions or Behavior CRO Acknowledges high turbine vibration alarm. informs CRS. Monitors vibration.

Refers to ALM.

CRS Implements AOP-7E, Main Turbine Malfunction,Section V.

CRS / CRO Places main turbine and generator bearing temperatures on 30 second trend.

CRS Directs CRO to reduce MVARs to maintain vibration < 8 mils.

CRS Notifies AOM and System Engineer.

CRO Reduces turbine load.

RO inserts CEAs as needed to maintain Tc on program.

2006 Scenario #1 Page 11 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Event

Description:

Turbine Trip, ATWT, PORV Fails to Fully Reseat, Turbine Valves CV-4 & SV-4 Fail to Close, 12 MSlV Auto Close Failure CRO Informs CRS that CV-4 and SV-4 did not close.

CRS Directs CRO to manually close MSlVs CRO Closes MSIVs.

CRS Enters EOP-0.

1 CRO / RO 1 Implement immediate actions.

1I I RO I Identifies PORV not reseated. Closes block valve.

7 CRS ~ I Performs EOP-0 verification steps with CRO / RO.

2006 Scenario #l Page 12 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 3p-Test No.: 1 Scenario No.: 1 Event No.: 8 Event

Description:

12 SG Tube Rupture, SlAS Channel A Auto Failure Applicants Actions or Behavior Observes indications of 12 SGTR (pzr press decr, pzr level decr, 12 SG level incr)

Transitions to EOP-6, Steam Generator Tube Rupture.

I CRO Observes SlAS failure. Manually initiates SIAS.

I CRSICRO Verify proper ECCS operation.

I CRS/RO Trip one pair of RCPs (either 11N12B or 11BI12A)

Verifies boration in progress.

II CRS CRS Determines reopening MSlVs is not desirable due to turbine valve problem.

Confers with S M . Deviates from EOP-6, Step IV.G.3 Directs CRO / RO to commence RCS cooldown using ADVs to Th of 515°F.

CRO I RO Performs RCS cooldown to Th of 515°F.

CRS / CRO Initiate AFW with 13 AFW Pump to maintain unaffected SG -24 to +30 inches.

CRO Secure main feedwater system:

- trip both MFW pumps

- CBPsinPTL

- 1 cond pump in PTI

- both HD Pps in PTL

- FW isolations closed

- HW dump to CST closed

- SGBD valves closed.

- Cond to SGBD HX Dispatches PO to 45 ft switchgear room to standby to close 12 SG ADV.

I CRS/CRO Evaluate need to throttle HPSI.

I CRO Stops LPSl pumps.

CRS I RO Coordinate to depressurize to reduce subcooling and maintain pzr level.

Closes 12 SG ADV.

I CRO Closes 12 SG AFW Stm Supply Valves MS-4071-CV and MS-4071A-CV.

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CRO Shuts 12 SG AFW Block Valves 1-AM-4530,4531,4532 and 4533-CV.

Terminate scenario after 12 SG isolated.

2006 Scenario #1 Page 13 of 18 NUREG-1021, Revision 9

SHIFT TURNOVER (Attachment 1)

I. Present Plant Conditions 80%

11. Bumup: XXXXX MWDMTU (MOC) 111. Power History Startup in progress from 7 day shutdown to repair steam leak in containment on 11 Feed Line Check Valve 1-FW-133 IV. Equipment out of Service: 1A DG removed from service to repair governor (70 hrs left on 72 hr LCO, expected back in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ) 11 HPSI 0 0 s due to bearing oil leak (68 hrs left on 72 hr LCO, expected back in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months )

V. Abnormal Conditions: None VI. Surveillances Due: None VII. Instructions for Shift Following turnover, raise power to 90% at 1.9% per hour (<2%). OP-3 completed up through Step 6.1 .I.2. The brief for raising power has been completed.

VIII. U2 Status and 100% power.

Major Equipment 00s:

2B DG removed from service 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago because of discovered burned wiring in control cabinet.

2006 Scenario #1

U-1 Reactor Operator Shift Briefing Sheet Today Rx Power: 80 %

Boron: xxx ppm Burnup: XXX MWDMTU AS1 Value: xxx (Cecor) steady Xenon: xxx and xxx Neutral Blend: 3 gal BA & 35 gal DI Last Shot: 50 gal of DI 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago CEA Moves: GRP 5 120 1.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months ago cvcs IXs: 11for purification 12 for delithiation I Thumb Rules (Good until 11500 MWDRMTU)

Tcold: -1.4 deg F @ 100 % power Dilution: 160 gal of DI @ 100 % power Boration: 14.1 gal from the BAST 103.9 gal from the RWT CEAs: 6.75 inches Grp 5 SW Injection times: - to 2006 Scenario #1

SHIFT TURNOVER INFORMATION SHEET For Training Only PARAMETER UNIT 1 UNIT 2 MODE: 1 1

% POWER: 80 100 RCS TEMPERATURE: 544.8 547.9 RCS PRESSURE: 2250 2250 RCS BORON 943 595 MWe NET: 690 854 GROSS RCS LEAKAGE: 0.08 0.07 BULK POWER NOTIFICATION Normal 1 Periodic for DG 1A Inoperable TBD Shift Manager 2006 Scenario #I

SHIFT TURNOVER INFORMATION SHEET m ELECTRICATSYSTEW~ULU ,

-,r - UNiFi- '

500KV High Lines ~5051 m5072 E5052 500KV Buses BLACK ERED 13KV Supplies [xIP-13000-1 WP-13000-2 SMECO Bkr Status [x1252-2301 uOSH301 IXI OSH302 Site Self Power Feeders 1252-1106 m252-2106 13KV Buses a1 IXI12 m23 El21 122 Voltage Regulators Auto 1102 Auto 2102 Auto 1103 Auto 2103 Auto 1101 Auto 2101 4KV Transformers mu-4000-11 Ix]U-4000-21 [xIU-4000-12 mU-4000-22@U-mu-4000-13 4000-23 4KV Buses a 1 1 m12 a 13 m14 m21 a 2 2 m23 m24 Diesel Generators 01A 01B UOC 02A 02B c]OC 480V Buses H l l A H l l B m14A N14B m21A m21B m24A m24B 125VDC Battery Chargers all m23 a12 m24 B14 m22 m13 m21 125VDC Buses lxlll 412 1x122 1x121 120VAC Vital Buses mll m21 E13 H23 m14 a24 ml2 m22 I

2006 Scenario #1

SHIFT TURNOVER INFORMATION SHEET

1. A member of BOPSEU shall be available and should be present during the performance of MSlV Partial Stroke testing. A Qualified Mechanic shall be available (not necessarily on location in the MSlV Room) with a spare Haskel Pump Shuttle Valve in hand to facilitate a replacement if requested by Operations and/or System Engineering..

2. Contact Ginna 0 585-771-3235,Nine Mile Point Unit One Q 315-349-2480,and Nine Mile Point Unit Two Q 315-349-2170 if we enter AOP-7M for grid disturbances so they can evaluate any potential impact at their site. Result of 7-27-04 0800 conference call. (do not delete)

3. If Reactor Power lowers to below 85%, returns to 100% and is stable for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months then perform Thermal Performance Monitoring per PE 1-083-07-OM. RPA 2004-1447 submitted to add a step to OP-3 with this requirement.

4. PZR level alarms (E-33, E-34 and Plant Computer point PRZLVLHI) are credited in UFSAR 14.25. If BOTH E-33 AND E-34 are 00s OR if PRZLVLHI is unable to cause Selected Computer point (e.g., Plant Computer 00s or E-43 OOS), then EITHER place one Charging Pump in PTL OR station a DedicatedOperator. IRE-002-114. IRE-002-117.

5. Vent Charging pumps as follows: Vent suction stabilizers daily (normal PE), Vent pump discharge on pump shutdown when 3 are operable (this includes after weekly PE to run idle pumps), If any pump is inoperable, vent discharge on idle operable pump daily (During Vent PE).

6. Ensure 11 BABT is dumped to BAST within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months of sample because of the leaking DI valve. MO #1200501631 (P4, week 0614) for both Units.

7. If 14 Circ Pp Stator Temp alarms at 1TR-16, notify John lhnacik or Paul Gray for strategy. Alarm 125C, Use heat killer. Memo at CRS Desk.

8. During a Unit 1 Shutdown secure 11B RCP prior to 11A. If performing RCP Trip Strategy in EOPs, preferentially stop 11A and 128 RCPs. Reference Memo at U-1 CRS desk Contact M. Lewis for additional operating strategy related to 11B RCP.

9. Computer point for COG (1752A) is not processingcorrectly (input from RMS is good). GPD can be read on 1-RR-11.

SHORT TFRM NOTFQ.

1, If an Aux Boiler is run for an extended period Contact Fin to adjust packing on 13 Aux Boiler Fuel Oil Pp. The pump

. . is isolated with Temp Note 0-05-76 to prevent an oil leak house keeping issue:

2. Do not perform PE 0-027-6-0-W Aux Boiler Low Level Quick Drain Operability until the upcoming maintenancewindow is complete Week 0542 due to the safety concern around the steam emitting from the floor drain during the performance.

3. Vertical Tendon inspection in progress for next several weeks. Temporary Phone # for U-1 ContainmentRoof is X-3413, U-2 X-6553.

4. RPS Channel 'C'Delta T Power Pot is at setpoint file limit, leff voicemail with Skip Winter, Dave Schrumpf, and Mark Simpson.

1ot 12/05

5. New AS1 channel checks in ODAC logs, using internal AS1 in the quadrant near the LRNl detector. Computer points are on page 2 of the Operating Parametersgroup 102.

6. Cask is scheduled to be placed in SFP on Monday, keep this in mind if filling SFP.

7. 11 HPSI Pp is 00s due to bearing oil leak.

8. 1A DG is 00s due to a governor problem, out 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago expected to be back at the end of shift.

9. 28 DG is removed from service 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago due to discovered bumed wiring in local control cabinet.

2006 Scenario #1

Appendix D Attachment 1 Facility: Calvert Cliffs 1 & 2 Scenario No.: 2 Op-Test No.: 2006 Examiners: Operators:

initial Conditions: 75% Rated Thermal Power, MOL, Equilibrium Conditions Turnover: Unit 1 is at 75% power. The following equipment is out of service: 1A EDG for governor maintenance (70 hours8.101852e-4 days 0.0194 hours 1.157407e-4 weeks 2.6635e-5 months remaining on 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO 3.8.1 Action C because EDG 2B also OOS), 11 HPSl Pump to repair bearing oil leak (68 hours7.87037e-4 days 0.0189 hours 1.124339e-4 weeks 2.5874e-5 months remaining on 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO 3.5.2.a).

Maintenance on both components (EDG 1A, 11 HPSl PP) expected to be completed 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months from now. 15 CW PP off, Waterbox 13A open t o clean out grass. All required surveillances are complete. Weather conditions are normal. Unit 2 is at 100% power with EDG 2B declared 00s 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago due t o discovery of burned wiring in EDG 2B local control cabinet. Shift orders are to raise Unit 1 power t o 80% at 5% per hour. OP-3 Step 6.1.H.4 is complete.

Event Event Event Malf. No.

NO. Type* Description N (ALL) Raise Reactor Power t o 80%

c (RO) Group 5 CEA 36 Slippage (TS CRS)

C (CRO) 12 Component Cooling HX Marine Fouling (TSCRS) 4 (RCS026-01 I (RO) I Pressurizer Level Instrument LT-1lOX Fails High 5 I FWO19-01 I (CRO) I Feed Reg Valve Controller 1-FIG1111 Fails As Is CD001 R (RO)

N (CRO) 1 Main Condenser Vacuum Leak, Main Turbine Trip, Reactor Auto Trip Failure RCS003, 023, 024, 11 Main Steam Line break in containment, concurrent broken M (ALL) sensing line on pressurizer level / pressure tree 037, MS010 ESFA004 CSAS Train B Fails to Auto Actuate, Spray Valve SI-4150 Fails S1007-01 to Open on SI Signal I Terminate after SG blown dry and in LOCA EOP-5

(N)ormal, (R)eactivity, (i)nstrument, (C)omponent, (M)ajor 2006 Scenario #2 Page 1 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 SCENARIO OVERVIEW The scenario will begin with Unit 1 at 75%. DG 1A is 0 0 s for governor maintenance and 11 HPSI PP is 0 0 s to repair a bearing oil leak. 15 Circ Water Pump is off with 13A Waterbox open to clean out grass. Unit 2 is at 100% power with DG 2B declared inoperable 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago due to discovery of burned wiring in DG 2B local control cabinet. Shift orders are to raise reactor power to 80% at 5% per hour. During the power increase, Group 5 CEA 36 slips 25 inches from it's current position. The crew should respond per AOP-lB, refer to Tech Specs and align the CEA with its group. Next, 12 Component Cooling HX will exhibit symptoms of marine fouling. The crew will need to increase SW cooling to 11 CC HX. After the Tech Specs are addressed, Pressurizer Level Instrument LT-11OX will fail high. The crew will take manual control and shift channels per IC06 ALM. Feed Regulating Valve Controller ?IC-1 111 failing as is will require the CRO to control 11 SG level manually. A main condenser vacuum leak will develop. The crew should respond per AOP-7G and lower turbine load. The vacuum leak will lead to a turbine trip with auto reactor trip failure. The reactor will be manually tripped. A break occurs in containment on 11 Main Steam Line. Concurrently, a small RCS leak occurs from a broken instrument sensing line on the pressurizer. The crew will enter EOP-0, and address the events per EOP-4, EOP-8 and EOP-5. CSAS Train B will not auto actuate and Spray Valve 4150 will not auto open requiring manual actions by the operator. The scenario is terminated after 11 SG has blown dry and crew is responding to the leak per EOP-5.

INSTRUCTOR SCENARIO INFORMATION

1. Reset to IC-18,75%, MOC.

2. Perform switch check.

3. Place simulator in CONTINUE, advance charts and clear alarm display.

4. Place 11 HPSI Pump in PTL, align 12 HPSI Pump for operation.

5. Place 15 CWP in PTL,align for cleaning 13A Waterbox.

6. Place simulator in FREEZE.

7. Enter Triggers On main turbine trip TI:

msOlO at 15% with 2 second time delay rcsOO3 at 80 gpm rcsO23-02 LOW (PT-1OOY) rcsO24-03 LOW (PT-102C) rcsO25-02 LOW (PT-103-1) rcs026-02 HIGH (LT-11OY reference leg) rcsO37-02 at 22 psi (IT-lO5B) esfa004-02 (CSAS Trn B) siOO7-01 (Spray Is01 SI-4150) 2006 Scenario #2 Page 2 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1

8. Enter Malfunctions

a. Group 5 CEA 36 slips ceds009 for CEA 36

b. 12 Component Cooling heat exchanger marine fouling swOO3-07 at 100% on F3

c. Pressurizer level instrument LT-11OX fails high rcsO21-01 to HIGH on F4

d. Feed Reg Valve Controller FIC-1111 fails as is fwO19-01 on F5

e. Mn condr vac leak, turb trip, rx trip auto trip failure cdOOl at 10% on F6 rps005 on F6

9. Enter Panel Overrides None

10. Enter Remote Functions / Administrative

a. Caution tag 1A DG output bkr in PTL and caution tag its start pushbutton.

b. Caution tag 11 HPSI pump in PTL.

c. Caution tag 2B DG output bkr in PTL and caution tag its start pushbutton.

d. Place a protected equipment green tag on 2B DG.

e. Caution tag 15 CWP in PTL.

- 11. Set simulator time to real time, then place simulator in CONTINUE.

- 12. Give crew briefing.

a. Present plant conditions: 75% load at MOC xxxx MWD/MTU.

b. Power history:

c. Equipment out of service: 1A DG removed from service to repair governor (70 hrs left on 72 hr LCO, expected back in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ) 11 HPSI 00s due to bearing oil leak

. (68 hrs left on 72 hr LCO, expected back in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ) 2B DG removed from service 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago because of discovered burned wiring in control cabinet 15 CWP off, cleaning 13A Waterbox 2006 Scenario #2 Page 3 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1

d. Abnormal conditions: None

e. Surveillances due: None

f. Instructions for shift: Following turnover, raise power to 80% at 5% per hour.

OP-3 completed up through Step 6.1.H.4. The brief for raising power has been completed.

13. Allow crew 3-5 minutes to acclimate themselves with their positions.

14. Instructions for the Booth Operator

a. Insert MF CEDS009 on CEA 36, for CEA slippage on movement demand.

b. Remove MF CEDSOO9 after CEA 36 slips.

c. Activate F3, 12 CC HX fouling on lead examiner's cue.

d. Activate F4, LT-1 1OX failing high on lead examiner's cue.

e. Activate F5, 11 FRV controller FIC-1111 failure on lead examiner's cue.

f. Activate F6, condenser vacuum leak on lead examiner's cue. Increase severity to maximum on subsequent cue from lead examiner.

g. Collect trend data on the following for examiners:

Reactor Power Turbine Generator Load ( M W )

Main Condenser Vacuum Pressurizer Pressure Pressurizer Level Steam Generator Levels Containment Pressure Containment Spray Flows in Trains A and B 2006 Scenario #2 Page 4 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 RESPONSES TO CREW REQUEST If a request and response is not listed, delay response until reviewed with the examiner. If one request is dependent upon completion of another, then subsequent actions should not be responded to until the appropriate time delay has been observed. Responses to routine requests, which have no effect the scenario, do not require examiner clearance.

REQUEST RESPONSE

1. E&C investigate cause of CEA slippage Acknowledge request After 5 minutes, report ....

2. TBO investigate vacuum leak After 2 minutes, report that leak not yet located, still investigating REFERENCES Developmental:

Event 2 NEiOP-13, Technical Data Book, Rev 28 (Figures 1-I.A.2,4, and 6)

Event 7 LOI-064A2-0RCS Instrumentation Lesson Plan (Slide 38)

Procedures:

Event 1 OP-3, Alarm Manual, Tech Specs Event 2 AOP-lB, CEA Malfunction, Rev 29, TS LCO 3.1.4, CEA Alignment Event 3 TS LCO 3.7.5, Component Cooling System, Amendment 227 Event 4 1C06 ALM (Window E-33)

Event 5 Event 6 AOP-7G, Loss of Condenser Vacuum, Rev 3 Event 7 EOP-0, EOP-4, EOP-8, EOP-5 Event 8 EOP-0 CRITICAL TASKS 2006 Scenario #2 Page 5 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 c

II Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Event

Description:

Raise Reactor Power to 80%

Position Applicants Actions or Behavior CRS Orders RO / CRO to commence power increase and informs Chemistry.

RO Energizes all pressurizer backup heater banks.

RO Adjusts the setpoint of PIG1OOX to maintain 2250 psia pressurizer pressure.

Clicks on cControl>cload> Load Set, Ramp Rate and enters the desired Load CRO Ramp Rate of 1.9%

Increases turbine load by one of the three following methods:

1. Clicks on cControl>cload> Load Set, Load AND enters the desired Load Ref Cmd CRO

-OR-

2. Clicks on cControl>cload> Load Set, Manual Ad[, Raise

-0R-

3. Adjusts Turbine Load Set, 1-CS-80 Adjusts the Load Limit Setpoint to maintain it approximately 1O(k)% above CRO generator load by clicking on Load Limit, Setpoint AND entering the desired value.

Performs dilution per OI-2B to maintain Tc within 2°F of program per OP-3 RO Figure 1, Temperature Program Curve.

RO Withdraws CEAs as desired to maintain temperature and ASI.

2006 Scenario #2 Page 6 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 2 Event No.: 2 Event

Description:

Group 5 CEA 36 Slippage (TS CRS)

Time Position Applicants Actions or Behavior RO Observes CEA 36 misalignment. Stops CEA motion. Informs CRS.

CRS Implements AOP-1B, CEA Malfunction,Section VII.

RO Verifies Group 5 selected.

1 RO I Selects CEA 36.

RO Selects Manual Individual Mode.

RO If CMI is in effect, overrides CMI.

RO Realigns CEA 36 with Group 5 by pulling for 5.25 inches, then waiting 15 seconds.

CRS Refers to TS 3.1.4.

2006 Scenario #2 Page 7 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 2 Event No.: 3 Event

Description:

12 Component Cooling HX Marine Fouling (TS CRS)

Time Position Applicant's Actions or Behavior CRO Acknowledges 1C13 alarm "1 1/12 CCHX CC OUT TEMP HI". Observes CC outlet temperature. Informs CRS.

I CRS / CRO I Increases SW flow through 11 CC HX.

CRS / RO Monitors RCP temperatures.

CRS Refers to TS 3.7.5. Declares 11 CC subsystem inoperable.

I CRS I Informs maintenance of need to investigate.

2006 Scenario #2 Page 8 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 2 Event No.: 4 Event

Description:

Pressurizer Level Instrument LT-11OX Fails High Time I Position I Applicant's Actions or Behavior Ro I Acknowledges high level alarm on 1C06 (Window E-33). Compares indicators. Identifies LT-11OX failed. Informs CRS.

-1 1- R O ~ I Verifies backup charging pumps stopped. Verifies letdown at minimum.

I RO I Shifts 1-HS-110 to Channel Y I 1 RO 1 Shifts Pzr Htr Lo Lvl Cut-off Select Switch 1-HS-100-3to Channel Y.

I I RO I Observes pressurizer level and letdown flow controlling normally.

I 1 CRS 1 Notifies E&C for repair.

2006 Scenario #2 Page 9 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 2 Event No.: 5 1 Event

Description:

Feed Reg Valve Controller 1-FIC-1111 Fails As Is

/ I Time I I

Position Applicant's Actions'or Behavior Identifies SG level control problem. Determines problem is with FIC-1111 output. Informs CRS.

Directs CRO to take manual control and maintain normal level in 11 SG.

CRO Manually controls 11 SG level.

I 1 CRS Contacts E&C.

2006 Scenario #2 Page 10 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 2 Event No.: 6 Event

Description:

Main Condenser Vacuum Leak, Main Turbine Trip, Reactor Auto Trip Failure Time Position Applicant's Actions or Behavior CRO I RO Observes lowering turbine load, rising RCS temperature. Identifies lowering condenser vacuum. Informs CRS.

Implements AOP-7G , "Loss of Condenser Vacuum".

I CRS Dispatches personnel to look for leaks.

CRS Directs normal load reduction per OP-3 when vacuum c25 inches Hg.

CRO Checks running Circ Water pump amps are normal. Checks in-service WB inlet MOVs fully open.

CRS / CRO Has PO verify 1-CAR-101 thru 104 and 106 open, and 1CAR-105 shut.

CRO Has PO check for normal CAR operation CRO Verifies 1C02 TURBINE EXP JOINT LVL LO alarm clear.

CRO Verifies GS functioning properly.

t-- I CRO CRO CRO Has PO verify proper vacuum breaker seal water level.

Has PO verify proper waterbox priming system operation.

Verifies TBVs are closed.

t----j+ CRO Has PO check WB D/Ps, SGFP turbine or LP turbines exhaust rupture disks.

Checks CST level >1 foot.

Has PO check MT oil waste drain lines.

Observes sudden decrease in vacuum and MT trip. Informs CRS.

Observes no auto reactor trip, manually trips reactor from 1C05.

2006 Scenario #2 Page 11 of 18 NUREG-1021, Revision 9

~~~ ~ ~

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 2 Event No.: 7 Event

Description:

11 Main Steam Line break in containment, concurrent broken sensing line on pressurizer level / pressure tree Time Position Applicants Actions or Behavior CRS Announces EOP-0 entry.

CRO / RO Perform immediate action verifications. Observe rising containment pressure and pressurizer instrument failures. Inform CRS.

I CRO / RO I Confirm proper ESF actuation.

1 CRS Determines MSL Break exists in containment. Transitions to EOP-4 or EOP-18.

CRS Directs CRO to secure feeding and steaming 11 SG.

2006 Scenario #2 Page 12 of 18 NUREG-1021, Revision 9

Appendix D Attachment 1 a

I/

tr Op-Test No.: 1 Scenario No.: 2 Event No.: 8 I Event

Description:

CSAS Train B Fails to Auto Actuate, Spray Valve 9-4150 Fails to Open on SlAS 2006 Scenario #2 Page 13 of 18 NUREG-1021, Revision 9

SHIFT TURNOVER (Attachment 1)

I. Present Plant Conditions 75%

11. Burnup: xxxxx MWDMTU (MOC) 111. Power History IV. Equipment out of Service: 1A DG removed from service to repair governor (70 hrs left on 72 hr LCO, expected back in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ) 11 HPSI 00s due to bearing oil leak (68 hrs left on 72 hr LCO, expected back in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ) 15 CWP off, cleaning 13A Waterbox V. Abnorrnal Conditions:

VI. Surveillances Due: None VI1. Instructions for Shift Following turnover, raise power to 80% at 5%

per hour. OP-3 completed up through Step 6.1.H.4 VIII. U2 Status and 100% power Major Equipment 00s: 2B DG removed from service 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago because of discovered burned wiring in control cabinet 2006 Scenario #2

U-1 Reactor Operator Shift Briefing Sheet Today Rx Power: 75 %

Boron: xxx ppm Burnup: XXXXX M WD/MTU AS1 Value: 0.011 (Cecor) steady Xenon: 1.85 and building in Neutral Blend: 3 gal BA & 35 gal DI Last Shot: 50 gal of DI 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago CEA Moves: GRP 5 120 1.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months ago cvcs IXs: 11for purification 12 for delithiation 1 Thumb Rules ( ~ o o until d 11500 MWDMTU)

Tcold: -1.4 deg F @ 100 %power Dilution: 160 gal of DI @ 100 % power Boration: 14.1 gal from the BAST 103.9 gal from the R WT CEAs: 6.75 inches Grp 5 SW Injection times: - to 2006 Scenario #2

SHIFT TURNOVER INFORMATION SHEET For Training Only PARAMETER UNIT 1 UNIT 2 MODE: 1 1

% POWER: 75 100 RCS TEMPERATURE: 544.1 547.9 RCS PRESSURE: 2250 2250 RCS BORON xxx 595 MWe NET: 724 854 GROSS RCS LEAKAGE: 0.08 0.07 BULK POWER NOTIFICATION Norma1 STP -

STP I Shift Manager 2006 Scenario #2

SHIFT TURNOVER INFORMATION SHEET 500KV High Lines [XlSOSl a5072 a5052 500KV Buses BLACK RED 13KV Supplies NP-13000-1 aP-13000-2 SMECO Bkr Status m252-2301 nOSH301 OSH302 Site Self Power Feeders [x1252-1106 a252-2106 13KV Buses N11 a12 El23 a21 a22 Voltage Regulators Auto 1102 Auto 2102 Auto 1103 Auto 2103 Auto 1101 Auto 2101 4KV Transformers NU-4000-11 [xIU-4000-21 [xIU-4000-12 ~ U - 4 0 0 0 - 2 2 ~ U -

mu-4000-13 4000-23 4KV Buses mll m12 a 13 a14 a 2 1 a 2 2 m23 a 2 4 Diesel Generators u1A U1B OOC 02A 02B DOC 480V Buses a l 1 A m l l B m14A a 1 4 B a 2 1 A a 2 1 B m24A m24B 125VDC Battery Chargers mll m23 m12 a24 a14 a22 a1 3 m21 125VDC Buses Ell1 Ed12 El22 Em 120VAC Vital Buses [XI11 m 2 1 m13 a23 a14 a24 a12 m22 I 11 HPSIPp I 2ADG I 15CWP I I 1A DG 2006 Scenario #2

SHIFT TURNOVER INFORMATION SHEET I 34 psig 12/03/04 I 32 psig 12/15/04 I I-

1. A member of BOPSEU shall be available and should be present during the performance of MSlV Partial Stroke testing. A Qualified Mechanic shall be available (not necessarily on location in the MSlV Room) with a spare Haskel Pump Shuttle Valve in hand to facilitate a replacement if requested by Operations and/or System Engineering..

2. Contact Ginna 0 585-771-3235, Nine Mile Point Unit One Q 315-349-2480, and Nine Mile Point Unit Two 0 315-349-2170if we enter AOP-7M for grid disturbances so they can evaluate any potential impact at their site. Result of 7-27-04 0800 conference call. (do not delete)

3. If Reactor Power lowers to below 85%, returns to 100% and is stable for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months then perform Thermal Performance Monitoring per PE 1-083-07-OM. RPA 2004-1447 submitted to add a step to OP-3 with this requirement.

4. PZR level alarms (E-33, E-34 and Plant Computer point PRZLVLHI) are credited in UFSAR 14.25. If BOTH E-33 AND E-34 are 00s OR if PRZLVLHI is unable to cause Selected Computer point (e.g., Plant Computer 00s or E-43 OOS), then EITHER place one Charging Pump in PTL OR station a Dedicated Operator. IRE-002-114. IRE-002-117.

5. Vent Charging pumps as follows: Vent suction stabilizers daily (normal PE), Vent pump discharge on pump shutdown when 3 are operable (this includes after weekly PE to run idle pumps), If any pump is inoperable, vent discharge on idle operable pump daily (During Vent PE).

6. Ensure 11 BABT is dumped to BAST within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months of sample because of the leaking DI valve. MO #1200501631 (P4, week 0614) for both Units.

7. If 14 Circ Pp Stator Temp alarms at ITR-16, notify John lhnacik or Paul Gray for strategy. Alarm 125C, Use heat killer. Memo at CRS Desk.

8. During a Unit 1 Shutdown secure 11B RCP prior to 11A. If performing RCP Trip Strategy in EOPs, preferentially stop 11A and 128 RCPs. Reference Memo at U-1 CRS desk Contact M. Lewis for additional operating strategy related to 11B RCP.

9. Computer point for COG (1752A) is not processing correctly (input from RMS is good). GPD can be read on 1-RR-11.

SHORT TFBM NOTFS-.

1. If an Aux Boiler is run for an extended period Contact Fin to adiust packinn

' - on 13 Aux Boiler Fuel Oil Pp. The .pump. is isolated with Temp Note 0-05-76 to prevent an oil leak house keeping issue:

2. Do not perform PE 0-027-6-0-W Aux Boiler Low Level Quick Drain Operability until the upcoming maintenance window is complete Week 0542 due to the safety concern around the steam emitting from the floor drain during the performance.

3. Vertical Tendon inspection in progress for next several weeks. Temporary Phone # for U-1 Containment Roof is X-3413, U-2 X-6553.

4. RPS Channel 'C' Delta T Power Pot is at setpoint fife limit, left voicemaif with Skip Winter, Dave Schrurnpf, and Mark Sirnpson.

10112/05

5. New AS1 channel checks in ODAC logs, using internal AS1 in the quadrant near the LRNl detector. Computer points are on page 2 of the Operating Parameters group 102.

6. Cask is scheduled to be placed in SFP on Monday, keep this in mind if filling SFP.

7. 11 HPSl Pp is 00s due to bearing oil leak.

a. 1A DG is 00s due to a governor problem, out 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago expected to be back at the end of shift.

9. 28 DG is removed from service 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago due to discovered burned wiring in local control cabinet.

IO. 15 CWP is off with 13A Waterbox open for cleaning.

2006 Scenario #2

Appendix D Attachment 1 SCENARIO OVERVIEW The scenario will begin with Unit 1 at 3% power. A quick trip recovery has just been performed following a reactor trip 34 hours3.935185e-4 days 0.00944 hours 5.621693e-5 weeks 1.2937e-5 months ago due to personnel error during RPS testing. 11 SGFP is out of service for alignment. 15 Circ Water Pump is off with 13A Waterbox open to clean out grass. The wind speed detector for 60 meters is out of service with 4 days remaining on the 7 day LCO. 4KV Bus 13 is aligned to U-4000-21. Maintenance has been completed on 4KV Bus 13 Normal Feeder Breaker 152-1311. Unit 2 is in Mode 5. Shift orders are to transfer 4KV Bus 13 to U-4000-11 and to raise Unit 1 power to 12%. Several minutes after the crew begins the power increase, PI'-lOOX fails high. The crew will respond IAW 1C06 ALM and swap control channels. Next, an E&C technician to inform that Battery 11 Cell 38 voltage is low. The CRS should use Tech Specs to determine that Battery 11 is inoperable. The crew should direct alignment of the reserve battery in place of Battery 11 on DC Bus 11. After Tech Specs are addressed, 14 Containment Air Cooler Fan will trip. Crew will respond by starting 13 Fan and declaring 14 Fan inoperable per Tech Specs. The Turbine Bypass Valve Controller output will fail high, opening TBVs. The CRO will need to place controls in manual and readjust output to stabilize the plant. A packing leak will develop on the running charging pump. After diagnosis, the crew will swap charging pumps and isolate the affected pump. The major event is a loss of offsite power with a fault on 4kV Bus 11.

Two CEAs will fail to insert on the trip. ERV-402 will stick partially open. HPSI will not auto actuate on SIAS because of ESFAS relay failure. The PORV cannot be isolated because the Train A MCC power source to the block valve is de-energized. The crew will respond EOP-0, EOP-2 and EOP-5. The CRO should manually start and align HPSI. The RO should emergency borate for the stuck CEAs. The scenario is terminated after leak isolation is attempted in EOP-5.

INSTRUCTOR SCENARIO INFORMATION

1. Reset to 3%, BOC conditions 34 hours3.935185e-4 days 0.00944 hours 5.621693e-5 weeks 1.2937e-5 months after trip from full power.

2. Perform switch check.

3. Place simulator in CONTINUE, advance charts and clear alarm display.

- 4. Place 15 CWP in Pm, align for cleaning 13A Waterbox.

5. Close 152-1301, open 152-1311.

- 6. Place simulator in FREEZE.

7. Enter Triggers None

8. Enter Malfunctions

a. Pressurizer pressure instrument PT-1OOX fails high rcsO23-01 to HIGH on F3 2006 Scenario #3 Page 2 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1

b. 14 containment air cooler fan trip cntmOO1-04 on F5

c. Turbine bypass valve controller PIC-4056 output failure high ms013 to 100% ramped over 2 minutes on F6

d. Charging pump packing leak cvcsO18-01 ramped to 5 gpm over 10 minutes on F7

e. LOOP, 4kV Bus 11 fault, 2 CEAs stuck,PORV-402 sticks, HPSI auto actuation failure swydOO2,2 second time delay on FS 4kvOO 1-0 1 , 2 second time delay on F8 cedsOlO for CEAs 45 and 59 on FS rcsO21 ramp to 6% over 3 minutes, with 4 second initiation time delay on F8 esfa017-01 on F8

9. Enter Panel Overrides None

10. Enter Remote Functions / Administrative

a. Caution tag 11 SGFP.

b. Caution tag 15 CWP in PTL.

c. Caution tag 60 meter wind speed indication.

11. Set simulator time to real time, then place simulator in CONTINUE.

__. 12. Give crew briefing.

a. Present plant conditions: 3% power at BOC xxxx MWD/MTU.

b. Power history: A quick trip recovery has just been performed following a reactor trip 34 hours3.935185e-4 days 0.00944 hours 5.621693e-5 weeks 1.2937e-5 months ago due to personnel error during RPS testing.

c. Equipment out of service: 11 SGFP is out of service for alignment.

15 Circ Water Pump is off with 13A Waterbox open to clean out grass.

60 meter wind speed 00s with 4 days remaining on the 7 day LCO.

d. Abnormal conditions: None

e. .Surveillances due: None

f. Instructions for shift: Following turnover, transfer 4KV Bus 13 to U-4000-11 and raise Unit 1 power to 12%. The brief for raising power has been completed.

2006 Scenario #3 Page 3 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1

- 13. Allow crew 3-5 minutes to acclimate themselves with their positions.

14. Instructions for the Booth Operator.

a. Activate F3, PT-lOOX failing high on lead examiner's cue.

b. Call CR with message from E&C technician when prompted by lead examiner for Event 4.

"Cell voltage readings were taken 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago on 125 VDC Battery 11. A review of the data shows Cell #38 has low voltage reading at 2.03 volts 'I.

If asked any followup questions, inform CRS that you don't have any other information. Supervisorjust asked you to call to inform Operations of low voltage reading. Will have Supervisor call Control Room when he gets back into the shop.

C. Activate F5,14 Containment Air Cooler Fan trip on lead examiner's cue.

d. Activate F6, TBV controller failure on lead examiner's cue.

e. Activate F7, charging pump packing leak on lead examiner's cue.

f. Activate F8, LOOP, 4KV Bus 11 fault on lead examiner's cue.

5 Collect trend data on the following for examiners:

0 Reactor Power 0 Turbine Generator Load ( M W )

0 RCS Loop Temperatures (Th, Tavg, Tc) 0 Pressurizer Pressure 0 Pressurizer Level Steam Generator Levels 2006 Scenario #3 Page 4 of 19 NUREG-1021, Revision 9

~~ ~~

Appendix D Attachment 1 RESPONSES TO CREW REQUEST If a request and response is not listed, delay response until reviewed with the examiner. If one request is dependent upon completion of another, then subsequent actions should not be responded to until the appropriate time delay has been observed. Responses to routine requests, which have no effect the scenario, do not require examiner clearance.

REOUEST RESPONSE

1. If asked any followup questions on report of Inform CRS that you don't have any other low battery cell voltage. information. Supervisorjust asked you to call to inform Operations of low voltage reading. Will have Supervisor call Control Room when he gets back into the shop.

2. Radiation Protection investigate high Acknowledge request activity readings in Aux Bldg REFERENCES Developmental:

Procedures:

Event 1 01-27C, 4.16 KV System, Rev 23 (Section 6.14)

Event 2 OP-2 Event 3 1C06 Alarm Manual (Window E-29)

Event 4 TS LCO 3.8.4 and LCO 3.8.6, DC Sources, Battery Parameters OI-26A, 125 Volt Vital DC, Rev 14 (Section 6.1)

Event 5 TS LCO 3.6.6, Containment Spray and Cooling Systems, Amendment 227 Event 6 Event 7 AOP-2A, Excessive Reactor Coolant Leakage, Rev 20 Event 8 CRITICAL TASKS 2006 Scenario #3 Page 5 of 19 NUREG-1021, Revision 9

~ ~

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 3 Event No.: 1 Event

Description:

Transfer 4KV Bus 13 to U-4000-11 Time Position Applicants Actions or Behavior CRS Orders shift of 4 KV Bus 13 from alternate to normal supply IAW OI-27C Verifies associated service transformer supply breaker is closed and no CRO transformer trouble alarms are present.

I CRO Inserts sync stick into sync jack for Normal Bus Feeder Breaker 152-1311 Verifies frequencies matched, sources in sync, checks bus voltage within 7 volts of incoming source voltage.

Closes normal feeder breaker 152-1311.

Opens alternate feeder breaker 152-1301.

Returns sync stick to home and informs CRS of completed evolution.

2006 Scenario #3 Page 6 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 3 Event No.: 2 Event

Description:

Raise Reactor Power to 12%

r RO 1 Ensures all pressurizer backup heater banks are energized I I CRO I Ensures PIC-1OOX is adjusted to maintain 2250 psia pressurizer pressure.

2006 Scenario #3 Page 7 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 3 Event No.: 3 Event

Description:

Pressurizer Pressure lnst PT-1OOX Fails High Time Position Applicant's Actions or Behavior Acknowledges 1C06 PZR CH 100 PRESS alarm. Observes PT-1OOX high, RO spray valves open, heaters de-energized. Informs CRS.

I I

RO I I

Shifts pressurizer pressure control to PT-1OOY.

I I Ro I Observes proper heater and spray operation. Monitors parameters returning to normal. informs CRS.

2006 Scenario #3 Page 8 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 3 Event No.: 4 Event

Description:

Technician Reports Low Float Voltage Reading on Battery 11, Cell 38 at 2.03 Volts (TS CRS)

.i I I Time Position Applicants Actions or Behavior CRS Receives call from technician informing him that cell voltage readings were taken 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago on 125 VDC Battery 11. A review of the data shows Cell

38 has low voltage reading at 2.03 volts.

CRS Refers to TS 3.8.6 and determines Battery 11 is inoperable.

CRS Refers to TS 3.8.4 and determines Battery must be replaced with Reserve Battery within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

Directs replacing Battery 11 with the Reserve Battery.

2006 Scenario #3 Page 9 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 II I I

CRS CRO I

Directs CRO to start 13 Containment Air Cooler Fan 1 Starts 13 CAC Fan and verifies proper operation.

I I CRS 1 Determines 14 CAC Fan is inoperable. Enters TS LCO 3.6.6 Action.

2006 Scenario #3 Page 10 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Event

Description:

Turbine Bypass Valve Controller Failure (Valves Open) 1 Time I Position Applicants Actions or Behavior Observe indications of excessive cooling (pzr press decr, pzr Ivl decr, Tc decr). Identify turbine bypass valves are failing open.

~~ ~~ ~ ~~

Places TBV controller in MANUAL and throttles closed on TBVs.

1 RO inserts /withdraws CEAs as needed / directed.

I 1 CRS Contacts maintenance for troubleshooting and repair.

2006 Scenario #3 Page 11 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 est No.: 1 vent

Description:

Charging Pump Primary Packing Leak Applicant's Actions or Behavior Observe indications of increasing activity in aux bldg. Inform CRS.

Monitors for RCS leakage increase. May note slight decrease in letdown flow.

Informs Radiation Protection.

Enters AOP-2A, "Excessive Reactor Coolant Leakage" Directs activities to attempt to determine RCS leak rate.

i I CRS If needed, directs activities to attempt to determine leak location.

Contact AB0 to look for leaks per Attachment 2.

l---t=- CRS / RO Informed by AB0 of 11 Charging Pump packing leakage.

Shifts to backup charging pump. Places 11 Chg Pump in PTL.

Direct AB0 to isolate 11 Charging Pump.

Contacts maintenance for repair.

2006 Scenario #3 Page 12 of 19 NUREG-I 021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 3 Event No.: 8 Event

Description:

Loss of Offsite Power with Fault on 4kV Bus 11,2 CEAs Fail to Fully Insert Performs immediate actions. Determines 2 CEAs did not fully insert.

Commences emergency boration.

CRO ~~ I Performs immediate actions.

Directs response per EOP-0, EOP-2 and EOP-5.

2006 Scenario #3 Page 13 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 3 Event No.: 9 Event

Description:

PORV 402 sticks partially open, HPSl Auto Actuation Failure 1 Time 1 Position Applicant's Actions or Behavior I Ro Determines PORV-402 did not fully reseat. Informs CRS that valve is not closed and unable to close block valve due to loss of power to MOV.

Determines HPSI did not auto actuate, manually starts 13 HPSl Pump and manually opens SI-636-MOV and SI-646-MOV.

I I CRO Informs CRS.

2006 Scenario #3 Page 14 of 19 NUREG-1021, Revision 9

SHIFT TURNOVER (Attachment 1)

I. Present Plant Conditions 3%

11. Burnup: xx MWD/MTU (MOC) 111. Power History Startup from trip from 100% power 34 hours3.935185e-4 days 0.00944 hours 5.621693e-5 weeks 1.2937e-5 months ago.

IV. Equipment out of Service: 11 SGFP is out of service for alignment. 15 Circ Water Pump is off with 13A Waterbox open to clean out grass. 60 meter wind speed 00s with 4 days remaining on the 7 day LCO.

V. Abnormal Conditions: None VI. Surveillances Due: None VII. Instructions for Shift Following turnover, transfer 4KV Bus 13 to U-4000-1 1 and raise Unit 1 power to 12%.

VIII. U2 Status and Mode 5 Major Equipment 00s:

2006 Scenario #3

U-1 Reactor Operator Shift Briefing Sheet Today RxPower:3 %

Boron: xxx ppm Burnup: XXXXX MWD/MTU AS1 Value: 0.011 (Cecor) steady Xenon: 1.85 and building in Neutral Blend: 3 gal BA & 35 ga2 DZ Last Shot: 50 gal of DI 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago CEA Moves: GRP 5 120 1.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months ago cvcs IXs: 11for purification 12 for delithiation

Thumb Rules (Good until 11500 MWDMTU)

Tcold: -1.4 deg F @ 100 % power Dilution: 160 gal of DI @ 100 % power Boration: 14.1 gal from the BAST 103.9 gal from the R WT CEAs: 6.75 inches Glp 5 SW Injection times: - to 2006 Scenario #3

SHIFT TURNOVER INFORMATION SHEET For Training Only I PARAMETER UNIT 1 UNIT 2 I MODE: 1 5

% POWER: 3 0 RCS TEMPERATURE: 532.3 108 RCS PRESSURE: 2250 atmos RCS BORON xxx 2538 h4We NET: 0 0 GROSS RCS LEAKAGE: 0.08 NIA BULK POWER NOTIFICATION Normal I

TBD Shift Manager 2006 Scenario #3

SHIFT TURNOVER INFORMATION SHEET 3

2 'ELECTRICAL SYSTEM-,

500KV High Lines N505l m5072 m5052 500KV Buses QBLACK BRED 13KV Supplies QP-13000-1 Ix]P-13000-2 SMECO Bkr Status m252-2301 00SH301 OSH302 Site Self Power Feeders B252-1106 m252-2106 13KV Buses a11 m12 a23 Ea21 Ea22 Voltage Regulators Auto 1102 Auto 2102 Auto 1103 Auto 2103 Auto 1101 Auto 2101 4KV Transformers [X1U-4000-11 Ix]U-4000-21 NU-4000-12 [xIU-4000-22BU-

@U-4000-13 4000-23 4KV Buses @ll Q12 m13 m 1 4 a 2 1 a 2 2 a 2 3 1x124 Diesel Generators D1A D1B DOC [72A 02B UOC 480V Buses E l l A B l l B N14A M14B N21A a 2 l B a 2 4 A B 2 4 B 125VDC Battery Chargers E11 R23 ml2 a24 a14 m22 a1 3 a21 125VDC Buses Ell1 lxll2 a22 e121 120VAC Vital Buses all a21 a 13 N23 N14 a24 a12 N22 60 Meter Wind Speed 15 CWP 11 SGFF' 2006 Scenario #3

SHIFT TURNOVER INFORMATION SHEET I 34 psig 12/03/04 1 32 psig 12/15/04 , I

1. A member of BOPSEU shall be available and should be present during the performance of MSlV Partial Stroke testing. A Qualified Mechanic shall be available (not necessarily on location in the MSlV Room) with a spare Haskel Pump Shuttle Valve in hand to facilitate a replacement if requested by Operations andlor System Engineering..

2. Contact Ginna @ 585-771-3235, Nine Mile Point Unit One @ 315-349-2480, and Nine Mile Point Unit Two @ 315-349-2170 if we enter AOP-7M for grid disturbances so they can evaluate any potential impact at their site. Result of 7-27-04 0800 conference call. (do not delete)

3. If Reactor Power lowers to below 85%, returns to 100% and is stable for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months then perform Thermal Performance Monitoring per PE 1-083-07-OM. RPA 2004-1447 submitted to add a step to OP-3 with this requirement.

4. PZR level alarms (E-33, E-34 and Plant Computer point PRZLVLHI) are credited in UFSAR 14.25. If BOTH E-33 AND E-34 are 00s OR if PRZLVLHI is unable to cause Selected Computer point (e.g., Plant Computer 00s or E-43 OOS), then EITHER place one Charging Pump in PTL OR station a Dedicated Operator. IRE-002-114. IRE-002-117.

5. Vent Charging pumps as follows: Vent suction stabilizers daily (normal PE), Vent pump discharge on pump shutdown when 3 are operable (this includes after weekly PE to run idle pumps), If any pump is inoperable, vent discharge on idle operable pump daily (During Vent PE).

6. Ensure 11 BABT is dumped to BAST within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months of sample because of the leaking DI valve. MO #1200501631 (P4, week 0614) for both Units.

7. If 14 Circ Pp Stator Temp alarms at 1TR-16, notify John lhnacik or Paul Gray for strategy. Alarm 125C, Use heat killer. Memo at CRS Desk.

8. During a Unit 1 Shutdown secure 11B RCP prior to 11A. If performing RCP Trip Strategy in EOPs, preferentially stop 11A and 12B RCPs. Reference Memo at U-1 CRS desk Contact M. Lewis for additional operating strategy related to 11B RCP.

9. Computer point for COG (1752A) is not processing correctly (input from RMS is good). GPD can be read on 1-RR-11.

RT TF5M NOTFS..

I. If an Aux Boiler is run for an extended period Contact Fin to adjust packing on 13 Aux Boiler Fuel Oil Pp. The pump

. . is isolated with Temp Note 0-05-76 to prevent an oil leak house keeping issue:

2. Do not perform PE 0-027-6-0-W Aux Boiler Low Level Quick Drain Operability until the upcoming maintenance window is complete Week 0542 due to the safety concern around the steam emitting from the floor drain during the performance.

3. Vertical Tendon inspection in progress for next several weeks. Temporary Phone # for U-1 Containment Roof is X-3413, U-2 X-6553.

4. RPS Channel 'C' Delta T Power Pot is at setpoint file limit, lefl voicemail with Skip Winter, Dave Schrumpf, and Mark Simpson.

10112/05

5. New AS1 channel checks in ODAC logs, using internal AS1 in the quadrant near the LRNl detector. Computer points are on page 2 of the Operating Parameters group 102.

6. Cask is scheduled to be placed in SFP on Monday, keep this in mind if filling SFP.

7. 15 CWP is off with 13A Waterbox open for cleaning.

0. 11 SGFP 00s for alignment.

9. 60 meter wind speed 00s.

2006 Scenario #3

Appendix D Attachment 1 Facility: Calvert Cliffs 1 & 2 Scenario No.: 4 Op-Test No.: 2006 Initial Conditions: 50% Rated Thermal Power, MOL, Equilibrium Conditions Turnover: Unit 1 is at 50% power. 11 SGFP alignment complete, ready for startup. The following equipment is out of service: 15 CW PP off and Waterbox 13A open to clean out grass. In TRM LCO 15.3.2 Action A for 60 meter wind speed detector 00s (4 days remaining on 7 day LCO). All required surveillances are complete. Weather conditions are normal. Unit 2 is in MODE 5.

Orders are to place 11 SGFP in service and raise Unit 1 power to 65% at 10% per hour. OP-3 Step 6.1 .F.1 is complete. OI-12A Step 6.1 1.C.2.w is complete. 11 SGFP has been rotating with gland seal steam aligned for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

1 -------------- (CRo) Start 11 SGFP and Raise Reactor Power to 65%

R (RO)

I 2 I CEDSOOS I C (RO) I Raise Relay Sticks When CEAs Withdrawn 3 SRW003-01 C (CRO) Service Water Pump 11 Trip (TS CRS) 4 OR HS5292 ------- Loss of Containment Rad Monitor Sample Flow (TS CRS) 5 RCS036 I (RO) Pressurizer Level Controller Output Fails Below 4 mA I 6 ITGO26 I C (CRO) I Main Generator Auto Voltage Regulator Failure CD008 FIRE001 Condensate Booster Pump Discharge Line Rupture, A M , 2 RPS005/006 (ALL) CEAs Fail to Fully Insert CEDSOl 1 Loss of All Feedwater AFWOOl I

I Terminate after once-through cooling established in EOP-3

~~~~

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2006 Scenario #4 Page 1 of 19 NUREG-1021, Revision 9

~ ~~

Appendix D Attachment 1 SCENARIO OVERVIEW The scenario will begin with Unit 1 at 50% power. 15 Circ Water Pump is off with 13A Waterbox open to clean out grass. The wind speed detector for 60 meters is out of service with 4 days remaining on the 7 day LCO. Unit 2 is in Mode 5. Shift orders are to start up 11 SGF'P and raise reactor power to 65% at 10% per hour. During the power increase, a CEA raise relay failure causes CEAs to withdraw continuously. The RO will place CEDS in off. Troubleshooting will be initiated. Next, 11 SRW Pump will trip, requiring realignment of 13 SRW pump to 11 subsystem.

13 SRW Pump will be started on 11 subsystem. The CRS will reference Tech Specs and declare 11 subsystem inoperable due to misaligned power supply to 13 SRW Pump. Containment atmosphere particulate and gaseous radiation monitors (5280/5281) will lose sample flow when the associated sample line isolation, 1-CRM-5291-CV closes. The CRS will refer to Tech Specs. The RO will respond to a failure of the pressurizer level controller output by taking the controller to manual and restoring proper level control. A failure of the main generator voltage regulator will require the CRO to shift the regulator to manual and readjust reactive load. A rupture of the condensate booster pump discharge line in the turbine building will result in a trip of both main feed pumps. The CRS should order a manual reactor trip. Both auto and manual reactor trips fail, requiring a trip by de-energizing MG sets. 2 CEAs fail to fully insert, requiring the RO to commence emergency boration. 12 and 13 AFW pumps trip upon start signals and 11 AFW pump does not come up to normal full speed, only pumping approximately 60 gpm. The crew should respond IAW EOP-0 and EOP-3. All RCPs will be stopped. Once-through core cooling will be initiated. The scenario is terminated after once-through established in EOP-3.

INSTRUCTOR SCENARIO INFORMATION

- 1. Reset to IC-16,50%, MOC.

- 2. Perform switch check.

__ 3. Place simulator in CONTINUE, advance charts and clear alarm display.

4. Setup 11 SGF'P for parallel operation through OI-l2A, Step 6.1 1.C.2.w.

- 5. Place 15 CWP in PTL,align for cleaning 13A Waterbox.

6. Place simulator in FREEZE.

7. Enter Triggers None

8. Enter Malfunctions

a. Raise relay sticks when CEAs withdrawn ceds003

b. 11 SRW pump trip snvOO3-01 on F3 2006 Scenario #4 Page 2 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1

c. Pressurizer level controller output fails below 4 mA rcsO36 on F5

d. Main generator auto voltage regulator failure tg026 on F6

e. CBP disch line rupture, ATWT, 2 CEAs fail to fully insert cd008 at 80% on F7 (CBP disch line rupture) fire001 on F7 (fire alarm) rps005 on F7 (auto reactor trip failure) rps006 on F7 (manual reactor trip failure) cedsOlO for CEAs 1 and 37 on F7 (2 stuck rods) afwOO5 on F7 (13 AFW pump breaker failure) afw001-02 on F7 (12 AFW pump trip)

9. Enter Panel Overrides

a. Override the lC10 handswitch for 1-CRM-5291-CV7Cntmt RMS Isol, to the CLOSE position on F4

10. Enter Remote Functions / Administrative

a. Caution tag 15 CWP in PTL.

b. Caution tag 60 meter wind speed indication.

- c. afwOl2 at 5% on F7 (1 1 AFWPT steam supply)

11. Set simulator time to real time, then place simulator in CONTINUE.

12. Give crew briefing.

a. Present plant conditions: 50% power at MOC xxxx mm.

b. Power history: xxxx

c. Equipment out of service: 15 Circ Water Pump is off with 13A Waterbox open to clean out grass.

60 meter wind speed 0 0 s with 4 days remaining on the 7 day LCO.

d. Abnormal conditions: None

e. Surveillances due: None

f. Instructions for shift: Following turnover, start 11 SGFP and raise power to 65% at 10% per hour.

OP-3 is complete through Step 6.1.F. 1.

11 SGFP startup is complete through OI- 12A Step 6,11.C.2. The brief for raising power has been completed.

- 13. Allow crew 3-5 minutes to acclimate themselves with their positions.

- 14. Instructions for the Booth Operator.

2006 Scenario #4 Page 3 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1

a. Insert MF CEDS003, to stick raise relay when CEAs withdrawn.

b. Activate F3, 11 SRW pump trip on lead examiner's cue.

c. Activate F4, loss cntmt rad monitor sample flow on lead examiner's cue.

d. Activate F5, pressurizer level controller failure on lead examiner's cue.

e. Activate F6, CBP disch line rupture, ATWT, AFW failure on lead examiner's cue.

f. Collect trend data on the following for examiners:

Reactor Power Turbine Generator Load (MW)

RCS loop temperatures (Th, Tavg, Tc)

Pressurizer Pressure Pressurizer Level Steam Generator Levels 2006 Scenario #4 Page 4 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 RESPONSES TO CREW REQUEST If a request and response is not listed, delay response until reviewed with the examiner. If one request is dependent upon completion of another, then subsequent actions should not be responded to until the appropriate time delay has been observed. Responses to routine requests, which have no effect the scenario, do not require examiner clearance.

REOUEST RESPONSE

1. E&C investigate cause of continuous CEA Acknowledge request. After 5 minutes, withdraw a1 report cause identified as faulty withdrawal relay, can be replaced within about 30 minutes.

2. TBO investigate trip of SRW pump. After 3 minutes, report 86 lockout on breaker, motor casing warm, no other obvious signs of problems.

3. Maintenance investigate closure of Acknowledge request.

containment rad monitor sample line isolation 5291.

4. PO identify local alarm on 1E01. Acknowledge request. After 2 minutes, report that alarm is Window Al-5, "MXL is LIMITING" REFERENCES Developmental:

Event 3 01-27C, 4.16 KV System, Rev 23 Procedures:

Event 1 OI- 12A, OP-3 Event 2 Event 3 AOP-7BYLoss of Service Water, Rev 13 Event 4 1C10 ALM (Window J-07)

Event 5 Event 6 lCOl ALM (Window A-41), lEOl ALM (Window "MXL is LIMITING")

OI-43A, Main Turbine and GeneratorExciter Operation, Rev 4 1 Event 7 EOP-0, EOP-3 CRITICAL TASKS 2006 Scenario #4 Page 5 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 4 Event No.: 1 Event

Description:

Start 11 SGFP and Raise Reactor Power to 65%

-=-$===

Time Position Applicants Actions or Behavior I CRS Orders CRO to startup 11 SGFP and place in automatic parallel operation with 12 SGFP IAW OI-12A at Section 6.11. C.2.w.

I CRO Refers to 01-12A.

Ensures 11 SGFP HIC controller is in MANUAL.

Adjusts 11 SGFP SPD CONTR, 1-HIC-4516 until the XFER PERM indicator is lit on the OCS.

When XFER PERM is illuminated, depresses the HIC pushbutton on the ocs.

Checks that DEMAND RPM displayed on the OCS and the output of 11 SGFP are within 50 rpm.

I CRO Returns the BIAS setting for 11 SGFP to 5.0.

I CRO Places 11 SGFP Miniflow Controller, 1-FIC-4484 in MANUAL.

Raises 11 SGFP speed to match the MANUAL signal with the AUTO signal.

Adjusts the BIAS on 12 SGFP.

1 CRO Places 11 SGFPT SPD CONTR, 1-HIC-4516, in AUTO.

Monitors SGFPs for proper automatic operation.

Slowly shuts 11 SGFP miniflow using 1-FIC-4484, until the valve is shut or miniflow controller is at setpoint while adjusting the BIAS towards the ideal setting of 5.0 on 12 SGFP to maintain minimum flow requirements.

Places 11 SGFP Miniflow Controller, 1-FIC-4484, in AUTO.

Places 11 SGFPT drains handswitch, 1-HS-8005, in CLOSE.

Orders RO / CRO to commence power increase and informs Chemistry.

~~

Energizes all pressurizer backup heater banks.

2006 Scenario #4 Page 6 of 19 NUREG-1021, Revision 9

~ _ ~~ _ ~ ~

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 4 Event No.: 1 Event

Description:

Start 11 SGFP and Raise Reactor Power to 65%

Position Applicants Actions or Behavior P

RO Adjusts the setpoint of PIC-1OOX to maintain 2250 psia pressurizer pressure.

Clicks on <Control><load> Load Set, Ramp Rate and enters the desired Load CRO Ramp Rate of 1.9%

Increases turbine load by one of the three following methods:

1. Clicks on <Control><load> Load Set, Load AND enters the desired Load Ref Cmd CRO

-0R-

2. Clicks on <Control><load> Load Set, Manual Adi, Raise

-0R-

3. Adjusts Turbine Load Set, 1-CS-80 Adjusts the Load Limit Setpoint to maintain it approximately lo(+)%above CRO generator load by clicking on Load Limit, Setpoint AND entering the desired value.

Performs dilution per 01-26 to maintain Tc within 2°F of program per OP-3 RO Figure 1, Temperature Program Curve.

RO Withdraws CEAs as desired to maintain temperature and ASI.

2006 Scenario #4 Page 7 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 4 Event No.: 2 Event

Description:

Raise Relay Sticks When CEAs Withdrawn I/ I Time Position Applicants Actions or Behavior RO Withdraws CEAs with In-Hold-Out Switch RO Releases switch and determines CEAs continue to withdraw. Informs CRS.

RO Selects OFF on CEDS. Observes CEAs stop withdrawing.

2006 Scenario #4 Page 8 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 4 Event No.: 3 Event

Description:

Service Water Pump 11 Trip (TS CRS)

Time Position Applicants Actions or Behavior Determines 11 SRW Pump has tripped. Reports to CRS.

Refers to AOP-7B. Directs CRO to realign 13 SRW pump to 11 subsystem.

Places 13 SRW pump handswitch in PTL.

I CRO Orders TBO to lock shut 13 pump suctions / discharges to 12 subsystem and lock open suction / discharges to 11 subsystem.

Reports to CRS when 13 SRW pump mechanically aligned to 11 subsystem.

Orders CRO to start 13 SRW pump.

I CRO Announces then starts 13 SRW pump and verifies proper indications.

1 CRS Refers to TS 3.7.6, declares 11 subsystem inoperable because 13 SRW pump power supply not aligned to 11 4KV Bus. Enters 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO.

2006 Scenario #4 Page 9 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 4 Event No.: 4 Event

Description:

Loss of Containment Rad Monitor SampleFlow (TS CRS)

Time Position Applicants Actions or Behavior ,

Acknowledges CNTMT RMS FLOW alarm at 1C10. Informs CRS.

Refers to ALM.

Determines 1-CRM-5291-CV, Cntmt RMS Is01 (HS on 1C10, valve located 27 foot Cntmt East) is shut. Informs CRS.

Refers to TS 3.4.1 4, RCS Leakage Detection Instrumentation. Enters TS LCO 3.4.14 Action B.

I CRS Directs Plant Chemistry to obtain containment atmosphere grab samples once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and analyze for activity per TS LCO 3.4.14 Acction B.

Contacts maintenance to troubleshoot and repair 1-CRM-5291-CV.

2006 Scenario #4 Page 10 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 4 Event No.: 5 Event

Description:

Pressurizer Level Controller Output Fails Below 4 mA Observes unexpected parameter change (letdown flow increasing)

I Ro I Determines that pressurizer level controller output has failed. Takes manual control of HIC-110. Informs CRS.

I RO I Restores letdown flow to normal.

Contacts E&C to troubleshoot and repair.

2006 Scenario #4 Page 11 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 4 Event No.: 6 Event

Description:

Main Generator Auto Voltage Regulator Failure Time Position Applicants Actions or Behavior CRO Acknowledges MAIN GEN VOLT REG 1E01 alarm on 1CO1. Informs CRS.

CRO Contacts PO to determine affected local alarm on 1E01.

I CRo II Observes increased MVAR and increased exciter field current on 1CO1.

Recommends controlling voltage regulator in MANUAL.

I CRS Directs CRO to shift VR to MANUAL per OI-43A, Section 6.5.

CRS Informs SO-TSO of malfunction and planned actions.

CRO Places VR Selector 1-CS-43 in MANUAL.

2006 Scenario #4 Page 12 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 4 Event No.: 7 Event

Description:

Condensate Booster Pump Discharge Line Rupture, A M , 2 CEAs Fail to Fully Insert I Time Position Applicants Actions or Behavior CRO Observes indications of line rupture (fire alarm, trip of MFW pumps, loss of CBP discharge pressure, lowering SG level) and informs CRS.

CRS Orders manual reactor trip and enters EOP-0 RO Attempts manual reactor trip by depressing trip pushbuttons at 1C05.

CRO Attempts manual reactor trip by depressing trip pushbuttons at 1C15.

CRO Opens 480 Volt Buses 12A and 13A Feeder Breakers at 1C17.

RO Observes prompt drop in NI power and a negative SUR.

CRO Re-closes 480 Volt Buses 12A and 13A Feeder Breakers at 1C17.

RO Determines 2 CEAs failed to fully insert on trip and initiates boration by:

- opening 514-MOV, direct MU valve

- opening 508-MOV, gravity feed valve

- opening 509-MOV, gravity feed valve

- starting a BA pump

- starting all available charging pumps

- closes 501-MOV, VCT outlet valve CRO / RO Perform EOP-0 immediate actions.

CRO Observes 12 and 13 AFW Pumps are tripped and 11 ANV pump is not providing normal flow. Dispatches operators to investigate.

CRS Determines a loss of feedwater event is in progress. Transitions to EOP-3.

May also transition to EOP-8.

2006 Scenario #4 Page 13 of 19 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 4 Event No.: 8 Event

Description:

Loss of All Feedwater Applicants Actions or Behavior Trips all RCPs.

Closes SGBD Valves 4010,401 1,401 2,4013 Confirms boration in progress with 3 charging pumps running.

Direct activities to attempt to restore ARN flow.

Determines criteria met for once-through cooling Places pzr heaters in OFF.

Shuts Letdown isolations CVC-515-CV and CVC-516-CV.

Opens both PORVs.

Blocks SIAS.

Starts all 3 HPSl pumps.

Opens main and aux HPSl header isolations (8 valves).

Opens all Cntmt Clr Emer Outlet Valves Starts all Cntmt Air Coolers in High.

Verifies HPSl once-through cooling flow per Attachment 10 when RCS pressure is e1270 psia.

Verifies CET temperatures constant or falling.

If SlAS has not initiated, directs local initiation of SIAS A6 and B6.

CRO Performs Attachment 17.

2006 Scenario #4 Page 14 of 19 NUREG-1021, Revision 9

SHIFT TURNOVER (Attachment 1)

I. Present Plant Conditions 50%

11. Burnup: xxxxx MWD/MTU (MOC) 111. Power History IV. Equipment out of Service: 15 Circ Water Pump is off with 13A Waterbox open to clean out grass. 60 meter wind speed 00s with 4 days remaining on the 7 day LCO.

V. Abnormal Conditions:

VI. Surveillances Due: None VII. Instructions for Shift Following turnover, start 11 SGFP and raise power to 65% at 10% per hour. OP-3 is complete through Step 6.1.F.1. 11 SGFP startup is complete through 01-12A Step 6.1 1.C.2.

VIII. U2 Status and Mode 5 Major Equipment 0 0 s :

2006 Scenario #4

U-1 Reactor Operator Shift Briefing Sheet Today Rx Power: 50 %

Boron: x= PPm Burnup: XXX M WD/MTU AS1 Value: 0.011 (Cecor) steady Xenon: 1.85 and building in Neutral Blend: 3 g d BA & 35 gaE DI Last Shot: 50 gal of DI 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago CEA Moves: GRP 5 120 1.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months ago CVCS IXs: 11for pur@cation Dr 12 for delithiation I Thumb Rules (Good until 11500 MWDMTU)

Tcold: -1.4 deg F @ 100 % power Dilution: 160 gal of DI @ 100 % power Boration: 14.1 gal from the BAST 103.9 gal from the RWT CEAs: 6.75 inches Grp 5 SW Injection times: - to 2006 Scenario #4

SHIFT TURNOVER INFORMATION SHEET Fur Training Only PARAMETER UNIT 1 UNIT 2 MODE: 1 5

% POWER: 50 0 RCS TEMPERATURE: 539.9 108 RCS PRESSURE: 2250 atmos RCS BORON XXX 2538 MWe NET: xxx 0 GROSS RCS LEAKAGE: 0.08 NIA BULK POWER NOTIFICATION Normal TED Shift Manager 2006 Scenario #4

SHIFT TURNOVER INFORIUATION SHEET 500KV High Lines a5051 H5072 a5052 500KV Buses [XIBLACK RED 13KV Supplies HP-13000-1 aP-13000-2 SMECO Bkr Status m252-2301 00SH301 OSH302 Site Self Power Feeders m252-1106 [x1252-2106 13KV Buses a1 1 a12 m23 El21 a22 Voltage Regulators Auto 1102 Auto 2102 Auto 1103 Auto 2103 Auto 1101 Auto 2101 4KV Transformers mu-4000-11 mu-4000-21 Ix]U-4000-12 mU-4000-22HU-

@U-4000-13 4000-23 4KV Buses mll m 1 2 m13 m 1 4 a 2 1 m22 m23 m24 Diesel Generators 01A 01B [IIlOC 02A 02B OOC 480V Buses m l l A m l l B H14A m14B m21A H21B H24A m24B 125VDC Battery Chargers m11 m23 a12 a24 a14 a22 a1 3 a21 125VDC Buses Ell1 Ix112 [xi22 421 120VAC Vital Buses a1 1 m21 a 13 m23 a14 [xi24 H12 a22 I I 1 60 meter wind speed 15 CWP 2006 Scenario #4

SHIFT TURNOVER INFORMATION SHEET 1.

2.

A member of BOPSEU shall be available and should be present during the performance of MSlV Partial Stroke testing. A Qualified Mechanic shall be available (not necessarily on location in the MSlV Room) with a spare Haskel Pump Shuttle Valve in hand to facilitate a replacement if requested by Operations and/or System Engineering..

Contact Ginna @ 585-771-3235, Nine Mile Point Unit One @ 315-349-2480, and Nine Mile Point Unit Two @ 315-349-2170 if we enter AOP-7M for grid disturbances so they can evaluate any potential impact at their site. Result of 7-27-04 0800 conference call. (do not delete)

3. If Reactor Power lowers to below 85%, returns to 100% and is stable for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months then perform Thermal Performance Monitoring per PE 1-083-07-OM. RPA 2004-1447 submitted to add a step to OP-3 with this requirement.

4. PZR level alarms (E-33, E-34 and Plant Computer point PRZLVLHI) are credited in UFSAR 14.25. If BOTH E-33 AND E-34 are 00s OR if PRZLVLHI is unable to cause Selected Computer point (e.g., Plant Computer 00s or E-43 OOS), then EITHER place one Charging Pump in PTL OR station a Dedicated Operator. IRE-002-114. IRE-002-117.

5. Vent Charging pumps as follows: Vent suction stabilizers daily (normal PE), Vent pump discharge on pump shutdown when 3 are operable (this includes after weekly PE to run idle pumps), If any pump is inoperable, vent discharge on idle operable pump daily (During Vent PE).

6. Ensure 11 BABT is dumped to BAST within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months of sample because of the leaking DI valve. MO #1200501631 (P4, week 0614) for both Units.

7. If 14 Circ Pp Stator Temp alarms at 1TR-16, notify John lhnacik or Paul Gray for strategy. Alarm 125C, Use heat killer. Memo at CRS Desk.

8. During a Unit 1 Shutdown secure 11B RCP prior to 11A. If performing RCP Trip Strategy in EOPs, preferentially stop 11A and 12B RCPs. Reference Memo at U-1 CRS desk Contact M. Lewis for additional operating strategy related to 11B RCP.

9. Computer point for COG (1752A) is not processingcorrectly (input from RMS is good). GPD can be read on 1-RR-11.

SHORT TFRM NOTF&.

I. If an Aux Boiler is run for an extended period Contact Fin to adjust .packing on 13 Aux Boiler Fuel Oil Pp. The pump is isolated with Temp Note 0-05-76 to prevent an oil leak house keeping issue.

2. Do not perform PE 0-027-6-0-W Aux Boiler Low Level Quick Drain Operability until the upcoming maintenance window is complete Week 0542 due to the safety concern around the steam emitting from the floor drain during the performance.

3. Vertical Tendon inspection in progress for next several weeks. Temporary Phone # for U-1 Containment Roof is X-3413, U-2 X-6553.

4. RPS Channel 'C' Delta T Power Pot is at setpoint file limit, lefl voicemail with Skip Winter, Dave Schrumpf, and Mark Simpson.

10112/05

5. New AS1 channel checks in ODAC logs, using internal AS1 in the quadrant near the LRNl detector. Computer points are on page 2 of the Operating Parameters group 102.

6. Cask is scheduled to be placed in SFP on Monday, keep this in mind if filling SFP.

7. 15 CWP is off with 13A Waterbox open for cleaning.

8. 60 meter wind speed 00s.

2006 Scenario #4

Appendix D Attachment 1 Facility: Calvert Cliffs 1 & 2 Scenario No.: 5 Op-Test No.: 2006 Examiners: Operators:

Initial Conditions: 100% Rated Thermal Power, MOL, Equilibrium Conditions Turnover: Unit 1 is at 100% power. DG 1A declared inoperable 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago due to discovery of burned wiring in DG 1A local control cabinet. Repairs are in progress. 71 hours8.217593e-4 days 0.0197 hours 1.173942e-4 weeks 2.70155e-5 months remaining on 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO 3.8.1 Action C because DG 2B also out of service. 11 HPSl Pump tagged to repair bearing oil leak (68 hours7.87037e-4 days 0.0189 hours 1.124339e-4 weeks 2.5874e-5 months remaining on 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO 3.5.2.a). Maintenance on these components (DG l A , 11 HPSl PP) expected t o be completed 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months from now. 15 CW PP off, Waterbox 13A open to clean out grass. All required surveillances are complete. Weather conditions are normal.

Unit 2 is in MODE 5 with DG 2 6 out of service for liner inspection. DG OC is aligned to Unit 2 due to DG 2 8 00s.Shift orders are to maintain Unit 1 at 100% power.

Event Event Event Malf. No.

No. Type* Description 1 OR HS1415 (Ro) 16B FWH High Level Dump Fails Open N(CRO) 2 S1009-04 C (CRO) Safety Injection Tank 128 Leakage (TS CRS)

I CVCSO15 I I (RO) I VCT Level Transmitter LT226 Fails Low

~~ ~

3 4 (TGOO4 I C (CRO) I Turbine Control Valve Fails Closed 5 I RCS030 I C (RO) I Failed Fuel (TS CRS) 6 1 1

~ ~ ~ ~ " _ " 0M ' (ALL) 2 1 Loss of Offsite Power, DG 1B Start Failure I Terminate after Power Restored to Bus 14

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2006 Scenario #5 Page 1 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1 SCENARIO OVERVIEW The scenario will begin with Unit 1 at 100% power. DG 1A declared inoperable 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago due to discovery of burned wiring in DG 1A local control cabinet. Repairs are in progress. 11 HPSI PP is 00s to repair a bearing oil leak. 15 Circ Water Pump is off with 13A Waterbox open to clean out grass. Unit 2 is in Mode 5 with DG 2B out of service for liner inspection. DG OC is aligned to Unit 2 due to DG 2B 00s. Shift orders are to maintain Unit 1 at 100% power. 16B Feedwater Heater High Level Dump valve fails open, requiring the crew to reduce turbine load to maintain power less than 100%. 12B Safety Injection Tank will exhibit leakage, requiring the crew to fill the SIT. Tech Specs will be referenced. VCT level transmitter LT226 will fail low, resulting in auto VCT makeup. The RO will take manual control and stop the auto makeup. Next, a turbine control valve will fail closed. The crew will stabilize load at a lower value. Activity will increase in the RCS due to a fuel failure. The CRS will refer to Tech Specs and determine activity exceeds TS limits. A loss of offsite power will occur with a failure of DG 1B to start. AFAS will not auto actuate. The crew will respond IAW EOP-0 and EOP-7. AFW will be manually started. Later DG 1B will be successfully restarted and aligned to 4KV Bus 14. The scenario is terminated after power is restored to Bus 14.

INSTRUCTOR SCENARIO INFORMATION

1. Reset to IC-12, loo%, MOC.

2. Perform switch check.

3. Place simulator in CONTINUE, advance charts and clear alarm display.

4. Place 11 HPSI Pump in PTL, align 12 HPSI Pump for operation.

5. PIace simulator in FREEZE.

6. Enter Triggers

a. Fail 16B FWH HLC CV-1415 open T1:

OR HS 1415 to OPEN position

b. Manually isolate CV-1415 T2:

OR HS 1415 open indicator red light ON OR HS 1415 closed indicator green light OFT OR HS 1415 to CLOSED position

7. Enter Malfunctions

a. SIT 12B leakage siOO9-04 on F2

b. LT-226 fails low CVCSO15 to LOW on F3 2006 Scenario #5 Page 2 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1 C. Turbine control valve fails closed tg004 on F4

d. Failed fuel rcs030 on F5

e. LOOP, DG 1B start failure swyd002 on F6 dg001-02 on F6 afwOO4 on F6

8. Enter Panel Overrides None

9. Enter Remote Functions / Administrative

a. Caution tag 1A DG output bkr in PTL and caution tag its start pushbutton.

b. Caution tag 11 HPSI pump in PTL. 0

- c. Caution tag 2B DG output bkr in PTL and caution tag its start pushbutton.

- d. Caution tag 60 meter wind speed indicator.

- 10. Set simulator time to real time, then place simulator in CONTINUE.

11. Give crew briefing.

a. Present plant conditions: 100%load at MOC xxxx MYDMTU.

b. Power history: At 100% power for 6 weeks.

c. Equipment out of service: DG 1A declared inoperable 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago due to discovery of burned wiring in DG 1A local control cabinet (71 hrs left on 72 hr LCO) 11 HPSI 00s due to bearing oil leak (68 hrs left on 72 hr LCO, expected back in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months )

DG 2B 00s for liner inspection.

d. Abnormal conditions: None

e. Surveillances due: None

f. Instructions for shift: Shift orders are to maintain Unit 1 at 100% power.

- 12. Allow crew 3-5 minutes to acclimate themselves with their positions.

13. Instructions for the Booth Operator.

a. Activate Trigger TI, to simulate 16B FWH high level dump failing open on lead examiners cue.

2006 Scenario #5 Page 3 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1

b. Activate F2, 12B SIT leakage on lead examiner's cue.

b. Activate F3, LT-226failure on lead examiner's cue.

C. Activate F4, turbine control valve failure on lead examiner's cue.

a. Activate F5, failed fuel on lead examiner's cue.

e. Activate F6, loss of offsite power, DG failure on lead examiner's cue.

f. Delete MF DG001-02 to allow start of DG 1B on lead examiner's cue.

g. Collect trend data on the following for examiners:

Reactor Power Turbine Generator Load ( M W )

VCT Level Pressurizer Pressure Pressurizer Level Steam Generator Levels SIT 12B Level RCS loop temperatures (Th, Tavg, Tc) 2006 Scenario #5 Page 4 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1 RESPONSES TO CREW REOUEST If a request and response is not listed, delay response until reviewed with the examiner. If one request is dependent upon completion of another, then subsequent actions should not be responded to until the appropriate time delay has been observed. Responses to routine requests, which have no effect the scenario, do not require examiner clearance.

REQUEST RESPONSE

1. TBO investigate 16B FWH HL dump valve. Acknowledge request After 2 minutes, report that dump valve is fully open and air tubing to control valve broken at diaphram assembly, possibly due to vibration.

2. TI30 isolate HLC CV-1415 by closing 1- After 2 minutes, Activate Trigger T2. Report HDV-157, HLC Downstream Isolation. that 1-HDV-157 is closed.

3. CRS informs main turbine engineer of Acknowledge report. Inform CRS that you faiIure of main turbine control valve. will generate a work order and direct maintenance to begin troubleshooting immediately.

4. CRS requests Plant Chemistry perform RCS Acknowledge request. After 5 minutes, activity sample. report results of RCS activity sample: Dose Equivalent I- 131 is 1.02 uCi/gm.

REFERENCES Developmental:

Event 1 Drawing 60705 Sh 1, Heater Vents & Drains System, Rev 34 Procedures:

Event 1 Event 2 1CO9 Alarm Manual (Windows H-08), TS 3.5.1, Safety Injection Tanks Event 3 1C07 Alarm Manual (Window F- 11)

Event 4 AOP-7E, Main Turbine Malfunction, Revision 18 (Section XIV)

Event 5 TS LCO 3.4.15, RCS Specific Activity, IC07 ALM (Window F-21)

AOP-6A, Abnormal Reactor Coolant Chemistry/Activity, Rev 11 Event 6 EOP-0, EOP-7 CRITICAL TASKS 2006 Scenario #5 Page 5 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 5 Event No.: 1 Event

Description:

16B FWH High Level Dump Fails Open 1 Time I Position Applicants Actions or Behavior Observes indications of excessive cooling (stm flow incr, Tc decr). Informs RO CRS.

Determines that 16B FWH High Level Dump 1415-CV is open. Dispatches CRO TBO to investigate.

Directs CRO to reduce turbine load to maintain Tc on program.

Directs RO to insert CEAs as needed to maintain reactor power 4 0 0 % .

Recieves report of broken air tubing at valve actuator.

Direct isolation of CV-1415 by closing 1-HDV-157, HLC Downstream Isolation.

Directs RO to withdraw CEAs to maintain Tc on program.

Contacts maintenance to repair broken air line.

2006 Scenario #5 Page 6 of 17 NUREG-1021, Revision 9

Appendix D Attach ment 1 Op-Test No.: 1 Scenario No.: 5 Event No.: 2 Event

Description:

Safety Injection Tank 12B Leakage (TS CRS)

Time Position Applicants Actions or Behavior CRO Acknowledges SIT level alarm at 1CO9. Informs CRS. Refers to ALM.

CRS Directs CRO to fill SIT IAW OI-3A, Safety Injection and Containment Spray CRO Refers to OI-3A, Section 6.3.

CRO Opens HPSl Hdr lsol MOV 646 or 647 CRO Opens Leakoff to RCDT, 1-51-661-CV CRO Starts 12 HPSI Pump.

Throttles open check valve leakage CV for 12B SIT until a 60 to 65 GPM flowrate (indicated on the Safety Injection Recirculation Flow Indicator, 1-SI-CRO 305-FI) has been established OR the valve is fully open.

128 SIT CKV LKG CV, 1-SI-648-CV After 15 minutes of flushing, will notify Plant Chemistry to draw a sample from CRO the Safety Injection miniflow sample point.

When Chemistry reports sample is drawn, shuts:

- 128 SIT CKV LKG CV, 1-SI-648-CV CRO - Leakoff to RCDT, 1-51-661-CV and leaves 12 HPSI Pump running.

After Chemistry reports header concentration of 2560 ppm, commences fill of CRO 12B SIT by opening 12B SIT Fill Valve, 1-SI-641-CV.

Closes 1-SI-648-CV and 1-SI-641-CV when SIT level is high in the control CRO band.

2006 Scenario #5 Page 7 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 5 Event No.: 3 Event

Description:

VCT Level Transmitter LT226 Fails Low ITme Position Applicant's Actions or Behavior Acknowledges VCT low level alarm. Refers to ALM.

Determines LT-226 failed low. Informs CRS.

Stops auto makeup of VCT.

Contacts maintenanceto troubleshoot and repair.

2006 Scenario #5 Page 8 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 5 Event No.: 4 Event

Description:

Turbine Control Valve Fails Closed Time Position Applicants Actions or Behavior

~~

CRO Identifies valve failure. Reports to CRS.

CRS Implements AOP-7E,Section XIV for valve malfunctions.

CRS / RO Inserts CEAs to stabilize plant and control RCS temperature.

CRS Orders CRO to adjust TBV controller setpoint.

Slowly adjusts the Auto setpoint on TURBINE BYPASS VLV CONTR, I-PIC-CRO 4056, to a pressure just above steam header pressure, without starting to open a TBV, but NOT less than 830 PSIA.

CRS 1 Informs dispatcher of reason for power reduction.

2006 Scenario #5 Page 9 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 5 Event No.: 5 Event

Description:

Failed Fuel (TS CRS)

Time Position Applicants Actions or Behavior CRO / RO Observes indications of increasing RCS activity (1CO7 RAD MON LVL HI, RR-202activity rising). Informs CRS.

CRS Requests Plant Chemistry perform RCS activity sample.

~~

CRS Implements AOP-6A, Abnormal Reactor Coolant Chemistty/Activity.

Notifies Radiation Safety Supervisor of high RCS activity.

~ ~~~

Increases letdown and charging to maximize purification flow.

Receives report from Plant Chemistry that dose equivalent 1-131 is 1.02 uCi/gm. Refers to TS 3.4.1 5. Enters TS LCO 3.4.1 5 Action A.

I 2006 Scenario #5 Page 10 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 5 Event No.: 6 Event

Description:

Loss of Offsite Power, DG 1 B Start Failure Time Position Applicants Actions or Behavior CRS Enters EOP-0.

I C$ / RO 1 Perform immediate actions.

I ~~~

CRS I Determines that a station blackout has occurred. Transitions to EOP-7.

CRS Directs activities to restore power.

CRO Shuts both MSIVs. Shuts SGBD isolations (4010, 401 1, 4012, 4013)

RO Shuts letdown isolations (515, 516 )

RO Shuts RCP bleedoff isolations (505, 506)

CRO Shuts sample valve (5464)

I 1 CRO 1 Coordinates with field for local operation of ADVs from 45 foot Aux Bldg. 1 CRO Coordinates with field to establish AFW flow control to steam generators.

CRO Controls SG levels between -24 inches and +30 inches.

CRO Shuts down condensate and feedwater.

CRO Establishes alignment for power restoration per EOP-7 Step H.

RO Shuts CC cntmt supply valve CC-3832-CV.

A I CRO I Attempts to restore power to a bus. When DG 1B started, restores Bus 14. 1 2006 Scenario #5 Page 11 of 17 NUREG-1021, Revision 9

Appendix D Attachment 1 Op-Test No.: 1 Scenario No.: 5 Event No.: 7 Event

Description:

AFAS Fails to Auto Actuate Time Position Applicants Actions or Behavior

~~~

CRO Recognizes AFAS fails to auto actuate.

CRO Manually actuates AFAS.

2006 Scenario #5 Page 12 of 17 NUREG-1021, Revision 9

SHIFT TURNOVER (Attachment 1)

I. Present Plant Conditions 100%

11. Burnup: 10,885 MWDMTU (MOC) 111. Power History At 100% power for 6 weeks IV. Equipment out of Service: 12 AFW Pump is 00s due to governor problem (has been out of service for 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months , expected back and ready to test by end of shift) 14 CAR 00s for next shift due to a failed motor bearing.

V. Abnormal Conditions: 11 ADV is wisping a small amount of steam.

VI. Surveillances Due: None VII. Instructions for Shift Following turnover, raise power to 100%. OP-3 is completed up to Step 6.1.1.2.

VIII. U2 Status and Mode 5 Major Equipment 00s: 2A DG out of service yesterday due to lube oil cooler leak.

2006 Scenario #5

U-1 Reactor Operator Shift Briefing Sheet Today Rx Power: 100 %

Boron: 897 ppm Burnup: 10885 MWD/MTU AS1 Value: 0.011 (Cecor) steady Xenon: 1.85 and building in Neutral Blend: 3 gaE BA & 35 ga2 DI Last Shot: 50 gal of DI 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago CEA Moves: GRP 5 120 1.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months ago cvcs IXs: 11for purification 1

Thumb Rules GOO^ until 11500 MWDMTU)

Tcold: -1.4 deg F @ 100 %power Dilution: 160 gal of DI @ IO0 % power Boration: 14.1 gal from the BAST 103.9 gal from the R WT CEAs: 6.75 inches Grp 5 SW Injection times: - to 2006 Scenario #5

SHIFT TURNOVER INFORMATION SHEET For Training Only DATE: Todav ON-COMING SHIFT: DAY PARAMETER UNIT 1 UNIT 2 MODE: 1 5

% POWER: 100 0 RCS TEMPERATURE: 548.0 108 RCS PRESSURE: 2250 atmos RCS BORON 897 2538 MWe NET: 860 0 GROSS RCS LEAKAGE: 0.08 N/A BULK POWER NOTIFICATION Normal I I I I TBD Shift Manager 2006 Scenario #5

SHIFT TURNOVER INFORMATION SHEET 500KV High Lines m505l [x15072 m5052 500KV Buses HBLACK NRED 13KV Supplies BP-13000-1 [xIP-13000-2 SMECO Bkr Status m252-2301 nOSH301 H OSH302 Site Self Power Feeders m252-1106 m252-2106 13KV Buses a1 1 m23 a21 E22 Voltage Regulators Auto 1102 Auto 2102 Auto 1103 Auto 2103 Auto 1101 Auto 2101 4KV Transformers mu-4000-11 [xIU-4000-21 [xiU-4000-12 (xIU-4000-22~U-mu-4000-13 4000-23 4KV Buses mll a 1 2 B13 a 1 4 a 2 1 B 2 2 m 2 3 m24 Diesel Generators 01A 01B UOC 02A n2B DOC 480V Buses B l l A N l l B m14A m14B a 2 1 A a 2 1 B m24A m24B 125VDC Battery Chargers a1 1 1x123 1x112 a24 a14 m22 m13 a21 125VDC Buses 311 la12 a22 a21 120VAC Vital Buses mll a21 m13 a23 m14 a24 m12 m22 11 HPSI 2006 Scenario #5

SHIFT TURNOVER INFORMATION SHEET

1. A member of BOPSEU shall be available and should be present during the performance of MSlV Partial Stroke testing. A Qualified Mechanic shall be available (not necessarily on location in the MSlV Room) with a spare Haskel Pump Shuttle Valve in hand to facilitate a replacementif requested by Operations and/or System Engineering..

2. Contact Ginna @ 585-771-3235,Nine Mile Point Unit One Q 315-349-2480, and Nine Mile Point Unit Two Q 315-349-2170 if we enter AOP-7M for grid disturbances so they can evaluate any potential impact at their site. Result of 7-27-04 0800 conference call. (do not delete)

3. If Reactor Power lowers to below 85%, returns to 100% and is stable for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months then perform Thermal Performance Monitoring per PE 1-083-07-OM. RPA 2004-1447 submitted to add a step to OP-3 with this requirement.

4. PZR level alarms (E-33, E-34 and Plant Computer point PRZLVLHI) are credited in UFSAR 14.25. If BOTH E-33 AND E-34 are 00s OR if PRZLVLHI is unable to cause Selected Computer point (e.g., Plant Computer 00s or E-43 OOS), then EITHER place one Charging Pump in PTL OR station a Dedicated Operator. IRE-002-114. IRE-002-117.

5. Vent Charging pumps as follows: Vent suction stabilizers daily (normal PE), Vent pump discharge on pump shutdown when 3 are operable (this includes afler weekly PE to run idle pumps), If any pump is inoperable, vent discharge on idle operable pump daily (During Vent PE).

6. Ensure 11 BABT is dumped to BAST within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months of sample because of the leaking DI valve. MO #1200501631 (P4, week 0614) for both Units.

7. If 14 Circ Pp Stator Temp alarms at 1TR-16, notify John lhnacik or Paul Gray for strategy. Alarm 1252, Use heat killer. Memo at CRS Desk.

8. During a Unit 1 Shutdown secure 11B RCP prior to 11A. If performing RCP Trip Strategy in EOPs, preferentiallystop 11A and 126 RCPs. Reference Memo at U-1 CRS desk Contact M. Lewis for additional operating strategy related to 11B RCP.

9. Computer point for COG (1752A) is not processingcorrectly (input from RMS is good). GPD can be read on 1-RR-11.

SHORT TFRM NOTFa.

1. If an Aux Boiler is run for an extended period Contact Fin to adjust packing on 13 Aux Boiler Fuel Oil Pp. The pump is isolated with Temp Note 0-05-76 to prevent an oil leak house keeping issue.

2. Do not perform PE 0-027-6-0-W Aux Boiler Low Level Quick Drain Operability until the upcoming maintenancewindow is complete Week 0542 due to the safety concern around the steam emitting from the floor drain during the performance.

3. Vertical Tendon inspection in progress for next several weeks. Temporary Phone # for U-1 Containment Roof is X-3413, U-2 X-6553.

4. RPS Channel 'C' Delta T Power Pot is at setpoint file limit, left voicemail with Skip Winter, Dave Schrumpf, and Mark Simpson.

1Of 12/05

5. New AS1 channel checks in ODAC logs, using internal AS1 in the quadrant near the LRNl detector. Computer points are on page 2 of the Operating Parameters group 102.

6. Cask is scheduledto be placed in SFP on Monday, keep this in mind if filling SFP.

7. 14 CAR is 00s due to motor bearing failure.

8. 12 AFW Pp is 00s due to a governor problem, out 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months ago expected to be back at the end of shift.

9. 2A DG is removed from service yesterday due to lube oil cooler leak. OC DG is aligned to 21 4KV Bus.

2006 Scenario #5

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