ML15125A481

On DCS Boric Acid Blender Graphic, perform the following:

Select 2X5 for VCT Level 2.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 1 Page 11 of 65 Event

Description:

VCT Level Channel I fails HIGH

. Determine which level transmitter is NOT faulted.

NVAA 5761 (Transmitter A) NOTE: NVAA 5761 (Transmitter A) is NOT faulted.

NVAA 5760 (Transmitter_B)

. Select the non-faulted level NOTE: The BOP will transmitter for VCT level input recognize that Transmitter A is (Transmitter A or Transmitter B). selected.

. Select DEV MRE INHIBIT to block the deviation input.

. Check MRE BLOCKED lit (blinking red).

NOTE: An Auto Makeup may occur once the crew removes the faulty instrument from service.

On DCS Boric Acid Blender graphic, perform the following:

. Select NV-i 37A (VCT_Level)

Ensure NV-i37A is in auto CRS

WHEN VCT Level Channel has been NOTE: The CRS may call repaired, go to Section 3.4. WCC/IAE to address the malfunction.

If so, Booth Instructor acknowledge as WCC.

NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner move to Event #2.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 2 Page 12 of 65 Event

Description:

Pzr Level Channel fails LOW Next, Pzr Level channel 3 will fail LOW. The DCS will automatically select a non-failed instrument to replace the failed instrument as the controlling channel, and no NCS inventory control upset will result. The operator will address Technical Specification LCO 3.3.1, Reactor Trip System (RTS) Instrumentation.

Booth Operator Instructions: insert XMT-NC_INCLT5I7O = 0 Indications Available:

MCB Annunciator 1AD-2 E8, DCS TROUBLE

OAC Alarm M1A0976, Ui PZR LEVEL Ill

1NCP-5170, Pzr Level Channel 3 indicates 0%

NOTE: The DCS will auto select a non-failed instrument to control the Pzr level system.

The CRS will evaluate the effect of the failure on Technical specifications.

TECHNICAL SPECIFICATION 3.3.1, REACTOR TRIP SYSTEM (RTS)

INSTRUMENTATION CRS LCO 3.3.1 The RTS instrumentation for NOTE: The CRS will each Function in Table 3.3.1-1 shall be determine that Function 9 (Pzr OPERABLE. Water Level High) of Table 3.3.1-1 is affected by this failure.

CRS APPLICABILITY: According to Table 3.3.1-1.

CRS ACTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 2 Page 13 of 65 Event

Description:

Pzr Level Channel fails LOW Time Pos. Expec ed ActionsIB iavior Comments CONDITION REQUIRED COMPLETION ACTION TI ME A. One or more A.1 Enter the Immediately NOTE: The CRS will Functions Condition with one or referenced in determine that ACTION A.1 more Table 3.3.1-1 must be entered.

required for the channels channel(s).

inoperable.

M. One channel M.1 Place 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months NOTE: The CRS will inoperable. channel in trip.

determine that ACTION M.1 must be entered.

OR M.2 Reduce 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months THERMAL POWER to

< P-7.

At the discretion of the Lead Examiner move to Event #3. !

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 14 of 65 Event

Description:

1SA48 fails OPENITDCA Pump starts inadvertently Following this, 1SA48 will fail OPEN causing the TDCA Pump to start. The crew will recognize that reactor power is rising, and that the pump should not be running, and take action to reduce Turbine load and isolate CA flow to the Steam Generators per the Crew Expectation Manual. The operator will address Technical Specification LCO 37.5, Auxiliary Feedwater (AFW) System, which will require a plant shutdown, and SLC 16.9.7, Standby Shutdown System. The operator may use API1/A1550011, Steam Leak, to diagnose the failure, and if so, use OP111A162501002, Auxiliary Feedwater System, in an attempt to stop the pump. Ultimately, the crew will enter AP111A1550014, Rapid Downpower.

Booth Operator Instructions: insert REM-SAOO48ABC = 1.0 Indications Available:

. Reactor power starts to rise

. 1SA48ABC Red status light is LIT.

. TDCA Pump Turbine Speed rising

. MCB Annunciator 1AD-5/F1 TURBINE DRIVEN CA PUMP LO SUCTION PRESSURE CONTROL ROOM EXPECTATIONS MANUAL RO/ TIG load reduction during normal ops and BOP transients (no procedure guidance and immediate need to reduce load = transient) for over power events.

Normal load changes: Auto is preferred NOTE: The RO will reduce Transient load changes: Manual is Turbine load sufficiently to preferred- immediately reduce 2OMWe and maintain Rx power < 100%.

then reduce as needed to maintain Rx power less than pre-transient condition. After the initial 20 MWe load reduction, it is preferred that the operators use multiple and diverse indications to determine how much more load should be reduced. TPBE on the OAC updates once per minute. Other indications (PR meters and Delta T meters) will indicate reactor response more quickly and will enable the operators to control the plant even more precisely. (This combines the Operator Fundamentals of Conservatism and Controlling Plant Evolutions Precisely).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 15 of 65 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time P05. Expected ActionslBehavior Comments RO! CA Operation above 10% power.

BOP IF CA Auto start at greater than 3% power NOTE: The BOP will throttle and Main Feedwater is providing flow to the CA flow from the TDCA Pump, steam generators, then CA flow should be rendering the CA Pumps throttled/isolated as soon as practical. This inoperable.

will make the affected CA pumps inoperable due to the control valve not being fully open above 10% as required by the CA Surveillance Requirements.

NOTE: The CRS may or may not address APi.

If so, the crew will ultimately go to OP/i /A/6250/002 and attempt to shutdown the TDCA Pump.

On the other hand, the operator may elect to leave the pump running, close the CA Control Valves, and investigate the failure.

APIIIAI5500IOI, STEAM LEAK CRS (Step 1) Monitor Foldout page. NOTE: Manual Reactor Trip Criteria is NOT expected to be utilized.

RD (Step 2) Reduce turbine load to maintain the NOTE: The RO will need to following: reduce load to limit reactor power.

. Excore NIs LESS THAN OR EQUAL TO 100%.

. NC Loop D/Ts LESS THAN 60°F D/T

. T-Avg - AT T-REF.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 16 of 65 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected ActionslBehavior Comments CRS (Step 3) Check containment entry IN NOTE: A Containment Entry is PROGRESS. NOT in progress.

CRS (Step 3 RNO) GO TO Step 5.

BOP (Step 5) Check Pzr pressure prior to event GREATER THAN P-li (1955 PSIG).

BOP (Step 6) Check Pzr level STABLE OR NOTE: Pzr level is expected to GOING UP. be stable, however, it may be lowering. If so, perform Step 6 RNO. Otherwise continue with Step 7.

BOP (Step 6 RNO) Perform the following as required to maintain level:

. Maintain charging flow less than 200 GPM at all times in subsequent steps.

. Ensure 1NV-238 (Ui Charging Hdr Control) OPENING.

. OPEN 1NV-241 (Ui Seal Water Inj Flow Control) while maintaining NC pump seal flow greater than 6 GPM.

. Reduce or isolate letdown.

. Start additional NV pump.

IF Pzr level going down with maximum NOTE: It is expected that the charging flow... BOP will be able to control Pzr level.

BOP (Step 7) IF AT ANY TIME while in this NOTE: This is a Continuous procedure Pzr level cannot be maintained Action. The CRS will make stable, THEN RETURN TO Step 6. both board operators aware.

Appendix D Operator Action Form ES-D2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 17 of 65 Event

Description:

1SA48 fails OPENITDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments CRS (Step 8) GO TO Step 12.

CRS (Step 12) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement that AP-1 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 13) Identify and isolate leak on Unit 1 as follows:

. (Step 1 3a) Check SM PORVs CLOSED.

RO * (Step 13.b) Check condenser dump valves CLOSED.

(Step 13.b RNO) IF steam dumps NOTE: The Steam Dumps are required to be closed.., likely to be closed.

BOP * (Step 1 3.c) Check containment conditions NORMAL:

Containment temperature

Containment pressure

Containment humidity

Containment floor and equipment sump level.

RO I * (Step 1 3.d) Check TD CA pump OFF.

BOP NOTE: The TDCA Pump is running.

(Step 13.d RNO) IF operation of TD CA Examiner NOTE: CRS may pump is causing uncontrolled cooldown direct that the TDCA Pump be AND flow from TD CA pump not stopped per the OP.

required THEN stop TD CA pump PER

.. If so, continue as scripted.

0P111A162501002 (Auxiliary Feedwater System) Enclosure 4.4 (Manual If NOT, continue with the Operation of #1 TD CA Pump) remaining steps of AP-1 on Page 20.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 18 of 65 Event

Description:

1SA48 fails OPENITDCA Pump starts inadvertently NOTE: The CRS will likely conduct a Focus Brief.

NOTE: The CRS may address Tech Specs based on plant response.

OPII 1A162501002, AUXILIARY FEEDWATER SYSTEM ENCLOSURE 4.4, MANUAL OPERATION OF #1 TO CA PUMP BOP (Step 3.1) Evaluate all outstanding R&Rs NOTE: The CRS/BOP may that may impact performance of this call WCC/IAE to address the procedure. R&Rs on the TDCA Pump.

If so, Booth Instructor acknowledge as WCC, and report none exist.

BOP (Step 3.2) Ensure that a pre-job briefing has NOTE: The CRS may call been performed that includes discussion of WCC/IAE to address the reactivity management concerns with this R&Rs on the TDCA Pump.

procedure.

BOP (Step 3.3) IF #1 TD CA Pump to be operated NOTE: The pump is NOT to locally... be operated locally.

BOP (Step 3.4) Perform the following sections, as applicable:

. Section 3.6, Stopping #1 TD CA Pump BOP (Step 3.6) Stopping #1 TD CA Pump

. IF stopping pump following EP/AP, NOTE: The CRS may decide check TURB depressed on the to take this action if the OP following: was entered from APi.

. CA Modulating Valves Reset Train A

. CA Modulating Valves Reset Train B

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 19 of 65 Event

Description:

1SA48 fails OPENITDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments IF operating #1 TD CA Pump locally... NOTE: The pump is NOT to be operated locally.

Ensure the following closed:

1CA-64AB (Ui TD CA Pump Disch to 1A S!G Control)

1CA-52AB (Ui TD CA Pump Disch to 1 B S/G Control)

1CA48AB (Ui TD CA Pump Disch to 1C SIG Control)

1CA-36AB (Ui TD CA Pump Disch to 1 D SIG Control)

Ensure RESET lit on TD CA Pump Auto Start Reset.

Place #1 TD CA Pump in STOP.

Ensure the following closed:

1SA-48ABC (1C S!G SM Supply To NOTE: The CRS will Ui TD CA Pump Turb Isol) recognize that ISA-48ABC has failed OPEN.

Because of this the CRS may dispatch an AC to locally close the upstream isolation valve 1 SA-1. The only other choice is to leave the TDCA Pump running.

If so, Floor Instructor acknowledge as AO.

Booth Instructor: Wait 3 minutes and Insert REM SA000I = 0.0; then call as AO and report that 1 SA-1 is CLOSED.

1SA-49AB (lB S/G SM Supply To Ui TD CA Pump Turb Isol)

NOTE: The CRS will likely conduct a Focus Brief.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 20 of 65 Event

Description:

1SA48 fails OPENITDCA Pump starts inadvertently APIIIAI5500IOI, STEAM LEAK Examiner NOTE: Continue here if the OP is NOT used to stop TDCA Pump.

BOP * (Step 1 3.e) Check valves on STEAM NOTE: One or more of these LINE DRAIN VALVES board (1 MC-9) valves may be cycling. The CLOSED. RNO will direct closing the valves.

CRS * (Step 13.f) Check opposite Unit (Unit 2) NOTE: CRS may ask U2 RO STEAM HEADER PRESSURE for AS Header pressure.

GREATER THAN 200 PSIG. If so, Floor Instructor report as U2 RO that U2 Steam Header pressure is zl000 psig.

(Step 1 3.g) Dispatch operator to check NOTE: The CRS may dispatch for leaks. an AO to look for leaks.

If so, Floor Instructor:

acknowledge.

Booth Instructor: Report back in 3-5 minutes that there are no leaks.

NOTE: The CRS may NOT dispatch AOs to look for leaks because it is understood that the Steam Dump valve opening was the reason that AP-1 was entered.

BOP (Step 14) Check UST level STABLE OR GOING UP.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 21 of 65 Event

Description:

1SA48 fails OPENITDCA Pump starts inadvertently Time Pos. Expected ActionslBehavior Comments CRS (Step 15) Evaluate unit shutdown as follows:

. Check unit status IN MODE 1 OR 2.

Determine if unit shutdown or load NOTE: CRS may call reduction is warranted based on the WCC/Management to address following criteria: the startup.

If so, Booth Instructor acknowledge as WCC.

. Size of leak Location of leak

. Rate of depletion of secondary inventory

. IF steam is leaking from a secondary NOTE: No Relief Valve is heater relief OR MSR relief valve, leaking.

THEN reducing turbine load....

. IF turbine trip will isolate steam leak NOTE: A Turbine Trip is NOT (such as feedwater heater leak or needed to isolate the steam MSR leak)... leak.

Check unit shutdown or load reduction NOTE: Shutdown/Load REQUIRED. Reduction will NOT be required.

CRS (Step 1 5.c RNO) Perform the following:

. Maintain present plant conditions until leak can be isolated or repaired.

. Exit this procedure.

NOTE: The CRS will likely conduct a Focus Brief.

NOTE: The CRS may address Tech Specs based on plant response.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 22 of 65 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments TECHNICAL SPECIFICATION 3.7.5, AUXILIARY FEEDWATER (AFW) SYSTEM CRS LCO 3.7.5 Three AFW trains shall be OPERABLE.

CRS APPLICABILITY: MODE 1, 2, And 3, MODE 4 when steam generator is relied upon for heat removal.

CRS ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME A. One steam A. 1 Restore 7 days NOTE: The CRS will supply to steam supply turbine driven to jjij determine that ACTION A.1 AFW pump OPERABLE must be entered.

10 days form inoperable status. discovery of failure to meet the LCO B. One AFW B.1 Restore AFW 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months NOTE: The CRS will train train to inoperable in OPERABLE recognize that ACTION B.1 MODE 1,2, status. was entered upon shift 10 days from or 3 for discovery of turnover.

reasons failure to meet other than the LCO Condition A.

C. Required C.1 Bein Action and MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months NOTE: If the CA Valves associated remain closed the CRS will Completion AND determine that ACTION C.1 Time for and C.2 must be entered.

Condition A C.2 Be in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or B not MODE 4. The CRS will note that this met. condition requires a plant OR shutdown.

Two AFW trains inoperable in MODE 1,2, or3.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 23 of 65 Event

Description:

1SA48 fails OPENITDCA Pump starts inadvertently Time Pos. Expected ActionslBehavior Comments SELECTED LICENSEE COMMITMENT 16.9.7, STANDBY SHUTDOWN SYSTEM CRS COMMITMENT The Standby Shutdown System (SSS) shall be FUNCTIONAL.

CRS APPLICABILITY: MODES 1, 2, and 3.

CRS REMEDIAL ACTIONS The SRO should ensure that security is notified 10 minutes prior to declaring the SSS inoperable. Immediately upon discovery of the SSS inoperability, Security must be notified to implement compensatory measures within 10 minutes of discovery.

CRS CONDITION REQUIRED COMPLETION NOTE: If the CA Valves ACTION TIME remain closed the CRS will A. One or more A.1 Verify the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months determine that SLC 16.9.7 required SSS FUNCTIONA ACTION A.1 and A.2 must be components LITY of fire entered.

identified in detection and Table 16.9.7- suppression 1 non systems in functional. the associated areas identified in TabIel 6.9.7-AND A.2 Restore the component to 7 days FUNCTIONAL status.

TECHNICAL SPECIFICATION 3.4.1, RCS PRESSURE, TEMPERATURE, AND FLOW DEPARTURE FROM NUCLEATE BOILING (DNB) LIMITS CRS LCO 3.4.1 RCS DNB parameters for NOTE: If NC System Pressure pressurizer pressure, RCS average drops to < 2216 psig on the temperature, and RCS total flow rate shall be failure, then TS 3.4.1 might be within the limits specified in Table 3.4.1-1. entered and exited during the transient.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 3 Page 24 of 65 Event

Description:

1SA48 fails OPENITDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments CRS APPLICABILITY: MODE 1.

CRS ACTIONS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTION A.1 A. Pressurizer A.1 Restore DNB 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months must be entered (May be pressure or parameter(s) cleared by the time that the RCS average to within limit.

temperature determination is made).

DNB parameters not within limits.

NOTE: CRS will call WCC/Management to address the CA inoperability.

When this occurs, Booth Instructor acknowledge as WCC, and as Station Management direct the crew to be in Mode 3 within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months due to the inoperability and the impending bad weather.

When the crew enters AP-4 move to Event #4.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 4 Page 25 of 65 Event

Description:

Rapid Downpower Ultimately, the crew will enter API1/A1550014, Rapid Downpower.

Booth Operator Instructions: NA Indications Available: NA AP111A15500104, RAPID DOWNPOWER RO/ (Step 1) Monitor Foldout page.

BOP Uncontrolled Cooldown (If Tavg < 551 F and lowering Not Expected)

Power Factor (Adjust power factor during NOTE: The RO will adjust load reduction to maintain power factor MVARS as needed.

between 0.9 to 1.0 lagging, using VOLTAGE ADJUST pushbutton)

Manual Rod Control Criteria ( < 0-5, Not Expected)

Turbine Shutdown (Turbine Load < 15 MWe Not Expected)

CRS (Step 2) Announce occurrence on page. NOTE: The CRS may ask U2 RO to make Plant Announcement that AP-4 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 3) Check turbine control IN AUTO.

RO (Step 4) Check MW LOOP IN SERVICE.

RO (Step 4 RNO) Depress MW IN/MW OUT pushbutton.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 4 Page 26 of 65 Event

Description:

Rapid Downpower Time Pos. Expected Actions/Behavior Comments CRS (Step 5) Check shutdown to Mode 3 DESIRED.

CRS (Step 6) Check if Shutdown Via Reactor Trip from 15% Power appropriate:

. Shutdown Via Reactor Trip from NOTE: It is normal practice to 15% PowerDESIRED shut down the reactor by driving rods, rather than tripping from 15°/b.

If the crew elects to trip the reactor from 15% power, the CRS will perform Step 7, rather than the Step 6 RNO.

. At least two CA pumps -

EU NCTI ONAL.

CRS (Step 6 RNO) Perform the following:

IF Mode 3 is timed critical AND the reactor will be shutdown by manually inserting control rods, THEN allow an additional 45 minutes to reach Mode 3 once turbine load reduction is complete.

. IF turbine will be shutdown during downpower, THEN enter target load of 15 MWE in turbine control panel.

. Observe Note prior to Step 8 and GO TO Step 8.

BOP (Step 7) Enter target load of 180 MWE in NOTE: This will ONLY be turbine control panel. performed if the reactor will be tripped from 15% power.

CRS (Step 8) Determine the required power NOTE: The CRS will reduce reduction rate (MW/mm). load at10 MWe/minute.

RO (Step 9) Check control rods IN AUTO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 4 Page 27 of 65 Event

Description:

Rapid Downpower Time Pos. Expected ActionslBehavior Comments RO (Step 9RNO) Perform the following:

. IF auto control available, THEN perform the following:

. Place control rods in auto.

. GOTOSteplO.

BOP (Step 10) Notify SOC of load reduction (red Booth Instructor: as SOC, dispatcher phone). acknowledge.

RO (Step 11) Initiate turbine load reduction to desired load at desired rate.

BOP (Step 12) Borate NC System as follows:

. Energize all backup Pzr heaters.

Check unit to be shutdown VIA NOTE: It is normal practice to REACTOR TRIP FROM 15% POWER. shut down the reactor by driving rods, rather than tripping from 15%.

CRS (Step 12b. RNO) GO TO Step 12.d.

Determine boration amount based on the following:

Power Reduction Rate (MW/mm)

Present NC System Boron Concentration (ppm)

Total Power change_(%).

Record calculated boration amount: 800 NOTE: Based on the rate of gallons. load reduction the total boration is 800 gallons.

Check auto or manual rod control AVAILABLE.

Perform boration in 4 equal additions NOTE: The CRS may assign during load reduction PER the BOP to perform this action.

OP/1/A16150/009 (Boron Concentration If so, BOP Examiner follow Control), Enclosure 4.7 (Boration Using actions of Enclosure 4.7.

1 NV-265B (Boric Acid to NV Pumps)).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 4 Page 28 of 65 Event

Description:

Rapid Downpower Time Pos. Expected ActionslBehavior Comments 0P111A161501009 BORON CONCENTRATION CONTROL ENCLOSURE 4.7 BORATION USING INV-265B (BORIC ACID TO NV PUMPS)

BOP (Step 3.1) Evaluate all outstanding R&Rs that may impact performance of this procedure.

BOP (Step 3.2) Evaluate energizing additional pressurizer heaters per 0P111A161001003 (Controlling Procedure For Unit Operation) to enhance system mixing when changing NC System boron concentration. (R.M.)

BOP (Step 3.3) Perform following sections, as applicable:

. Section 3.6, Adding Greater Than 20 Gallons of Boric Acid BOP (Step 3.6) Adding Greater Than 20 Gallons of Boric Acid

. Ensure one of the following running:

. lABATransPump OR

lB BA Trans Pump

Determine length of time 1NV-265B (Ui NV Pump Boric Acid Sup Isol) full open as follows: (R.M.)

IF using Table 4.7-1 (Time 1 NV- NOTE: The BOP will 265B Full Open With One BAT determine that 1 NV-265 must Pump Running), record time 1 NV- be open for 138 seconds.

2658 full open from table: sec.

IF using equation

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 4 Page 29 of 65 Event

Description:

Rapid Downpower Time Pos. Expected Actions/Behavior Comments

. Open 1 NV-265B (Ui NV Pump Boric NOTE: When the BOP opens Acid Sup Isol). (R.M.) 1 NV-265 the Turbine Control will fail to MANUAL.

HOLD until 1 NV-265B (Ui NV Boric Acid Sup Isol) full open time elapsed, THEN close 1 NV-265B (Ui NV Pump Boric Acid Sup Isol). (R.M.)

. IF 1 NV-265B (Ui NV Boric Acid Sup Isol) will NOT close...

. IF BA Trans Pump started in Step 3.6.1, perform the following:

. Ensure the following off:

. 1A BA Trans Pump

. lB BA Trans Pump

. Ensure one of the following selected to AUTO:

. 1A BA Trans Pump OR

. lB BA Trans Pump When the Turbine Shifts to Manual, move to Event #5.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 5 Page 30 of 65 Event

Description:

Turbine Control Unit fails to MANUAL During the downpower, a failure will occur in the Turbine Control Unit causing the unit to shift from Operator Auto to Manual control. The operator will address 1AD-1/F-4, TURBINE IN MANUAL, and control the Turbine manually during the downpower in accordance with OPI1IA!6300/OO1A, Enclosure 4.1, Turbine Generator Load Change.

Booth Operator Instructions: (Turbine Control Fails to MANUAL) Set in initial conditions. Triggered from I NV-265B open light ON.

Indications Available:

. Turbine MWe indication stabilizes

. MCB Annunciator 1AD-1/F-4, TURBINE IN MANUAL Time Pos. Expected ActionslBehavior Comments NOTE: The CRS will continue in AP-4 while the ARP/OP are addressed.

MCB ANNUNCIATOR IAD-11F4, TURBINE IN MANUAL RO Immediate Action: Ensure Turbine/Generator NOTE: The Turbine will operation stabilizes in either Load or Speed stabilize in LOAD Mode.

Modes of operation.

CRS (Step 1) Determine cause and effect, then NOTE: The CRS may call notify IAE of any malfunction. WCC/IAE to address the Turbine Control failure.

If so, Booth Instructor acknowledge as WCC.

RO (Step 2) Refer to OP/i /A/6300/00i A NOTE: The RO will continue (Turbine-Generator Load Change) for the load reduction in MANUAL.

manual operation of Turbine Generator.

CRS (Step 3) WHEN available and desired, return DEH to OPER AUTO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 5 Page 31 of 65 Event

Description:

Turbine Control Unit fails to MANUAL Time Pos. Expected Actions/Behavior Comments OP/11A163001001 A, TURBINE-GENERATOR LOAD CHANGE ENCLOSURE 4.1, TURBINE-GENERATOR LOAD CHANGE RO (Step 3.5) Changing Turbine Load RO (Step 3.5.1) IF Turbine in OPERATOR AUTO...

RO (Step 3.5.3) IF Turbine in MANUAL perform the following:

. Ensure desired change within Calculated Capability Curve.

. If turbine load will increase or decrease more than 10 MWs, notify Dispatcher of expected load change.

. IF raising load,

. IF decreasing load, depress GV LOWER.

Examiner NOTE: It may be necessary to allow the crew to stabilize the plant prior to moving to Event 6.

AP111A15500104, RAPID DOWNPOWER RO (Step 13) Check control rods MOVING IN AS REQUIRED TO MAINTAIN T-AVG AT T-REF.

RO (Step 14) Display Rod Insertion Limits on OAC by entering turn on code RIL.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 5 Page 32 of 65 Event

Description:

Turbine Control Unit fails to MANUAL Time Pos. Expected Actions/Behavior Comments CRS (Step 15) IF AT ANYTIME CONTROL ROD NOTE: This is a Continuous BANK LO LO LIMIT alarm (1AD-2, B-9) is Action. The CRS will make lit, THEN perform one of the following to both board operators aware.

comply with Tech Spec 3.1.6 (Control Bank Insertion Limits)

. Ensure alarm clears within one hour as Xenon builds in.

. Initiate boration as necessary within one hour to restore control rods above insertion limits.

CRS (Step 16) IF AT ANY TIME during this NOTE: This is a Continuous procedure C-7A is received, THEN ensure Action. The CRS will make Transient Monitor freeze is triggered. both board operators aware.

CRS (Step 17) REFER TO the following: NOTE: The CRS may ask OSM to address.

If so, Floor Instructor acknowledge as OSM.

. RPIOIAI5700I000 (Classification of Emergency)

. RPIOIAI5700IO1O (NRC Immediate Notification Requirements).

CRS (Step 18) Notify Reactor Engineer on duty of NOTE: The CRS may call load reduction. WCC/RE to address the load reduction.

If so, Booth Instructor acknowledge as WCC/RE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 5 Page 33 of 65 Event

Description:

Turbine Control Unit fails to MANUAL Time Pos. Expected ActionslBehavior Comments Examiner NOTE: The CRS may proceed past Step 18 of AP4 while waiting for the BOP to complete the first boration.

If so, wait until the BOP is complete with the first boration and then proceed to the next event.

(Step 19) Check target load LESS THAN 1000 MW.

(Step 20) Check Unit 2 available to supply aux steam as follows:

. Unit 2 Reactor power GREATER THAN NOTE: CRS will ask U2 RO 15% for status.

Floor Instructor: Report as U2 RO that Unit 2 is at 100%

power.

. Unit 2 AS-i 2 (U2 SM to AS Hdr Control NOTE: CRS will ask U2 RO Inlet Isol) OPEN for valve position.

Floor Instructor: Report as U2 RO that Unit 2 AS-12 is OPEN.

. Unit 2 AVAILABLE TO SUPPLY AS NOTE: CRS will ask U2 RO HEADER. for AS availability.

Floor Instructor: Report as U2 RO that Unit 2 is available to supply AS Header.

(Step 21) Check SM flow on all S/Gs GREATER THAN 25%.

(Step 22) WHEN all SM flows are less than 75%, THEN ensure the following valves ramp CLOSED:

. 1CF-1O4AB (1AS/G CF Control Bypass)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 5 Page 34 of 65 Event

Description:

Turbine Control Unit fails to MANUAL

. 1CF-1O5AB (lB S!G CF Control Bypass)

. iCE-i O6AB (1C SIG CF Control Bypass)

. iCE-i O7AB (1D SIG CF Control Bypass)

EXAMINER NOTE: The crew will continue in AP4 as Event 6 is ramping in.

Move to Event #6.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 6 Page 35 of 65 Event

Description:

High Vibration on I B NCP After this, a high vibration condition will develop on the 1 B NCP. The operator will respond in accordance with OAC Alarm M1D3041, lB NC PUMP VIBRATION (HALM),

and enter AP111A15500108, Malfunction of NC Pump. Ultimately, the vibration condition will rise above the Hi-Hi threshold requiring tripping of the reactor and stopping the NCP.

The operator will manually trip the reactor and enter EP/1IA/50001E-O, Reactor Trip or Safety Injection.

Booth Operator Instructions: insertMAL-NCPOO3B=4.6 (HI Vibration Alarm) insertMAL-NCP003B5.1 cd =

X05_001 El 1_I = I (Hi Vibration Alarm Ramp = 300 seconds) (HI-HI Vibration Alarm)

Indications Available:

. OAC Alarm: lB NC Pump Vibration

. MOB Annunciator 1AD-61E-11 NC Pump Hi Vibration

. lB NC Pump hi vibration on NC Pump Vibration Monitor NOTE: The performance of Step 5 of AP8 will be dependent upon the timing addressing the procedure (i.e.

Step 5 may be performed when Hi-Hi Vibration exceeds setpoint).

AP111A15500108, MALFUNCTION OF NC PUMP CASE III, EXCESSIVE VIBRATION BOP (Step 1) Check NC Pump vibration problem KNOWN TO BE VALID.

BOP (Step 2) Check affected NC pump vibration indication within operating limits:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 6 Page 36 of 65 Event

Description:

High Vibration on lB NCP

. Motor frame vibration LESS THAN 5 NOTE: The Motor Frame MILS Vibration will be rising.

. All of the following LESS THAN 20 MI LS

. Motor shaft vibration

. Pump shaft vibration

. Motor axial vibration

. Motor flywheel vibration CRS (Step 3) IF AT ANY TIME vibration exceeds NOTE: CRS will make crew operating limits, THEN GO TO Step 5 aware.

CRS (Step 4) GO TO Step 6 CRS (Step 6) Announce occurrence on the paging system.

CRS (Step 7) Check NC pumps ANY RUNNING

- NOTE: All 4 NCPs are currently running. The CRS will direct the crew to continue monitoring NCP vibrations until the Hi Hi Vibration alarm actuates. When alarm occurs, the crew will go to Step 5.

BOP (Step 5) Stop affected NC pump as follows:

. IF A or B NC pump is the affected pump, Then CLOSE associated spray valve:

1 NC-27C (1A NC Loop PZR Spray Control).

1 NC-29C (1 B NC Loop PZR Spray Control).

Check unit status IN MODE 1 OR 2.

Trip reactor

Appendix D Operator Action Form ES-D-2 Op Test No.: N14i Scenario # 1 Event # 6 Page 37 of 65 Event

Description:

High Vibration on lB NCP Time Pos. Expected Actions/Behavior Comments BOP

WHEN reactor power less than 5%,

THEN stop affected NC pump.

CRITICAL TASK (SS) Trip the Reactor prior to stopping the NCP during a high vibration condition, and trip the NCP only after Reactor power level has dropped to less than 5%.

GO TO EPI1IAJ5000IE-O (Reactor Trip or Safety Injection).

When the crew trips the reactor move to Events #7-9.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 38 of 65 Event

Description:

Premature FWlSIFaiIure of Main Turbine to TriplFailure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/IA MDCA Pump trips upon Auto Start Following the plant trip, a Feedwater Isolation Signal (FWIS) will occur prematurely, the Main Turbine will fail to trip automatically or manually, and the Main Steam Line Isolation signal will fail to automatically actuate. The operator will be required to either manually close the Turbine Governor Valves or the MSIVs. It is likely that SI will actuate due to the delayed Turbine isolation. At the same time, the TDCA Pump, if not already running, will start on low Steam Generator levels. If the TDCA Pump was not running at the start of the event, it will trip on overspeed upon startup. If the TDCA Pump was running at the start of the event, it will trip when the operator initiates flow to the Steam Generators.

Furthermore, the 1A MDCA Pump will trip on overcurrent during pump startup, and any attempts to restart the pump will be unsuccessful. Consequently, a Red Path on Heat Sink will occur shortly after SI actuation, or upon the transition to EPI1IAI5000!ES-O.1, Reactor Trip Response. The operator will transition from EPI1/AI5000IE-O to EPI1IAI5000IFR-H.i, Response to Loss of Secondary Heat Sink. The operator will eventually restore feed flow using a CF Pump in accordance with Enclosure 8 (Re establishing CF Flow) of FR-Ri. Upon restoration of feed flow to the Steam Generators, the crew will transition back to E-O. The scenario will terminate upon the operator returning to E-O, or ES-O. 1, after the secondary heat sink has been restored.

Booth Operator Instructions: The following will occur on the Rx trip:

insert MAL-ISEOO7A ACT_AUTO cd=H_XOI_094_2 EQ 1 (FWIS Train A)

insert MAL-ISEOO7B ACT_AUTO cdH_XOI_094_2 EQ 1 (FWIS Train B)

insertMAL-DEHOO3A = TRUE (Main Turbine fails to Auto Trip)

insertMAL-DEHOO3B TRUE (Main Turbine fails to Manually Trip)

insert MAL-CAOO9A TRUE cdH_Xl 0_i 02_4 EQ I, (MD CA Pump IA trips on startup)

insert MAL-CAOO5 TRIP cdH_XOI_094_2 EQ 1 delayo (TDCA Overspeed Trip occurs on Reactor Trip Breaker Open Indicating Light)

NOTE: When an AO is dispatched to check the IA MDCA Pump Breaker.

Acknowledge as AO. Wait five minutes and report back that the breaker has an overcurrent lockout relay showing, and the motor smells of burnt insulation.

NOTE: When an AO is dispatched to check the ITDCA Pump. Wait five minutes and report back that the TDCA Turbine has overspeed and will NOT reset.

Indications Available:

MCB Annunciator IAD-4!B-1 through 4, SIG A-D LEVEL DEVIATION

MCB Annunciator 1AD-4/C-1 through 4, S/G A-D FLOW MISMATCH LO CF FLOW

MCB Annunciator 1AD-4/E-1 through 4, SIG A-D LO LEVEL ALERT

RED Path on Heat Sink.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 39 of 65 Event

Description:

Premature FWISIFaiIure of Main Turbine to TriplFailure of Main Steam Line IsolationlOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start NOTE: If the TDCA Pumps is still running from a previous malfunction, the BOP may attempt to open the CA Control Valves to prevent the Red Path on Heat Sink.

However, the TDCA will overspeed shortly after event initiation.

EPIIIPJ5000IE-O, REACTOR TRIP OR SAFETY INJECTION RO/ (Step 1) Monitor Foldout page.

BOP NC Pump Trip Criteria (Not expected)

CA Suction Sources (CA storage tank (water tower) goes below 1 .5 ft Not expected)

Position Criteria for 1 NV-i 50B and 1 NV- NOTE: The BOP will monitor 151A (Ui NV Pump Recird Isol) these conditions.

. IF NV S/I flowpath aligned AND NC pressure is less than 1500 PSIG, THEN CLOSE 1NV-150B and 1NV-151A.

. IF NC pressure is greater than 2000 PSIG, THEN OPEN 1NV-150B and 1NV-i5iA.

Ruptured S/G Aux Feedwater Isolation Criteria (Not expected)

Faulted S/G Aux Feedwater Isolation Criteria (Not expected)

RO (Step 2) Check Reactor trip: Immediate Action

. All rod bottom lights LIT

. Reactor trip and bypass breakers OPEN

. hR amps - GOING DOWN.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 40 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to TriplFailure of Main Steam Line IsolationlOverspeed Trip of TDCA Pump/IA MDCA Pump trips upon Auto Start RD (Step 3) Check Turbine Trip: Immediate Action

. All throttle valves CLOSED.

RD (Step 3 RNO) Perform the following: Immediate Action

. Trip turbine.

. IF turbine will not trip, THEN perform the NOTE: Turbine will NOT trip following: manually.

. Place turbine in manual.

. CLOSE governor valves in fast action.

. IF governor valves will not close...

CRITICAL TASK:

(E-O QIFRH-1) Manually close the Main Turbine Governor Valves or establish feedwater flow into at least one Steam Generator before Wide Range Level in 3 Steam Generators reaches 24% (36%).

BOP (Step 4) Check 1 ETA and 1 ETB Immediate Action ENERGIZED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 41 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to TriplFailure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/IA MDCA Pump trips upon Auto Start NOTE: Depending on the timing of diagnosis of the failure of the Main Turbine to trip, the crew may or may not actuate SI.

The script assumes that SI has occurred, and that FR-H.i will be entered later.

If SI is NOT actuated the crew will transition to EPI1IAI5000!ES-O.1, and with the RED Path on Heat Sink active, transition to FR-H.1 instead. If so, Examiners move forward to Page 45.

ROI (Step 5) Check if S/I is actuated: Immediate Action BOP A SAFETY INJECTION ACTUATED status light (1SI-18) LIT.

Both LOCA Sequencer Actuated status lights (1 SI-i 4) LIT.

CRS (Step 6) Announce Unit 1 Safety Injection. NOTE: CRS may ask U2 RO to make Plant Announcement that Unit 1 Safety Injection has actuated.

If so, Floor Instructor acknowledge as U2 RD.

RD (Step 7) Check all Feedwater Isolation status lights (1SI-4) LIT.

BOP (Step 8) Check Phase A RESET lights DARK.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 42 of 65 Event

Description:

Premature FWlSIFailure of Main Turbine to TriplFailure of Main Steam Line IsolationlOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start BOP (Step 9) Check ESF Monitor Light Panel on energized train(s):

. Groups 1,2,5 DARK.

. Group 3LIT.

. Group 4 LIT AS REQUIRED.

. Group6LIT.

GO TO Step 10.

RO/ (Step 10) Check proper CA pump status: NOTE: Both MDCA Pumps BOP are OFF.

MDCApumpsON (Step lOa RNO) Start pumps

. N/R level in at least 3 S/Gs GREATER THAN 17%.

(Step lOb RNO) Ensure TD CA pump on.

BOP (Step 11) Check all KC pumps - ON BOP (Step 12) Check both RN pumps ON.

CRS (Step 13) Notify Unit 2 to perform the Floor Instructor: As U2 RO following: report 2A RN Pump is running.

Start 2A RN pump.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 3 of 65 Event

Description:

Premature FWlSIFailure of Main Turbine to Trip/Failure of Main Steam Line IsolationlOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start THROTTTLE Unit 2 RN flow to minimum Booth Instructor:

for existing plant conditions. insert LOA-RN087 (Start 2A RN Pump) insert LOA-RN083 8050000000 delayo ramplo (Unit 2 Train A Demand Flow)

RO (Step 14) Check all SIG pressures GREATER THAN 775 PSIG.

BOP (Step 15) Check Containment Pressure NOTE: Containment pressure HAS REMAINED LESS THAN 3 PS 1G. is normal.

BOP (Step 16) Check S/I flow:

Check NV PMPS TO COLD LEG FLOW gauge INDICATING FLOW.

Check NC pressure LESS THAN 1600 PS 1G.

BOP (Step 16.b RNO) Perform the following:

Ensure ND pump miniflow valve on running pump(s) OPEN:

1ND-68A (1A ND Pump & Hx Mini Flow Isol)

1ND-67B (lB ND Pump & Hx Mini Flow Isol).

IF valve(s) open on all running ND pumps, THEN GO TO Step 17.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 44 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to TriplFailure of Main Steam Line lsolationlOverspeed Trip of TDCA Pump/IA MDCA Pump trips upon Auto Start CRS (Step 17) Notify OSM or other SRO to NOTE: The CRS may ask perform EP/1/A15000/G-1 (Generic OSM to address.

Enclosures), Enclosure 22 (OSM Actions If so, Floor Instructor Following an S/I) within 10 minutes.

acknowledge as OSM.

(Step 18) Check CA flow:

. Total CA flow GREATER THAN 450 GPM.

(Step 18 RNO) Perform the following:

. IF N/R level in all S/Gs is less than 1 1%

(32% ACC), THEN perform the following:

. Ensure correct valve alignment.

. Start CA pumps.

IF N/R level in all S/Gs is less than 11%

(32% ACC) AND feed flow greater than 450 GPM cannot be established, THEN perform the following:

. Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).

. GO TO EP/1/A15000/FR-H.1 (Response To Loss of Secondary Heat Sink).

Examiner NOTE: It is expected that the Red Path on Heat Sink will exist by this time.

The CRS will transition to FR H.1.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 45 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line IsolationIOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start EP!1IAI5OOO/FR-H1, RESPONSE TO LOSS OF SECONDARY HEAT SINK CRS (Step 1) IF total feed flow is less than 450 NOTE: This condition is NOT GPM due to operator action... met, and the crew will remain in FR-H.1.

ROI (Step 2) Check if secondary heat sink is BOP required:

. NC pressure GREATER THAN ANY NON-FAULTED SIG PRESSURE.

. Any NC T-Hot GREATER THAN 350°F NOTE: A Secondary Heat Sink (347°F ACC). is required.

RO/ (Step 3) Monitor Foldout Page.

BOP NC System Feed and Bleed Criteria (Applies after Step 2 in the body of the procedure) (3 S/Gs goes below 24% (36% ACC) Not expected)

Cold Leg Recirc Switchover Criteria (FWST level reaches 95 inches Not expected)

CA Suction Sources (CA storage tank (water tower) goes below 1.5 ft Not expected)

BOP (Step 4) Check at least one of the following NV pumps AVAILABLE:

. lANVpump OR

. lBNVpump.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 46 of 65 Event

Description:

Premature FWISIFailure of Main Turbine to TriplFailure of Main Steam Line Isolation/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start Time Pos. Expected ActionslBehavior Comments RO (Step 5) Check if NC System feed and bleed should be initiated:

. Check W/R level in at least 3 S!Gs LESS THAN 24% (36% ACC).

ROI (Step 5.a RNO) Perform the following:

. Monitor feed and bleed initiation criteria.

. WHEN criteria satisfied, THEN GO TO NOTE: This is a Continuous Step 22. Action. The CRS will make both board operators aware.

CRS . GOTOStep6.

BOP (Step 6) Ensure S/G BB and NM valves NOTE: The CRS may assign CLOSED PER Enclosure 3 (SIG B8 and the BOP (RO) to perform this Sampling Valve Checklist). action.

If so, BOP (RO) Examiner follow actions of Enclosure 3.

Others should move ahead to Step 7 on Page 48 to continue in FR-Hi.

EPIIIAI5000/FR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK ENCLOSURE 3, S!G BB AND SAMPLING VALVE CHECKLIST BOP (Step 1) Check the following valves Examiner NOTE: Follow the (RO) CLOSED. actions associated with Enclosure 3 if BOP is assigned by CRS to perform.

. 1BB-1B (1A S/G Blowdown Cont Outside Isol Control) CLOSED

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 47 of 65 Event

Description:

Premature FWISIFaiIure of Main Turbine to TriplFailure of Main Steam Line Isolation/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start

. 1 BB-2B (1 B S/G Blowdown Cont Outside Isol Control) CLOSED

. 1 BB-3B (1 C SIG Blowdown Cont Outside Isol Control) CLOSED

. 1BB-4B (1D SIG Blowdown Cont Outside Isol Control) CLOSED

. IBB-5A (A SIG BB Cont Inside Isol) -

CLOSED

. 1BB-6A (B SIG BB Cont Inside Isol) -

CLOSED

. 1 BB-7A (C S!G BB Cont Inside Isol) -

CLOSED

. 1BB-8A (D SIG BB Cont Inside Isol)

CLOSED

. 1NM-187A (1A SIC Upper Shell Sample Cont Inside Isol) CLOSED BOP

1NM-190A (1A SIC Blowdown Sample (RO) Cont Inside Isol) CLOSED

1NM-201A (lB S/C Blowdown Sample Hdr Cont Outside Isol) CLOSED

1NM-207A (1C S/C Upper Shell Sample Cont Inside Isol) CLOSED

1NM-210A (1C S/G Blowdown Sample Cont Inside Isol) CLOSED

1NM-221A (1D S/G Blowdown Sample Hdr Cont Outside Isol) CLOSED

1NM-191B (1A S/G Blowdown Sample Hdr Cont Outside Isol) CLOSED

1 NM-i 97B (1 B S/G Upper Shell Sample Cont Inside Isol) CLOSED BOP

1NM-200B (lB SIG Blowdown Sample (RO) Cont Inside Isol) CLOSED

1 NM-2i 1 B (1 C S/C Blowdown Sample Hdr Cont Outside Isol) CLOSED

1 NM-2i 7B (1 D S/G Upper Shell Sample Cont Inside Isol) CLOSED

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 48 of 65 Event

Description:

Premature FWISIFaiIure of Main Turbine to TriplFailure of Main Steam Line Isolation/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start

. 1 NM-220B (1 D SIG Blowdown Sample Cont Inside Isol) CLOSED RESPONSE TO LOSS OF SECONDARY HEAT SINK RO (Step 7) Attempt to establish CA flow to at Examiner NOTE: Examiners (BOP) least one SIG as follows: NOT following BOP (RO) actions in Enclosure 3, continue HERE.

. Check power to both MD CA pumps NOTE: The 1A MDCA Pump is AVAILABLE. OOS, and the 1 B MDCA Pump has failed upon Auto Start.

NOTE: 1 ETA and 1 ETB are both energized.

NOTE: The CRS will dispatch an AO.

Booth Instructor:

Acknowledge as AO. Wait five minutes and report back that the breaker has an overcurrent lockout relay showing, and the motor smells of burnt insulation.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 9 of 65 Event

Description:

Premature FWlSIFailure of Main Turbine to TriplFailure of Main Steam Line IsolationlOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start RO

Ensure control room CA valves aligned NOTE: The CRS may assign (BOP) PER Enclosure 4 (CA Valve Alignment), the RO (BOP) to perform this action.

If so, RO (BOP) Examiner follow actions of Enclosure 4.

Others should move ahead to Step 7.c on Page 51 to continue in FR-Hi.

EPIIIAI5000IFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK ENCLOSURE 4, CA VALVE ALIGNMENT Examiner NOTE: Follow the actions associated with Enclosure 4 if RO (BOP) is assigned by CRS to perform.

RO (Step 1) Check the following valves OPEN (BOP)

1CA-66AC (Ui TD CA Pump Disch To 1A SIG Isol) OPEN

1CA-62A (1A CA Pump Disch To 1A 5/0 Isol) OPEN

1CA-54AC (Ui TD CA Pump Disch To lB S/G Isol) OPEN

1CA-58A (1A CA Pump Disch To 18 S/G lsol) OPEN

1CA-50B (Ui TD CA Pump Disch To IC S/G Isol) OPEN

1CA-46B (lB CA Pump Disch To 1C S/G Isol) OPEN

1CA-388 (Ui TD CA Pump Disch To 1D S/G Isol) OPEN

1 CA-42B (1 B CA Pump Disch To 1 D S/G Isol) OPEN

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 50 of 65 Event

Description:

Premature FWISIFaiIure of Main Turbine to TriplFailure of Main Steam Line IsolationlOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start RO (Step 2) Check the following valves OPEN -

(BOP)

. 1CA-64B (Ui TD CA Pump Disch To 1A SIG Control) OPEN

. 1CA-60A (1A CA Pump Disch To 1A S/G Control) OPEN

. 1CA-52AB (Ui TD CA Pump Disch To 1 B SIG Control) OPEN

. 1CA-56A (1A CA Pump Disch To lB SIG Control) OPEN

. 1CA-48AB (Ui TD CA Pump Disch To 1C SIG Control) OPEN

. 1CA-44B (lB CA Pump Disch To 1C SIG Control) OPEN

. 1CA-36AB(U1 TD CA Pump Disch To 1 D SIG Control) OPEN

. 1 CA-40B (1 B CA Pump Disch To 1 D S/G Control) OPEN RO (Step 3) Check CA Storage Tank (water (BOP) tower) level GREATER THAN 1.5 FT.

RO (Step 4) Check the following valves -

(BOP) CLOSED

. 1RN-69A(1A RN Assured Supply TO Ui CA lsol) CLOSED

. 1CA-86A (Ui TD CA Pump Suction From 1A RN lsol) CLOSED

. 1CA-15A (1A CA Pump Suction From 1A RN lsol) CLOSED

. 1RN-162B (lB RN Assured Supply To Ui CA Isol) CLOSED

. 1CA-116B (Ui TD CA Pump Suction From 1 B RN Isol) CLOSED

. 1CA-1 8B (1 B CA Pump Suction From 1 B RN Isol) CLOSED

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 51 of 65 Event

Description:

Premature FWlSIFailure of Main Turbine to Trip/Failure of Main Steam Line lsolation/Overspeed Trip of TDCA Pump/IA MDCA Pump trips upon Auto Start RO (Step 5) Check the following valves OPEN:

(BOP)

. 1 CA-i 1A (iA CA Pump Suction lsol) -

OPEN

. 1CA-7AC (Ui TD CA Pump Suction lsol)

- OPEN

. 1 CA-9B (18 CA Pump Suction Isol) -

OPEN RO (Step 6) GO TO Step 8.

(BOP)

RO (Step 8) Check 1CA-2 (Ui CA Pump Suct (BOP) From CA Storage Tank Isol) OPEN.

RO (Step 9) Check CA pump suction from UST (BOP) and CA Condensate Storage Tank (service bldg roof tank) valves CLOSED:

. 1CS-18(U1 USTToCAPumpSuctHdr Isol) CLOSED

. 1CA-4(U1 CAPumpsSuctFromSUT Isol) CLOSED

. 1CA-6 (Ui CA Pumps Suct From CA CST Isol) CLOSED.

EPIIIAI5000IFR-H.I, RESPONSE TO LOSS OF SECONDARY HEAT SINK Examiner NOTE: Examiners NOT following RO (BOP) actions in Enclosure 4, continue HERE.

8OP (Step 7.c) Start all available CA pumps.

(RO)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 52 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line IsolationlOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start BOP (Step 7.d) Check TD CA pump RUNNING. NOTE: The TDCA Pump is (RO) NOT running.

BOP (Step 7.d RNO) Perform the following as (RO) necessary:

. IF 1SA-48BC (SM From SIG C To TD CA NOTE: 1SA-488C indicates Pump lsol) is closed, THEN... OPEN.

. IF 1SA-49AB (SM From S/G B to TD CA NOTE: 1SA-49AB indicates Pump Isol) is closed, THEN... OPEN.

IF TD CA PUMP STOP VLV NOT NOTE: The CRS will dispatch OPEN alarm (1AD-5, F-3) is lit, THEN an AO.

dispatch operator to reset ISA-3 (Unit 1 Booth Instructor:

TD CA Pump Turb Stop Valve) PER Acknowledge as AO. Wait EPI1IAI5000IG-1 (Generic Enclosures), five minutes and report back Enclosure 24 (Resetting TD CA Stop that the TDCA Turbine has Valve). overspeed and will NOT reset.

IF reason for loss of steam supply to TD NOTE: The CRS will CA pump not determined,.., determine from the AO report that the TDCA Pump is unavailable.

ROt (Step 7.e) Check total flow to S/G(s) NOTE: There is no feedwater BOP GREATER THAN 450 GPM. flow.

ROt (Step 7.e RNO) Perform the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 53 of 65 Event

Description:

Premature FWlSIFaiIure of Main Turbine to Trip/Failure of Main Steam Line lsolation/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start

. IF only one MD CA pump is on,... NOTE: There are no MDCA Pumps running.

. IF any CA pump is started,... NOTE: There are no CA Pumps running.

. IF any feed flow to at least on SIG is NOTE: There is no feedwater indicated,.., flow.

IF no feed flow indicated, THEN perform the following:

. IF no CA pump can be started, NOTE: The CRS may call THEN dispatch operator and WCC/IAE to address the CA maintenance to CA pumps to try to Pump situation.

restore one CA pump to service.

If so, Booth Instructor acknowledge as WCC.

Dispatch operator to ensure CA NOTE: The CRS will dispatch valves aligned PER Enclosure 6 an AC.

(Local CA Valve Alignment).

Booth Instructor:

Acknowledge as AC.

Booth Instructor: After 5 minutes report completion.

GO TO Step 8.

RO (Step 8) Check steam dumps as follows:

Check condenser available as follows:

C-9 COND AVAILABLE FOR STEAM DUMP status light (1 SI-i 8)-

LIT

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 54 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to TriplFailure of Main Steam Line Isolation/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start

. Any MSIV OPEN. NOTE: The MSIVs may be OPEN or CLOSED. If the MSIVs are CLOSED, proceed to Step 9.

STEAM DUMP SELECT IN T-AVG MODE.

Perform the following to place steam dumps in steam pressure mode:

. Ensure STM PRESS CONTROLLER setpoint at 1090-1095 PSIG.

. Place STM PRESS CONTROLLER in manual.

. Adjust STM PRESS CONTROLLER output to equal STEAM DUMP DEMAND signal.

. Place STEAM DUMP SELECT in steam pressure mode.

. Place STM PRESS CONTROLLER in auto.

BOP (Step 9) Stop all NC pumps.

BOP (Step 10) Reset Feedwater Isolation as follows:

. Check any Condensate Booster pump ON.

Check the following alarms DARK.

. 1AD-5, G-6 (Inner Doghouse Level Hi)

. 1AD-5, H-6 (Outer Doghouse Level Hi).

Appendix D Operator Action Form ES-D-2 Op Test No.: N141 Scenario # 1 Event # 7, 8 & 9 Page 55 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to TriplFailure of Main Steam Line Isolation/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments CRS

Dispatch operator to block Feedwater NOTE: The CRS will dispatch Isolation signal PER Enclosure 7 an AC.

(Feedwater Isolation Override).

Booth Instructor:

Acknowledge as AC.

Booth Instructor: dellA MAL ISEOO7A = 2 (Upon Demand to Reset FWIS) dellA MAL-ISEOO7B = 2 (Upon Demand to Reset FWIS) insert MAL-ISEOO7A =

BLK BOTH (Upon Demand to Reset FWIS) insert MAL-ISEOO7B =

BLK_BOTH (Upon Demand to Reset FWIS)

As AO, report completion.

Booth instructor: do not delay performance of enclosure 7 BOP

Check S/I HAS BEEN ACTUATED. NOTE: SI may have been actuated.

Reset the following:

S/I

Sequencers BOP

IF AT ANY TIME a B/C signal occurs, THEN restart S/I equipment previously on.

Do not continue until Enclosure 7 (Feedwater Isolation Override) is completed.

BOP (Step 11) Check CM System in service:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 56 of 65 Event

Description:

Premature FWISIFaiIure of Main Turbine to TriplFailure of Main Steam Line IsolationlOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start

. Hotwell pump(s) - ON

. Condensate Booster pump(s) ON.

ROI (Step 12) Check CF pumps AT LEAST NOTE: Both CF Pumps are BOP ONE AVAILABLE TO START. available to start.

CRS (Step 13) Establish CF flow PER Enclosure 8 (Re-establishing CF Flow).

NOTE: The CRS will transition to Enclosure 8.

EPIIIAI5000IFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK ENCLOSURE 8, RE-ESTABLISHING CF FLOW RO (Step 1) Place the following valves in manual and CLOSE:

. SIG CF control valves

. SIG CF control bypass valves.

RO (Step 2) CLOSE the following CF control isolation valves:

. CLOSE 1CF-31 (1A SIG CF Control Inlet Isol).

. CLOSE 1CF-33 (1A S!G CF Control Outlet Isol).

. CLOSE 1CF-22 (lB SIG CF Control Inlet Isol).

. CLOSE 1CF-24 (lB SIG CF Control Outlet Isol).

. CLOSE 1CF-19 (1C SIG CF Control Inlet Isol).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 57 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to TriplFailure of Main Steam Line Isolation/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start Time Pos. Expected ActionslBehavior Comments

. CLOSE 1CF-21 (1C S/G CF Control Outlet Isol).

. CLOSE 1CF-16 (1D SIG CF Control Inlet Isol).

. CLOSE 1CF-18 (1D SIG CF Control Outlet Isol).

CRS (Note prior to Step 3) The following step must be completed even if a Feedwater Isolation signal has not occurred.

BOP (Step 3) Depress and release the Feedwater Isolation reset pushbuttons.

ROI (Step 4) Check any CF pump RESET.

BOP CRS (Step 4 RNO) GO TO Step 13.

ROl (Step 13) Depress RESET on 1A OR lB BOP CF PUMP RECIRC VALVE CLOSURE CIRCUIT and check RESET light lit.

ROl (Step 14) Reset CF pump turbine that will be BOP placed in service as follows:

Depress RESET and hold RESET 2-3 seconds after the RST light is lit on pump to be started.

Check CF pump turbine to be started RESET.

RO (Step 15) Align AS header as follows:

. CLOSE 1AS-9 (Ui C Htr Bleed To AS Hdr Isol).

Check Unit 2 as follows:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 58 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line IsolationlOverspeeci Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

. Unit 2 Reactor power GREATER NOTE: CRS will ask U2 RO to THAN 15% report power level.

If so, Floor Instructor report 100% as U2 RO.

. Unit 2 2AS-12 (U2 SM to AS Hdr NOTE: CRS will ask U2 RO to Control Inlet Isol) OPEN

- report valve position.

If so, Floor Instructor report 2AS-12 is OPEN.

CRS . Unit 2 AVAILABLE TO SUPPLY NOTE: CRS will ask U2 RO to AS HEADER. report U2 AS Availability.

If so, Floor Instructor report U2 AS is available.

ROI . Isolate Unit 1 SM to AS header as BOP follows:

. IF AT ANY TIME AS header NOTE: This is a Continuous pressure cannot be maintained Action. The CRS will make greater than 140 PSIG while both board operators aware.

performing the following step, THEN GO TO Step 15.e.

RO/ . Slowly CLOSE 1AS-12 (Ui SM To BOP AS Hdr Control Inlet Isol) while monitoring AS header pressure.

CRS (Step 15.d) GO TO Step 16.

RO/ (Step 16) Check 1 HM-95 (Ui Aux Steam NOTE: 1HM-95 is CLOSED.

BOP Supply to CF Pumps Turbine Isol) OPEN.

RO/ Step 16 RNO) Open 1HM-95.

BOP RO! (Step 17) CLOSE the following valves:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 59 of 65 Event

Description:

Premature FWISIFaiIure of Main Turbine to TriplFailure of Main Steam Line IsolationlOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start

. CLOSE 1CF-35AB (1A SIG CF Cont Outside Isol).

. CLOSE 1 CF-3OAB (1 B S/G CF Cont Outside Isol).

. CLOSE 1CF28AB (1C SIG CF Cont Outside Isol).

. CLOSE 1CF-26AB (1D S/G CF Cont Outside Isol).

ROl (Step 18) Check 1A CF pump TO BE NOTE: The CRS may elect to BOP PLACED IN SERVICE, use the lB CF Pump, rather than the 1A CF Pump. If so, similar steps are used to those associated with the starting the 1A CF Pump.

RO/ (Step 19) Place 1A CF pump in service as NOTE: The CRS may elect to BOP follows: use the 1 B CF Pump.

. Place the following in auto:

. 1A CF pump turbine low pressure governor control.

. 1A CF pump turbine high pressure governor control.

OPEN stop valves by depressing RAISE on 1A CF PUMP TURBINE HP-LP SV until MAX light is lit on the following:

. iSP-i 5 (1A CFPT Turb Hi Press NOTE: If the 1 B CF Pump is Step valve) used, 1SP-17

. 1 HM-1 57 (1A CFPT Turb Lo Press NOTE: If the 1 B CF Pump is Step valve) used, 1 HM-1 59 Adjust 1A CF pump turbine speed using NOTE: SIG pressures are control located on low pressure governor 11OO psig.

controller to establish CF HEADER PRESSURE 50-100 PSIG above SIG pressure.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 60 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to TriplFailure of Main Steam Line IsolationlOverspeed Trip of TDCA Pump/IA MDCA Pump trips upon Auto Start Time Pos. Expected ActionslBehavior Comments CRS (Step 19.d) GO TO Step 21.

RO! (Step 21) Check feed and bleed NOTE: Feed and Bleed has BOP ESTABLISHED IN BODYOF THIS NOT been established.

PROCEDURE.

RO! (Step 21 RNO) Perform the following:

BOP WHEN restoring feed flow in next steps, THEN control feed flow as required to raise S/G levels while preventing an uncontrolled NC system cooldown.

CRS . GO TO Step 25.

RO (Step 25) OPEN the following valve(s) for the S/Gs to be fed:

. iCE-i 26B (1A S/G CF To CA Nozzle Isol)

. 1 CF-i 27B (1 B S/G CF To CA Nozzle Isol)

. 1 CF-i 28B (1 C S/G CF TO CA Nozzle Isol)

. iCE-i 29B (1D S/G CF To CA Nozzle Isol).

RO (Step 26) Establish feed flow to desired S/G(s) as follows:

. THROTTLE OPEN S/G CF control bypass valve for S/G(s) to be fed.

. Monitor CF pump discharge pressure NOTE: This is a Continuous and adjust CF pump speed as needed to Action. The CRS will make maintain CF HEADER PRESSURE 50- both board operators aware.

100 PSIG above S/G pressure.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 61 of 65 Event

Description:

Premature FWISIFaiIure of Main Turbine to TriplFailure of Main Steam Line Isolation/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start Time Pos. Expected ActionslBehavior Comments

. IF AT ANY TIME SIG CF control bypass NOTE: This is a Continuous valves are throttled closed, THEN ensure Action. The CRS will make pump speed is controlled at same time to both board operators aware.

avoid a CF pump trip on high discharge pressure (1435 PSIG).

CRS (Step 27) Check Step 23 or 24 in this NOTE: Step 23 or 24 have enclosure IMPLEMENTED.

NOT been implemented.

RO (Step 27 RNO) Perform the following:

. WHEN S!G NIR level is greater than 1 1%

(32% ACC), THEN control CF flow to maintain NIR level between 11% (32%

ACC) and 50%.

CRITICAL TASK (E-O QIFRH-1) Manually close the Main Turbine Governor Valves or establish feedwater flow into at least one Steam Generator before Wide Range Level in 3 Steam Generators reaches 24% (36%).

CRS (Step 27 RNO b) RETURN TO step in effect in body of this procedure.

NOTE: The CRS will transition to Step 14 of FR-H.1.

RESPONSE TO LOSS OF SECONDARY HEAT SINK RO/ (Step 14) Check SIG levels:

. N/R level in at least on SIG GREATER THAN 11% (32% ACC).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 62 of 65 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start RO/ (Step 14 RNO a) Perform the following:

. IF feed flow to at least on SIG is indicated, THEN maintain flow to restore N/R level to between 1 1% (32% ACC) and 50%.

. IF feed flow not indicated, THEN NOTE: Feed flow is indicated.

. Check feed and bleed ESTABLISHED PER STEP 23 through 27.

CRS (Step 14 RNO b) Return to procedure and NOTE: The CRS will transition step in effect. to E-0 or ES-0.1 if the transition into FR-H.1 came from ES-0.1.

Examiner Note: If the transition is made to ES-0.1, move to Termination of the Exam.

EP!IIAI5000IE-O, REACTOR TRIP OR SAFETY INJECTION RO! (Step 19) Check NC temperatures:

. IF any NC pump on...

. IF all NC pumps off, THEN check NC T Colds STABLE OR TRENDING TO 557SF.

BOP (Step 20) Check Pzr PORV and spray valves:

. All Pzr PORVs CLOSED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 63 of 65 Event

Description:

Premature FWISIFaiIure of Main Turbine to Trip/Failure of Main Steam Line Isolatiori/Overspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start

. Normal Pzr spray valves CLOSED.

. At least one Pzr PORV isolation valve OPEN.

RO (Step 21) Check NC subcooling based on core exit T/Cs GREATER THAN 0°F.

RO (Step 22) Check if main steamlines intact:

. All SIG pressures STABLE OR GOING UP.

. All S/Gs PRESSURIZED.

RO! (Step 23) Check if SIG tubes intact:

. The following secondary EMFs NORMAL:

. 1EMF-34(L) (S/G Sample (Lo Range))

. 1EMF-24(S/GA)

. 1 EMF-25 (S/G B)

. 1EMF-26 (S/G C)

. 1 EMF-27 (5/0 D)

. S/G levels STABLE OR GOING UP IN A CONTROLLED MANNER.

BOP (Step 24) Check if NC System intact as follows:

. 1 EMF-38(L) (Containment Particulate (LR)) NORMAL

. 1 EMF-39(L) (Containment Gas (Lo Range)) NORMAL

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 1 Event # 7, 8 & 9 Page 64 of 65 Event

Description:

Premature FWISIFaiIure of Main Turbine to TriplFailure of Main Steam Line IsolationlOverspeed Trip of TDCA PumpIlA MDCA Pump trips upon Auto Start

. 1 EMF-40 (Containment Iodine) -

NORMAL

. Check containment pressure LESS THAN 1 PSIG

. Check containment sump level NORMAL.

At the discretion of the Lead Examiner terminate the exam.

UNIT I STATUS:

Power Level: 100% NCS [B] 925 ppm Pzr [B]: 925 ppm Xe: Per OAC Power History: At this power level for 178 days Core Burnup: 251 EFPDs CONTROLLING PROCEDURE: 0P111A16100103 Controlling Procedure for Unit Operation OTHER INFORMATION NEEDED TO ASSUME THE SHIFT:

The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

The following equipment is Out-Of-Service:

The 1 B MDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION B.

MCB Annunciator IAD-9, C-6, GLYCOL EXPANSION TNK HI LEVEL, has alarmed spuriously several times over the last hour, and has currently failed ON (IAE is investigating).

Crew Directions:

Maintain current plant conditions.

Work Control SRO/Offsite Communicator Jim Plant SRO Joe NLOs AVAILABLE Uniti Unit2 Aux Bldg. John Aux Bldg. Chris Turb Bldg. Bob Turb Bldg. Mike th 5

Rounds. Carol Extra(s) Bill Ed Wayne Tanya

Appendix D Scenario Outline Form ES-D-1 (Rev 071614)

Facility: McGuire Scenario No.: 4 Op Test No.: N 14-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 15% power (BOL) with the Main Turbine at 1800 RPM. The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . A power ascension is in progress and it is expected that the crew will phase the Main Generator to the Grid and raise power to 30% on this shift.

Turnover: The following equipment is Out-Of-Service: The 1A Hotwell Pump is OOS for motor replacement. 1KCP-5490, KC Pump 1A Header Pressure, failed last shift (IAE is investigating) and MCB Annunciator lAD-i 3, F-7, WE TANK LO LEVEL, has been in constant alarm over the last hour (IAE is investigating).

Event MaIf. Event Type* Event No. No. Description I X01_157 C-RO Synchronize the Main Generator to the Grid/Failure of Main C-SRO Generator Autosynch Circuit 2 NA R-RO Raise power to 1 2OMWe N-BOP N-SRO MAL 3 C-BOP 1A2 KC Pump trip KCQ1OB C(TS)-SRO 4 MAL C-BOP Loss of 1 ETA(Ground Fault)/Sequencer Failure EPOO8A CTS SRO EPOO9A -

EQBOO3A MAL 5 C-RO Turbine Low Lube Oil Pressure/Turbine Trip /Generator Breaker LTOO2E Fails to OPEN/Steam Dump failure/lA SG PORV fails partially c-SRO DEHOO1 OPEN EPOO4B SMOO2A REM SB000X MAL 6 M-RO 1 D Steam Line Break Inside Containment SMOO7D M-BOP M-SRO MAL 7 NA SI fails to actuate automatically ISEOO2A ISEOO2B (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1

Appendix D Scenario Outline Form ES-D-1 (Rev 071614)

McGuire 2014 NRC Scenario #4 The plant is at 15% power (BOL) with the Main Turbine at 1800 RPM. The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . A power ascension is in progress and it is expected that the crew will phase the Main Generator to the Grid and raise power to 30% on this shift.

The following equipment is Out-Of-Service: The 1A Hotwell Pump is OOS for motor replacement. 1KCP, KC Pump 1A Header Pressure, failed last shift (IAE is investigating) and MCB Annunciator 1AD-13, F-7, WE TANK LO LEVEL, has been in constant alarm over the last hour (IAE is investigating).

Upon shift turnover, the operator will continue with the startup starting with Step 3.33.16 of Enclosure 4.1, Power Increase, of OP/1/A16100/003, Controlling Procedure for Unit Operation, and continue with the Turbine startup starting with Step 3.13 of Enclosure 4.1, Startup with Turbine Control in Operator Auto, of OP/1/A16300/001, Turbine Generator Startup/Shutdown. The operator will place the Voltage Regulator in service and attempt to synchronize the Main Generator to the electrical grid. When the operator attempts to synchronize the Main Generator the autosynch circuit for the breaker that is attempted to be closed first, will fail. The operator will need to recognize the failure and attempt to close the other breaker in accordance with Step 3.14.12.3 of Enclosure 4.1, Startup with Turbine Control in Operator Auto, of OP/1/A/6300/001, Turbine Generator Startup/Shutdown.

Once the Main Generator is connected to the grid, the turbine will be loaded to 120 MWe, and the crew will realign the Steam Dump System from Steam Pressure Mode to Tavg Mode. It is expected that one or more boron concentration dilutions will be required.

Next, the 1A2 KC Pump will trip. The operator will enter AP/1/A/5500/21, Loss of KC or KC System Leakage. The operator will address Technical Specification LCO 3.7.6, Component Cooling Water (CCW) System, LCO 3.5.2, ECCS Operating, and LCO 3.6.6, Containment Spray System.

Shortly afterwards, the normal supply breaker to 1 ETA will trip open causing 1 ETA to de energize. The 1A EDG will not automatically start due to a sequencer failure.

Ultimately, it will be determined that a ground fault has occurred on 1 ETA, and the bus will remain de-energized. The operator will enter AP/1IA/5500/07, Loss of Electrical Power, and start the equipment on the B Train. The operator will address Technical Specification LCO 3.8.1, AC Sources Operating, LCO 3.8.4, DC Sources Operating, and LCO 3.8.9 Distribution Systems Operating. The crew may need to restore Normal Letdown in accordance with AP/1/A15500!12, Loss of Letdown, Charging or Seal Injection.

Next, a low lube oil pressure condition will develop on the Main Turbine eventually causing the Main Turbine to trip. Since the plant power is less than P-8, the Reactor will not trip. Simultaneously, the lB Main Generator Breaker will fail to trip causing a reverse powering of the Main Generator and the Steam Dump Valves will fail to open causing the SG PORV5 to open. The operator will respond in accordance with AP/1/A15500/02, Turbine Generator Trip. When the operator takes control of the Appendix D Scenario Outline Form ES-D-1 (Rev 071614)

Steam Dump System, the 1A SG PORV will fail 10% OPEN. The operator will need to manually isolate this valve in accordance with the requirements of API1!A15500101, Steam Leak.

Following this, a large steam rupture will occur inside Containment on the 1D Steamline.

SI will fail to actuate automatically. The operator will trip the Reactor and manually actuate Safety Injection, and then enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection. With 1 ETA still de-energized, only the B Train of ESF equipment will function.

Upon completion of E-0, the operator will transition to EP/1/A15000/E-2, Faulted Steam Generator Isolation. Upon completion of E-2, the operator will transition either to EP/1!A15000/E-1, Loss of Reactor or Secondary Coolant, or to EP/1/A15000/ES-1 .1, SI Termination. If the crew transitions to E-1, the scenario will terminate upon transition. If the crew transitions to ES-i .1, the scenario will terminate at Step 7.c of ES-i .1, after the crew has closed 1NI-1OB.

Critical Tasks:

E-0 D Manually actuate at least one train of SIS-actuated safeguards prior to transition out of E-0, Reactor Trip or Safety Injection.

Safety Significance: Failure to manually actuate SI under the postulated conditions constitutes mis-operation or incorrect crew performance that leads to degraded ECCS capacity. Since SI can be initiated manually from the Control Room, failure to do so demonstrates an inability by the crew to recognize a failed auto actuation of an ESF and take appropriate action, and to take action that would unnecessarily challenge a CSF. In the specified scenario, if ECCS systems are not actuated, all assumptions made in the FSAR analysis for the Steam Line break analysis are invalid.

E-2A Isolate CA flow to the Faulted Steam Generator before an unwarranted Red Path occurs on Subcriticality or NCS Integrity.

Safety Significance: Failure to isolate a Faulted SG that can be isolated causes challenges to the Critical Safety Functions that may not otherwise occur. Failure to isolate flow could result in an unwarranted Orange or Red Path condition on NC Integrity and/or Subcriticality (if cooldown is allowed to continue uncontrollably).

PROGRAM: McGuire Operations Training MODULE: Initial License Operator Training Class 30 TOPIC: NRC Simulator Exam Scenario N14-1-4

REFERENCES:

1. OP/1/A16100/003, Controlling Procedure for Unit Operation (Rev 190)

2. 0P111A16150/009, Boron Concentration Control (Rev 125)

3. OP/i /A/6300/00l, Turbine Generator Startup/Shutdown (Rev 98)

4. OP/l/A163001001A, Turbine Generator Load Change (Rev 11)

5. AP/iIAJ5500I2, Loss of KC or KC System Leakage (Rev 10)

6. Technical Specification LCO 3.7.6, Component Cooling Water (CCW) System (Amendment 184/166)

7. Technical Specification LCO 3.5.2, ECCS Operating (Amendment 184/1 66)

8. Technical Specification LCO 3.6.6, Containment Spray System (Amendment 265/245)

9. API1/A/5500/07, Loss of Electrical Power (Rev 33) iO. API1/A/5500/i2, Loss of Letdown, Charging or Seal Injection (Rev 24) ii. Technical Specification LCO 3.8.1, AC Sources Operating (Amendment 22 1/203)

12. Technical Specification LCO 3.8.4, DC Sources Operating and (Amendment 184/i 66)

13. Technical Specification LCO 3.8.9 Distribution Systems Operating (Amendment 184/i 66)

14. AP/1/A/5500/2, Turbine Generator Trip (Rev 25)

15. EP/1/A/5000/E-0, Reactor Trip or Safety Injection (Rev 33)

16. EP/1/A/5000/E-2, Faulted Steam Generator Isolation (Rev 10)

17. EP/1 /A/5000/ES-1 .2, Safety Injection Termination (Rev 26)

Validation Time: 128 minutes Author: David Lazarony, Western Technical Services, Inc.

Facility Review:

Rev. 071614 i

Scenario Event Description NRC Scenario 4 Facility: McGuire Scenario No.: 4 Op Test No.: N14-1 Examiners: Operators: (SRO)

( RO)

(BOP)

Initial Conditions: The plant is at 15% power (BOL) with the Main Turbine at 1800 RPM. The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . A power ascension is in progress and it is expected that the crew will phase the Main Generator to the Grid and raise power to 30% on this shift.

Turnover: The following equipment is Out-Of-Service: The 1A Hotwell Pump is OOS for motor replacement. 1KCP-5490, KC Pump 1A Header Pressure, failed last shift (IAE is investigating) and MOB Annunciator lAD-i 3, F-7, WE TANK LO LEVEL, has been in constant alarm over the last hour (IAE is investigating).

Event Maif. Event Type* Event No. No. Description 1 X01157 C-RO Synchronize the Main Generator to the Grid/Failure of Main Generator Autosynch Circuit C-SRO 2 NA R-RO Raise power to 1 2OMWe N-BOP N-SRO MAL 3 C-BOP 1A2 KC Pump trip KCO1OB C(TS)-SRO 4 MAL C-BOP Loss of 1 ETA(Ground Fault)/Sequencer Failure EPOO8A C(TS)-SRO EPOO9A EQBOO3A MAL C-RO Turbine Low Lube Oil Pressure/Turbine Trip /Generator Breaker LTOO2E Fails to OPEN/Steam Dump failure/lA SG PORV fails partially C-SRO DEHOO1 OPEN EPOO4B SMOO2A REM SB000X MAL 6 M-RO 1 D Steam Line Break Inside Containment SMOO7D M-BOP M-SRO MAL NA SI fails to actuate automatically ISEOO2A ISEOO2B (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario Event Description NRC Scenario 4 McGuire 2014 NRC Scenario #4 The plant is at 15% power (BOL) with the Main Turbine at 1800 RPM. The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . A power ascension is in progress and it is expected that the crew will phase the Main Generator to the Grid and raise power to 30% on this shift.

The following equipment is Out-Of-Service: The 1A Hotwell Pump is OOS for motor replacement. 1KCP, KC Pump 1A Header Pressure, failed last shift (IAE is investigating) and MCB Annunciator 1AD-13, F-7, WE TANK LO LEVEL, has been in constant alarm over the last hour (IAE is investigating).

Upon shift turnover, the operator will continue with the startup starting with Step 3.33.16 of .1, Power Increase, of OP/1/A16100/003, Controlling Procedure for Unit Operation, and continue with the Turbine startup starting with Step 3.13 of Enclosure 4.1, Startup with Turbine Control in Operator Auto, of OP/1/A16300/001, Turbine Generator Startup/Shutdown. The operator will place the Voltage Regulator in service and attempt to synchronize the Main Generator to the electrical grid. When the operator attempts to synchronize the Main Generator the autosynch circuit for the breaker that is attempted to be closed first, will fail. The operator will need to recognize the failure and attempt to close the other breaker in accordance with Step 3.14.12.3 of Enclosure 4.1, Startup with Turbine Control in Operator Auto, of OP/i /A/6300/001, Turbine Generator Startup/Shutdown.

Once the Main Generator is connected to the grid, the turbine will be loaded to 120 MWe, and the crew will realign the Steam Dump System from Steam Pressure Mode to Tavg Mode. It is expected that one or more boron concentration dilutions will be required.

Next, the 1A2 KC Pump will trip. The operator will enter AP/1/A15500/21, Loss of KC or KC System Leakage. The operator will address Technical Specification LCO 3.7.6, Component Cooling Water (CCW) System, LCO 3.5.2, ECCS Operating, and LCO 3.6.6, Containment Spray System.

Shortly afterwards, the normal supply breaker to 1 ETA will trip open causing 1 ETA to de energize. The 1A EDG will not automatically start due to a sequencer failure. Ultimately, it will be determined that a ground fault has occurred on 1 ETA, and the bus will remain de-energized.

The operator will enter AP/1/A15500/07, Loss of Electrical Power, and start the equipment on the B Train. The operator will address Technical Specification LCO 3.8.1, AC Sources Operating, LCO 3.8.4, DC Sources Operating, and LCO 3.8.9 Distribution Systems Operating. The crew may need to restore Normal Letdown in accordance with AP/i/A15500/12, Loss of Letdown, Charging or Seal Injection.

Next, a low lube oil pressure condition will develop on the Main Turbine eventually causing the Main Turbine to trip. Since the plant power is less than P-8, the Reactor will not trip.

Simultaneously, the 1 B Main Generator Breaker will fail to trip causing a reverse powering of the Main Generator and the Steam Dump Valves will fail to open causing the SG PORVs to open.

The operator will respond in accordance with AP/1/A15500/02, Turbine Generator Trip. When the operator takes control of the Steam Dump System, the 1A SG PORV will fail 10% OPEN.

The operator will need to manually isolate this valve in accordance with the requirements of AP/1/A/5500/01, Steam Leak.

Following this, a large steam rupture will occur inside Containment on the 1D Steamline. SI will fail to actuate automatically. The operator will trip the Reactor and manually actuate Safety Scenario Event Description NRC Scenario 4 Injection, and then enter EP/1IAI5000IE-O, Reactor Trip or Safety Injection. With 1 ETA still de energized, only the B Train of ESF equipment will function.

Upon completion of E-O, the operator will transition to EPI1IAJ5000/E-2, Faulted Steam Generator Isolation. Upon completion of E-2, the operator will transition either to EP/i/A/5000/E-l, Loss of Reactor or Secondary Coolant, or to EP/i!AI5000IES-l.l, SI Termination. If the crew transitions to E-i, the scenario will terminate upon transition. If the crew transitions to ES-li, the scenario will terminate at Step 7.c of ES-i.l, after the crew has closed 1NI-1OB.

Critical Tasks:

E-O D Manually actuate at least one train of SIS-actuated safeguards prior to transition out of E 0, Reactor Trip or Safety Injection.

Safety Significance: Failure to manually actuate SI under the postulated conditions constitutes mis-operation or incorrect crew performance that leads to degraded ECCS capacity. Since SI can be initiated manually from the Control Room, failure to do so demonstrates an inability by the crew to recognize a failed auto actuation of an ESF and take appropriate action, and to take action that would unnecessarily challenge a CSF. In the specified scenario, if ECCS systems are not actuated, all assumptions made in the FSAR analysis for the Steam Line break analysis are invalid.

E-2A Isolate CA flow to the Faulted Steam Generator before an unwarranted Red Path occurs on Subcriticality or NCS Integrity.

Safety Significance: Failure to isolate a Faulted SG that can be isolated causes challenges to the Critical Safety Functions that may not otherwise occur. Failure to isolate flow could result in an unwarranted Orange or Red Path condition on NC Integrity and/or Subcriticality (if cooldown is allowed to continue uncontrollably).

Scenario Event Description NRC Scenario 4 SIMULATOR OPERATOR INSTRUCTIONS Bench Mark ACTIVITY DESCRIPTION Q Sim. Setup Rod Step On Reset to Temp IC 243 T 0 Malfunctions (From IC-15):

Q =

(Originally 15).

insert LOA-CM056 = Racked Out; insert LOA CMO56A = Racked Out; (IA Hotwell Pump is OOS) insert XMT-KC_IKCPT549O = 0 (PKC-5490 is OOS) insert OVR-IADI3_F07 = ON (MCB Annunciator IADI3IF7)

From IC-243 Per Lesson Plan 2014 NRC Exam Scenario 4 insert MAL-ISEOO2A AUTO (SI Train A Fails to Actuate in AUTO) insert MAL-ISEOO2B AUTO (SI Train B Fails to Actuate in AUTO)

RUN Place TagoutlO-Stick on:

Q IA CM Pump (Tagout)

Reset all SLIMs PKC-5490 (0-stick)

MCB Annunciator IAD-13, F-7 (0-stick)

Update Status Board, NOTE: RMWST DO <1000 ppb.

Q =

Setup OAC Q Freeze.

Q Update Fresh Tech.

Spec. Log.

Q Fill out the A0s Available section of Shift Turnover Info.

Scenario Event Description NRC Scenario 4 Bench Mark ACTIVITY DESCRIPTION Q Prior to Crew RUN Briefing Q Crew Briefing

1. Assign Crew Positions based on evaluation requirements

2. Review the Shift Turnover Information with the crew.

3. Provide crew with Reactivity Plan associated with power increase.

4. Provide Enclosure 4.1 of OP!11A161001003 marked up as follows:

All Limits and Precautions (Including NOTEs) Checked

Step 2.3 initialed.

Note prior to Step 3.1 checked.

Step 3.1 Checkbox is checked.

Step 3.2 initialed.

Step 3.3 initialed.

Step 3.3.1 Checkbox is checked.

Step 3.3.2 Checkbox is checked, Step 3.33.16 is entered.

Step 3.3.3 Checkbox is checked.

Step 3.3.4 is NA.

Step 3.33.1 Checkbox is checked.

Step 3.33.2 is initialed.

Step 3.33.3 is initialed.

Step 3.33.4 Checkbox is checked.

Step 3.33.5 Checkbox is checked.

Note prior to Step 3.33.6 checked.

Step 3.33.6 is NA.

Step 3.33.7 Checkbox is checked.

Note prior to Step 3.33.8 checked.

Step 3.33.8 is initialed.

Step 3.33.9 is NA.

Step 3.33.10 Checkbox is checked.

Note prior to Step 3.33.11 checked.

Step 3.33.11 is initialed (Person Notified Time and Date are entered).

Step 3.33.12 is NA.

Step 3.33.13 is NA.

Step 3.33.14 is NA.

Step 3.33.15 initialed.

Scenario Event Description NRC Scenario 4 Bench Mark ACTIVITY DESCRIPTION

5. Provide Enclosure 4.1 of 0P111A163001001 marked up as follows:

. All Limits and Precautions (Including NOTEs) Checked.

. Step 2.1 is initialed.

. Step 3.1 Checkbox is checked.

. Step 3.2 is circled.

. Step 3.3 is initialed.

. Step 3.1 1 is initialed.

. Step 3.11.1 is NA.

. Step 3.1 1 .2 is NA.

. Step 3.1 1 .3 is initialed.

d 2

. Step 3.11.4 1 st Bullet initialed, Bullet is NA.

st 1

. Step 3.11.5 Bullet initialed, 2 Bullet initialed.

. Step 3.1 1 .6 is initialed.

. Step 3.11.7 Checkbox is checked.

. Step 3.11 .8 is initialed.

. Step 3.11.9 is initialed.

. Step 3.11.10 Checkbox is checked.

. Step 3.11.11 Checkbox is checked.

. Note prior to Step 3.12 is checked.

. Step 3.12 Checkbox is checked.

. Step 3.18.5 Checkbox is checked.

6. Provide a completed copy of Enclosure 4.4 (Piston Operated Check Valve Checklist) of OP/i /A/6300/001 (Turbine Generator Startup/Shutdown).

7. Direct the crew to Review the Control Boards taking note of present conditions, alarms.

Q T-0 Begin Familiarization Period Q At direction of Execute Lesson Plan examiner for Simulator Scenario N14-1-4.

Q At direction of Event I Synchronize the Main Generator to the examiner Grid/Failure of Main Generator Autosynch Circuit Insert XOI_157_2 = I Delete IA XOI_157_2 = 2 (Delete After Opposite Switch Position Selected)

Q When Main Event 2 Raise power to 1 2OMWe Gen synched to the Grid Q At direction of Event 3 1A2 KC Pump trip examiner Insert MAL-KCOIOB =

TRUE Scenario Event Description NRC Scenario 4 Bench Mark ACTIVITY DESCRIPTION Q At direction of Event 4 Loss of 1 ETA(Ground Fault)/Sequencer Failure examiner insert MAL-EPOO9A = AP-7 Actions TRIP insertLOA-RN087 = ON delay = 60 seconds (Start 2A RN Pump) insert MALEQBOOIA = insertLOA-RN 083 = 8000 delay = 60 seconds ON_BO_AND_LOCA (Throttle RN Flow) insertMAL-EPOO8A = insertREMRN0O4OA_1 = 0 (Close I RN-40A)

NOT ACTIVE (IETA Ground Fault)

Q At direction of Event 5 Turbine Low Lube Oil Pressure/Turbine examiner Trip/Generator Breaker Fails to OPEN/Steam Insert MALLTOO2 = Dump failure/lA SG PORV fails partially OPEN 6M, Ramp = 120 Insert:

REM-SB0003, 6, 9, 12, 15, 18, 21, 24, and 27=0 Delete:

REM-SB0003, 6, 9, 12, 15, 18, 21, 24, and 27=2 Cd=X02_1 63_3 EQI insert MAL-EPOO4B ACTIVE (lB Generator Breaker fails to Trip on Turbine Trip) delete MAL- EPOO4B cdXOl_189_1 EQI and X01_189_1 EQI X01_001E05_1 = I insertMAL-DEHOOI TRUE insertlADl_A09 = ON (Turbine Trip)

H_X02_087_4 = I InsertMAL-SMOO2A =

10 (IA SM PORV OPEN)

Q At direction of Event 6 1 D Steam Line Break Inside Containment examiner insert MAL-SMOO7D 2021250.000000 Ram p60 Scenario Event Description NRC Scenario 4 Bench Mark ACTIVITY DESCRIPTION Q Post-Rx Trip Event 7 SI fails to actuate automatically insert MAL-ISE0O2A Note: This event is set at T=0.

AUTO (SI Train A Fails to Actuate in AUTO) E-0 Actions Start 2A RN Pump and Throttle Flow insert MAL-ISEOO2B insertLOA-RN087 = ON delay = 60 seconds AUTO (SI Train B Fails (Start 2A RN Pump) to Actuate in AUTO) insertLOA-RN083 = 8000 delay = 60 seconds (Throttle RN Flow)

Stop All NF AHUs insert LOA-NFOI6 STOP (Ice Condenser AHU StartlStop)

Q Terminate the scenario upon direction of Lead Examiner Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 10 of 83 Event

Description:

Synchronize the Main Generator to the Grid/Failure of Main Generator Autosynch Circuit Upon shift turnover, the operator will continue with the startup starting with Step 3.33.16 of Enclosure 4.1, Power Increase, of 0P111A161001003, Controlling Procedure for Unit Operation, and continue with the Turbine startup starting with Step 3.13 of Enclosure 4.1, Startup with Turbine Control in Operator Auto, of OP/1/A/6300/OO1, Turbine Generator Startup/Shutdown. The operator will place the Voltage Regulator in service and attempt to synchronize the Main Generator to the electrical grid. When the operator attempts to synchronize the Main Generator the autosync circuit for the breaker that is attempted to be closed first, will fail. The operator will need to recognize the failure and attempt to close the other breaker in accordance with Step 3.14.12.3 of Enclosure 4.1, Startup with Turbine Control in Operator Auto, of OPI1IA/6300/OO1, Turbine Generator Startup/Shutdown.

Booth Operator Instructions: Insert XO1.j57_2 = I AO (Bill) is standing by at the Main Generator Voltage Regulator Panel.

Indications Available: NA Examiner NOTE: The RD should be performing activities associated with the Main Turbine Generator during this event.

0P111A161001003, CONTROLLING PROCEDURE FOR UNIT OPERATION ENCLOSURE 4.1, POWER INCREASE CRS (Step 3.33.16) Ensure TV/GV Transfer complete and Voltage Regulator placed in service per OP/1/A/6300/001 (Turbine Generator Startup/Shutdown).

CRS (Step 3.33.1 7) Close Generator MODs per OP/1/A/6300/O01 (Turbine Generator Startup/Shutdown).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 11 of 83 Event

Description:

Synchronize the Main Generator to the Grid/Failure of Main Generator Autosynch Circuit CRS (Step 3.33.18) Synchronize Generator and load Generator to 120 MWE per OP/1/A/6300/001 (Turbine Generator Startup/Shutdown).

CRS (Step 3.33.19) WHEN Main Generator Breakers closed, record the following values and notify Engineering:

. 1A Main Generator Breaker Air Compressor Pilot Valve Counter

. 1 B Main Generator Breaker Air Compressor Pilot Valve Counter

. Date/Time 1A Main Generator Breaker Closed

. Date/Time 1 B Main Generator Breaker Closed CRS (Step 3.33.20) IF performing NOTE: AVR Testing will NOT Generator/Automatic Voltage be performed.

Regulator(AVR) testing on line at 15%

RTP...

OPII/A16300/OOl, TURBINE GEN ERATOR STARTUP/SHUTDOWN ENCLOSURE 4.1, STARTUP WITH TURBINE CONTROL IN OPERATOR AUTO RO (Step 3.13) Place Voltage Regulator in service as follows:

RO (Step 3.13.1) Check Turbine speed greater than 1710 rpm.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 12 of 83 Event

Description:

Synchronize the Main Generator to the Grid/Failure of Main Generator Autosynch Circuit RD (Step 3.13.2) Locally check closed: NOTE: RD will contact AD (Bill).

Booth Operator: As AD (Bill) report Disconnects are CLOSED.

. 1 EGB-SX-Q701 (Ui Gen Voltage Reg Ch 1 Discon)

. 1 EGB-SX-Q702 (Ui Gen Voltage Reg Ch 2 Discon)

RD (Step 3.13.3) Check PMG voltage 120 140 VAC.

RD/ (Note prior to Step 3.13.4) Alarm M1L0607 (Field Ground test Circuit) will remain in CRS alarm status for up to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months following startup due to test timing circuit.

RD (Step 3.13.4) IF any Voltage Regulator NOTE: RD will contact AD Alarms are present at Local control Panel... (Bill).

Booth Operator: As AD (Bill) report There are NO alarms at local panel.

RD (Step 3.13.5) Check Voltage Regulator aligned for Control Room operation per one of the following:

. DAC Graphic MAING EN

. Ui Gen Voltage Reg Local Control Panel

. M1D2342 (Ui Gen Volt Reg in Local Cabinet Control)

RD (Step 3.13.6) Check one of the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 13 of 83 Event

Description:

Synchronize the Main Generator to the Grid/Failure of Main Generator Autosynch Circuit Time Pos. Expected Actions/Behavior Comments

. M1D2348 (Ui Gen Voltage Regulator System) is normal OR

. Trouble alarms or faults have been reviewed on the following:

. Ui Gen Voltage Reg Local Control Panel

. Ui Gen Voltage Reg Ch 1 Panel

. Ui Gen Voltage Reg Ch 2 Panel RO (Step 3.1 3.7) Ensure Voltage Regulator in MAN.

RO (Step 3.1 3.8) IF performing Generator / NOTE: Turnover has Automatic Voltage Regulator (AVR) indicated that this testing will testing,... not occur.

RO (Step 3.13.9) Ensure Excitation ON.

RO (Step prior to Step 3.1 3.10) IF Step 3.13.10 will be performed, it will be performed during startup following performance of PT111A14250/004 C (Turbine OPC and Mechanical Overspeed Trip Test).

RO (Step 3.13.10) IF Generator /AVR personnel NOTE: Turnover has are performing post Turbine OPC and indicated that this testing will Mechanical Overspeed Trip Test tuning, not occur.

RO (Step 3.13.1 1) Check Generator Voltage 22.4 23.2 KV.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # I Page 14 of 83 Event

Description:

Synchronize the Main Generator to the GridlFailure of Main Generator Autosynch Circuit RD (Note prior to Step 3.13.12) READY may take 15-90 seconds to illuminate after Excitation Breakers are closed.

RD (Step 3.13.12) Check READY lit on Voltage Regulator.

RD (Note prior to Step 3.13.13) Voltage Regulator must be in AUTO for Autosync capability.

RD (Step 13.13.13) IF auto Voltage Regulator operation is desired, perform the following:

. Ensure Voltage Regulator in AUTO.

. Notify SOC that McGuire Unit 1 NOTE: RD will contact SOC.

Generator Voltage Regulator status is Booth Operator: As SOC now in AUTO AND to update this status acknowledge.

in the EMS System. (Dispatcher Phone or 704-382-4413)

RD (Step 3.13.14) IF manual Voltage Regulator NOTE: Manual voltage operation is desired.... regulator operation is NOT desired.

RD (Step 3.1 3.15) Depress and hold SYNC on either Generator Breaker lA or Generator Breaker 1B.

RD (Step 3.13.16) Using Voltage Adjust, ensure Station Run Volts slightly higher than Generator Incoming Volts.

RD (Step 3.1 3.17) Release SYNC.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 15 of 83 Event

Description:

Synchronize the Main Generator to the Grid/Failure of Main Generator Autosynch Circuit Time Pos. Expected ActionslBehavior Comments RD (Step 3.13.18) Notify Engineering that Exciter NOTE: RD will contact field has been flashed. WCC/SE.

Booth Operator: As WCC/SE (Jim Allgood) acknowledge.

RD (Step 3.14) Close Generator MODs as follows:

RD (Step 3.14.1) Ensure Generator Frequency greater than or equal to 59.6 Hz.

RD (Step 3.14.2) IF Control Room operation of Generator Breaker MODs is desired, perform the following:

(Step 3.14.2.1) Close

. MODs for Generator Breaker 1A

. MODs for Generator Breaker 1 B RD (Step 3.14.2.2) Dispatch operator to locally NOTE: RD will dispatch AD.

check:

Booth Operator: As AD report MODs IA and lB CLOSED, no condensation in IPB Enclosures.

. MDDs closed for Generator Breaker 1A (if_closed)

. MDDs closed for Generator Breaker 1 B (if closed)

. No condensation in IPB enclosures through windows at MDDs

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 16 of 83 Event

Description:

Synchronize the Main Generator to the GridlFailure of Main Generator Autosynch Circuit Time Pos. Expected ActionslBehavior Comments RD (Step 3.14.3) IF local operation of MODs is NOTE: local operation will not required,... be required.

RD (Step 3.15) IF auto synchronization of Generator to grid is desired, perform the following:

RD (Step 3.15.1) Obtain a copy of DPI1IAI6300IOO1 A (Turbine-Generator Load Change).

RD (Step 3.1 5.2) Notify SOC (System Operation NOTE: RD will contact SOC.

Center) unit to be paralleled to the grid. (382-Booth Operator: As SOC 4413 or dispatcher phone) acknowledge.

RD (Step 3.1 5.3) Perform the following to limit Governor Valves travel:

. Depress Valve Position Limit Display

. Check Valve Position Limit Display lit.

. Depress Valve Position Limit Lower until Variable Display indicates 17%.

RD (Step 3.1 5.4) Check Voltage Regulator in AUTO.

RD (Note prior to 3.1 5.5) SYNC must be depressed for indication on Synchroscope and Station Run Voltage/Gen Incoming Voltaqe.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 17 of 83 Event

Description:

Synchronize the Main Generator to the Grid/Failure of Main Generator Autosynch Circuit Time Pos. Expected ActionslBehavior Comments RD (Step 3.15.5) Depress and hold SYNC for breaker to be closed.

RD (Step 3.15.6) Using Voltage Adjust, ensure Station Run Voltage is slightly higher than Gen Incoming Voltage.

RD (Notes prior to Step 3.15.7)

Synchroscope hand should be moving less than 1 revolution in 20 seconds. Adjusting Generator speed in 1 rpm increments with Turbine in Operator Auto will result in Synchroscope hand moving smoothly and slowly.

Synchroscope should be allowed to make at least one complete revolution.

RD (Step 3.1 5.7) Adjust Generator speed per DP/1/A16300/001 A (Turbine-Generator Load Change) until Synchroscope hand moves smoothly and slowly in FAST direction.

OP/1!A16300/OO1 A, TURBINE GENERATOR LOAD CHANGE ENCLOSURE 4.1, TURBINE GENERATOR LOAD CHANGE RD (Step 3.3) Changing Turbine Speed IF Turbine in OPERATOR AUTO, perform the following:

. Depress ACC RATE.

. Enter desired acceleration rate in NOTE: The RD will enter VARIABLE DISPLAY. 1801.

. Depress ENTER.

. Depress REFERENCE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 18 of 83 Event

Description:

Synchronize the Main Generator to the Grid/Failure of Main Generator Autosynch Circuit

. Enter desired speed in VARIABLE DISPLAY.

. Depress ENTER.

. Depress GO. NOTE: The RO will press ENTER.

. IF desired to stop acceleration, depress HOLD.

OPII /A163001001, TURBINE GENERATOR STARTUPISHUTDOWN ENCLOSURE 4.1, STARTUP WITH TURBINE CONTROL IN OPERATOR AUTO RO (Note prior to Step 3.15.8) The following step prevents any leading power factor causing voltage transient to the Generator and Grid.

RO (Step 3.15.8) IF a significant time delay (greater than 5 minutes) has occurred since performing Step 3.15.6, ensure Station Run Volts is slightly higher than Gen Incoming Voltage.

RO (Step 3.15.9) Release SYNC.

RO (Step 3.15.10) Place Gen Auto/Man Sync Select to Auto lA or Auto 1 B.

RO (Step 3.15.11) WHEN selected Generator NOTE: The selected Breaker Breaker closes will NOT Close.

Appendix D Operator Action Form ES-D-2 OpTestNo.: N14-1 Scenario# 4 Event# 1 Page 19 of 83 Event

Description:

Synchronize the Main Generator to the GridlFailure of Main Generator Autosynch Circuit Time Pos. Expected ActionslBehavior Comments RO (Step 3.15.13) IF the selected Generator Breaker did NOT close, immediately perform the following:

. Depress Auto Sync on DEH panel.

. WHEN time allows, notify Engineering of which Generator breaker(s) failed to auto sync.

. IF selected Generator Breaker fails NOTE: The RO will attempt to to close within 5 minutes, perform close the other breaker.

Steps 3.15.5 3.15.12.2 for opposite breaker.

RO (Step 3.15.5) Depress and hold SYNC for breaker to be closed.

RO (Step 3.15.6) Using Voltage Adjust, ensure Station Run Voltage is slightly higher than Gen Incoming Voltage.

RO (Step 3.15.7) Adjust Generator speed per 0P111A163001001 A (Turbine-Generator Load Change) until Synchroscope hand moves smoothly and slowly in FAST direction.

RO (Step 3.15.8) IF a significant time delay (greater than 5 minutes) has occurred since performing Step 3.15.6, ensure Station Run Volts is slightly higher than Gen Incoming Voltage.

RO (Step 3.1 5.9) Release SYNC.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 20 of 83 Event

Description:

Synchronize the Main Generator to the GridlFailure of Main Generator Autosynch Circuit RD (Step 3.15.10) Place Gen Auto/Man Sync BoothlFloor Instructor:

Select to Auto lA or Auto 1B. Observe Gen Auto/Man Sync Select position, and take following action:

DEL IA XO1_157_2 = 2 RD (Step 3.15.11) WHEN selected Generator NOTE: The selected Breaker Breaker closes immediately load the will Close.

Generator by performing the following: {PIP M-13-1808}

. Using Voltage Adjust, maintain Pwr Fact 0.90-0.95 (Lag).

. Depress MW IN.

. Depress LOAD RATE.

. Enter a Load Rate of 25 in VARIABLE DISPLAY.

. Depress ENTER.

. Depress REFERENCE.

. Enter a Load of 50 in VARIABLE D IS PLAY.

. Depress ENTER.

. Depress GO.

. Check Generator loaded by comparing actual load to Demand and Reference windows.

RD (Step 3.15.12) IF the selected Generator NOTE: The selected Breaker Breaker closes, check Generator loaded by is Closed.

comparing actual load to Demand and Reference windows (Step 3.15.14) Place Gen Auto/Man Sync Select in Man.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 1 Page 21 of 83 Event

Description:

Synchronize the Main Generator to the GridlFailure of Main Generator Autosynch Circuit RO (Step 3.15.1 5) IF neither Generator Breaker NOTE: One Breaker is Closed.

is closed,...

RO (Step 3.15.16) Place other Generator NOTE: The RO will Close the u,d 2

Breaker in service as follows: Generator Breaker.

. Depress and hold SYNC for selected breaker.

. AFTER Synchroscope for selected breaker in 12 oclock position, depress CLOSE for selected breaker until CLSD light is lit.

. Release SYNC.

RO (Step 3.15.17) Perform the following to limit Governor Valve travel:

. Depress Valve Position Limit Display and check Valve Position Limit Display lit.

. Depress Valve Position Limit Raise until Variable Display indicates 120%.

RO (Step 3.16) IF manual synchronization of NOTE: The Generator is Generator to grid is desired.... already synched to the Grid.

When the Main Generator is synched to the Grid move to Event #2.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 2 Page 22 of 83 Event

Description:

Raise power to I2OMWe Once the Main Generator is connected to the grid, the turbine will be loaded to 120 MWe, and the crew will realign the Steam Dump System from Steam Pressure Mode to Tavg Mode. It is expected that one or more boron concentration dilutions will be required.

Booth Operator Instructions: NA Indications Available: NA 0P111A161001003, CONTROLLING PROCEDURE FOR UNIT OPERATION ENCLOSURE 4.1, POWER INCREASE RO (P&L 2.3) WHEN Turbine Generator NOTE: This Precaution and paralleled to grid with Steam Dumps closed Limitation is applicable during AND CRD Select in MANUAL, maximum turbine loading.

Tava deviation from Tref is +/-2°F RO (P&L 2.6) WHEN Reactor critical, minimum NOTE: This Precaution and Tavg is 551°F. Limitation is applicable and may be challenged during steam dump operation.

OPII 1A163001001 TURBINE GENERATOR STARTUPISHUTDOWN ENCLOSURE 4.1, STARTUP WITH TURBINE CONTROL IN OPERATOR AUTO RO (Step 3.17) Load Turbine to 120 MWE per OP/i !A/6300/001 A (Turbine-Generator Load Change).

BOP (Step 3.18) Perform the following while continuing with unit startup:

. Maintain air temperature out of Exciter Air Cooler at 90-115°F by throttling 1 KR-i 78 (Exciter Air Cooler Throttle)._{PIP_00-0867}

. Place Turb Drn Vlvs Cntrl in AUTO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 2 Page 23 of 83 Event

Description:

Raise power to I20MWe

. Place in AUTO:

. 1SM-78 (A SM line Drain)

. 1SM-84 (B SM line Drain)

. 1SM-90 (C SM line Drain)

. 1SM-96 (D SM line Drain)

IF MSR Control System is in SYTSTEM MANUAL...

Check all piston operated check NOTE: Enclosure 4.4 of valves open per Enclosure 4.4 0P111A163001001 was (Piston Operated Check Valve previously completed, and Checklist), handed out during the turnover.

OPII 1A161 001003, CONTROLLING PROCEDURE FOR UNIT OPERATION ENCLOSURE 4.1, POWER INCREASE BOP (Step 3.33.21) IF PT111A142501004 C (Turbine OPC and Mechanical Overspeed Trip Test) to be performed following load increase to greater than 1 12 MWe...

(Step 3.33.22) WHEN steam dumps close, perform the following:

. IF C-7A Loss of Load lntlk Cond Dump on 1SI-18 lit...

. Place Steam Dump Select to T AVG.

. Place STM PRESS CONTROLLER to auto.

. Set STM PRESS CONTROLLER setpoint at 1092 psig (1 090-1 095).

BOP (Step 3.33.23) Perform the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 2 Page 24 of 83 Event

Description:

Raise power to I2OMWe Monitor the following while opening isp-i (Main Steam to 1A CF Pump Turb Isol) and iSP-2 (Main Steam to iB CF Pump Turb Isol): (PIP 09-6340)

MiA0723 (Ui H/P Steam to iA CFPT Press)

M1A0729 (Ui H/P Steam to lB CFPT Press)

Open the following: NOTE: The BOP may direct an AC to open these valves.

If so, FloorlBooth Instructor acknowledge as AO, and wait 3 minutes and report that they are OPEN (NOT Modeled).

iSP-i (Main Steam to iA CF Pump Turb Isol) iSP-2 (Main Steam to lB CF Pump Turb Isol)

Check the following for corresponding increase in steam pressure with iSP-i (Main Steam to iA CF Pump Turb Isol) and iSP-2 (Main Steam to 1 B CF Pump Turb Isol)_open:_(PIP_09-6340)

M1A0723 (Ui H/P Steam to iA CFPT Press)

M1A0729 (Ui H/P Steam to lB CFPT Press)

OPIIIA!61501009, BORON CONCENTRATION CONTROL ENCLOSURE 4.4, ALTERNATE DILUTE NOTE: The BOP may repeat this task as needed during the power increase.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 2 Page 25 of 83 Event

Description:

Raise power to I2OMWe BOP (Step 3.6) Determine amount of reactor makeup water needed to obtain desired boron concentration using McGuire Data Book, OAC, Reactor Group Guidance, or plant parameters (T-Ave, Steam Pressure, Xenon worth, etc.). (R.M.)

. Total Reactor Makeup Water: NOTE: Total makeup is 200 gallons.

BOP (Step 3.7) Ensure the following reset to zero:

(R.M.)

. Total Make Up Flow Counter

. Boric Acid Flow Counter BOP (Step 3.8) Set Total Make Up Flow Counter to value determined in Step 3.6. (R.M.)

BOP (Step 3.9) Select ALTERNATE DILUTE on NC Sys M!U Controller.

BOP (Step 3.10) IF desired to makeup only through 1NV-175A(Ui Boric Acid Blender To VCT Outlet Control), select CLOSED on 1 NV-i 71 A (Ui Boric Acid Blender to VCT Inlet Control).

BOP (Step 3.11) IF AT ANY TIME it is desired to NOTE: It is NOT desired to adjust reactor makeup water flow, adjust Rx adjust reactor makeup water M/U Water Flow Control setpoint to achieve flow.

desired flowrate.

BOP (Step 3.12) IF AT ANY TIME it is desired to manually adjust reactor makeup water flow, perform the following:

(Step 3.12.1) Place Rx M/U Water Flow Control in manual.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 2 Page 26 of 83 Event

Description:

Raise power to I2OMWe (Step 3.12.2) Adjust Rx M/U Water Flow Control output to control reactor makeup water flowrate.

BOP (Step 3.13) IF AT ANY TIME it is desired to lower VCT level, perform the following:

(Step 3.13.1) Monitor Letdown Pressure.

(Step 3.13.2) Select HUT on 1 NV-i 37A (Ui NOTE: The BOP may do this NC Filters OtIt to VCT 3-Way Diversion at any time to lower VCT level.

Contrl).

(Step 3.13.3) IF Letdown Pressure increases greater than 20 psig, notify CRS.

(Step 3.13.4) AFTER desired level achieved, select AUTO on 1NV-i37A (Ui NC Filters OtIt to VCT 3-Way Diversion Cntrl).

BOP (Step 3.14) IF AT ANY TIME plant parameters require termination of dilution, perform the following:

(Step 3.14.1) Place NC System Make Up to STOP. (R.M.)

(Step 3.14.2) IF 1NV-137A (Ui NC Filters OtIt to VCT 3-Way Diversion Cntrl) was placed to HUT, place to AUTO.

BOP (Step 3.15) Momentarily select START on NC System Make Up. (R.M.)

BOP (Step 3.16) Check NC System Make Up red light lit.

BOP (Step 3.17) Check 1 NV-i 75A (Ui Boric Acid Blender To VCT Outlet Control) open.

BOP (Step 3.18) Check 1NV-252A (Rx M/U Water Supply To Ui BA Blender Cntrl) open or throttled as required.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 2 Page 27 of 83 Event

Description:

Raise power to I2OMWe BOP (Step 3.19) IF 1NV-171A(U1 Boric Acid NOTE: 1NV-171A is NOT in Blender To VCT Inlet Control) in AUTO, AUTO.

check 1NV-171A(U1 Boric Acid Blender to VCT Inlet Control) open.

BOP (Step 3.20) Check Rx M/U Water Pump starts.

BOP (Step 3.21) Monitor Total Make Up Flow Counter. (R.M.)

BOP (Step 3.22) HOLD until one of the following occurs:

. Amount of reactor makeup water recorded per Step 3.6 added OR

. Reactor makeup water addition manually terminated BOP (Step 3.23) Ensure dilution terminated as follows: (R.M.)

(Step 3.23.1) IF in AUTO, ensure the following off:

. 1A Rx M/U Water Pump

. 1 B Rx M/U Water Pump BOP (Step 3.23.2) Ensure the following closed:

. 1 NV-i 75A (Ui Boric Acid Blender To VCT Outlet Control)

. 1 NV-252A (RX M/U Water Supply To Ui BA Blender Cntrl)

. 1NV-l7iA(U1 Boric Acid BlenderTo VCT Inlet Control)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 2 Page 28 of 83 Event

Description:

Raise power to I2OMWe BOP (Step 3.24) Ensure 1NV-171A(U1 Boric Acid Blender to VCT Inlet Control) in AUTO.

BOP (Step 3.25) Ensure Rx M/U Water Flow Control in AUTO. (R.M.)

BOP (Step 3.26) IF Rx M.U Water Flow Control NOTE: The Rx M.U Water adjusted per Step 3.1 1 Flow Control was NOT adjusted.

BOP (Step 3.27) Ensure 1NV-137A (Ui NC Filters OtIt to VCT 3-Way Diversion Cntrl) in AUTO.

BOP (Step 3.28) IF desired to flush blender.... NOTE: It is NOT desired to flush the blender.

BOP (Step 3.29) Select AUTO for NC Sys M/U Controller.

BOP (Step 3.30) Momentarily select START on NC System Make Up.

BOP (Step 3.31) Check NC System Make Up red light lit.

BOP (Step 3.32) Ensure the following reset to zero: (R.M.)

. Total Make Up Flow Counter

. Boric Acid Flow Counter BOP (Step 3.33) Record in Auto Log that final blender content is Rx Makeup Water.

At the discretion of the Lead Examiner move to Event #3.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 3 Page 29 of 83 Event

Description:

1A2 KC Pump trip Next, the 1A2 KC Pump will trip. The operator will enter AP/11A15500121, Loss of KC or KC System Leakage. The operator will address Technical Specification LCO 3.7.6, Component Cooling Water (CCW) System, LCO 3.5.2, ECCS - Operating, and LCO 3.6.6, Containment Spray System.

Booth Operator Instructions: insert MAL-KCOIOB Indications Available:

OAC Alarm: 1A2 KC Pump Trip

1A2 KC Pump Green Status light LIT

lA2KCPumpampsgotoO

MCB Annunciator 1AD-6, Bi through B4, A (B, C, and D) NC PUMP UPPER MTR BRG LO KC FLO, alarms (Delayed)

MCB Annunciator 1 RAD1 1 EMF 46A, LOSS OF TRN A KC SAMPLE FLO (Delayed)

MCB Annunciator 1 RAD1 1 EMF 46B, LOSS OF TRN B KC SAMPLE FLO (Delayed)

NOTE: The CRS may dispatch an NEC to check out the 1A2 KC Pump.

If so, Booth Instructor, wait 3 minutes, and then report that the 1A2 KC Pump Breaker shows a 51/50 Relay has operated, and the pump is NOT running.

NOTE: The CRS will transition toAP-21.

AP/1/A15500121, LOSS OF KC OR KC SYSTEM LEAKAGE BOP (Step 1) Check any KC pump ON. NOTE: The 1A1 KC Pump is ON, and running properly.

ROt (Step 2) Monitor Foldout page.

BOP KC header isolation criteria (KC Surge Tank level goes below 2 ft due to KC System leak Not expected)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 3 Page 30 of 83 Event

Description:

1A2 KC Pump trip NC Pump trip criteria (NC Pump motor bearing temperature reaches 195°F Not expected)

ND Pump trip and flow isolation criteria (Applies if ND aligned for RHR) (ND Pumps OFF Not expected)

KC Pump trip criteria (KC Surge Tank level goes below 0.5 ft and valid Not expected)

VCT high temperature (IF VCT HI TEMP alarm (1AD-7, D-1) is received Not expected)

BOP (Step 3) Secure any dilution in progress. NOTE: A dilution may still be in progress.

BOP (Step 4) Check ND IN RHR MODE. NOTE: ND is NOT in the RHR Mode.

CRS (Step 4 RNO) GO TO Step 7.

CRS (Step 7) Announce occurrence on paging NOTE: The CRS may ask U2 system. RO to make Plant Announcement that AP-21 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 8) Check both trains KC Surge Tank level STABLE OR GOING UP.

BOP (Step 9) Start standby KC train as follows:

. Check standby KC train AVAILABLE TO START.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 3 Page 31 of 83 Event

Description:

1A2 KC Pump trip

. Check standby KC Surge Tank Level GREATER THAN 2 FT.

. Start standby KC train PER one of the following enclosures:

. To start 1 B Train, GO TO Enclosure 5 (Startup of 1 B KC Train).

AP111A15500121, LOSS OF KC OR KC SYSTEM LEAKAGE ENCLOSURE 5, STARTUP OF lB KC TRAIN BOP (Step 1) Check 1KC-81B (lB ND Hx KC Inlet Isol) CLOSED.

BOP (Step 2) Check 1 KC-56A (1A ND Hx KC Inlet Isol) CLOSED.

BOP (Step 3) Check 1A Train KC pumps OFF. NOTE: The 1A1 KC Pump is ON, and running properly.

CRS (Step 3 RNO) GO TO Step 5.

BOP (Step 5) Check 1 B Train KC pumps OFF.

BOP (Step 6) IF voiding of 1 B KC Train is NOTE: Voiding is NOT suspected.... suspected.

BOP (Step 7) Close the following:

. 1 KC-53B (Tm B Aux Bldg Non Ess Sup Isol).

. 1 KC-2B (Tm B Aux Bldg Non Ess Ret Isol).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 3 Page 32 of 83 Event

Description:

1A2 KC Pump trip

. 1KC-228B (Tm B Rx Bldg Non Ess Sup Isol).

. 1KC-18B (Tm B Rx Bldg Non Ess Ret lsoI).

BOP (Step 8) Start 1 B RN pump.

BOP (Step 9) Ensure 1RN-187B (B KC Hx Inlet Isol) OPENS.

BOP (Step 10) Place control switch for 1 KC-54B (Train B Recirc IsoI) in the AUTO position.

BOP (Step 1 1) Ensure I KC-54B (Train B Recirc Isol) OPENS.

BOP (Step 12) Start 1B1 KC pump.

BOP (Step 13) Check 1KC-12 (1B1 KC Pump NOTE: 1KC-12 was NOT Disch Isol) LOCALLY THROTTLED IN locally throttled in Step 6.

STEP 6.

BOP (Step 13 RNO) Perform the following: NOTE: The CRS/BOP may dispatch an AO to check out the B Train KC Pumps.

If so, Booth Instructor, as AO report that both pumps are operating normally.

. StartlB2KCpump.

CRS . GOTOStep17.

BOP (Step 17) Check ND pumpsANY ON NOTE: BOTH ND Pumps are PRIOR TO ENTERING THIS PROCEDURE. and have been OFF.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event# 3 Page 33 of 83 Event

Description:

1A2 KC Pump trip CRS (Step 17 RNO) GO TO Step 20.

BOP (Step 20) Check KC leak HAS NOTE: A KC System Leak has OCCURRED. NOT occurred.

BOP (Step 20 RNO) Perform the following:

. Limit KC pump flow to 4000 GPM per operating KC pump in next step.

. OPEN the following valves:

. 1KC-18B (Tm B Rx Bldg Non Ess Ret Isol).

. 1 KC-228B (Tm B Rx Bldg Non Ess Sup Isol).

. CLOSE the following valves:

. 1 KC-230A (Tm A Rx Bldg Non Ess Sup Isol).

. 1 KC-3A (Tm A Rx Bldg Non Ess Ret Isol).

. Open the following valves:

. 1 KC-2B (Tm B Aux Bldg Non Ess Ret Isol).

. 1 KC-53B (Tm B Aux Bldg Non Ess Sup Isol).

CRS . GO TO Step 25.

BOP (Step 25) Check 1A ND pump OFF.

BOP (Step 26) Check 1 KC-56A (1A ND Hx KC Inlet Isol) CLOSED.

BOP (Step 27) Place control switch for 1 KC-51 A (Train A Recirc Isol) in the CLOSE position.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 3 Page 34 of 83 Event

Description:

1A2 KC Pump trip BOP (Step 28) Ensure 1KC-51A (Train A Recirc Isol) closes.

BOP (Step 29) Stop 1A1 and 1A2 Pumps. NOTE: The BOP will stop the 1A1 KC Pump.

BOP (Step 30) Check KC flow LESS THAN 4000 GPM PER OPERATING KC PUMP.

BOP (Step 31) Check ND pumps ANY ON NOTE: BOTH ND Pumps are PRIOR TO ENTERING THIS PROCEDURE. and have been OFF.

CRS (Step 31 RNO) GO TO Step 37.

BOP (Step 37) Check KC System leak HAS NOTE: A KC System Leak has OCCURRED. NOT occurred.

CRS (Step 37 RNO) GO TO Step 41 in body of this procedure.

AP111A15500121, LOSS OF KC OR KC SYSTEM LEAKAGE BOP (Step 41) Check any letdown path IN NOTE: Normal Letdown is in SERVICE. service.

BOP (Step 42) Check NC pump thermal barrier valves OPEN:

. 1 KC-394A (A NC Pump Therm Bar OtIt)

. 1KC-345A (C NC Pump Therm Bar OtIt)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 3 Page 35 of 83 Event

Description:

1A2 KC Pump trip

. 1 KC-364B (B NC Pump Therm Bar OtIt)

. 1KC-413B (D NC Pump Therm Bar OtIt).

BOP (Step 43) Check KC to Aux Bldg Non essential header ESTABLISHED.

BOP (Step 44) Check NM valves (on 1 MC-8) NOTE: NM Valves have NOT PREVIOUSLY CLOSED BY THIS been previously Closed by this PROCEDURE. procedure.

CRS (Step 44 RNO) GO TO Step 46.

CRS (Step 46) Check KC Surge Tank makeup HAS BEEN INITIATED.

NOTE: KC System makeup has NOT occurred.

(Step 46 RNO) GO TO Step 48. NOTE: There is NO NEED for KC System Feed and Bleed.

BOP (Step 48) Check both trains RN suction ALIGN ED TO LLI.

CRS (Step 49) RETURN TO procedure and step in effect.

NOTE: The CRS will likely address Technical Specifications.

TECHNICAL SPECIFICATION 3.7.6, COMPONENT COOLING WATER SYSTEM CRS LCO 3.7.6 Two CCW trains shall be OPERABLE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 3 Page 36 of 83 Event

Description:

1A2 KC Pump trip CRS APPLICABILITY: MODES 1, 2, 3, and 4.

CRS ACTIONS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TI ME determine that ACTION A.1 A. One CCW A.1 Restore CCW 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months must be entered.

train train to inoperable. OPERABLE status.

TECHNICAL SPECIFICATION 3.52, ECCS OPERATING -

CRS LCO 3.5.2 Two ECCS trains shall be OPERABLE.

CRS APPLICABILITY: MODES 1, 2, and 3.

CRS ACTIONS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTION A.1 A. One or more A.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months must be entered.

trains train(s) to inoperable. OPERABLE status.

AND At least 100%

of the ECCS flow equivalent to a single OPERABLE ECCS train available.

TECHNICAL SPECIFICATION 3.6.6, CONTAINMENT SPRAY SYSTYEM LCO 3.6.6 Two containment spray trains shall be OPERABLE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 3 Page 37 of 83 Event

Description:

1A2 KC Pump trip CRS APPLICABILITY: MODES 1, 2, 3, and 4.

CRS ACTIONS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTION A.1 A. One A.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months must be entered.

containment Containment spray train spray train to inoperable. OPERABLE status.

NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner move to Event #4.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 38 of 83 Event

Description:

Loss of IETA(Ground Fault)/Sequencer Failure Shortly afterwards, the normal supply breaker to 1 ETA will trip open causing 1 ETA to de energize. The 1A EDG will not automatically start due to a sequencer failure.

Ultimately, it will be determined that a ground fault has occurred on 1ETA, and the bus will remain de-energized. The operator will enter API1/A15500/07, Loss of Electrical Power, and start the equipment on the B Train. The operator will address Technical Specification LCO 3.8.1, AC Sources Operating, LCO 3.8.4, DC Sources Operating,-

and LCO 3.8.9 Distribution Systems - Operating. The crew may need to restore Normal Letdown in accordance with AP111A15500112, Loss of Letdown, Charging or Seal Injection.

Booth Operator Instructions: insert MAL-EPOO9A = TRIP insert MAL-EQBOOIA = ON_BLACKOUT Indications Available:

. 1 SI-i 4 Status Light for ETA LOSS/UNDERVOLTAGE PHASE X is LIT

. iSl-i4 Status Light for ETA LOSS/UNDERVOLTAGE PHASE Y is LIT

. iSl-i4 Status Light for ETA LOSS/UNDERVOLTAGE PHASE Z is LIT

. MOB Annunciator lAD-i i/A-i U ETA 4.16KV TROUBLE

. MOB Annunciator lAD-i i/A-2U ETA 600V LO TROUBLE

. MOB Annunciator lAD-i l/A-3U ETA 600V/l 20V TROUBLE

. 1 ETA Normal Supply Breaker Green status light is LIT Time Pos. Expected ActionslBehavior Comments AP111A15500107, LOSS OF ELECTRICAL POWER CASE II, LOSS OF NORMAL POWER TO EITHER IETA OR IETB BOP (Step 1) Check affected bus(s) - Immediate Action ENERGIZED AND SEQUENCER APPLYING LOADS.

BOP (Step 1 RNO) Perform the following: Immediate Action

. IF both busses deenergized... NOTE: I ETB is energized.

. Ensure the following pumps running on energized bus:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 39 of 83 Event

Description:

Loss of IETA(Ground Fault)/Sequencer Failure Time Pos. Expected ActionslBehavior Comments

. NV pump NOTE: The BOP will start the lB NV Pump.

. KC pumps NOTE: The 1B1 and 1B2 KC Pumps are running.

. RN pump. NOTE: The BOP will start the lB RN Pump.

BOP (Step 2) Ensure NC pump thermal barrier Immediate Action isolation valves on energized train(s)

OPEN.

RO (Step 3) Maintain reactor power less than or equal to 100%.

BOP (Step 4) Check 1 ETA and 1 ETB BOTH NOTE: ONLY 1 ETB is ENERGIZED. energized.

CRS (Step 4 RNO) GO TO Step 6.

BOP (Step 6) Check S/I HAS OCCURRED NOTE: SI has NOT occurred.

DURING THIS EVENT.

BOP (Step 6 RNO) Perform the following:

. IF both NV pumps off,... NOTE: The lB NV is running.

IF any pump was manually started per NOTE: The 1 B NV Pump was APO7 Immediate Actions, THEN GO TO manually started.

Step 8.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 40 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos. Expected ActionslBehavior Comments CRS (Step 8) Check D/Gs OFF. NOTE: The CRS may dispatch an AD to check out the Diesel and the Sequencer.

If so, FloorlBooth Instructor acknowledge as AD. Report back within 5 minutes:

. IA DIG is NOT running

. A Lockout Relay has operated on IETA BOP (Step 9) Check ND System status:

. ND System IN RHR MODE AT TIME NOTE: ND is NOT in RHR OF BID. Mode.

CRS (Step 9a RNO) GO TO Step 10.

BOP (Step 10) Check any RN pump RUNNING. NOTE: The lB RN Pump is running.

BOP (Step 1 1) Align KC as follows:

Place recirc valve on operating train in AUTO:

. 1KC-54B (Train B Recirc Isol).

. Ensure KC flow remains less than 4000 GPM per operating KC pump while performing next step.

Ensure the following valves on energized train are OPEN:

B Train:

OPEN 1 KC-1 8B (Tm B Rx Bldg Non Ess Ret Isol)

OPEN 1KC-228B (Tm B Rx Bldg Non Ess Sup_Isol)

Appendix D Operator Action Form ES-D-2 OpTestNo.: N14-1 Scenario# 4 Event# 4 Page 41 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos. Expected Actions/Behavior Comments

. OPEN 1KC-364B (B NC Pump Therm Bar OtIt)

. OPEN 1KC-413B (D NC Pump Therm Bar OtIt).

BOP (Step 12) Check any charging pump RUNNING.

BOP (Step 13) Align RN as follows:

. Check 1A RN pump RUNNING. NOTE: The 1A RN is OFF.

BOP (Step 1 3a RNO) Align 1 B RN as follows:

. Ensure 1RN-187B (B KC Hx Inlet Isol) is OPEN.

. THROTTLE IRN-190B (RN To B KC Hx Control) for desired KC cooling, while maintaining the following:

. lB RN pump flowLESS THAN 14,000 GPM.

. 1 B RN pump discharge pressure GREATER THAN 50 PS 1G.

BOP . Start all available RV pumps. NOTE: Two additional RV pumps will be started.

CRS . GOTOStepl4.

CRS (Step 14) Notify Unit 2 RO to start 2A RN Floor Instructor: As U2 RO pump. report 2A RN Pump is running.

Booth Instructor:

insertLOA-RN087 = ON delay 60 seconds (Start 2A RN Pump)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 42 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos. Expected ActionslBehavior Comments BOP (Step 15) Check VCT makeup control system.

. Ensure boric acid transfer pump on energized train running.

. Ensure NC System makeup controller in auto.

. Place NC System makeup switch to start.

BOP (Step 16) Check B/C ON 1 ETA.

BOP (Step 17) Check B and D Pzr heater group Examiner NOTE: IF NV Pump supply breakers on vertical board not started on B Train within CLOSED. 20 seconds of BC, loss of letdown/ Pzr heaters off will occur, and require RNO actions.

If NV Pump started within 20 seconds, move forward to Step 18.

BOP (Step 17 RNO) Perform the following:

. IF Pzr level is less than 17% NOTE: Pzr level is most likely

> 17%.

. IF S/I has occurred NOTE: SI has NOT occurred.

. Place the following Pzr heater groups in manual:

. B

. D

. Close the following Pzr heater group supply breakers:

. B

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 43 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos. Expected Actions/Behavior Comments

. D

. Close C Pzr heater group supply breaker.

. Return the following Pzr heater groups to auto:

. B

. D BOP (Step 18) Perform one of the following to isolate RN train crosstie:

. Dispatch operator to close 1 RN-40A NOTE: The CRS will dispatch (Train A To Non Ess Hdr Isol) (aux bldg, an AC to close 1 RN-40A.

716+7, GG-55 beside Unit 1 side Booth Instructor:

stairway to 695 elevation), acknowledge as appropriate.

insertREM-RNOO4OA_1 = 0, delay 5 mm (Close IRN 40A)

After closing valve, Booth Instructor report action taken to Control Room.

OR Caution: Closing 1 RN-41 B (Train B To Non Ess Hdr Isol) will isolate 1 B Train RN flow to NC pumps and other non essential loads.

. Evaluate CLOSING 1RN-41B (Train B To Non Ess Hdr Isol).

CRS (Step 19) WHEN RN train crosstie is NOTE: This is a Continuous isolated, THEN 1RN-190B (RN To B KC Hx Action. The CRS will make Control) may be throttled further OPEN, both board operators aware.

while maintaining the following:

. 1 B RN pump flow LESS THAN 14,000 GPM.

. 1 B RN pump discharge pressure GREATER THAN 50 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 44 of 83 Event

Description:

Loss of IETA(Ground Fault)/Sequencer Failure Time Pos. Expected Actions/Behavior Comments CRS (Step 20) Dispatch operator to close the NOTE: CRS will dispatch an following valves: NEC to close 1 KC-230A and 1 KC-3A.

Booth Instructor:

acknowledge as appropriate.

insert REM-KC0003A = 0, delay = 5 mm (Close IKC 3A) insert REM-KCO23OA = 0, delay = 5 mm (Close IKC 230A)

After closing valves, Booth Instructor report action taken to Control Room.

BOP . 1 KC-230A (Tm A Rx Bldg Non Ess Sup Isol) (aux bldg, 750+12, JJ-55, above north end of KC HX 1A)

BOP . 1 KC-3A (Tm A Rx Bldg Non Ess Ret Isol) (aux bldg, 733+8, HH-55, north of column HH-55).

BOP (Step 21) Check 1A ND Train WAS IN RHR MODE.

CRS (Step 21 RNO) GO TO Step 36.

BOP (Step 36) Check normal letdown IN SERVICE.

CRS (Step 36 RNO) IF desired to establish normal NOTE: Normal Letdown may or excess letdown, THEN have any available have isolated. If so, the CRS operator establish letdown PER may direct BOP to restore AP/1/A15500/12 (LOSS OF LETDOWN, Letdown per AP12. If so, CHARGING OR SEAL INJECTION) while follow actions on Page 50, continuing with this procedure. while crew continues in AP7.

BOP (Step 37) Check any Unit 1 6900V bus -

ENERGIZED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 45 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos. Expected ActionslBehavior Comments CRS (Step 38) GO TO Step 45.

BOP (Step 45) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement that the Unit 1 has entered AP 7.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 46) Check S/I HAS OCCURRED DURING THIS EVENT.

CRS (Step 46 RNO) Perform the following:

Initiate EPI1IAI5000IG-1 (Generic NOTE: The CRS may ask U2 Enclosures), Enclosure 13 (VC And VA BOP to perform Enclosure 13.

System Operation) within 30 minutes of If so, Floor Instructor BlO. acknowledge as U2 BOP, and perform.

CRS (Step 47) Have available licensed operator NOTE: The CRS may ask initiate Enclosure 7 (DC Bus Alignment) WCCS for an available within 30 minutes of BlO. Licensed Operator to perform Enclosure 7.

If so, Floor Instructor acknowledge as WCCS, and perform.

BOP (Step 48) Check DIG on bus that was NOTE: The 1A DIG is OFF.

blacked out ON.

BOP (Step 48 RNO) Perform the following on affected DIG:

. IF DIG was stopped using emergency NOTE: The 1A DIG did NOT stop pushbutton start due to a Sequencer failure.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 46 of 83 Event

Description:

Loss of IETA(Ground Fault)/Sequencer Failure Time Pos. Expected ActionslBehavIor Comments

. IF bus known to be locked out, THEN NOTE: It is likely that the CRS GO TO Step 50. has determined that 1 ETA is Locked Out (AO investigation).

BOP (Step 50) Check S/I HAS OCCURRED DURING THIS EVENT.

BOP (Step 50 RNO) Perform the following:

. IF 1 ETA OR 1 ETB deenergized, THEN ensure both VL fans on energized train are running in HIGH.

. GO TO Step 52.

NOTE: The CRS will NOT stop to look at Tech Specs while in AP-07. Tech Spec review should occur after completion of scenario. Therefore, at the discretion of the lead examiner, move to Event 5 (Page 57)

TECHNICAL SPECIFICATION 3.8.1, AC SOURCES - OPERATING CRS 3.8.1 AC Source - Operating CRS LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 47 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos. Expected ActionslBehavior Comments

. Two qualified circuits between the offsite transmission network and the Onsite Essential Auxiliary Power System AND

. Two diesel generators (DGs) capable of supplying the Onsite Essential Auxiliary Power Systems AND

. The automatic load sequencers for Train A and Train B shall be OPERABLE.

CRS APPLICABILITY: MODES 1, 2, 3, and 4.

CRS ACTIONS CRS CONDITION REQUIRED COMPLETION ACTION TIME NOTE: The CRS will A. One offsite A.1 Perform SR 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months circuit 3.8.1.1 for determine that one offsite line inoperable. OPERABLE AND and one DG are inoperable offsite Once per 8 because neither are capable of circuit, hours thereafter supplying the Emergency Bus AND (TS Basis pB3.8.1-2).

A.2 Declare 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from Consequently, ACTION A.1, required discovery of no features A.2 and A.3 must be entered.

offsite power to with no one train Additionally, The CRS will offsite concurrent with power determine that ACTION B.1, inoperabilityof available redundant B.2, either B.3.1 or B.3.2 and inoperable required B.4 must be entered.

with its feature(s).

redundant required feature(s) is inoperable.

AND A.3 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months offsite circuit AND to OPERABLE 6 days from status. failure to meet LCO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 48 of 83 Event

Description:

Loss of I ETA(Ground Fault)ISequencer Failure Time Pos. Expe ed ActionslBe avior Comments B. One DG B.1 Perform SR 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. 3.81.1 for OPERABLE AND offsite Once per 8 circuit. hours AND thereafter.

B.2 Declare required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from features discovery of supported Condition B by the concurrent with inoperable inoperability of DG redundant inoperable required when its feature(s).

required redundant feature(s) is inoperable.

AND B.3.1 Determine inoperable DG is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE DO.

AND B.4 Restore DO 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE AND status 6 days from failure to meet LCO.

TECHNICAL SPECIFICATION 3.8.4, DC SOURCES OPERATING -

CRS LCO 3.8.4 The four channels of DC sources shall be OPERABLE.

CRS APPLICABILITY: MODES 1, 2, 3, and 4.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 49 of 83 Event

Description:

Loss of IETA(Ground Fault)/Sequencer Failure Time Pos. Expected ActionslBehavior Comments CRS ACTIONS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that the AC Battery A.. One A.1 Restore 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Chargers are inoperable. (TS channel of channel of Basis pB3.8.4-3).

DC source DC source to inoperable. OPERABLE Consequently, ACTION A.1, or status. A.2.1 and A.2.2 must be OR entered.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months A.2.1 Verify associated bus tie breakers are closed between DC channels.

AND A.2.2 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months channel of DC source to OPERABLE status.

TECHNICAL SPECIFICATION 3.&9, DISTRIBUTION SYSTEMS - OPERATING CRS LCO 3.8.9 Train A and Train B AC, four channels of DC, and four AC vital buses electrical power distribution subsystems shall be OPERABLE.

CRS APPLICABILITY: MODES 1,2, 3, and 4.

CRS ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 50 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos. Expec ?d ActionslBe avior Comments A. One or more A.1 Restore AC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months NOTE: The CRS will AC electrical electrical determine that 1 ETA is power power AND distribution distribution inoperable.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from subsystem(s) subsystem(s) discovery of inoperable, to Consequently, ACTION A.1 failure to meet OPERABLE LC0. must be entered.

status.

NOTE: The CRS may direct the BOP to perform AP-12, while the remainder of the crew continues with AP-7.

If so, BOP Examiner follow the AP-1 2 steps below.

APII/A15500112, LOSS OF LETDOWN, CHARGING OR SEAL INJECTION BOP (Step 1) Check if charging is aligned to Regenerative Hx as follows:

. Charging flow GREATER THAN 20 NOTE: The BOP may take GPM MANUAL control of 1 NV-238 to control Charging flow.

. 1NV-241 (Ui Seal Water Inj Flow Control) THROTTLED OPEN

. 1 NV-244A (Ui Charging Hdr Cont Outside Isol) OPEN

. 1NV-245B (Ui Charging Hdr Cont Outside Isol) OPEN.

BOP (Step 2) Check Pzr Level LESS THAN 96%.

BOP (Step 3) Stop any power or temperature changes in progress.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 51 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos. Expected ActionslBehavior Comments BOP (Step 4) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement that AP-i 2 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 5) IF this AP entered due to loss of letdown only, THEN GO TO Step 37.

BOP (Step 37) Ensure the following valves are CLOSED:

. 1 NV-458A (Ui 75 GPM L/D Orifice OtIt Cont Isol)

. 1 NV-457A (Ui 45 GPM L/D Orifice OtIt Cont Isol) 1 NV-35A (Ui Variable L/D Orifice OtIt Cont Isol).

BOP (Step 38) Ensure NC System makeup controller is in AUTO.

BOP (Step 39) Ensure charging flow going down NOTE: The BOP may take to maintain Pzr at program level. MANUAL control of iNV-238 to control Charging flow.

BOP (Step 40) Check LETDN RELIEF HI TEMP alarm (iAD-7, 1-4) HAS REMAINED DARK.

BOP (Step 41) Check 1NV-2iA (Ui NV Supply to Ui Aux PZR Spray Isol) CLOSED.

BOP (Step 42) Operate Pzr heaters as follows:

. Check A, B, and D Pzr heater group supply breakers on vertical board CLOSED.

. Check normal Pzr spray AVAILABLE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 52 of 83 Event

Description:

Loss of I ETA(Ground Fault)ISequencer Failure Time Pos. Expected Actions/Behavior Comments BOP Place the following Pzr heater groups in manual and ON to maximize spray flow:

A

B

D BOP (Step 43) Check the following valves NOTE: If normal Letdown has OPEN: been isolated, it is likely that these valves are CLOSED.

. 1NV-1A (Ui NC LID Isol To Regenerative Hx)

. 1 NV-2A (Ui NC L/D Isol To Regenerative Hx).

BOP (Step 43 RNO) Perform the following:

. IF normal letdown known to be NOTE: If Pzr level has been unavailable restored, Normal Letdown is available.

Prior to opening 1 NV-i A or 1 NV-2A in subsequent step, attempt to evacuate all personnel from lower containment (potential water hammer event).

. Observe Caution prior to Step 45 and GO TO Step 45.

BOP (Caution prior to Step 45) Establishing normal letdown without local pressurization may cause some water hammer.

BOP Determine if conditions allow immediate restoration of normal letdown as follows:

. Check both 1NV-1A (Ui NC L/D Isol To Regenerative Hx) and INV-2A (Ui NC L/D Isol To Regenerative Hx) OPEN WITHIN THE LAST 60 MINUTES.

. Check orifice isolation valves AUTO CLOSED

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 53 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos. Expected ActionslBehavior Comments SOP Determine exact time each NV letdown valve went closed on the OAC by performing the following:

0 Enter turn on code ARCHIVE.

0 Ensure OAC automatically populates START TIME and STOP TIME (previous hour).

o Enter group name AP12.

0 Click F3 VIEW PID.

. Check if orifice isolation valves reached fully closed PRIOR TO 1NV-1A OR 1NV-2A CLOSING.

BOP (Step 46) GO TO Step 49.

SOP (Step 49) Establish normal letdown as follows:

. Ensure 1 NV-459 (Ui Variable L/D Orifice Outlet Flow Cntrl) is CLOSED.

. Place 1NV-124 (Ui Letdown Press Control) in manual with output between 40-45% OPEN.

. Check OAC IN SERVICE.

. Check valve position on OAC for 1 NV-124 INDICATING THROTTLED.

. Check the following valves OPEN: NOTE: Both valves are expected to be CLOSED.

. 1NV-1A (Ui NC L/D Isol To Regenerative_Hx)

. 1NV-2A (Ui NC L/D Isol To Regenerative_Hs).

. IF time allows, THEN wait until all personnel are evacuated from lower containment.

. Establish cooling to Regenerative Hx by performing the following concurrently:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event# 4 Page 54 of 83 Event

Description:

Loss of IETA(Ground Fault)/Sequencer Failure Time Pos. Expected ActionslBehavior Comments BOP

Establish at least 65 GPM charging NOTE: The BOP will take flow by THROTTLING OPEN 1 NV- MANUAL control of 1 NV-238 238 (Ui Charging Hdr Control) or to control Charging flow.

raising PD pump_speed.

. THROTTLE 1 NV-241 (Ui Seal Water Inj Flow Control) to establish approximately 8 GPM seal injection flow to each NC pump.

OPEN letdown line isolation valves as follows:

OPEN 1NV-7B (Ui Letdown Cont Outside Isol).

. OPEN 1NV-1A (Ui NC LID Isol To Regenerative_Hx).

OPEN 1 NV-2A (UI NC L/D Isol To Regenerative_Hx).

OPEN I NV-35A (Ui Variable L/D Orifice Otlt Cont Isol).

Slowly THROTTLE OPEN 1 NV-459 (Ui Variable LID Orifice Outlet Flow Cntrl) until one of the following conditions met:

. Letdown flow GOES UP OR

1 NV-459 valve demand AT 60%.

Do not continue until one of the above conditions is met.

Check letdown flow HAS GONE UP.

THROTTLE CLOSED 1NV-i24 (UI Letdown Press Control) until one of the following conditions is met:

Letdown pressure is between 250-350 PSIG.

1NV-i24 is 10-20% OPEN.

Adjust charging flow as needed in subsequent steps while maintaining the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 4 Page 55 of 83 Event

Description:

Loss of I ETA(Ground Fault)/Sequencer Failure Time Pos. Expected Actions/Behavior Comments

. NC pump seal injection flow greater than 6 GPM

. Regenerative Hx letdown temperature less than 380°F.

Establish desired letdown flow (normally greater than or equal to 75 GPM) by completing the following concurrently:

Slowly THROTTLE OPEN 1 NV-459 (Ui Variable LID Orifice Outlet Flow Orifice Outlet Flow Cntrl) to achieve desired letdown flow.

. As letdown pressure rises, THROTTLE 1NV-124 (Ui Letdown Press Control) to maintain letdown pressure between 250 PSIG and 350 PSIG.

Do not continue until desired flow rate is established.

Check setpoint for INV-124(U1 Letdown Press Control) SET BETWEEN 348-352 PSIG.

THROTTLE 1 NV-i 24 to obtain letdown pressure between 348-352 PSIG.

Place 1NV-i24 in auto.

Ensure letdown pressure controlling between 348-352 PSIG.

IF more letdown flow required NOTE: Additional Letdown flow will NOT be required.

Adjust charging flow as desired while maintaining the following:

NC pump seal injection flow greater than 6 GPM

Regenerative Hx letdown temperature less than 380° F

Pzr level at program level.

Check iA or 1 B NV pump SUPPLYING

- NOTE: The 1 B NV Pump is NORMAL CHARGING. running.

Appendix D Operator Action Form ES-D-2 OpTestNo.: N14-1 Scenario# 4 Event# 4 Page 56 of 83 Event

Description:

Loss of IETA(Ground Fault)ISequencer Failure Time Pos Expected ActionslBehavior Comments BOP

WHEN Pzr level matches program level, THEN perform the following:

Place 1NV-238 (Ui Charging Hdr Control) in auto.

On DCS workstation, place PZR LEVEL MASTER in auto.

. THROTTLE 1 NV-241 (Ui Seal Water Inj Flow Control) as necessary to maintain approximately 8 GPM seal injection flow to each NC pump.

Notify Chemistry that normal letdown is NOTE: The BOP may contact in service. WCCSlChemistry for this notification.

If so, Booth Instructor acknowledge as WCCS/Chemistry.

Check position of 1NV-127A (Ui LID Hx 3-Way Temp Control) ALIGNED TO D EM I N.

Operate Pzr heaters as desired.

WHEN time allows, THEN notify NOTE: The BOP may contact engineering to document the following WCCSIRE for this notification.

transients: If so, Booth Instructor acknowledge as WCCSIRE.

Letdown isolation

Potential charging nozzle transient

IF NV Aux Spray was in service, THEN spray nozzle transient.

Check excess letdown - ISOLATED.

RETURN TO procedure and step in NOTE: The BOP will inform effect. the CRS that Normal Letdown has been restored.

At the discretion of the Lead Examiner move to Event 5.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 5 Page 57 of 83 Event

Description:

Turbine Low Lube Oil PressurelTurbine Trip /Generator Breaker Fails to OPEN/Steam Dump failurellA SG PORV fails partially OPEN Next, a low lube oil pressure condition will develop on the Main Turbine eventually causing the Main Turbine to trip. Since the plant power is less than P-8, the Reactor will not trip. Simultaneously, the 1 B Main Generator Breaker will fail to trip causing a reverse powering of the Main Generator and the Steam Dump Valves will fail to open causing the SG PORVs to open. The operator will respond in accordance with AP/11A15500102, Turbine Generator Trip. When the operator takes control of the Steam Dump System, the 1A SG PORV will fail 10% OPEN. The operator will need to manually isolate this valve in accordance with the requirements of API1IAJ5500IO1, Steam Leak.

Booth Operator Instructions: Insert: MAL-LT002 = 6.0, Ramp = 2 mm Insert: REM-SB0003, 6, 9, 12, 15, 18, 21, 24, and 270 Insert MAL-EPOO4B ACTIVE (lB Generator Breaker fails to Trip on Turbine Trip)

InsertMAL-DEHOOI TRUE (Turbine Trip) lnsertMAL-SMOO2A = 10 (IA SM PORV OPEN)

Indications Available:

OAC Alarm: Unit 1 Turbine Seal Oil Backup Pump On.

Turbine bearing oil pressure starts to lower.

MCB Annunciator lAD-i IA-9 LO TURB BRG OIL PRESS TURB TRIP

Turbine Trip Valves closed

Turbine Governor Valves closed

Rx does NOT trip (Rx Trip Breakers closed)

lB Generator Breaker remains closed on Turbine Trip

Steam Dump Valves do not open NOTE: If a AC is dispatched to investigate:

Wait 5 mm, then report there is a large oil leak on the discharge of the Main Turbine Oil Tank Eductor.

NOTE: The CRS will enter AP-02.

APIIIAI500IO2, TURBINE GENERATOR TRIP RO (Step 1) Check Turbine Trip:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 5 Page 58 of 83 Event

Description:

Turbine Low Lube Oil Pressure/Turbine Trip /Generator Breaker Fails to OPENISteam Dump failure/IA SG PORV fails partially OPEN Time Pos. Expected ActionslBehavior Comments

. All throttle valves CLOSED.

RO (Step 2) Check P/R meters LESS THAN NOTE: PR indication is <

20%. 20%.

(Step 3) Stabilize reactor power as follows:

. Place control rods in manual. NOTE: The rods must be moved in MANUAL.

. Check P/R meters GREATER THAN NOTE: The CRS will 5%. designate the RO.

. Stabilize reactor power, as indicated on NOTE: This is a Continuous P/R meters, between 12%-i 5% with Action. The CRS will make control rods in manual. both board operators aware.

WHEN reactor power is stabilized between 12%-i 5%, THEN maintain hR startup rate at 0 to ensure a constant power level.

RO (Step 4) IF AT ANY TIME reactor power NOTE: This is a Continuous goes below 5%, THEN perform the following: Action. The CRS will make both board operators aware.

RO . Do not pull control rods.

. Insert control rods as necessary to maintain negative SUR on hR startup rate meters.

RO (Step 5) Check C-9 COND AVAILABLE FOR STEAM DUMP status light (1 SI-i 8)

LIT.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 5 Page 59 of 83 Event

Description:

Turbine Low Lube Oil PressurelTurbine Trip IGenerator Breaker Fails to OPEN/Steam Dump failurellA SG PORV fails partially OPEN BOP (Step 6) Check any CF pump IN SERVICE. NOTE: The 1A CF Pump is in service.

RO (Step 7) Check both generator breakers NOTE: The 1 B Generator OPEN. Breaker is CLOSED.

NOTE: The operator may have previously taken manual action to depress the ENABLE and TRIP Breaker Pushbutton simultaneously.

RO (Step 7 RNO) Perform the following:

. Manually initiate turbine trip.

. IF any main turbine throttle valve is still open...

. IF both generator breakers open... NOTE: The 18 Generator Breaker is CLOSED.

. IF Turbine Generator output less than or equal to zero MW, THEN perform the following:

. Open both generator breakers by depressing ENABLE and TRIP at the same time.

. GOTOStep8.

RO (Step 8) Check EXCITATION OFF.

RO (Step 9) IF AT ANY TIME T-Avg is less than NOTE: This is a Continuous 551F AND going down, THEN perform the Action. The CRS will make following: both board operators aware.

. Trip reactor.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 5 Page 60 of 83 Event

Description:

Turbine Low Lube Oil PressurelTurbine Trip /Generator Breaker Fails to OPENISteam Dump failurellA SG PORV fails partially OPEN Time Pos. Expected Actions/Behavior Comments

. GO TO EPI1IAI5000IE-0 (Reactor Trip or Safety Injection).

RO (Step 10) Check all control rods ALIGNED WITH ASSOCIATED BANK.

RO (Step 11) Check MSR RESET light LIT.

CRS (Step 12) Announce the following: Unit 1 NOTE: CRSmayaskU2 RO Turbine trip, non-essential personnel stay out to make Plant Announcement of Unit 1 turbine bldg. that the Unit 1 Turbine has tripped, and that non-essential personnel must stay out of Unit 1 turbine bldg.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 13) Check UNBLOCK light for AMSAC ACTUATION BLOCK/UNBLOCK switch (1 MC-2) DARK.

RO (Step 14) Check condenser dump valves NOTE: The condenser dump MODULATING OPEN. valves are CLOSED.

BOP (Step 14 RNO) Transfer steam dumps to steam pressure mode as follows:

. Ensure STM PRESS CONTROLLER setpoint at 1090-1095 PSIG.

. Place STM PRESS CONTROLLER in manual.

. Adjust STM PRESS CONTROLLER output to 0%.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 5 Page 61 of 83 Event

Description:

Turbine Low Lube Oil PressurelTurbine Trip IGenerator Breaker Fails to OPEN/Steam Dump failurellA SG PORV fails partially OPEN

. Using STEAM DUMP SELECT switch, perform the following:

. Ensure C-7A reset.

. Place steam dumps in steam pressure mode.

. IF STEAM HEADER PRESSURE is greater than 1100 PSIG, THEN manually OPEN steam dumps to control pressure 1090-1 095 PSIG.

. Place STM PRESS CONTROLLER NOTE: When the Steam in auto. Dump Valves are controlled in the Steam Pressure Mode, the SG PORVs will be expected to CLOSE.

The operator should observe that the 1A SG PORV is failed OPEN, and take immediate action to close the 1A SG PORV Isolation Valve per AP 1.

BOP (Step 15) Check Pzr pressure control response:

. Ensure Pzr heaters are in auto.

. Ensure Pzr spray control valves are in auto.

. Check Pzr PORVs CLOSED.

. Check Pzr spray control valves CLOSED.

BOP (Step 16) Check Pzr level TRENDING TO PROGRAM.

RO (Step 17) Ensure Bearing Lift Pump in AUTO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 5 Page 62 of 83 Event

Description:

Turbine Low Lube Oil Pressure/Turbine Trip /Generator Breaker Fails to OPENISteam Dump failurellA SG PORV fails partially OPEN Time Pos. Expected Actions/Behavior Comments RO (Step 18) WHEN bearing oil pressure goes down to 1 1-12 PSIG, THEN ensure AC Bearing Oil Pump starts.

RO (Step 19) Transfer AS header supply:

CLOSE 1AS-9 (Ui C Htr Bleed To AS Hdr Isol).

Check Unit 2 as follows:

. Unit 2 Reactor power GREATER NOTE: CRS will ask U2 RO to THAN 15% report power level.

If so, Floor Instructor report 100% as U2 RO.

. Unit 2 2AS-1 2 (U2 SM to AS Hdr NOTE: CRS will ask U2 RO to Control Inlet Isol) OPEN

- report valve position.

If so, Floor Instructor report 2A5-12 is OPEN.

. Unit 2 AVAILABLE TO SUPPLY AS NOTE: CRS will ask U2 RO to HEADER. report U2 AS Availability.

If so, Floor Instructor report U2 AS is available.

Isolate Unit 1 SM to AS header as follows:

IF AT ANY TIME AS pressure cannot NOTE: This is a Continuous be maintained greater than 140 Action. The CRS will make PSIG while performing the following both board operators aware.

step, THEN GO TO Step I 9e.

Slowly CLOSE 1AS-12 (Ui SM TO AS Hdr Control Inlet Isol) while monitoring AS header pressure.

GO TO Step 20.

RO (Step 20) Remove one CF pump from service as follows:

Check both CF pumps RESET.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 5 Page 63 of 83 Event

Description:

Turbine Low Lube Oil PressurelTurbine Trip IGenerator Breaker Fails to OPENISteam Dump failurellA SG PORV fails partially OPEN Time Pos. Expected ActionslBehavior Comments CRS (Step 20 RNO) GO TO Step 21.

RO (Step 21) Check T-Avg GREATER THAN 561°F.

RO (Step 22) Check steam seal supply aligned to AS as follows:

. Check 1TL-21 (AS To Steam Seal Isol) OPEN.

. Check 1TL-3 (SM TO Steam Seal Isol) CLOSED.

CRS (Step 23) Check reactor shutdown to less than 5% power PLANNED OR HAS OCCURRED.

CRS (Step 23 RNO) IF reactor power to remain greater than or equal to 5%, THEN perform the following:

. IF AT ANY TIME it is determined that NOTE: This is a Continuous reactor power cannot be maintained Action. The CRS will make greater than or equal to 5%, THEN both board operators aware.

RETURN TO Step 19.

. Observe Caution prior to Step 31 and GO TO Step 31.

RO (Caution prior to Step 31) S/G shrink and swell effects will be more severe with the turbine shutdown.

RO (Step 31) Monitor S/G levels as follows:

. IF AT ANY TIME SIG NIR level(s) NOTE: This is a Continuous cannot be controlled within +/- 10% of Action. The CRS will make setpoint, THEN control SIG level(s) both board operators aware.

manually PER Step 31 c through 31 e

. GO TO Step 32.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 5 Page 64 of 83 Event

Description:

Turbine Low Lube Oil PressurelTurbine Trip /Generator Breaker Fails to OPEN/Steam Dump failure/IA SG PORV fails partially OPEN Time Pos. Expected ActionslBehavior Comments RO (Step 32) Swap CF pump steam supply as follows:

. Check 1 HM-95 (Ui Aux Steam Supply to CF Pumps Turbine Isol)

CLOSED.

CRS (Step 32a RNO) IF 1 HM-95 is full open, THEN GO TO Step 34.

CRS (Step 34) IF AT ANY TIME CF control NOTE: This is a Continuous bypass valves are maintaining SIG levels Action. The CRS will make AND all CF control valves are closed, THEN both board operators aware.

perform the following:

. CLOSE 1CF-31 (1A SIG CF Control Inlet Isol).

. CLOSE 1CF-22 (lB SIG CF Control Inlet Isol).

. CLOSE 1CF-19 (1C SIG CF Control Inlet Isol).

. CLOSE 1CF-16 (1D S/G CF Control Inlet Isol).

. Place all SIG CF control valves in manual.

CRS (Step 35) Align turbine drain valves as follows:

. Place TURB DRN VLVS CNTRL switch in AUTO.

. Check turbine drain valves OPEN.

At the discretion of the Lead Examiner, move to Events #6-7.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 65 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Following this, a large steam rupture will occur inside Containment on the 1 D Steamline.

SI will fail to actuate automatically. The operator will trip the Reactor and manually actuate Safety Injection, and then enter EP/1/A15000/E-O, Reactor Trip or Safety Injection. With 1 ETA still de-energized, only the B Train of ESF equipment will function.

Upon completion of E-O, the operator will transition to EP/i/A15000/E-2, Faulted Steam Generator Isolation. Upon completion of E-2, the operator will transition either to EPI1IAI5000/E-i, Loss of Reactor or Secondary Coolant, or to EPI1/AI5000IES-i .1, SI Termination. If the crew transitions to E-1, the scenario will terminate upon transition. If the crew transitions to ES-i .1, the scenario will terminate at Step 7.c of ES-i .1, after the crew has closed i NI-i OB.

Booth Operator Instructions: insert MAL-SMOO7D 2021250 Ramp6O Indications Available:

. Containment pressure rises to> 1 psig

. MCB Annunciator 1AD9 A-5, ICE CONDENSER DOORS INLET DOORS OPEN

. MOB Annunciator 1AD9 A-8, CONT .5 PSIG ALERT

. Tavg starts to lower.

NOTE: Crew will carry out Immediate Actions of E-O, prior to the CRS addressing the EP.

EPIIIAI5000IE-0, REACTOR TRIP OR SAFETY INJECTION ROt (Step 1) Monitor Foldout page.

BOP NC Pump Trip Criteria (Not expected)

CA Suction Sources (CA storage tank (water tower) goes below 1.5 ft Not expected)

Position Criteria for 1 NV-i 50B and 1 NV- NOTE: The BOP will monitor 151A (Ui NV Pump Recird Isol) these conditions.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 66 of 83 Event

Description:

ID Steam Line Break Inside Containmentl SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments

. IF NV S/I flowpath aligned AND NC pressure is less than 1500 PSIG, THEN CLOSE 1NV-150B and 1NV-151A.

. IF NC pressure is greater than 2000 PSIG, THEN OPEN 1NV-1 SOB and 1NV-151A.

Ruptured S/G Aux Feedwater Isolation Criteria (Not expected)

Faulted S/G Aux Feedwater Isolation Criteria NOTE: The BOP will monitor (Expected) these conditions, and isolate CA flow to the 1D SG when met.

. IF all of the following conditions met, THEN stop CA flow to affected S!G:

. SIG pressure going down in an uncontrolled manner or completely depressurized

. Only one S/G is diagnosed as faulted

. Secondary heat sink:

. N/R level in at least one S/G - NOTE: Adverse Containment GREATER THAN 1 1 %(32% numbers will need to be used.

ACC)

. Total feed flow to S/Os -

GREATER THAN 450 GPM.

RO (Step 2) Check Reactor trip: Immediate Action

. All rod bottom lights LIT

. Reactor trip and bypass breakers OPEN

. hR amps - GOING DOWN.

RO (Step 3) Check Turbine Trip: Immediate Action

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 67 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments

. All throttle valves CLOSED.

BOP (Step 4) Check 1 ETA and 1 ETB Immediate Action ENERGIZED.

BOP (Step 4 RNO) Perform the following:

. IF both busses de-energized NOTE: 1ETA is de-energized.

. WHEN time allows, THEN try to restore NOTE: AP-7 will not be power to de-energized bus PER implemented further due to a AP/1/A15500!07 (Loss of Electrical Bus Overload Lockout on Power) while continuing with this 1 ETA.

procedure.

RO? (Step 5) Check if S/I is actuated: Immediate Action BOP NOTE: SI will fail to auto actuate, but may have been manually actuated by the time that the crew arrives at this Step.

If NOT, the RO/BOP will manually actuate SI.

A SAFETY INJECTION ACTUATED status light (151-i 8) LIT.

Both LOCA Sequencer Actuated status lights_(1SI-14) LIT.

CRITICAL TASK:

(E-O D) Manually actuate at least one train of SIS-actuated safeguards prior to transition out of E-O, Reactor Trip or Safety Injection.

Appendix D Operator Action Form ES-D-2 OpTestNo.: N14-1 Scenario# 4 Event# 6&7 Page 68 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments CRS (Step 6) Announce Unit 1 Safety Injection. NOTE: The CRS may ask U2 RO to make Plant Announcement that a Ui Safety Injection has occurred.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 7) Check all Feedwater Isolation status lights (1SI-4) LIT.

BOP (Step 8) Check Phase A RESET lights DARK.

BOP (Step 9) Check ESF Monitor Light Panel on energized train(s):

. Groups 1,2, 5DARK.

. Group3LIT

Group 4 LIT AS REQUIRED.

Group6-LIT

. GOTOSteplO.

ROI (Step 10) Check proper CA pump status:

. MDCApumps-ON NOTE: The 1A MDCA Pump is OFF.

(Step 10.a RNO) Start pumps. NOTE: No attempt will be made to start the 1A MDCA Pump.

. N/R level in at least 3 S/Gs GREATER THAN 17%.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenano # 4 Event # 6&7 Page 69 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically ROI (Step 1O.b RNO) Ensure TD CA pump on. NOTE: Depending on SG BOP Levels, the TDCA Pump may be running.

BOP (Step 11) Check all KC pumps ON. NOTE: The 1A KC Pumps are OFF.

(Step 1 1 RNO) Perform the following: NOTE: No attempt will be made to start the 1A KC Pumps.

. Start pumps.

. IF all KC pumps running... NOTE: The 1A KC Pumps are OFF.

. IF any NC pump KC low flow annunciator NOTE: It is expected that the lit on 1AD-6, THEN stop all NC pumps. NC Pumps will be stopped.

BOP (Step 12) Check both RN pumps ON. NOTE: The 1A RN Pump is OFF.

BOP (Step 12 RNO) Perform the following:

. Start pump(s). NOTE: No attempt will be made to start the 1A RN Pump.

. IF any RN pump off, THEN perform the following:

. IF 1A RN pump is off, THEN stop NC NOTE: It is expected that the pumps. NC Pumps will be stopped.

IF affected train is de-energized, AND its DIG is off, THEN GO TO Step 13.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 70 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically CRS (Step 13) Notify Unit 2 to perform the Floor Instructor: As U2 RD following: report 2A RN Pump is running.

. Start2ARN pump.

RD

THROTTLE Unit 2 RN flow to minimum Booth Instructor:

for existing plant conditions. insert LOA-RN087 (Start 2A RN Pump) insert LOA-RN083 8050.000000 delay0 ramplo (Unit 2 Train A Demand Flow)

RD (Step 14) Check all SIG pressures GREATER THAN 775 PSIG.

RD (Step 14 RND) Perform the following: NOTE: 1D SG Pressure is decreasing uncontrollably.

Check the following valves closed:

AIIMSIVs

All MSIV Bypass Valves

AIISMPORVs

If any valve open NOTE: All SM PORVs are CLOSED.

ROI (Step 15) Check containment pressure NOTE: Containment Pressure HAS REMAINED LESS THAN 3 PS 1G. is > 3 psig.

BDP BDP (Step 15 RND) Perform the following:

Check Monitor Light Panel Group 7 lit.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 71 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected Actions!Behavior Comments IF Group 7 window is dark on energized NOTE: Group 7 status lights train(s).., are LIT.

Stop all NC pumps while maintaining seal injection flow.

Ensure all RV pumps are in manual and off.

Energize H 2 Igniters by depressing ON and OVERRIDE.

Dispatch operator to stop all Unit 1 NE NOTE: The CRS will dispatch AHUs PER EPI1IAI5000IG-1 (Generic AO.

Enclosures) Enclosure 28 (De-energizing Booth Instructor:

Ice Condenser AHU5).

Acknowledge as appropriate.

Booth Instructor:

insert LOA-NFOI6 STOP (Ice Condenser AHU Start/Stop)

And then, report as AO that breakers are closed.

WHEN time allows, THEN check Phase NOTE: The CRS may assign B HVAC equipment PER Enclosure 2 the RO (BOP) to perform this (Phase B HVAC Equipment). action.

If so, RO (BOP) Examiner follow actions of Enclosure 2.

Other Examiners follow E-O Actions, Step 16, on Page 73.

E-O, REACTOR TRIP OR SAFETY INJECTION ENCLOSURE 2, PHASE B HVAC EQUIPMENT Examiner NOTE: Follow the actions associated with Enclosure 2 if RO (BOP) is assigned by CRS to perform.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 72 of 83 Event

Description:

ID Steam Line Break Inside Containmentl SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments RO! (Step 1) Check VE System in operation as BOP follows:

. VE Fans ON.

. Ensure all damper mode select switches in AUTO:

. 1AVS-D-7 Mode Select

. 1AVS-D-8 Mode Select

. 1AVS-D-2 Mode Select

. 1AVS-D-3 Mode Select

. Annulus pressure being maintained -

NEGATIVE.

RO! (Step 2) Check VX System in operation as BOP follows:

. Time since Phase B actuation -

NOTE: it is likely that 10 GREATER THAN 10 MINUTES. minutes has NOT elapsed since the Phase B actuation.

RO/ (Step 2 RNO) WHEN 10 minutes has BOP expired, THEN perform rest of this enclosure.

RO! (Step 2.b) Check the following dampers -

BOP OPEN:

. 1 RAF-D-4 (1 B Cont Air Ret Fan To Lwr Cont Test A)

. 1VX-2B (lB H2 Skimmer Fan Isol Test A)

. 1 RAF-D-2 (1 A Cont Air Ret Fan To Lwr Cont Test A)

. 1VX-1A (1A H2 Skimmer Fan Isol Test A).

RO! (Step 2.c) Check Containment Air Return BOP fans-ON

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 73 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments ROI (Step 2.d) Check H2 Skimmer fans - ON.

BOP E-O, REACTOR TRIP OR SAFETY INJECTION Examiner NOTE: Examiners following the CRSIBOP (RO) continue HERE.

BOP (Step 16) Check S/I flow:

. Check NV PMPS TO COLD LEG FLOW gauge INDICATING FLOW.

. Check NC pressure LESS THAN 1600 NOTE: NC Pressure is 1400 PS 1G. psig.

BOP (Step 16.b RNO) Perform the following:

. Ensure ND pump miniflow valve on running pump(s) OPEN:

. 1 ND-68A (1A ND Pump & Hx Mini Flow Isol)

. 1ND-676 (lB ND Pump & Hx Mini Flow Isol).

CRS . IF valve(s) open on all running ND pumps, THEN GO TO Step 17.

CRS (Step 17) Notify OSM or other SRO to NOTE: The CRS may ask perform EP/1/A/5000/G-1 (Generic OSM to address.

Enclosures), Enclosure 22 (OSM Actions If so, Floor Instructor Following an S/I) within 10 minutes.

acknowledge as OSM.

RO/ (Step 18) Check CA flow:

. Total CA flow GREATER THAN 450 GPM.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 74 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments BOP . Check VI header pressure GREATER THAN 60 PSIG.

RO WHEN each SIG NIR level is greater NOTE: Adverse Containment than 11% (32% ACC), THEN control CA numbers will need to be used.

flow to maintain that SIG NIR level between 1 1% (32% ACC) and 50%.

RO (Step 19) Check NC temperatures:

. IF all NC pumps off, THEN check NC T NOTE: All NC Pumps will be Colds STABLE OR TRENDING TO OFF.

5570 F.

(Step 19 RNO) Perform the following based NOTE: The CRS may assign on plant conditions: the RO to perform this action.

If so, RO Examiner follow actions of Enclosure 3.

Others should move ahead to Step 20 on Page 76 to continue in E-0.

5570 IF temperature less than F AND going down, THEN attempt to stop cooldown PER Enclosure 3 (Uncontrolled NC System Cooldown).

E-O, REACTOR TRIP OR SAFETY INJECTION ENCLOSURE 3, UNCONTROLLED NC SYSTEM COOLDOWN RO (Step 1) Check steam dump valves Examiner NOTE: Follow the CLOSED. actions associated with Enclosure 3 if RO is assigned by CRS to perform.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 75 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments RD (Step 2) Check all SM PORVs CLOSED.

RO (Step 3) Check MSR RESET light LIT.

RD (Step 4) Check any NC pump ON.

RD (Step 4 RND) Perform the following:

. IF any NC T-Cold is still going down, THEN GO TO Step 6.

RD (Step 6) Control feed flow as follows:

. IF S/G N/R level is less than 1 1% (32% NOTE: Adverse Containment ACC) in all S/Gs,... numbers will need to be used.

. WHEN N/R level is greater than 11% NOTE: Adverse Containment (32% ACC) in at least one S/G, THEN numbers will need to be used.

THROTTLE feed flow further to:

. Minimize cooldown

. Maintain at least one S/G N/R level NOTE: The RD may stop feed greater than 1 1% (32% ACC). flow to 1 D SG.

RD (Step 7) Check MSIVs ANY OPEN. NOTE: All MSIVs will be closed.

RD (Step 7 RND) Perform the following:

. Close MSIV bypass valves.

. Exit this enclosure.

Appendix D Operator Action Form ES-D-2 OpTestNo.: N14-1 Scenario# 4 Event# 6&7 Page 76 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected Actions/Behavior Comments E-O, REACTOR TRIP OR SAFETY INJECTION Examiner NOTE: Examiners NOT following RO actions in Enclosure 3, continue HERE.

BOP (Step 20) Check Pzr PORV and spray valves:

. All Pzr PORVs CLOSED.

BOP . Normal Pzr spray valves CLOSED.

. At least one Pzr PORV isolation valve OPEN.

BOP (Step 21) Check NC subcooling based on core exit T/Cs GREATER THAN 0°F.

BOP (Step 22) Check if main steamlines intact:

. All SIG pressures STABLE OR GOING NOTE: The 1D SG is Faulted.

UP

. All SIGs PRESSURIZED.

BOP (Step 22 RNO) IF any SIG is faulted, THEN perform the following:

CRS . Implement EPI1!AI5000IF-0 (Critical Safety Function Status Trees).

CRS . GO TO EP/1/A15000/E-2 (Faulted Steam NOTE: The CRS will transition Generator Isolation). to E-2.

EPII IAI5000IE-2, FAULTED STEAM GENERATOR ISOLATION ROI (Step 1) Monitor Foldout page.

BOP Cold Leg Switchover Criteria (< 95 INCHES in FWST Not expected)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 77 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected Actions/Behavior Comments CA Suction Sources (<1.5 feet Not expected)

Position Criteria for 1 NV-i 50B and 1 NV 151A (NV Pumps Recirculation)

. IF NV S/I flowpath aligned AND NC NOTE: The BOP will monitor pressure is less than 1500 PSIG, THEN these conditions.

CLOSE 1NV-150B and 1NV-151A.

. IF NC pressure is greater than 2000 PSIG, THEN OPEN 1NV-i SOB and 1NV-151A.

CRS (Step 2) Maintain any faulted S/C or secondary break isolated during subsequent recovery actions unless needed for NC System cooldown.

RO (Step 3) Check the following CLOSED:

. AIIMSIVs

. All MSIV bypass valves.

RO (Step 4) Check at least one S/G pressure NOTE: Although all SG STABLE OR GOING UP. pressures may be decreasing slowly, the operator will report stable based on plant conditions (i.e. faulted SC).

Otherwise a transition to ECA 2.1 will be made.

RO/ (Step 5) Identify faulted S/G(s): NOTE: The 1 D SG is Faulted.

. Any S/G pressure GOING DOWN IN AN UNCONTROLLED MANNER OR

. Any S/G DEPRESSURIZED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 78 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments RO (Step 6) Maintain at least one SIG available for NC System cooldown in subsequent steps.

RO (Step 7) Check faulted SIG(s) SM PORV CLOSED.

BOP (Step 8) Reset CA modulating valves.

RO! (Step 9) Isolate faulted S/G(s) as follows:

BOP ROl

For1DS/G:

Check SIG D FDW ISOLATED status light (1SI-4) LIT.

CLOSE 1CA-38B (Ui TD CA Pump Disch To 1 D SIG Isol).

. CLOSE 1CA-42B (lB CA Pump Disch To 1 D S/G Isol).

Check BB valves CLOSED:

1 BB-4B (1 D S/G Blowdown Cont Outside lsol Control).

1BB-8A (D SIG BB Cont Inside lsol).

Close 1SM-lOl (D SM Line Drain Isol).

CRITICAL TASK:

Isolate CA flow to the Faulted Steam Generator before an unwarranted Red Path occurs on Subcriticality or NCS Integrity.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 79 of 83 Event

Description:

1D Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments RO (Step 10) Close 1AS-12 (Ui SM To AS Hdr Control inlet isol).

RO! (Step 1 1) Check SIG tubes intact as follows:

. Check the following EMFs NORMAL:

. 1 EMF-33 (Condenser Air Ejector Exhaust)

. 1 EMF-24 (SIG_A)

. 1EMF-25(S/GB)

. 1 EMF-26 (SIC_C)

. 1EMF-27(S/GD).

. IF any SIG has previously been identified NOTE: There have been no as ruptured SGTRs identified.

. Notify RP to perform the following: NOTE: The CRS may call RP to perform surveys.

If so, Booth Instructor acknowledge as RP.

. IF S/C(s) fault known to be outside containment, THEN monitor area of steam fault for radiation.

. Frisk all Unit 1 S/G cation columns to determine if activity level is significantly_higher for any SIG.

. Notify Control Room of any abnormal radiation conditions.

. WHEN activity results reported, THEN notify station management to evaluate SIG activity.

RO/ (Step 12) Check S/I termination criteria:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 80 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments

. NC subcooling based on core exit T/Cs GREATER THAN 0°F.

. Secondary heat sink:

. NIR level in at least one intact S!G NOTE: Adverse Containment GREATER THAN 11% (32% ACC) numbers will need to be used.

. Total feed flow to intact S/Gs GREATER THAN 450 GPM.

. NC pressure STABLE OR GOING UP.

. Pzr level GREATER THAN 11% (29% NOTE: Adverse Containment ACC). numbers will need to be used.

CRS (Step 12.d RNO) GO TO Step 13. NOTE: Because of the Adverse Containment condition, the crew may NOT meet the Pzr Level threshold to terminate SI.

If NOT, the crew will go to E-1, and the exam should be terminated.

CRS (Step 12.e) GO TO EP/1/A15000/ES-1 .1 NOTE: The crew may meet (Safety Injection Termination). the Pzr Level threshold to terminate SI. If so, the CRS will transition to ES-Il.

EPIIIAI5000IES-1 .1, SAFETY INJECTION TERMINATION RO! (Step 1) Monitor Foldout page.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 81 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments S/I Reinitiation Criteria (Applies after Step 10 in body of this procedure) (Not expected)

Secondary Integrity Criteria (Not expected)

Cold Leg Switchover Criteria (< 95 INCHES in FWST Not expected)

CA Suction Sources (<1 .5 feet Not expected)

BOP (Step 2) Reset the following:

. S/I.

. Sequencers.

. Phase A Isolation.

. Phase B Isolation.

. IF AT ANY TIME a B/C signal occurs, NOTE: This is a Continuous THEN restart S/I equipment previously Action. The CRS will make on. both board operators aware.

BOP (Step 3) Establish VI to containment as follows:

. Open the following valves:

. 1VI-129B(VI Supply toACont Ess VI Hdr Outside Isol)

. 1VI-160B (VI Supply to B Cont Ess Hdr Outside Isol)

. 1VI-150B (Lwr Cont Non-Ess Cont Outside Isol).

. Check VI header pressure GREATER THAN 85 PSIG.

BOP (Step 4) Stop all but one NV pump.

RO (Step 5 Check NC pressure STABLE OR GOING UP.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 4 Event # 6&7 Page 82 of 83 Event

Description:

ID Steam Line Break Inside Containment! SI fails to actuate automatically Time Pos. Expected ActionslBehavior Comments BOP (Step 6) Isolate NV S/I flowpath as follows:

. Check the following valves OPEN:

. 1NV-221A(U1 NV Pumps Suct From FWST Isol)

. 1NV-222B (Ui NV Pumps Suct From FWST Isol)

. Check the following valves - OPEN NOTE: Both valves are CLOSED.

. 1NV-150B (Ui NV Pump Recirc Isol)

. 1NV-151A (Ui NV Pump Recirc Isol).

BOP (Step 6.b RNO) Perform the following:

. OPEN valves.

. IF both valves open, THEN GO TO Step 6.c.

(Step 6.c) CLOSE the following valves:

. 1 Nl-9A (NC Cold Leg lnj From NV)

. 1NI-1OB (NC Cold Leg inj From NV).

At the discretion of the Lead Examiner terminate the exam.

UNIT I STATUS:

Power Level: 15% NCS [B] 1963 ppm Pzr [B]: 1974 ppm Xe: Per OAC Power History: Startup in progress Core Burnup: 25.1 EFPDs CONTROLLING PROCEDURE: OP/1/A/61 00/003, Enclosure 4.1, Controlling Procedure for Unit Operation.

OP/1/A/6300/001, Enclosure 4.1, Turbine Generator Startup/Shutdown OTHER INFORMATION NEEDED TO ASSUME THE SHIFT:

The plant is at 15% power (BOL) with the Main Turbine at 1800 RPM.

The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

A power ascension is in progress and it is expected that the crew will phase the Main Generator to the Grid and raise power to 30% on this shift.

The following equipment is Out-Of-Service:

The 1A Hotwell Pump is OOS for motor replacement.

1KCP-5490, KC Pump 1A Header Pressure, failed last shift (IAE is investigating)

MCB Annunciator 1AD-13, F-7, WE TANK LO LEVEL, has been in constant alarm over the last hour (IAE is investigating).

Crew Directions:

The crew will be expected to complete the Turbine startup and synchronize the main generator to the electrical grid starting with Step 3.33.16 of Enclosure 4.1 of OP/i AJ6100/003, Controlling Procedure for Unit Operation

Conditioned Power Level is 100% power.

AO (Bill) is standing by at the Main Generator Voltage Regulator Panel.

Jim Aligood (SE) is available in the WCC (x4276).

Automatic Voltage Regulator (AVR) testing and post Turbine OPC and Mechanical Overspeed Trip Test will NOT be conducted.

Enclosure 4.4 (Piston Operated Check Valve Checklist) of OP/i/A/6300/001 (Turbine Generator Startup/Shutdown) has been completed.

Use of Alternate Dilute has been approved.

RE has recommended an initial Alternate Dilution of 200 gallons.

Turbine loading rate can be up to 5MWe/minute.

Work Control SROlOffsite Communicator Jim Plant SRO Joe AOs AVAILABLE Uniti Unit2 Aux Bldg. John Aux Bldg. Chris Turb Bldg. Bob Turb Bldg. Mike th 5

Rounds. Carol Extra(s) Bill Ed Wayne Tanya

Appendix D Scenario Outline Form ES-D-1 (Rev 071614)

Facility: McGuire Scenario No.: 3 Op Test No.: N14-l Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 40% power (BOL). The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The crew will be directed to raise power to 100% on this shift.

Turnover: The following equipment is Out-Of-Service: Pzr PORV INC-32B has been isolated (per AP-1 1) due PORV leakage. ACTION has been taken in accordance with Technical Specification LCO 3.4.11 ACTION A. OKRP-5040, KR tank Level, failed last shift (IAE is investigating) and MCB Annunciator lAD-Il, E-2, SEQB LOSS OF CONTROL PWR, spuriously alarmed several times during the shift (IAE is investigating).

Event Malf. Event Type* Event No. No. Description 1 NA R-RO Power Increase N-BOP N-SRO MAL 2 C-BOP Pzr PORV 1 NC34A fails partially OPEN NCOO3B C TS SRO NCO12B -

MAL 3 C-RO SG 1 B PORV fails OPEN SMOO1B C-SRO C-BOP Steam Generator Tube Leak SGOO1B C(TS)-SRO MAL 5 C-RO Continuous inward Rod Motion IREOO3A C-SRO MAL 6 M-RO 1 B Steam Generator Tube Rupture SGOO1B M-BOP M-SRO MAL 7 NA Failure of the C-9 Interlock IPEOO4H REM 8 NA Pzr Spray Valves fail to OPEN NC0027 NC0029 (N)ormal, (R)eactivity, ( I)nstrument, (C)omponent, (M)ajor 1

Appendix D Scenario Outline Form ES-D-1 (Rev 071614)

McGuire 2014 NRC Scenario #3 The plant is at 40% power (BOL). The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The crew will be directed to raise power to 100% on this shift.

The following equipment is Out-Of-Service: Pzr PORV 1NC-32B has been isolated (per AP-1 1) due PORV leakage. ACTION has been taken in accordance with Technical Specification LCO 3.4.11 ACTION A. OKRP-5040, KR tank Level, failed last shift (IAE is investigating) and MCB Annunciator lAD-li, E-2, SEQB LOSS OF CONTROL PWR, spuriously alarmed several times during the shift (IAE is investigating).

Shortly after taking the watch, the operator will commence a load increase to 100%

starting with Step 3.35.14 of Enclosure 4.1, Power Increase, of OP/1/A16100/003, Controlling Procedure for Unit Operation. The operator will dilute the NC System Boron concentration in accordance with Enclosure 4.4, Alternate Dilute, of OPI1IA6150!009, Boron Concentration Control, and raise Turbine load in accordance with OP/1/A16300/001 A, Turbine-Generator Load Change.

During the power increase, Pzr PORV 1NC34A will fail partially OPEN, and fail in this position. The operator will respond in accordance with AP/1/A15500/11, Pressurizer Pressure Anomalies. The operator will ultimately close the Block Valve for Pressurizer PORV 1NC34A when it is determined that the PORV cannot be closed. The operator will address Technical Specification LCO 3.4.1, RCS Pressure, Temperature and Flow Departure From Nucleate Boiling (DNB) Limits, and LCO 3.4.11, Pressurizer Power Operated Relief Valves (PORVS).

Next, the 18 Steam Generator PORV will fail OPEN. The operator will respond in accordance with AP/1/A15500/01, Steam Leak, and isolate the PORV. The operator will address Technical Specification LCO 3.7.4, Steam Generator Power Operated Relief Valves (SG PORV5), and will determine that the required number of SG PORVs are OPERABLE for current plant conditions; and may enter LCO 3.4.1, RCS Pressure, Temperature and Flow Departure from Nucleate Boiling (DNB) Limits.

Subsequently, a 90 gpm Steam Generator Tube Leak will occur (over 10 minutes) on the lB Steam Generator. The operator will enter AP/1/A15500/10, NC System Leakage Within the Capacity of Both NV Pumps. The operator will address Technical Specification LCO 3.4.13, RCS Operational Leakage, and SLC 16.9.7, Standby Shutdown System. The crew will be directed by AP/1/A15500/10 to reduce plant power to Mode 3 within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months . The operator will perform a rapid downpower in accordance with AP/1 /A15500/04, Rapid Downpower.

During the downpower, the Control Rods will continuously insert. The operator will enter AP/1/A!5500/14, Rod Control Malfunction, and take manual control of the rods.

After this, the leak will develop into a 500 gpm Steam Generator Tube Rupture and the operator will enter EP/1/A15000/E-0, Reactor Trip or Safety Injection. Upon completion of E-0, the operator will transition to EP/1/A15000!E-3, Steam Generator Tube Rupture, to isolate the flow into and out of the 1 B Steam Generator and then conduct a cooldown of the NC System. While performing an NCS cooldown the C-9 Interlock will fail and Appendix D Scenario Outline Form ES-D-1 (Rev 071614) result in a loss of the steam dumps. The operator will be required to re-initiate the cooldown using the available SG PORVs. During the NCS depressurization, the Pzr Spray Valves will fail to open. The operator will be required to conduct the depressurization using the last available Pzr PORV.

The scenario will terminate at Step 22.c of E-3, after the crew has closed the Cold Leg Isolation Valves from the NV System.

Critical Tasks:

E-3A (E-3A) Isolate feedwater flow into and steam flow from the ruptured SG so that minimum AP between ruptured Steam Generator and intact Steam Generators is not less than 250 psid once target temperature is reached (Entry into ECA-3.1).

Safety Significance: Failure to isolate the ruptured SG causes a loss of AP between the ruptured SG and the intact SGs. Upon a loss of t\P, the crew must transition to a contingency procedure that constitutes an incorrect performance that necessitates the crew taking compensating action which complicates the event mitigation strategy. If the crew fails to isolate steam from the SG, or feed flow into the SG the ruptured SG pressure will tend to decrease to the same pressures as the intact SGs, requiring a transition to a contingency procedure, and delaying the stopping of RCS leakage into the SG.

E-3C Depressurize the NCS to meet SI termination criteria before the Quality of the steam exiting the SG exceeds 80% (0.8 on Void Fraction SGINFO.cts).

Safety Significance: Failure to stop the reactor coolant leakage into a ruptured SG by depressurizing the RCS (when it is possible to do so) needlessly complicates the mitigation of the event, It also constitutes a significant reduction of Safety Margin beyond that irreparably introduced by the scenario. If RCS depressurization does NOT occur, the inventory in the secondary side of the ruptured SG will rise to the level of the Main Steam Lines leading to water release through the SG PORV or Safety Valve, which could cause and unisolable fault in the ruptured SG.

PROGRAM: McGuire Operations Training MODULE: Initial License Operator Training Class 30 TOPIC: NRC Simulator Exam Scenario N14-1-3

REFERENCES:

1. API1IAI5500/1 1, Pressurizer Pressure Anomalies (Rev 11)

2. Technical Specification LCO 3.4.11, Pressurizer Power Operated Relief Valves (PORVS)

(Amendment 221/203)

3. OP/1/A16100/003, Controlling Procedure for Unit Operation (Rev 190)

4. OP/1/A16150/009, Boron Concentration Control (Rev 125)

5. OP/1/A16300/OO1A, Turbine Generator Load Change (Rev 11)

6. Technical Specification LCO 3.4.1, RCS Pressure, Temperature and Flow Departure From Nucleate Boiling (DNB) Limits (Amendment 219/201)

7. AP/1!A15500/01, Steam Leak (Rev 18)

8. Technical Specification LCO 3.7.4, Steam Generator Power Operated Relief Valves (SG PORVs) (Amendment 221/203)

9. AP/1/A15500/10, NC System Leakage Within the Capacity of Both NV Pumps (Rev 23)

10. OP/0/A6450/01 1, Control Area Ventilation/Chilled Water System (Rev 97)

11. AP!1/A15500/04, Rapid Downpower (Rev 24)

12. Technical Specification LCO 3.4.13, RCS Operational Leakage (Amendment 237/219)

13. SLC 16.9.7, Standby Shutdown System (Rev 133)

14. AP/1/A15500!14, Rod Control Malfunction (Rev 16)

15. EP/1/A/5000/E-0, Reactor Trip or Safety injection (Rev 33)

16. EP/1/A/5000/E-3, Steam Generator Tube Rupture (Rev 23)

Validation Time: 106 minutes Author: David Lazarony, Western Technical Services, Inc.

Facility Review:

Rev. 071614 1

Scenario Event Description NRC Scenario 3 Facility: McGuire Scenario No.: 3 Op Test No.: N14-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 40% power (BOL). The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The crew will be directed to raise power to 100% on this shift.

Turnover: The following equipment is Out-Of-Service: Pzr PORV 1 NC-32B has been isolated (per AP-1 1) due PORV leakage. ACTION has been taken in accordance with Technical Specification LCO 3.4.11 ACTION A. OKRP-5040, KR tank Level, failed last shift (IAE is investigating) and MCB Annunciator lAD-il, E-2, SEQB LOSS OF CONTROL PWR, spuriously alarmed several times during the shift (IAE is investigating).

Event Malt. Event Type* Event No. No. Description 1 NA R-RO Power Increase N-BOP N-SRO MAL 2 C-BOP Pzr PORV 1 NC34A fails partially OPEN NCOO3B C(TS)-SRO NCO12B MAL 3 C-RO SG 1 B PORV fails OPEN SMOO1B C-SRO MAL 4 C-BOP Steam Generator Tube Leak SGOO1B C(TS)-SRO MAL 5 C-RO Continuous inward Rod Motion IREOO3A C-SRO MAL 6 M-RO 1 B Steam Generator Tube Rupture SGOO1B M-BOP M-SRO MAL 7 NA Failure of the C-9 Interlock IPEOO4H REM 8 NA Pzr Spray Valves fail to OPEN NC0027 N00029 (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario Event Description NRC Scenario 3 McGuire 2014 NRC Scenario #3 The plant is at 40% power (BOL). The area has experienced severe weather over the last 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and this is expected to continue for the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The crew will be directed to raise power to 100% on this shift.

The following equipment is Out-Of-Service: Pzr PORV 1 NC-32B has been isolated (per AP-1 1) due PORV leakage. ACTION has been taken in accordance with Technical Specification LCO 3.4.11 ACTION A. OKRP-5040, KR tank Level, failed last shift (IAE is investigating) and MCB Annunciator lAD-il, E-2, SEQB LOSS OF CONTROL PWR, spuriously alarmed several times during the shift (IAE is investigating).

Shortly after taking the watch, the operator will commence a load increase to 100% starting with Step 3.35.14 of Enclosure 4.1, Power Increase, of OP/1/A16100/003, Controlling Procedure for Unit Operation. The operator will dilute the NC System Boron concentration in accordance with .4, Alternate Dilute, of OP/1/A161 50/009, Boron Concentration Control, and raise Turbine load in accordance with OP/1/A/6300/001 A, Turbine-Generator Load Change.

During the power increase, Pzr PORV 1NC34A will fail partially OPEN, and fail in this position.

The operator will respond in accordance with AP/1/A/5500/1 1, Pressurizer Pressure Anomalies. The operator will ultimately close the Block Valve for Pressurizer PORV 1 NC34A when it is determined that the PORV cannot be closed. The operator will address Technical Specification LCO 3.4.1, RCS Pressure, Temperature and Flow Departure From Nucleate Boiling (DNB) Limits, and LCO 3.4.11, Pressurizer Power Operated Relief Valves (PORVS).

Next, the 1 B Steam Generator PORV will fail OPEN. The operator will respond in accordance with AP/1/A/5500/01, Steam Leak, and isolate the PORV. The operator will address Technical Specification LCO 3.7.4, Steam Generator Power Operated Relief Valves (SG PORVs), and will determine that the required number of SG PORVs are OPERABLE for current plant conditions; and may enter LCO 3.4.1, RCS Pressure, Temperature and Flow Departure from Nucleate Boiling (DNB) Limits.

Subsequently, a 90 gpm Steam Generator Tube Leak will occur (over 10 minutes) on the lB Steam Generator. The operator will enter AP/1/A15500/10, NC System Leakage Within the Capacity of Both NV Pumps. The operator will address Technical Specification LCO 3.4.13, RCS Operational Leakage, and SLC 16.9.7, Standby Shutdown System. The crew will be directed by AP/1/AJ5500/10 to reduce plant power to Mode 3 within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months . The operator will perform a rapid downpower in accordance with AP/1/A15500/04, Rapid Downpower.

During the downpower, the Control Rods will continuously insert. The operator will enter AP/l/A15500/14, Rod Control Malfunction, and take manual control of the rods.

After this, the leak will develop into a 500 gpm Steam Generator Tube Rupture and the operator will enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection. Upon completion of E-0, the operator will transition to EP/1/A15000/E-3, Steam Generator Tube Rupture, to isolate the flow into and out of the 1 B Steam Generator and then conduct a cooldown of the NC System. While performing an NCS cooldown the C-9 Interlock will fail and result in a loss of the steam dumps.

The operator will be required to re-initiate the cooldown using the available SG PORVs. During the NCS depressurization, the Pzr Spray Valves will fail to open. The operator will be required to conduct the depressurization using the last available Pzr PORV.

Scenario Event Description NRC Scenario 3 The scenario will terminate at Step 22.c of E-3, after the crew has closed the Cold Leg Isolation Valves from the NV System.

Critical Tasks:

E-3A (E-3A) Isolate feedwater flow into and steam flow from the ruptured SG so that minimum AP between ruptured Steam Generator and intact Steam Generators is not less than 250 psid once target temperature is reached (Entry into ECA-3.1).

Safety Significance: Failure to isolate the ruptured SG causes a loss of AP between the ruptured SG and the intact SGs. Upon a loss of AP, the crew must transition to a contingency procedure that constitutes an incorrect performance that necessitates the crew taking compensating action which complicates the event mitigation strategy. If the crew fails to isolate steam from the SG, or feed flow into the SG the ruptured SG pressure will tend to decrease to the same pressures as the intact SG5, requiring a transition to a contingency procedure, and delaying the stopping of RCS leakage into the SG.

E-3C Depressurize the NCS to meet SI termination criteria before the Quality of the steam exiting the SG exceeds 80% (0.8 on Void Fraction SGINFO.cts).

Safety Significance: Failure to stop the reactor coolant leakage into a ruptured SG by depressurizing the RCS (when it is possible to do so) needlessly complicates the mitigation of the event. It also constitutes a significant reduction of Safety Margin beyond that irreparably introduced by the scenario. If RCS depressurization does NOT occur, the inventory in the secondary side of the ruptured SG will rise to the level of the Main Steam Lines leading to water release through the SG PORV or Safety Valve, which could cause and unisolable fault in the ruptured SG.

Scenario Event Description NRC Scenario 3 SIMULATOR OPERATOR INSTRUCTIONS Bench Mark ACTIVITY DESCRIPTION Q Sim. Setup Rod Step On Reset to Temp IC 242 T 0 Malfunctions (From IC-18):

Q (Originally IC-18).

=

Place INC3IB to CLOSE; (Pzr PORV INC-32B is OOS) insert XMT-KR_OKRP_5040 = 0 (OKRP-5040, KR Tank Level is OOS) insert OVR-1ADII_E02 = OFF (MCB Annunciator IADIIIE2)

From IC-242:

T0 MAL-IPEOO4H = True (C-9 fails),

cdH_X01_0942 I (IA RTB Open indicating lamp ON)

REM-NCOO27C 0 (A Spray Valve fails closed)

REM-NCOO29C 0 (B Spray Valve fails closed) cdH_X0I_094_2 = I (IA RTB Open indicating lamp ON)

RUN Place Tagout/O-Stick on:

Q I NC-32B (Tagout)

Reset all SLIMs OKRP-5040 (0-stick)

MCB Annunciator lAD-Il, E-2 (0-stick)

Update Status Board, NOTE: RMWST DO <1000 ppb.

Q =

Setup OAC Q Freeze.

Q Update Fresh Tech.

Spec. Log.

Scenario Event Description NRC Scenario 3 Bench Mark ACTIVITY DESCRIPTION Q Fill out the AOs Available section of Shift Turnover Info.

Q Prior to Crew RUN Briefing Q Crew Briefing

1. Assign Crew Positions based on evaluation requirements

2. Review the Shift Turnover Information with the crew.

3. Provide crew with Reactivity Plan associated with power increase.

4. Provide Enclosure 4.1 of OPI1/A161001003 marked up as follows:

Step 2.3 initialed.

Note prior to Step 3.1 checked.

Step 3.1 Checkbox is checked.

Step 3.2 initialed.

Step 3.3 initialed.

Step 3.3.1 Checkbox is checked.

Step 3.3.2 Checkbox is checked, Step 3.35.14 is entered.

Step 3.3.3 Checkbox is checked.

Step 3.3.4 Initialed.

Step 3.35 circled.

Step 3.35.1 Checkbox is checked.

Note prior to Step3.35.2 is checked.

Step 3.35.2 Checkbox is checked.

Step 3.35.3 is NA.

Step 3.35.4 is initialed (Person Notified/Todays time and date filled in).

Step 3.35.5 is circled.

Step 3.35.6 is initialed (Person Notified/Todays time and date filled in).

Step 3.35.7 Checkbox is checked.

Step 3.35.8 Checkbox is checked.

Step 3.35.9 Checkbox is checked.

Step 3.35.10 Checkbox is checked.

Step 3.35.11 All four Bullets are initialed.

Step 3.35.12.1 Initialed. All three Checkboxes are Checked.

Step 3.35.12.2 Checkbox is checked.

Note prior to Step 3.35.13 is checked.

Step 3.35.13 is initialed.

5. Direct the crew to Review the Control Boards taking note of present conditions, alarms.

Scenario Event Description NRC Scenario 3 Bench Mark ACTIVITY DESCRIPTION Q T-O Begin Familiarization Period Q At direction of Execute Lesson Plan examiner for Simulator Scenario N14-1-3.

Q At direction of Event I Power Increase examiner Q At direction of Event 2 Pzr PORV 1 NC34A fails partially OPEN examiner insertMAL NCNCOO3B3O NOTE: insert LOA-NCO34A = RACKED_OUT insertMAL-NCOI2B = when directed.

25 Q At direction of Event 3 SG 1 B PORV fails OPEN examiner insert MAL-SMOOIB 100 rampl0 Q At direction of Event 4 Steam Generator Tube Leak examiner insert MAL-SGOOIB =

90 ram p600 Q Upon Crew Event 5 Continuous inward Rod Motion Entry into AP4 insertMAL-IREOO3A = NOTE: If needed (i.e. No current Rod Demand)

IN insertMAL-DCSI2I3 =TRUE Q At direction of Event 6 1 B Steam Generator Tube Rupture examiner insert MAL-SGOOIB NOTE: insertLOA-RN087 =ON and LOA-RN083 500 rampl2O = 8000 when directed.

NOTE: insertREM-SA0002 =0 and REM-00078 =

0 when directed.

Q Post-Rx Trip Event 7 Failure of the C-9 Interlock durhigNCS InsertMAL-IPEOO4H = NOTE: This event will occur on Rx Trip True (C-9 fails),

cdH_X01_094_2 = I (IA RTB Open indicating lamp ON)

Scenario Event Description NRC Scenario 3 Bench Mark ACTIVITY DESCRIPTION fl Post-Rx Trip Event 8 Pzr Spray Valves fail to OPEN insertREM-NCOO27C = NOTE: This event will occur on Rx Trip depress.

O(ASprayValvefails closed) insertREM-NCOO29C =

O(BSprayValvefails closed) cdH_XO1_094_2 I (IA RTB Open indicating lamp ON)

Q Terminate the scenario upon direction of Lead Examiner Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 1 Page 9 of 66 Event

Description:

Power Increase Shortly after taking the watch, the operator will commence a load increase to 100%

starting with Step 3.35.14 of Enclosure 4.1, Power Increase, of OPI1IAI6100/003, Controlling Procedure for Unit Operation. The operator will dilute the NC System Boron concentration in accordance with Enclosure 4.4, Alternate Dilute, of OP/1/A16150/009, Boron Concentration Control, and raise Turbine load in accordance with OP/1/A16300/001 A, Turbine-Generator Load Change.

Booth Operator Instructions: NA Indications Available: NA OPIIIAI6IOOIOO3, CONTROLLING PROCEDURE FOR UNIT OPERATIONS ENCLOSURE 4.1, POWER INCREASE CRS (Step 3.35) Increase power to 50% RTP. NOTE: The power increase will be at 2 Mwe/minute.

ROl (Step 3.35.14) WHEN Turbine load greater that 40% (360 psig Turbine Inlet Pressure)

BOP begin aligning MSRs per OP/i 11250/011 (Moisture Separator Reheater Operation).

OP!11A161501009, BORON CONCENTRATION CONTROL ENCLOSURE 4.4, ALTERNATE DILUTE BOP (Step 3.6) Determine amount of reactor NOTE: The BOP may repeat makeup water needed to obtain desired this task as needed during the boron concentration using McGuire Data power increase.

Book, OAC, Reactor Group Guidance, or plant parameters (T-Ave, Steam Pressure, Xenon worth, etc.). (R.M.)

. Total Reactor Makeup Water:

BOP (Step 3.7) Ensure the following reset to zero:

(R.M.)

. Total Make Up Flow Counter

. Boric Acid Flow Counter

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 1 Page 10 of 66 Event

Description:

Power Increase BOP (Step 3.8) Set Total Make Up Flow Counter to value determined in Step 3.6. (R.M.)

BOP (Step 3.9) Select ALTERNATE DILUTE on NC Sys M/U Controller.

BOP (Step 3.10) IF desired to makeup only through 1 NV-i 75A (Ui Boric Acid Blender To VCT Outlet Control), select CLOSED on 1 NV-i 71 A (Ui Boric Acid Blender to VCT Inlet Control).

BOP (Step 3.1 1) IF AT ANY TIME it is desired to NOTE: It is NOT desired to adjust reactor makeup water flow, adjust Rx adjust reactor makeup water M/U Water Flow Control setpoint to achieve flow.

desired flowrate.

BOP (Step 3.12) IF AT ANY TIME it is desired to manually adjust reactor makeup water flow, perform the following:

(Step 3.12.1) Place Rx M/U Water Flow Control in manual.

(Step 3.12.2) Adjust Rx M/U Water Flow Control output to control reactor makeup water flowrate.

BOP (Step 3.13) IF AT ANY TIME it is desired to lower VCT level, perform the following:

(Step 3.13.1) Monitor Letdown Pressure.

(Step 3.13.2) Select HUT on 1NV-i37A (Ui NOTE: The BOP may do this NC Filters OtIt to VCT 3-Way Diversion at any time to lower VCT level.

Contrl).

(Step 3.1 3.3) IF Letdown Pressure increases greater than 20 psig, notify CRS.

(Step 3.13.4) AFTER desired level achieved, select AUTO on iNV-i37A (Ui NC Filters OtIt to VCT 3-Way Diversion Cntrl).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 1 Page 11 of 66 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments BOP (Step 3.14) IF AT ANY TIME plant parameters require termination of dilution, perform the following:

(Step 3.14.1) Place NC System Make Up to STOP. (R.M.)

(Step 3.14.2) IF 1NV-137A (Ui NC Filters OtIt to VCT 3-Way Diversion Cntrl) was placed to HUT, place to AUTO.

BOP (Step 3.15) Momentarily select START on NC System Make Up. (R.M.)

BOP (Step 3.16) Check NC System Make Up red light lit.

BOP (Step 3.17) Check 1NV-175A (Ui Boric Acid Blender To VCT Outlet Control) open.

BOP (Step 3.18) Check 1NV-252A (Rx M/U Water Supply To Ui BA Blender Cntrl) open or throttled as required.

BOP (Step 3.19) IF 1NV-171A(U1 Boric Acid NOTE: 1NV-171A is NOT in Blender To VCT Inlet Control) in AUTO, AUTO.

check 1NV-171A (Ui Boric Acid Blender to VCT Inlet Control) open.

BOP (Step 3.20) Check Rx M/U Water Pump starts.

BOP (Step 3.21) Monitor Total Make Up Flow Counter. (R.M.)

BOP (Step 3.22) HOLD until one of the following occurs:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 1 Page 12 of 66 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments

. Amount of reactor makeup water recorded per Step 3.6 added OR

. Reactor makeup water addition manually terminated BOP (Step 3.23) Ensure dilution terminated as follows: (R.M.)

(Step 3.23.1) IF in AUTO, ensure the following off:

. 1A Rx M/U Water Pump

. lB Rx M/U Water Pump BOP (Step 3.23.2) Ensure the following closed:

. 1 NV-i 75A (Ui Boric Acid Blender To VCT Outlet Control)

. 1 NV-252A (RX M/U Water Supply To Ui BA Blender Cntrl)

. 1NV-171A(Ui Boric Acid BlenderTo VCT Inlet Control)

BOP (Step 3.24) Ensure 1NV-171A(Ui Boric Acid Blender to VCT Inlet Control) in AUTO.

BOP (Step 3.25) Ensure Rx M/U Water Flow Control in AUTO. (R.M.)

BOP (Step 3.26) IF Rx M.U Water Flow Control NOTE: The Rx M.U Water adjusted per Step 3.1 1 ... Flow Control was NOT adjusted.

BOP (Step 3.27) Ensure 1NV-137A (Ui NC Filters OtIt to VCT 3-Way Diversion Cntrl) in AUTO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 1 Page 13 of 66 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments BOP (Step 3.28) IF desired to flush blender.... NOTE: It is NOT desired to flush the blender.

BOP (Step 3.29) Select AUTO for NC Sys M!U Controller.

BOP (Step 3.30) Momentarily select START on NC System Make Up.

BOP (Step 3.31) Check NC System Make Up red light lit.

BOP (Step 3.32) Ensure the following reset to zero: (R.M.)

. Total Make Up Flow Counter

. Boric Acid Flow Counter BOP (Step 3.33) Record in Auto Log that final blender content is Rx Makeup Water.

0P111A163001001 A, TURBINE-GEN ERATOR STARTUPISHUTDOWN ENCLOSURE 4.1, TURBINE-GENERATOR LOAD CHANGE RO (Step 3.5) Changing Turbine Load (Step 3.5.1) IF Turbine in OPERATOR AUTO, perform the following:

(Step 3.5.1.1) Ensure desired change within Calculated Capability Curve.

(Step 3.5.1.2) IF turbine load will increase or decrease more than 10 MWs, notify Dispatcher of expected load change.

(Step 3.5.1 .3)_Depress LOAD RATE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 1 Page 14 of 66 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments (Step 3.5.1.4) Enter desired load rate in NOTE: the RO will select 2 VARIABLE DISPLAY. Mwe/Min loading rate.

(Step 3.5.1.5) Depress ENTER.

(Step 3.5.1.6) Depress REFERENCE.

(Step 3.5.1.7) Enter desired load in VARIABLE DISPLAY.

(Step 3.5.1 .8) Depress ENTER.

(Step 3.5.1.9) Depress GO (Step 3.5.1.10) Check load changes at selected rate.

0P111A161001003, CONTROLLING PROCEDURE FOR UNIT OPERATIONS ENCLOSURE 4.1, POWER INCREASE RO! (Step 3.35.15) WHEN Turbine Inlet Pressure NOTE: Based on the extent of 365 367 psig, check AMSAC ACTUATION the power increase, this action BOP BLOCK/UNBLOCK as follows: may or may not be taken.

. IF UNBLOCK dark, reset as follows:

. Check all AMSAC SIG LOW FLOW status lights dark.

. Check S/G PATH CLSD>30 SEC dark.

. Depress UNBLOCK for AMSAC ACTUATION BLOCK/UNBLOCK.

. Check UNBLOCK lit.

At the discretion of the Lead Examiner move to Event #2.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 2 Page 15 of 66 Event

Description:

Pzr PORV I NC34A fails partially OPEN During the power increase, Pzr PORV 1NC34A will fail partially OPEN, and fail in this position. The operator will respond in accordance with AP/1/A15500/11, Pressurizer Pressure Anomalies. The operator will ultimately close the Block Valve for Pressurizer PORV 1NC34A when it is determined that the PORV cannot be closed. The operator will address Technical Specification LCO 3.4.1, RCS Pressure, Temperature and Flow Departure From Nucleate Boiling (DNB) Limits, and LCO 3.4.11, Pressurizer Power Operated Relief Valves (PORVS).

Booth Operator Instructions: insert MAL-NC0O3B = 30 (PZR PORV I NC-34A fails OPEN)

Insert MAL-NCOI2B 25 (PZR PORV INC-34A sticks OPEN on CLOSE)

Indications Available:

OAC Alarm: Ui PZR PRESS I through IV

1 NC-34A dual status light indication (Red and Green status lights LIT)

MCB Annunciator 1AD-61B-9 PZR PORV DISCH TEMP HI

MCB Annunciator 1AD-61C-6 PZR LO PRESS CONTROL

Pzr Pressure is lowering NOTE: It is likely that the operator will take actions to isolate the Pzr PORV prior to being directed by the CRS.

APIIIAI5500III, PRESSURIZER PRESSURE ANOMALIES BOP (Step 1) Check Pzr pressure HAS GONE Immediate Action DOWN.

BOP (Step 2) Check Pzr PORVs CLOSED. Immediate Action BOP (Step 2 RNO) Perform the following: Immediate Action

CLOSE PORVs. NOTE: 1 NC-34A will display dual indication, even after closing the PORV.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 2 Page 16 of 66 Event

Description:

Pzr PORV I NC34A fails partially OPEN

. IF PORV will not close, THEN CLOSE PORV isolation valve.

BOP (Step 3) Check Pzr spray valves CLOSED. Immediate Action BOP (Step 4) Check Pzr PORVs CLOSED.

BOP (Step 4 RNO) Perform the following:

. CLOSE associated PORV inlet drain valve as follows:

. IF 1 NC-34A (PZR PORV) failed, NOTE: 1 NC-34A has failed THEN CLOSE 1 NC-270 (PZR PORV OPEN.

Drn Isol For 1NC-34A).

CRS . IF Pzr PORV isolation valve is closed for failed Pzr PORV, THEN GO TO Step 5.

BOP (Step 5) Check Pzr spray valves CLOSED.

CRS (Step 6) Announce occurrence on page. NOTE: CRS may ask U2 RO to make Plant Announcement that AP-1 1 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 7) Check 1NV-21A (NV Spray To PZR Isol) CLOSED.

BOP (Step 8) Check the following Pzr heaters ON:

. 1A

. lB

. 1D

Appendix D Operator Action Form ES-D-2 OpTestNo.: N14-1 Scenario# 3 Event# 2 Page 17 of 66 Event

Description:

Pzr PORV I NC34A fails partially OPEN BOP (Step 9) Check 1C Pzr heaters ON.

BOP (Step 10) Check PZR PRESS MASTER IN AUTO.

BOP (Step 11) Check 1 NC-27 PRESSURIZER SPRAY EMERGENCY CLOSE switch SELECTED TO NORMAL.

BOP (Step 12) Check 1NC-29 PRESSURIZER SPRAY EMERGENCY CLOSE switch S ELECTED TO NORMAL.

BOP (Step 13) Check Pzr pressure GOING UP TO DESIRED PRESSURE.

CRS (Step 14) Exit this procedure. NOTE: The CRS may call WCC/IAE to address the valve position.

If so, Booth Instructor acknowledge as WCC.

Booth Instructor: insert LOA-NC034 = Racked Out, delay = 10 minutes.

As AO call and report.

NOTE: The CRS will likely conduct a Focus Brief.

TECHNICAL SPECIFICATION 3.4.11, PRESSURIZER POWER OPERATED RELIEF VALVES (PORVs)

CRS LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 2 Page 18 of 66 Event

Description:

Pzr PORV INC34A fails partially OPEN CRS APPLICABILITY: MODES 1, 2 AND 3.

CRS ACTIONS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTION 8.1, B. One or two B.1 Close 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 8.2 and B.3 must be entered.

PORVs associated inoperable block valves.

and not capable of AND being B.2 Remove 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months manually power from cycled. associated block valves.

AND B.3 Restore one 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months PORVto OPERABLE status if two PORVs are inoperable.

TECHNICAL SPECIFICATION 3.4.1, RCS PRESSURE, TEMPERATURE, AND FLOW DEPARTURE FROM NUCLEATE BOILING (DNB) LIMITS CRS LCO 3.4.1 RCS DNB parameters for NOTE: If NC System Pressure pressurizer pressure, RCS average drops to < 2216 psig on the temperature, and RCS total flow rate shall be failure, then TS 3.4.1 might be within the limits specified in Table 3.4.1-1. entered and exited during the transient.

CRS APPLICABILITY: MODE 1.

CRS ACTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 2 Page 19 of 66 Event

Description:

Pzr PORV I NC34A fails partially OPEN CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTION A.1 A. Pressurizer A.1 Restore DNB 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months must be entered (May be pressure or parameter(s) cleared by the time that the RCS average to within limit, determination is made).

temperature DNB parameters not within limits.

At the discretion of the Lead Examiner move to Event #3.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 3 Page 20 of 66 Event

Description:

SG lB PORV fails OPEN Next, the 18 Steam Generator PORV will fail OPEN. The operator will respond in accordance with API1IAI5500IO1, Steam Leak, and isolate the PORV. The operator will address Technical Specification LCO 3.7.4, Steam Generator Power Operated Relief Valves (SG PORVs), and will determine that the required number of SG PORVs are OPERABLE for current plant conditions; and may enter LCO 3.4.1, RCS Pressure, Temperature and Flow Departure from Nucleate Boiling (DNB) Limits.

Booth Operator Instructions: insert MAL-SMOOIB 100 delayo ramplo (SIG PORV ISVI3 SGB fails OPEN)

Indications Available:

iSV-i 3AB Red status light LIT

iSV-i 3AB Black needle indication at 100%

OAC Alarm: TM FREEZE M1D3499-VLVSV13B SM PORV

OAC Alarm: Ui SV-PORV/SAFETY VLV OPEN -T/D CA PMP ON

OAC Alarm: 1SV-13AB lB SM PORV

Core Ts rising

Rx Power rising

Steam flow on 1 B steam line rising Time Pos. Expected ActionslBehavior Comments NOTE: It is likely that the operator will take actions to isolate the 1 B SG PORV prior to being directed by the CRS.

(Step 13)

CONTROL ROOM CREW EXPECTATIONS MANUAL RO Transient load changes: Manual is preferred NOTE: The crew may immediately reduce 2OMwe and then diagnose an overpower reduce as needed to maintain Rx power less condition and adjust turbine than pre-transient condition. After the initial load per the Crew Expectation 20 Mwe load reduction, it is preferred that the Manual.

operators use multiple and diverse indications to determine how much more load should be reduced.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 3 Page 21 of 66 Event

Description:

SO lB PORV fails OPEN Time Pos. Expected ActionslBehavior Comments APIIIAJ5500IOI, STEAM LEAK CRS (Step 1) Monitor Foldout page. NOTE: Manual Reactor Trip Criteria is NOT expected to be utilized.

RO (Step 2) Reduce turbine load to maintain the following:

. Excore Nis LESS THAN OR EQUAL TO 100%.

. NC Loop D/Ts LESS THAN 60°F DJT

. T-AvgATT-REF.

CRS (Step 3) Check containment entry IN NOTE: A Containment Entry is PROGRESS. NOT in progress.

CRS (Step 3 RNO) GO TO Step 5.

BOP (Step 5) Check Pzr pressure prior to event GREATER THAN P-il (1955 PSIG).

BOP (Step 6) Check Pzr level STABLE OR GOING UP.

BOP (Step 7) IF AT ANY TIME while in this NOTE: This is a Continuous procedure Pzr level cannot be maintained Action. The CRS will make stable, THEN RETURN TO Step 6. both board operators aware.

CRS (Step 8) GO TO Step 12.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 3 Page 22 of 66 Event

Description:

SG I B PORV fails OPEN Time Pos. Expected ActionslBehavior Comments CRS (Step 12) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement that AP-1 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 13) Identify and isolate leak on Unit 1 as follows:

. (Step 13a) Check SM PORVs NOTE: The lB SG PORV is CLOSED. Open.

RO (Step 13a RNO) IF SIG pressure is less than 1092 PSIG, THEN perform the following:

. Close affected SIG SM PORV manual NOTE: Closing the Manual loader. Loader will have no effect.

IF SM PORV is still open, THEN perform NOTE: The lB SG PORV the following: Isolation Valve will need to be closed.

Close SM PORV isolation valve.

IF SM PORV isolation valve still NOTE: The PORV Isolation open valve is closed.

RO * (Step 13.b) Check condenser dump valves CLOSED.

BOP * (Step 1 3.c) Check containment conditions NORMAL:

Containment temperature

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 3 Page 23 of 66 Event

Description:

SG lB PORV fails OPEN Time Pos Expected ActionslBehavior Comments

. Containment pressure

. Containment humidity

. Containment floor and equipment sump level.

RO I * (Step 1 3.d) Check TD CA pump OFF.

BOP BOP * (Step 1 3.e) Check valves on STEAM NOTE: One or more of these LINE DRAIN VALVES board (1 MC-9) valves may be cycling. The CLOSED. RNO will direct closing the valves.

CRS * (Step 1 3.f) Check opposite Unit (Unit 2) NOTE: CRS may ask U2 RO STEAM HEADER PRESSURE for AS Header pressure.

GREATER THAN 200 PS 1G. If so, Floor Instructor report as U2 RO that U2 Steam Header pressure is 1OOO psig.

CRS * (Step 1 3.g) Dispatch operator to check NOTE: The CRS may dispatch for leaks. an AO to look for leaks.

If so, Floor Instructor:

acknowledge.

Booth Instructor: Report back in 3-5 minutes that there are no leaks.

NOTE: The CRS may NOT dispatch AOs to look for leaks because it is understood that the SM PORV opening was the reason that AP-1 was entered.

BOP (Step 14) Check UST level STABLE OR GOING UP.

CRS (Step 15) Evaluate unit shutdown as follows:

Check unit status IN MODE 1 OR 2.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 3 Page 24 of 66 Event

Description:

SG lB PORV fails OPEN Time Pos. Expected ActionsIBehavior Comments

. Determine if unit shutdown or load NOTE: CRS may call reduction is warranted based on the WCC/Management to address following criteria: the startup.

If so, Booth Instructor acknowledge as WCC.

. Size of leak

. Location of leak

. Rate of depletion of secondary inventory

. IF steam is leaking from a secondary heater relief OR MSR relief valve...

. IF turbine trip will isolate steam leak (such as feedwater heater leak or MSR leak...

. Check unit shutdown or load reduction NOTE: Shutdown/Load REQUIRED, Reduction will NOT be required.

CRS (Step 1 5.c RNO) Perform the following:

. Maintain present plant conditions until leak can be isolated or repaired.

. Exit this procedure.

NOTE: The CRS will likely conduct a Focus Brief.

NOTE: The CRS may address Tech Specs based on plant response.

TECHNICAL SPECIFICATION 3.7.4, STEAM GENERATOR POWER OPERATED RELIEF VALVES (SG PORVs)

CRS LCO 3.7.4 Three SG PORV lines shall be OPERABLE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 3 Page 25 of 66 Event

Description:

SG lB PORV fails OPEN Time Pos. Expected ActionslBehavior Comments CRS APPLICABILITY: MODES 1, 2, and 3, MODE NOTE: After evaluation, the 4 when steam generator is relied upon for CRS will determine that iSV-heat removal. 13AB is inoperable, however, the remaining three SG PORVs are OPERABLE and that LCO 3.7.4 is NOT entered.

TECHNICAL SPECIFICATION 3.4.1, RCS PRESSURE, TEMPERATURE, AND FLOW DEPARTURE FROM NUCLEATE BOILING (DNB) LIMITS CRS LCO 3.4.1 RCS DNB parameters for NOTE: If NC System Pressure pressurizer pressure, RCS average drops to < 2216 psig on the temperature, and RCS total flow rate shall be failure, then TS 3.4.1 might be within the limits specified in Table 3.4.1-1. entered and exited during the transient.

CRS APPLICABILITY: MODE 1.

CRS ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME A. Pressurizer A.1 Restore DNB 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months NOTE: The CRS py pressure or parameter(s) determine that ACTION A.1 RCS average to within limit.

tern perature must be entered.

DNB parameters not within limits.

At the discretion of the Lead Examiner move to Event #4.

Appendix D Operator Action Form ES-D-2 OpTestNo.: N14-1 Scenario# 3 Event# 4 Page 26 of 66 Event

Description:

Steam Generator Tube Leak Subsequently, a 90 gpm Steam Generator Tube Leak will occur (over 10 minutes) on the lB Steam Generator. The operator will enter API1IAI5500I1O, NC System Leakage Within the Capacity of Both NV Pumps. The operator will address Technical Specification LCO 3.4.13, RCS Operational Leakage, and SLC 16.9.7, Standby Shutdown System. The crew will be directed by API1IAI5500I1O to reduce plant power to Mode 3 within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months . The operator will perform a rapid downpower in accordance with AP/11A15500/04, Rapid Downpower.

Booth Operator Instructions: insert MAL-SGOOIB 90 delay0 ramp600 (SIG lB Tube Leak)

Indications Available:

. Pzr level is lowering

. Charging starts to rise

. MCB Annunciator 1AD-6/E-7, PZR LO LEVEL DEVIATION

. Trip 1 on EMF 72 APIIIAI5500IIO, NC SYSTEM LEAKAGE WITHIN THE CAPACITY OF BOTH NV PUMPS CASE I, STEAM GENERATOR TUBE LEAKAGE BOP (Step 1) Check Pzr level STABLE OR NOTE: Pzr Level will be slowly GOING UP. lowering.

BOP (Step 1 RNO) Perform the following as required to maintain level:

. Maintain charging flow less than 200 GPM at all times in subsequent steps.

. Ensure 1NV-238 (Ui Charging Hdr NOTE: The BOP may take Control) OPENING.

manual control of 1NV-238.

. OPEN 1NV-241 (Ui Seal Water Inj Flow Control) while maintaining NC pump seal flow greater than 6 GPM.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 27 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expected Actions/Behavior Comments

. Reduce or isolate letdown. NOTE: The BOP may reduce letdown flow to 45 gpm, or isolate it altogether.

. Start additional NV pump. NOTE: The BOP will NOT need to start an additional NV Pump.

. IF CLAs are isolated NOTE: The CLAs are NOT isolated.

. IF Pzr level cannot be maintained greater NOTE: The Pzr level is NOT <

than 4% 4%, or decreasing with maximum Charging flow.

RO! (Step 2) IF AT ANY TIME Pzr level goes NOTE: This is a Continuous BOP down in an uncontrolled manner OR cannot Action. The CRS will make be maintained greater than 4%, THEN both board operators aware.

perform Step 1.

RO! (Step 3) Identify affected SIG as follows:

. Any S/G N/R level GOING UP IN AN UNCONTROLLED MANNER.

. Check any of the following EMFs ABOVE NORMAL:

. 1 EMF-24 (S/G A Steamline Hi Rad)

. 1EMF-25 (S/G B Steamline Hi Rad)

. 1 EMF-26 (SIG C Steam line Hi Rad)

. 1EMF-27 (SIG D Steamline Hi Rad)

. 1 EMF-71 (S/G A Leakage Hi Rad)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 28 of 66 Event

Description:

Steam Generator Tube Leak Time Pos Expected ActionslBehavior Comments

. 1 EMF-72 (S/G B Leakage Hi Rad) NOTE: This rad monitor will be rising, and could be in either Trip 1 or TRIP 2.

. 1 EMF-73 (SIG C Leakage Hi Rad)

. 1 EMF-74 (SIG D Leakage Hi Rad)

. Check CF Flow LOWER IN ANY SIC COMPARED TO ALL.

CRS (Step 4) Announce occurrence on page. NOTE: The CRS may ask U2 RO to make Plant Announcement that AP-1 0 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

CRS (Step 5) REFER TO the following: NOTE: The CRS may ask OSM to address.

If so, Floor Instructor acknowledge as OSM.

. RP/0/A157001000 (Classification of Emergency)

RPIO/A15700!010 (NRC Immediate Notification Requirements).

CRS (Step 6) IF AT ANY TIME NC leakage NOTE: The CRS will exceeds Tech Spec limits, THEN perform the determine that Leakage has following: exceeded the TS Limits.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 29 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expected ActionslBehavior Comments Ensure Outside Air Pressure Filter train NOTE: The CRS may ask U2 in service PER OP/OIA/6450!O1 1 BOP to take this action.

(Control Area Ventilation/Chilled Water If so, Floor Instructor System), Enclosure 4.4 (Control Room acknowledge as U2 BOP, and Atmosphere Pressurization During perform actions.

Abnormal Conditions).

Have another SRO evaluate if leakage NOTE: The CRS may ask exceeds SLC 16.9.7 condition C limits OSM, STA, or Plant SRO to and immediately notify security if SSF is perform this action.

inoperable. If so, Floor Instructor acknowledge accordingly.

NOTE: The CRS may assign the BOP to perform this action.

If so, BOP Examiner follow actions of Enclosure 4.4.

Other Examiners follow AP 10 Actions, Step 7, on Page 31.

0111450111, CONTROL AREA VENTILATIONICHILLED WATER SYSTEM ENCLOSURE 44, CONTROL ROOM ATMOSPHERE PRESSURIZATION DURING ABNORMAL CONDITIONS (Step 3.1) Evaluate all outstanding R&Rs that may impact performance of this procedure.

(Step 3.2) Pressurize Control Room using Outside Air Pressure Fans as follows:

(Step 3.2.1) Ensure at least one of the following groups of intake valves open:

. 1VC-1A (VC Otsd Air Intake Isol from Unit 1)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 30 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expected Actions/Behavior Comments

. 1VC-2A (VC Otsd Air Intake Isol from Unit 1)

. 1VC-3B (VC Otsd Air Intake Isol from Unit 1)

. 1VC-4B (VC Otsd Air Intake Isol from Unit 1)

. 1VC-9A (VC Otsd Air Intake Isol from Unit 2)

. 1VC-1OA (VC Otsd Air Intake Isol from Unit 2)

. 1VC-11B (VC Otsd Air Intake Isol from Unit 2)

. 1VC-12B (VC Otsd Air Intake Isol from Unit 2)

(Step 3.2.2) IF A Train VC/YC operating, place A Train CR Outside Air Press Fan to (Step 3.2.3) IF B Train VC/YC operating, place B Train CR Outside Air Press Fan to 0 N.

(Step 3.2.4) Depress MAN for the following (to ensure fans off):

. #1 CRA Otsd Air Fan

. #2 CRA Otsd Air Fan (Step 3.2.5) Depress OFF for the following:

. CRA-OAD-4 (CR Area Otsd Air Fans Damper)

. CRA-OAD-3 (CR Area Otsd Air Fans Dam per)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 31 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expected ActionslBehavior Comments (Step 3.2.6) Check the following dark:

. CRA-OAD-4 (CR Area Otsd Air Fans Damper) OPEN light.

. CRA-OAD-3 (CR Area Otsd Air Fans Damper) OPEN light.

APII/A15500!1O, NC SYSTEM LEAKAGE WITHIN THE CAPACITY OF BOTH NV PUMPS CASE I, STEAM GENERATOR TUBE LEAKAGE Examiner NOTE: Examiners following the CRSIRO continue HERE.

BOP (Step 7) Check if unit shutdown or reactor trip required as follows:

. Check VCT makeup IN PROGRESS. NOTE: A VCT makeup may be in progress.

. Check VCT level - GOING UP.

Check 5/G tube leak size LESS THAN NOTE: The CRS will 90 GPM. determine the SGTL to be about 70-90 gpm.

Leakage in one S/G GREATER THAN 125 GPD (GALLON PER DAY).

Observe the following limits while reducing load in Step 8:

Ensure reactor power is less than 50% within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months of exceeding 125 GPD.

Be in Mode 3 within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months of exceeding 125 GPD.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 32 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expected ActionslBehavior Comments CRS (Note prior to Step 8) If load reduction less than 10 MW/mm is planned once below 50%

power, the OP below is the optimal procedure to use. If load reduction greater than or equal to 10 MW/mm all the way to mode 3 is planned, APO4 is the optimal procedure to use. A more rapid shutdown is prudent for lamer leaks.

CRS (Step 8) Reduce load PER one of the following, while continuing with this AP as time allows beginning at Step 9.

CRS . AP/1 /A/5500/04 (Rapid Downpower) NOTE: The CRS will implement AP-4, and may continue with these actions after the down power is started.

(Examiner Move forward to Page 35)

. OP/i /A/6100/003 (Controlling Procedure For Unit Operation). Enclosure 4.2 (Power Reduction).

RO (Step 9) Minimize secondary side NOTE: The following actions contamination as follows: are scripted because as the plant power is reduced, the CRS may continue to perform actions within AP-lO.

Check affected SIG IDENTIFIED.

CLOSE the blowdown throttle control valve for affected SIG.

. 1A: 1BB-123(1AS/G Blowdown Throttle Control)

. 1B: 1BB-124 (lB S/G Blowdown Throttle Control)

. 1C: 1BB-125 (1C S/C Blowdown Throttle Control)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 33 of 66 Event

Description:

Steam Generator Tube Leak

. 1D: 1BB-126 (1D SIG Blowdown Throttle Control)

Perform EP/1/A/5000/G-1 (Generic NOTE: The CRS may ask the Enclosures), Enclosure 15 (Minimizing U2 BOP to perform this action.

Secondary Side Contamination). If so, Floor Instructor:

acknowledge as U2 BOP.

RO (Step 10) Check reactor trip breakers OPEN.

(Step 10 RNO) Do not continue in the procedure until the reactor is tripped PER Step 8.

Examiner NOTE: Based on the transient nature of evaluating this TS, the Examiner may need to question the CRS after the scenario.

TECHNICAL SPECIFICATION 3.4.13, RCS OPERATIONAL LEAKAGE CRS LCO 3.4.13 RCS operational LEAKAGE shall be limited to:

. 389 gallons per day total primary to secondary LEAKAGE through all steam generators (SGs): and

. 135 gallons per day primary to secondary LEAKAGE through any one steam generator (SG)

CRS APPLICABILITY: MODES 1, 2, 3 and 4 CRS ACTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 34 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expec ed Actions/BE taylor Comments CRS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTION B.1 B. Required B.1 Be in MODE 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and B.2 must be entered.

Action and 3.

associated Completion AND Time of B.2 Be in MODE Condition A 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months not met.

OR Pressure boundary LEAKAGE exists.

OR Primary to secondary LEAKAGE not within limits.

SELECTED LICENSEE COMMITMENT 16.9.7, STANDBY SHUTDOWN SYSTEM CRS COMMITMENT The Standby Shutdown System (SSS) shall be operable.

CRS APPLICABILITY: MODES 1, 2, and 3.

CRS REMEDIAL ACTIONS The SRO should ensure that security is notified 10 minutes prior to declaring the SSS inoperable. Immediately upon discovery of the SSS inoperability, Security must be notified to implement compensatory measures within 10 minutes of discovery.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 35 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expec ed Actions/BE iavior Comments CRS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTION C.1 C. Total C.1 Declare the Immediately and C.2 must be entered.

Unidentified Standby LEAKAGE, Makeup Identified Pump LEAKAGE, inoperable.

and reactor coolant pump AND seal leakoff> C.2 Enter 20 gpm. Condition A.

OR Total reactor coolant pump seal leakoff

> 16.3 gpm.

OR Any reactor coolant pump No. 1 seal leakoff> 4.0 gpm.

Simulator Instructor: Insert Event 5 upon crew entering AP-4.

AP111A15500104, RAPID DOWNPOWER ROI (Step 1) Monitor Foldout page.

BOP Uncontrolled Cooldown (If Tavg < 551 F and lowering Not Expected)

Power Factor (Adjust power factor during NOTE: The RO will adjust load reduction to maintain power factor MVARS as needed.

between 0.9 to 1 .0 lagging, using VOLTAGE ADJUST pushbutton)

Manual Rod Control Criteria ( < C-5, Not Expected)

Turbine Shutdown (Turbine Load < 15 MWe Not Expected)

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 36 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expected ActionslBehavior Comments CRS (Step 2) Announce occurrence on page. NOTE: The CRS may ask U2 RO to make Plant Announcement that AP-4 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 3) Check turbine control IN AUTO.

RO (Step 4) Check MW LOOP IN SERVICE.

CRS (Step 5) Check shutdown to Mode 3 DESIRED.

CRS (Step 6) Check if Shutdown Via Reactor Trip from 15% Power appropriate:

. Shutdown Via Reactor Trip from 15% NOTE: It is normal practice to Power DESIRED.

shut down the reactor by driving rods, rather than tripping from 15%.

. At least two CA pumps - FUNCTIONAL CRS (Step 6 RNO) Perform the following:

. IF Mode 3 is time critical AND the reactor will be shutdown by manually inserting control rods, THEN allow an additional 45 minutes to reach Mode 3 once turbine load reduction is complete.

. IF turbine will be shutdown during down power, THEN enter target load of 15 MWE in turbine control panel.

. Observe Note prior to Step 8 and GO TO Step 8.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 37 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expected ActionslBehavior Comments CRS (Step 8) Determine the required power NOTE: The CRS will reduce reduction rate (MW/rn in). load at 1 0-15 MWe/minute.

RO (Step 9) Check control rods IN AUTO.

BOP (Step 10) Notify SOC of load reduction (red Booth Instructor: as SOC, dispatcher phone). acknowledge.

RO (Step 1 1) Initiate turbine load reduction to desired load at desired rate.

BOP (Step 12) Borate NC System as follows:

. Energize all backup Pzr heaters.

Check unit to be shutdown VIA NOTE: It is normal practice to REACTOR TRIP FROM 15% POWER. shut down the reactor by driving rods, rather than tripping from 15%.

CRS (Step 12b. RNO) GO TO Step 12.d.

Determine boration amount based on the following:

Power Reduction Rate (MW/mm)

Present NC System Boron Concentration (ppm)

Total Power change_(%).

NOTE: Based on the rate of load reduction the total boration is 320 gallons.

Check auto or manual rod control AVAILABLE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 38 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expected Actions/Behavior Comments BOP

Perform boration in 4 equal additions during load reduction PER OP/i /A161 50/009 (Boron Concentration Control), Enclosure 4.7 (Boration Using 1 NV-265B (Boric Acid to NV Pumps)).

RO (Step 13) Check control rods MOVING IN AS REQUIRED TO MAINTAIN T-AVG AT T-REF.

RO (Step 14) Display Rod Insertion Limits on OAC by entering turn on code RIL.

RO (Step 15) IF AT ANY TIME CONTROL ROD NOTE: This is a Continuous BANK LO LO LIMIT alarm (1AD-2, B-9) is lit Action. The CRS will make THEN comply with Tech Spec 3.1 .6 (Control both board operators aware.

Bank Insertion Limits):

RO (Step 16) IF AT ANY TIME during procedure NOTE: This is a Continuous C-7A is received, THEN insure Transient Action. The CRS will make Monitor freeze is triggered, both board operators aware.

CRS (Step 17) REFER TO the following:

RP/0/A15700/000 (Classification of Emergency)

RP/0/A/5700/010 (NRC Immediate NOTE: The CRS may ask Notification Requirements). OSM to address.

If so, Floor Instructor acknowledge as OSM.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 4 Page 39 of 66 Event

Description:

Steam Generator Tube Leak Time Pos. Expected ActionslBehavior Comments CRS (Step 18) Notify Reactor Engineer on duty of NOTE: The CRS may call load reduction. WCC/RE to address the switch position.

If so, Booth Instructor acknowledge as WCC/RE as appropriate.

When Rod Control Malfunction is diagnosed move to Event 5.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 5 Page 40 of 66 Event

Description:

Continuous inward Rod Motion During the downpower, the Control Rods will continuously insert. The operator will enter AP111A15500114, Rod Control Malfunction, and take manual control of the rods.

Booth Operator I nstructions: insertMAL-I REOO3A (IN)

NOTE: If needed (i.e. No current Rod Demand) insertMAL-DCSI2I3 =TRUE Indications Available:

. Control Rods are moving inward in AUTO without a proper signal.

Time Pos. Expected ActionslBehavior Comments APII 1A15500114, ROD CONTROL MALFUNCTION RO (Step 1) IF two or more rods are either Immediate Action dropped OR misaligned by greater than 24 NOTE: No Rods have dropped ste s

.. in this event.

RO (Step 2) Place control rods in manual. Immediate Action NOTE: The RO will place the rods in MANUAL.

RO (Step 3) Check rod movement STOPPED. Immediate Action NOTE: When the RO places the Rods to MANUAL, continual inward Rod Motion will stop.

RO (Step 4) Check all rods ALIGNED WITH ASSOCIATED BANK.

RO (Step 5) Check ROD CONTROL URGENT FAILURE alarm (1AD-2, A-b) DARK.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 5 Page 41 of 66 Event

Description:

Continuous inward Rod Motion Time Pos. Expected Actions/Behavior Comments RO (Step 6) Check T-AVG/T-REF FAILURE ROD STOP alarm (1AD-2, 8-7) DARK.

CRS (Step 7) IF this AP entered due to NOTE: The CRS will transition unwarranted rod insertion or withdrawal, to Enclosure 3 of AP-14.

THEN GO TO Enclosure 3 (Response To Continuous Rod Movement).

ROD CONTROL MALFUNCTION ENCLOSURE 3 RESPONSE TO CONTINUOUS ROD MOVEMENT CRS (Step 1) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement that AP-14 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

CRS (Step 2) Notify IAE to investigate problem. NOTE: The CRS may call WCC/IAE to address the switch position.

If so, Booth Instructor acknowledge as WCC.

CRS (Step 3) Evaluate the following prior to any control rod withdrawal:

. Ensure no inadvertent mode change will occur.

. Ensure control rods are withdrawn in a deliberate manner, while closely monitoring the reactors response.

RO (Step 4) Check T-Ref indication - NORMAL

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 5 Page 42 of 66 Event

Description:

Continuous inward Rod Motion Time Pos. Expected ActionslBehavior Comments CRS/ (Step 5) Do not move rods until IAE Booth Instructor: after 2 RO determines rod motion in permissible. minutes, as IAE, report that MANUAL rod control only is permissible.

RO (Step 6) Maintain T-Avg within 1°F of T-Ref as follows:

. Adjust Turbine load OR

. Borate/dilute NC System.

RO (Step 7) IF AT ANY TIME a runback occurs NOTE: This is a Continuous while in this procedure,... Action. The CRS will make both board operators aware.

ROI (Step 8) IF AT ANY TIME while in this NOTE: This is a Continuous procedure a unit shutdown is required AND Action. The CRS will make BOP rods cannot be moved, THEN perform the both board operators aware.

following:

. Borate as required during shutdown to maintain T-Avg at T-Ref.

. Monitor AFD during load reduction.

. IF AT ANY TIME AFD reaches Tech Spec limit AND reactor power is greater than 50%,

. IF entry into Mode 3 is desired, THEN perform the following:

. WHEN the turbine is tripped OR at desired power level, THEN perform the following:

. Trip Reactor.

. GO TO EP/1IAJ5000IE-0 (Reactor Trip or Safety Injection).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 5 Page 43of 66 Event

Description:

Continuous inward Rod Motion Time Pos. Expected ActionslBehavior Comments CRS (Step 9) WHEN problem is repaired...

NOTE: The RO can move rods in MANUAL.

NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner move to Events #6-8.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 44 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 InterlocklPzr Spray Valves fail to OPEN After this, the leak will develop into a 500 gpm Steam Generator Tube Rupture and the operator will enter EPI1IAI5000/E-0, Reactor Trip or Safety Injection. Upon completion of E-0, the operator will transition to EP/1/A15000/E-3, Steam Generator Tube Rupture, to isolate the flow into and out of the 1 B Steam Generator and then conduct a cooldown of the NC System. While performing an NCS cooldown the C-9 Interlock will fail and result in a loss of the steam dumps. The operator will be required to re-initiate the cooldown using the available SG PORVs. During the NCS depressurization, the Pzr Spray Valves will fail to open. The operator will be required to conduct the depressurization using the last available Pzr PORV. The scenario will terminate at Step 22.c of E-3, after the crew has closed the Cold Leg Isolation Valves from the NV System.

Booth Operator Instructions: insert MAL-SGOOIB 500 delayo rampI2O (SIG lB Tube Rupture)

Indications Available:

Pzr level lowers uncontrollably

Pzr pressure lowers consistently with Pzr level NOTE: Upon changing plant conditions the crew will implement Continuous Action Step 2 of AP-lO, and return to Step 1 of AP-lO.

APIIIAI5500IIO, NC SYSTEM LEAKAGE WITHIN THE CAPACITY OF BOTH NV PUMPS CASE I, STEAM GENERATOR TUBE LEAKAGE BOP (Step 1) Check Pzr level STABLE OR NOTE: Pzr Level will be slowly GOING UP. lowering.

BOP (Step I RNO) Perform the following as required to maintain level:

. Maintain charging flow less than 200 GPM at all times in subsequent_steps.

. Ensure 1NV-238 (Charging Line Flow Control) OPENING.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 45 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 lnterlock/Pzr Spray Valves fail to OPEN BOP

OPEN 1NV-241 (Ui Seal Water In] Flow Control) while maintaining NC pump seal flow greater than 6 GPM.

Reduce or isolate letdown. NOTE: If not isolated already the BOP isolate letdown.

Start additional NV pump. NOTE: The BOP will need to start an additional NV Pump.

IF CLAs are isolated NOTE: The CLAs are NOT isolated.

IF Pzr level cannot be maintained greater NOTE: The Pzr level is than 4% OR Pzr level going down with decreasing with maximum maximum charging flow, THEN perform Charging flow.

the following:

IF lB OR 1C SIG identified as NOTE: The CRS will dispatch ruptured, THEN immediately two AOs.

dispatch two operators to isolate TD Floor Instructor:

CA pump steam supply from Acknowled g e as AOs ruptured SIG PER Enclosure 3 (TD CA Pump Steam Supply Isolation) Booth Instructor:

insertREMSA0002 = 0 insertREMSAOO78 = 0 Within 3 minutes, as AO report that steam has been isolated to the TD CA Pump from the lB SG.

Trip reactor.

RO!

WHEN reactor tripped OR auto S/I BOP setpoint reached, THEN ensure S/I initiated.

GO TO EPI1IAJ5000/E-O (Reactor Trip or Safety_Injection).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 46 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 lnterlocklPzr Spray Valves fail to OPEN EPIIIAI5000IE-O, REACTOR TRIP OR SAFETY INJECTION RO/ (Step 1) Monitor Foldout page. NOTE: Crew will carry out BOP Immediate Actions of E-O, prior to the CRS addressing the EP.

NC Pump Trip Criteria (Not expected)

CA Suction Sources (CA storage tank (water tower) goes below 1.5 ft Not expected)

Position Criteria for 1 NV-i 50B and 1 NV- NOTE: The BOP will monitor 151A (Ui NV Pump Recird Isol) these conditions.

. IF NV S/I flowpath aligned AND NC pressure is less than 1500 PSIG, THEN CLOSE 1NV-150B and 1NV-i 51 A,

. IF NC pressure is greater than 2000 PSIG, THEN OPEN 1NV-1 SOB and 1NV-i5iA.

Ruptured S/G Aux Feedwater Isolation NOTE: The BOP will monitor Criteria (Expected) these conditions, and isolate CA flow to the 1 B SC when met.

. IF both of the following conditions met, THEN stop CA flow to affected S/G:

. Level going up in an uncontrolled manner or radiation level in that S/G is abnormal

. N/R level GREATER THAN 11%

(32% ACC).

Faulted S/C Aux Feedwater Isolation Criteria (Not expected)

RO (Step 2) Check Reactor Trip: Immediate Action

. All rod bottom lights LIT

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 47 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 InterlocklPzr Spray Valves fail to OPEN Time Pos. Expected ActionslBehavior Comments

. Reactor trip and bypass breakers OPEN

. hR amps - GOING DOWN.

NOTE: The reactor will trip manually.

RO (Step 3) Check Turbine Trip: Immediate Action

. All throttle valves CLOSED.

BOP (Step 4) Check 1 ETA and 1 ETB Immediate Action ENERGIZED.

RO/ (Step 5) Check if S/I is actuated: Immediate Action BOP

. SAFETY INJECTION ACTUATED status light (151-i 8) LIT.

. Both LOCA Sequencer Actuated status lights (151-i 4) LIT.

CRS (Step 6) Announce Unit I Safety Injection. NOTE: The CRS may ask U2 RO to make Plant Announcement that a Ui Safety Injection has occurred.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 7) Check all Feed water Isolation status lights (1SI-4) LIT.

BOP (Step 8) Check Phase A RESET lights DARK.

BOP (Step 9) Check ESF Monitor Light Panel on Energized train(s):

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 48 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 Interlock/Pzr Spray Valves fail to OPEN Time Pos. Expected ActionslBehavior Comments

. Groups 1,2, 5DARK.

. Group3LIT.

. Group 4 LIT AS REQUIRED.

BOP (Step 9c RNO) Align or start components as required.

. Group 6LIT.

GO TO Step 10.

RO (Step 10) Check proper CA pump status:

MDCApumps-ON.

. NIR level in at least 3 SIGs GREATER THAN 17%.

BOP (Step 11) Check all KC pumps ON.

80P (Step 12) Check both RN pumps ON.

CRS (Step 13) Notify Unit 2 to perform the Floor Instructor: As U2 RO following: report 2A RN Pump is running.

Start2ARN pump.

THROTTLE Unit 2 RN flow to minimum Booth Instructor:

for existing plant condition. insert LOA-RN087 (Start 2A RN Pump) insert LOA-RN083 8050.000000 delayo rampl0 (Unit 2 Train A Demand Flow)

RO (Step 14) Check all SIG pressures GREATER THAN 775 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-i Scenario # 3 Event # 6, 7 & 8 Page 49 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 InterlocklPzr Spray Valves fail to OPEN Time Pos. Expected Actions/Behavior Comments BOP (Step 15) Check Containment Pressure NOTE: Containment Pressure HAS REMAINED LESS THAN 3 PSIG. is normal.

BOP (Step 16) Check S/I flow:

. Check NV PMPS TO COLD LEG FLOW gauge INDICATING FLOW.

Check NC pressure LESS THAN 1600 PSIG.

BOP (Step 1 6b RNO) Perform the following:

Ensure ND pump miniflow valve on running pump(s) OPEN:

1ND-68A (1A ND Pump & Hx Mini Flow Isol)

1 ND-67B (1 B ND Pump & Hx Mini Flow Isol).

IF valve(s) open on all running ND pumps, THEN GO TO Step 17.

CRS (Step 17) Notify OSM or other SRO to NOTE: The CRS may ask perform EP/1/A]5000/G-1 (Generic OSM to address.

Enclosures), Enclosure 22 (OSM Actions If so, Floor Instructor Following an S/I) within 10 minutes.

acknowledge as OSM.

RO/ (Step 18) Check CA flow:

. Total CA flow GREATER THAN 450 GPM.

Check VI header pressure GREATER THAN 60 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 50 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 InterlocklPzr Spray Valves fail to OPEN ROl

WHEN each SIG N/R level is greater NOTE: This is a Continuous BOP than 11% (32% ACC), THEN control CA Action. The CRS will make flow to maintain that SIG NIR level both board operators aware.

between 1 1% (32% ACC) and 50%.

RU (Step 19) Check NC temperatures:

IF any NC pumps on, THEN check NC NOTE: NC Pumps are OFF T-Avg STABLE OR TRENDING TO due to the LOOP.

557F.

NOTE: It is most likely that the cooldown will be under control.

If NOT, the CRS will assign the RU (BOP) to perform Enclosure 3 (Not Scripted),

and continue the performance of E-0 with the BOP (RU).

BOP (Step 20) Check Pzr PORV and spray (RU) valves:

AllPzrPORVsCLOSED.

(Step 20a RNO) IF Pzr pressure less than 2315 PSIG, THEN perform the following:

CLOSE Pzr PORV(s).

IF any Pzr PORV cannot be closed, THEN perform the following:

CLOSE its isolation valve.

CLOSE the following_valve(s):

IF 1 NC-34A (Ui Pzr PORV) failed, THEN CLOSE 1NC-270 (PZR PORV Drn Isol For 1 NC-34).

IF PORV isolation valve cannot be closed...

Normal Pzr spray valves CLOSED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 51 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 lnterlocklPzr Spray Valves fail to OPEN

. At least one Pzr PORV isolation valve-OPEN.

BOP (Step 21) Check NC subcooling based on (RO) core exit TICs GREATER THAN 0°F.

BOP (Step 22) Check if main steamlines intact:

(RO)

. All SIG pressures STABLE OR GOING UP

. All SIGs PRESSURIZED.

BOP (Step 23) Check if SIG tubes intact:

( RO)

. The following secondary EMFs NORMAL:

. 1 EMF-33 (Condenser Air Ejector Exhaust)

. 1 EMF-34(L) (S!G Sample (Lo Range))

. 1 EMF-24 (SIG_A)

. 1 EMF-25 (SIG_B)

. 1 EMF-26 (SIG_C)

. 1 EMF-27 (SIG_D).

. SIG levels STABLE OR GOING NOTE: The 1 B SG Level is UP IN A CONTROLLED MANNER. increasing in an uncontrolled manner.

CRS (Step 21 RNO) IF SIG levels going up in an uncontrolled manner OR any EMF abnormal, THEN perform the following:

. Implement EPI1IAI5000IF-0 (Critical Safety Function Status Trees).

. GO TO EP/1IAI5000IE-3 (Steam Generator Tube Rupture).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 52 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 Interlock/Pzr Spray Valves fail to OPEN Time Pos. Expected Actions!Behavior Comments NOTE: The CRS will transition toE-3.

EPII IAI5000IE-3, STEAM GENERATOR TUBE RUPTURE RO/ (Step 1) Monitor Foldout page.

BOP NC Pump Trip Criteria (Not expected)

S/I Reinitiation Criteria (SI On Not expected)

Secondary Integrity Criteria (Not expected)

Cold Leg Switchover Criteria (< 95 INCHES in FWST Not expected)

CA Suction Sources (<1 .5 feet Not expected)

Multiple Tube Rupture Criteria (Not expected)

Position Criteria for 1 NV-i 50B and 1 NV i5iA (NV Pumps Recirculation)

. IF NV S/I flowpath aligned AND NC NOTE: The BOP will monitor pressure is less than 1500 PSIG, THEN these conditions.

CLOSE 1NV-150B and 1NV-i 51 A.

. IF NC pressure is greater than 2000 PSIG, THEN OPEN 1NV-150B and 1NV-i5iA.

BOP (Step 2) Identify ruptured S/G(s):

. Any S/G N/R level GOING UP IN AN NOTE: The 1 B SG Level is UNCONTROLLED MANNER increasing in an uncontrolled manner.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 53 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 lnterlocklPzr Spray Valves fail to OPEN

. Chemistry or RP has determined NOTE: The CRS may contact ruptured SIG. Chemistry for sampling.

Booth Instructor:

Acknowledge as appropriate.

. Any of the following EMFs ABOVE NORMAL:

. 1 EMF-24 (SIG_A)

. 1 EMF-25 (SIG_B)

. 1 EMF-26 (SIG_C)

. 1EMF-27(S!GD)

RO (Step 3) Check at least one SIG AVAILABLE FOR NC SYSTEM COOLDOWN.

RO (Step 4) Isolate flow from ruptured SIG(s) as follows:

. Check ruptured SIG(s) PORV NOTE: This valve has CLOSED. previously failed open.

(Step 4a RNO) WHEN ruptured SIG pressure is less than 1092 PSIG, THEN perform the following on affected SM PORV:

. Check SM PORV closed.

. IF SM PORV is still open, THEN NOTE: Previous operation of CLOSE its manual loader, the Manual Loader has failed to close the lB SG PORV.

. IF SM PORV is still open, THEN perform the following:

. CLOSE SM PORV isolation valve.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 54 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 lnterlocklPzr Spray Valves fail to OPEN Time Pos. Expected Actions/Behavior Comments IF SM PORV isolation valve cannot be closed...

Check SIGs 1 B and 1 C INTACT. NOTE: The 1 B SG is NOT ntact.

CRS (Step 4b RNO) Isolate TD CA pump steam supply from ruptured S!G as follows:

IF TD CA pump is the only source of NOTE: The TD CA Pump is feedwater.... NOT the ONLY CA Source.

Ensure operators dispatched in next step immediately notify Control Room Supervisor when valves are closed.

Immediately dispatch 2 operators to NOTE: This step was most concurrently verify (CV), unlock and likely accomplished in AP-1 0 If CLOSE valves on ruptured SIG(s): NOT, the CRS will dispatch two AOs.

Floor Instructor:

Acknowledge as AOs.

For1BS/G:

. 1SA-78 (lB SIG SM Supply to Booth Instructor:

Unit 1 TD CA Pump Turb insertREMSA0002 = 0 Loop Seal Isol) (Unit 1 interior doghouse, 767+10, FF-53). insertREMSAOO78 = 0 Within 3 minutes, as AO report that steam has been isolated to the TD CA Pump from the lB SG.

. 1SA-2 (lB SIG SM Supply to Unit 1 TD CA Pump Turb Maint Isol) (Unit 1 interior doghouse, 767+1 0, FF-53, above ladder).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 55 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 Interlock/Pzr Spray Valves fail to OPEN CRS

IF AT ANY TIME local closure of SA NOTE: Eight minutes will NOT valves takes over 8 minutes, THEN elapse before the valves are isolate TD CA pump steam supply closed.

PER Enclosure 2 (Tripping TD CA Pump Stop Valve or Alternate Steam Isolation).

Check blowdown isolation valves on ruptured SIGI(s) CLOSED.

For1BS/G:

1BB-2B (lB SIG Blowdown Cont Outside Isol Control)

1BB-6A (B S/G BB Cont Inside Isol).

CLOSE steam drain on ruptured SIG(s)

1SM-89 (B SM Line Drain Isol)

CLOSE the following valves on ruptured SIG(s):

MSIV

MSIV bypass valve.

RO (Step 5) Control ruptured SIG(s) level as follows:

Check ruptured S/G(s) N/R level GREATER THAN 11% (32% ACC).

Isolate feed flow to ruptured SIG(s):

For1BS!G:

CLOSE 1CA-54AC (Ui TD CA Pump Disch TO 1 B SIG Isol).

CLOSE 1CA-58A (1A CA Pump Disch To 1 B S/G Isol).

RO (Step 6) Check ruptured S/G(s) pressure GREATER THAN 280 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 56 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 lnterlock/Pzr Spray Valves fail to OPEN Time Pos. Expected ActionslBehavior Comments BOP (Step 7) Check any NC pump RUNNING.

BOP (Step 8) Check Pzr pressure GREATER THAN 1955 PSIG.

CRS (Notes prior to Step 9)

NC pump trip criteria based on subcooling does not apply after starting a controlled cooldown.

After the Low Pressure Steamline Isolation signal is blocked, maintaining steam pressure negative rate less than 2 PSIG per second will prevent a Main Steam Isolation.

RO (Step 9) Initiate NC System cooldown as follows:

CRS . Determine required core exit temperature based on lowest ruptured SIG pressure:

>1099 psig - 520°F NOTE: The CRS will determine the target 1000-1 099 psig - 508°F temperature to be between 508-520°F.

RO . Check the following valves on ruptured SIG(s) CLOSED:

. MSIV

. MSIV bypass valve.

RO . Check ruptured SIG(s) SM PORV CLOSED.

(Step 9c RNO) IF ruptured SIG pressure is less than 1092 PSIG, THEN perform the following:

. Ensure SM PORV on ruptured SIG(s) is CLOSED or isolated.

. IF SM PORV is not closed or isolated, THEN perform the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 57 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 InterlocklPzr Spray Valves fail to OPEN

. Ensure operator dispatched to CLOSE SM PORV isolation valve.

. Do not continue until affected SIG PORV is:

. Isolated OR

. Determined to be unisolable.

Check SIG(s) 1 B and 1 C INTACT. NOTE: The 1 B SG is ruptured.

RO (Step 9.d RNO) IF lB OR 1C SIG is ruptured, THEN perform the following:

Ensure steam to TDCA pump is isolated from ruptured S/G per one of the following:

. Local isolation of SA line (per Step 4.b)

NOTE: If NOT already done, the CRS will direct two AOs to CLOSE 1SA-2 and 78.

Booth Instructor:

insertREMSA0002 = 0 insertREMSAOO78 = 0 Within 3 minutes, as AO report that steam has been isolated to the TD CA Pump from the lB SG.

RO * (Step 9e) Check condenser available as NOTE: Because of a C-9 follows: failure the Condenser is NOT available.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 58 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 lnterlocklPzr Spray Valves fail to OPEN Time Pos. Expected ActionslBehavior Comments RO

C-9 COND AVAILABLE FOR STEAM DUMP status light (1 SI-i 8)

LIT CRS (Step 9e RNO) GO TO RNO for Step 9.h.

BOP (Step 9h RNO) Perform the following:

Ensure at least one Pzr PORV isolation valve is OPEN.

IF VI is lost... NOTE: Neither condition has occurred.

. IF Pzr pressure is greater than 1955 NOTE: Pzr Pressure may be <

PSIG, THEN depressurize to 1900 PSIG 1955 psig. If pressure> 1955 using Pzr PORV. psig, the crew will have to depressurize.

Depress BLOCK on Low Pressure Steamline Isolation block switches.

Maintain NC pressure less than 1955 PSIG.

Ensure Main Steam Isolation reset.

Ensure SM PORVs reset.

IF any intact SIG SM PORV isolation NOTE: 1 B SG PORV has valves is closed AND associated SM previously failed OPEN.

PORV is operable THEN perform the following:

Dump steam using all intact SIG(s) SM PORVs at maximum rate as follows:

CLOSE SM PORV manual NOTE: 1 B SG PORV has loader on ruptured SIG(s). previously failed OPEN and has been isolated.

Place intact S/G SM PORV manual loaders at 50%.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 59 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 lnterlocklPzr Spray Valves fail to OPEN Time Pos. Expected ActionslBehavior Comments

. Select MANUAL on SM PORV MODE SELECT.

Adjust manual loaders on intact S/C SM PORVs as required to control intact SIC depressurization rate at approximately 2 PSIG per second.

CRS . IF any intact SIC SM PORV closed,... NOTE: lB SG PORV has previously failed OPEN.

CRS . IF no intact SIC available... NOTE: The 1A, 1C and 1D SG are available.

RO (Step 9i) Check Low Pressure Steamline Isolation BLOCKED.

(Step 9i RNO) Perform the following:

. Depressurize Pzr to less than 1955 PSIG using one of the following:

. Maximum available Pzr spray OR

. IF normal Pzr spray is not available, THEN use Pzr PORV.

. Do not continue until Pzr pressure is less than 1955 PSIG.

. Depress BLOCK on Low Pressure Steamline Isolation block switches.

. CLOSE Pzr spray valve(s) and Pzr PORVs.

. Maintain NC pressure less than 1955 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 60 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 lnterlock/Pzr Spray Valves fail to OPEN RO * (Step 9.j) Check Core exit TICs- LESS NOTE: It is likely that when the THAN REQUIRED TEMPERATURE. CRS arrives at this step, that the target temperature will NOT be reached.

RO (Step 9.j RNO) Perform the following: NOTE: This action will be taken after the target temperature has been achieved.

. WHEN Core exit T/Cs are less than required temperature, THEN perform the following:

Stop NC System cooldown.

Maintain core exit T/Cs less than required temperature.

CRS NOTE: The CRS will proceed and return to this step when the target temperature has been achieved.

RO (Step 10) Control intact SIG levels:

Check NIR level in any intact S/C GREATER THAN 11% (32% ACC).

Throttle feed flow to maintain all intact S/G NIR levels between 22% (32% ACC) and 50%.

BOP (Step 1 1) Check Pzr PORVs and isolation valves:

Power to all Pzr PORV isolation valves AVAILABLE.

(Step 1 1 a RNO) Evaluate cause of power loss and initiate actions to restore power to affected isolation valve(s).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 61 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 tnterlocklPzr Spray Valves fail to OPEN

. All Pzr PORVs CLOSED.

(Step 11 b RNO) IF Pzr pressure less than 2315 PSIG, THEN perform the following:

. CLOSE Pzr PORV(s).

. IF any Pzr PORV cannot be closed, THEN CLOSE it isolation valve.

. IF PORV isolation valve cannot be closed...

. IF any Pzr PORV cannot be closed or isolated...

. IF any Pzr PORV cannot be closed, THEN CLOSE the following valve(s):

IF 1NC-34A (Ui Pzr PORV) failed, THEN CLOSE 1 NC-270 (PZR PORV Drn Isol For 1 NC-34A).

(Step 1 1 c) At least one Pzr PORV isolation valve OPEN.

BOP (Step 12) Reset the following:

. S/I

Sequencers

. Phase A Isolation

. Phase B Isolation BOP (Step 13) Establish VI to containment as follows:

. Open the following valves:

. 1VI-129B(VI Supply toACont Ess VI Hdr Outside Isol))

. 1VI-160B (VI Supply to B Cont Ess VI Hdr Outside Isol))

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 62 of 66 Event

Description:

I B Steam Generator Tube Rupture/Failure of the C-9 lnterlocklPzr Spray Valves fail to OPEN Time Pos. Expected ActionslBehavior Comments

. 1VI-150B (Lwr Cont Non Ess Cont Outside Isol).

. Check VI header pressure GREATER THAN 85 PS 1G.

RO (Step 14) Check if NC System cooldown should be stopped as follows:

Check cooldown INITIATED PER STEP 9.

. Check Core exit T/Cs LESS THAN NOTE: It is likely that when the REQUIRED TEMPERATURE. CRS arrives at this step, that the target temperature will NOT be reached.

CRS (Step 14b RNO) Perform the following:

IF AT ANY TIME while in this step NOTE: This is a Continuous ruptured SIG pressure changes by over Action. The CRS will make 100 PSIG, AND ruptured SIG pressure is both board operators aware, greater than 400 PSIG, THEN select a and HOLD.

new target temperature from table in Step 9.a.

. Do not continue until core exit T/Cs are less than target temperature.

RO . (Step 14c) Stop NC System cooldown.

. Maintain Core exit T/Cs LESS THAN REQURIED TEMPERATURE.

RO (Step 15) Check ruptured S/G(s) pressure STABLE OR GOING UP.

CRITICAL TASK:

(E-3A) Isolate feedwater flow into and steam flow from the ruptured SG so that minimum AP between ruptured Steam Generator and intact Steam Generators is not less than 250 psid once target temperature is reached (Entry into ECA-3.1).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 63 of 66 Event

Description:

I B Steam Generator Tube RupturelFailure of the C-9 InterlocklPzr Spray Valves fail to OPEN Time Pos. Expected Actions/Behavior Comments RO (Step 16) Check NC subcooling based on core exit T/Cs GREATER THAN 20°F.

BOP (Step 17) Depressurize NC System using Pzr spray as follows:

. Check normal Pzr spray flow AVAILABLE.

. Initiate NC depressurization using NOTE: The Pzr Spray valves maximum available spray. will not open when operated.

IF AT ANY TIME during this step, spray valves are not effective in reducing NC pressure, OR ruptured SIG(s) NR level goes above 83% (73% ACC), THEN GO TO Step 18.

CRS (Step 1 7a RNO) GO TO Step 18.

BOP (Step 18) Depressurize NC System using Pzr PORV as follows:

. Check at least one Pzr PORV -

AVAILABLE.

. Open one Pzr PORV.

. Do not continue until any of the following conditions satisfied:

. NC subcooling based on core exit T/Cs LESS THAN 0°F OR

. Pzr level GREATER THAN 76%

(58% ACC)

. Both of the following:

. NC pressure LESS THAN RUPTURED S/G(s)

PRESSURE.

. Pzr level GREATER THAN 11%(29% ACC).

Appendix D Operator Action Form ES-D-2 Op Test No.: N14-1 Scenario # 3 Event # 6, 7 & 8 Page 64 of 66 Event

Description:

lB Steam Generator Tube RupturelFailure of the C-9 InterlocklPzr Spray Valves fail to OPEN

. Close Pzr PORV

. Close Pzr spray valves.

BOP (Step 19) Check NC pressure GOING UP.

RO! (Step 20) Check S/I termination criteria: