ML102640727

Initial Exam 2010-301 Final Simulator Scenarios

ML102640727
Person / Time
Site:	Mcguire, McGuire
Issue date:	08/30/2010
From:	NRC/RGN-II
To:	Duke Energy Carolinas, Duke Power Co
References
50-369/10-301, 50-370/10-301 50-369/10-301, 50-370/10-301
Download: ML102640727 (298)

Text

Scenario Event Description NRC Scenario I Facility: McGure Scenario No.: I Op Test No.: Nb-I Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 99% power (BOL), following an unplanned load reduction four days ago to complete corrective maintenance on the lB CF Pump. The maintenance was completed and the pump restarted, and power level raised to the present power level three days ago. The 1 B CF Pump is operating in MANUAL Control, for Vendor observation. Upon Turnover the crew is expected to restore the lB CF Pump to Auto Control.

Turnover: The following equipment is Out-Of-Service: IA DIG is OOS to correct a cooling water system leak. 1 EMF45A, Nuclear Service Water Radiation Monitor, failed last shift (IAE is investigating) and MCB Annunciator 1AD-9, D-6, GLYCOL EXPANSION TNK HI-HI LEVEL has alarmed spuriously several times over the last hour (IAE is investigating).

Event MaIf. Event Type* Event No. No. Description 1 NA N-BOP Return I B CF Pump to Auto Control N-SRO 2 FWOO5 l(TS)-SRO FWST Level Channel failure 3 IDEOO3C C-RO Steam Dump Valve fails Open C (TS)-SRO 4 0V0749C 1-RO Reactor Control DCS failure OV0748C l-SRO 5 0V0773B C-BOP 1 CF PumpRollback C(TS)-SRO 6 LFOO3B R-RO ICF Pump trips/Turbine Runback/Rods fail in Auto IREOO9 C-BOP C-SRO 7 NCOO5D4 M-RO Rod Ejection/SB LOCA M-BOP M-SRO 8 NIOO9A NA lNl-9AI1OB fail to OPEN automatically NIOO9B 9 ISEOO3A NA Phase A Containment Isolation Auto Signal failure ISEOO3B (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario Event Description NRC Scenario 1 McGuire 2010 NRC Scenario #1 The plant is at 99% power (BOL), following an unplanned load reduction four days ago to complete corrective maintenance on the lB CF Pump. The maintenance was completed and the pump restarted, and power level raised to the present power level three days ago. The 1 B CF Pump is operating in MANUAL Control, for Vendor observation. Upon Turnover the crew is expected to restore the 1 B CF Pump to Auto Control.

The following equipment is Out-Of-Service: 1A DIG is OOS to correct a cooling water system leak. 1 EMF45A, Nuclear Service Water Radiation Monitor, failed last shift (IAE is investigating) and MCB Annunciator IAD-9, D-6, GLYCOL EXPANSION TNK HI-HI LEVEL, has alarmed spuriously several times over the last hour (IAE is investigating).

Shortly after taking the watch, the operator will place the 1 B CF Pump back in AUTO control in accordance with Enclosure 4.14, Changing CF Pump Auto/Manual Control, of OP/I IA/6250/001 Condensate and Feedwater System.

Afterwards, FWST Level, Channel I will fail low. The operator will respond in accordance with OAC Alarm, M1AOO3, FWST LEVEL CHANNEL I. The operator will address Technical Specification 3.3.2, ESFAS Instrumentation.

After this, Steam Dump Valve 1SB-24 will fail to the full open position. The operator will enter AP/I/A/5500/0l, Steam Leak. The operator will address Technical Specification 3.4.1, RCS Pressure, Temperature and Flow Departure From Nucleate Boiling (DNB) Limits.

Then, a Reactor Control DCS failure will occur causing continuous rod insertion. The operator will enter AP/l/A/5500/14, Rod Control Malfunction. After the implementation of the AP, the failure will be corrected, and rods will be placed back in AUTO.

Subsequently, the 1 B CF will rollback to minimum speed requiring manual speed control of the Main Feed Pumps and a reduction in Turbine load may be needed to stabilize the plant. The operator will enter AP/l/A/5500/06, SIG Feedwater Malfunction. The operator will address Technical Specification 3.4.1, RCS Pressure, Temperature and Flow Departure from Nucleate Boiling (DNB) Limits.

Following this, the lB CF Pump will trip and a Turbine Runback will occur. The operator will enter AP/1/A/5500/03, Load Rejection. During the Runback, the rods will fail to move in AUTO, and the operator will need to drive rods in Manual to stabilize the plant.

During the plant stabilization, Control Rod D-4 will be ejected from the core causing a 1000 gpm Small Break LOCA. The operator will trip the Reactor and actuate Safety Injection, and then enter EP/l/A/5000/E-0, Reactor Trip or Safety Injection. On the Safety Injection actuation 1 NI 9A and 1NI-1OB will fail to automatically open. The operator will attempt to manually open 1NI-9A unsuccessfully, and open INI-1OB manually to restore NV Pump injection flow. Additionally, on the Safety Injection, both Trains of Phase A Containment Isolation will fail to actuate automatically, requiring that the operator manually actuate Containment Isolation Phase A.

Upon completion of E-0, the operator will transition to EP/l/A/5000/E-1, Loss of Reactor or Secondary Coolant. On the transition, an Orange Path will exist on the Containment Critical Safety Function, and the transition will be made to EP/1/AI5000/FR-Z.l, Response to High Containment Pressure, prior to E-l. Upon completion of FR-Z.l the operator will transition to E-l.

Scenario Event Description NRC Scenario I The scenario will terminate at Step 10 of E-1, after the crew has been directed to return back to the beginning of E-1.

Critical Tasks:

E-O J Establish flow from at least one high-head ECCS Pump by opening INI-IOB before transition out of E-O.

Safety Significance: Failure to establish flow from the NV System after failure of the automatic actuation constitutes a demonstrated inability by the operator to recognize a failure and/or correct a failure of an ESF System or component. The FSAR analyses of response to high energy line breaks assume that at least one train of safeguards actuates. If the minimum assumed ESF components are NOT actuated the Safety Analyses results are invalid. Because compliance with the assumptions in the FSAR are part of the facility license, failure to comply constitutes a violation of the license condition.

E-OO Actuate Phase A Containment Isolation before transition out of E-O.

Safety Significance: Failure to close at least one Containment Isolation Valve on each critical penetration under the postulated conditions when it is possible to do so, constitutes mis-operation leading to degradation of the Containment Barrier. Failure to take this action leads to an unnecessary release of fission products to the auxiliary building, increasing the potential for release to the environment, and reducing accessibility to vital equipment within the Auxiliary Building. Higher radiation levels within the Auxiliary Building will result in a degradation of ALARA principles.

Scenario Event Description NRC Scenario I SIMULATOR OPERATOR INSTRUCTIONS Bench Mark ACTIVITY DESCRIPTION Q Sim. Setup Rod Step On Reset to Temp I/C T = 0 Malfunctions:

157. NIOO9A, INI-9A Fails to Open Automatically NIOO9B, lNl-IOB Fails to Open Automatically EPQO0IA, Loss of DC Control Power EMFI45AL = IE+7 Lo Range failed OVR-NIOI4C INI-9A Open PB set to OFF ISEOO3A 3, Block Auto, Train Phase A CIS fails in AUTO ISEOO3B = 3, Block Auto, Train Phase A CIS fails in AUTO RUN Place TagoutlO-Stick on:

Q IA DIG (Tagout)

Reset all SLIMs IEMF45 (0-Stick)

MCB Annunciator IAD-9, D-6 (0-stick)

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

Setup OAC Q Freeze.

Q Update Fresh Tech.

Spec. Log.

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

Q Prior to Crew RUN Briefing Scenario Event Description NRC Scenario 1 Bench Mark ACTIVITY DESCRIPTION Q Crew Briefing

1. Assign Crew Positions based on evaluation requirements

2. Review the Shift Turnover Information with the crew.

3. Provide Enclosure 4.14 of 0P111A16250/OOl, marked up so that Step 2.1 is initialed, and Step 3.1 Checkbox is CHECKED.

4. Provide T-SAIL Entry for 1A DIG.

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

T-O Begin Familiarization Period Q At direction of Event I Return 1 B CF Pump to Auto Control examiner Q At direction of Event 2 FWST Level Channel failure examiner (XMT) FWOO5 0 No Ramp Trigger #1 J At direction of Event 3 Steam Dump Valve fails Open examiner (MALF) IDEOO3C NOTE: (MALF) IDEOO3 will need to deleted

=100% during the event.

No Ramp NOTE: Trigger #5 (LOA-SBOO9 = 0 (4 minutes

. delayed)) is operated when operator is Trigger #3 dispatched to isolate I SB-24.

Q At direction of Event 4 Reactor Control DOS failure examiner (MALF) OV0749C = 0 (MALF) 0V0748C = 0 Trigger #7 Q At direction of Event 5 1 B CF Pump Rollback examiner OV0773B = 2 (True)

Trigger #9 At direction of Event 6 iCE Pump trips/Turbine Runback/Rods fail in Auto Q examiner (MALF) LFOO3B (MALF) IREOO9 = 0 Trigger #11

-6

Scenario Event Description NRC Scenario 1 Bench Mark ACTIVITY DESCRIPTION Q At direction of Event 7 Rod Ejection/SB LOCA examiner (MALF) NCOO5D4 = NOTE: Trigger #15 (LOA-NI024 = RI (2 minutes 1000 gpm delayed)) is operated when operator is dispatched to Close Breaker for INI-173A.

No Ramp

. NOTE: Trigger #17 (LOA-N1025 = RI (3 minutes Trigger #13 delayed)) is operated when operator is dispatched to Close Breaker for INI-178B.

Continued Event 8 1NI-9A/1OB fail to OPEN automatically from Event 7 (MALF) NIOO9A NOTE: These malfunctions are entered at ThO (MALF) NIOO9B J Continued Event 9 Phase A Containment Isolation Auto Signal failure from Event (MALF) ISEOO3A = NOTE: These malfunctions are entered at T=0 Block Auto (MALF) ISEOO3B =

Block Auto Q Terminate the scenario upon direction of Lead Examiner Appendix D Operator Action Form ES-D-2 Op Test No.; Nb-i Scenario # 1 Event # 1 Page 8 of 50 Event

Description:

Return I B CF Pump to Auto Control Shortly after taking the watch, the operator will place the lB CF Pump back in AUTO control in accordance with Enclosure 4.14, Changing CF Pump Auto/Manual Control, of OPI1IA/6250/OO1, Condensate and Feedwater System.

Booth Operator Instructions: NA Indications Available: NA Time Pos. Expected ActionslBehavior Comments OP111A162501001, CONDENSATE AND FEEDWATER SYSTEM ENCLOSURE 4.14, CHANGING CF PUMP AUTO!MANUAL CONTROL BOP (Step 3.2) Perform the following sections, as applicable:

. Section 3.6, Placing CF Pump in Auto During At Power Operation BOP (Step 3.6) Placing CF Pump in Auto During At Power Operation BOP (Step 3.6.1) Check one CF Pump currently NOTE: The BOP will place the operating in auto: 1 B CF Pump in AUTO.

. 1ACFPump OR

. 1BCFPump BOP (Step 3.6.2.2) IF IA CF Pump Turbine in NOTE: The IA CF Pump is Manual... NOT in MANUAL.

BOP (Step 3.6.3) IF placing I B CF Pump Turbine in auto, perform the following:

BOP (Step 3.6.3.1) IF lB CF Pump Turbine in L- NOTE: The lB CF Pump is manual... NOT in L-MANUAL.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # I Event # 1 Page 9 of 50 Event

Description:

Return lB CF Pump to Auto Control Time Pos. Expected Actions/Behavior omments BOP (Step 3.6.3.2) IF lB CF Pump Turbine in manual, perform the following:

• Check the following:

. lB CF Pump Turbine LP GOV CNTRL in manual

. 1 B CF Pump Turbine HP GOV CNTRL in manual Using raise or lower pushbutton(s) on 1 B NOTE: The BOP will adjust I B CF Pump Turbine LP GOV CNTRL/HP CF Pump LP Governor SLIMs GOV CNTRL as required, slowly adjust to raise Turbine Speed.

lB CF Pump Turbine speed to match IA CF Pump Turbine speed (within 100-200 RPM) while monitoring the following:

. FPB DEM (Feedpump B NOTE: These indications are Demand) in RPM located on the DCS Computer Screen.

. SEL SPD (FPB Selected Speed) in RPM

. FPA DEM (Feedpump A Demand) in RPM

. SEL SPD (FPA Selected Speed) in RPM

. AUTO SPT (Auto Setpoint signal to both CF Pumps) in RPM Place 1 B CF Pump Turbine in auto as follows:

. Determine governor that is NOTE: The 1 B CF Pump LP controlling flow: Governor is controlling flow.

• 18 CF Pump Turbine LP GOV CNTRL

. lB CF Pump Turbine HPGOVCNTRL

. Place governor that is controlling flow in auto:

. I B CF Pump Turbine NOTE: The BOP will place the LP GOV CNTRL 1 B CF Pump LP Governor in AUTO.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # I Page 10 of 50 Event

Description:

Return lB CF Pump to Auto Control Time Pos. Expected ActionslBehavior Comments OR

. 18 CF Pump Turbine HP GOV CNTRL

. Place the other governor in auto:

. 1 B CF Pump Turbine LP GOV CNTRL OR

. lB CF Pump Turbine NOTE: The BOP will place the HP GOV CNTRL lB CF Pump HP Governor in AUTO.

BOP (Step 3.6.3.3) Check SIG levels and CF flows stable.

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

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # I Event # 2 Page 11 of 50 Event

Description:

FWST Level Channel failure Afterwards, FWST Level, Channel I will fail low. The operator will respond in accordance with OAC Alarm, M1AOO3, FWST LEVEL CHANNEL I. The operator will address Technical Specification 3.3.2, ESFAS Instrumentation.

Booth Operator Instructions: Operate Trigger #1 (XMT-FWOO5 (0))

Indications Available:

. QAC Alarm, M1A0003, FWST LEVEL CH I

. 1FWP-5010, FWST CH 1, indicates 0.

Time Pos. Expected ActionslBehavior Comments OAC ALARM, MIA0003, FWST LEVEL CH I BOP (Lo Step 1) Initiate Makeup NOTE: The BOP will conduct a Channel Check and determine that makeup is NOT needed, but that one Channel has failed.

BOP (Lo Step 1) Refer to OPI1/N61001010 M NOTE: This ARP deals with an (Annunciator Response for Panel 1AD12, E4 actual low level.

(FWST at Makeup Level).

CRS (Lo-Lo Step 1) Refer to TS 3.5.4. NOTE: The CRS will check TS based on a failed FWST level channel and determine that TS 3.3.2 applies.

TECHNICAL SPECIFICATION 3.3.2, ESFAS INSTRUMENTATION CRS LCO 3.3.2 The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE.

SRO APPLCIABILITY: According to Table 3.3.2-1.

CRS ACTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # I Event # 2 Page 12 of 50 Event

Description:

FWST Level Channel failure Time Pos. Expected ActionslBehavior Comments CRS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that Functional Unit A. One or A. 1 Enterthe Immediately 7.A on Table 3.3.2-1 IS more Condition affected by this event, and that Functions referenced with one or in Table Conditions A and P are more 3.3.2-1 for required.

required the channels channel(s).

inoperable.

P. One P.1 Place 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> channel channel in inoperable. trip.

AND P.2 Restore 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> channel to OPERABLE status.

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

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 3 Page 13 of 50 Event

Description:

Steam Dump Valve fails Open After this, Steam Dump Valve I SB-24 will fail to the full open position. The operator will enter API1IAI5500IO1, Steam Leak. The operator will address Technical Specification 3.4.1, RCS Pressure, Temperature and Flow Departure From Nucleate Boiling (DNB)

Limits.

Booth Operator Instructions: Operate Trigger #3 (IDEOO3C(100))

NOTE: This malfunction must be deleted when the RO takes the Steam Dumps to OFF RESET.

Indications Available:

• OAC Alarms, Ui PZR PRESS I, II, Ill, AND IV

. 1SB-24 Red Status light is LIT.

. Tavg-Tref on Rod Motion Demand moves negative, w/Auto Rod Motion Signal

• No actual Auto Rod motion (Blocked due to C-I 1)

. MOB Annunciator 1AD-6, C-6, PZR LO PRESS CONTROL Tim FnertrI AfinnIRchvinr

---I------.

Comments NOTE: The RO may defeat the Steam Dumps by the time that APi is entered.

APIIIAI5500IOI, STEAM LEAK RO! (Step 1) Monitor Foldout page.

BOP RQ (Step 2) Reduce turbine load to maintain the NOTE: The RO will take the following: Turbine to Manual and reduce load by 2O-8OMWe.

. Excore NIs LESS THAN OR EQUAL TO 100%

. NC Loop D/Ts LESS THAN 60°F D/T

. T-Ave AT i-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.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # I Event # 3 Page 14 of 50 Event

Description:

Steam Dump Valve fails Open Time Pos. Expected ActionslBehavior Comments BOP (Step 5) Check Pzr pressure prior to event GREATER THAN P-lI (1955 PSIG).

BOP (Step 6) Check Pzr level STABLE OR GOING UP.

CRS (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.

CRS (Step 12) Announce occurrence on paging NOTE: The CRS may ask U2 system. RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 13) Identify and isolate leak on Unit 1:

. Check SM PORVs CLOSED.

RO . Check condenser dump valves NOTE: One Steam Dump CLOSED. Valve (ISB-24) will have failed opened and most likely have been closed by the RO already.

IF NOT, the valves will be closed here.

RO (Step 13b RNO) IF steam dumps required to be closed, THEN perform the following;

. Select OFF RESET on the following Booth Instructor: Delete switches: MALF IDEOO3C when the RO takes the Steam Dumps to OFF RESET.

. STEAM DUMP INTLK BYPASS CHANNEL A

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # I Event # 3 Page 15 of 50 Event

Description:

Steam Dump Valve fails Open Time Pos. Expected ActionslBehavior Comments

. STEAM DUMP INTLK BYPASS CHANNEL B.

. IF valve will not close, THEN NOTE: Valve Closes when Steam Dumps taken to OFF Reset.

. WHEN leaking condenser dump valve is NOTE: This is a Continuous isolated OR repaired, THEN return the Action. The SRO will make following switches to ON: both board operators aware.

. STEAM DUMP INTLK BYPASS CHANNEL A

. STEAM DUMP INTLK BYPASS NOTE: The CRS will dispatch CHANNEL B. an NEC.

Booth Instructor:

Operate Trigger #5 (LOA SBOO9 (4 minutes delayed)).

As NEO report that ISB-24 has been isolated.

BOP * (Step 13c) Check containment conditions NORMAL:

• Containment temperature

• Containment pressure

• Containment humidity

. Containment floor and equipment sump level RO

• Check TD CA pump OFF.

BOP

• Check valves on STEAM LINE DRAIN VALVES board (1 MC-9) CLOSED.

CRS

• Check opposite Unit STEAM HEADER NOTE: The CRS will ask U2 PRESSURE GREATER THAN 200 RO to report Steam Header PSIG. Pressure.

Floor Instructor:

acknowledge as U2 RO, and report Steam Header Pressure

= 980 psig.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 3 Page 16 of 50 Event

Description:

Steam Dump Valve fails Open Time Pos. Expected Actions!Behavior Comments

. Dispatch operator to check for leaks. NOTE: The CRS may NOT dispatch an operator since the source of the steam leak is known to be the SD Valve.

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.

. Determine if unit shutdown or load reduction is warranted based on the following criteria:

• Size of leak

• Location of leak

. Rate of depletion of secondary inventory

. IF steam is leaking from a secondary NOTE: Steam is NOT leaking heater relief OR MSR relief valve, from a secondary heater relief OR MSR relief valve.

. IF turbine trip will isolate steam leak NOTE: Turbine Trip is NOT (Such as feedwater heater leak or necessary to isolate Steam MSR leak), THEN Leak.

. Check unit shutdown or load reduction NOTE: The CRS may call REQUIRED. WCC to address.

If so, Booth Instructor acknowledge as WCC.

SRO (Step 15c 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.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 3 Page 17 of 50 Event

Description:

Steam Dump Valve fails Open Time Pos. Expected ActionslBehavior Comments TECHNICAL SPECIFICATION 3.4.1, RCS PRESSURE, TEMPERATURE, AND FLOW DEPARTURE FROM NUCLEATE BOILING (DNB) LIMITS CRS 3.4.1 RCS Pressure, Temperature, and Flow NOTE: Tech Spec applicability Departure from Nucleate Boiling (DNB) will vary depending of how Limits. quickly the event is diagnosed.

If Pzr Pressure drops < 2218 psig the TS is applicable.

CRS LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified in Table 3.4.1-1.

CRS APPLICABILITY: MODE 1.

CRS ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME A. Pressurizer AiRestore DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

pressure or parameter(s)

RCS to within limit.

average temperature DNB parameters not within limits.

Examiner NOTE: DO NOT move forward until the leaking Steam Dump valve has been isolated.

At the discretion of the Lead Examiner move to Event #4.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 4 Page 18 of 50 Event

Description:

Reactor Control DCS failure Then, a Reactor Control DCS failure will occur causing continuous rod insertion. The operator will enter API1IA/5500114, Rod Control Malfunction. After the implementation of the AP, the failure will be corrected, and rods will be placed back in AUTO.

Booth Operator Instructions: Operate Trigger #7 (0V0749C (0),

0V0748C (0))

Indications Available:

• Control rods heard and observed to be moving in Auto.

. Tref indication fails low -

Time Pos. Expected ActionslBehavior Comments AP111A15500114, ROD CONTROL MALFUNCTION RO (Step 1) IF more than one rod dropped, Immediate Action THEN perform the following:

NOTE: No Rods have dropped.

. Trip reactor.

. GO TO EP/IIA!50001E-0 (Reactor Trip or Safety Injection).

RO (Step 2) Place control rods in manual. Immediate Action RO (Step 3) Check rod movement STOPPED. Immediate Action RO (Step 4) Check all rods ALIGNED WITH ASSOCIATED BANK.

RO (Step 5) Check ROD CONTROL URGENT FAILURE alarm (1AD-2, A-b) DARK.

RO (Step 6) Check T-AVG/T-REF FAILURE ROD STOP alarm (IAD-2, B-7) DARK-

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 4 Page 19 of 50 Event

Description:

Reactor Control DCS failure Time Pos. Expected ActionslBehavior Comments CRS (Step 7) IF this AP entered due to unwarranted rod insertion or withdrawal, THEN GO TO Enclosure 3 (Response to Continuous Rod Movement).

NOTE: The CRS will go to Enclosure 3.

AP111A15500114, ROD CONTROL MALFUNCTION, ENCLOSURE 3, RESPONSE TO CONTINUOUS ROD MOVEMENT CRS (Step 1) Announce occurrence on paging NOTE: The CRS may ask U2 system. RO to make Plant Announcement.

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.

If so, Booth Instructor acknowledge as WCC/IAE.

RO (Step 3) Evaluate the following prior to any control rod withdrawal:

. Ensure no inadvertent mode change will occur.

. Ensure the control rods are withdrawn in a deliberate manner, while closely monitoring the reactors response.

RO (Step 4) Check T-Ref indication - NORMAL: NOTE: T-Ref is lower than normal.

RO (Step 4 RNO) Perform the following:

. IF TURB IMP PRESS OH 2 failed, NOTE: Channel 2 has NOT THEN ensure P-7 and P-13 interlocks failed.

are in required state for existing unit conditions (Tech_Spec_3.3.1.16).

. IF unit coastdown in progress NOTE: Coastdown is NOT in progress.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 1 Event # 4 Page 20 of 50 Event

Description:

Reactor Control DCS failure Time Pos. Expected ActionslBehavior Comments RO . Perform any of the following as necessary to maintain T-Colds 555°F to 557°F:

. Position control rods in manual.

OR

. Borate/dilute NC System OR

. Adjust turbine load.

CRS . GO TO Step 9.

RO (Step 9) WHEN problem is repaired, THEN NOTE: This is a Continuous perform the following: Action. The CRS will make both board operators aware.

. Ensure T-Avg at T-Ref +/- 1 °F.

. IF auto rod control desired, THEN place rods in auto.

CRS (Step 10) Exit this procedure. NOTE: The CRS will likely conduct a Focus Brief.

Booth Instructor: Delete N1ALF 0V0749C and 0V748C.

As IAE, call and indicate that a blown fuse was discovered in the Tref circuitry, and it has been replaced.

At the discretion of the Lead Examiner move to Event #5.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 5 Page 21 of 50 Event

Description:

lB CF Pump Rollback Subsequently, the lB CF will rollback to minimum speed requiring manual speed control of the Main Feed Pumps and a reduction in Turbine load may be needed to stabilize the plant. The operator will enter AP/1IA/5500106, SIG Feedwater Malfunction. The operator will address Technical Specification 3.4.1, RCS Pressure, Temperature and Flow Departure from Nucleate Boiling (DNB) Limits.

Booth Operator Instructions: Operate Trigger #9 (0V0773B)

Indications Available:

. MCB Annunciator 1AD-2, E8, DCS TROUBLE ALARM

. MCB Annunciator IAD-4 Cl, S/G A FLOW MISMATCH LO CF FLOW

. MCB Annunciator 1AD-4 C2, SIG B FLOW MISMATCH LO CF FLOW

. MCB Annunciator IAD-4 C3, SIG C FLOW MISMATCH LO CF FLOW

. MCB Annunciator 1AD-4 C4, SIG D FLOW MISMATCH LO CF FLOW

. I B CF Turbine speed is lowering

. All SG Narrow Range Levels are lowering

. All SG Feedwater Flows are lowering Tmz I IIII Df%

I A+;I.k.*,;r Il 1.jI JLV I.1I Comments CONTROL ROOM CREW EXPECTATIONS MANUAL RO Immediately reduce 2OMWe and then reduce NOTE: If load was NOT as needed to maintain Rx power less than reduced during the previous pre-transient condition. Steam Dump failure, the RO will drop load on the Turbine 30-60MWe.

APII!A15500!06, SIG FEEDWATER MALFUNCTIONS RO (Step 1) Check all CF control and bypass valves OPERATING PROPERLY.

BOP (Step 2) Check both CF pumps OPERATING PROPERLY.

BOP (Step 2 RNO) Perform the following:

. IF malfunctioning CF pump has tripped NOTE: The lB CF Pump is in OR pump is in rollback hold in Mode 3.... rollback hold, however the plant is in Mode 1.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 5 Page 22 of 50 Event

Description:

lB CF Pump Rollback Time Pos. AJi.LU iujiiiieiiavpji Comments

. IF CF pump is not controlling properly in auto, THEN control affected CF pump in manual as follows:

BOP

• Place low pressure governor control in manual.

. Place high pressure governor control in manual.

• AdjustCFpumpspeedto maintain desired CF pump discharge pressure and S/G levels.

. IF both of the following conditions are met:

• Flow from malfunctioning CF pump- COMPLETELY LOST

• Turbine Impulse pressure NOTE: The flow from the 1 B GREATER THAN 400 PSIG, CF Pump is NOT completely THEN... lost.

RO (Step 3) Check unit status as follows:

. Reactor trip breakers CLOSED

• Pzr pressure GREATER THAN P-I I (1955 PSIG)

RO (Step 4) IF AT ANY TIME S/G level NOTE: This is a Continuous approaches 17% OR 83%, THEN perform Action. The CRS will make the following: both board operators aware.

• Trip Reactor

• GO TO EP/1/A15000/E-O (Reactor Trip or Safety Injection)

CRS (Step 5) Announce occurrence on page. NOTE: The CRS may ask U2 RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 5 Page 23 of 50 Event

Description:

lB CF Pump Rollback Time Pos. Expected Actions/Behavior Comments RD (Step 6) Check reactor power GREATER THAN 3%.

RD (Step 7) Check CM/CF PRESENTLY FEEDING S/Gs.

RD (Step 8) Check S/G levels STABLE OR TRENDING TO PROGRAM LEVEL.

RD (Step 9) Check NC temperatures as follows:

. IF any NC pump on, THEN check NC T Avg STABLE DR TRENDING TO DESIRED TEMPERATURE.

RD (Step 10) Check all S/G CF control valves IN AUTO.

RD (Step 11) Check all S/G CF control bypass valves IN AUTO.

BOP (Step 12) Check the following on running CF pumps:

On DCS workstation, Feedpump Overview graphic, check AUTO (located below AUTD/SPD select button on running CF pump(s)) -

INDICATED

• CF pump low pressure governor control IN AUTO

. CF pump high pressure governor control IN AUTO RD/ (Step 13) Check all CA pumps OFF.

BOP

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario# 1 Event# 5 Page 24 of 50 Event

Description:

lB CF Pump Rollback Time I II I I SI -

Ar+iriricIlr.h,r.r Ivrv4tI flhI WI II WI 1b4 VII- WI I III II Ib NOTE: The CRS may call WCC/IAE to address the switch position.

If so, Booth Instructor acknowledge as WOO.

NOTE: The CRS will likely conduct a Focus Brief.

TECHNICAL SPECIFICATION 3.4.1, RCS PRESSURE, TEMPERATURE, AND FLOW DEPARTURE FROM NUCLEATE BOILING (DNB) LIMITS ORS 3.4.1 ROS Pressure, Temperature, and Flow NOTE: Tech Spec applicability Departure from Nucleate Boiling (DNB) will vary depending of how Limits. quickly the event is diagnosed.

If Pzr Pressure drops < 2218 psig the TS is applicable.

Examiner Note: Because of the transient nature of this event, the ORS may NOT

. evaluate Technical Specifications until the plant is sufficiently stabilized.

Therefore, the TS should be evaluated after the scenario has been completed.

ORS LOO 3.4.1 ROS DNB parameters for pressurizer pressure, ROS average temperature, and ROS total flow rate shall be within the limits specified in Table 3.4.1-1.

ORS APPLIOABILITY: MODE 1.

ORS AOTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 5 Page 25 of 50 Event

Description:

lB CF Pump Rollback Tmt Dtc vrr4irl A ,+fnc IPch snr-.r Cnmmnts CONDITION REQUIRED COMPLETION ACTION TIME A. Pressurizer A.1 Restore DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> pressure or parameter(s)

RCS average to within limit.

temperature DNB parameters not within limits.

At the discretion of the Lead Examiner move to Event #6.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 1 Event # 6 Page 26 of 50 Event

Description:

ICF Pump tripslTurbine RunbacklRods fail in Auto Following this, the 1 B CF Pump will trip and a Turbine Runback will occur. The operator will enter AP/11A15500103, Load Rejection. During the Runback, the rods will fail to move in AUTO, and the operator will need to drive rods in Manual to stabilize the plant.

Booth Operator Instructions: Operate Trigger #11 (LFOO3B, IREOO9 (0))

Indications Available:

. MOB Annunciator IAD-5 Cl, B CF Pump Turbine Trip.

. MOB Annunciator lAD-I D6, DEH TURBINE RUNBACK.

• lB CF Pump Speed Control indicates 0.

. 1 B OF Pump Green TRIP status light is LIT.

. 1 B CF Pump discharge pressure drops to 0 psig.

. MWe lowers initially to 560 MWe.

• Rods do NOT move in Auto.

Pos. ExDected ActionslBehavior Comments AP111A15500103, LOAD REJECTION RO (Step 1) Ensure control rods in auto. Immediate Action NOTE: The RO will determine that the rods are NOT moving in AUTO, and Manually drive rods inward.

RO (Step 2) Check Turbine Generator response as follows:

• Check Generator TIED TO GRID.

. Check Generator output GOING DOWN AS REQUIRED.

RO (Step 3) Check control rod response as follows:

. Check control banks MOVING IN AS NOTE: The Control Rods will REQUIRED. NOT be moving in as required.

RO (Step 3 RNO) IF no rods will move in auto, THEN perform the following:

. Place control rods in manual.

Appendix D Operator Action Form ES-D-2 Op Test No.: N 10-1 Scenario # I Event # 6 Page 27 of 50 Event

Description:

ICF Pump trips/Turbine RunbacklRods fail in Auto Pos. Expected ActionslBehavior Comments

. Insert rods to reduce T-Avg equal to NOTE: The RO will Manually programmed T-Ref. drive rods inward.

. IF no rods will move, THEN NOTE: The rods will move in manual.

RO . Check all rods ALIGNED WITH ASSOCIATED BANK.

BOP (Step 4) Check CM system response as follows:

. Standby Hotwell and Condensate Booster pumps RUNNING.

. 1CM-420 (Unit 1 Generator Load Rejection Bypass Control) OPEN.

RO (Step 5) IF 50% runback, THEN ensure turbine impulse pressure going down to less than 410 PSIG.

CRS (Step 6) Announce: UNIT 1 LOAD NOTE: CRS may ask U2 RO REJECTION, NON-ESSENTIAL to make Plant Announcement.

PERSONNEL STAY OUT OF UNIT 1 If so, Floor Instructor TURBINE BLDG. acknowledge as U2 RO.

RO (Step 7) Check P/R meters LESS THAN 20%.

CRS (Step 7 RNO) Perform the following:

. Designate an operator to continuously NOTE: CRS will direct the RO monitor reactor power. to continuously monitor reactor power.

. IF AT ANY TIME reactor power is less NOTE: This is a Continuous than 20%, THEN perform Step 8 to Action. The CRS will make stabilize reactor power. both board operators aware.

CRS

• GOTOStep9.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # I Event # 6 Page 28 of 50 Event

Description:

ICF Pump tripslTurbine RunbacklRods fail in Auto Pos. Expected ActionslBehavior Comments RO (Step 9) Check condenser dump valves NOTE: The runback will MODULATING OPEN. terminate 50%.

BOP (Step 10) Check IPB AIR FLOW TROUBLE alarm (lAD-il, J-5) DARK.

BOP (Step ii) Check Pzr pressure control NOTE: The BOP may control response as follows: I NV-241 as needed to adjust NC Pump Seal flow.

. Ensure Pzr heaters are in auto.

. Ensure Pzr spray control valves are in auto.

. Check Pzr PORVs CLOSED.

. (Step lid) Check Pzr spray control valves CLOSED.

BOP (Step 12) Check load rejection DUE TO NOTE: The runback was LOSS OF CF PUMP. initiated because of the lB CF Pump.

CRS (Step 13) Dispatch operator as necessary to NOTE: The CRS will dispatch determine cause of CF pump trip. an NEO.

BOP (Step 14) Ensure in service CF pump properly responds in as follows:

. Monitor in service CF pump discharge pressure.

. lA CF PUMP DISCHARGE PRESS (OAC_point_M1A11O8).

. Monitor S/G N/R Levels.

CRS

• IF AT ANY TIME any of the following NOTE: This is a Continuous occurs: Action. The CRS will make both board operators aware.

• CF PUMP DISCHARGE HI PRESS IAD-8, A-4 alarms (Setpointat 1335 PSIG)

Appendix D Operator Action Form ES-D-2 Op Test No.: N 10-1 Scenario # 1 Event # 6 Page 29 of 50 Event

Description:

ICF Pump tripslTurbine RunbacklRods fail in Auto Pos. Expected ActionslBehavior Comments OR

• S/G NIR level approaches Hi Hi level (83%)

OR

. SIG N/R level approaches Lo Lo level (17%)

CRS THEN take manual control of in NOTE: This is a Continuous service CF pump as follows: Action. The CRS will make both board operators aware.

. Place low pressure governor control in manual.

. Place high pressure governor control in manual.

Adjust CF pump speed to maintain CF header pressure 100-1 20 PSIG above steam header pressure.

CRS . Do not continue until the following are satisfied:

. In service CF pump discharge NOTE: The CRS may hold at pressure is stable. this Step to allow plant stabilization.

. S!G levels are at setpoint.

RD (Step 15) Check turbine impulse pressure LESS THAN 260 PSIG.

CRS (Step 15 RNO) Perform the following:

. IF AT ANY TIME turbine impulse NOTE: This is a Continuous pressure drops to less than 260 PSIG, Action. The CRS will make THEN GO TO Step 16. both board operators aware.

CRS . GOTOStepI9.

RD (Step 19) Check Main Generator as follows:

. Check Generator Breakers EITHER GENERATOR BREAKER CLOSED.

. Check Generator TIED TO GRID.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # I Event # 6 Page 30 of 50 Event

Description:

ICF Pump tripslTurbine RunbacklRods fail in Auto Pos. Expected Actions!Behavior Comments

. Check generator power factor 0.9 TO 1.0 LAGGING.

CRS (Step 20) REFER TO RP/0/A/5700/000 NOTE: The CRS may ask (Classification of Emergency). OSM to address.

If so, Floor Instructor acknowledge as OSM.

RO (Step 21) WHEN transient is over, THEN perform the following:

. (Step 21 .a) Check reactor power GREATER THAN 40%.

BOP * (Step 21 .b) Check the following on in NOTE: The 1A CF Pump is the service CF pump(s). ONLY CF Pump running.

. Low pressure governor control IN AUTO

. High pressure governor control IN AUTO RO . (Step 21.c) Check SM flow on all S/Gs LESS THAN 75%.

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

RO (Step 21 .d RNO) Perform the following:

Check the following CF control bypass valves CLOSED:

. 1CF-1O4AB (IA S/G CF Control Bypass) CLOSED

. 1CF1O5AB (lB S/G CF Control Bypass) CLOSED

. 1CF-1O6AB (IC S/G CF Control Bypass) CLOSED

. ICF-IO7AB (1D S/G CF Control Bypass) CLOSED.

IF any CF control bypass valve is open NOTE: The CF Control OR throttled Bypass Valves are Closed.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 6 Page 31 of 50 Event

Description:

ICF Pump trips/Turbine RunbacklRods fail in Auto Pos. Expected ActionslBehavior Comments CRS

• GOTOStep2l.f BOP (Step 21.f) Slowly CLOSE ICM-420 NOTE: The BOP will most (Unit 1 Generator Load Rejection likely call up M1A1 090 on the Bypass Control) while monitoring OAC.

Condensate Booster pump suction pressure.

BOP . (Step 21.g) WHEN 1CM-420 is closed, THEN check load rejection signal reset (OAC turn on code CM).

BOP * (Step 21 .h) Reposition manual loader for 1CM-420 to 100% OPEN.

BOP (Step 21.i) IF thermal power is greater than 15% THEN within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of reaching stable conditions, ensure each power range channel is within 2% of heat balance.

RO . (Step 21 .j) Check T-avg GREATER THAN 561°F.

RO . (Step 21k) Check CONTROL ROD NOTE: IAD-2, B-9 will be LIT.

BANK LO LO LIMIT alarm (IAD-2, B-9)

- DARK.

RO (Step 21.k RNO) Perform the following:

Ensure a shutdown margin NOTE: The CRS may ask U2 calculation is complete within 45 RO to perform this calculation.

minutes of runback initiation If so, Floor Instructor PER OP/0/N6100/006 acknowledge as U2 RO.

(Reactivity Balance Calculation),

Enclosure 4.4 (Shutdown Margin Unit at Power Modes 1 and 2).

WHEN calculation complete, NOTE: This calculation will THEN... NOT be completed during this scenario.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 1 Event # 6 Page 32 of 50 Event

Description:

ICF Pump trips/Turbine RunbacklRods fail in Auto Pos. Expected ActionsIBehavor Comments RO . (Step 21 .1) Check CONTROL ROD NOTE: 1AD-2, A-9 will be LIT.

BANK LO LIMIT alarm (1AD-2, A-9)

DARK.

RO (Step 21.1 RNO) Ensure the CONTROL ROD BANK LO LIMIT alarm clears as Xenon builds in.

BOP (Step 22) Check load rejection DUE TO NOTE: The run back was LOSS OF CF PUMP. initiated because of the 1 B CF Pump.

BOP (Step 23) Reset CF pump recirc valves as follows:

. CLOSE recirc valve manual loader for CF pump that is tripped:

. ICF-76 (1A CF Pump Recirc Control)

OR

• iCE-Si (18 CF Pump Recirc Control).

BOP

• Depress IA OR 1 B CF PUMP RECIRC VALVE CLOSURE CIRCUIT RESET pushbuttom and ensure red ACTIVE light goes out and yellow RESET light is lit.

• Check the following valves OPEN:

• ICM-266 (1A CF Pump Suction Isol)

• 1CM-272 (lB CF Pump Suction Isol).

• Check main oil pump on tripped CF pump RUNNING.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 6 Page 33 of 50 Event

Description:

ICF Pump trips/Turbine Runback/Rods fail in Auto Pos. Expected ActionslBehavior Comments

. Check if CF pump TRIPPED AUTOMATICALLY.

. Slowly OPEN recirc valve on tripped CF pump while monitoring suction pressure on in service CF pump.

At the discretion of the Lead Examiner move to Events #7-9.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # I Event # 7, 8 & 9 Page 34 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically I Phase A Containment Isolation Auto Signal failure During the plant stabilization, Control Rod D-4 will be ejected from the core causing a 1000 gpm Small Break LOCA. The operator will trip the Reactor and actuate Safety Injection, and then enter EPIIIAI5000IE-0, Reactor Trip or Safety Injection. On the Safety Injection actuation lNl-9A and 1NI-10B will fail to automatically open. The operator will attempt to manually open 1NI-9A unsuccessfully, and open lNl-1OB manually to restore NV Pump injection flow. Additionally, on the Safety Injection, both Trains of Phase A Containment Isolation will fail to actuate automatically, requiring that the operator manually actuate Containment Isolation Phase A. Upon completion of E-0, the operator will transition to EP/11A15000/E-1, Loss of Reactor or Secondary Coolant.

On the transition, an Orange Path will exist on the Containment Critical Safety Function, and the transition will be made to EP/1/A/5000/FR-Z.1, Response to High Containment Pressure, prior to E-1. Upon completion of FR-Z.1 the operator will transition to E-1.

The scenario will terminate at Step 10 of E-1, after the crew has been directed to return back to the beginning of E-1.

Booth Operator Instructions: Operate Trigger #13 (NCOO5D4 (1000 gpm))

Indications Available:

• Control Rod D-4 Red Rod Bottom Light flashes on DRPI

• Containment Pressure starts to rise

• Charging flow starts to increase

• Pzr level starts to lower Time Pose Expected Actions/Behavior Comments NOTE: Crew will carry out Immediate Actions of E-O, prior to the CRS addressing the EP.

EPIIIAI5000!E-0, REACTOR.TRIP OR SAFETY INJECTION RO/ (Step 1) Monitor Foldout page.

BOP RO (Step 2) Check Reactor Trip: Immediate Action

• All rod bottom lights LIT NOTE: The Ejected Rod does NOT indicate on the Bottom.

• Reactor trip and bypass breakers OPEN

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # I Event # 7, 8 & 9 Page 35 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure Timp Pnc Fynpttøt1 ArfinnqIRphavinr Comments

. hR amps - GOING DOWN.

RO (Step 2 RNO) Perform the following: Immediate Action

. Trip reactor.

RO (Step 3) Check Turbine Trip: Immediate Action

. All throttle valves CLOSED.

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

ROI (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 (1SI-14) LIT.

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

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 7) Check ESF Monitor Light Panel on energized train(s):

. Groupsl,2,5DARK.

• Group 3 LIT.

. OACIN SERVICE.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 7, 8 & 9 Page 36 of 50 Event

Description:

Rod Ejection!SB LOCAIINI-9AIIOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure T; .me. D,a s,nnn+nA A an ma IDe. I, .n,n..

I IIIi I . r.., LIJI II LI ici V I.JI Comments

• Group 4, Rows A through F LIT AS NOTE: The light for 1 Nl-9A REQUIRED. will be DARK, and the light for lNl-1OB may be DARK.

Phase A CIS has NOT occurred automatically (The BOP may have may actuated Phase A CIS).

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

. Ensure both trains Phase A Isolation are initiated.

. Align or start S/I and Phase A NOTE: If 1NV- lOB has NOT components with individual windows in been opened, it may be Group 4 as required. opened here.

. GO TO Step 7.f.

BOP (Step 7.f) Check LOCA Sequencer Actuated status light (ISI-14) on energized train(s) -

LIT.

BOP . (Step 7.g) Check the following windows on Monitor Light Panel Group 4 LIT:

. C-3 CONT ISOL PHASE A TRN A VLVS ALIGNED

. C-6 CONT ISOL PHASE A TRN B VLVS ALIGNED

. F-4 SAFETY INEJCTION TRAIN A COMPONENTS ALIGNED

. F-5 SAFETY INEJCTION TRAIN B COMPONENTS ALIGNED BOP (Step 7.g RNO) Perform the following on energized train(s):

. Check OAC Monitor Light Program (MONL) for associated light.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 7, 8 & 9 Page 37 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure Time Pos Expected ActionslBehavior Comments

. Align valves as required, while continuing in the EP.

CRITICAL TASK:

(E-O J) Establish flow from at least one high-head ECCS Pump by opening INI-lO before transition out of E-O.

Safety Significance: Failure to establish flow from the NV System after failure of the automatic actuation constitutes a demonstrated inability by the operator to recognize a failure and/or correct a failure of an ESF System or component. The FSAR analyses of response to high energy line breaks assume that at least one train of safeguards actuates. If the minimum assumed ESF components are NOT actuated the Safety Analyses results are invalid. Because compliance with the assumptions in the FSAR are part of the facility license, failure to comply constitutes a violation of the license condition.

CRITICAL TASK:

(E-O 0) Actuate Phase A Containment Isolation before transition out of E-O.

Safety Significance: Failure to close at least one Containment Isolation Valve on each critical penetration under the postulated conditions when it is possible to do so, constitutes mis-operation leading to degradation of the Containment Barrier. Failure to take this action leads to an unnecessary release of fission products to the auxiliary building, increasing the potential for release to the environment, and reducing accessibility to vital equipment within the Auxiliary Building. Higher radiation levels within the Auxiliary Building will result in a degradation of ALARA principles.

BOP (Step 8) Check proper CA pump status:

. MDCApumpsON

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

BOP (Step 9) Check all KC pumps - ON BOP (Step 10) Check both RN pumps ON.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 7, 8 & 9 Page 38 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure Time Pos. Expected ActionslBehavior Comments CRS (Step 11) Notify Unit 2 to start 2A RN pump. Floor Instructor: As U2 RO report 2A RN Pump is running.

RD (Step 12) Check all SIG pressures GREATER THAN 775 PS 1G.

BOP (Step 13) Check Containment Pressure NOTE: Containment pressure HAS REMAINED LESS THAN 3 PSIG. is 2.5 psig, and slowly rising due to the LOCA.

BOP (Step 14) Check S/I flow:

BOP . Check NV PMPS TO COLD LEG NOTE: If 1NV- lOB has NOT FLOW gauge INDICATING FLOW.

been opened, it will be opened here.

. Check NC pressure LESS THAN 1600 PSIG.

. Check NI pumps INDICATING FLOW.

. Check NC pressure Less than 286 PSIG.

BOP (Step 15.d RNO) Perform the following:

. Ensure ND pump miniflow valve on running pump(s) open:

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

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

CRS . IF valve(s) open on all running ND pumps, THEN GO TO Step 15.

CRS (Step 15) Notify OSM or other SRO to NOTE: The CRS may ask perform EP/1/N5000/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.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 7, 8 & 9 Page 39 of 50 Event

Description:

Rod EjectionlSB LOCAIINJ-9AIIOB fail to OPEN automatically I Phase A Containment Isolation Auto Signal failure Time Pos. Expected ActionslBehavior Comments BOP (Step 16) Check CA flow:

. Total CA flow GREATER THAN 450 GPM.

. Check VI header pressure GREATER THAN 60 PSIG.

WHEN N/R level in any SIG greater than NOTE: This is a Continuous 1 1% (32% ACC), THEN control CA flow Action. The CRS will make to maintain N/R levels between 1 1% both board operators aware.

(32% ACC) and 50%.

NOTE: The use of adverse Containment numbers is required if Containment Pressure is> 3 psig.

RO (Step 17) Check NC temperatures: NOTE: The NC Pumps could be on or off depending on NC Subcooling and Containment Pressure.

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

OR

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

BOP (Step 18) Check Pzr PORV and spray valves:

. All Pzr PORVs CLOSED.

. Normal Pzr spray valves CLOSED RO (Step 19) Check NC subcooling based on core exit T/Cs GREATER THAN 0°F.

BOP (Step 19 RNO) IF at least one NV OR NI pump on, THEN stop all NC pumps while maintaining seal injection flow.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 7, 8 & 9 Page 40 of 50 Event

Description:

Rod Ejection!SB LOCAIINI-9AIIOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure Time Pos. Expected ActionslBehavior Comments RO (Step 20) Check if main steamlines intact:

. All S/G pressures STABLE OR GOING UP

. All S/Gs PRESSURIZED.

RO! (Step 21) Check if S/G tubes intact:

BOP

. The following secondary EMFs NORMAL:

. 1 EMF-33 (Condenser Air Ejector Exhaust) 1 EMF-34(L) (S/G Sample (Lo Range))

. 1EMF-24(S/GA)

. 1EMF-25(S/G B)

. 1EMF-26(S/GC)

. IEMF-27 (S/G D)

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

RO! (Step 22) Check if NC System intact:

BOP

. Check containment EMF5 NORMAL: NOTE: I EMF-38L is in TRIP 2.

. IEMF-38(L) (Containment Particulate (LR))

. I EMF-39(L) (Containment Gas (Lo Range))

. 1 EMF-40 (Containment_Iodine)

. IEMF-9 (Reactor Bldg Incore Inst Rm)

Appendix D Operator Action Form ES-D2 Op Test No.: Nb-i Scenario # 1 Event # 7, 8 & 9 Page 41 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure Tim p FvrrftI ( rm 111

. 1EMF-16 (Containment Refueling Brdg).

BOP (Step 22 RNO) Perform the following:

IF H2 Igniters are off, THEN perform the NOTE: The H2 lgniters are following: OFF.

. Energize H2 Igniters by depressing ON and OVERRI DE.

. Dispatch operator to stop all NOTE: The CRS will dispatch Unit 1 NF AHUs PER an NEC.

EP/IIAI5000IG-1 (Generic Booth Instructor: as NEO Enclosures), Enclosure 28 acknowledge (De-energizing Ice Condenser AHU5).

CRS

• IF AT ANY TIME both of the following NOTE: Neither condition conditions exist, THEN start one train of exists.

VX PER ENCLOSURE 4 (VX Manual Start).

• Containment pressure is between 1 PSIG and 3 PSIG....

NOTE: Upon transition to E-1, an ORANGE Path will exist on Containment.

The CRS will transition to FR Z.1, rather than E-1.

RESPONSE TO HIGH CONTAINMENT PRESSURE CRS (Step 1) IF loss of emergency coolant recirc NOTE: Loss of Emergency has occurred, THEN .... Coolant Recirc has NOT occurred.

RO/ (Step 2) Monitor Foldout Page.

BOP

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # I Event # 7, 8 & 9 Page 42 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically I Phase A Containment Isolation Auto Signal failure Time Pos. Expected Actions/Behavior Comments BOP (Step 3) Stop all NC pumps. NOTE: All NC Pumps are stopped.

BOP (Step 4) Ensure all RV pumps are in manual and off.

BOP (Step 5) Ensure operator dispatched to NOTE: The CR5 will dispatch remove white tags and close the following NEO.

breakers:

FloorlBooth Instructor:

Acknowledge as appropriate.

. I EMXA-R2A (IA ND To A&B Cold Legs Cont Outside Isol Motor (lNl-173A)) (aux bldg, 750, FF-54, FF-55)

. IEMXB1-6B (lB ND To C&D Cold Leg Booth Instructor:

Cont Outside lsol Motor (lNl-178B)) (aux Operate Trigger #15 (LOA bldg, 733, GG-55, GG-56) N1024 = RI (2 minutes delayed)) and Trigger #17 (LOA-N 1025 = RI (3 minutes delayed)).

And then, report as NEO that breakers are closed.

BOP (Step 6) Check containment pressure NOTE: Containment pressure LESS THAN 15 PSIG. is 3 psig due to the LOCA.

BOP (Step 7) Check any NS pump ON. - NOTE: Both NS Pumps are ON.

CRS (Step 8) Perform the remainder of this EP as NOTE: The CRS may time allows, continue with FR-Z.1 or Transition to E-1.

If Transition is made here, moved forward to Page 45.

BOP (Step 9) Check containment isolation:

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 1 Event # 7, 8 & 9 Page 43 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically I Phase A Containment Isolation Auto Signal failure Time Pos. ExDected ActionslBehavior Comments

. Check OAC IN SERVICE.

. Check the following windows on Group 4 of ESF Monitor light Panel LIT.

. C-3 CONT ISOL PHASE A TRN A VLVS ALIGNED

. C-6 CONT ISOL PHASE A TRN B VLVS ALIGNED

. G-4 CONT ISOL PHASE B TRN A VLVS ALIGNED

. G-5 CONT ISOL PHASE B TRN B VLVS ALIGNED.

BOP (Step 10) Check NS System in operation as follows:

. Check EP/1/N5000/ECA-1.1 (Loss of NOTE: Loss of Emergency Emergency Coolant Recirc) IN Coolant Recirc is NOT in EFFECT. effect.

CRS (Step 10.a RNO) GO TO Step 10.d.

BOP * (Step 10.d) Check NS suction ALIGN ED TO FWST AS FOLLOWS:

• Check 1NS-18A (1A NS Pump Suct From Cont Sump Isol) CLOSED

• Check 1NS-20A (1A NS Pump Suct From FWST Isol) OPEN

• Check INS-lB (lB NS Pump Suct From Cont Sump Isol) CLOSED

• Check 1NS-3B (lB NS Pump Suct From FWST Isol) OPEN BOP

• Check containment pressure NOTE: Containment pressure GREATER THAN 3 PSIG. is 4 psig due to the LOCA.

BOP

• Check the following NS pump discharge valvesOPEN:

• 1NS-32A (1A NS Hx Outlet Cont Outside Isol)

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Eyent # 7, 8 & 9 Page 44 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure Time Pos. Expected ActionslBehavior Comments

. 1NS-29A (IA NS Hx Outlet Cont Outside Isol)

. 1NS-12B (lB NS HxOutlet Cont Outside Isol)

. I NS-1 5B (1 B NS Hx Outlet Cont Outside Isol)

BOP

• Check NS pumps ON.

CRS (Step II) Check Phase B HVAC equipment NOTE: The CRS may ask U2 PER Enclosure 3 (Phase B HVAC BOP to perform this action.

Equipment).

If so, Floor Instructor:

Acknowledge as U2 BOP.

RD (Step 12) Check the following CLOSED:

. AIIMSIVs

. All MSIV bypass valves.

RD (Step 13) Check steamlines intact:

. All SIG pressures STABLE OR GOING UP

. All S/Gs PRESSURIZED.

BOP (Step 14) Check if one or two trains of ND aux containment spray should be aligned as follows:

. Any ND Train OPERATING IN COLD LEG RECIRC MODE.

BOP (Step 14.a RNO) Perform the following:

. WHEN EPI1IA/5000IES-1.3 (Transfer To NOTE: This is a Continuous Cold Leg Recirc), is completed, THEN Action. The CRS will make perform Step 14 to determine if one or both board operators aware.

two trains of ND aux spray should be aligned.

CRS GOTOStep15.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 7, 8 & 9 Page 45 of 50 Event

Description:

Rod EjectionlSB LOCA!INI-9A!IOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure Time Pos. Expected ActionslBehavior Comments BOP (Step 15) Check containment H 2 NOTE: The H2 Analyzers are concentration: NOT in service.

• Ensure operator dispatched to stop Unit 1 NF AHUs PER EP/1/A/5000/G-1 (Generic Enclosures), Enclosure 28 (De energizing Ice Condenser AHUs).

. Check H 2 analyzers IN SERVICE.

BOP (Step 15 RNO) Perform the following: NOTE: The CRS will dispatch NEO.

Floor!Booth Instructor:

Acknowledge as appropriate.

Dispatch operator to place H2 analyzers in service PER EP/1/A/5000/G-1 (Generic Enclosures), Enclosure 5 (Placing H2 Analyzers In Service).

. WHEN H2 analyzers in service, THEN Booth Instructor: Wait 15 complete Steps 15.c through 15.e. minutes, Insert LOA:

VXOO9 = In Service!Enabled VXOIO In Service/Enabled And then, report as NEO that H2 Analyzers are in service.

CRS . GOTOStepl6.

CRS (Step 16) RETURN TO procedure and step NOTE: The CRS will in effect. transition to E-1.

NOTE: CRS will likely conduct a Focus Brief.

EP!1/AI5000IE-1, LOSS OF REACTOR OR SECONDARY COOLANT RO/ (Step 1) Monitor Foldout page. Examiner NOTE: After Transition to E-1, terminate BOP scenario at Lead Examiner discretion.

Appendix D Operator Action Form ES-D-2 Op Test No.: N 10-1 Scenario # 1 Event # 7, 8 & 9 Page 46 of 50 Event

Description:

Rod Ejection/SB LOCAIINI-9AIIOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure Time Pos. Expected ActionslBehavior Comments RO (Step 2) Check NC subcooling based on core NOTE: The NC Pumps should exit T/Cs GREATER THAN 0°F.

be stopped by this time, even if Subcooling is recovering.

RO (Step 3) Check if main steamlines intact:

. All S/G pressures STABLE OR GOING UP

. All S/Gs PRESSURIZED.

(Step 4) Control intact S/G levels:

RO . Check N/R level in any intact S/G NOTE: Adverse Containment GREATER THAN 11% (32% ACC). Numbers will be used.

BOP . Check VI header pressure GREATER THAN 60 PSIG.

RO . Throttle feed flow to maintain all intact NOTE: Adverse Containment S/G N/R levels between 1 1% (32% ACC) Numbers will be used.

and 50%.

CRS (Step 5) Check secondary radiation normal as follows:

. Check all S/Gs INTACT.

. Notify RP to perform the following: NOTE: The CRS may call WCC/RP to address the switch position.

If so, Booth Instructor acknowledge as WCC/RP.

. Frisk all Unit I S/G cation columns to determine if activity level is significantly_higher for any S/G.

. Notify Control Room of survey results.

CRS

• WHEN survey results reported, THEN NOTE: This is a Continuous perform the following: Action. The CRS will make both board operators aware.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # I Event # 7, 8 & 9 Page 47 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically I Phase A Containment Isolation Auto Signal failure Time Pos Expected ActionslBehavior Comments

. Check all S/G(s) activity levels NORMAL.

BOP

• Check secondary EMFs NORMAL:

. 1 EMF-33 (Condenser Air Ejector Exhaust)

• IEMF-34(L) (S/G Sample (Lo Range))

. IEMF-24(SIGA)

• 1EMF-25(S/GB)

. IEMF-26(S/GC)

. IEMF-27(S/GD).

BOP (Step 6) Check Pzr PORVs and isolation valves:

. Power to all Pzr PORV isolation valves AVAILABLE.

• All Pzr PORVs CLOSED.

• At least one Pzr PORV isolation valve OPEN.

• IF AT ANY TIME any Pzr PORV opens NOTE: This is a Continuous due to high pressure, THEN after Action. The CRS will make pressure goes below 2315 PSIG, ensure both board operators aware.

PORV closes or is isolated.

RO/ (Step 7) Check S/I termination criteria:

BOP

• NC subcooling based on core exit T/Cs GREATER THAN 0°F.

• Secondary heat sink:

• N/R level in at least one intact SIG GREATER THAN 11%

(32% ACC)

OR

• Total feed flow to intact S/Gs GREATER THAN 450 GPM.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 1 Event # 7, 8 & 9 Page 48 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9AIIOB fail to OPEN automatically I Phase A Containment Isolation Auto Signal failure Time Pos. ExDected Actions!Behavior Comments

. NC pressure STABLE OR GOING UP.

. Pzr level GREATER THAN 11% (29% NOTE: Pzr Level is NOT>

ACC). 11% (29%).

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

. If NC pressure going up, AND NOTE: Pzr Spray is NOT Pzr spray available, THEN.... available.

• GOTOStep7.f RO/ . Monitor S/I termination criteria PER Enclosure 2 (S/I Termination Criteria)

BOP while in the procedure.

. IF AT ANY TIME while in this procedure NOTE: This is a Continuous S/I termination criteria is met, THEN Action. The CRS will make RETURN TO Step 7. both board operators aware.

BOP (Step 8) Check if NS pump should be stopped:

. AnyNSpumpON. NOTE: The NS Pumps are both ON.

. Containment pressure LESS THAN 2 NOTE: Containment pressure PSIG. is 4 psig due to the LOCA.

BOP (Step 8.b RNO) Perform the following:

. IF NS pump suction has been aligned for NOTE: Neither NS Pump has Cold Leg Recirc, THEN been aligned for Cold Leg Recirc.

CRS IF AT ANY TIME containment pressure is NOTE: This is a Continuous less than 2 PSIG, AND NS pump suction Action. The CRS will make is still aligned to FWST, THEN perform both board operators aware.

Step 8.

CRS

• GO TO Step 9.

BOP (Step 9) Check if ND pumps should be stopped:

. NC pressure GREATER THAN 286 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # I Event # 7, 8 & 9 Page 49 of 50 Event

Description:

Rod EjectionlSB LOCAIINI-9A/IOB fail to OPEN automatically!

Phase A Containment Isolation Auto Signal failure Time Pos. Expected Actions!Behavior Comments

. NC pressure STABLE OR GOING UP.

. Any ND Pump ON.

. Running ND Pumps Suction ALIGNED TO FWST.

. Check both NS Pumps OFF. NOTE: Both NS Pumps are running.

CRS (Step 9.e RNO) Go To Step 10.

RO (Step 10) Check NC and S/G pressures:

. All S/G pressures STABLE OR GOING UP.

. NC pressure STABLE OR GOING NOTE: NC System pressure DOWN. is rising.

CRS (Step 10.b RNO) RETURN TO Step I. NOTE: The CRS will return to Step 1 of E-1, and await transition to ES-1.3 Criteria.

At the discretion of the Lead Examiner terminate the exam.

UNIT I STATUS:

Power Level: 99% NCS [B] 1310 ppm Pzr [B]: 1326 ppm Xe: Per OAC Power History: The Plant is at 99% power (BOL), for Core Burnup: 12 EFPDs three days.

CONTROLLING PROCEDURE: OP/i 1AJ6100103 Controlling Procedure for Unit Operation OTHER INFORMATION NEEDED TO ASSUME TO SHIFT:

• The plant is at 99% power (BOL), following an unplanned load reduction four days ago to complete corrective maintenance on the ,1 B CF Pump.

• The maintenance was completed and the pump restarted, and power level raised to the present power level three days ago.

• The I B CF Pump is operating in MANUAL Control, for Vendor observation.

• Upon Turnover the crew is expected to restore the I B CF Pump to Auto Control.

The following equipment is Out-Of-Service:

• 1A DIG is OOS to correct a cooling water system leak.

• 1 EMF45A, Nuclear Service Water Radiation Monitor, failed last shift (IAE is investigating).

• MCB Annunciator 1AD-9, 0-6, GLYCOL EXPANSION TNK HI-HI LEVEL, has alarmed spuriously several times over the last hour (IAE is investigating).

Crew Directions:

• Return the lB CF Pump to automatic control in accordance with Enclosure 4.14, Changing CF Pump Auto/Manual Control, of OP/i/AJ62501001, Condensate and Feedwater System.

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

Duke Energy Procedure No.

McGuire Nuclear Station /A/6250/OO1 Condensate And Feedwater System Revision No.

176 Electronic Reference No.

MC00474P Continuous Use PERFORMANCE I

• * * * * * * * * *UNCQNTRQLLEDFORPRII4T* * * * * * * * * *

(ISSUED) PDF Format

Enclosure 4.14 OP/l/A/6250/ool Changing CF Pump Auto / Manual Control Page 1 of 9

1. Limits and Precautions 1.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing NC System temperature. (R.M,)

1.2 Maximum CF Header Pressure is 1325 psig. CF Pump Turbine trip occurs at 1435 psig.

2. Initial Conditions 2.1 IF in Mode 1 OR 2, ensure reactivity management controls established per SOMP 01-02 (Reactivity Management). (R.M.)

3. Procedure LI 3.1 Evaluate all outstanding R&Rs that may impact performance of this procedure.

3.2 Perform the following sections, as applicable:

LI Section 3.3, Placing CF Pump(s) in Manual Mode LI Section 3.4, Placing CF Pump(s) in L-manual (Local Manual) Mode LI Section 3.5, Adjusting Bias With CF Pump(s) in Auto LI Section 3.6, Placing CF Pump in Auto During At Power Operation Unit 1

Enclosure 4.14 oP/1/A/625o/ool Changing CF Pump Auto / Manual Coiltrol Page 2 of 9 3.3 Placing CF Pump(s) in Manual Mode 3.3.1 Determine CF Pump Turbine to be placed in manual control:

D IA CF Pump Turbine O lB CF Pump Turbine 3.3.2 On selected CF Pump Turbine, perform the following:

• Place LP GOV CNTRL in manual

• Place HP GOV CNTRL in manual NOTE: Adjusting CF Pump speed will cause a change in feedwater flow and can result in the addition of relatively cold feedwater to the steam generators. (R.M.)

3.3.3 j the second CF Pump Turbine is NOT in auto, use manual raise or lower pushbutton on LP GOV CNTRL or HP GOV CNTRL as required to maintain stable CF flow and S/G levels.

3.3.4 j desired to place second CF Pump Turbine in manual control, perform the following on the second CF Pump Turbine:

• Place LP GOV CNTRL in manual

• Place HP GOV CNTRL in manual NOTE: Adjusting CF Pump speed will cause a change in feedwater flow and can result in the addition of relatively cold feedwater to the steam generators. (R.M.)

3.3.5 Using manual raise or lower pushbutton on 1A (1B) CF Pump Turbine LP GOV CNTRL or HP GOV CNTRL, maintain stable CF flow and S/G levels.

Unit 1

Enclosure 4.14 oP/1/A/625o/ool Changing CF Pump Auto / Manual Control Page 3 of 9 3.4 Placing CF Pump(s) in h-manual (Local Manual) Mode CAUTION: Placing a CF Pump Gov. Cntrl in L-manual bypasses all DCS system signals and gives the operator direct valve control. MANUAL control should be utilized if available.

3.4.1 Determine CF Pump Turbine to be placed in L-manual control:

0 1 A CF Pump Turbine 0 1 B CF Pump Turbine 3.4.2 On selected CF Pump Turbine, perform the following:

• Place LP GOV CNTRL in L-manual

. Place HP GOV CNTRL in L-manual NOTE: Adjusting CF Pump speed will cause a change in feedwater flow and can result in the addition of relatively cold feedwater to the steam generators. (R.M.)

3.4.3 IF the second CF Pump Turbine is NOT in auto, use L-manual raise or lower pushbutton on LP GOV CNTRL or HP GOV CNTRL as required to maintain stable CF flow and S/G levels.

CAUTION: Placing a CF Pump Gov. Cntrl in L-manual bypasses all DCS system signals and gives the operator direct valve control. MANUAL control should be utilized if available.

3.4.4 j desired to place the second CF Pump Turbine in L-manual control, perform the following on the second CF Pump Turbine:

. Place LP GOV CNTRL in L-manual

• Place HP GOV CNTRL in L-manual NOTE: Adjusting CF Pump speed will cause a change in feedwater flow and can result in the addition of relatively cold feedwater to the steam generators. (R.M.)

3.4.5 Using h-manual raise or lower pushbutton on IA (1B) CF Pump Turbine LP GOV CNTRL or HP GOV CNTRL, maintain stable CF flow and S/G levels.

Unit 1

Enclosure 4.14 OP/1/A/6250/OO1 Changing CF Pump Auto / Manual Control Page 4 of 9 3.5 Adjusting Bias With CF Pump(s) in Auto NOTE: CF Pump bias is available only on the DCS soft controls via Feedpump Overview Graphic LP/HP Gov Cntrl pop-up.

3.5.1 Determine one of the following:

U Desired Pump RPM OR U Desired RPM Mismatch OR U Desired CF Pump Suction Flow Mismatch 3.5.2 On DCS Feedpump Overview Graphic, select one of the following:

U CFPT A LP/HP U CFPT B LP/HP NOTE:

• Adjusting CF Pump speed will cause a change in feedwater flow and can result in the addition of relatively cold feedwater to the steam generators. (R.M.)

• The following step should be performed SLOWLY allowing the CF Pump suction flows to stabilize between adjustments.

3.5.3 Using BIAS raise or lower pushbutton on selected CF Pump Turbine LP GOV CNTRL, slowly adjust BIAS to achieve desired Pump RPM, RPM Mismatch or Suction Flow Mismatch as determined in Step 3.5.1. (R.M.)

Unit 1

Enclosure 4.14 QP/1/A/6250/001 Changing CF Pump Auto / Manual Control Page 5 of 9 3.6 Placing CF Pump in Auto During At Power Operation 3.6.1 Check one CF Pump currently operating in auto:

D 1ACFPump OR D 1BCFPump NOTE: L-manual for each CF Pump Turbine Gov is only available on the Main Control Board.

3.6.2 IF placing 1A CF Pump Turbine in auto, perform the following:

3.6.2.1 jj. 1A CF Pump Turbine in L-manual, perform the following:

A. Check the following:

D 1A CF Pump Turbine LP GOV CNTRL in L-manual D 1A CF Pump Turbine HP GOV CNTRL in L-manual B. Using L-manual raise or lower pushbuttons on 1A CF Pump Turbine HP GOV CNTRL, match OUTPUT value

(+/- 2%) to OUTPUT value on lB CF Pump Turbine HP GOV CNTRL.

C. Place lA CF Pump Turbine HP GOV CNTRL in manual.

D. Using L-manual raise or lower pushbuttons on 1A CF Pump Turbine LP GOV CNTRL, match OUTPUT value

(+/- 2%) to OUTPUT value on lB CF Pump Turbine LP GOV CNTRL.

LI E. Check 1A CF Pump Turbine speed and lB CF Pump Turbine speed within 100 200 rpm.

F. Place 1A CF Pump Turbine LP GOV CNTRL in manual.

Unit 1

Enclosure 4.14 QP/1/A/6250/001 Changing CF Pump Auto / Manual Control Page 6 of 9 3.6.2.2 IF IA CF Pump Turbine in manual, perform the following:

A. Check the following:

EJ 1A CF Pump Turbine LP GOV CNTRL in manual D IA CF Pump Turbine HP GOV CNTRL in manual NOTE: The following indications are on DCS Feedpump Overview Graphic.

B. Using raise or lower pushbutton(s) on 1A CF Pump Turbine LP GOV CNTRL/HP GOV CNTRL as required, slowly adjust 1 A CF Pump Turbine speed to match 1 B CF Pump Turbine speed (within 100 200 RPM) while monitoring the following:

EJ FPA DEM (Feedpump A Demand) in RPM U Sel SPD (FPA Selected Speed) in RPM U FPB DEM (Feedpump B Demand) in RPM U SEL SPD (FPB Selected Speed) in RPM U AUTO SPT (Auto Setpoint signal to both CF Pumps) in RPM NOTE: WHEN placing IA CF Pump in auto, the CF Pumps will converge to match AUTO SPT.

C. Place IA CF Pump Turbine in auto as follows:

1. Determine governor that is controlling flow:

U IA CF Pump Turbine LP GOV CNTRL U IA CF Pump Turbine HP GOV CNTRL

2. Place governor that is controlling flow in auto:

U IA CF Pump Turbine LP GOV CNTRL OR U IA CF Pump Turbine HP GOV CNTRL Unit 1

Enclosure 4.14 OP/1/A/6250/oo1 Changing CF Pump Auto I Manual Control Page 7 of 9

3. Place the other governor in auto:

D IA CF Pump Turbine LP GOV CNTRL OR D 1A CF Pump Turbine HP GOV CNTRL Q 3.6.2.3 Check S/G levels and CF flows stable.

3.6.3 IF placing lB CF Pump Turbine in auto, perform the following:

3.6.3.1 IF lB CF Pump Turbine in L-manual, perform the following:

A. Check the following:

D lB CF Pump Turbine LP GOV CNTRL in L-manual D lB CF Pump Turbine HP GOV CNTRL in L-manual B. Using L-manual raise or lower pushbuttons on lB CF Pump TurbineHP GOV CNTRL, match OUTPUT value

(+/- 2%) to OUTPUT value on IA CF Pump Turbine HP GOV CNTRL.

C. Place lB CF Pump Turbine HP GOV CNTRL in manual.

D. Using L-manual raise or lower pushbuttons on lB CF Pump Turbine LP GOV CNTRL, match OUTPUT value

(+/- 2%) to OUTPUT value on IA CF Pump Turbine LP GOV CNTRL.

D B. Check lB CF Pump Turbine speed and 1A CF Pump Turbine speed within 100 200 rpm.

F. Place lB CF Pump Turbine LP GOV CNTRL in manual.

Unit 1

Enclosure 4.14 oP/1/A/625o/ool Changing CF Pump Auto / Manual Control Page 8 of 9 3.6.3.2 IF lB CF Pump Turbine in manual, perform the following:

A. Check the following:

LI lB CF Pump Turbine LP GOV CNTRL in manual LI lB CF Pump Turbine HP GOV CNTRL in manual NOTE: The following indications are on DCS Feedpump Overview Graphic.

B. Using raise or lower pushbutton(s) on I B CF Pump Turbine LP GOV CNTRL/HP GOV CNTRL as required, slowly adjust lB CF Pump Turbine speed to match 1A CF Pump Turbine speed (within 100 200 RPM) while monitoring the following:

LI FPB DEM (Feedpump B Demand) in RPM LI Sel SPD (FPB Selected Speed) in RPM LI FPA DEM (Feedpump A Demand) in RPM LI SEL SPD (FPA Selected Speed) in RPM LI AUTO SPT (Auto Setpoint signal to both CF Pumps) in RPM NOTE: WHEN placing lB CF Pump in auto, the CF Pumps will converge to match AUTO SPT.

C. Place lB CF Pump Turbine in auto as follows:

1. Determine governor that is controlling flow:

.LI lB CF Pump Turbine LP GOV CNTRL LI lB CF Pump Turbine HP GOV CNTRL

2. Place governor that is controlling flow in auto:

LI lB CF Pump Turbine LP GOV CNTRL OR LI lB CF Pump Turbine HP GOV CNTRL Unit 1

Enclosure 4.14 OP/1/A/6250/ool Changing CF Pump Auto / Manual Control Page 9 of 9

3. Place the other governor in auto:

D lB CF Pump Turbine LP GOV CNTRL OR 0 lB CF Pump Turbine HP GOV CNTRL O 3.6.3.3 Check S/G levels and CF flows stable.

End of Enclosure Unit 1

PROGRAM: McGuire Operations Training MODULE: nitial License Operator Training Class 26 TOPIC: NRC Simulator Exam Scenario N10-1-2

REFERENCES:

1. OP/1/A16100/010 C, Annunciator Response for Panel 1AD-2.

2. OP/1/A/6102/003, DCS System Operation.

3. API1/A15500101, Steam Leak

4. Technical Specification 3.4.1, RCS Pressure, Temperature and Flow Departure from Nucleate Boiling (DNB) Limits.

5. Specification 3.5.2, ECCS System Operating.

6. Technical Specification 3.0.3

7. AP/1 /A15500104, Rapid Downpower.

8. OP/1/A/6150/009, Boron Concentration Control.

9. OAC Alarm M1P1367, UI TAVGTREF.

10. AP/1/A/5500/14, Rod Control Malfunctions.

11. OAC Alarm M1D3041, IA NC PUMP VIBRATION

12. AP/1/A/5500/08, Malfunction of NC Pump.

13. EP/1/A/5000/E-0, Reactor Trip or Safety Injection.

14. EP/1/A/5000/ES-0.1, Reactor Trip Response.

15. EP/1/A/5000/E-3, Steam Generator Tube Rupture.

Author: David Lazarony, Western Technical Services, Inc.

Facility Review:

Rev. 070710 1

Scenario Event Description NRC Scenario 2 Facility: McGuire Scenario No.: 2 Op Test No.: Nb-I Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The Plant is at 56% power (MOL), following a plant startup and load ascension four days ago to this power level. The power ascension was halted due to unusually high vibrations on the 1A NCP. The System Engineer has been monitoring the NCP, and vibration levels have stabilized out at normally expected levels. A load ascension is expected soon, but not planned for this shift.

Turnover: The following equipment is Out-Of-Service: lB ND Pump is OOS for motor replacement. 1EMF46A, Train A KC Radiation Monitor, failed last shift (IAE is investigating) and MCB Annunciator IAD-12, F-5, FWST EMERGENCY LOW TEMPERATURE, has alarmed even though FWST Temperature is normal (IAE is investigating).

Event MaIf. Event Type* Event No. No. Description 1 NVOO1 C-BOP VCT Controller Failure C-SRO 2 SMOO2B C-RO 1 B SG PORV Fails OPEN C(TS)-SRO 3 NA C (TS)-SRO 1A ND Pump is OOS 4 NA R-RO Rapid Downpower N-BOP N-SRO 5 IREOO9 C-RO Control Rods fail to move in AUTO C-SRO 6 NCPOO3A C-BOP High Vibrations 1A NCP C-SRO 7 SGOO1 B M-RO SGTR M-BOP M-SRO OVR 8 SBOO4A NA Steam Dump System fails to operate SBOO4A (N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Scenario Event Description NRC Scenario 2 McGuire 2010 NRC Scenario #2 The Plant is at 56% power (MOL), following a plant startup and load ascension four days ago to this power level. The power ascension was halted due to unusually high vibrations on the 1A NCP. The System Engineer has been monitoring the NCP, and vibration levels have stabilized out at normally expected levels. A load ascension is expected soon, but not planned for this shift.

The following equipment is Out-Of-Service: lB ND Pump is DOS for motor replacement.

1EMF46A, Train A KC Radiation Monitor, failed last shift (IAE is investigating) and MCB Annunciator 1AD-12, F-5, FWST EMERGENCY LOW TEMPERATURE, has alarmed even though FWST Temperature is normal (IAE is investigating).

Shortly after taking the watch, the VCT level controller will fail High. The operator will respond in accordance with MCB Annunciator IAD-2, F8, DCS ALTERNATE ACTION, and go to OP/1/A/6102/003, DCS System Operation, Enclosure 4.4, Removing/Returning a VCT Level Channel From/To Service.

After this, the I B SG PORV will fail fully OPEN. The operator will enter AP/1/A/5500/0l, Steam Leak, and stabilize the plant. The operator will address Technical Specification 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits.

Subsequently, the 1A ND Pump is discovered to be inoperable. The operator will address Technical Specification 3.5.2, ECCS System Operating, and determine that an entry into Technical Specification 3.0.3 is needed, and a shutdown to Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> will be required.

Shortly after this, the operator will enter AP/1/A/5500/04, Rapid Downpower, and decrease load to enter mode 3.

During the downpower, the control rods will fail to move in AUTO. The operator will respond in accordance with OAC Alarm M1P1367, UI TAVG TREF (HALM), and enter AP/I/A/5500/14, Rod Control Malfunctions, and take Manual control of the rods.

As the downpower continues, a high vibration condition will develop on the IA NCP. The operator will respond in accordance with OAC Alarm M1D3041, IA NC PUMP VIBRATION (HALM), and enter AP/I/A/5500/08, Malfunction of NC Pump. The operator will eventually manually trip the reactor, and then stop the 1A NCP.

Upon reactor trip, the operator will enter EP/l/A/5000/E-0, Reactor Trip or Safety Injection.

Simultaneous with the Reactor Trip, a 700 gpm SGTR to occur in the 1 C Steam Generator, and, although the operator may transition to EPJI/A/5000/ES-0.l, Reactor Trip Response, the operator will eventually manually actuate Safety Injection and complete E-0.

Upon completion of E-0, the operator will transition to EP/l/A/5000!E-3, Steam Generator Tube Rupture, and isolate the flow into and out of the IC Steam Generator and then conduct a cooldown of the NC System. When the operator attempts to conduct a cooldown of the NC System, the Steam Dumps will fail to operate, and the cooldown will need to be accomplished using the Steam Generator PORVs on the intact Steam Generators.

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.

Scenario Event Description NRC Scenario 2 Critical Tasks:

E-3A Isolate feedwater flow into and steam flow from the ruptured SG before a transition to ECA-3.1 occurs.

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 SGs, requiring a transition to a contingency procedure, and delaying the stopping of RCS leakage into the SG.

E-3B Establishlmaintain an RCS temperature so that transition from E-3 does not occur because RCS temperature is either too high to maintain minimum required subcooling, or too low causing an Orange path on Subcriticality or Integrity.

Safety Significance: Failure to establish and maintain the correct RCS temperature during a SGTR leads to a transition from E-3 to a contingency procedure which constitutes an incorrect performance that necessitates the crew taking compensating action which complicates the event mitigation strategy. If the RCS temperature is too high when RCS depressurization is started, a loss of subcooling will occur when the RCS depressurization is started. On the other hand, if RCS temperature is allowed to continue to decrease after the initial cooldown, the operator may be required to transition to the Subcriticality or Integrity response FRP, and delay the RCS depressurization.

Scenario Event Description NRC Scenario 2 SIMULATOR OPERATOR INSTRUCTIONS Bench Mark ACTIVITY DESCRIPTION Q Sim. Setup Rod Step On Q Reset to Temp I/C T 0 Malfunctions:

158. ANN ADII-C05 = ON, Transformer lights ANN ADII-B05 = ON, Transformer lights ANN ADII-E05 = ON, Transformer lights ANN ADII-F05 = ON, Transformer lights MALF-EMFI46A = IE+7, IEMF46A, Train A KC Radiation Monitor ANN ADI2 F05 = ON LOA-NDOO3 = Racked Out, lB ND Pump OOS RUN Place Stickers on:

Q lB ND (Tagout)

Reset all SLIMs IEMF46A (0-Stick)

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

Setup OAC Q Freeze.

Q Update Fresh Tech.

Spec. Log.

J Fill out the NEOs Available section of Shift Turnover Info.

Q Prior to Crew RUN Briefing

Scenario Event Description NRC Scenario 2 Bench Mark ACTIVITY DESCRIPTION Q Crew Briefing

1. Assign Crew Positions based on evaluation requirements

2. Review the Shift Turnover Information with the crew.

3. Provide T-SAIL Entry for I B ND.

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

Q T-O Begin Familiarization -__________________________

Period J At direction of Event I VCT Controller Failure examiner (XMT) NVOOI Set = 100%

No Ramp Trigger #1 Q At direction of Event 2 1 B SG PORV Fails OPEN examiner (MALF) SMOO3B Set = 100%

No Ramp Trigger #3 Q At direction of Event 3 IA ND Pump is OOS examiner (LOA) NDOO2 = Racked Out Trigger #5 At direction of Event 4 Rapid Down power examiner Q Continued Event 5 Control Rods fail to move in AUTO from Event 4 (MALF) IREOO9 = 0 (AUTO ONLY)

Trigger #7

-6

Scenario Event Description NRC Scenario 2 Bench Mark ACTIVITY DESCRIPTION Q At direction of Event 6 High Vibrations 1A NCP examiner (MALF) NCPOO3A = 18 No Ramp NOTE: This malfunction will be subsequently

. set to 30, causing the NCP trip criteria to be Trigger #9 met.

Q Continued Event 7 SGTR from Event 6 (MALF) SGOOIC = 700 gpm NOTE: Trigger #11 will be operated on the No Ramp Reactor Trip.

Trigger #11 Q Continued Event 8 Steam Dump System fails to operate from Event 7 (OVR) SBOO4A = ON (OFF Reset)

NOTE: Trigger #11 will be operated on the (OVR) SBOO4B = ON Reactor Trip.

(OFF Reset) . .

NOTE: Trigger #13 (3 minute delayed) will be Trigger #11 operated during the SGTR to isolate the Steam Supply from the IC SG, to the UI TD CA PUMP (LOA-5A002 = 0).

Terminate the scenario upon direction of Lead Examiner Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 1 Page 8 of 51 Event

Description:

VCT Controller Failure Shortly after taking the watch, the VCT level controller will fail High. The operator will respond in accordance with MOB Annunciator 1AD-2, F8, DOS ALTERNATE ACTION, and go to OPI1/A16102/003, DOS System Operation, Enclosure 4.4, Removing/Returning a VCT Level Channel From/To Service.

Booth Operator Instructions: Operate Trigger #1 (XMT-NVOOI (100))

Indications Available:

. MCB Annunciator 1AD-7 D3, VCT ABNORMAL (Momentary)

. MCB Annunciator 1AD-2 E8, DCS TROUBLE

. MCB Annunciator IAD-2 F8, DCS Alternate Action

. VCT Level (1NVP-5760) indicates 100%

. VCT Level (1 NVP-5763) indicates that the level is lowering.

. VCT Level SLIM shifts into MANUAL Time Pos. Expected ActionslBehavior Comments NOTE: The BOP may address ARP for 1AD-7, D3 NOTE: The CRS may direct the BOP to place I NV-i 37 to VCT position.

MCB ANNUNCIATOR IAD-2, F8 DCS ALTERNATE ACTION CRS (Step 1) Halt any power change in progress.

BOP (Step 2) Check DCS Workstation alarms.

DCS WORKSTATION ALARMS M1D1168, VCT LEVEL ALTERNATE ACTION BOP (Step 1) Manually control VCT level at desired valve.

CRS (Step 2) Write work request and investigate repair.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 1 Page 9 of 51 Event

Description:

VCT Controller Failure Time Pos. Expected ActionslBehavior Comments CRS (Step 3) GO TO OP/1/A/6102/002 (DOS System Operation).

NOTE: The ORS will transition to 0P111A16102/002.

0P111A16102/002, DCS SYSTEM OPERATION ENCLOSURE 4.4, REMOVINGIRETURNING A VCT LEVEL CHANNEL FROM/TO SERVICE BOP (Step 3.1) Performing the following section, as applicable:

• Section 3.2, To Respond To An Alternate Action.

BOP * (Step 3.2.2) On DOS Boric Acid Blender graphic, perform the following:

• Select 2XS for VCT Level 1.

. Determine which level transmitter is NOT faulted.

• NVAA 5760 (Transmitter A)

• NVAA 5761 (Transmitter B) NOTE: NVAA 5761 (Transmitter B) is NOT faulted.

. Select the non-faulted level transmitter for VOT level input (Transmitter A or Transmitter B).

. Select DEV MRE INHIBIT to block the deviation input.

. Oheck MRE BLOOKED lit (blinking red),

BOP * (Step 3.2.2) On DOS Boric Acid Blender Graphic, perform the following: _________________________

• Select 2X5 for VOT Level 2.

• Determine which level transmitter is NOT faulted.

• NVAA 5761 (Transmitter A)

• NVAA 5760 (Transmitter B) NOTE: NVAA 5761 (Transmitter A) is NOT faulted.

Appendix D Operator Action Form ES-D-2 Op Test No.: NW-i Scenario # 2 Event # 1 Page 10 of 51 Event

Description:

VCT Controller Failure Time Pos. Expected Actions/Behavior Comments

. Select the non-faulted level transmitter for VCT level input (Transmitter A or Transmitter B).

. Select DEV MRE INHIBIT to block the deviation input.

. Check MRE BLOCKED lit (blinking red).

BOP * (Step 3.2.3) On DCS Boric Acid Blender graphic, perform the following:

. Select NV-i 37A (VCT Level)

• Ensure NV-i 37A is in auto CRS * (Step 3.2.4) HOLD until the faulted NOTE: The CRS may call transmitter is repaired. 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.: Nb-i Scenario # 2 Event # 2 Page 11 of 51 Event

Description:

lB SG PORV Fails OPEN After this, the I B SG PORV will fail fully OPEN. The operator will enter AP/IIA/5500101 Steam Leak, and stabilize the plant. The operator will address Technical Specification 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB)

Limits.

Booth Operator Instructions: Call the OATC and ensure that they are engaged in a phone conversation, and Operate Trigger #3 (SMOO3B (100))

Indications Available:

. lB SIG PORV (ISV-I 3AB) output indicates 100%

. lB S/G PORV (iSV-i 3AB) Red Status Light is LIT

• OAC Alarm M1Q3498, 1SV-13 lB SM PORV Time Pos. Expected Actions!Behavior Comments NOTE: The CRS may enter APi directly.

OAC ALARM M1Q3498, ISV-13 lB SM PORV RO (Step 1) Determine if affected SM PORV was NOTE: The PORV was NOT opened per approved procedure. opened per procedure.

RO (Step 2) IF affected SV PORV was NOT opened per approved procedure, THEN perform the following:

Attempt to isolate by performing one of the following:

. Close the affected PORV with the manual loader as applicable:

• ISVOI(DSMPORV)

. ISVO7 (C SM PORV)

. 1SV13(BSMPORV)

. ISV19(ASMPORV)

. Close the PORV Block Valve as applicable:

. IF 1SV13 (B SM PORV)

OPENED, THEN close 1SV28 (B SM PORV SQL).

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 2 Page 12 of 51 Event

Description:

lB SG PORV Fails OPEN Time Pos. Expected ActionslBehavior Comments CRS . GO TO AP/1/A15500/001 (Steam Leak)

NOTE: The failed PORV will most likely be isolated by the time that APi is entered.

APII!A/5500101, STEAM LEAK RO! (Step 1) Monitor Foldout page.

BOP RO (Step 2) Reduce turbine load to maintain the following:

. Excore NIs LESS THAN OR EQUAL TO 100%.

. NC Loop DITs LESS THAN 60°F D/T

. T-Avg AT T-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.

CRS (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.: Nb-i Scenario # 2 Event # 2 Page 13 of 51 Event

Description:

lB SO PORV Fails OPEN Time Pos. Expected ActionslBehavior Comments CRS (Step 12) Announce occurrence on paging NOTE: The CRS may ask U2 system. RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

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

. Check SM PORVs CLOSED. NOTE: The I B SG PORV was Opened, and most likely previously Closed. IF NOT, it will be closed here.

RO (Step 13 RNO) IF SIG pressure is less than 1092 PSIG, THEN perform the following:

. Close affected SIG SM PORV manual NOTE: The RO will close the loader. Manual Loader.

. IF SM PORV is still open, THEN ... NOTE: The lB SG PORV is closed.

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

. Check containment conditions NORMAL:

• Containment temperature

• Containment pressure

• Containment humidity

• Containment floor and equipment sump level.

BOP

• Check TD CA pump OFF.

BOP

• Check valves on STEAM LINE DRAIN VALVES board (1MC-9) CLOSED.

RO

• Check opposite Unit (Unit 2) STEAM HEADER PRESSURE GREATER THAN 200 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 2 Event # 2 Page 14 of 51 Event

Description:

18 SG PORV Fails OPEN Time Pos. Expected Actions!Behavior Comments CRS . Dispatch operator to check for leaks. NOTE: The CRS will NOT dispatch NEOs to look for leaks because it is understood that the SM PORV opening was the reason that AP-1 was entered.

However, the CRS may dispatch an NEO to verify that the PORV is Closed.

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.

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

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: A relief valve is NOT heater relief OR MSR relief valve, leaking.

THEN

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

MSR leak), THEN Check unit shutdown or load reduction NOTE: The CRS may call REQUIRED. WCC/Management to address the failure.

If so, Booth Instructor acknowledge as WCC.

CRS (Step 15.c RNO) Perform the following: _____________________

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 2 Page 15 of 51 Event

Description:

lB SG PORV Fails OPEN Time Pos. Expected Actions/Behavior Comments

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

CRS

• Exit this procedure. NOTE: SRO will likely conduct a Focus Brief.

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: Tech Spec applicability pressurizer pressure, RCS average will vary depending of how temperature, and RCS total flow rate shall be quickly the event is diagnosed.

within the limits specified in Table 3.4.1-1.

If Pzr Pressure drops < 2218 psig the TS is applicable.

CRS APPLICABILITY: MODE 1.

CRS ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME A. Pressurizer A.1 Restore DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> pressure or parameter(s)

RCS average to within limit.

temperature DNB parameters not within limits.

TECHNICAL SPECIFICATION 3.7.4, STEAM GENERATOR POWER OPERTED RELIEF VALVES CRS LCO 3.7.4, Three SG PORV lines shall be OPERABLE.

CRS MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 2 Page 16 of 51 Event

Description:

lB SO PORV Fails OPEN Time Pos. Expected ActionslBehavior Comments CRS After evaluation, the CRS determines that NO ACTION is necessary.

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

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 3 Page 17 of 51 Event

Description:

IA ND Pump is OOS Subsequently, the IA ND Pump is discovered to be inoperable. The operator will address Technical Specification 3.5.2, ECCS System Operating, and determine that an entry into Technical Specification 3.0.3 is needed, and a shutdown to Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> will be required.

Booth Operator Instructions: Call as the Plant SRO (Joe) and state:

Due to a burning smell coming from the IA ND Pump breaker, the NEO will be racking out the breaker.

THEN, Operate Trigger #5 (LOA-NDOO2)

Indications Available:

• IA ND RED and GREEN Breaker status light are OFF.

Time Pos. Expected ActionslBehavior Comments TECHNICAL SPECIFICATION 3.5.2, ECCS -OPERATING CRS LCO 3.5.2 Two ECCS trains shall be OPERABLE.

CRS APPLICABILITY: MODE 1, 2 and 3.

CRS ACTIONS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that both Trains of A.One or more A. 1 Restore 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ECCS are inoperable.

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 LCO 3.0.3

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 3 Page 18 of 51 Event

Description:

IA ND Pump is OOS Time Pos. Expected ActionslBehavior Comments CRS LCO 3.0.3 When an LCO is not met and the associated ACTIONS are not met, and associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place the unit, as applicable, in:

. MODE 3 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />;

. MODE 4 within 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />; and

. MODE 5 within 37 hours4.282407e-4 days <br />0.0103 hours <br />6.117725e-5 weeks <br />1.40785e-5 months <br />.

Exceptions to this Specification are stated in the individual Specifications.

NOTE: The CRS may call plant management.

Regardless, Booth Instructor:

After TS evaluation, as Operations Superintendent call and direct that the plant be

. brought to Mode 3 in the next two hours.

NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner move to Events #4-5.

Appendix D Operator Action Form ES.D-2 OpTestNo.: Nb-i Scenario# 2 Event# 4&5 Page 19 of 51 Event

Description:

Rapid Downpowerl Control Rods fail to move in AUTO Shortly after this, the operator will enter AP111A15500104, Rapid Downpower, and decrease load to enter mode 3. During the downpower, the control rods will fail to move in AUTO. The operator will respond in accordance with OAC Alarm MI P1367, Ui TAVG TREF (HALM), and enter API1IA/5500114, Rod Control Malfunctions, and take Manual control of the rods.

Booth Operator Instructions: NA Indications Available: NA Pos. Expected ActionslBehavior Comments AP111A15500104, RAPID DOWNPOWER ROI (Step 1) Monitor Foldout page.

BOP CRS (Step 2) Announce occurrence on page. NOTE: The CRS may ask U2 RO to make Plant Announcement.

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 NOTE: Shutdown to Mode 3 DESIRED. is desired.

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

. Shutdown Via Reactor Trip from 15%

Power DESIRED

. At least two CA pumps OPERABLE.

RO (Step 7) Enter target load of 180 MW in Turbine Control Panel.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 4 & 5 Page 20 of 51 Event

Description:

Rapid Downpowerl Control Rods fail to move in AUTO Pos. Expected ActionslBehavior Comments CRS (Step 8) Determine the required power NOTE: The CRS will reduce reduction rate (MW/mm). load at5-10 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.

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

BOP (Step 12) Borate NC System as follows:

. Check TTI1/B/EC782411003 B (Ovation PCS Plant Transient Testing) IN EFFECT.

CRS (Step 12.a RNO) GO TO Step 12.c.

BOP

• Energize all backup Pzr heaters.

• Check unit to shutdown VIA REACTOR TRIP FROM 15% POWER.

CRS

• Calculate Total Power Change NOTE: The CRS calculates a 40% power change.

BOP

• Determine boration amount based on the following:

• Power Reduction Rate (MW/mm)

• Present NC System Boron Concentration (ppm)

• Total Power change_(%).

BOP

• Record calculated boration amount: NOTE: The BOP calculates a 280-330 gallon boration.

RD

• Check auto or manual rod control AVAILABLE.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 4&5 Page 21 of 51 Event

Description:

Rapid Downpoweri Control Rods fail to move in AUTO Pos. Expected ActionslBehavior Comments BOP

• Perform boration in 4 equal additions NOTE: Allow the BOP to during load reduction PER make at least one boration.

OP/I /N6 150/009 (Boron Concentration Control), Enclosure 4.7 (Boration Using 1 NV-265B (Boric Acid to NV Pumps)).

BOP Examiner follow actions of Enclosure 4.7.

Others should move ahead to AP4 actions.

0P111A161501009, BORON CONCENTRATION CONTROL ENCLOSURE 4.7, BORATION USING INV-265B (BORIC ACID TO NV PUMPS)

BOP (Step 3.6.1) Ensure one of the following running:

• 1A BA Transfer Pump

• 1 B BA Transfer Pump BOP (Step 3.6.2) Determine the length of time 1 NV-265B (Boric Acid to NV Pumps) full open as follows:

• If using Table 4.7-1 (Timel NV-265B Full NOTE: The BOP will Open), record time 1 NV-265B full open determine that 1 NV-265B from Table. should be opened 31-62 seconds.

BOP (Step 3.6.3) Open INV-265B (Boric Acid to NV Pumps).

BOP (Step 3.6.4) HOLD until 1NV-265B (Boric Acid to NV Pumps) full open time elapsed, THEN close 1NV-265B (Boric Acid to NV Pumps).

AP!11A15500104, RAPID DOWNPOWER

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 4&5 Page 22 of 51 Event

Description:

Rapid Downpowerl Control Rods fail to move in AUTO Pos. Expected ActionslBehavior Comments RO (Step 13) Check control rods MOVING IN NOTE: In the subsequent AS REQUIRED TO MAINTAIN T-AVG AT steps, after the Crew has T-REF. diagnosed the Rod failure, the CRS may back up to perform the Step 13 RNO.

Booth Instructor: Operate Trigger #7 (IREOO9 (AUTO)).

During the downpower, the control rods will fail to move in AUTO. The operator will respond in accordance with OAC Alarm M1P1367, Ui TAVG TREF (HALM), and enter APIIIA/5500114, Rod Control Malfunctions, and take Manual control of the rods.

Indications Available:

• White RODS IN Rod Control Status light is LIT

• Inward Rod direction arrow on the rod motion demand signal indicator

• OAC Alarm M1P1 367, Ui TAVG-Tref HI 1.5°F Examiner NOTE: In the subsequent steps, IF the Crew places the Rods in MANUAL, and does NOT address AP14, continue with the last step performed in AP4.

If the CRS transitions to API4, to address the Rod malfunction, move forward to AP14 actions on Page 25.

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

CRS (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 perform one of the following to comply both board operators aware.

with Tech Spec 3.1.6 (Control Bank Insertion Limits):

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

OR

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

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 4&5 Page 23 of 51 Event

Description:

Rapid Downpowerl Control Rods fail to move in AUTO Pos. Expected Actions/Behavior Comments 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:

. RP/01A15700/000 (Classification of Emergency)

. RPIOIA5700IO1O (NRC Immediate NOTE: The CRS may ask Notification Requirements). OSM to address.

If so, Floor Instructor acknowledge as OSM.

CRS (Step 18) Notify Reactor Group Duty NOTE: The CRS may ask Engineer of load reduction. OSM to address.

If so, Floor Instructor acknowledge as OSM.

The CRS may call WCC/RE to address failure.

If so, Booth Instructor acknowledge as WCC.

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

RD (Step 20) Check Unit 2 AVAILABLE TO SUPPLY AUX STEAM (AS) HEADER.

CRS (Step 21) Dispatch operator to ensure the following valves are open:

. IAS-74 (Unit 1 Unit 2 Aux Steam Hdr Cross-Tie Isol) (service bldg, 739+ 12, room 202,_R-27, over B RL Pump)

. Unit 2 valve 2AS-74 (Unit 1 & Unit 2 Aux Steam Hdr Cross-Tie lsol) (service bldg, 739+14, room 202, S-27, above RL strainer.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 4&5 Page 24 of 51 Event

Description:

Rapid Downpowerl Control Rods fail to move in AUTO Pos. Expected ActionslBehavior Comments

. 1AS-253 (Unit I Aux Steam Hdr Isol) NOTE: The CRS will dispatch (service bldg, 739+15 P-28 above an NEO.

overhead door to Unit 1 turbine bldg).

If so, Floor Instructor acknowledge as NLO, and after 5 minutes, report back that the valves are OPEN.

RO (Step 22) WHEN all SM flows are less than NOTE: The CF Control 65% THEN ensure the following valves ramp Bypass valves should be CLOSED; closed.

• 1CF-1O4AB (1A S/G CF Control Bypass)

. 1CF-105AB (lB S/G CF Control Bypass)

• 1CF-1O6AB (1C SIG CF Control Bypass)

• ICF-107AB (1D SIG CF Control Bypass)

RO (Step 23) WHEN P/R instruments indicate less than 48%m THEN check P-8 HI PWR LO FLO RX TRIP BLOCKED status light (1DI-18) LIT.

RO (Step 24) Check the following:

. P/R meters indicate reactor power -

LESS THAN 40%.

CRS (Step 24 RNO) Perform the following; NOTE: The CRS will hold until power is < 40%.

IF target load is less than 40%, THEN perform the following;

. Do not continue with this procedure until;

• P/R instruments indicate reactor power is less than 40%.

. All CF flows are less than 40%.

. Impulse pressure is less than 260 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 4&5 Page 25 of 51 Event

Description:

Rapid Downpowerl Control Rods fail to move in AUTO Pos. Expected ActionslBehavior Comments AP111A15500114, ROD CONTROL MALFUNCTION RO (Step 1) IF more than one rod dropped, Immediate Action THEN NOTE: No control rods dropped during this event.

RO (Step 2) Place control rods in manual. Immediate Action NOTE: The RO placed the rods in manual during the downpower when the malfunction occurred.

RO (Step 3) Check rod movement STOPPED. Immediate Action RO (Step 4) Check all rods ALIGNED WITH ASSOCIATED BANK.

RO (Step 5) Check ROD CONTROL URGENT FAILURE alarm (IAD-2, A-la) DARK.

RO (Step 6) Check T-AVG/T-REF FAILURE ROD STOP alarm (1AD-2, B-7) DARK.

RO (Step 7) IF this AP entered due to NOTE: The CRS entered unwarranted rod insertion or withdrawal, AP14 because the Rods were THEN.... NOT moving when required.

CRS (Step 8) IF this AP entered due to a failure of rods to withdraw or insert when required, THEN GO TO Enclosure 2 (Failure Of Rods To Move On Demand).

NOTE: The SRO will transition to AP-14, Enclosure 2.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 4&5 Page 26 of 51 Event

Description:

Rapid Downpower/ Control Rods fail to move in AUTO Pos. Expected ActionslBehavior Comments AP111A15500114, ROD CONTROL MALFUNCTION ENCLOSURE 2, FAILURE OF RODS TO MOVE ON DEMAND CRS (Step 1) Announce occurrence on paging NOTE: CRS may ask U2 RD system. to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RD.

RD (Step 2) Maintain T-Avg within 1°F of T-Ref NOTE: The RD will adjust using any of the following methods: Turbine Load to maintain Temperature.

• Borate/dilute NC System DR

. Adjust Turbine load.

CRS (Step 3) Notify IAE to investigate problem. NOTE: The CRS may call WCC/IAE to address the Rod Control malfunction.

If so, Booth Instructor acknowledge as WCC.

RD (Step 4) Check if rod control system failure has occurred as follows:

. ROD CONTRDL URGENT FAILURE NOTE: The Urgent Failure alarm (1AD-2, A-b) LIT.

light is DARK.

RD (Step 4 RND) Perform the following:

. If Manual Rod Control available, THEN rods can be used to maintain T-avg within 1°F of T-Ref.

RD/ (Step 5) Do not move rods until IAE CRS determines rod motion is permissible.

CRS (Step 6) IF AT ANY TIME a runback occurs NOTE: This is a Continuous while in this procedure, THEN observe the Action. The CRS will make following guidance: both board operators aware.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 4&5 Page 27 of 51 Event

Description:

Rapid Downpowerl Control Rods fail to move in AUTO Pos. Expected ActionslBehavior Comments IF IAE has determined that it is permissible to move rods, THEN respond to the runback PER API1/A15500103 (Load Rejection).

. For all other circumstances, assume rod control is not available and respond to the runback as follows:

. Trip Reactor.

. GO TO EPI1/AI5000IE-0 (Reactor Trip or Safety Injection).

CRS (Step 7) IF AT ANY TIME while in this NOTE: A Unit Shutdown is procedure a unit shutdown is required AND required, and the CRS may rods cannot be moved, THEN perform the contact WCC/IAE and ask following: about the use of Control Rods in Manual.

NOTE: If so, as IAE, report that the use of Manual Rod Control during the Unit Shutdown is permitted.

. Borate as required during shutdown to maintain T-Avg at T-Ref.

. Monitor AFD during had reduction.

. IF AT ANY TIME AFD reaches Tech Spec limit AND reactor power is greater than 50%, THEN....

. 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/1/N5000/E-0 CRS (Step 8) Check if reactor control system failure has occurred as follows:

. T-AVG/T-REF FAILURE ROD STOP alarm (1AD-2, B-7) LIT.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 4&5 Page 28 of 51 Event

Description:

Rapid Downpower! Control Rods fail to move in AUTO Pos. Expected ActionslBehavior Comments CRS (Step 8.a RNO) GO TO Step 9.

CRS (Step 9) WHEN rod control problem is NOTE: A Unit Shutdown is repaired, OR Engineering determines that required, and the CRS may rod control malfunction will not affect auto contact WCC/IAE and ask rod motion, THEN perform the following: about the use of Control Rods in Manual.

NOTE: If so, as IAE, report that the use of Manual Rod Control during the Unit Shutdown is permitted.

When the CRS continues the shutdown with rods in Manual, return to the last Step performed in AP4, starting on Page 22 (After insertion of Rod malfunction).

• Ensure T-Avg atT-Ref+/- 1°F.

. IF auto rod control desired, THEN place control rods in auto.

At the discretion of the Lead Examiner move to Event #6.

Appendix D Operator Action Form ES-D-2 OpTestNo.: Nb-i Scenario# 2 Event# 6 Page 29 of 51 Event

Description:

High Vibrations IA NCP As the downpower continues, a high vibration condition will develop on the IA NCP.

The operator will respond in accordance with QAC Alarm M1D3041, 1A NC PUMP VIBRATION (HALM), and enter APII/A15500/08, Malfunction of NC Pump. The operator will eventually manually trip the reactor, and then stop the 1A NCP.

Booth Operator Instructions: Operate Trigger #9 (NCPOO3A (18)

Indications Available:

• MCB Annunciator IAD-6, Eli, NC PUMP HI VIBRATION

• At Reactor Coolant Pump Vibration Monitoring Cabinet:

• MotorAxialAl = 18

• PumpShaftX4=17

• PumpShaftY4=17

• OAC Alarm M1D3041, 1A NC PUMP VIBRATION Time Pos. Expected ActionslBehavior Comments NOTE: The RO may take the Turbine to HOLD while addressing the NC Pump failure.

OAC ALARM M1D3041, IA NC PUMP VIBRATION CRS (Step I) RefertoOPIlIAI6lOOIOlOG ANNUNCIATOR RESPONSE FOR PANEL 1AS6-E1 1 (ND Pump HI Vibration)

AP111A15500108, MALFUNCTION OF NC PUMP CASE III, EXCESSIVE VIBRATION BOP (Step 1) Go to the NC pump vibration monitor panel and perform the following:

. Compare all 9 vibration channels on the alarming pump.

. Check if readings indicate VALID NOTE: Several indicators are VIBRATION PROBLEM. indicating vibration, reflecting a valid problem.

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

. Motor frame vibration LESS THAN 5 MILS.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 6 Page 30 of 51 Event

Description:

High Vibrations IA NCP Time Pos. Expected ActionslBehavior Comments

. All of the following LESS THAN 20 MILS:

. Motor shaft vibration

. Pump shaft vibration

. Motor axial vibration

. Motor flywheel vibration RO! (Step 3) IF AT ANY TIME vibration exceeds NOTE: This is a Continuous BOP operating limits, THEN GO TO Step 5. Action. The CRS will make both board operators aware.

CRS (Step 4) GO TO Step 6 CRS (Step 6) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 7) Check NC pumps ANY RUNNING.

Booth Instructor: Increase severity of NCPOO3A to 30.

Indications Available:

. MCB Annunciator IAD-6, Fli, NC PUMP HIHI VIBRATION

. At Reactor Coolant Pump Vibration Monitoring Cabinet:

. Motor Axial Al = 30

. PumpShaftX4=30

. PumpShaft4=30 NOTE: The CRS may enter AP8 directly.

MCB ANNUNCIATOR IAD-6, Fli, NC PUMP HI-HI VIBRATION CRS (Step 1) GO to AP/l/A/5500/008 (Malfunction of NC Pump).

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 6 Page 31 of 51 Event

Description:

High Vibrations IA NCP Time Pos. Expected Actions!Behavior Comments CRS (Step 2) IF the vibration has been slowly increasing AND the System Engineer is aware of the problem, follow any Special Orders that the System Engineer has issued.

AP111A15500108, MALFUNCTION OF NC PUMP CASE UI, EXCESSIVE VIBRATION NOTE: Upon the actuation of the HI-HI Alarm, the CRS will continue with the Continuous Action previously identified within AP8.

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

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

. I NC-27C (A NC Loop PZR NOTE: The BOP will need to Spray Control) Close the Spray Valve.

• Check unit status IN MODE 1 OR 2.

RO . Trip Reactor

. WHEN reactor power less than 5%,

THEN stop affected NC pump.

CRS . GO TO EP/1/A/5000/E-O (Reactor Trip or Safety Injection).

Upon Reactor Trip move to Events #7-8.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 32 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Upon reactor trip, the operator will enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection. Simultaneous with the Reactor Trip, a 700 gpm SGTR to occur in the 1C Steam Generator, and, although the operator may transition to EPIIIAI5000IES-0.l, Reactor Trip Response, the operator will eventually manually actuate Safety Injection and complete E-0. Upon completion of E-0, the operator will transition to EP/1/A/5000/E-3, Steam Generator Tube Rupture, and isolate the flow into and out of the IC Steam Generator and then conduct a cooldown of the NC System. When the operator attempts to conduct a cooldown of the NC System, the Steam Dumps will fail to operate, and the cooldown will need to be accomplished using the Steam Generator PORVs on the intact Steam Generators. 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: NA Trigger #11 (SGOOIC (700 gpm), OVR-SBOO4A, 5A (ON)) is tied to the Reactor Trip.

Indications Available:

. MCB Annunciator 1RAD-1 Cl, 1EMF 71, SIG A LEAKAGE HI RAD

. MCB Annunciator IRAD-1 Dl, IEMF 72, SIG B LEAKAGE HI RAD

. MCB Annunciator 1 RAD-1 D2, 1 EMF 73, SIG C LEAKAGE HI RAD

. MCB Annunciator 1 RAD-1 D3, 1 EMF 74, SIG D LEAKAGE HI RAD

. IC SG Level Narrow Range level increasing uncontrollably

. Pzr level and Pressure is lowering Time Pos. Expected ActionslBehavior Comments EPIIIAI5000!E-0, REACTOR TRIP OR SAFETY INJECTION (Step 1) Monitor Foldout page. NOTE: Crew will carry out Immediate Actions of E-O, prior to the SRO addressing the EP.

(Step 2) Check Reactor Trip: Immediate Action

. All rod bottom lights LIT

. Reactor trip and bypass breakers OPEN

. I/RampsGOINGDOWN.

RD (Step 3) Check Turbine Trip: Immediate Action

. All throttle valves CLOSED.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 33 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected ActionslBehavior Comments 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 (1SI-18) LIT.

RO! (Step 5a RNO) Perform the following: Immediate Action BOP

• Check if S/I is required:

. Pzr pressure less than 1845 PSIG OR

. Containment pressure greater than 1 PSIG.

IF S/I is required THEN....

IF S/I is not required, THEN perform the NOTE: SI is neither actuated following: nor presently required.

. Implement EPI1/N5000IF-O (Critical Safety Function Status Trees).

• GO TO EP/1/N5000/ES-O.1 (Reactor Trip_Response).

NOTE: The CR3 will transition to ES-O. 1, however, Pzr Level will be continuously lowering with the SGTR.

EPII!AI5000IES-O.1, REACTOR TRIP RESPONSE NOTE: The ES-O.1 Foldout Page requires actuation of SI if Pzr Level lowers to 4%.

When this occurs, the CRS will return to E-O, Step 1.

Examiners move forward to actions on Page 36.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7 & 8 Page 3 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Po& Expected ActionslBehavior Comments RO/ (Step 1) Monitor Foldout page. NOTE: The decision to BOP Manually actuate Safety Injection will be based on Pzr Level lowering to < 4%.

BOP (Step 2) Check the following:

• VI pressure GREATER THAN 70 PSIG.

• Unit 1 6900V busses ENERGIZED.

CRS (Step 3) Announce: Unit 1 Reactor trip, non NOTE: CRS may ask U2 RO essential personnel stay out of Unit 1 turbine to make Plant Announcement.

bldg.

If so, Floor Instructor acknowledge as U2 RO.

CRS (Step 4) REFER TO RPIO/A157001000 NOTE: The CRS may ask (Classification of Emergency). OSM to address.

If so, Floor Instructor acknowledge as OSM.

RO (Step 5) Check NC temperatures:

. IF any NC pump on, THEN check NC T NOTE: Tavg will be controlled Avg STABLE OR TRENDING TO by the SG PORVs at 559°F.

557°F.

RO (Step 5 RNO) Perform the following based on plant conditions:

. IF temperature less than 557°F AND NOTE: Tavg will be controlled going down by the SG PORVs at 559°F.

. IF temperature greater than 557° F AND going_up, THEN perform the following:

. IF steam dumps are available, NOTE: The Steam Dumps are THEN.... NOT available.

Appendix D Operator Action Form ES-D-2 Op Test No.: N 10-1 Scenario # 2 Event # 7&8 Page 35 of 51 Event

Description:

SGTRI Steam Dump System fails to operate T;.

IF all SIG pressures are greater than 775 PSIG AND SM PORVs are available, THEN use SM PORVs to stabilize temperature at 557°F.

RO (Step 6) Continue to monifor NC temperature _______________________

as follows:

. Check any NC pump ON. NOTE: ONLY the 1A NCP is OFF.

CRS

• IF AT ANY TIME while in this procedure NOTE: This is a Continuous the following occurs, THEN perform Step Action. The CRS will make

5. both board operators aware.

. NC T-Avg is less than 557°F and going down OR

. NC T-Avg is greater than 557°F and going up.

RO (Step 7) Check Main Generator as follows:

• Check both generator breakers OPEN.

• Check EXCITATION OFF.

RO (Step 8) Check MSR RESET light LIT.

CRS (Step 9) Dispatch operator to perform NOTE: The CRS will dispatch Enclosure 5 (MSR Second Stage Drain Tank an NEO.

Isolation).

RO (Step 10) Check NC T-Avg GREATER THAN 553°F.

NOTE: The ES-0.1 Foldout Page requires actuation of SI if Pzr Level lowers to 4%.

When this occurs, the CRS will return to E-0, Step 1.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7 & 8 Page 36 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected ActionslBehavior Comments EP!IIAI5000IE-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.

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

• 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 (1Sl18) LIT.

. Both LOCA Sequencer Actuated status lights_(1SI-14) LIT.

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

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 7) Check ESF Monitor Light Panel on energized train(s):

. Groupsl,2,5DARK.

. Group 3 LIT.

Appendix D Operator Action Form ES..D-2 OpTestNo.: Nb-i Scenario# 2 Event# 7&8 Page 37 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected ActionslBehavior Comments

. OACIN SERVICE.

. Group 4, Rows A through F LIT AS NOTE: Both ND Pumps are REQUIRED. OFF.

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

. Ensure both trains Phase A Isolation are initiated.

. Align or start S/I and Phase A components with individual windows in Group 4 as required.

• GO TO Step 7.f BOP . Check LOCA Sequencer Actuated status light (1 SI-14) on energized train(s)

LIT.

BOP . Check the following windows on Monitor Light Panel Group 4 LIT:

. C-3 :CONTISOLPHASEATRNA VLVS ALIGNED

. C-6 CONT ISOL PHASE A TRN B VLVS ALIGNED

. F-4 SAFETY INJECTION TRAIN A COMPONENTS ALIGNED

. F-5 SAFETY INJECTION TRAIN B COMPONENTS ALIGNED.

BOP (Step 8) Check proper CA pump status:

. MDCApumpsON.

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

BOP (Step 9) Check all KC pumps ON.

BOP (Step 10) Check both RN pumps ON.

CRS (Step 1 1) Notify Unit 2 to start 2A RN pump. Floor Instructor: As U2 RD report 2A RN Pump is running.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 38 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected ActionslBehavior Comments RD (Step 12) Check all SIG pressures GREATER THAN 775 PSIG.

BOP (Step 13) Check Containment Pressure NOTE: Containment Pressure HAS REMAINED LESS THAN 3 PSIG. is normal.

BOP (Step 14) Check S/I flow:

. Check NV PMPS TO COLD LEG FLOW gauge INDICATING FLOW.

• Check NC pressure LESS THAN 1600 PSIG.

• Check NI pumps INDICATING FLOW.

. Check NC pressure LESS THAN 286 PSIG.

BOP (Step 14d RNO) Perform the following:

. Ensure ND pump miniflow valve on NOTE: Both ND Pumps are running pump(s) open: OFF.

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

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

CRS . IF valve(s) open on all running ND pumps, THEN GO TO Step 15.

CRS (Step 15) 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 Following an S/I) within 10 minutes. If so, Floor Instructor acknowledge as OSM.

BOP (Step 16) 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.: Nb-i Scenario # 2 Event # 7&8 Page of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected Actions/Behavior Comments WHEN N/R level in any S/G greater than 1 1% (32% ACC), THEN control CA flow to maintain NIR levels between 11%

(32% ACC) and 50%.

RO (Step 17) Check NC temperatures:

. IF any NC pumps on, THEN check NC T-Avg STABLE OR TRENDING TO 557°F.

BOP (Step 18) Check Pzr PORV and spray valves:

. All Pzr PORVs CLOSED.

. Normal Pzr spray valves CLOSED.

RO (Step 19) Check NC subcooling based on core exit T/Cs GREATER THAN 0°F.

RO (Step 20) Check if main steamlines intact:

. All S/G pressures STABLE OR GOING UP

. All S/Gs PRESSURIZED.

BOP (Step 21) Check if S/G tubes intact: NOTE: Since the Steam Dumps failed at the time of the Reactor trip, all S/G EMFs are Normal.

However, all of the Steam Line monitors are in alarm, and the CRS will go to the RNO based on this.

. The following secondary EMFs NORMAL:

. 1 EMF-33 (Condenser Air Ejector Exhaust)

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

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 40 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos Expected ActionslBehavior Comments

. 1EMF-24 (SIC_A)

. 1EMF-25 (S/G_B)

. 1EMF-26 (SIC_C)

. 1EMF-27(S/GD).

CRS (Step 21 RNO) IF SIC levels going up in an NOTE: The 1C SG Level is uncontrolled manner OR any EMF abnormal, increasing in an uncontrolled THEN perform the following: manner.

. Implement EP/1/A15000/F-O (Critical Safety Function Status Trees).

. GO TO EP/1/N5000/E-3 (Steam Generator Tube Rupture).

NOTE: The CRS will transition to E-3.

EPII !A!5000IE-3, STEAM GENERATOR TU BE RUPTURE SRO (Step 1) Monitor Foldout page. ________

BOP (Step 2) Identify ruptured S/G(s):

. Any SIG NIR level GOING UP IN AN NOTE: The 1C SG Level is UNCONTROLLED MANNER increasing in an uncontrolled manner.

NOTE: The CRS may contact Chemistry for sampling.

Booth Instructor:

Acknowledge as appropriate.

RO (Step 3) Check at least one SIG AVAILABLE FOR NC SYSTEM COOLDOWN.

RO (Step 4) Isolate steam flow from ruptured S/C(s) as follows:

. Check ruptured S/C(s) PORV CLOSED.

. IF TD CA pump is the only source of NOTE: The TD CA Pump is feedwater, THEN.... NOT the ONLY CA Source.

. Check S/Cs lB and 1C INTACT.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 41 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected Actions!Behavior Comments CRS (Step 4c RNO) Isolate TD CA pump steam supply from ruptured SIG as follows:

Ensure operators dispatched in next NOTE: The CRS will dispatch step immediately notify Control an NEO.

Room Supervisor when valves are closed.

Immediately dispatch 2 operators to concurrently verify (CV), unlock and CLOSE valves on ruptured_SIG(s):

For1CSIG:

• 1SA-77 (1C SIG SM Supply to Unit 1 TD CA Pump Turb Loop Seal Isol) (Unit 1 interior doghouse,_767+10,_FF-53).

. ISA-i (1C SIG SM Supply to Booth Instructor:

Unit I TD CA Pump Turb Maint Operate Trigger #13 (LOA Isol) (Unit 1 interior doghouse, SAOO2 = 0 iClosed 767+10, FF-53, above ladder).

Within 3 minutes, as NEO report that steam has been isolated to the TD CA Pump from the IC SG.

CRS

• IF AT ANY TIME local closure of SA NOTE: Eight minutes will NOT valves takes over 8 minutes, elapse before the valves are THEN.... closed.

RO

• Check blowdown isolation valves on ruptured_SIGI(s) CLOSED.

• For1CS/G:

• 1BB-3B (1C S/G Blowdown Cont Outside Isol Control)

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

BOP

• CLOSE steam drain on ruptured S/G(s)

RO

• CLOSE the following on ruptured S/G(s):

• MSIV

• MSIV bypass valve.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O1 Scenario # 2 Event # 7&8 Page 42 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos Expected ActionslBehavior Comments RO (Step 5) Control ruptured S/G(s) level as follows:

. Check ruptured S/G(s) N/R level GREATER THAN 11% (32% ACC).

BOP

• Isolate feed flow to ruptured S/G(s):

• ForiCS/G:

• CLOSE 1CA-50B (Ui TD CA Pump Disch TO 1C S/G Isol).

• CLOSE 1CA-46B(1B CA Pump Disch To IC S/G Isol).

CRITICAL TASK:

(E-3A) Isolate feedwater flow into and steam flow from the ruptured SG before a transition to ECA-3.1 occurs.

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 SGs, requiring a transition to a contingency procedure, and delaying the stopping of RCS leakage into the SG.

BOP (Step 6) Check ruptured S/G(s) pressure GREATER THAN 280 PSIG.

BOP (Step 7) Check any NC pump RUNNING. NOTE: ONLY the 1A NCP is OFF.

BOP (Step 8) Check Pzr pressure GREATER THAN 1955 PSIG.

BOP (Step 8 RNO) IF P-Il PRESSURIZER S/I BLOCK PERMISSIVE status light (1 SI-i 8) is lit, THEN block Low Pressure Steamline Isolation as follows:

Appendix D Operator Action Form ES-D.-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 43 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected ActionslBehavior Comments

. Depress BLOCK on Low Pressure Steamline Isolation block switches.

. Maintain NC pressure less than 1955 PSIG.

RD (Step 9) Initiate NC System cooldown as follows:

CRS

• Determine required core exit temperature based on lowest ruptured S/G pressure:

NOTE: The CRS will determine the target temperature to be 508°F.

RD

• Check the following on ruptured S/G(s)

CLOSED:

. MSIV

. MSIV bypass valve.

RD

• Check ruptured S/G(s) SM PORV CLOSED.

RD

• Check S/G(s) lB and 1C INTACT. NOTE: The 1C SG is ruptured.

RO (Step 9.d RND) IF lB OR 1C SIG is ruptured, THEN do not continue until steam is isolated to TD CA pump from ruptured S/G per one of the following:

• Local isolation of SA line (per Step 4.c)

OR

• Tripping TD CA pump stop valve (per Step 4.c)

NOTE: If NOT already done, the CRS will direct two NLOs to CLOSE iSA-i and 77.

Booth Instructor: Set LOA SAOO2 = 0, (1SA-1/77)

Within 3 minutes, as NEO report that steam has been isolated to the TD CA Pump from the IC SG.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 44 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Timp Fynpgfpri ( rm m rife RO . (Step 9e) Check condenser available: NOTE: Although the Steam Dumps did NOT operate on the trip, the CRS will determine that the Condenser is available.

RO . C-9 COND AVAILABLE FOR STEAM DUMP status light (1ST-i 8)

LIT

. MSIV on intact SIG(s) OPEN RO . (Step 9.f) Perform the following to place steam dumps in steam pressure mode:

. 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.

RO * (Step 9g) WHEN P-i2 LO-LO TAVG status light (151-i 8) lit, THEN place steam dumps in bypass interlock.

RO * (Step 9h) Dump steam from intact SIG(s) NOTE: The Steam Dumps will to condenser at maximum rate while fail to operate.

attempting to avoid a Main Steam Isolation.

(Step 9h RNO) Perform the following:

BOP

• Insure at least one Pzr PORV isolation valve is OPEN.

• IF VI is lost, OR a Phase B Isolation has NOTE: Neither condition has occurred, THEN occurred.

• IF Pzr pressure is greater than i955 NOTE: Pzr Pressure is < 1955 PSIG, THEN.... psig.____________________

RO

• Depress BLOCK on Low Pressure Steamline Isolation block switches.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario# 2 Event# 7&8 Page 45 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected ActionslBehavior Comments BOP

• Maintain NC pressure less than 1955 PSIG.

RO

• Ensure Main Steam Isolation reset.

RO

• Ensure SM PORVs reset.

RO

• IF any intact SIG SM PORV isolation NOTE: The 1 B SG PORV valves is closed needed to be closed due to a previous malfunction, however the valve is NOT isolated.

RO

• Dump steam using all intact SIG(s) SM PORVs at maximum rate as follows:

• CLOSE SM PORV manual loader on ruptured_S/G(s).

• Place intact S/G SM PORV NOTE: When the RO places manual loaders at 50%. the 1 B SG PORV manual Loader in 50%, it will open immediately, due to a previous failure.

. Select MANUAL on SM PORV MODE SELECT.

• Adjust manual loaders on intact S/G SM PORVs as required to control intact SIG depressurization rate at approximately 2 PSIG per second.

CRS

• IF any intact S/G SM PORV closed, NOTE: The lB SG PORV will THEN be OPEN at this time.

CRS

• IF no intact S/G available, THEN NOTE: The 1A, lB and 1D SG are available (Although the 1A NC Pump is OFF).

RO * (Step 91) Check Low Pressure Steamline Isolation BLOCKED.

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.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-I Scenario # 2 Event # 7&8 Page 46 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected Actions/Behavior Comments 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.

CR5

• GOTOSteplO.

RO (Step 10) Control intact S/C levels:

• Check N/R level in any intact S/G GREATER THAN 11% (32% ACC).

. Throttle feed flow to maintain all intact S/C N/R levels between 22% (32% ACC) and 50%.

BOP (Step 1 1) Check Pzr PORVs and isolation valves:

. Power to all Pzr PQRV isolation valves AVAILABLE.

. All Pzr PQRVs CLOSED.

. 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 VT to containment:

. Open the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page z7 of 51 Event

Description:

SGTRJ Steam Dump System fails to operate Time Pos. Expected ActionslBehavior Comments

. lVl-129B (VI Supply to A Cont Ess VI Hdr Outside Isol))

. 1VI160B (VI Supply to B Cont Ess VI Hdr Outside Isol))

. lVl-150B (Lwr Cont Non Ess Cont Outside Isol).

. Check VI header pressure GREATER THAN 85 PSIG.

RO (Step 14) Check if NC System cooldown should be stopped as follows:

. 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 14a RNO) Perform the following:

• IF AT ANY TIME while in this step NOTE: This is a Continuous ruptured S/G pressure changes by over Action. The CRS will make 100 PSIG, AND both board operators aware, and HOLD.

• Do not continue until core exit T/Cs are less than target temperature.

RO * (Step 14b) Stop NC System cooldown.

. Maintain Core exit T/Cs LESS THAN REQURIED TEMPERATURE.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 4 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected ActionslBehavior Comments CRITICAL TASK:

(E-3B) Establishlmaintain an RCS temperature so that transition from E-3 does not occur because RCS temperature is either too high to maintain minimum required subcooling, or too low causing an Orange path on Subcriticality or Integrity.

Safety Significance: Failure to establish and maintain the correct RCS temperature during a SGTR leads to a transition from E-3 to a contingency procedure which constitutes an incorrect performance that necessitates the crew taking compensating action which complicates the event mitigation strategy. If the RCS temperature is too high when RCS depressurization is started, a loss of subcooling will occur when the RCS depressurization is started. On the other hand, if RCS temperature is allowed to continue to decrease after the initial cooldown, the operator may be required to transition to the Subcriticality or Integrity response FRP, and delay the RCS depressurization.

RO (Step 15) Check ruptured S/G(s) pressure STABLE OR GOING UP.

RO (Step 16) Check NC subcooling based on core exit T/Cs GREATER THAN 20°F.

BOP (Step 17) Depressurize NC System as follows:

. Check ruptured S/G(s) NR level LESS NOTE: The ruptured SG level THAN 73% (63% ACC). will be> 73%.

CRS (Step 17a 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)

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 49 of 51 Event

Description:

SGTR/ Steam Dump System fails to operate Time Pos. Expected ActionslBehavior Comments OR

. Both of the following:

. NC pressure LESS THAN RUPTURED S/G(s)

PRESSURE. I

. Pzr level GREATER THAN 11% (29%ACC).

• Close Pzr PORV.

• Close Pzr spray valves.

BOP (Step 19) Check NC pressure GOING UP.

ROl (Step 20) Check S/I termination criteria:

BOP

• NC subcooling based on core exit T/Cs GREATER THAN 0°F.

• Secondary heat sink:

. N/R level in at least one intact S/G GREATER THAN 11% (32% ACC)

OR

. Total feed flow available to S/G(s)

GREATER THAN 450 GPM.

• NC pressure STABLE OR GOING UP.

. Pzr level GREATER THAN 11% (29%

ACC).

BOP (Step 21) Stop S/I pumps as follows:

. NI pumps.

• All but one NV pump.

BOP (Step 22) Isolate NV S/I flowpath as follows:

. Check the following valves - OPEN

. 1NV-221A (NV Pumps Suct From FWST)

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 2 Event # 7&8 Page 50 of 51 Event

Description:

SGTRI Steam Dump System fails to operate Time Pos. Expected Actions!Behavior Comments

. 1NV-222B (NV Pumps Suct From FWST).

. Check the following valves - OPEN

. 1NV-1 508 (NV Pumps Recirculation)

. 1NV-151A (NV Pumps Recirculation).

. Close the following valves:

. 1NI-9A (NC Cold Leg_Inj 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: 56% NCS [B] 1220 ppm Pzr [B]: 1234 ppm Xe: Per OAC Power History: The Plant is at 56% power (MOL), Core Burnup: 250 EFPDs for four days.

CONTROLLING PROCEDURE: OPI1/A16100103 Controlling Procedure for Unit Operation OTHER INFORMATION NEEDED TO ASSUME TO SHIFT:

• The Plant is at 56% power (MOL), following a plant startup and load ascension four days ago to this power level.

• The power ascension was halted due to unusually high vibrations on the 1A NCP.

• The System Engineer has been monitoring the NCP, and vibration levels have stabilized out at normally expected levels.

• A load ascension is expected soon, but not planned for this shift.

The following equipment is Out-Of-Service:

• 1 B ND Pump is OOS for motor replacement.

• 1 EMF46A, Train A KC Radiation Monitor, failed last shift (IAE is investigating).

• MCB Annunciator IAD-12, F-5, FWST EMERGENCY LOW TEMPERATURE, has alarmed.

• Control Room FWST Temperature indication is normal (IAE is investigating)

Crew Directions:

• Maintain present plant conditions.

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

t h Rounds. Carol Extra(s) Bill Ed Wayne Tanya

PROGRAM: McGuire Operations Training MODULE: Initial License Operator Training Class 26 TOPIC: NRC Simulator Exam Scenario N10-1-3

REFERENCES:

1. OPI1/A161001003, Controlling Procedure for Unit Operation.

2. OP/i /A/6 150/009, Boron Concentration Control.

3. OPI1/A163001001 A, Turbine-Generator Load Change.

4. API1IAI5500/14, Rod Control Malfunction.

5. QAC Alarm M1A0960, Ui GENERATOR MVAR PRIMARY.

6. AP/1IA/5500/05, Generator Voltage and Electrical Grid Disturbances.

7. OP/1IA/61001010 D, Annunciator Response for Panel 1AD-3.

8. Technical Specification 3.3.2, ESFAS Instrumentation.

9. Alarm M1A0495, lB NV PUMP MOTOR OUTBOARD BEARING TEMP.

10. OP/1IA/6200/001 B, Chemical and Volume Control System Charging.

11. Technical Specification 3.5.2, ECCS Operating.

12. Selected License Commitment 16.9.9, Boration Systems Flow Path (Operating).

13. AP/1/A/5500/07, Loss of Electrical Power.

14. EP/i/A/5000/ECA-0.0, Loss of All AC Power.

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

16. EP/1 /A/5000/ES-0. 1, Reactor Trip Response.

Author: David Lazarony, Western Technical Services, Inc.

Facility Review:

Rev. 070710 1

Scenario Event Description NRC Scenario 3 Facility: McGuire Scenario No.: 3 Op Test No.: Nb-I Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 75% power (MOL), following a plant load decrease four days ago to this power level, due to unusually high vibrations on the lB NCP. The System Engineer has been monitoring the NCP, and vibration levels have stabilized out at normally expected levels. A power ascension to 100% power is expected for the shift. It is expected to raise power at 3 MWe/Minute. Use of Alternate Dilute during power ascension in accordance with Enclosure 4.4, Alternate Dilute, of OPII/A16150/009, Boron Concentration Control, has been approved. The RMWST Dissolved Oxygen Concentration is 800 ppb. Conditioned Power Level is 100%.

Turnover: The following equipment is Out-Of-Service: 1A CA Pump is OOS. 1ASP-5121, AS Header Pressure, failed last shift (IAE is investigating) and MCB Annunciator IAD-7, J 4, BAT EMPTY, has failed to off (IAE is investigating).

Event Maif. Event Type* Event No. No. Description 1 NA R-RO Power Increase N-SOP N-SRO 2 IREOO3A C-RO Uncontrolled outward Rod Motion in AUTO C-SRO 3 MGOOI C-RO Main Generthor Voltage Regulator Failure C-SRO 4 XMT I(TS)-SRO SG Pressure Transmitter fails Low SMO15 5 XMT C-BOP lB NV Pump Hi Bearing Temperature NV075 C(TS)-SRO 6 EPOO9B C-BOP LOP to I ETB/1 B DG trips on Auto Start DGOO3B C-SRO 7 EPOO1 M-RO Loss of Off-Site Power/lA Sequencer fails to Start the DG EQBOO3A M-BOP M-SRO 8 DEHOO3A NA Main Turbine fails to Auto trip (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario vent Description NRC Scenario 3 McGuire 2010 NRC Scenario #3 The plant is at 75% power (MOL), following a plant load decrease four days ago to this power level, due to unusually high vibrations on the lB NCP. The System Engineer has been monitoring the NCP, and vibration levels have stabilized out at normally expected levels. A power ascension to 100% power is expected for the shift. It is expected to raise power at 3 MWe/Minute. Use of Alternate Dilute during power ascension in accordance with Enclosure 4.4, Alternate Dilute, of OPII/A161501009, Boron Concentration Control, has been approved. The RMWST Dissolved Oxygen Concentration is 800 ppb. Conditioned Power Level is 100%.

The following equipment is Out-Of-Service: 1A CA Pump is QOS. 1ASP-5121, AS Header Pressure, failed last shift (IAE is investigating) and MCB Annunciator IAD-7, J-4, BAT EMPTY, has failed to off (IAE is investigating).

Shortly after taking the watch, the operator will commence a load increase to 100% starting with Step 3.32.11 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 OP/1/N6150/009, Boron Concentration Control, and raise Turbine load in accordance with OP/1/A16300/001 A, Turbine-Generator Load Change.

After the load increase is started, the Control Rods will fail such that rods are moving outward in AUTO. The operator will enter AP/1/A/5500/14, Rod Control Malfunction.

After this, the Main Generator Voltage Regulator will fail causing the generator to operate outside the Capability Curve. The operator will respond in accordance with OAC Alarm M1A0960, Ui GENERATOR MVAR PRIMARY, and enter API1/A!5500/05, Generator Voltage and Electrical Grid Disturbances, and make adjustments of Main Generator voltage.

Subsequently, the 1A SG pressure will fail, low. The DCS will respond in such a way that the plant will be unaffected. However, the operator will address MCB Annunciator 1AD-4, S/G A LO PRESS STM LINE ISOL ALERT, and Technical Specification 3.3.2, ESFAS Instrumentation.

Subsequently, the lB NV Pump motor will develop a hot bearing. The operator will respond in accordance with OAC Alarm M1A0495, lB NV PUMP MOTOR OUTBOARD BEARING TEMP, and swap Charging Pumps in accordance with OP/1/A/6200/001 B, Chemical and Volume Control System Charging, Enclosure 4.2, NV Pump Operation. The operator will address Technical Specification 3.5.2, ECCS Operating, and Selected License Commitment 16.9.9, Boration Systems Flow Path (Opeating).

Following this, the Normal Supply Breaker for IETB will trip OPEN causing an LOP on IETB.

The operator will enter API1/A15500107, Loss of Electrical Power. On the LOP, the 1 B DG will trip, and the operator will need to start the A Train equipment.

Shortly after this, a total loss of off-site power will occur. The 1A DG will NOT start automatically, and the operator will enter EP/1/A15000/ECA-0.0, Loss of All AC Power.

Additionally, the Main Turbine will fail to trip automatically, and the operator will trip the Turbine Manually.

Within ECA-0.0, the operator will be directed to start the 1A DG manually. After the operator starts the 1A DG, the Sequencer will fail to load Bus 1 ETA automatically, requiring the operator to manually load the Train A equipment onto the Bus. Upon re-energizing and manually loading Scenario Event Description NRC Scenario 3 equipment onto Bus 1ETA, the operator will transition to EPI1IAI5000IE-O, Reactor Trip and Safety Injection, and then to EP/1/A5000/ES-O.1, Reactor Trip Response.

The scenario will terminate when the operator transitions to ES-O.1.

Critical Tasks:

E-O C Energize at least one AC Emergency Bus before completing Step 7 of ECA-O.O.

Safety Significance: Failure to energize at least one AC Emergency Bus when conditions exist that allow the operator to do so, constitutes mis-operation or incorrect operator performance that unnecessarily prolongs a degraded AC Emergency Power condition, that under varying circumstances could lead to the direct challenge of fission product barriers. For instance, if the Emergency AC Power System is degraded longer than that required by plant circumstances, a single failure in the operation of the SSF, or delayed placement in service, could affect unnecessarily and challenge the RCP Seals (NC System Barrier).

Likewise, if the Emergency AC Power System is degraded longer than that required by plant circumstances, a single failure in the operation of the TDAFW Pump, or delayed placement in service, could affect unnecessarily and challenge the Heat Sink and then the Core Cooling Critical Safety Functions (NC System Barrier).

E-OQ Manually trip the Turbine before an Orange path develops on the Subcriticality or Integrity Critical Safety Function.

Safety Significance: Failure to trip the Main Turbine when conditions exist that allow the operator to do so, constitutes mis-operation or incorrect operator performance that unnecessarily challenges the Subcriticality or Integrity Critical Safety Function during a degraded AC Emergency Power condition.

Additionally, failure to trip the Main Turbine reduces Steam Generator Inventory when the CA System is in a reduced capacity condition. Under such conditions, a Single failure, such as an overspeed of the TD AFW Pump, could result in a challenge to the Heat Sink Critical Safety Function, and subsequently, the Core Cooling Critical Safety Function.

Scenario Event Description NRC Scenario 3 SIMULATOR OPERATOR INSTRUCTIONS Bench Mark ACTIVITY DESCRIPTION Q Sim. Setup Rod Step On Q Reset to Temp I/C T 0 Malfunctions:

159. ANN-ADII-C05 ON, Transformer A Urgent Alarm ANN-ADII-F05 = ON, Transformer B Urgent Alarm ANN-ADII-B05 = ON, Transformer A Trouble Alarm ANN-ADII-E05 = ON, Transformer B Trouble Alarm LOA-CAOO9 = Racked Out, IA CA Pump Breaker Racked Out XMT-ASOOI = 0, AS Header Pressure ANN-ADO7-J04 = I (OFF)

MAL EQBOO3A = 2 DEHOO3A, Main Turbine fails to Trip Q RUN Place 0-Stick on:

IA CA Pump Breaker Racked Out Reset All SLIMS AS Header Pressure IAD-7, J4 Update Status Board, NOTE: RMWST DO = <1000 ppb.

Setup OAC Freeze.

j Update Fresh Tech.

Spec. Log.

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

Prior to Crew RUN Briefing Scenario Event Description NRC Scenario 3 Bench Mark ACTIVITY DESCRIPTION Crew Briefing Assign Crew Positions based on evaluation requirements

2. Review the Shift Turnover Information with the crew.

3. Provide T-SAIL Entry for IA CA Pump.

4. Provide Enclosure 4.1 of OP/1/A/6100/003, Enclosure 4.1 marked as follows:

Step 2.3 Initialed.

Step 3.1 Checkbox checked.

Step 3.2 Initialed.

Step 3.3 Initialed.

Step 3.3.1 Checkbox checked.

Step 3.3.2 Checkbox checked, Entry Step = 3.32.1.

Step 3.3.3 Checkbox checked.

Step 3.32.1 Checkbox checked.

Step 3.32.2 Checkbox checked.

Step 3.32.3 Initialed, Person Notified Monty Champion, Todays Date Step 3.32.5 Checkbox checked.

Step 3.32.6.1 Initialed, Person Notified Bob Smith, Todays Date Step 3.32.6.2 NA/Initialed.

Step 3.32.6.3 NA/Initialed.

Step 3.32.7.1 Checkbox checked.

Step 3.32.7.2 Initialed.

Step 3.32.8.1 Checkbox checked.

Step 3.32.8.2 Checkbox checked.

Step 3.32.8.3 All five Checkboxes checked.

Step 3.32.9 NA/Initialed.

Step 3.32.10 NA/Initialed.

5. Provide copy of OP/1/A/6150/009.

6. Provide copy of OP/1/N6300/001 A.

7. Provide reactivity Plan based on the following Data:

RTP 75.429 Rods SDB-226, A, B, C, D CBA226 CBB -226 CBC226 CBD178 Xe worth 2444.09 Sm Eq (+)4.54 Xe rate (+).57 pcm/min NC Boron1135.98 ppm

[Xe] -2395.4 250 EFPD Tave 576.4

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

NOTE: The Floor Instructor will need to provide the CRS with a pre-printed copy of OPIIIA!62001001 B during event 5.

Scenario Event Description NRC Scenario 3 Bench Mark ACTIVITY DESCRIPTION Q T-O Begin Familiarization Period At direction of Event I Power Increase examiner At direction of Event 2 Uncontrolled outward Rod Motion in AUTO examiner (MALF) IREOO3A = OUT Trigger #1 D At direction of Event 3 Main Generator Voltage Regulator Failure examiner MGOOI = 95%

60 second Ramp Trigger #3 Q At direction of Event 4 SG Pressure Transmitter fails Low examiner (XMT) SMOI5 = 0 5 second Ramp Trigger #5 Q At direction of Event 5 lB NV Pump Hi Bearing Temperature examiner (XMT) NV075 = 206 Ramp Start Value = 185 NOTE: Place severity at 150 on 300 second Ramp after lB NV Pump is stopped.

420 second Ramp

• NOTE: The Floor Instructor will need to Trigger #7 provide the CR5 with a pre-printed copy of OPII!A162001001 B during this event.

Q At direction of Event 6 LOP to 1 ETB/1 B DG trips on Auto Start examiner (MALF) EPOO9B (5 second delayed)

NOTE: This malfunction is entered at T0 (MALF) DGOO3B Trigger #9 Scenario Event Description NRC Scenario 3 Bench Mark ACTIVITY DESCRIPTION Q At direction of Event 7 Loss of Off-Site Power/IA Sequencer fails to Start examiner the DG (MALF) EPOOI (MALF) EQBOO3A NOTE: This malfunction is entered at T=O Trigger #11 NOTE: When directed to activate SSF, activate CAEP RUN ZZRUNSSF After 8 minutes, takes 2 minutes to complete.

Use Trigger #13 (MALF-KCOO2F = 0, 30 second Ramp); when need to Close IKC-338B.

Q Continued Event 8 Main Turbine fails to Auto trip from Event 7 (MALF) DEHOO3A NOTE: This malfunction is entered at T=0 Q Terminate the scenario upon direction of Lead Examiner Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 1 Page 9 of 46 Event

Description:

Power Increase Shortly after taking the watch, the operator will commence a load increase to 100%

starting with Step 3.32.11 of Enclosure 4.1, Power Increase, of OP/11A16100/003, Controlling Procedure for Unit Operation. The operator will dilute the NC System Boron concentration in accordance with Enclosure 4.4, Alternate Dilute, of 0P111A161501009, Boron Concentration Control, and raise Turbine load in accordance with 0P111N63001001 A, Turbine-Generator Load Change.

Booth Operator Instructions: NA Indications Available: NA Time Pos. Expected ActionslBehavior Comments OPII!AI61 001003, CONTROLLING PROCEDURE FOR UNIT OPERATIONS ENCLOSURE 4.1, POWER INCREASE CRS (Step 3.32.11) Continue power increase to NOTE: The power increase 95% RTP. will be at 3 MWe/minute.

OPIIIAI6I 501009, BORON CONCENTRATION CONTROL ENCLOSURE 4.4, ALTERNATE DILUTE NOTE: The BOP may repeat this task as needed during the power increase.

BOP (Step 3.6) Ensure the following reset to zero:

(R.M.)

. Total Make Up Flow Counter

. Boric Acid Flow Counter BOP (Step 3.7) Set Total Make Up Flow Counter to value determined in Step 3.5. (R.M.)

BOP (Step 3.8) Select ALTERNATE DILUTE on NC Sys M/U Controller.

BOP (Step 3.9) If desired to makeup only through 1 NV-i 75A (BA Blender to VCT Outlet),

select CLOSED on 1NV-171A(BA Blender to VCT Inlet).

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 1 Page 10 of 46 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments BOP (Step 3.10) IF desired to adjust reactor NOTE: It is NOT desired to makeup water flow adjust reactor makeup water flow.

BOP (Step 3.11) IF desired to manually adjust reactor makeup water flow....

BOP (Step 3.12) IF AT ANY TIME it is desired to NOTE: It is NOT required to lower VCT level, perform the necessary lower VCT level.

steps.

BOP (Step 3.13) IF AT ANY TIME plant parameters require termination of dilution, perform the necessary steps.

BOP (Step 3.14) Momentarily select START on NC System Make Up. (R.M.)

BOP (Step 3.15) Check NC System Make Up red light lit.

BOP (Step 3.16) Check 1NV-175A(BA Blender To VCT Outlet) open.

BOP (Step 3.17) Check 1NV-252A (Rx M/U Water To Blender control) open or throttled as required.

BOP (Step 3.18) IF INV-171A(BA Blender To NOTE: 1NV-171A is NOT in VCT Inlet) in AUTO AUTO.

BOP (Step 3.19) Check Rx M/U Water Pump starts.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario# 3 Event# 1 Page 11 of 46 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments BOP (Step 3.20) Monitor Total Make Up Flow Counter. (R.M.)

BOP (Step 3.21) HOLD until one of the following occurs:

. Amount of reactor makeup water recorded per Step 3.5 added OR

. Reactor makeup water addition manually terminated BOP (Step 3.22) Ensure dilution terminated as follows: (R.M.)

. IF in AUTO, ensure the following off:

. 1A Rx M/U Water Pump

. lB Rx M/U Water Pump

. Ensure the following closed:

. 1 NV-i 75A (BA Blender To VCT Outlet)

. 1 NV-252A (RX M/U Water To Blender Control)

. 1NV-171A (BA Blender To VCT Inlet)

BOP (Step 3.23) Ensure 1NV-171A(BA Blender to VCT Inlet) in AUTO.

BOP (Step 3.24) Ensure Rx M/U Water Flow Control in AUTO. (R.M.)

BOP (Step 3.25) IF Rx M.U Water Flow Control NOTE: The Rx M.U Water adjusted per Step 3.10 OR Step 3.1 1.... Flow Control was NOT adjusted.

BOP (Step 3.26) Ensure 1NV-137A (NC Filters OtIt 3-Way Control) in AUTO.

11-

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 1 Page 12 of 46 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments BOP (Step 3.27) IF desired to flush blender.... NOTE: It is NOT desired to flush the blender.

BOP (Step 3.28) Select AUTO for NC Sys M/U Controller.

BOP (Step 3.29) Ensure the following reset to zero: (R.M.)

. Total Make Up Flow Counter

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

OP/11A163001001A, TURBINE-GENERATOR STARTUP/SHUTDOWN ENCLOSURE 4.1, TURBINE-GENERATOR LOAD CHANGE RO (Step 3.5) Changing Turbine Load IF Turbine in OPERATOR AUTO, 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.

. Depress LOAD RATE.

. Enter desired load rate in NOTE: the RO will select 3 VARIABLE DISPLAY. MWe/Min loading rate.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 1 Page 13 of 46 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments

. Depress ENTER.

. Depress REFERENCE.

. Enter desired load in VARIABLE DIS PLAY.

. Depress ENTER.

. Depress GO

. Check load changes at selected rate.

OPII!A161001003, CONTROLLING PROCEDURE FOR UNIT OPERATIONS ENCLOSURE 4.1, POWER INCREASE ROI (Step 3.32.12) At greater than 85% steam flow from each SIG, ensure the following BOP valves in auto and open:

. ICFIO4AB (1A SIG CF Cntrl VIv Bypass)

. 1CF1O5AB (lB SIC CF Cntrl Vlv Bypass)

. 1CFIO6AB (10 S!G CF Cntrl Vlv Bypass)

. 1CF1O7AB (1D SIC CF Cntrl Vlv Bypass)

Examiner NOTE: It may take several minutes for the next malfunction to appear. It may be prudent to GO TO the next malfunction, enter Trigger #1, while the power increase continues. This Malfunction requires an actual rod demand signal to be present to actuate the failure.

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

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario# 3 Event# 2 Page 14 of 46 Event

Description:

Uncontrolled outward Rod Motion in AUTO After the load increase is started, the Control Rods will fail such that rods are moving outward in AUTO. The operator will enter API1/A15500/14, Rod Control Malfunction.

Booth Operator Instructions: Operate Trigger #1 (IREOO3A)

Indications Available: _____________________

• Rods stepping out continuously, more than the normal one to two steps.

Tavg Tref is positive with rods still moving outward.

Time Pos. Expected ActionslBehavior Comments NOTE: When the malfunction is diagnosed the CRS may go to HOLD on the Turbine.

AP111A15500114, ROD CONTROL MALFUNCTION RO (Step 1) IF more than one rod dropped, Immediate Action THEN NOTE: No control rods dropped during this event.

RO (Step 2) Place control rods in manual. Immediate Action RO (Step 3) Check rod movement STOPPED. Immediate Action NOTE: There was no rod motion when the Rods were taken to Manual.

RO (Step 4) Check all rods ALIGNED WITH ASSOCIATED BANK.

RO (Step 5) Check ROD CONTROL URGENT FAILURE alarm (1AD-2, A-1O) DARK.

RO (Step 6) Check T-AVG/T-REF FAILURE ROD STOP alarm (1AD-2, B-7) DARK.

- 14-

Appendix D Operator Action Form ES-D-2 Op Test No.: NW-i Scenario # 3 Event # 2 Page 15 of 46 Event

Description:

Uncontrolled outward Rod Motion in AUTO Time Pos. Expected ActionslBehavior Comments RO (Step7) IF this AP entered due to NOTE: The SRO will transition unwarranted rod insertion or withdrawal, to AP-14, Enclosure 3.

THEN GO TO Enclosure 3 (Response to Continuous Rod Movement).

APII 1A15500114, ROD CONTROL MALFUNCTION ENCLOSURE 3, RESPONSE TO CONTINUOUS ROD MOVEMENT CRS (Step 1) Announce occurrence on paging NOTE: The CRS may ask U2 system. RO to make Plant Announcement.

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 Rod Control malfunction.

If so, Booth Instructor acknowledge as WCC.

RO (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.

RO (Step 5) Do not move rods until IAE determines rod motion is permissible.

RO (Step 6) Maintain T-Avg within 1°F of programmed T-Ref as follows:

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 2 Page 16 of 46 Event

Description:

Uncontrolled outward Rod Motion in AUTO Time Pos. Expected Actions/Behavior Comments

. Adjust Turbine load NOTE: The RO will adjust Turbine Load as needed to maintain T-avg.

OR

. Borate/dilute NC System.

RO (Step 7) IF AT ANY TIME a runback occurs NOTE: This is a Continuous while in this procedure, THEN observe the Action. The CRS will make following guidance: both board operators aware.

IF IAE has determined that it is permissible to move rods, THEN respond to the runback PER AP/1/A/5500/03 (Load Rejection).

. For all other circumstances, assume rod control is not available and respond to the run back as follows:

. Trip Reactor.

. GO TO EP/1/N5000/E-0 (Reactor Trip or Safety Injection).

RO (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 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%, THEN perform the following:

. Trip Reactor.

• GO TO EP/1/N5000/E-0 (Reactor Trip or Safety Injection).

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario# 3 Event# 2 Page 17 of 46 Event

Description:

Uncontrolled outward Rod Motion in AUTO Time Pos. Expected ActionslBehavior Comments NOTE: The CRS may call WCC/IAE to address.

If so, Booth Instructor acknowledge as WCC. After 5 minutes, report that the Control Rods must be kept in MANUAL, and that they can move rods in MANUAL as needed.

RO (Step 9) WHEN problem is repaired, THEN NOTE: The CRS will likely perform the following: conduct a Focus Brief.

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

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 3 Page 18 of 46 Event

Description:

Main Generator Voltage Regulator Failure After this, the Main Generator Voltage Regulator will fail causing the generator to operate outside the Capability Curve. The operator will respond in accordance with OAC Alarm M1A0960, UI GENERATOR MVAR PRIMARY, and enter AP/l/A/5500105, Generator Voltage and Electrical Grid Disturbances, and make adjustments of Main Generator voltage. ____________________

Booth Operator Instructions: Operate Trigger #3 (MGOOI (95% on 60 second Ramp))

Indications Available:

• OAC Alarm M1A0960, UI GENERATOR MVAR PRIMARY LO-LO

. MCB MVAR indication lower from 150 to -242

. Main Generator Power Factor moves to Leading 0.95

. Main Generator Voltage 22.71KV e A S i lfl I lime ros. txpeciea Comments

McilQflsibeflaVlor :

NOTE: The CRS may enter AP5 directly.

OAC ALARM M1A0960, UI GENERATOR MVAR PRIMARY CRS (Step 1) LO-LO 100 MVARs Leading (-100 MVARS)

. GO TO AP/1/A/5500/05 (Generator NOTE: The CRS will transition Voltage and E!ectric Grid Disturbances). to AP5.

APII!A15500105, GENERATOR VOLTAGE AND ELECTRIC GRID DISTURBANCES CRS (Step 1) Announce occurrence on page. NOTE: The CRS may ask U2 RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

CRS (Step 2) Ensure dispatcher is aware of NOTE: The CRS/BOP will problem. contact SOC.

Booth Instructor: as SOC, acknowledge.

Appendix D Operator Action Form ES-D-2 Op Test No.: N 10-1 Scenario # 3 Event # 3 Page 19 of 46 Event

Description:

Main Generator Voltage Regulator Failure Time Pos. Exoected ActionslBehavior Comments CRS (Step 3) Notify Unit 2 to evaluate Floor Instructor: As U2 RO, implementing API2IA/5500/05 (Generator acknowledge.

Voltage and Electric Grid Disturbances).

RO (Step 4) Check Unit 1 Generator TIED TO GRID.

RO (Step 5) IF AT ANY TIME reactor power is NOTE: This is a Continuous greater than 100%, THEN reduce turbine Action. The CRS will make load to maintain reactor power less than both board operators aware.

100%.

RO (Step 6) Check Unit 1 Generator frequency-GREATER THAN 58.5 Hz.

RO (Step 7) Monitor Generator Capability Curve NOTE: The RO or BOP will as follows: most likely place Curve on OAC Screen.

. Check Generator voltage LESS THAN 24 KV.

. Check OAC IN SERVICE.

. Monitor Generator Capability Curve PER OAC turn on code GENCAP.

RO (Step 8) Check Generator MVARs WITHIN NOTE: The MVARs will NOT LIMITS OF GENERATOR CAPABILITY be within the capability curve.

CURVE.

CRS (Step 8 RNO) GO TO Step 11.

RO (Step 1 1) Adjust MVAR5 to within the capability curve by performing one of the following:

. Depress RAISE on the VOLTAGE NOTE: This adjustment will ADJUST to reduce leading MVARs. NOT be effective at controlling MVAR5.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 3 Page 20 of 46 Event

Description:

Main Generator Voltage Regulator Failure Time Pos. Expected ActionslBehavior Comments RO (Step 12) Check Generator MVARs NOTE: The MVARs will NOT WITHING LIMITS OF GENERATOR be within the capability curve.

CAPABILITY CURVE.

RO (Step 12 RNO) IF actions in Step 11 do not restore MVARs, THEN perform the following:

. IF voltage regulator in AUTO, THEN perform the following:

. Place voltage regulator in MAN.

. Adjust MVARs to within the capability curve.

• IF unable to maintain MVARs within NOTE: The MVARs will be curve, THEN.... able to be adjusted with the Voltage Regulator in MAN UAL.

RO (Step 13) Monitor Generator frequency as follows:

• Check generator frequency AT 60 Hz.

. IF AT ANY TIME generatdr frequency is NOTE: This is a Continuous abnormal OR TCCISQC reports Action. The CRS will make abnormal grid frequency condition, both board operators aware.

THEN GO TO Step 13d.

CRS . GOTOStep16.

RO (Step 16) Check if voltage regulator malfunction has occurred:

. Generator MVARs FLUCTUATING (SWINGING) WITHOUT A KNOWN GRID DISTURBANCE IN EFFECT OR

. OAC turn on code MAINGEN INDICATES PROBLEM WITH VOLTAGE REGULATOR. -_________________

OR Appendix D Operator Action Form ES-D-2 OpTestNo.: °- Scenario# 3 Event# 3 Page 21 of 46 Event

Description:

Main Generator Voltage Regulator Failure Time Pos. Expected ActionslBehavior Comments

. VOLTAGE REGULATOR COMMON NOTE: The RO will conclude TROUBLE alarm (lAD-i, D-4) LIT. that a Voltage Regulator malfunction has occurred because it would NOT operate in AUTO.

CRS (Step 17) Contact the following personnel for NOTE: The CRS may call guidance: WOO to address the malfunction.

If so, Booth Instructor acknowledge as WCC.

. System Engineering

. Maintenance Technical Support.

CRS (Step 18) IF AT ANY TIME System NOTE: This is a Continuous Engineering or Maintenance Technical Action. The CRS will make Support request operation of the voltage both board operators aware.

regulator from the local panel, THEN dispatch licensed operator to perform applicable section(s) of OP/i /A/6300/00 1 (Turbine Generator Startup/Shutdown),

Enclosure 4.10 (Voltage Regulator Operation From Ui Gen Voltage Reg Local Control Panel).

RO (Step 19) Check voltage regulator- IN NOTE: The Voltage Regulator AUTO. is NOT in AUTO.

RO (Step 19 RNO) Perform the following:

Notify SOC of the following: NOTE: The CRS/BOP will contact SOC.

Booth Instructor: as SOC, acknowledge.

. Unit 1 voltage regulator is in manual.

. Ensure Real Time Contingency Analysis (RTCA) considers status of the Unit 1 voltage regulator.

- 21 -

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 3 Page 22 of 46 Event

Description:

Main Generator Voltage Regulator Failure r . ..___.__I *_.

IIIII U dJItIIIIIIL

. WHEN Engineering or Maintenance NOTE: The investigation will directs restoring voltage regulator to continue.

AUTO, THEN CRS (Step 20) Check if TCC or Soc has reported any of the following:

Real Time Contingency Analysis (RTCA) indicated that switchyard voltage would not be adequate should the unit trip.

OR Real Time Contingency Analysis (RTCA) indicates that switchyard voltage would not be adequate if further grid degradation occurs.

OR

. Actual or predicted Megawatt reserves are less than 500 MW.

OR

. North American Electric Reliability Corporation (NERC) Alert Level 2 or 3 has been declared.

OR

. Degraded 230 KV switchyard (grid) NOTE: SOC has NOT voltage or frequency condition exists. reported any of the listed conditions.

CRS (Step 20 RNO) GO TO Step 27.

CRS (Step 27) IF AT ANY TIME TCC notifies NOTE: This is a Continuous control room that Real Time Contingency Action. The CRS will make Analysis (RTCA) will be out of service for both board operators aware.

greater that four hours, THEN CRS (Step 28) WHEN conditions return to normal, NOTE: This is a Continuous THEN perform the following: Action. The CRS will make both board operators aware.

Appendix D Operator Action Form ESD-2 Op Test No.: Nb-i Scenario # 3 Event # 3 Page 23 of 46 Event

Description:

Main Generator Voltage Regulator Failure Time Pns Exncrtd ActinnsIRhvinr Cnmmnnt

. Check Generator frequency HAS REMAINED GREATER THAN 58.5 HZ.

. Check Unit 1 Generator TIED TO GRID.

Ensure Unit 1 Generator Bus Voltage is adjusted PER Data Book, Enclosure 4.3, Table 3.1.3, Generator Voltage Operating Schedule, including any operational restrictions.

CRS . Exit this AP. NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner move to Event #4.

- 23 -

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 4 Page 24 of 46 Event

Description:

SG Pressure Transmitter fails Low Subsequently, the 1A SG pressure will fail low. The DCS will respond in such a way that the plant will be unaffected. However, the operator will address MCB Annunciator lAD-4, SIG A LO PRESS STM LINE ISOL ALERT, and Technical Specification 3.3.2, ESFAS Instrumentation.

Booth Operator Instructions: Operate Trigger #5 (XMT-SMOI5 (0 on 5 second Ramp))

Indications Available:

. MOB Annunciator 1AD-2 E-8, DCS TROUBLE

. MOB Annunciator 1AD-3 A-i, SIG A LO PRESS STM LINE SQL ALERT

. MOB Annunciator IAD-4 B-5, S/G LO STEAM PRESS

. iA SG Pressure (1SMP-5100) indicates 0 psig.

Pos. Expected ActionslBehavior Comments MCB ANNUNCIATOR IAD-3, Al, S!G A LO PRESS STM LINE ISOL ALERT ORS (Step 1) Notify IAE. NOTE: The ORS may call WCO/IAE to address the malfunction.

If so, Booth Instructor acknowledge as WOO.

ORS (Step 2) Refer to Tech Specs.

TECHNICAL SPECIFICATION 3.3.2, ESFAS INSTRUMENTATION ORS LOO 3.3.2 The ESFAS instrumentation for each Function in Table 3.3.2-i shall be OPERABLE (Functions 4.d.i and 2).

ORS APPLIOABILITY: According to Table 3.3.2-i.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 4 Page 25 of 46 Event

Description:

SO Pressure Transmitter fails Low Pos. Exnected Actinns!Rhivior Cnmmnt CRS ACTIONS CRS CONDITION REQUIRED COMPLETION ACTION TIME A. One or more A.1 Enter the Immediately Functions Condition with one or referenced more in Table required 3.3.2-1 for channels or the trains channel(s) inoperable or train(s).

D. One channel D. 1 Place 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. channel in trip.

OR D.2.1 Be in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> MODE 3.

AND D.2.2 Be in 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> MODE 4.

At the discretion of the Lead Examiner move to Event #5.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-I Scenario # 3 Event # 5 Page 26 of 46 Event

Description:

lB NV Pump Hi Bearing Temperature Subsequently, the lB NV Pump motor will develop a hot bearing. The operator will respond in accordance with OAC Alarm M1A0495, lB NV PUMP MOTOR OUTBOARD BEARING TEMP, and swap Charging Pumps in accordance with OP111A162001001 B, Chemical and Volume Control System - Charging, Enclosure 4.2, NV Pump Operation. The operator will address Technical Specification 3.5.2, ECCS -

Operating, and Selected License Commitment 16.9.9, Boration Systems Flow Path (Operating).

Booth Operator Instructions: Operate Trigger #7 (XMT-NV075 (206 on 420 second Ramp (starting from 1850))

NOTE: The Floor Instructor will provide the CRS with a pre-printed copy of OPII/A16200/001 B per the scripted response.

Indications Available:

. OAC Alarm M1A0495, lB NV PUMP MOTOR OUTBOARD BEARING TEMP.

Time Pos. Expected ActionslBehavior Comments OAC ALARM M1A0495, lB NV PUMP MOTOR OUTBOARD BEARING TEMP BOP (Step 1) Check oil levels on affected Pump NOTE: The CRS will dispatch and Motor. an NEO to evaluate the pump.

If so, Booth Instructor wait 4 minutes and report back that the lB NV Pump motor casing is very hot.

BOP (Step 2) If either oil level is low (Below red tape)

BOP (Step 3) If motor oil ring is NOT rotating BOP (Step 4) If motor bearing temperature is NOTE: The CRS will obtain a increasing greater than 2°F/minute, copy of OP/1/N6200!OO1 B.

Shutdown Affected Pump per Floor Instructor: When the OP/l/A/6200/OO1 B (Chemical and Volume CRS seeks to obtain copy, Control System Charging) provide a pre-printed copy.

BOP (Step 5) Monitor affected NV bearing Temperature on point trend.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 5 Page 27 of 46 Event

Description:

lB NV Pump Hi Bearing Temperature Time Pos Expected ActionslBehavior Comments BOP (Step 6) Verify thrust bearing oil temp gauge is less than 150°F.

BOP (Step 7) Notify Ehgineering of the high NV NOTE: The CRS may call Bearing temperature. WCC/Maintenance to address the Pump Motor.

If so, Booth Instructor acknowledge as WOO.

0P111A162001001 B, CHEMICAL AND VOLUME CONTROL SYSTEM - CHARGING ENCLOSURE 42, NV PUMP OPERATION CRS (Step 3.1) Evaluate all outstanding R&Rs NOTE: The CRS may call that may impact performance of this WCC/Maintenance to address procedure. the 1A NV Pump.

If so, Booth Instructor report as WCCS that there are no outstanding R&Rs that could affect the performance of the IA NV Pump.

CRS (Step 3.2) Perform the following section, as applicable.

Section 3.4, Shifting from 1 B NV Pump to NOTE: The CRS will go to 1A NV Pump with all reactor Coolant Section 3.4.

Cold Leg Temperatures Greater Than 300°F.

BOP (Step 3.4) Shifting from lB NV Pump to 1A NV Pump with all reactor Coolant Cold Leg Temperatures Greater Than 300°F.

. If NC System is less than 400 psig NOTE: The NC System is>

400 psig.

. If immediate pump swap is NOT NOTE: There are several required.... steps designed to allow the operator to start the pump immediately if needed.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 5 Page 28 of 46 Event

Description:

lB NV Pump Hi Bearing Temperature Timp Pnc PvnirtcI Comments

. If immediate pump swap is NOT required...

• If immediate pump swap is NOT required....

BOP

• Start 1A NV Lube Oil Pump.

. If this is a routine start of the IA NV NOTE: This is NOT a routine Pump Start of the Pump.

• Start the 1A NV Pump.

BOP

• Place in AUTO 1A NV Lube Oil Pump.

• Depress STP for 1A NV Lube Oil Pump.

• Check START pushbutton released AND OFF lit for 1A NV Lube Oil Pump.

. Calculate DP between Seal Balancing NOTE: The BOP will contact Line Pressure and Suction Pressure for the NEO to obtain the local IA NV Pump. pressures necessary for this calculation.

Booth Instructor: as NEO, report the following:

1NVPG-5810 (Seal Balancing Line Pressure) = 51.2 psig 1 NVPG-5790 (Suction Pressure) = 31.2

• If DP between Seal Balancing Line NOTE: The DP is < 50 psid.

Pressure and Suction Pressure greater than 50 psid

• Stop the I B NV Pump. Booth Instructor: When the 1 B NV Pump is stopped, change severity of XMT NV075 to 150, ramped over 300 seconds.

• Adjust charging flow and seal flow as needed.

• Evaluate back leakage through 1 B NV Pump as follows:

• HOLD until Pzr level stable at setpoint, THEN check I NV-238 (Charging Line Flow Control)_output.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 3 Event # 5 Page 29 of 46 Event

Description:

lB NV Pump Hi Bearing Temperature Time Pos. Expected ActionslBehavior Comments

. If charging flow less than or equal to NOTE: No back leakage will 75 gpm AND INV-238 output greater be indicated.

than 74%

NOTE: The CRS will likely conduct a Focus Brief.

TECHNICAL SPECIFICATION 3.5.2, ECCS-OPERATING CRS LCO 3.5.2 Two ECCS trains shall be OPERABLE.

CRS APPLICABILITY: MODES 1, 2, and 3.

CRS ACTIONS CRS CONDITION REQUIRED COMPLETION ACTION TIME A. One or more A. 1 Restore 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> trains train(s) to inoperable OPERABLE status.

AND At least 100% of the ECCS flow equivalent to a single OPERALBE ECCS train available.

SELECTED LICENSEE COMMITMENT 16.9.9, BORATION SYSTEMS FLOW PATH (OPERATING)

CRS 16.9.9 Boration Systems Flow Path (Operating)

CRS COMMITMENT: Two of the following three boron injection flow paths shall be OPERABLE:

Appendix D Operator Action Form ES-D-2 Op Test No.: N 10-1 Scenario # 3 Event # 5 Page 30 of 46 Event

Description:

lB NV Pump Hi Bearing Temperature r r A Comments I IIJI I nLII I, CRS . The flow path from a boric acid tank via a boric acid transfer pump and a charging pump to the reactor coolant system AND CRS . Two flow paths from the refueling water storage tank via charging pumps to the reactor coolant system.

CRS APPLICABILITY: MODES 1,2, and 3.

CRS ACTIONS CRS CONDITION REQUIRED COMPLETION ACTION TIME A. One required A.1 Restore the 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> boron required injection flow boron path injection inoperable. flow path to OPERABLE status.

At the discretion of the Lead Examiner move to Event #6.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 6 Page 31 of 46 Event

Description:

LOP to IETB/IB DG trips on Auto Start Following this, the Normal Supply Breaker for 1ETB will trip OPEN causing an LOP on 1ETB. The operator will respond enter AP/1/A/5500/07, Loss of Electrical Power. On the LOP, the I B DG will trip, and the operator will need to start the A Train equipment.

Booth Operator Instructions: Operate Trigger #9 (EPOO9B (5 second delay),

DGOO3B)

Indications Available:

• MCB Annunciator lAD-Il D-1, ETB 4.16 KVTROUBLE

• MCB Annunciator lAD-i 1 D-2, ETB 600V LC TROUBLE

• MCB Annunciator lAD-I 1 D-3, ETB 600/120V TROUBLE

• MCB Annunciator lAD-i 1 D-6, D/G PANEL TROUBLE

• ISI-14 Status Light, ETB LOSS/U NDERVOLTAGE PHASE X is LIT

• lSl-14 Status Light, ETB LOSS/UNDERVOLTAGE PHASE Y is LIT

• lSl-14 Status Light, ETB LOSS/U NDERVOLTAGE PHASE Z is LIT

• ISl-14 Status Light, BLACKOUT SEQ ACTUATED TRAIN B is LIT

• 1 B DG Diesel Generator voltaqe readinq 0 volts Time Pos Expected ActionslBehavior Comments AP!11A15500107, 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 NOTE: The Sequencer will APPLYING LOADS.

NOT be applying loads.

BOP (Step 1 RNO) Perform the following: Immediate Action

. IF both busses de-energized THEN.... NOTE: 1ETA is energized.

. Ensure the following pumps running on energized bus:

. NVpump

. KC pumps NOTE: The BOP will need to start the 1A1 and 1A2 KC Pumps.

. RN pump NOTE: The BOP will need to start the 1A RN Pump.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 6 Page 32 of 46 Event

Description:

LOP to IETBIIB DG trips on Auto Start Time Pos. Expected ActionslBehavior Comments 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 ETA 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, THEN.... NOTE: The IA NV Pump is running.

CRS . IF any pump was manually started per NOTE: Both the KC and RN APO7 Immediate Action, THEN GO TO Pumps were started as Step 8. Immediate Actions.

BOP (Step 8) Check D/Gs OFF. NOTE: The lB D/G has failed, Both D/Gs are OFF.

BOP (Step 9) Check ND System status:

. ND System IN RHR MODE AT TIME OF B/O.

CRS (Step 9 RNO) GO TO Step 10.

BOP (Step 10) Check any RN pump RUNNING. NOTE: The 1A RN Pump is running.

BOP (Step 1 1) Align KC as follows:

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 6 Page 33 of 46 Event

Description:

LOP to IETBIIB DO trips on Auto Start Time Pos. Expected ActionslBehavior Comments

. Place recirc valve on operating train in AUTO.

. 1KC-51A (Train A 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:

. A Train:

B OPEN 1 KC-3A (Tm A Rx Bldg Non Ess Ret Isol)

. OPEN I KC-230A (Tm A Rx Bldg Non Ess Sup_1501)

. OPEN 1 KC-394A (A NC Pump Therm Bar OtIt) -______________________

. OPEN 1 KC-345A (C 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.

. Ensure I RN-86A (A KC Hx Inlet Isol) is OPEN.

• CLOSE 1RN-43A (Train B To Non Ess Hdr lsol).

. THROTTLE I RN-89A (RN to A KC Hx Control) for desired KC cooling.

CRS (Step 14) Notify Unit 2 RO to start 2A RN Floor Instructor: As U2 RO pump. acknowledge.

At the discretion of the Lead Examiner move to Events #7-8.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 7 &8 Page 34 of 46 Event

Description:

Loss of Off-Site PowerIlA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Shortly after this, a total loss of off-site power will occur. The IA DG will NOT start automatically, and the operator will enter EP/1IA/5000/ECA-O.O, Loss of All AC Power.

Additionally, the Main Turbine will fail to trip automatically, and the operator will trip the Turbine Manually. Within ECA-O.O, the operator will be directed to start the 1A DG manually. After the operator starts the 1A DG, the Sequencer will fail to load Bus I ETA automatically, requiring the operator to manually load the Train A equipment onto the Bus. Upon re-energizing and manually loading equipment onto Bus 1ETA, the operator will transition to EPIIIA/50001E-O, Reactor Trip and Safety Injection, and then to EP/1/AI5000IES-O.1, Reactor Trip Response. The scenario will terminate when the operator transitions to ES-O.1.

Booth Operator Instructions: Operate Trigger #11 (EPOOI)

Indications Available:

. ISI-14 Status Light, ETA LOSS/U NDERVOLTAGE PHASE X is LIT

. ISI-14 Status Light, ETA LOSS/U NDERVOLTAGE PHASE Y is LIT

. ISI-14 Status Light, ETA LOSS/U NDERVOLTAGE PHASE Z is LIT

. Control Room lighting darkens

. DRPI Screens go dark.

. Reactor Trip Breaker GREEN status lights are LIT

. NC Pumps Breaker GREEN status lights are LIT T m Di r+ciI A +a Comments i- . - .. -

NOTE: The BOP may try to start the 1A DG manually.

ECA-O.O, LOSS OF ALL AC POWER CRS (Step 1) CSF Status trees shquld be NOTE: Crew will carry out monitored for information onIS. EPs Immediate Actions of ECA-O.O, referenced by them should not be prior to the CRS addressing implemented. the EP.

RO (Step 2) Check Reactor Trip: Immediate Action

. All rod bottom lights LIT

. Reactor trip and bypass breakers OPEN

. hR amps GOING DOWN. NOTE: The RO will NOT be able to determine rod bottom lights LIT and implement the Step 2 RNO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N 10-1 Scenario # 3 Event # 7&8 Page 3 of 46 Event

Description:

Loss of Off-Site PowerIlA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. Expected Actions!Behavior Comments RO (Step 2 RNO) Trip reactor. Immediate Action RO (Step 3) Check Turbine Tiip: Immediate Action

. All throttle valves CLOSED.

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

. Trip the Turbine

. IF the Turbine will not trip, THEN.... NOTE: When the RO manually trips the Turbine, the turbine will trip.

CRITICAL TASK:

(E-O Q) Manually trip the Turbine before an Orange path develops on the Subcriticality or Integrity Critical Safety Function.

Safety Significance: Failure to trip the Main Turbine when conditions exist that allow the operator to do so, constitutes mis-operation or incorrect operator performance that unnecessarily challenges the Subcriticality or Integrity Critical Safety Function during a degraded AC Emergency Power condition. Additionally, failure to trip the Main Turbine reduces Steam Generator Inventory when the CA System is in a reduced capacity condition. Under such conditions, a Single failure, such as an overspeed of the TD AFW Pump, could result in a challenge to the Heat Sink Critical Safety Function, and subsequently, the Core Cooling Critical Safety Function.

CRS (Step 4) Establish NC pump seal injection from the SSF as follows:

. Dispatch operator to SSF to perform the NOTE: The CRS will dispatch following: NEO to complete Enclosure 1.

If so, Booth Instructor/Floor Instructor acknowledge.

Wait 10 minutes and report that Enclosure 1 is complete.

. Obtain Brown Folder at SSF and complete Enclosure 1 (Unit 1 SSF ECA-O.O Actions).

. Dispatch operator to 1 ETA room as follows:

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 7 & 8 Page 36 of 46 Event

Description:

Loss of Off-Site PowerIlA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. Expected ActionslBehavior Comments

• Check if operator will enter Aux Bldg

- FROM MG SET ROOM.

. Give operator dosimeter from Unit 2 BOP desk.

CRS . Dispatch operator to perform NOTE: The CRS will dispatch Enclosure 2 (Unit I EMXA4 ECA NEO to complete Enclosure 2.

0.0 Actions). If so, Booth Instructor/Floor Instructor acknowledge as appropriate.

Booth Instructor: wait 8 minutes, then RUN CAEP file ZZRUNSSF_ECAO.O.

Wait 2 minutes and report that Enclosure 2 is complete.

CRS Use any of the following to notify security NOTE: The CRS will contact to immediately dispatch officer with key Security.

to SSF to ensure operator can access Booth Instructor: As SAS SSF: Operator, acknowledge.

• Security ringdown phone (located on Unit 2 BOP desk)

. 2688

. 4900. -

BOP (Step 5) Check NC System ISOLATED:

• Check the following letdown orifice isolation valves CLOSED.

. 1NV-458A (75 GPM LID Orifice Outlet Cont Isol).

. 1 NV-457A (45 GPM L/D Orifice Outlet Cont Isol).

. I NV-35A (Variable L/D Orifice Outlet Cont Isol).

. CLOSE the following valves:

. INV-IA (NC LID Isol To Regen_Hx)

. 1 NV-2A (NC L/D Isol To Regen_Hx).

. Check Pzr PORVs CLOSED

Appendix D Operator Action Form ES-D2 Op Test No.: Nb-i Scenario # 3 Event # 7&8 Page 7 of 46 Event

Description:

Loss of Off-Site PowerIlA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. ExDected Actions/Behavior Comments

• Check the following excess letdown isolation valves CLOSED:

. 1NV-24B (C NC Loop To Exs LID Hx IsoI)

• I NV-25B (C NC Loop To Exs LID Hx Isol).

• Check 1NV-121 (UI ND Letdown Control) CLOSED.

BOP (Step 6) Check total CA flow GREATER NOTE: The TD CA pump is THAN 450 GPM. the only operating CA pump, and the discharge flow control valves may have been throttled closed, due to the previous Blackout on 1 ETA.

BOP (Step 7) Try to restore power to I ETA or I ETB as follows:

. Place both trains DIG mode select switches to control room.

. Perform the following for any D/G(s) that are off:

. Depress, then release, RESET on sequencer.

. Start D/G. NOTE: the 1A DIG will start but NOT sequence loads.

. Check both DIGs RUNNING.

. (Step 7c RNO) Perform the following:

. Initiate S/I

. Notify Unit 2 to immediately ensure Floor Instructor: As U2 BOP flow path to 2B RN pump PER acknowledge.

Enclosure 6 (Unit 2 Actions). _________________________

CRS

• IF at least one DIG starts, THEN GO NOTE: The 1A DIG is running TO Step 7.d. but loads are NOT sequencing on.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 7&8 Page 38 of 46 Event

Description:

Loss of Off-Site Power/IA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. Expected ActionslBehavior Comments BOP . (Step 7.d).Check bus energized and NOTE: The Sequencer will sequencer applying loads. NOT be applying loads.

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

. Ensure normal and standby breakers open to allow auto loading of bus.

. IF bus not energized OR sequencer not applying loads, THEN GO TO Enclosure 4 (Manual Loading of Emergency Bus).

ECA-O.O, LOSS OF ALL AC POWER ENCLOSURE 4 - MANUAL LOADING OF EMERGNECY BUS BOP (Step 1) Reset S/I as follows:

. Ensure 1 minute has elapsed since initiation of S/I.

. Reset S/I.

BOP (Step 2) Check the following:

. 1AD/GRUNNING.

. I ETA Emergency Breaker CLOSED

- NOTE: The 1A D/G is running but the 1 ETA Emergency Breaker is OPEN.

CRS (Step 2.b RNO) GO TO Step 4.

ROt (Step 4) Hold RESET on IA sequencer NOTE: This task will require while completing Steps 5 through 7. both the RO and the BOP.

BOP RO? (Step 5) Unload 1 ETA emergency bus as follows:

BOP

. Open 1A CA pump breaker. NOTE: The 1A CA Pump is OOS.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 7&8 Page 39 of 46 Event

Description:

Loss of Off-Site PowerIlA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. Exnected ActionslBehavior Comments

. Open remaining pump breakers on 1ETA:

. 1A NV pump

. 1A ND pump

. 1A NI pump

. IAI KC pump

. 1A2 KC pump

. IA RN pump

. lAKE pump

. Check IA NS pump breaker OPEN.

. Open the following 600 V essential transformer feeder breakers:

. 1ELXA

. 1ELXE

. 1ELXC ROI (Step 6) Place IA DIG Mode Select switch to control room.

BOP ROI (Step 7) Close 1 ETA Emergency Breaker NOTE: I ETA is now energized.

BOP

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 7&8 Page 40 of 46 Event

Description:

Loss of Off-Site PowerIlA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. Expected Actions/Behavior Comments CRITICAL TASK:

(E-0 C) Energize at least one AC Emergency Bus before completing Step 7 of ECA 0.0.

Safety Significance: Failure to energize at least one AC Emergency Bus when conditions exist that allow the operator to do so, constitutes mis-operation or incorrect operator performance that unnecessarily prolongs a degraded AC Emergency Power condition, that under varying circumstances could lead to the direct challenge of fission product barriers. For instance, if the Emergency AC Power System is degraded longer than that required by plant circumstances, a single failure in the operation of the SSF, or delayed placement in service, could affect unnecessarily challenge the RCP Seals (NC System Barrier). Likewise, if the Emergency AC Power System is degraded longer than that required by plant circumstances, a single failure in the operation of the TDAFW Pump, or delayed placement in service, could affect unnecessarily challenge the Heat Sink and then the Core Cooling Critical Safety Functions (NC System Barrier).

RO! (Step 8) Release RESET on 1A sequencer.

BOP BOP (Step 9) Load I ETA emergency bus as follows:

. Close 1 ELXA feeder breaker

. Close 1ELXC feeder breaker NOTE: Control Room lights wWcome back on.

. Close IELXE feeder breaker

. CLOSE I RN-43A (Train B To Non Ess Hdr Isol).

. Ensure 1A RN pump suction and discharge_flowpath is available.

. Start 1A RN pump.

. Ensure the following valves are OPEN:

. 1RN-70A (A DIG Hx Inlet Isol) e 1 RN-73A (A DIG Outlet Isol)

. Start 1A NV pump.

Appendix D Operator Action Form ESD-2 Op Test No.: Nb-i Scenario # 3 Event # 7&8 Page 41 of 46 Event

Description:

Loss of Off-Site Power/IA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. Expected Actions/Behavior Comments BOP (Step 10) Observe the following limitations while placing loads on I ETA emergency bus in the next step:

. Continuous load on 1A DIG should not exceed 4000 KW.

. Voltage and frequency should be allowed to stabilize before applying the next load group.

BOP (Step 11) Continue loading I ETA emergency bus as follows:

. Ensure EVCA battery charger indicates ON.

. Ensure EVCC battery charger indicates ON.

. CLOSE I KC-338B (NC Pump Sup NOTE: 1 KC-338B has no Hdr Cont Outside Isol). power.

BOP (Step 11 .c RNO) Perform the following:

CLOSE the following valves:

. 1 KC-50A (Ten A Aux Bldg Non Ess Sup_Isol)

. 1 KC-230A (Tm A Rx Bldg Non Ess Si.ip_Isol)

Dispatch operator to CLOSE I KC-338B NOTE: The CRS will dispatch (auxbldg, 750+11, HH-52, lOft west of NED.

UHI blue valves). Booth InstructorlFloor Instructor acknowledge as appropriate.

Wait 2 minutes, Operate Trigger #13 (MALF-KCOO2F =

0, 30 second Ramp)

Report that I KC-338B is Closed.

WHEN I KC-338B is closed, THEN evaluate RE-OPENING any valve that was closed in Step I of this RNO. _________________________

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 3 Event # 7&8 Page 42 of 46 Event

Description:

Loss of Off-Site PowerIlA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. Expected ActionslBehavior Comments

• CLOSE I KC-425A (NC Pumps Ret Hdr Cont Outside Isol).

CRS

• Place info stickers next to 1 KC-425A NOTE: CRS may ask U2 RO and 1KC-338B switches stating: Do to make stickers.

not reopen due to steam voiding in If so Floor Instructor NCP thermal barriers acknowledge as U2 RO.

BOP

• Place IKC-51A (Train A Recirc Isol) in AUTO Start IA1 KC pump.

Start 1A2 KC pump

• Monitor KC surge tank levels for system leakage due to water hammers.

Start IA CA pump. NOTE: The IA CA Pump is 00s.

BOP (Step I 1.j RNO) IF CA pump breaker locked NOTE: The 1A CA Pump is out, THEN OOS.

. On OAC graphic for 1ETA bus, check 1 ELXC load center breaker to 1 EMXG CLOSED.

BOP (Step 12) Check the following:

• 1BD/G-RUNNING NOTE: The lB D/G is NOT running.

CRS (Step 12a RNO) Perform the following:

• IF at least one bus energized, THEN NOTE: The CRS will go back GO TO Step 7.e in body of this to the body of ECA-O.O.

procedure.

ECA-O.O, LOSS OF ALL AC POWER

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 7&8 Page 43 of 46 Event

Description:

Loss of Off-Site PowerIlA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. Expected ActionslBehavior Comments CRS . (Step 7.e.) Notify dispatched operators at NOTE: The CRS will direct the 1 EMXA-4 and SSF to stop where they two dispatched NEOs to cease are at. and desist assigned actions at the SSF.

Booth Instructor: If actions are delayed and the field actions have already been taken, RUN CAEP file ZZSDSSF.

. (Step 7.f) Check status of the following local actions:

• SSF DIG OFF NOTE: The SSF DIG may be ON.

CRS (Step 7.f.1 RNO) Perform the following:

. Have another operator perform NOTE: The CRS may ask an Enclosure 5 (Recovery from SSF NEO to perform Enclosure 5.

Actions) while continuing with If so, Floor Instructor this procedure. acknowledge as NEO.

CRS . GOTOStep7.h.

CRS . (Step 7.h) Implement EP/11N5000/F-O (Critical Safety Function Status Trees).

CRS . RETURN TO procedure and step in NOTE: The SRO will go to E effect. 0.

EPIIIAI5000IE-O, REACTOR TRIP OR SAFETY INJECTION RO/ (Step 1) Monitor Foldout page.

BOP RO (Step 2) Check Reactor Trip: Immediate Action

. All rod bottom lights LIT

. Reactor trip and bypass breakers OPEN

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 7&8 Page 44 of 46 Event

Description:

Loss of Off-Site Power/IA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Tim FnrfrI AefInnIRAhivirr Comments

. hR amps GOING DOWN.

RO (Step 3) Check Turbine Trip: Immediate Action

. All throttle valves CLOSED.

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

Immediate Action BOP (Step 4 RNO) Perform the following:

. If both busses de-energized, THEN NOTE: I ETA is energized.

GO TO EP/1/A/5000/ECA-O.O (Loss of ALL AC Power).

BOPI WHEN time allows, THEN try to CRS restore power to de-energized bus PER AP/1/A/5500/07 (Loss of Electrical Power) while continuing with this procedure.

RO/ (Step 5) Check if S/I is actuated: Immediate Action BOP

. SAFETY INJECTION ACTUATED status light (1SI-18) LIT. __________________________

(Step 5.a RNO) Perform the following:

. Check ifS/I is required:

. Pzr pressure less than 1845 PSIG OR

. Containment pressure greater than I PSIG

. If S/I is required THEN initiate S/I. __________________________

. IF S/I is not required THEN perform the following:

. Implement EP/1/N5000/F-O (Critical Safety Function Status Trees).

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 3 Event # 7& 8 Page 45 of 46 Event

Description:

Loss of Off-Site PowerIlA Sequencer fails to Start the DGI Main Turbine fails to Auto trip Time Pos. Expected ActionslBehavior Comments

. GO TO EP/1/A/5000/ES-O.1 NOTE: SI will NOT be (Reactor Trip Response). activated or required.

At the discretion of the Lead Examiner terminate the exam.

UNITISTATUS:

Power Level: 75% NCS [B] 1136 ppm Pzr [8]: 1145 ppm Xe: Per OAC Power History: The Plant is at 75% power (MOL), Core Burnup: 250 EFPDs for four days.

CONTROLLING PROCEDURE: 0P111N6100103 Controlling Procedure for Unit Operation OTHER INFORMATION NEEDED TO ASSUME TO SHIFT:

• The Plant is at 75% power (MOL), following a plant load decrease four days ago to this power level, due to unusually high vibrations on the 1 B NCP.

• The System Engineer has been monitoring the NCP, and vibration levels have stabilized out at normally expected levels.

• A power ascension to 100% power is expected for the shift.

• It is expected to raise power at 3 MWe/Minute.

• The RMWST Dissolved Oxygen Concentration is 800 ppb.

• Conditioned Power Level is 100%.

The following equipment is Out-Of-Service:

• 1A CA Pump is OOS.

• 1ASP-5121, AS Header Pressure, failed last shift (IAE is investigating).

• MCB Annunciator 1AD-7, J-4, BAT EMPTY, has failed to off (IAE is investigating).

Crew Directions:

• Raise power to 100% starting at Step 3.32.11 of Enclosure 4.1 of OP/1/A16100/03, Controlling Procedure for Unit Operation.

• Use of Alternate Dilute during power ascension in accordance with Enclosure 4.4, Alternate Dilute, of OP/i /A161 50/009, Boron Concentration Control, has been approved.

• The Reactor Group has recommended that a Dilution of 100 gallons be made during initial power increase.

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

Duke Energy Procedure No.

McGuire Nuclear Station OP/lIAI6loo/oo3 Controlling Procedure For Unit Operation Revision No.

163 Electronic Reference No.

MC00472R Continuous Use PERFORMANCE I This Procedure was printed on 07/08/10 at 08:23 :44 from the electronic library as:

(ISSUED) PDF Format -

Compare with Control Copy every 14 calendar days while work is being performed.

Compared with Control Copy Compared with Control Copy Compared with Control Copy Date(s) Performed Work Order/Task Number (WO#)

COMPLETION Q Yes Q NA Checklists and/or blanks initialed, signed, dated, or filled in NA, as appropriate?

D Yes L NA Required enclosures attached?

E1 Yes U NA Charts, graphs, data sheets, etc. attached, dated, identified, and marked?

U Yes U NA Calibrated Test Equipment, if used, checked out/in and referenced to this procedure?

Li Yes LI NA Procedure requirements met?

Verified By Date Procedure Completion Approved Date Remarks (attach additional pages, if necessary)

Printed Date: *07/08/2010*

IMPORTANT: Do NOT mark on barcodes.

Enclosure No.: *4 1

• i H IIHli i 1 1 iII Ull Hil Hil iIi Hil fil Ii ilH iiI l hI II iI Revision No.: *163*

iII l IU liii IH IiI Procedure No.: *OP/1/ftJ6l00/003$

I11 1 1 1 1 1 1 H HIl I I I I I I HHI 1 1 1 1 1 1 1 1 1 1 1 I I I 1 1 1 1111111 1 li i

Enclosure 4.1 OP/1/61oo/oo3 Power Increase Page 1 of 45

1. Limits and Precautions 1.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing NC System temperature and by changing neutron absorption in the reactor core. (R.M.)

1.2 Any inadvertent power reduction requires investigation and correction prior to continuing power increase.

NOTE: Limit and Precautions 1.3 and 1.4 are NOT applicable during performance of PTIO/A141 50/027 A (End of Cycle Moderator Temperature Coefficient Determination Boron / Dilution Method). (PIP 08-4252) 1.3 WHEN Turbine Generator paralleled to grid, maximum Tavg deviation from Tref is +/-4°F. (Assumption in the accident analysis in the UFSAR) 1.4 WHEN Turbine Generator paralleled to grid with Steam Dumps closed AND CRD Select in MANUAL, maximum Tavg deviation from Tref is +/-3°F.

1.5 WHEN transfelTing CRD Select from MANUAL to AUTO, Tavg maximum deviation from Tref is +/-1°F.

1.6 WHEN Reactor critical, minimum Tavg is 551 °F.

1.7 Maximum Power Mismatch is +/-2% for each Power Range channel (NIS vs BETP) during steady state power operations. (Should be calibrated within 4 hrs)

NOTE: The following recommended AFD targets are NOT applicable during initial cycle startup.

1.8 The following AFD targets are recommended by Nuclear Engineering:

• 1 % of target from 90 100% RTP with equilibrium xenon

• 2% of target from 90 100% RTP with transient xenon

• 2% of target from 50 90% RTP

• 5% of target from 20 50% RTP

• 10% of target below 20% RTP 1.9 Maximum Boron concentration difference between Pzr and NC System is 50 ppm.

Unit 1

Enclosure 4.1 A/61001003 IOPI 1

Power Increase Page 2 of 45 1.10 IF in Mode 3 and SDM is outside required limit, TS 3.1.1 requires boration within 15 minutes to restore SDM.

1.11 Maximum S/G tube leakage from any S/G is 100 gpd.

1.12 IF both Rod Position Indicator systems (DRPI and OAC) become inoperable during Mode 3, Tech Specs require tripping the Reactor..

1.13 Minimum individual S/G outlet pressure is 870 psig to prevent flow induced vibration of S/G tubes. fMDUK-1242.01-0001.001 (Temperature and Power Limits for Operation As Controlled by Pressure Boundary Structural Analysis and Safety Analysis)}

1.14 The following apply to Fuel Maneuvering Limits:

• Fuel Maneuvering Limits apply to power increase and NOT power decrease

• Fuel Maneuvering Limits are based on Reactor Power and NOT Generator Load

• The Reactor Group shall be contacted for any questions that arise concerning Fuel Maneuvering Limits 1.15 Control Rod withdrawal rate is limited by Fuel Maneurvering Limits (Data Book Section 1.3). The rod withdrawal rate for unconditioned fuel above 50% power is limited to 3 steps/hour. Fuel is considered conditioned with respect to rod position once the control rods have been withdrawn to a given position at a given power level.

1.16 During power changes, the following alternate indications for Reactor Power are available:

• Thermal Power Best Estimate (TPBE)

• Tavg, Tcold, NC Loop Delta-T

• Intermediate Range Channels

• Turbine Impulse Pressure, Megawatt output

• CF flowrate Unit 1

Enclosure 4.1 oP/1/A/6loo/oo3 Power Increase Page 3 of 45 NOTE: This enclosure will affect reactivity of the core and is therefore designated important to Reactivity Management per the guidelines of NSD 703 (Reactivity Management) (R.M.)

2. Initial Conditions 2.1 Mode 3 with NC System at 557°F and 2235 psig in anticipation of Reactor Startup OR 2.2 Mode 2 2.3 Mode 1 in anticipation of power increase

3. Procedure NOTE: initial power escalation for a fuel cycle, this procedure will be performed in parallel with Nuclear Engineering procedure PT/OIA/41501021 (Post Refueling Controlling Procedure for Criticality, Zero Power Physics and Power Escalation Testing).

3.1 Evaluate all outstanding R&Rs that may impact performance of this procedure.

3.2 Evaluate OP/1/A/6100/SU-19 (Heatup to 557 Degrees F), Enclosure 4.4 (Pre-Startup SRO System Alignments) to determine if additional actions may need to be performed.

3.3 IF plant conditions require entering this procedure at some point other than the SRO beginning, perform the following:

[13.3.1 Determine entry step based upon plant conditions.

/

R( 3.3.2 Record entry step: . .3c. I

[13.3.3 Evaluate all steps prior to that recorded in Step 3.3.2 for additional actions that need to be performed.

3.4 iF Zero Power Physics Testing will be performed, maintain the following:

El NC System pressure within +/- 20 psig of 2235 psig El NC System Tavg within +/- 1.0°F of 557°F by throttling S/G blowdown 3.5 WHEN NC System temperature has been 557°F for at least 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, configure Loose Parts Monitoring System for at power monitoring per OP/1/B/6150/016 (Loose Parts Monitoring System).

Unit 1

Enclosure 4.1 OPI1IAI6100IOO3 Power Increase Page 4 of 45 EJ 3.6 Maintain proper NC System parameters by operating Pzr Htr Groups as required per Enclosure 4.6 (Operation of Pzr Heaters).

3.7 On DCS Workstation Feedpump Overview graphic, ensure operating CF Pump Turbine in auto.

3.8 Ensure the following S/G CF Cntrl Bypass Valves in auto:

• 1CF-.1O4AB (1A SIG CF Control Bypass)

• 1CF-1O5AB (lB S/G CF Control Bypass)

• 1CF-1O6AB (1C SIG CF Control Bypass)

• 1CF-1O7AB (1D SIG CF Control Bypass) 3.9 Defeat Hi Flux at Shutdown alarms as follows:

3.9.1 Place Hi Flux At Shutdown for Channel N31 to BLOCK. (SR drawer) 3.9.2 Place Hi Flux At Shutdown for Channel N32 to BLOCK. (SR drawer)

LI 3.9.3 Check 1AD-2, D2 (SIR High Flux Aim Blocked) lit.

3.9.4 Place Shutdown Monitor A Annun Bypass to BYPASS.

3.9.5 Place Shutdown Monitor B Annun Bypass to BYPASS.

3.10 Within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> prior to achieving criticality, perform the following to check SDM:

NOTE: j the REACT program says Reactivity Summation is negative! Please perform an ECB. This means that with all rods out the reactor is NOT predicted to go critical.

El 3.10.1 Check Estimated Critical Rod Position is above COLR insertion limit per OP/0/A/6100/006 (Reactivity Balance Calculation).

LI 3.10.2 Check all control rods operable.

El 3.10.3 Record in PT/1/A14600/008 (Surveillance Requirements for Unit Heatup).

Unit 1

Enclosure 4.1 oP/1/A/6loo/oo3 Power In crease Page 5 of 45 3.11 j TV/GV hot calibration was started in OP/1/A/6100/SU-19 (Heatup to 557 Degrees F)

AND has NOT been completed, perform the following:

3.11.1 Notify IAF to stop/suspend TV/GV hot calibration.

Person Notified Date Time 3.11.2 HOLD until confirmed that IAE is NOT performing TV/GV hot calibration.

IAE 3.12 Ensure a Reactor startup 9 1-01 briefing has been performed:

SRO Management Designee:

Evolution Coordinator:

Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power In crease Page 6 of 45 3.13 Begin Reactor startup to critical as follows:

NOTE:

• Minimum 1 decade overlap required between SR and IR.

• Minimum 1 decade overlap required between JR and PR.

• IF positive reactivity addition occurs, Mode 2 can be achieved with all control rods inserted.

• Tech Specs define Mode 2. (Mode 2 may be declared when Control Banks are initially withdrawn from fully inserted position).

3.13.1 IF Reactor startup being performed by control rod withdrawal, complete SRO RO Enclosure 4.3 (Guidelines For Approaching Criticality Via Control Rod Withdrawal) before control bank withdrawal.

U 3.13.2 Announce over page, Commencing Unit 1 Reactor Startup.

LI 3.13.3 Using Plant Mode Change & Alarm Look Ahead, change OAC to Mode 2.

3.13.4 On the DCS Work Station, change the DCS Modal Alarming to MODE 2 as follows:

U 3.13.4.1 Access DCS PLANT MODE SELECTION Screen (6012).

U 3.13.4.2 Select MODE 2.

LI 3.13.4.3 Select ACCEPT MODE.

LI 3.13.4.4 Check MODE 2 is displayed in CURRENT PLANT MODE.

3.13.5 Notify SRO and RO to continuously monitor the following to determine when SRO RO the Reactor is supercritical:

• Constant positive SUR without control rod movement or NC System dilution

• Log Power increasing linearly without control rod movement or NC System dilution Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power In crease Page 7 of 45 3.13.6 Initiate 1IM plot per one of the following:

U Nuclear Engineering procedure guidance on initial startup for fuel cycle OR U PTIOIAJ415O/047 (1IM Monitoring During Startup) 3.13.7 WhEN control rods are being withdrawn, perform Table 4.1-1 (Control Rod Bank Parameters).

3.13.8 Select HI on Nuclear Power (%) recorder. (1ENBCR945O) 3.13.9 Withdraw control banks per one of the following:

3.13.9.1 IF initial startup for fuel cycle, withdraw control rods per Nuclear Engineering procedure guidance.

OR 3.13.9.2 Perform the following:

A. Place CRD Bank Select in MANUAL.

U B. Withdraw control banks in 50 60 step increments.

U C. Wait until SR counts stabilize. (1 minute)

U D. Repeat Steps B - C until Reactor is critical.

3.13.10 IF IR Compensating Voltage was adjusted to -4OVDC due to improper compensation 2j IR Detector Replacement, evaluate JR Compensating Voltage adjustments.

Unit 1

Enclosure 4.1 1A161001003 1

0P1 Power Increase Page 8 of 45 Table 4.1-1. Control Rod Bank Parameters Record Bank and step position at each stop point.

Initial box after checking each parameter.

Bank:

Step:

Parameter:

WHEN below ECP lower limit window, a rapid decrease in SUR.

Proper count rate, SUR and recorder response.

Proper Bank Overlap between Control Banks per Unit 1 Data Book, Enc 4.3, Sect 1.13 DRPI vs bank demand counters acceptable.

l/M plot acceptable.

Tavg> 551°F Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power Increase Page 9 of 45 3.13.11 WHEN Reactor critical, begin increasing JR power to 1 x 108 Amps.

LI 3.13.12 Check at least one decade overlap between SR and JR instrumentation.

3.13.13 WHEN greater than 1 x 10° Amps, perform the following:

LI 3.13.13.1 Check lit P-6 S/R Block Permissive. (1SI-18) 3.13.13.2 Place both Source Range Select to BLOCK.

3.13.13.3 Check lit on 1SI-18:

LI SR Train A Trip Blkd Hi Voltage Off LI SR Train B Trip Blkd Hi Voltage Off 3.13.13.4 Select both IR channels on Nuclear Power (%) recorder.

(1 ENB CR9450)

LI 3.13.14 Maintain Reactor Power at 1 x 108 Amps.

LI 3.13.15 Record the following:

• Rod Position Bank

• Tavg

• Boron Concentration

• Time

• Xenon worth (OAC)

• Samarium difference from equilibrium pcm (OAC)

LI 3.13.16 Record above parameters in Auto log.

3.13.17 Select LO on Nuclear Power (%) recorder. (1ENBCR945O) 3.13.18 IF initial power escalation for a fuel cycle:

3.13.18.1 Perform Zero Power Physics Test as advised by Nuclear Engineering procedure PTIO/A141 50/02 1 (Post Refueling Controlling Procedure for Criticality, Zero Power Physics and Power Escalation Testing).

3.13.18.2 HOLD until Nuclear Engineering testing complete.

/

Person Notified Date Time 3.13.19 Ensure one PR channel selected on Nuclear Power (%) recorder.

(1ENBCR945O)

Unit 1

Enclosure 4.1 OP/i /A/6100/003 Power Increase Page 10 of 45 3.14 Begin performance of Enclosure 4.8 (Guidelines For Power Increase).

SRO 3.15 Perform the following to control NC System temperature until Turbine Generator is paralleled to the grid:

NOTE: Steps 3.15.1 - 3.15.2 should be performed concurrently.

3.15.1 Maintain the following by adjusting setpoint on STM PRESS CONTROLLER:

LI Tcold 557 559°F Li SM Pressure 1060 1110 psig NOTE:

• While maintaining Tcold at 557 559°F using Steam Dumps, Table 4.1-2 should be used to approximate Tavg for a given Reactor Power level.

• Increasing Reactor Power while Turbine Power remains constant will result in Tavg exceeding Program Tref (557°F). (Turbine Impulse Pressure Channels will NOT increase until Turbine Generator is paralleled to the grid.)

LI 3.15.2 Refer to Table 4.1-2 (Reactor Power / Expected Tavg) for expected Tavg for a given Reactor Power level:

Table 4.1-2 Reactor Power / Expected Tavg r Reactor Power (%)

15 Expected Tavg (°F) 561.215 14 560.934 13 560.653 12 560.372 11 560.091 10 559.810 9 559.529 8 559.248 7 558.967 6 558.686 5 558.405 4 558.124 3 557.843 2 557.562 1 557.281 0 557.000 Unit 1

Enclosure 4.1 OP/l/A/61001003 Power Increase Page 11 of 45 3.16 IF feedwater flow is aligned to CA nozzles, perform the following:

NOTE: Thermal Power Best Estimate calculations during low power conditions use a weighted (double counted) value for CA Nozzle flow. This results in conservative indication of TPBE. To prevent this, feedwater flow should be swapped to CF Nozzles prior to 20% RTP. (PiP 03-5427) 3.16.1 Ensure Reactor Power will remain less than 20% RTP.

El 3.16.2 Evaluate swapping to CF nozzles per OP/11A162501001 (Condensate and Feedwater System) 3.17 Ensure in service CF Pump Turbine LP GOV CNTRL and HP GOV CNTRL in auto.

NOTE: Due to inherent design of BWI S/Gs, S/G WR level will decrease as Reactor Power is increased through 3% RTP.

3.18 IF AT ANY TIME S/G N/R Level decreases to 28% OR exceeds 52%, perform the following:

3.18.1 IF individual S/G level control problem, perform the following:

3.18.1.1 Place affected S/G CF Control Bypass andlor CF Control Valve in manual.

3.18.1.2 Adjust affected S/G CF Control Bypass or CF Control Valve as required to return affected S/G N/R level to setpoint.

3.18.1.3 Place affected S/G CF Control Bypass andlor CF Control Valve in auto.

3.18.2 all S/Gs indicate level control problems, perform the following:

3.18.2.1 Place operating CF Pump Turbine LP GOV CNTRL and HP GOV CNTRL in manual.

3.18.2.2 Use CF Pump Turbine LP GOV CNTRL increase/decrease pushbuttons to restore associated S/G NR levels to normal.

3.18.2.3 WHEN S/G NR levels normal, place operating CF Pump Turbine HP GOV CNTRL in auto.

3.18.2.4 WHEN in service CF Pump Turbine speed within 50 100 rpm-of AUTO SPY on DCS Feedpump Overview graphic, place LP GOV CNTRL in auto.

Unit 1

Enclosure 4.1 OP/11A16 100/003 Power Increase Page 12 of 45 LI 3.19 Increase Reactor Power to 2% RTP (2.0 2.5%).

3.20 HOLD at 2% RTP (2.0 2.5%) for a minimum of 10 minutes.

3.21 Increase Rx Power to 4% RTP (3.5 4.0%) as follows:

3.21.1 WHEN greater than 3% RTP, perform the following:

3.21.1.1 Open:

• 1SM-83 (A SM Line Drain)

• 1SM-89 (B SM Line Drain)

• 1SM-95 (C SM Line Drain)

• 1SM-lOl (D SM Line Drain)

NOTE: IF the Turbine is placed in manual in the following step, lAD-i, F4 (Turbine in Manual) will alarm. This is an expected alarm.

3.21.1.2 Ensure Turbine in MANUAL.

3.21.1.3 Close Governor Valves using GV Lower.

NOTE: Mode 1 is entered at 5% RTP.

3.22 WHEN at 4% RTP, perform the following:

3.22.1 HOLD at 4% RTP (3.5 4.0%) for a minimum of 10 minutes.

LI 3.22.2 Using Plant Mode Change & Alarm Look Ahead, change the OAC to Mode 1.

3.22.3 On the DCS Work Station, change the DCS Modal Alarming to Mode 1 as follows:

LI 3.22.3.1 Access DCS PLANT MODE SELECTION Screen (6012).

LI 3.22.3.2 Select MODE 1.

LI 3.22.3.3 Select ACCEPT MODE.

LI 3.22.3.4 Check MODE 1 is displayed in CURRENT PLANT MODE.

Unit 1

Enclosure 4.1 QP/l/A,61001003 Power In crease Page 13 of 45 El 3.23 Increase Reactor Power to 6% RTP (6.0 6.5%).

3.24 HOLD at 6% RTP (6.0 6.5%) for a minimum of 10 minutes.

3.25 WifEN any SI0 CF Control Bypass Valve indicates between 50 60% open, place the associated Sf0 CF Cntrl Valve in service as follows:

3.25.1 Ensure the following Sf0 CF Control Bypass valves in auto:

• ICF-1O4AB (1A Sf0 CF Control Bypass)

• 1CF-1O5AB (lB S/G CF Control Bypass)

• 1CF-1O6AB (1C S/G CF Control Bypass)

• ICF-1O7AB (1D S/G CF Control Bypass) 3.25.2 Place S/G CF Control Valves in service as follows:

NOTE:

• Placing Sf0 CF Cntrl Vlvs in auto should be performed in a controlled manner, one S/G at a time.

• Allow CF flow and S/G water level to stabilize one S/G at a time.

• S/G CF Control Bypass Valves are expected to modulate when the SIG CF Cntrl Valves are placed in service.

• S/G CF Cntrl Valves can be placed in service in any order.

CAUTION: A greater than 65% demand on the S/G CF Control Bypass Valve sends a 5%

minimum open demand signal to the associated Sf0 CF.Control Valve. The CF Bypass Valve has to close to less than 35% to clear the demand signal to the S/G CF Control Valve.

3.25.3 For A S/G, perform the following:

3.25.3.1 Ensure 1CF-32AB (1A SfG CF Control) in manual and closed.

3.25.3.2 Open the following:

• 1 CF-3 1 (A S/C CF Cntrl Inlet Isol)

• 1CF-33 (A Sf0 CF Cntrl Outlet Isol)

El 3.25.3.3 Check 1CF-1O4AB (1A S/0 CF Control Bypass) output less than 65%.

3.25.3.4 Place ICF-32AB (1A Sf0 CF Control) in auto.

Unit 1

Enclosure 4.1 1 OP 1 A161001003 /

Power Increase Page 14 of 45 3.25.4 For B S/G, perform the following:

3.25.4.1 Ensure ICF-23AB (lB S/G CF Control) in manual and closed.

3.25.4.2 Open the following:

• 1CF-22 (B SIG CF Cntrl Inlet Isol)

• 1 CF-24 (B S/G CF Cntrl Outlet Isol)

LI 3.25.4.3 Check 1CF-1O5AB (lB S/G CF Control Bypass) output less than 65%.

3.25.4.4 Place 1CF-23AB (lB S/G CF Control) in auto.

3.25.5 For C SIG, perform the following:

3.25.5.1 Ensure 1CF-2OAB (1C SIG CF Control) in manual and closed.

3.25.5.2 Open the following:

• 1 CF- 19 (C S/G CF Cntrl Inlet Isol)

• ICF-21 (C S/G CF Cntrl Outlet Isol)

El 3.25.5.3 Check 1CF-1O6AB (1C SIG CF Control Bypass) output less than 65%.

3.25.5.4 Place 1CF-2OAB (1C S/G CF Control) in auto.

3.25.6 For D SIG, perform the following:

3.25.6.1 Ensure 1CF-17AB (1D SIG CF Control) in manual and closed.

3.25.6.2 Open the following:

• 1 CF- 16 (D SIG CF Cntrl Inlet Isol)

• ICF-18 (D S/G CF Cntrl Outlet Isol El 3.25.6.3 Check 1CF-1O7AB (ID S/G CF Control Bypass) output less than 65%.

3.25.6.4 Place 1CF-17AB (1D S/G CF Control) in auto.

Unit 1

Enclosure 4.1 oPIlIAJ6loo/oo3 Power In crease Page 15 of 45 11 3.26 Increase Rx Power to 8% RTP(8.0 8.5%). -

3.27 WHEN at 8% RTP (8.0 8.5%), perform the following:

3.27.1 HOLD at 8% RTP (8.0 8.5%) for a minimum of 10 minutes.

3.27.2 Notify Secondary Chemistry to verify secondary water chemistry acceptable for operation greater than 15% RTP.

Person Notified Date Time LTh 3.27.3 Place BB Pump in service per OP/1/A/6250/008 (Steam Generator B lowdown).

3.27.4 IF required for S/G cleanup, adjust the following while maintaining NC System temperature:

• 1BB-123 (A SIG BB Flow Control)

• 1BB-124 (B SIG BB Flow Control)

• 1BB-125 (C SIG BB Flow Control)

• IBB-126 (D S/G BB Flow Control)

Unit 1

Enclosure 4.1 OPI1/A161001003 Power Increase Page 16 of 45 3.28 Increase Reactor Power to 10 - 12% RTP as follows:

LI 3.28.1 Begin power increase to 10 - 12% RTP.

3.28.2 WHEN Reactor Power reaches 10% RTP, perform the following:

3.28.2.1 Check on 1SI-18:

LI P-lU Nuclear at Power lit LI P-7 Lo Power Reactor Trips Blocked dark 3.28.2.2 Block the JR high level trip and rod stop by depressing both Intermediate Range Block pushbuttons.

3.28.2.3 Check lit on 1SI-18:

LI hR Train A Trip Blocked LI I/R Train B Trip Blocked 3.28 .2.4 Block PR low setpoint trip by depressing both Power Range Block pushbuttons.

3.28.2.5 Check lit on 1SI-18:

LI P/R Lo Setpoint Train A Trip Blocked LI P/R Lo Setpoint Train B Trip Blocked 3.28.3 IF required for IAE to tune Process Control Systems, perform the following:

3.28.3.1 HOLD at 10- 12% RTP.

LI 3.28.3.2 Allow IAE to gather data on Process Control Systems.

3.28.3.3 WHEN LAE data gathering and tuning complete, continue power increase.

3.29 Increase Reactor Power to 12 - 18% RTP as follows:

LI 3.29.1 Begin power increase to 12 - 15% RTP.

3.29.2 HOLD until Reactor Power is 12 - 15% RTP.

3.29.3 Ensure proper secondary water chemistry for operation greater than 15% RTP.

CHEM LI 3.29.4 Begin power increase to 18% RTP.

LI 3.29.5 Maintain 12 - 18% RTP.

Unit 1

Enclosure 4.1 QP/1/A/6100/003 Power Increase Page 17 of 45 NOTE: TV/GV hot calibration was NOT started in OP/1/A/6100/SU-19 (Heatup to 557 Degrees F), the following step restores LH to Throttle Valves.

3.29.6 IF TV/GV hot calibration NOT complete, notify IAE to beginlresume performing TV/GV hot calibration.

Person Notified Date Time LI 3.29.7 Reset Main Turbine per OP/1/A/6300/001 (Turbine Generator Startup/Shutdown).

_NOTE: Steps 3.29.8 - 3.29.10 may be performed in any order or concuently.

3.29.8 Calibrate Power Range NIS channels to maintain Power Mismatch (NIs vs IAE BETP) +/-1% for each Power Range channel.

3.29.9 IF required for IAE to tune Process Control Systems, HOLD at 12 - 18%

RTP until IAE gathers data on Process Control Systems.

LI 3.29.10 Roll Main Turbine to 1800 rpm per OP/11A16300/O0 1 (Turbine Generator Startup/Shutdown).

NOTE: Engineering will determine if PT/1/A/42501004 C (Turbine OPC and Mechanical Overspeed Trip Test) is to be performed with Turbine Generator at 1800 rpm or at greater than 112 MWE.

3.29.11 Notify Engineering to determine if and when PT/1/A/4250/004 C (Turbine OPC and Mechanical Overspeed Trip Test) will be performed.

Person Notified Date Time Unit 1

Enclosure 4.1 A16100/003

/OPI 1

Power Increase Page 18 of 45 3.29.12 PTI1/A142501004 C (Turbine OPC and Mechanical Overspeed Trip Test) will be performed with Turbine Generator at 1800 rpm, complete the following:

[1 3.29.12.1 Maintain 12 - 18% RTP.

El 3.29.12.2 Perform PT/1/A14250/004 C (Turbine OPC and Mechanical Overspeed Trip Test).

3.29.12.3 WhEN PT/1/A14250/004 C (Turbine OPC and Mechanical Overspeed Trip Test) complete, perform TV/GV Transfer and place Voltage Regulator in service per OP/1/A/6300/001 (Turbine Generator Startup/Shutdown).

3.29.13 j performing Generator / Automatic Voltage Regulator (AVR) testing, complete the following:

3.29.13.1 IF performed, HOLD until Step 3.29.12 complete.

3.29.13.2 Ensure TV/GV Transfer complete and Voltage Regulator placed in service per OP/1/A16300/001 (Turbine Generator Startup/Shutdown).

3.29.13.3 HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.29.14 jj required to perform Main Generator Flux Mapping, notity Maintenance Main Generator Team to perform mapping.

Person Notified Date Time 3.29.15 HOLD until Step 3.29.13 complete.

3.29.16 Ensure TV/GV Transfer complete and Voltage Regulator placed in service per OP/1/A/6300/00 1 (Turbine Generator Startup/Shutdown).

LI 3.29.17 Close Generator MODs per OP/l/A/6300/OOl (Turbine Generator Startup/Shutdown).

0 3.29.18 Synchronize Generator and load Generator to 120 MWE per OP/I /A/6300/00 I (Turbine Generator Startup/Shutdown).

Unit 1

Enclosure 4.1 1 0P 1 A161001003 1 Power In crease Page 19 of 45 3.29.19 WHEN Main Generator Breakers closed, record the following values and notify System Engineer:

LI 1A Main Generator Breaker Air Compressor Pilot Valve Counter LI lB Main Generator Breaker Air Compressor Pilot Valve Counter LI Date/Time 1A Main Generator Breaker Closed /

LI Date/Time lB Main Generator Breaker Closed /

Person Notified Date Time 3.29 .20 IF performing Generator I Automatic Voltage Regulator (AVR) testing on line at 15% RTP, HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power Increase Page 20 of 45 NOTE:

• IF Turbine Generator holds for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> at 112 MWE for PT/l/A142501004 C (Turbine OPC and Mechanical Overspeed Trip Test), Reactor Core Flux Mapping may be performed during the hold.

• IF Turbine Generator holds for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> at 112 MWE for PT/1/A14250/004 C (Turbine OPC and Mechanical Overspeed Trip Test), Generator / Automatic Voltage Regulator (AVR) testing may be performed during the hold.

3.29.21 PT/11AJ42501004 C (Turbine OPC and Mechanical Overspeed Trip Test) to be performed following load increase to greater than 112 MWe, perform the following:

LI 3.29.21.1 Maintainl2-18%RTP.

3.29.21.2 jj performing Generator / Automatic Voltage Regulator (AVR) testing, HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.29.21.3 required to perform 15% RTP Reactor Core Flux Mapping during 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> hold at greater than 112 MWE, perform flux mapping.

3.29.21.4 IF required to perform Main Generator Flux Mapping, notity Maintenance Main Generator Team to perform mapping.

Person Notified Date Time 3.29.21.5 HOLD until Steps 3.29.21.2 and 3.29.21.3 complete.

LI 3.29.21.6 Shutdown Generator per OP/1/A/6300/001 (Turbine Generator Startup/Shutdown).

LI 3.29.21.7 Perform PT/1/A/4250/004 C (Turbine OPC and Mechanical Overspeed Trip Test).

LI 3.29.21.8 Startup Turbine and parallel Generator per OP/i /A/6300/00 1 (Turbine Generator Startup/Shutdown).

Unit 1

Enclosure 4.1 QP/1/A/6100/003 Power Increase Page 21 of 45 3.29.22 WhEN steam dumps close, perform the following:

3.29.22.1 C-7A Loss of Load Intik Cond Dump on 1SI-18 lit, perform the following:

A. Momentarily place Steam Dump Select to C-7A Reset.

Li B. Check C-7A Loss of Load Intik Cond Dump dark.

3.29.22.2 Place Steam Dump Select to T-AVG.

3.29.22.3 Place STM PRESS CONTROLLER to auto.

3.29.22.4 Set STM PRESS CONTROLLER setpoint at 1092 psig (1090 1095).

3.29.23 Perform the following:

3.29.23.1 Monitor the following while opening isp-i (SM to CF Pump 1A Isol) and 1SP-2 (SM to CF Pump lB Iso!): (PIP 09-6340)

Li M1A0723 (Ui H/P Steam to 1A CFPT Press)

LI M1A0729 (Ui HIP Steam to lB CFPT Press)

NOTE: iSP-i (SM to CF Pump 1A Isol) and 1SP-2 (SM to CF Pump lB Iso!) are physically located such that verifying the position is difficult. { PIP 09-6340 3.29.23.2 Open:

• isp-i (SM to CF Pump 1A Isol) cv

• 1SP-2 (SM to CF Pump lB Isol) cv 3.29.23.3 Check the following for corresponding increase in steam pressure with iSP- 1 (SM to CF Pump 1 A Isol) and 1 SP-2 (SM to CF Pump lB Isol) open: (PIP 09-6340)

LI M1A0723 (Ui H/P Steam to 1A CFPT Press)

LI M1A0729 (Ui HIP Steam to lB CFPT Press)

LI 3.29.24 Check operating CF Pump greater than 3600 rpm and in auto per OP/i/A/6250/001 (Condensate and Feedwater System).

Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power Increase Page 22 of 45 3.29.25 jj 15% RTP Reactor Core Flux Map performed, notify Nuclear Engineering to perform the following:

U 3.29.25.1 Evaluate flux mapping data.

U 3.29.25.2 Determine allowed power increase.

U 3.29.25.3 Record limiting power level per Nuclear Engineering procedure:

%RTP

/

Person Notified Date Time 3.29.26 Ensure TV/GV hot calibrations complete (Step 3.29.6).

IAE 3.29.27 HOLD at 12 - 18% RTP until Step 3.29.25 completed.

3.29.28 Complete Enclosure 4.8 (Guidelines For Power Increase).

SRO Unit 1

Enclosure 4.1 OPI1/A161001003 Power Increase Page 23 of 45 3.30 Increase Reactor Power to 30% RTP as follows:

3.30.1 Notify IAE to stand by for periodic adjustments of Power Range NI channels.

Person Notified Date Time 3.30.2 IF AT ANY TIME Power Mismatch % (Excore/Thermal Power Mismatch) indicates greater than 4% during power increase, perform the following:

LI 3.30.2.1 Stop power increase.

3.30.2.2 Have IAE calibrate each Power Range NI Channel to +/-1% Power Mismatch (NIs vs BETP).

3.30.2.3 WHEN calibration complete, continue with power increase.

LI 3.30.3 Begin power increase to 30% RTP.

El 3.30.4 Load turbine per OP/1/A/6300/001 A (Turbine-Generator Load Change).

NOTE: IF OAC out of service, monitoring IA and lB XFMR Oil Temps may be performed at local gauges.

3.30.5 WHEN M1A0913 (1A XFMR Oil Temp) indicates greater than 45°C, ensure cooling groups energized on 1 A Main Transformer:

• Circuit 1

• Circuit 2

• Circuit 3

• Circuit 4

• Circuit 5

• Circuit 6

• Circuit 7

• Circuit 8 Unit 1

Enclosure 4.1 OPI1/A/6100/003 Power In crease Page 24 of 45 3.30.6 WHEN M1A0925 (lB XFMR Oil Temp) indicates greater than 45°C, ensure cooling groups energized on 1 B Main Transformer:

• Circuit 1

• Circuit 2

• Circuit 3

• Circuit 4

• Circuit 5

• Circuit 6

• Circuit 7

• Circuit 8 3.30.7 Place Exh Hood Spray in MAN.

3.30.8 WHEN C-5 Lo Turb Impulse Press Rod Block dark, CRD Bank Select may be placed in AUTO.

3.30.9 WHEN Turbine Imp Press greater than 75 psig, check P-13 Turbine Not At Power dark. (1SI-18) 3.30.10 Prior to 20% RTP, ensure Main Feedwater flow to all S/Gs through CF nozzles per OP/l/A/6250/00l (Condensate and Feedwater System).

Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power In crease Page 25 of 45 NOTE:

• At approximately 18% CF flow, each SIG will transition from LOW POWER mode to HIGH POWER mode.

• SIG HIGH POWER mode includes validated steam flow, validated feedwater flow, validated N/R level, and NIR level setpoint to calculate the feedwater flow demand for that S/G.

• CF Flow, in percent flow, is indicated on DCS Feedwater Overview Graphic for all four S/Gs.

3.30.11 AFTER exceeding 18% CF flow, check each SIG in HIGH POWER mode as follows:

0 3.30.11.1 On DCS Workstation, select Steam Generator A Level graphic 1 3.30.11.2 On Steam Generator A Level graphic, check HIGH POWER lit.

0 3.30.11.3 On DCS Workstation, select Steam Generator B Level graphic El 3.30.11.4 On Steam Generator B Level graphic, check HIGH POWER lit.

0 3.30.11.5 On DCS Workstation, select Steam Generator C Level graphic 0 3.30.11.6 On Steam Generator C Level graphic, check HIGH POWER lit.

El 3.30.11.7 On DCS Workstation, select Steam Generator D Level graphic EJ 3.30.11.8 On Steam Generator D Level graphic, check HIGH POWER lit.

3.30.12 Ensure BB Pump in service per OP/1/A/6250/008 (Steam Generator B lowdown).

3.30.13 Initiate maximum BB flow for S/G cleanup while maintaining NC System temperature by throttling the following:

• 1BB-123 (A S/G BB Flow Control)

• 1BB-124 (B S/G BB Flow Control)

• 1BB-125 (C S/G BB Flow Control)

• 1BB-126 (D S/G BB Flow Control)

El 3.30.14 Adjust letdown to desired flow per OP/1/A16200/001 A (Chemical and Volume Control System Letdown).

Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power Increase Page 26 of 45 CAUTION: IF lAS-li (SM to AS Header Control) is to supply AS Header, anticipate an increase in Reactor Power or a decrease in NC System temperature when opening 1AS-12 (SM to AS).

3.30.15 Align AS as follows:

3.30.15.1 Slowly open 1AS-12 (Main Steam to Aux Steam).

3.30.15.2 Open 1AS-9 (C Htr Bleed to Aux Steam).

3.30.15.3 jj Aux Electric Boilers no longer required, perform following:

A. Close 1AS-120 (Aux Elec Bir A & B to AS Isol).

LI B. Shutdown Aux Electric Boilers per OP/i/B16250/007 B (Auxiliary Electric Boiler).

_NOTE: Steam Seal Supply should remain on AS for improved efficiency.

3.30.16 conditions require, transfer Steam Seal Supply to SM as follows:

3.30.16.1 Slowly open 1TL-3 (SM to Steam Seal Isol).

3.30.16.2 Close 1TL-21 (AS to Steam Seal Iso!).

3.30.17 WhEN Turbine impulse pressure is greater than 200 psig:

3.30.17.1 Ensure Turb Drn Vlvs Cntrl in AUTO.

El 3.30.17.2 Check all turbine drain valves closed.

3.30.18 Ensure second Hotwell Pump operating.

3.30.19 Ensure standby Hotwell Pump in AUTO.

3.30.20 Ensure second CM Booster Pump operating.

3.30.2 1 Ensure standby CM Booster Pump in AUTO.

LI 3.30.22 Close valves per OP/l/B/6250/004 (Feedwater Heater Vents, Drains and Bleed System), Enclosure 4.4 (Startup Vent Valve Checklist).

Unit 1

Enclosure 4.1 oPIl/AI6looIoo3 Power In crease Page 27 of 45 NOTE:

• At approximately 30% steam flow, all SIG CF Bypass Valves will go closed and S/G level will be controlled by S/G CF Valves and CF Pump Turbine speed demand.

SM Flow, in percent flow, is indicated on DCS Feedwater Overview Graphic for all four S/Gs.

3.30.23 At greater than 30% steam flow from each S/G, check the following valves in auto and closed:

LI 1CF1O4AB (1A S/G CF Contrl Bypass)

LI 1CF-1O5AB (lB S/G CF Contri Bypass)

LI 1CF-1O6AB (1C S/G CF Contrl Bypass)

LI 1CF-IO7AB (1D SIG CF Contrl Bypass)

LI 3.30.24 Check S/G levels stable and at program for current power level.

3.30.25 HOLD at 30% RTP and concurrently perform the following:

3.30.25.1 required to tune Process Control Systems, perform the IAE following:

A. HOLDat3O%RTP LI B. Allow IAE to gather data on Process Control Systems.

3.30.25.2 IF performing Generator / Automatic Voltage Regulator (AVR) testing at 30% RTP, HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.30.25.3 30% RTP Reactor Core Flux Map to be performed, notify Nuclear Engineering to perform the following:

LI A. Perform flux mapping.

LI B. Evaluate flux mapping data.

LI C. Determine allowed power increase.

LI D. Record limiting power level per Nuclear Engineering procedure:  % RTP Person Notified Date Time Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power Increase Page 28 of 45 3.31 Increase power to 50% RTP as follows:

3.31.1 Notify Secondary Chemistry to verify secondary water chemistry acceptable for operation greater than 50% RTP Person Notified Date Time El 3.31.2 Maintain control rods within insertion and withdrawal limits per COLR.

NOTE: Maintaining AFD within Nuclear Engineering recommended limits prevents AFD exceeding Tech Spec Limits (Limit and Precaution 1.8).

El 3.31.3 Maintain AFD within target band per OP/1/A/6100/022 (Unit 1 Data Book),

Enclosure 4.3, Graph(s) 1.1.

3.31.4 IF initial startup following refueling outage, check Bank D Control Rods greater than or equal to 200 steps withdrawn.

3.31.5 Notify IAE to stand by for periodic adjustments of Power Range NI channels.

Person Notified Date Time 3.31.6 IF AT ANY TIME Power Mismatch % (Excore/Thermal Power Mismatch) indicates greater than 4% during power increase, perform the following:

El 3.3 1.6.1 Stop power increase.

3.31.6.2 Have IAE calibrate each Power Range NI Channel to +/-1% Power Mismatch (NIs vs BETP).

3.31.6.3 WHEN calibration complete, continue with power increase.

El 3.31.7 Begin power increase to 50% RTP.

El 3.31.8 Maintain one pen selected to PR channel on Nuclear Power (%) recorder.

(1 ENBCR945O)

El 3.31.9 Maintain other pen as desired on Nuclear Power (%) recorder.

(1 ENB CR9450)

Unit 1

Enclosure 4.1 QP/1/A76100/003 Power Increase Page 29 of 45 NOTE: To prevent tripping BB Pump on low BB Tank level, 1BB-238 (S/G BB Demineralizers) and 1BB-44 (Blowdown Blowoff Recirc Control) must be allowed time to reposition while positioning flow control valves in substeps of 3.3 1.10.

3.31.10 WhEN plant conditions permit, swap Blowdown Blowoff Tank Vent from the Condenser to D Heater Extraction as follows:

LI 3.31.10.1 Record the following:

LI 1BB-123 (A SIG BB Flow Control)________ lbs rn/hr LI 1BB-124 (B S/G BB Flow Control) lbs rn/hr LI 1BB-125 (C SIG BB Flow Control) lbs rn/hr LI 1BB-126 (D SIG BB Flow Control)________ lbs rn/hr 3.31.10.2 Throttle the following to minimum flow (2000 7000 lbs rn/hi) over 15 minutes:

• 1BB-123 (A SIG BB Flow Control)

• 1BB-124 (B SIG BB Flow Control)

• 1BB-125 (C SIG BB Flow Control)

• 1BB-126 (D S/G BB Flow Control) 3.31.10.3 Place 1BB-98 & 100 BB Tank Vent D Htr/Cond to D HTR.

LI 3.3 1.10.4 Check open 1BB-98 (Blowdown Blowoff Tank Vent to D Heater Extraction Isol).

LI 3.3 1.10.5 Check closed 1BB-100 (Blowdown Blowoff Tank Vent to Condenser).

3.31.10.6 Throttle the following to positions recorded in Step 3.31.10.1 or as directed by Secondary Chemistry over 15 minutes:

• 1BB-123 (A S/G BB Flow Control)

• 1BB-124 (B SIG BB Flow Control)

• 1BB-125 (C S/G BB Flow Control)

• 1BB-126 (D S/G BB Flow Control)

Unit 1

Enclosure 4.1 OP/1IA/6100/003 Power Increase Page 30 of 45 NOTE: Power increase may continue while performing Step 3.3 1.11.

3.3 1.11 WhEN 35% RTP, transfer to GV Sequential Valve Mode as follows:

3.31.11.1 Ensure IvIW OUT lit.

3.31.11.2 Ensure IMP TN lit.

3.31.11.3 Depress SINGLE/SEQUENTIAL.

NOTE:

• A digital clock will appear on the DEH OIU Graphic 200 and indicate the amount of time left in the Single Valve / Sequential Valve Transfer.

Speed Loop will be automatically removed from service at intiation of transfer and will be automatically placed back in service following transfer.

3.31.11.4 Depress START/HALT to begin transfer.

3.31.11.5 Ensure SPEED OUT lit.

3.31.11.6 WHEN transfer is complete, perform the following:

A. Ensure SPEED IN lit.

B. Place Turbine in MANUAL.

C. Ensure IMP OUT lit.

D. Place Turbine in OPERATOR AUTO.

E. Select MW IN.

3.3 1.12 Ensure the following valves greater than 25% open and controlling S/G levels at program level:

• 1CF-32AB (1A S/G CF Control)

• 1CF-23AB (lB S/G CF Control)

• 1 CF-2OAB (1 C S/G CF Control)

• ICF-17AB (1D S/G CF Control) 3.31.13 Adjust Turbine load per OP/ 1 /A16300/00 1 A (Turbine-Generator Load Change).

Unit 1

Enclosure 4.1 OPI1/A16100/003 Power In crease Page 31 of 45 3.3 1.14 Perform the following to start the third Hotwell Pump:

3.3 1.14.1 Notify Secondary Chemistry of the following:

• Third Hotwell Pump is about to be started

• Check Polishing Demineralizers bypassed or isolated

{PIP M99-2044}

• Monitor Polishing Demineralizers for signs of pressure induced damage after Hotwell Pump start { PIP M99- 1828)

Person Notified Date Time LI 3.3 1.14.2 Place third Hotwell Pump in service per OPI1IA/6250/001 (Condensate and Feedwater System).

NOTE: AMSAC will automatically UNBLOCK when Turbine Impulse Pressure increases to 290 psig.

3.3 1.15 Prior to 40% Turbine load (290 psig Impulse Pressure), check all AMSAC SIG Low Flow status lights dark. (ISI-4) 3.3 1.16 WHEN Turbine load greater than 40% (290 psig Impulse Pressure), begin aligning MSRs per OP/1/B/6250/01 1 (Moisture Separator Reheater Operation).

3.3 1.17 WHEN Turbine Impulse Pressure 295 305 psig, check AMSAC ACTUATION BLOCK/UNBLOCK as follows:

3.31 .17.1 IF UNBLOCK dark, reset as follows:

Li A. Check all AMSAC S/G LOW FLOW status lights dark.

Li B. Check S/G PATH CLSD >30 SEC dark.

C. Depress UNBLOCK for AMSAC ACTUATION BLOCK/UNBLOCK.

LI 3.3 1.17.2 Check UNBLOCK lit.

Unit 1

Enclosure 4.1 OP/1I6lOOI0O3 Power Increase Page 32 of 45 3.3 1.18 WHEN 40% RTP, perform the following:

NOTE: Steps 3.3 1.18.1 and 3.3 1.18.2 can be performed concurrently.

3.3 1.18.1 Notify RP to adjust setpoints for the following: {PIP 99-5073}

• 1EMF-71 (S/G A Leakage Hi Rad)

• 1EMF72 (SIG B Leakage Hi Rad)

• 1EMF-73 (SIG C Leakage Hi Rad)

• 1EMF-74 (S/G D Leakage Hi Rad)

Person Notified Date Time 3.31.18.2 IF 1HM-95 (AS to A & B CF Pumps) is open, close by concurrently performing the following:

U A. Check operating CF Pump in auto.

B. Monitor OAC Graphic for operating CF Pump:

U 1A CF PUMP DETAIL Li lB CF PUMP DETAIL C. On operating CF Pump Turbine, monitor LP GOV CNTRL and HP GOV CNTRL positions.

NOTE:

• 1HM-95 will almost be closed before an effect is seen. (approximately 90% closed)

On operating CF Pump, LP Gov. demand will be 100% before HP Gov begins to open.

D. Slowly pulse 1HM-95 (AS to A & B CF Pumps) closed. (R.M.)

E. Monitor the following on CF Pump graphic:

U LP Gov position U HP Gov position U Decrease in LP Steam Supply Pressure Unit 1

Enclosure 4.1 OP!1/A/6100!003 Power Increase Page 33 of 45 F. IF any of the following occur, perform the following:

• Operating CF Pump speed decreases

• Operating CF Pump discharge pressure decrease

1. Stop closing 1HM-95.

2. Place operating CF Pump Turbine LP GOV CNTRL and HP GOV CNTRL in manual.

LI 3. Stabilize operating CF Pump speed! discharge pressure.

4. Continue to close 1HM-95 while maintaining operating CF Pump speed! discharge pressure.

5. WHEN 1HM-95 closed, place operating CF Pump governors in auto per OP!1!A!6250!001 (Condensate and Feedwater System).

CAUTION: Generator ! Automatic Voltage Regulator (AVR) testing must be performed prior to reactor power exceeding permissive P-8.

3.31.19 IF performing Generator ! Automatic Voltage Regulator (AVR) testing at 45% RTP, perform the following:

3.3 1.19.1 HOLD at 45% RTP until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.31.19.2 WHEN Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup, begin power increase to 50% RTP.

3.31.20 IF performing Generator Reactive Limits Verification testing at 45 50% RTP, perform the following:

LI 3.3 1.20.1 Perform applicable sections of PT!1!B!4350!001 C (Generator Reactive Limits Verification Test).

3.31.20.2 HOLD until Testing Personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

Unit 1

Enclosure 4.1 oPIlIAf6looIoo3 Power Increase Page 34 of 45 NOTE: Steps 3.3 1.21 and 3.3 1.22 may be performed concurrently as long as conditions for both steps are met. (PIP 08-2768) 3.3 1.21 WKEN 48 - 56% RTP, place second CF Pump in service as follows:

J 3.31.21.1 Maintain constant Reactor Power.

El 3.3 1.21.2 Check CF Pump supplying CF Header in auto.

El 3.31.21.3 Start second CF Pump per OP/11A16250/001 (Condensate and Feedwater System), Enclosure 4.17 (CF Pump Reset / Startup),

Section 3.4 (1A CF Pump Startup) or Section 3.5 (lB CF Pump Startup).

3.3 1.21.4 WhEN CF Pump operation stabilized, continue power increase.

CAUTION: Reactor Power ramp rate is limited by Fuel Maneurvering Limits (Data Book Section 1.3). The recommended load rate for unconditioned fuel above 50% power is 3% / hour, but shall never exceed 4% I hour, 7% I 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, 10% / 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> or a 3% step change. (PIP 08-2768) 3.31.22 Prior to 50% RTP, perform the following concurrently:

3.31.22.1 Ensure proper secondary water chemistry for operation greater CHM than 50% RTP.

El 3.31.22.2 Evaluate air ejector off gas and nozzle operation per OP/1/B/6300/006 (Main Vacuum and Vacuum Priming System).

El 3.3 1.22.3 Record highest value:

• 1 A Main Generator Breaker Air Compressor Pilot Valve Counter

• lB Main Generator Breaker Air Compressor Pilot Valve Counter

• Date/Time of counter readings 3.31.22.4 Notify System Engineer to calculate Main Generator Breaker air leakage using counter readings from Step 3.29.19 and Step 3.3 1.22.3.

Person Notified Date Time Unit 1

Enclosure 4.1 OP/l/A/6 100/003 Power Increase Page 35 of 45 3.3 1.22.5 Notify TCC (Transmission Control Center) (382-9401 or 382-9402) to check amperage output balanced on both busses to switchyard.

Person Notified Date Time NOTE: Maintaining AFD within Nuclear Engineering recommended limits prevents AFD exceeding Tech Spec Limits (Limit and Precaution 1.8).

El 3.31.22.6 Maintain AFD within target band per OP/1/A/6 100/022 (Unit 1 Data Book), Enclosure 4.3, Graph(s) 1.1.

3.31.22.7 Power Range detectors have been replaced AND startup is lAB NOT an Initial Cycle Startup, check the following:

El New detector current data inserted El Power Range High Flux (High Range) setpoints at 109%

3.3 1.22.8 IF Initial Cycle Startup, perform the following:

A. Notify Reactor Engineering to determine if Power Range NI calibration is required prior to 50% RTP.

Person Notified Date Time B. IF Power Range NI calibration is required prior to 50% RTP, perform the following:

El 1. Stop power increase.

2. Have IAE calibrate desired Power Range NI Channel(s).

3. WHEN calibration complete, continue power increase.

NOTE: Quadrant Power Tilt Ratio (QPTR) is NOT applicable until calibration of the Power Range NIs is completed subsequent to refueling. (TS 3.2.4)

C. Check QPTR less than or equal to 1.02.

3.3 1.22.9 IF NOT Initial Cycle Startup, check QPTR less than or equal to 1.02.

El 3.31.22.10 Check P-8 Hi Pwr Lo Flo Reactor Trip Blocked dark. (lSI-18)

Unit 1

Enclosure 4.1 QP/l/A/6100/003 Power Increase Page 36 of 45 3.32 Increase power to 95% RTP as follows:

3 .32.1 1

E Maintain control rods within insertion and withdrawal limits per COLR.

NOTE: Maintaining AFD within Nuclear Engineering recommended limits prevents AFD exceeding Tech Spec Limits (Limit and Precaution 1.8).

d3.32.2 Maintain AFD within target band per OP/1/A/6100/022 (Unit 1 Data Book),

Enclosure 4.3, Graph(s) 1.1.

3.32.3 Notify IAE to stand by for periodic adjustments of Power Range NI channels.

Person 1ktified Date Time 3.32.4 IF AT ANY TIME Power Mismatch % (Excore/Thermal Power Mismatch) indicates greater than 4% during power increase, perform the following:

LI 3.32.4.1 Stop power increase.

3.32.4.2 Have IAE calibrate each Power Range NI Channel to +/-1% Power Mismatch (NIs vs BETP).

3.32.4.3 WHEN calibration complete, continue power increase.

3.32.5 Begin power increase to 95% RTP 3.32.6 Prior to exceeding 56% Main Turbine power, perform the following:

3.32.6.1 Notify System Engineer to determine if Main Generator Breakers air leakage has been calculated, based on Engineering review.

Person Notified Date Time 3.32.6.2 IF System Engineer desires cycling 1A Main Generator Breaker, perform the following:

A. Ensure Main Turbine power less than 56%.

LI B. Maintain Main Turbine power less than 56%.

C. Open 1A Main Generator Breaker.

D. Close 1A Main Generator Breaker.

Unit 1

Enclosure 4.1 QP/l/A/6100/003 Power Increase Page 37 of 45 3.32.6.3 IF System Engineer desires cycling lB Main Generator Breaker, perform the following:

A. Ensure Main Turbine power less than 56%.

LI B. Maintain Main Turbine power less than 56%.

C. Open lB Main Generator Breaker.

D. Close lB Main Generator Breaker.

3.32.7 At 70% RTP or as directed by Secondary Chemistry, perform the following:

L3.32.7.l Begin placing C HDT Pumps in service per OP/1/B/6250/004 (Feedwater Heater Vents, Drains, and Bleed System).

3.32.7.2 WHEN C HDT Pumps are in service, stop one Hotwell Pump per OP/l/A16250/00 1 (Condensate and Feedwater System).

3.32.8 At 77-80% RTP, enable OTDT DCS alarming as follows:

3.32.8.l On DCS graphics, select MAINTENANCE MENU.

3.32.8.2 Select TAVG, DELTA T INPUTS & ALAI CHECKG graphic.

3.32.8.3 Select ON for the following:

NCAA 5422 E,NCAA 5462 E!l NCAA 5502 NCAA 5542 El OTDELTAT-FAIL Unit 1

Enclosure 4.1 OP!l/A16100!003 Power In crease Page 38 of 45 3.32.9 initial startup, perform the following:

3.32.9.1 Notify Nuclear Engineering to evaluate power increase to 78% RTP.

Person Notified Date Time El 3.32.9.2 Record limiting power level per Nuclear Engineering procedure:

%RTP El 3.32.9.3 Begin power increase to desired power level.

3.32.9.4 HOLD at desired power level until Reactor Core Flux Mapping completed.

3.32.9.5 Notify Nuclear Engineering to evaluate allowed power increase.

Person Notified Date Time El 3.32.9.6 Record desired power level.  % RTP thu 3.32.10 performing Generator! Automatic Voltage Regulator (AVR) testing at 78% RTP, HOLD until Generator! AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

El 3.32.11 Continue power increase to 95% RTP.

Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power Increase Page 39 of 45 CAUTION: IF CF Feed Reg Valves modulate less than 25%, potential exists to activate AMSAC.

Power increase may continue at OSMs discretion.

NOTE:

• At approximately 85% steam flow from each SIG, all S/G CF Bypass valves will ramp open (approximately 2 minute ramp) to 100% open position. SIG CF Valves will modulate to control S/G level.

• SIG SM Flow, in percent, can be monitored on DCS Feedwater Overview Graphic for

• all four S/Gs.

3.32.12 At greater than 85% steam flow from each S/G, ensure the following valves in auto and open:

• 1CF-1O4AB (1A S/G CF Cntrl Vlv Bypass)

• 1CF-1O5AB (lB S/G CF Cntrl Vlv Bypass)

• 1CF-1O6AB (1C S/G CF Cntrl Vlv Bypass)

• 1CF-1O7AB (1D S/G CF Cntrl Vlv Bypass) 3.32.13 WHEN at 976 MWE, check AS supply transferred from SM to C Heater Bleed by checking lAS-i 1 (SM Supply to Aux Steam Control) closed.

3.32.14 IF lAS-il failed to close, coordinate with SRO to establish required setpoint on lAS-i 1 controller to allow valve to close.

3.32.15 WHEN 85% RTP, place G Htr Drn Tank Pumps in service per OP/l/B/6250/004 (Feedwater Heater Vents, Drains, and Bleed System).

Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power Increase Page 40 of 45 3.32.16 IF startup is from a trip, shutdown, or load reduction to less than 90% RTP, perform the following:

3.32.16.1 HOLD at 90% RTP.

3.32.16.2 Notify Nuclear Engineering to evaluate performing PT/01A14 150/006 (Thermal Power Output Calculation).

Person Notified Date Time 3.32.16.3 IF performing Generator / Automatic Voltage Regulator (AVR) testing at 90% RTP, HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.32.17 Notify IAE to stand by for periodic adjustments of Power Range NI channels.

Person Notified Date Time NOTE: Step 3.3 1.19 is applicable for operation greater than 90% RTP.

3.32.18 IF AT ANY TIME Power Mismatch % (Excore/Thermal Power Mismatch) indicates greater than 1.5% during power increase, perform the following:

D 3.32.18.1 Stop power increase.

CAUTION: Allowing NC System temperature to change while calibrating NIs can result in a non-conservative adjustment which can result in exceeding 100% RTP.

{PIP 03-2117)

LI 3.32.18.2 Maintain steady state power and temperature.

3.32.18.3 Have IAE calibrate each Power Range NI Channel to +/-1% Power Mismatch (NIs vs BETP).

3.32.18.4 WHEN calibration complete, continue power increase.

Unit 1

Enclosure 4.1 OP/l/A/61001003 Power Increase Page 41 of 45 NOTE: Nuclear Engineering may perform PT/0/A/41 50/003 (Thermal Power Output Measurement) between 85 95% RTP. -

3.32.19 IF startup is from a refueling outage, perform the following:

3.32.19.1 HOLD at 95% RTP.

3.32.19.2 Ensure PTIO/A/41 50/003 (Thermal Power Output Measurement)

RX ENG completed.

3.32.19.3 IF performing Generator / Automatic Voltage Regulator (AVR) testing at 95% RTP, HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.32.20 Notify Maintenance to remove Limited Access signs used for startup per Model Work Order 0433323.

Person Notified Date Time Unit 1

Enclosure 4.1 oP/lIAI6looIoo3 Power Increase Page 42 of 45 3.32.21 WHEN 95% RTP, perform the following:

3.32.21.1 Ensure cooling groups energized on 1A Main Transformer:

• Circuit 1

• Circuit 2

• Circuit 3

• Circuit 4

• Circuit 5

• Circuit 6

• Circuit 7

• Circuit 8 3.32.21.2 Ensure cooling groups energized on lB Main Transformer:

• Circuit 1

• Circuit 2

• Circuit 3

• Circuit 4

• Circuit 5

• Circuit 6

• Circuit 7

• Circuit 8 Unit 1

Enclosure 4.1 OP/l/A/61001003 Power Increase Page 43 of 45 3.33 Increase power to 100% RTP as follows:

LI 3.33.1 Begin power increase to 100% RTP.

3.33.2 IF AT ANY TIME 1AD-6, ElO (Loop D/T Deviation) is received, perform the following:

3.33.2.1 Notify Reactor Engineering to evaluate.

Person Notified Date Time 3.3 3.2.2 Determine impact on power escalation.

CRS 3.33.2.3 IF power escalation CANNOT commence due to alarms, notify IAE to calibrate D/T channels.

Person Notified Date Time LI 3.3 3.3 Maintain control rods within insertion and withdrawal limits per COLR.

NOTE: Maintaining AFD within Nuclear Engineering recommended limits prevents AFD exceeding Tech Spec Limits (Limit and Precaution 1.8).

LI 3.33.4 Maintain AFD within target band per OP/1/A/6100/022 (Unit I Data Book),

Enclosure 4.3, Graph(s) 1.1.

NOTE: Dilution rates for reaching and maintaining 100% power may change significantly based on change in Xenon worth.

LI 3.3 3.5 Generate Xenon Prediction printout per OAC or REACT to determine expected changes in dilution rates. {PTP-99-0669}

3.33.6 WHEN 98% RTP, perform the following:

3.33.6.1 Depress MW IN/MW OUT.

3.33.6.2 Ensure lit MW OUT.

LI 3.33.6.3 Adjust Turbine load per OP/1/A16300/001 A (Turbine-Generator Load Change).

Unit 1

Enclosure 4.1 QP/l/A/6100/003 Power Increase Page 44 of 45 3.33.7 IF performing Generator Reactive Limits Verification testing at 98% RTP, perform the following:

LI 3.33.7.1 Perform applicable sections of PT/1/B/4350/001 C (Generator Reactive Limits Verification Test).

3.33.7.2 HOLD until Testing Personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

NOTE: The intent of the following hold step is to allow a more controlled final approach to 100% power.

3.33.8 WKEN 99.5% RTP, perform the following: {PIP 06-0754) 3.33.8.1 HOLD power escalation for at least 10 minutes to allow for Xenon and AFD oscillations to be seen.

3.33.8.2 WHEN at least 10 minutes have elapsed, continue power increase.

3.33.9 WHEN 100% RTP, perform the following:

CAUTION: Maximum #4 Governor Valve position is 45% with feedback ioops out of service to ensure valve maintained within its controlling band.

3.33.9.1 Ensure #4 Governor Valve less than 45% open unless advised by System Engineer.

LI 3.33.9.2 Check 100%RTPat3411MWT. (M1P1355) 3.33.9.3 IF necessary, have IAE calibrate each Power Range NI channel to +/-1% Power Mismatch (NIs vs BETP).

LI 3.33.9.4 Suspend logging Fuel Maneuvering Limit on RO Turnover Checklist.

El 3.33.9.5 Remove Pzr Htr Groups A, B and D from service per Enclosure 4.6 (Operation of Pzr Heaters).

Unit 1

Enclosure 4.1 OP/1/A16100/003 Power Increase Page 45 of 45 3.33.10 WhEN Nuclear Power (PR) instruments indicate 100%, perform the following:

3.33.10.1 Check the following between i0 - 102.25%: {PIP-98-2017}

LI 1A W/R Neutron Flux (%) (1ENBPI951O)

U lB W/R Neutron Flux (%) (1ENBPI952O) 3.33.10.2 outside of range, notify IAE to perform 1P101A132071006 A SRO (Gamma-Metrics Neutron Flux Monitor Calorimetric Adjustments).

Person Notified Date Time LI 3.33.11 Maintain proper NC System parameters by operating Pzr Htr Groups as required per Enclosure 4.6 (Operation of Pzr Heaters).

End of Enclosure Unit 1

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

(RO)

(BOP)

Initial Conditions: The plant is at 18% power (MOL), following a plant startup on the previous shift.

The plant had been shutdown for the previous six days to repair the 1A DG. A power ascension to 30% power is expected for the shift. It is expected to raise power at 2 MWe/Minute. Use of Alternate Dilute during power ascension in accordance with Enclosure 4.4, Alternate Dilute, of 0P111N6150/009, Boron Concentration Control, has been approved. The RMWST Dissolved Oxygen Concentration is 800 ppb.

Turnover: The following equipment is Out-Of-Service: 1C Hotwell Pump is OOS for Motor maintenance. 1NB LT-5420, RMWST Level, failed low last shift (IAE is investigating) and MCB Annunciator lAD-I, F-9, DEH/MSR SYSTEM MALFUNCT, has failed to off (IAE is investigating).

Event MaIf. Event Type* Event No. No. Description I NA R-RO Power Increase N-BOP N-SRO 2 SMO1O C-RO Steam Seal Pressure Regulator Failure C-SRO 3 SLIM06_ C-BOP Pzr Spray Valve (1 NC-27) Controller fails OPEN 07 C(TS)-SRO 4 IREOO6 C-RO Dropped Rod M12 C(TS)-SRO 5 RNOO7B C-BOP lB RN Pump Trips C-SRO 6 CFOO6C M-RO Unisolable Feedline Break (Doghouse) 1C SG M-BOP M-SRO 7 IPEOO1A NA Auto Reactor Trip Failure IPEOO1 B 8 ISE0O7A NA Feedwater Isolation Signal fails in AUTO ISEOO7B (N)ormal, (R)eactivity, (T)nstrument, (C)omponent, (M)ajor Scenario Event Description NRC Scenario 4 McGuire 2010 NRC Scenario #4 The plant is at 18% power (MOL), following a plant startup on the previous shift. The plant had been shutdown for the previous six days to repair the 1A DG. A power ascension to 30% power is expected for the shift. It is expected to raise power at 2 MWe/Minute. Use of Alternate Dilute during power ascension in accordance with Enclosure 4.4, Alternate Dilute, of OP/11A16150/009, Boron Concentration Control, has been approved. The RMWST Dissolved Oxygen Concentration is 800 ppb.

The following equipment is Out-Of-Service: IC Hotwell Pump is DOS for Motor maintenance.

1NB LT-5420, RMWST Level, failed low last shift (IAE is investigating) and MCB Annunciator lAD-i, F-9, DEH/MSR SYSTEM MALFUNCT, has failed to off (IAE is investigating).

Shortly after taking the watch, the operator will commence a load increase to 30% starting with Step 3.30 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 OP/1/A/6150/009, Boron Concentration Control, and raise Turbine load in accordance with OP/1/A16300/Q01 A, Turbine-Generator Load Change.

After this, the Steam Seal Header Pressure Control Valve, ITL-6, will fail closed. The operator will respond to OAC alarm M1A0689, UI GLAND STEAM SEAL HEADER PRESSURE, and restore Main Turbine and CFPT Sealing Steam Pressure before a low Main Condenser Vacuum condition develops.

Subsequently, the Pzr Spray Valve Controller, INC-27C A Spray, demand will fail to full output.

The operator will enter API1/A155Q0111, Pressurizer Pressure Anomalies. The operator will address Technical Specification 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits.

Afterwards, Control Rod M12 will drop into the core. The operator will enter AP/1/A/5500/14, Control Rod Malfunction, and address Enclosure 1, Response to Dropped or Misaligned Rod. The operator will address Technical Specification 3.1.4, Rod Group Alignment Limits.

Shortly after this, the lB RN Pump will trip on overcurrent, The operator will enter AP/i/A/5500/20, Loss of RN. The operator will address Technical Specification 3.7.7, Nuclear Service Water System (NSWS).

Following this, a major feedline break will occur in the 1 C Steam Generator Feedline inside the Doghouse. The Reactor will not trip automatically, and the operator will be required to manually trip the Reactor. Also, the Feedwater Isolation Signal (FWIS) will fail in AUTO. The operator will need to manually actuate FWIS.

The operator will enter EP/I/A/5000/E-0, Reactor Trip or Safety Injection, and then transition to EP!1/A15000/E-2, Faulted Steam Generator Isolation. The operator will isolate flow to and from the IC Steam Generator and then transition to EP/I/A15000/ES-1.i, SI Termination.

The scenario will terminate at Step 7.c of ES-il, after the crew has closed 1NI-9A and INI lOB.

Scenario Event Description NRC Scenario 4 Critical Tasks:

E-OA Manually trip the reactor prior to transition to FR-S1, Response to Nuclear Generation/ATWS.

Safety Significance: Failure to trip the reactor when required causes a challenge to the Subcriticality Critical Safety Function that otherwise would not exist. This mis-operation by the operator necessitates the crew taking compensating action which complicates the event mitigation strategy and demonstrates an inability by the operator to recognize a failure of the automatic actuation of the RPS.

E-2A Isolate the Faulted Steam Generator before transitioning out of E-2.

Safety Significance: Failure to isolate a Faulted SG that can be isolated causes challenges to the Critical Safety Functions that would 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 Q Reset to Temp I/C T = 0 Malfunctions:

160. ANN-ADII-C05 = ON, Transformer A Urgent Alarm ANN-ADII-F05 = ON, Transformer B Urgent Alarm ANN-ADII-B05 = ON, Transformer A Trouble Alarm ANN-ADII-E05 = ON, Transformer B Trouble Alarm MALF IPEOOIA, Auto Reactor Trip Failure MALF IPEOOIB, Auto Reactor Trip Failure XMT-NBOOI 0, RWMST Level Low LOA-CM058 = Racked Out, IC Hotwell Pump (MALF) ISEOO7A, Auto FWIS failure (MALF) ISEOO7B, Auto FWIS failure ANN-ADI-F09 = OFF, DEHIMSR SYSTEM MALFUNCT Q RUN Place 0-Stick on:

RWMST Level RESET all SLIMS DEHIMSR SYSTEM MALFUNCT Place Red Tag Label on:

IC Hotwell Pump Update Status Board, NOTE: RMWST DO = <1000 ppb.

Setup OAC J Freeze.

J Update Fresh Tech.

Spec. Log.

Fill out the NEOs Available section of Shift Turnover Info.

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

1. Assign Crew Positions based on evaluation requirements

2. Review the Shift Turnover Information with the crew.

3. Provide Enclosure 4.1 of OP!l/A!6100/003, marked up as follows:

Step 2.3 Initialed.

Step 3.1 Checkbox checked.

Step 3.2 Initialed.

Step 3.3 Initialed.

Step 3.3.1 Checkbox checked.

Step 3.3.2 Checkbox checked, Entry Step = 3.30.

Step 3.3.3 Checkbox checked.

Step 3.30.1 Initialed! Person Notified: Monty Champion Todays Date/Time.

4. Provide copy of OP/i !A/61 50/009.

5. Provide copy of OP/1/A16300/001 A.

6. Provide reactivity Plan based on the following Data:

Rods SDB-226, A, B, C, D CBA226 CBB -226 CBC 221/220 CBD 105/104 18.6% PTPBE Xe worth 3778.46 Sm Eq(-)41.98 Xe rate (-)2.32 pcm!min NC Boron 1586 ppm

[Xe] -46.83 250 EFPD Tave 561.7

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

J T-0 Begin Familiarization Period At direction of Event I Power Increase examiner Q At direction of Event 2 Steam Seal Pressure Regulator Failure examiner (MALF) SMOIO =

120 second Ramp Trigger #1 Scenario Event Description NRC Scenario 4 Bench Mark ACTIVITY DESCRIPTION Q At direction of Event 3 Pzr Spray Valve (1 NC-27) Controller fails OPEN examiner (MALF) SLIM-06 07 = I (SLIM fails to MANUAL)

(MALF) SLIM-06_04 = I (Raise Output)

Trigger #3 Q At direction of Event 4 Dropped Rod examiner IREOO6MI2 = I Trigger #5 At direction of Event 5 1 B RN Pump Trips examiner (MALF) RNOO7B Trigger #7 Q At direction of Event 6 Unisolable Feedline Break (Doghouse) 1C SG examiner (MALF) CFOO6C =

2.2E7 30 second Ramp Trigger #9 Continued Event 7 Auto Reactor Trip Failure Q from Event 6 (MALF) IPEOOIA NOTE: These malfunctions are entered at T=0 (MALF) IPEOOIB Continued Event 8 Feedwater Isolation Signal fails in AUTO from Event 6 (MALF) ISEOO7A = 3 NOTE: These malfunctions are entered at T0 (MALF) ISEOO7B = 3 NOTE: During the implementation will need to operate:

Trigger #11 LOA-DGOI 8 Stop PB, I B DG Emergency Stop (3 minutes delayed)

Trigger #13, LOA-SAOO2 = 0, Close IC TD CA Pump Steam Supply (5 minutes delayed)

J Terminate the scenario upon direction of Lead Examiner Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 1 Page 8 of 47 Event

Description:

Power Increase Shortly after taking the watch, the operator will commence a load increase to 30%

starting with Step 3.30 of Enclosure 4.1, Power Increase, of OPI1/A/61001003, Controlling Procedure for Unit Operation. The operator will dilute the NC System Boron concentration in accordance with Enclosure 4.4, Alternate Dilute, of OP/i/A/6150/009, Boron Concentration Control, and raise Turbine load in accordance with OP/i /A16300/001 A, Turbine-Generator Load Change.

Booth Operator Instructions: NA Indications Available: NA Tirn Pi I PnøføtI tIIn!Rh2vinr Comments 0P111A161001003, CONTROLLING PROCEDURE FOR UNIT OPERATIONS ENCLOSURE 4.1, POWER INCREASE CRS (Step 3.30.2) IF AT ANY TIME Power NOTE: The power increase Mismatch% (Excore/Thermal Power will be at 2 MWe/minute.

Mismatch) indicates greater than 4% during power increase, perform the following:

. Stop power increase.

. Have IAE calibrate each Power Range NI Channel to +/-1% Power Mismatch (Nis vs B ETP).

. WHEN calibration complete, continue with power increase.

BOP/ (Step 3.30.3) Begin power increase to 30%

RD RTP.

0P111A161501009, BORON CONCENTRATION CONTROL ENCLOSURE 4.4, ALTERNATE DILUTE NOTE: The BOP may perform this task more than once.

BOP (Step 3.6) Ensure the following reset to zero:

(R.M.)

. Total Make Up Flow Counter

Appendix D Operator Action Form ES-D-2 Op Test No.: N 10-1 Scenario # 4 Event # 1 Page 9 of 47 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments BOP (Step 3.7) Set Total Make Up Flow Counter to value determined in Step 3.5. (R.M.)

BOP (Step 3.8) Select ALTERNATE DILUTE on NC Sys M/U Controller.

BOP (Step 3.9) IF desired to make up only through 1 NV-i 75A (BA Blender to VCT Outlet), select CLOSED on INV-171A (BA Blender to VCT Inlet).

BOP (Step 3.10) IF desired to adjust reactor NOTE: It is NOT desired to makeup water flow adjust makeup flow.

BOP (Step 3.11) If desired to manually adjust reactor makeup water flow BOP (Step 3.12) IF AT ANY TIME it is desired to NOTE: It is NOT required to lower VCT level.... lower VCT level.

BOP (Step 3.13) IF AT ANY TIME plant parameters require termination of dilution, BOP (Step 3.14) Momentarily select START on NC System Make Up. (R.M.)

BOP (Step 3.15) Check NC System Make Up red light lit.

BOP (Step 3.16) Check 1NV-175A(BA Blender To VCT Outlet) open.

BOP (Step 3.17) Check 1NV-252A (Rx M/U Water To Blender control) open or throttled as required.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1D-1 Scenario # 4 Event # I Page 10 of 47 Event

Description:

Power Increase rin Dr

Comments BOP (Step 3.18) IF 1NV-171A (BA Blender To NOTE: INV-171A is NOT in VCT Inlet) in AUTO AUTO.

BOP (Step 3.19) Check Rx M/U Water Pump starts.

BOP (Step 3.20) Monitor Total Make Up Flow Counter. (R.M.)

BOP (Step 3.21) HOLD until one of the following occurs:

. Amount of reactor makeup water recorded per Step 3.5 added OR

. Reactor makeup water addition manually terminated BOP (Step 3.22) Ensure dilution terminated as follows: (R.M.)

. IF in AUTO, ensure the following off:

. IA Rx M/U Water Pump

. lB Rx M/U Water Pump

. Ensure the following closed:

. I NV-I 75A (BA Blender To VCT Outlet)

. I NV-252A (RX M/U Water To Blender Control)

. 1NV-171A (BA Blender To VCT Inlet)

BOP (Step 3.23) Ensure 1NV-171A (BA Blender to VCT Inlet) in AUTO.

BOP (Step 3.24) Ensure Rx M/U Water Flow Control in AUTO.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 1 Page 11 of 47 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments BOP (Step 3.25) IF Rx M/U Water Flow Control NOTE: The Rx M.U Water adjusted per Step 3.10 OR Step 3.11.... Flow Control was NOT adjusted.

BOP (Step 3.26) Ensure INV-137A (NC Filters OtIt 3-Way Control) in AUTO.

BOP (Step 3.27) IF desired to flush blender,, NOTE: It is NOT desired to flush the blender.

BOP (Step 3.28) Select AUTO for NC Sys M/U Controller.

BOP (Step 3.29) Ensure the following reset to zero: (R.M.)

. Total Make Up Flow Counter

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

0P111A163001001 A, TURBINE-GENERATOR STARTUPISHUTDOWN ENCLOSURE 4.1, TURBINE-GENERATOR LOAD CHANGE RO (Step 3.5) Changing Turbine Load

. IF Turbine in OPERATOR AUTO, perform the following:

. Ensure desired change within Calculated Capability Curve.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 1 Page 12 of 47 Event

Description:

Power Increase Time Pos. Expected ActionslBehavior Comments RO . IF turbine load will increase or decrease more than 10 MWs, notify Dispatcher of expected load change.

. Depress LOAD RATE.

. Enter desired load rate in NOTE: the RO will select 2 VARIABLE DISPLAY. MWe/Min loading rate.

. Depress ENTER.

. Depress REFERENCE.

. Enter desired load in VARIABLE DISPLAY.

. Depress ENTER.

. Depress GO

. Check load changes at selected rate.

OPII!A161001003, CONTROLLING PROCEDURE FOR UNIT OPERATIONS ENCLOSuRE 4.1, POWER INCREASE RO (Step 3.30.4) Load turbine per OP/1/A/6300/001 A (Turbine-Generator Load Change).

BOP (Step 3.30.5) WHEN M1A0913 (IA XFMR Oil Temp) indicates greater than 45°C, ensure cooling groups energized on IA Main Transformer BOP (Step 3.30.6) WHEN M1A0925 (lB XFMR Oil Temp) indicates greater than 45°C, ensure cooling groups energized on 1 B Main Transformer RO (Step 3.30.7) Place Exh Hood Spray in MAN.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario# 4 Event# 1 Page 13 of 47 Event

Description:

Power Increase Time Pos Expected ActionslBehavior Comments RD (Step 3.30.8) WHEN C-5 Lo Turb Impulse NOTE: The RD will place rods Press Rod Block dark, CRD Bank Select in AUTO.

may be placed in AUTO.

RD (Step 3.30.9) WHEN Turbine Imp Press greater than 75 psig, check P-13 Turbine Not At Power dark. (151-i 8)

RD (Step 3.30.10) Prior to 20% RTP, ensure NOTE: The CF nozzles are in Main Feedwater flow to all S/G through CF service per OP/1/A16250/001.

nozzles per OP/1/A16250/001 (Condensate and Feedwater System).

RO/ (Step 3.30.11) AFTER exceeding 18% CF flow, check each S/C in HIGH POWER BOP mode as follows:

. On DCS Workstation, select Steam Generator A Level graphic

. On Steam Generator A Level graphic, check HIGH POWER lit.

. On DCS Workstation, select Steam Generator B Level graphic

. On Steam Generator B Level graphic, Check HIGH POWER lit.

. On DCS Workstation, select Steam Generator C Level graphic

. On Steam Generator C Level graphic, check HIGH POWER lit,

. On DCS Workstation, select Steam Generator D Level graphic

. On Steam Generator D Level graphic, check HIGH POWER lit.

RO (Step 3.30.12) Ensure BB Pump is service NOTE: The BB Pump is in per OP/1/A16250/008 (Steam Generator service per OP/1/A!6250/008.

Blowdown).

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 1 Page 14 of 47 Event

Description:

Power Increase Time Pos. Expected Actions/Behavior Comments RD (Step 3.30.13) Initiate maximum BB flow for S/G cleanup while maintaining NC System temperature by throttling the following:

. 1BB-123 (A SIG BB Flow Control)

. IBB-124 (B S/G BB Flow Control)

. IBB-125 (C S/C BB Flow Control)

. IBB-126 (D S/G BB Flow Control)

BOP (Step 3.30.14) Adjust letdown to desired flow per OPI1IA/62001001 A (Chemical and Volume Control System Letdown).

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

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 2 Page 15 of 47 Event

Description:

Steam Seal Pressure Regulator Failure After this, the Steam Seal Header Pressure Control Valve, 1TL-6, will fail closed. The operator will respond to OAC alarm M1A0689, UI GLAND STEAM SEAL HEADER PRESSURE, and restore Main Turbine and CFPT Sealing Steam Pressure before a low Main Condenser Vacuum condition develops.

Booth Operator Instructions: Operate Trigger #1 (SMOIO (0%) on 120 second Ramp)

Indications Available:

. OAC Alarm M1A0689, Ui GLAND STEAM HEADER PRESSURE

. OAC Alarm M1A0801, IA & lB CFPT SEALING STEAM PRESSURE

. 1TLP-5010, STM Seal Header Press, indications lowers to 0 psig.

Time Pos. Expected ActionslBehavior Comments OAC ALARM M1A0689, UI GLAND STEAM SEAL HEADER PRESSURE RO (Step 1) Throttle open 1TL-8 (HP Steam Seal Bypass Valve) to maintain STM SEAL HEADER PRESS between 90-120 PSIG.

CRS (Step 2) Notify maintenance to troubleshoot NOTE: The CRS may call ITL-6 (Steam Seal Hdr Pressure Control WCC/Maintenance to address Valve). the malfunction.

If so, Booth Instructor acknowledge as WCC.

CRS (Step 3) IF STM SEAL HEADER PRESS NOTE: The CRS dispatch an cannot be maintained at least 90 PSIG, NEO to the valve.

dispatch an operator to look for steam leaks and verify valve alignment per If so, Booth Instructor acknowledge as NEO.

0P111B163001005 (STEAM SEAL SYSTEM).

NOTE: This alarm will come in if the operator delays getting the Bypass Open. If so, the crew may address this alarm as well, and dispatch an NEO.

OAC ALARM MIAO8OI, IA & lB CFPT SEALING STEAM PRESS

Appendix D Operator Action Form ES-D-2 Op Test No.: NW-i Scenario # 4 Event # 2 Page 16 of 47 Event

Description:

Steam Seal Pressure Regulator Failure Timg Prc Fvra,$rI A ,4rn&Pcih r&,ir Comments RO! (Step 1) Ensure Valve 1TF-2 (CF Pump Turb Booth Instructor: The NED NEO Steam Seal Ctrl) working properly to report should be FPGS maintain steam seal pressure between I to 4 pressure is 0 if they have NOT PSIG. opened ITL-8, and pressure is reading normal (2.5 psig) if they do.

RO (Step 2) IF necessary, open 1TF-4 (CF Pump Turb Steam Seal Ctrl Byp) to maintain steam seal pressure between 1 to 4 PSIG.

NOTE: The CRS will likely conduct a Focus Brief.

NOTE: There is a possibility that the crew may enter AP23 due to Low Condenser Vacuum. However, Condenser Vacuum will be improving, and the next event can be initiated while in this AR At the discretion of the Lead Examiner move to Event #3.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario# 4 Event# 3 Page 17 of 47 Event

Description:

Pzr Spray Valve (INC-27) Controller fails OPEN Subsequently, the Pzr Spray Valve Controller, 1NC-27C A Spray, demand will fail to full output. The operator will enter AP/1/A15500/1 1, Pressurizer Pressure Anomalies. The operator will address Technical Specification 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits.

Booth Operator Instructions: Operate Trigger #3 (SLIM-06 07 (1), SLIM-06_04 (1))

Indications Available:

• OAC Alarms Pzr Pressure Channel I through IV Low

• MCB Pzr Pressure gauges lowering

• Pzr Spray Valve Controller, 1 NC-27C A Spray, goes to 100% output.

• Pzr Spray Valve Controller, 1 NC-27C A Spray, Limit Switch indicates valve OPEN

• MCB Annunciator 1AD-6, C-6, PZR LO PRESS CONTROL Pos. Expected Actions/Behavior Comments NOTE: The BOP may take all the necessary actions in the Immediate Actions, before CRS reads AOP.

APIIIAI5500II 1, 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 3) Check Pzr spray valves CLOSED

- Immediate Action BOP (Step 3 RNO) CLOSE Pzr spray valve(s). NOTE: The BOP will recognize that the SLIMs is NOT effective at controlling the valve, and operate the EMERG SWITCH.

BOP (Step 4) Check Pzr PORVs CLOSED.

Appendix D Operator Action Form ES-D2 Op Test No.: Nb-i Scenario# 4 Event# 3 Page 18 of 47 Event

Description:

Pzr Spray Valve (INC-27) Controller fails OPEN Pos. Expected ActionslBehavior Comments BOP (Step 5) Check Pzr spray valves NOTE: IF the BOP has already CLOSED. used the EMERG SWITCH, the CRS may answer YES, and continue to Step 6.

If NOT, the Step 5 RNO will be performed (Scripted).

BOP (Step 5 RNO) IF NC pressure below desired pressure, THEN perform the following:

. Ensure Pzr spray emergency close NOTE: When the BOP uses switch on 1 MC-1 0 is in the CLOSE this switch the Spray Valve will position for failed spray valve. Close.

CRS . IF Pzr spray valve closed, THEN GO TO Step 6.

CRS (Step 6) Announce occurrence on page. NOTE: CRS may ask U2 RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 7) Check I NV-21A (NV Spray to PZR Iso) CLOSED.

BOP (Step 8) Check the following Pzr heaters ON:

. 1A

. lB

. 1D BOP (Step 8 RNO) IF NC pressure below desired NOTE: NC System pressure pressure, THEN perform the following: is 2150 psig.

. Place Pzr heater mode select switches in manual.

. Turn on heaters as necessary to control pressure.

Appendix D Operator Action Form ES-D2 OpTestNo.: Nb-i Scenario# 4 Event# 3 Page 19 of 47 Event

Description:

Pzr Spray Valve (INC-27) Controller fails OPEN FnrfrI ArfinnIRphvinr Comments WHEN Pzr pressure returns to normal AND automatic Pzr pressure control desired, THEN place Pzr heater in auto.

BOP (Step 9) Check IC Pzr heater ON.

BOP (Step 10) Check PZR PRESS MASTER IN AUTO.

BOP (Step 11) Check 1NC-27 PRESSURIZER NOTE: In order to close the SPRAY EMERGENCY CLOSE switch malfunctioning Spray Valve, SELECTED TO NORMAL. the BOP had to take the EMERG SWITCH to CLOSE.

CRS (Step 11 RNO) Notify station management to NOTE: The CRS may call ensure switch restored to NORMAL once WCC/Station Management to spray valve is repaired. address the switch position.

. If so, Booth Instructor

. acknowledge as WCC.

BOP (Step 12) Check 1NC-29 PRESSURIZER SPRAY EMERGENCY CLOSE switch SELECTED 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 failure.

If so, Booth Instructor acknowledge as WCC.

NOTE: The CRS will likely conduct a Focus Brief.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 3 Page 20 of 47 Event

Description:

Pzr Spray Valve (1 NC-27) Controller fails OPEN Pos Expected ActionslBehavior Comments TECHNICAL SPECIFICATION 3.4.1, RCS PRESSURE, TEMPERATURE, AND FLOW DEPARTURE FROM NUCLEATE BOILING (DNB) LIMITS CRS 3.4.1 RCS Pressure, Temperature, and Flow NOTE: NC System Pressure Departure from Nucleate Boiling (DNB) drops to 215O psig on the Limits. failure, and TS 3.4.1 was entered and exited during the transient.

CRS LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified in Table 3.4.1-1.

CRS APPLICABILITY: MODE 1.

CRS ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME A. Pressurizer A.1 Restore DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> pressure or parameter(s)

RCS average to within limit.

temperature DNB parameters not within limits.

At the discretion of the Lead Examiner move to Event #4.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 4 Page 21 of 47 Event

Description:

Dropped Rod Afterwards, Control Rod M12 will drop into the core. The operator will enter AP/1/A/5500/14, Control Rod Malfunction, and address Enclosure 1, Response to Dropped or Misaligned Rod. The operator will address Technical Specification 3.1.4, Rod Group Alignment Limits.

Booth Operator Instructions: Operate Trigger #5 (IREOO6MI2)

Indications Available:

. 1AD-21D9, RPI At Bottom Rod Drop.

. IAD-21A10, Rod Control Urgent Failure.

. IAD-2/D1O, RPI Urgent Failure.

. NC Temperature drops (Tavg < Tref).

. Power Ranqe recorders indicate a prompt flux drop.

Timc Pns Exrnrtcd Actinns!Rchivinr

.I Cnmmnts NOTE: The RD may immediately adjust load on the Turbine to maintain Tavg-Tref

= 1°F.

APII!A15500114, ROD CONTROL MALFUNCTION RD (Step 1) IF more than one rod dropped, Immediate Action THEN NOTE: Only one Rod Dropped during this event.

RD (Step 2) Place control rods in manual. Immediate Action NOTE: The will RD place the rods in Manual.

RD (Step 3) Check rod movement STOPPED. Immediate Action RD (Step 4) Check all rods ALIGNED WITH ASSOCIATED BANK.

RD (Step 4 RNO) Perform the following.

. IF two or more rods are misaligned.... NOTE: Only one rod is

, misaligned.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 4 Page 22 of 47 Event

Description:

Dropped Rod T;

. Comments

. IF T-Avg has gone down, THEN lower NOTE: The RO may adjust Turbine load as necessary to restore T load on the Turbine to Avg to T-Ref. maintain Tavg-Tref = 1°F.

. GO TO Enclosure 1 (Response To Dropped or Misaligned Rod)

NOTE: The CRS will transition to Enclosure 1.

APIIIA!5500114, ROD CONTROL MALFUNCTION ENCLOSURE 2, FAILURE OF RODS TO MOVE ON DEMAND CRS (Step 1) Announce occurrence on paging NOTE: The CRS may ask U2 system. RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

SRO (Step 2) Dispatch rod control system NOTE: The CRS may call qualified IAE to perform the following: WCC/IAE to address.

If so, Booth Instructor acknowledge as WCC/IAE as appropriate.

. Correct cause of misaligned rod.

. Notify Control Room operators when auto or manual rod motion is available for reactivity control.

CRS (Step 3) Check ROD CONTROL URGENT NOTE: 1AD-2, A-b is LIT.

FAILURE alarm (1AD-2, A-b) DARK. ______________________

RO (Step 3 RNO) Perform the following:

. Do not move control rods while the ROD CONTROL URGENT FAILURE alarm is lit, unless instructed by IAE.

. IF AT ANY TIME IAE desires to reset NOTE: This is a Continuous ROD CONTROL URGENT FAILURE Action. The CRS will make alarm, THEN depress the ROD both board operators aware.

CONTROL ALARM RESET pushbutton.

Appendix D Operator Action Form ES.D..2 Op Test No.: Nb-i Scenario # 4 Event # 4 Page 23 of 47 Event

Description:

Dropped Rod Time Pos. Expected ActionslBehavior Comments CRS . IF AT ANY TIME while in this procedure NOTE: This is a Continuous a runback occurs AND no rods will Action. The CRS will make move, THEN perform the following: both board operators aware.

. Trip Reactor.

. GO TO EP/11N50001E-0 (Reactor Trip or Safety Injection).

RO (Step 4) Use OAC point MP1385 (Reactor Thermal Power, Best Estimate), to determine reactor power in subsequent steps.

CRS! (Step 5) Check AFD (Tech Spec 3.2.3)

RO WITHIN TECH SPEC LIMITS.

CRS (Step 6) Check QPTR (Tech Spec 3.2.4) NOTE: The highest QPTR is WITHIN TECH SPEC LIMITS. 1.09.

RO (Step 6 RNO) Reduce reactor power as NOTE: because of the low required by Tech Specs as follows: present power level, a power reduction is NOT needed.

. Do not move rods until IAE determines rod movement is available.

BOP . Borate as required during power reduction to maintain T-Ave at T-Ref.

RO . Monitor AFD during load reduction.

CRS . IF AT ANY TIME AFD reaches Tech NOTE: Reactor power is <

Spec limit AND reactor power is greater 50%.

than 50%, THEN RO! . Reduce load as required by Tech Specs NOTE: Because of the low PER present power level, a power BOP reduction is NOT needed.

CRS (Step 7) Refer to the following Tech Specs:

. Tech Spec 3.1.4 (Rod Group Alignment Limits).

. Tech Spec 3.1.5 (Shutdown Bank Insertion Limits).

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 4 Page 24 of 47 Event

Description:

Dropped Rod Timø Fvnpifpd Comments

. Tech Spec 3.1.6 (Control Bank Insertion Limits).

. Ensure shutdown margin calculation is NOTE: The CRS may check performed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. the TS now and conclude that LCO 3.1.4 must be entered.

CRS (Step 8) Contact Reactor Engineering for NOTE: The CRS may call instructions. WOO/RE to address the switch position.

If so, Booth Instructor acknowledge as WCC.

RO (Step 9) Check reactor power GREATER THAN OR EQUAL TO 5%

RO (Step 10) Maintain T-Avg within 1°F of programmed T-Ref as follows:

. Adjust Turbine load. NOTE: The RO may adjust load on the Turbine as needed.

OR

. Borate/Dilute NC System.

RO (Step 11) Determine if power reduction is required as follows:

. Check any misaligned rod GREATER THAN 12 STEPS MISALIGNED.

. Check only one rod MISALIGNED.

. Check reactor power GREATER than NOTE: Power is < 50%.

50%

CRS (Step 11 RNO) GO TO Step 12.f.

RO (Step 12.f) Check only one rod MISALIGNED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N 101 Scenario # 4 Event # 4 Page 25 of 47 Event

Description:

Dropped Rod Tmé Pos. Expected ActionslBehavior Comments CRS (Step 12.g) Do not continue until the following conditions for rod alignment are satisfied:

. Reactor power is stable less than 50%.

. 15 hours1.736111e-4 days <br />0.00417 hours <br />2.480159e-5 weeks <br />5.7075e-6 months <br /> have elapsed from the time of rod misalignment.

NOTE: The CRS will likely conduct a Focus Brief.

TECHNICAL SPECIFICATION 3.1.4, ROD GROUP ALIGNMENT LIMITS CRS LCO 3.1.4 All shutdown and control rods shall be OPERABLE, with all individual indicated rod positions within 12 steps of their group step counter demand position.

CRS APPLICABILITY: MODES I and 2.

ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 4 Event # 4 Page 26 of 47 Event

Description:

Dropped Rod Time Pos. Expected ActionslBehavior Comments B. One rod not B.lRestore rod 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within to within alignment alignment limits, limits.

OR 82.1.1 Verify SDM is 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within the limit specified in the COLR.

OR B.2.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDM to within limit.

AND 8.2.2 Reduce 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> THERMAL POWER to

<75% RTP.

AND B.2.3 Verify SDM is within the Once per limit specified 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> in the COLR.

AND B.2.4 Perform SR 3.2.1.1. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND B.2.5 Perform SR 3.2.2.1. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND 8.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

At the discretion of the Lead Examiner move to Event #5.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 5 Page 27 of 47 Event

Description:

lB RN Pump Trips Shortly after this, the lB RN Pump will trip on overcurrent. The operator will enter AP/l/A/5500/20, Loss of RN. The operator will address Technical Specification 3.7.7, Nuclear Service Water System (NSWS).

Booth Operator Instructions: Operate Trigger #7 (RNOO7B)

Indications Available:

• MCB Annunciator 1AD-12, A-3, A RN PUMP DISCHARGE LO PRESSURE

• MCB Annunciator 1AD-12, A-4, B RN PUMP DISCHARGE LO PRESSURE

• MCB Annunciator 1AD-12, E-3, B RN PUMP ABNRMAL FLOW

• lB RN Pump GREEN Breaker Status Light is LIT

• lB RN Pump ammeter indicatinq 0 amps Time Pos. Expected ActionslBehavior Comments AP/l/A/5500!20, LOSS OF RN CASE I, LOSS OF OPERATING RN TRAIN BOP (Step 1) Check for potential loss of LU as -_______________________

follows:

. Check Unit 2 RN pump(s) that are Floor Instructor: If asked, As aligned to LLI OPERATING U2 RO report 2A RN Pump is PROPERLY. running properly.

. Check suction flowpath AVAILABLE.

CRS (Step 2) Announce occurrence on page. NOTE: CRS may ask U2 RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 3) Check if significant RN pump cavitation (flow, pressure, amps swinging)

IS OCCURRING.

CRS (Step 3 RNO) GO TO Step 6.

BOP (Step 6) Place idle RN train in service as follows:

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 4 Event # 5 Page 28 of 47 Event

Description:

lB RN Pump Trips Time Pos. Expected ActionslBehavior Comments BOP . Check idle RN train AVAILABLE TO START.

. Start one train of RN as follows:

. TO start 1A RN pump perform the following:

Place manual loader for 1RN-89A(RN to A KC Hx Control) to 10%

OPEN.

. Start 1A RN pump.

. Ensure the following valve for train being started OPEN.

. 1RN-86A (A KC Hx Inlet Isol).

. Ensure malfunctioning RN pump is off.

. Check if local venting of RN NOTE: Local venting of RN pump has been performed PER pump has NOT been one of the followipg: performed.

BOP (Step 6.e RNO) GO TO Step 6g.

BOP Check Enclosure 9 (NV Pump NOTE: Enclosure 9 has NOT Cooling Via Gravity Drain To been performed.

Sump)HAS BEEN PERFORMED.

CRS (Step 6.g RNO) GO TO Sep 6.i.

BOP . Check Case II (Loss of Low NOTE: Case II has NOT been Level or RC Supply Crossover) performed.

HAS BEEN IMPLEMENTED.

CRS (Step 6.i RNO) GO TO Step 7.

BOP (Step 7) Ensure cooling to KCas follows:

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 5 Page 29 of 47 Event

Description:

lB RN Pump Trips Time Pos. Expected Actions!Behavior Comments BOP . Check IA KC pump(s) RUNNING. NOTE: The B Train of KC is operating.

CRS (Step 7.a RNO) GO TO Step 7.f.

BOP . Check lB KC pump(s) RUNNING.

BOP . Ensure I B KC pumps aligned to reactor bldg non essential header as follows:

. OPEN the following valves:

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

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

• CLOSE the following valves:

. 1KC-230A (Tm A Rx Bldg Non Ess Sup Isol).

. 1 KC-3A (Tm A Rx bldg Non Ess Ret Isol).

BOP

• Check I B RN pump OFF.

BOP . Check IRN-187B (B KC Hx Inlet NOTE: 1RN-187B has NOT Isol) LOCALLY THROTTLED been locally throttled.

DURING THIS PROCEDURE.

CRS (Step 7.1 RNO) Perform the following:

. Place 1RNO187B MODE SELECT switch to manual.

. OPEN 1RN-187B (B KC Hx Inlet Isol).

BOP (Step 8) Perform the following on operating train:

. A Train:

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O1 Scenario # 4 Event # 5 Page 30 of 47 Event

Description:

lB RN Pump Trips Time Pos. Expected Actions!Behavior Comments IF 1A RN pump is aligned to LLI, THEN THROTTLE 1 RNO89A (RN to A KC Hx Control) to establish desired flow while attempting to maintain 1A RN pump flow less than 16000 GPM.

BC P1 (Step 9) Investigate reason for loss of RN CRS train as follows:

. Dispatch operator to check RN pump. NOTE: The BOPICRS will dispatch an NEC.

Booth Instructor: After 5 minutes, as NEC, report that the 51 Relay on the 1 B RN Pump breaker has operated.

. Dispatch operator to check RN pump breaker.

. Check suction flowpath alignment.

• Check discharge flowpath alignment. NOTE: The CRS may call WCC/IAE to address the Pump malfunction.

If so, Booth Instructor acknowledge as WCC.

CRS (Step 10) Ensure Control Room Area Chiller NOTE: CRS may ask U2 BOP in service PER Enclosure 4 (VC/YC to perform this Enclosure.

Operation).

If so, Floor Instructor acknowledge as U2 RO.

BCP (Step 1 1) Perform one of the following as necessary to align operating RN train with train of equipment cooled by RN:

. Swap operating equipment cooled by affected train of RN to opposite train....

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 5 Page 31 of 47 Event

Description:

lB RN Pump Trips Time Pos. Expected ActionslBehavior Comments Examiner NOTE: The CRS and BOP may proceed with evaluating equipment to realigned, and NOT address the TS.

If SO, move to next event, and evaluate the RN TS after the scenario.

TECHNICAL SPECIFICATION 3.7.7, NUCLEAR SERVICE WATER SYSTEM CRS 3.7.7 Nuclear Service Water System (NSWS)

CRS LCO 3.7.7 Two NSWS trains shall be OPERABLE.

CRS APPLICABILITY: MODES 1, 2, 3, and 4.

CRS ACTIONS CRS CONDITION REQUIRED COMPLETION ACTION TIME A, One NSWS A.i Restore 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> train NSWS train inoperable, to OPERABLE status.

At the discretion of the Lead Examiner move to Events #6-8.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 32 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Shortly after this, the lB RN Pump will trip on overcurrent. The operator will enter APII/A15500120, Loss of RN. The operator will address Technical Specification 3.7.7, Nuclear Service Water System (NSWS). Following this, a major feedline break will occur in the IC Steam Generator Feedhine inside the Doghouse. The Reactor will not trip automatically, and the operator will be required to manually trip the Reactor. Also, the Feedwater Isolation Signal (FWIS) will fail in AUTO. The operator will need to manually actuate FWIS. The operator will enter EPIIIAI5000IE-O, Reactor Trip or Safety Injection, and then transition to EP/1IAI5000IE-2, Faulted Steam Generator Isolation. The operator will isolate flow to and from the IC Steam Generator and then transition to EPI1/A15000/ES-1.1, SI Termination.

Booth Operator Instructions: Operate Trigger #9 (CFOO6C (2.2E7))

Indications Available:

• MCB Annunciator 1AD-4, A-3, S/G C FLOW MISMATCH LO STM FLOW

• MCB Annunciator 1AD-4, B-3, S/G C LEVEL DEVIATION

• MCB Annunciator 1AD-4, E-3, SIG C LO LEVEL ALERT

• MCB Annunciator IAD-4, F-3, S/G C LO-LO LEVEL ALERT

• IC S/G Narrow Range Level lowers

• 1C S/G Fed Flow lowers Time Pos. Expected ActionslBehavior Comments NOTE: Crew will carry out Immediate Actions of E-O, prior to the CRS addressing the EP.

EPII!A15000/E-O, REACTOR TRIP OR SAFETY INJECTION RO! (Step 1) Monitor Foldout page.

BOP 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.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 33 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos Expected Actions!Behavior Comments NOTE: The crew may NOT address the Step 2 RNO, even though the action is taken, based on the timing of reading the Step.

RO (Step 2 RNO) Perform the following Immediate Action

. Trip reactor

. IF reactor will not trip NOTE: The Reactor will trip Manually.

CRITICAL TASK:

(E-O A) Manually trip the reactor prior to transition to FR-S1, Response to Nuclear Generation!ATWS.

Safety Significance: Failure to trip the reactor when required causes a challenge to the Subcriticality Critical Safety Function that otherwise would not exist. This mis-operation by the operator necessitates the crew taking compensating action which complicates the event mitigation strategy and demonstrates an inability by the operator to recognize a failure of the automatic actuation of the RPS.

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

. A SAFETY INJECTION ACTUATED status light (151-i 8) LIT.

. Both LOCA Sequencer Actuated status lights (1SI-14) LIT.

Appendix D Operator Action Form ES-D-2 Op Test No.: N1O-1 Scenario # 4 Event # 6, 7 & 8 Page 34 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected Actions/Behavior Comments CRS (Step 6) Announce Unit 1 Safety Injection. NOTE: The CRS may ask U2 RD to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RD.

BOP (Step 7) Check ESF Monitor Light Panel on energized train(s):

. Groupsl,2,5DARK.

. Group 3 LIT.

. OACIN SERVICE.

. Group 4, Rows A through F LIT AS NOTE: The lights show that REQUIRED. INV-1 508 and 151A are OPEN.

BOP/ (Step 7.d RNO) Perform the following:

RD e Ensure both trains Phase A Isolation are initiated.

. Align or start S/I and Phase A components with individual windows in Group 4 as required.

CRS

• GO TO Step 7.f. NOTE: The BOP will CLOSE 1NV-150B and l5lAwhen NC pressure < 1500 psig.

BOP

• Check LOCA Sequencer Actuated status light (1SI-14) on energized train(s)

LIT.

BOP

• Check the following window on Monitor NOTE: The lights show that Light Panel Group 4 LIT.

- the FWIVs are OPEN.

• C-3 CONT ISOL PHASE A TRN A VLVS ALIGNED

• C-6 CONT ISOL PHASE A TRN B VLVS ALIGNED

• F-4 SAFETY INJECTION TRAIN A COMPONENTS ALIGNED

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 35 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected ActionslBehavior Comments

. F-5 SAFETY INJECTION TRAIN B COMPONENTS ALIGNED RO/ (Step 7.g RNO) Perform the following on energized train(s):

BOP

• Check OAC Monitor Light Program (MONL) for associated light.

Align valves as required, while NOTE: The RO will CLOSE continuing in the EP. the FWIVs.

BOP (Step 8) Check proper CA pump status:

. MDCApumps-ON

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

BOP (Step 9) Check all KC pumps ON.

BOP (Step 10) Check both RN pumps ON. NOTE: The lB RN Pump is NOT on.

(Step 10 RNO) Perform the following:

Start pump(s). NOTE: The 1 B RN Pump cannot be started based on Control Room Expectation Manual requirement.

BOP

• IF any RN pump off, THEN perform the following:

• IF IA RN pump is off, THEN .... NOTE: The 1A RN Pump is running.

• IF affected train is deenergized, AND NOTE: Both Trains are its D/G is off, THEN energized, and both D/Gs are running.

• Reset the following on affected train:

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 36 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SC! Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected Actions/Behavior Comments

. S/I NOTE: Train B is the affected Train.

• Sequencer BOP/ . Dispatch operator to stop affected NOTE: The CRS/BOP will CRS DIG using emergency stop dispatch an NEC.

pushbutton.

Booth Instructor: Operate Trigger #11 (LOADGOI8 (3 minutes delayed).

With in 3 minutes, as NEO report that the lB DIG has been emergency stopped.

ROI . Monitor affected RN cooled NOTE: This is a Continuous components and shut down as Action. The CRS will make BOP necessary. both board operators aware.

Examiner NOTE: In this event, lB RN Pump is NOT available, causing the operator to Reset SI and stop the I B DG. Because of this, B Train equipment will start to heat up, and the operator may elect to stop B train equipment, after verifying that its associated A Train component is operating.

CRS (Step 11) Notify Unit 2 to start 2A RN pump. Floor Instructor: As U2 RO report 2A RN Pump is running.

RO (Step 12) Check all SIG pressures NOTE: IC SG Pressure is GREATER THAN 775 PS 1G. decreasing uncontrollably.

RO (Step 12 RNO) Perform the following:

. Check the following closed:

. AIIMSIVs

. All MSIV bypass valves

. All SM PORVs.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 37 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected ActionslBehavior Comments

. IF any valve open, THEN.... NOTE: All SG Valves are Closed.

BOP (Step 13) Check Containment Pressure NOTE: Containment Pressure HAS REMAINED LESS THAN 3 PSIG. is normal.

BOP (Step 14) Check S/I flow:

. Check NV PMPS TO COLD LEG FLOW gauge INDICATING FLOW.

. Check NC pressure LESS THAN 1600 NOTE: NC Pressure is 800 PSIG. psig.

. Check NI pumps INDICATING FLOW.

• Check NC pressure LESS THAN 286 PSIG.

BOP (Step 14.d RNO) Perform the following:

. Ensure ND pump miniflb* 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 15.

CRS (Step 15) 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.

BOP (Step 16) 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.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 38 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC Sc! Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected Actions/Behavior Comments

• WHEN N/R level in any SIG greater than 1 1% (32% ACC), THEN control CA flow to maintain N/R levels between 11%

(32% ACC) and 50%.

RO (Step 17) Check NC temperatures: NOTE: During this event, Subcooling is momentarily lost, and regained. Based on this, it is expected that the NC Pumps will be ON, but may have been turned off.

• IF any NC pump on, THEN check NC T Avg STABLE OR TRENDING TO 557°F.

OR

. IF all NC pumps off, THEN check NC NOTE: Tavg is < 557°F.

T-Colds STABLE OR TRENDING TO 557°F.

RO (Step 17 RNO) Perform the following based on plant conditions:

. IF temperature less than 557°F AND going down, THEN attempt to stop cooldown PER Enclosure 3 (Uncontrolled NC System_Cooldown).

. IF temperature greater than 557°F AND NOTE: Tavg is < 557°F.

going_up, THEN NOTE: The CRS may assign the RO or the BOP to perform this action.

If so, appropriate Examiner follow actions of Enclosure 3.

Others should move ahead to Page 40 to continue in E-0.

EP!I/AI5000IE-0, REACTOR TRIP OR SAFETY INJECTION ENCLOSURE 3, UNCONTROLLED NC SYSTEM COOLDOWN

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected ActionslBehavior Comments RD (Step 1) Check steam dump valves Examiner NOTE: Follow the CLOSED. actions associated with Enclosure 3 if RD is assigned by CRS to perform.

RO (Step 2) Check all SM PORVs CLOSED.

RO (Step 3) Check MSR RESET light LIT.

RD (Step 3 RNO) Perform the following on MSR controls:

. Depress SYSTEM MANUAL

. Depress RESET RD (Step 4) Check any NC pump ON. NOTE: During this event, Subcooling is momentarily lost, and regained. Based on this, t is expected that the NC Pumps will be ON, but may have been turned off.

RO (Step 5) Check NC T-Avg GOING DOWN.

RO (Step 6) Control feed flow as follows:

. IF S/G N/R level is less than 11%(32% NOTE: N/R Level in at least ACC) in all S/Gs, THEN.... one SG is> 11%.

. WHEN N/R level is greater than 1 1%

(32% ACC) in at least one S/G, THEN throttle feed flow further to:

. Minimize cooldown

. Maintain at least one S/G N/R level greater than 11% (32% ACC).

RO (Step 7) Check MSIVs ANY OPEN. NOTE: All MSIVs will be CLOSED.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 40 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected ActionslBehavior Comments RO (Step 7 RNO) Perform the following:

. Close MSIV bypass valves.

. Exit this enclosure.

NOTE: The RO will report that Enclosure 3 is complete.

Examiner NOTE: Examiners NOT following the actions associated with Enclosure 3 continue HERE.

EPII!AI5000IE-O, REACTOR TRIP OR SAFETY INJECTION BOP (Step 18) Check Pzr PORV and spray valves:

. All PzrPORVsCLOSED.

. Normal Pzr spray valves CLOSED.

RO (Step 19) Check NC subcooling based on core exit T/Cs GREATER THAN 0°F.

RO (Step 20) Check if main steamlines intact:

. All S/G pressures STABLE OR GOING NOTE: The 1C SG is Faulted.

UP

. All S/Gs PRESSURIZED.

CRS (Step 20 RNO) IF any S!G is faulted, THEN perform the following:

. IF fault is outside containment, THEN perform the following:

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

. GO TO EPII/A15000/E-2 (Faulted NOTE: The CRS will transition Steam Generator Isolation). toE-2.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 41 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected ActionslBehavior Comments Examiner NOTE: In this event, lB RN Pump is NOT available, causing the operator to Reset SI and stop the 1 B DO. Because of this, B Train equipment will start to heat up, and the operator may elect to stop B train equipment, after verifying that its associated A Train component is operating.

EPIIIAI5000!E-2, FAULTED STEAM GENERATOR ISOLATION ROt (Step 1) Monitor Foldout page.

BOP RO (Step 2) Maintain at least one SIG available for NC System cooldown in subsequent steps.

ROI (Step 3) Maintain any faulted S/G or NOTE: The 1C SG is Faulted.

secondary break isolated during subsequent BOP recovery actions unless needed for NC System cooldown.

RO (Step 4) Check the following CLOSED:

. AIIMSIVs

. All MSIV bypass valves.

ROI (Step 5) Check at least one S/G pressure NOTE: Although all SG STABLE OR GOING UP. pressures may be decreasing BOP slowly, the operator will report stable based on plant

. conditions (i.e. faulted SO).

Otherwise a transition to ECA 2.1 will be made.

RO! (Step 6) Identify faulted SIG(s): NOTE: The 1C SG is Faulted.

BOP

Appendix D Operator Action Form ES-D..2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 42 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected ActionslBehavior Comments

. Any SIG pressure GOING DOWN IN AN UNCONTROLLED MANNER OR

. Any SIG DEPRESSURIZED.

RD (Step 7) Check faulted S/G(s) SM PORV CLOSED.

BOP (Step 8) Reset CA modulating valves.

BOP (Step 9) IF TD CA pump is the only source of NOTE: The TD CA Pump is feedwater, THEN... NOT the ONLY source of feedwater.

BOP (Step 10) Isolate faulted S/G(s) as follows:

• For1CS/G:

. Check S/G C FDW ISOLATED status light (1SI-4) LIT.

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

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

. Dispatch operator to unlock and close:

. ISA-i (IC S/G SM Supply to Unit 1 TD CA Pump Turb Maint Isol) (Unit 1 interior doghouse, 767+10, FF-53, above ladder).

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 43 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected ActionslBehavior Comments

. ISA-77 (1C S/G SM Supply NOTE: The CRS/BOP will to Unit 1 TD CA Pump Turb dispatch an NEO.

Loop Seal sal) (Unit 1 Booth Instructor: Operate u9tenor doghouse, 767+lOm Trigger #13 (LOASAOO2 (5

) minutes delayed).

Within 5 minutes, as NEO report that steam supply to the TD CA Pump from the IC SG has been isolated.

• Check BB valves CLOSED:

. IBB-3B (1C S/G Blowdown Cont Outside Isol Control)

. IBB-7A (C S/G BB Cont Inside Isol).

Close 1SM-95 (C SM Line Drain Isol).

CRITICAL TASK:

(E-2 A) Isolate the Faulted Steam Generator before transitioning out of E-2.

Safety Significance: Failure to isolate a Faulted SG that can be isolated causes challenges to the Critical Safety Functions that would 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).

RO (Step 11) Close 1AS-12 (Main Steam To Aux Steam).

BOP (Step 12) Check if S/G tubes intact:

• Check steamline EMFs NORMAL:

. 1EMF-24(S/GA)

. IEMF-25 (S/G_B)

. 1EMF-26 (S/G_C)

. 1EMF-27(S/GD).

. IF any S/G has previously been identified NOTE: There have been no as ruptured SGTRs identified.

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 44 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos. Expected ActionslBehavior Comments ROI (Step 13) Check S/I termination criteria:

BOP

. NC subcooling based on core exit T/Cs GREATER THAN 0°F.

. Secondary heat sink:

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

OR

. Total feed flow to intact S/Gs GREATER THAN 450 GPM.

. NC pressure STABLE OR GOING UP.

. Pzr level GREATER THAN 11% (29%

ACC).

. GO TO EP/1/A/5000/ES-1.1 (Safety NOTE: The CRS will transition Injection Termination). to ES-1.1 EPIIIAI5000IES-I .1, SAFETY INJECTION TERMINATION RO/ (Step 1) Monitor Foldout page.

BOP BOP (Step 2) Reset the following:

. S/I.

• Sequencers.

. Phase A Isolation.

. Phase B Isolation.

. IF AT ANY TIME a B/O 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:

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 45 of 47 Event

Description:

Unisolable Feedline Break (Doghouse) IC SGI Auto Reactor Trip Failure! Feedwater Isolation Signal fails in AUTO Time Pos Expected Actions/Behavior Comments

. lVl-129B (VI Supply to A Cont Ess VI Hdr Outside Isol)

. lVl-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) Check if NS pumps should be stopped:

. Any NS pump ON. NOTE: All NS Pumps are OFF.

CRS (Step 4.a RNO) Perform the following:

. IF AT ANY TIME while in this procedure NOTE: This is a Continuous an NS pump starts, THEN perform Action. The CRS will make Step 4. both board operators aware.

GO TO Step 5.

BOP (Step 5) Stop all but one NV pump. NOTE: The BOP should stop the I B NV Pump, if it has NOT been stopped already.

BOP (Step 6) Check NC pressure STABLE OR GOING UP.

BOP (Step 7) Isolate NV S/I flowpath as follows:

. Check the following valves OPEN:

. 1NV-221A (NV Pumps Suct From FWST)

. 1 NV-222B (NV Pumps Suct From FWST)

. Check the following valves OPEN

. 1NV-150B (NV_Pumps_Recirculation)

Appendix D Operator Action Form ES-D-2 Op Test No.: Nb-i Scenario # 4 Event # 6, 7 & 8 Page 46 of 47 Event

Description:

Unisolable Feedilne Break (Doghouse) IC SGI Auto Reactor Trip Failurel Feedwater Isolation Signal fails in AUTO Time Pos. Expected ActionslBehavior Comments

. 1NV-151A (NV Pumps Recirculation).

BOP

• CLOSE the following valves:

. 1NI-9A (NC Cold Leg_lnj From NV)

• 1NI-1OB (NC Cold Leg_lnj From NV).

At the discretion of the Lead Examiner terminate the exam.

UNIT I STATUS:

Power Level: 18% NCS [B] 1586 ppm Pzr [B]: 1589 ppm Xe: Per OAC Power History: The Plant is at 18% power (MDL), Core Burnup: 250 EFPDs following plant startup.

CONTROLLING PROCEDURE: OP/l/A/6100/03 Controlling Procedure for Unit Operation OTHER INFORMATION NEEDED TO ASSUME TO SHIFT:

• The Plant is at 18% power (MOL), following a plant startup on the previous shift.

• Control Rods are in MANUAL.

• The plant had been shutdown for the previous six days to repair the 1A DG.

• A load ascension to 30% power is expected for the shift.

• It is expected to raise power at 2 MWe/Minute.

• The RMWST Dissolved Oxygen Concentration is 800 ppb.

• CF Nozzles are in service per OP/1/A/6250/001.

• Chemistry has requested 7,500 Ibm/hr Blowdown Flow

• IA BB Pump has been placed in Service OP/1/A/6250/008.

The following equipment is Out-Of-Service:

• 1C Hotwell Pump is OOS for Motor maintenance.

• 1 NB LT-5420, RMWST Level, failed low last shift (IAE is investigating).

• MCB Annunciator lAD-i, F-9, DEH/MSR SYSTEM MALFUNCT, has failed to off (IAE is investigating)

Crew Directions:

• Raise power to 30% starting at Step 3.30.2 of Enclosure 4.1 of OP/1/A/6100/03, Controlling Procedure for Unit Operation.

• Use of Alternate Dilute during power ascension in accordance with Enclosure 4.4, Alternate Dilute, of OP/1/A/6150/009, Boron Concentration Control, has been approved.

• The Reactor Group has recommended that a Dilution of 200 gallons be made during initial power increase.

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

Rounds. Carol Extra(s) Bill Ed Wayne Tanya

Duke Energy Procedure No.

McGuire Nuclear Station oP/lIAJ6loOIOO3 Controlling Procedure For Unit Operation Revision No.

163 Electronic Reference No.

MC00472R Continuous Use PERFORMANCE This Procedure was printed on 07/08/10 at 08:38:13 from the electronic library as:

(ISSUED) PDF Format -

Compare with Control Copy every 14 calendar days while work is being performed.

Compared with Control Copy Compared with Control Copy Compared with Control Copy Date(s) Performed Work Order/Task Number (WO#)

COMPLETION LI Yes LI NA Checklists and/or blanks initialed, signed, dated, or filled in NA, as appropriate?

LI Yes LI NA Required enclosures attached?

LI Yes LI NA Charts, graphs, data sheets, etc. attached, dated, identified, and marked?

LI Yes LI NA Calibrated Test Equipment, if used, checked outJin and referenced to this procedure?

LI Yes LI NA Procedure requirements met?

Verified By Date Procedure Completion Approved Date Remarks (attach additional pages, if necessary)

Printed Date: *07/08/2010*

IMPORTANT: Do NOT mark on barcodes.

Enclosure No.: *4,1

• IIH lilttilt I Il iltit til I I Hil Iltit til IIItilt I lilt 1111 1 1 1 lit lift Revision No.:

• 163*

1 1 1 1111 1 1 1 tIl til Procedure No.: *OP/1/AJ6100/003*

1 1 1 1 HIlt I I Il lit Hil I I Ii lIlt Hil 11tH li i I It 11tH 11111 I li i

Enclosure 4.1 OP/l/A/6100/003 Power In crease Page 1 of 45

1. Limits and Precautions 1.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing NC System temperature and by changing neutron absorption in the reactor core. (R.M.)

1.2 Any inadvertent power reduction requires investigation and correction prior to continuing power increase.

NOTE: Limit and Precautions 1.3 and 1.4 are NOT applicable during performance of PT/0/A141501027 A (End of Cycle Moderator Temperature Coefficient Determination Boron / Dilution Method). (PIP 08-4252}

1.3 WhEN Turbine Generator paralleled to grid, maximum Tavg deviation from Tref is +/-4°F. (Assumption in the accident analysis in the UFSAR) 1.4 WHEN Turbine Generator paralleled to grid with Steam Dumps closed AND CRD Select in MANUAL maximum Tavg deviation from Tref is +/-3°F.

1.5 WHEN transferring CRD Select from MANUAL to AUTO, Tavg maximum deviation from Tref 5 +/-1°F.

1.6 WhEN Reactor critical, minimum Tavg is 551 °F.

1.7 Maximum Power Mismatch is +/-2% for each Power Range channel (NIS vs BETP) during steady state power operations. (Should be calibrated within 4 hrs)

NOTE: The following recommended AFD targets are NOT applicable during initial cycle startup.

1.8 The following AFD targets are recommended by Nuclear Engineering:

• 1% of target from 90 100% RTP with equilibrium xenon

• 2% of target from 90 100% RTP with transient xenon

• 2% of target from 50 90% RTP

• 5% of target from 20 50% RTP

• 10% of target below 20% RTP 1.9 Maximum Boron concentration difference between Pzr and NC System is 50 ppm.

Unit 1

Enclosure 4.1 OP/11A16100/003 Power In crease Page 2 of 45 1.10 IF in Mode 3 and SDM is outside required limit, TS 3.1.1 requires boration within 15 minutes to restore SDM.

1.11 Maximum SIG tube leakage from any SIG is 100 gpd.

1.12 IF both Rod Position Indicator systems (DRPI and OAC) become inoperable during Mode 3, Tech Specs require tripping the Reactor..

1.13 Minimum individual SIG outlet pressure is 870 psig to prevent flow induced vibration of S/G tubes. {MDUK-1242.01-0001.001 (Temperature and Power Limits for Operation As Controlled by Pressure Boundary Structural Analysis and Safety Analysis))

1.14 The following apply to Fuel Maneuvering Limits:

• Fuel Maneuvering Limits apply to power increase and NOT power decrease

• Fuel Maneuvering Limits are based on Reactor Power and NOT Generator Load

• The Reactor Group shall be contacted for any questions that arise concerning Fuel Maneuvering Limits 1.15 Control Rod withdrawal rate is limited by Fuel Maneurvering Limits (Data Book Section 1.3). The rod withdrawal rate for unconditioned fuel above 50% power is limited to 3 steps/hour. Fuel is considered conditioned with respect to rod position once the control rods have been withdrawn to a given position at a given power level.

1.16 During power changes, the following alternate indications for Reactor Power are available:

• Thermal Power Best Estimate (TPBE)

• Tavg, Tcold, NC Loop Delta-T

• Intermediate Range Channels

• Turbine Impulse Pressure, Megawatt output

• CF flowrate Unit 1

Enclosure 4.1 0PI1IA/6looIoo3 Power Increase Page 3 of 45 NOTE: This enclosure will affect reactivity of the core and is therefore designated important to Reactivity Management per the guidelines of NSD 703 (Reactivity Management) (R.M.)

2. Initial Conditions 2.1 Mode 3 with NC System at 557°F and 2235 psig in anticipation of Reactor Startup OR 2.2 Mode 2 2.3 Mode 1 in anticipation of power increase

3. Procedure NOTE: IF initial power escalation for a fuel cycle, this procedure will be performed in parallel with Nuclear Engineering procedure PT/0/A/4150/021 (Post Refueling Controlling Procedure for Criticality, Zero Power Physics and Power Escalation Testing).

Evaluate all outstanding R&Rs that may impact performance of this procedure.

3.2 Evaluate OP/1/A/6100/SU-19 (Heatup to 557 Degrees F), Enclosure 4.4 (Pre-Startup SRO System Alignments) to determine if additional actions may need to be performed.

3.3 IF plant conditions require entering this procedure at some point other than the SRO beginning, perform the following:

.3.1 Determine entry step based upon plant conditions.

Record entry step: -

i3.3.3 Evaluate all steps prior to that recorded in Step 3.3.2 for additional actions that need to be performed.

3.4 IF Zero Power Physics Testing will be performed, maintain the following:

LI NC System pressure within +/- 20 psig of 2235 psig LI NC System Tavg within +/- 1.0°F of 557°F by throttling S/G blowdown 3.5 WhEN NC System temperature has been 557°F for at least 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, configure Loose Parts Monitoring System for at power monitoring per OPI1/B/6150/016 (Loose Parts Monitoring System).

Unit 1

Enclosure 4.1 OP/11A161001003 Power Increase Page 4 of 45 El 3.6 Maintain proper NC System parameters by operating Pzr Htr Groups as required per Enclosure 4.6 (Operation of Pzr Heaters).

3.7 On DCS Workstation Feedpump Overview graphic, ensure operating CF Pump Turbine in auto.

3.8 Ensure the following S/G CF Cntrl Bypass Valves in auto:

• 1CF-1O4AB (1A SIG CF Control Bypass)

• 1CF-1O5AB (lB S/G CF Control Bypass)

• 1CF-1O6AB (1C S/G CF Control Bypass)

• 1CF-107AB (lD S/G CF Control Bypass) 3.9 Defeat Hi Flux at Shutdown alarms as follows:

3.9.1 Place Hi Flux At Shutdown for Channel N31 to BLOCK. (SR drawer) 3.9.2 Place Hi Flux At Shutdown for Channel N32 to BLOCK. (SR drawer)

El 3.9.3 Check 1AD-2, D2 (SIR High Flux Alm Blocked) lit.

3.9.4 Place Shutdown Monitor A Annun Bypass to BYPASS.

3.9.5 Place Shutdown Monitor B Annun Bypass to BYPASS.

3.10 Within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> prior to achieving criticality, perform the following to check SDM:

NOTE: g the REACT program says Reactivity Summation is negative! Please perform an ECB. This means that with all rods out the reactor is NOT predicted to go critical.

LI 3.10.1 Check Estimated Critical Rod Position is above COLR insertion limit per OP/0/A/6 100/006 (Reactivity Balance Calculation).

LI 3.10.2 Check all control rods operable.

LI 3.10.3 Record in PT/1/A14600/008 (Surveillance Requirements for Unit Heatup).

Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power In crease Page 5 of 45 3.11 IF TV/GV hot calibration was started in OP/1/A/6100/SU-19 (Heatup to 557 Degrees F)

AND has NOT been completed, perform the following:

3.11.1 Notify IAE to stop/suspend TV/GV hot calibration.

Person Notified Date Time 3.11.2 HOLD until confirmed that IAE is NOT performing TV/GV hot calibration.

IAE 3.12 Ensure a Reactor startup 91-01 briefing has been performed:

SRO Management Designee:

Evolution Coordinator:

Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power In crease Page 6 of 45 3.13 Begin Reactor startup to critical as follows:

NOTE:

• Minimum 1 decade overlap required between SR and IR.

• Minimum 1 decade overlap required between JR and PR.

• positive reactivity addition occurs, Mode 2 can be achieved with all control rods inserted.

• Tech Specs define Mode 2. (Mode 2 may be declared when Control Banks are initially withdrawn from fully inserted position).

3.13.1 IF Reactor startup being performed by control rod withdrawal, complete SRO RO Enclosure 4.3 (Guidelines For Approaching Criticality Via Control Rod Withdrawal) before control bank withdrawal.

LI 3.13.2 Announce over page, Commencing Unit 1 Reactor Startup.

LI 3.13.3 Using Plant Mode Change & Alarm Look Ahead, change OAC to Mode 2.

3.13.4 On the DCS Work Station, change the DCS Modal Alarming to MODE 2 as follows:

LI 3.13.4.1 Access DCS PLANT MODE SELECTION Screen (6012).

LI 3.13.4.2 Select MODE 2.

LI 3.13.4.3 Select ACCEPT MODE.

LI 3.13.4.4 Check MODE 2 is displayed in CURRENT PLANT MODE.

3.13.5 Notify SRO and RO to continuously monitor the following to determine when SRO RO the Reactor is supercritical:

• Constant positive SUR without control rod movement or NC System dilution

• Log Power increasing linearly without control rod movement or NC System dilution Unit 1

Enclosure 4.1 oP/1/A/6loo/oo3 Power In crease Page 7 of 45 3.13.6 Initiate 1IM plot per one of the following:

LI Nuclear Engineering procedure guidance on initial startup for fuel cycle OR LI PT/0/A/4 150/047 (1/M Monitoring During Startup) 3.13.7 WHEN control rods are being withdrawn, perform Table 4.1-1 (Control Rod Bank Parameters).

3.13.8 Select HI on Nuclear Power (%) recorder. (1ENBCR945O) 3.13.9 Withdraw control banks per one of the following:

3.13.9.1 initial startup for fuel cycle, withdraw control rods per Nuclear Engineering procedure guidance.

OR 3.13.9.2 Perform the following:

A. Place CRD Bank Select in MANUAL.

LI B. Withdraw control banks in 50 60 step increments.

LI C. Wait until SR counts stabilize. (1 minute)

LI D. Repeat Steps B - C until Reactor is critical.

3.13.10 IF IR Compensating Voltage was adjusted to -4OVDC due to improper lAB compensation OR IR Detector Replacement, evaluate JR Compensating Voltage adjustments.

Unit 1

Enclosure 4.1 OP/1/A16 100/003 Power Increase Page 8 of 45 Table 4.1-1. Control Rod Bank Parameters Record Bank and step position at each stop point.

Initial box after checking each parameter.

Bank:

Step:

Parameter:

WHEN below ECP lower limit window, a rapid decrease in SUR.

Proper count rate, SUR and recorder response.

Proper Bank Overlap between Control Banks per Unit 1 Data Book, Enc 4.3, Sect 1.13 DRPI vs bank demand counters acceptable.

l/M plot acceptable.

Tavg> 551°F Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power In crease Page 9 of 45 3.13.11 WHEN Reactor critical, begin increasing JR power to 1 x 108 Amps.

LI 3.13.12 Check at least one decade overlap between SR and JR instrumentation.

3.13.13 WHEN greater than 1 x 10° Amps, perform the following:

LI 3.13.13.1 Check lit P-6 S/R Block Permissive. (1SI-18) 3.13.13.2 Place both Source Range Select to BLOCK.

3.13.13.3 Check lit on 1SI-18:

LI SR Train A Trip Blkd Hi Voltage Off LI SR Train B Trip Blkd Hi Voltage Off 3.13.13.4 Select both JR channels on Nuclear Power (%) recorder.

(1ENBCR945O)

LI 3.13.14 Maintain Reactor Power at 1 x 1 0 Amps.

LI 3.13.15 Record the following:

• Rod Position Bank

• Tavg

• Boron Concentration

• Time

• Xenon worth (OAC)

• Samarium difference from equilibrium pcm (OAC)

LI 3.13.16 Record above parameters in Autolog.

3.13.17 Select LO on Nuclear Power (%) recorder. (1ENBCR945O) 3.13.18 !J initial power escalation for a fuel cycle:

3.13.18.1 Perform Zero Power Physics Test as advised by Nuclear Engineering procedure PT/0/A/4 150/021 (Post Refueling Controlling Procedure for Criticality, Zero Power Physics and Power Escalation Testing).

3.13.18.2 HOLD until Nuclear Engineering testing complete.

Person Notified Date Time 3.13.19 Ensure one PR channel selected on Nuclear Power (%) recorder.

(1 ENB CR9450)

Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power Increase Page 10 of 45 3.14 Begin performance of Enclosure 4.8 (Guidelines For Power Increase).

SRO 3.15 Perform the following to control NC System temperature until Turbine Generator is paralleled to the grid:

NOTE: Steps 3.15.1 - 3.15.2 should be performed concurrently.

3.15.1 Maintain the following by adjusting setpoint on STM PRESS CONTROLLER:

LI Tcold 557 559°F LI SM Pressure 1060 1110 psig NOTE:

• While maintaining Tcold at 557 559°F using Steam Dumps, Table 4.1-2 should be used to approximate Tavg for a given Reactor Power level.

• Increasing Reactor Power while Turbine Power remains constant will result in Tavg exceeding Program Tref (557°F). (Turbine Impulse Pressure Channels will NOT increase until Turbine Generator is paralleled to the grid.)

LI 3.15.2 Refer to Table 4.1-2 (Reactor Power / Expected Tavg) for expected Tavg for a given Reactor Power level:

Table 4.1-2 Reactor Power I Expected Tavg Reactor Power (%) Expected Tavg (°F) 15 561.215 14 560.934 13 560.653 12 560.372 11 560.091 10 559.810 9 559.529 8 559.248 558.967 6 558.686 5 558.405 4 558.124 3 557.843 2 557.562 1 557.281 0 557.000 Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power In crease Page 11 of 45 3.16 IF feedwater flow is aligned to CA nozzles, perform the following:

NOTE: Thennal Power Best Estimate calculations during low power conditions use a weighted (double counted) value for CA Nozzle flow. This results in conservative indication of TPBE. To prevent this, feedwater flow should be swapped to CF Nozzles prior to 20% RTP. (PIP 03-5427) 3.16.1 Ensure Reactor Power will remain less than 20% RTP.

El 3.16.2 Evaluate swapping to CF nozzles per OP/1/A16250/00l (Condensate and Feedwater System) 3.17 Ensure in service CF Pump Turbine LP GOV CNTRL and HP GOV CNTRL in auto.

NOTE: Due to inherent design of BWI S/Gs, SIG WR level will decrease as Reactor Power is increased through 3% RTP.

3.18 IF AT ANY TIME S/G N/R Level decreases to 28% OR exceeds 52%, perform the following:

3.18.1 individual S/G level control problem, perform the following:

3.18.1.1 Place affected S/G CF Control Bypass and/or CF Control Valve in manual.

3.18.1.2 Adjust affected S/G CF Control Bypass or CF Control Valve as required to return affected S/G N/R level to setpoint.

3.18.1.3 Place affected S/G CF Control Bypass and/or CF Control Valve in auto.

3.18.2 IF all S/Gs indicate level control problems, perform the following:

3.18.2.1 Place operating CF Pump Turbine LP GOV CNTRL and HP GOV CNTRL in manual.

3.18.2.2 Use CF Pump Turbine LP GOV CNTRL increase/decrease pushbuttons to restore associated S/G NR levels to normal.

3.18.2.3 WHEN S/G NR levels normal, place operating CF Pump Turbine HP GOV CNTRL in auto.

3.18.2.4 WHEN in service CF Pump Turbine speed within 50 100 rpm-of AUTO SPT on DCS Feedpump Overview graphic, place LP GOV CNTRL in auto.

Unit 1

Enclosure 4.1 OP/l/A/6 100/003 Power Increase Page 12 of45 LI 3.19 Increase Reactor Power to 2% RTP (2.0 2.5%).

3.20 HOLD at 2% RTP (2.0 2.5%) for a minimum of 10 minutes.

3.21 Increase Rx Power to 4% RTP (3.5 4.0%) as follows:

3.21.1 WITEN greater than 3% RTP, perform the following:

3.21.1.1 Open:

• 1SM-83 (A SM Line Drain)

• 1SM-89 (B SM Line Drain)

• 1SM-95 (C SM Line Drain)

• 1SM-101 (D SM Line Drain)

NOTE: the Turbine is placed in manual in the following step, lAD-i, F4 (Turbine in Manual) will alarm. This is an expected alarm.

3.21.1.2 Ensure Turbine in MANUAL.

3.21.1.3 Close Governor Valves using GV Lower.

NOTE: Mode 1 is entered at 5% RTP.

3.22 WHEN at 4% RTP, perform the following:

3.22.1 HOLD at 4% RTP (3.5 4.0%) for a minimum of 10 minutes.

LI 3.22.2 Using Plant Mode Change & Alarm Look Ahead, change the OAC to Mode 1.

3.22.3 On the DCS Work Station, change the DCS Modal Alarming to Mode 1 as follows:

LI 3.22.3.1 Access DCS PLANT MODE SELECTION Screen (6012).

LI 3.22.3.2 Select MODE 1.

LI 3.22.3.3 Select ACCEPT MODE.

LI 3.22.3.4 Check MODE 1 is displayed in CURRENT PLANT MODE.

Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power Increase Page 13 of 45 Q 3.23 Increase Reactor Power to 6% RTP (6.0 6.5%).

3.24 HOLD at 6% RTP (6.0 6.5%) for a minimum of 10 minutes.

3.25 WhEN any S/G CF Control Bypass Valve indicates between 50 60% open, place the associated SIG CF Cntrl Valve in service as follows:

3.25.1 Ensure the following S/G CF Control Bypass valves in auto:

• 1CF-1O4AB (1A SIG CF Control Bypass)

• 1CF-1O5AB (lB SIG CF Control Bypass)

• 1CF-1O6AB (1C S/G CF Control Bypass)

• 1CF-1O7AB (1D S/G CF Control Bypass) 3.25.2 Place S/G CF Control Valves in service as follows:

NOTE:

• Placing SIG CF Cntrl Vlvs in auto should be performed in a controlled manner, one S/G at a time.

• Allow CF flow and S/G water level to stabilize one S/G at a time.

• SIG CF Control Bypass Valves are expected to modulate when the S/G CF Cntrl Valves are placed in service.

• SIG CF Cntrl Valves can be placed in service in any order.

CAUTION: A greater than 65% demand on the S/G CF Control Bypass Valve sends a 5%

minimum open demand signal to the associated S/G CF Control Valve. The CF Bypass Valve has to close to less than 35% to clear the demand signal to the S/G CF Control Valve.

3.25.3 For A SIG, perform the following:

3.25.3.1 Ensure 1CF-32AB (lA S/G CF Control) in manual and closed.

3.25.3.2 Open the following:

• 1 CF-3 1 (A SIG CF Cntrl Inlet Isol)

• 1CF-33 (A SIG CF Cntrl Outlet Isol)

D 3.25.3.3 Check 1CF-1O4AB (1A SIG CF Control Bypass) output less than 65%.

3.25.3.4 Place 1CF-32AB (1A S/G CF Control) in auto.

Unit I

Enclosure 4.1 OP/l/A/6100/003 Power Increase Page 14 of 45 3.25.4 For B S/G, perform the following:

3.25.4.1 Ensure 1CF-23AB (lB S/G CF Control) in manual and closed.

3.25.4.2 Open the following:

• 1CF-22 (B S/G CF Cntrl Inlet Isol)

• 1CF-24 (B SIG CF Cntrl Outlet Isol)

El 3.25.4.3 Check 1CF-1O5AB (lB S/G CF Control Bypass) output less than 65%.

3.25.4.4 Place 1CF-23AB (lB S/G CF Control) in auto.

3.25.5 For C SIG, perform the following:

3.25.5.1 Ensure 1CF-2OAB (1C S/G CF Control) in manual and closed.

3.25.5.2 Open the following:

• 1CF-19 (C SIG CF Cntrl Inlet Isol)

• 1CF-21 (C SIG CF Cntrl Outlet Isol)

El 3.25.5.3 Check 1CF-1O6AB (1C S/G CF Control Bypass) output less than 65%.

3.25.5.4 Place 1CF-2OAB (1C SIG CF Control) in auto.

3.25.6 For D S/G, perform the following:

3.25.6.1 Ensure 1CF-17AB (1D S/G CF Control) in manual and closed.

3.25.6.2 Open the following:

• 1CF-16 (D S/G CF Cntrl Inlet Iso!)

• 1 CF- 18 (D S/G CF Cntrl Outlet Iso!

El 3.25.6.3 Check 1CF-1O7AB (1D S/G CF Control Bypass) output less than 65%.

3.25.6.4 Place 1CF-17AB (1D SIG CF Control) in auto.

Unit 1

Enclosure 4.1 OPI1IA/61001003 Power Increase Page 15 of 45 0 3.26 Increase Rx Power to 8% RTP (8.0 8.5%).

3.27 WHEN at 8% RTP (8.0 8.5%), perform the following:

3.27.1 HOLD at 8% RTP (8.0 8.5%) for a minimum of 10 minutes.

3.27.2 Notify Secondary Chemistry to verify secondary water chemistry acceptable for operation greater than 15% RTP.

Person Notified Date Time 0 3.27.3 Place BB Pump in service per OP/1/A16250/008 (Steam Generator Blowdown).

3.27.4 jj required for S/G cleanup, adjust the following while maintaining NC System temperature:

• 1BB-123 (A S/G BB Flow Control)

• 1BB-124 (B SIG BB Flow Control)

• 1BB-125 (C SIG BB Flow Control)

• 1BB-126 (D S/G BB Flow Control)

Unit 1

Enclosure 4.1 OP/11A161001003 Power Increase Page 16 of 45 3.28 Increase Reactor Power to 10 - 12% RTP as follows:

Li 3.28.1 Begin power increase to 10 - 12% RTP.

3.28.2 WhEN Reactor Power reaches 10% RTP, perform the following:

3.28.2.1 Check on 1SI-18:

Li P-lO Nuclear at Power lit Li P-7 Lo Power Reactor Trips Blocked dark 3.28.2.2 Block the IR high level trip and rod stop by depressing both Intermediate Range B lock pushbuttons.

3.28.2.3 Check lit on 1SI-18:

Li hR Train A Trip Blocked Li hR Train B Trip Blocked 3.28.2.4 Block PR low setpoint trip by depressing both Power Range Block pushbuttons.

3.28.2.5 Check lit on 1SI-18:

Li P/R Lo Setpoint Train A Trip Blocked Li PIR Lo Setpoint Train B Trip Blocked 3.28.3 IF required for lAB to tune Process Control Systems, perform the following:

3.28.3.1 HOLD at 10 12% RTP.

Li 3.28.3.2 Allow IAE to gather data on Process Control Systems.

3.28.3.3 WHEN IAE data gathering and tuning complete, continue power increase.

3.29 Increase Reactor Power to 12 - 18% RTP as follows:

Li 3.29.1 Begin power increase to 12- 15% RTP.

3.29.2 HOLD until Reactor Power is 12 15% RTP.

3.29.3 Ensure proper secondary water chemistry for operation greater than 15% RTP.

CHEM Li 3.29.4 Begin power increase to 18% RTP.

Li 3.29.5 Maintain 12 - 18% RTP.

Unit 1

Enclosure 4.1 QP/l/A/6100/003 Power Increase Page 17 of 45 NOTE: TV/GV hot calibration was NOT started in OP/1/A/6100/SU-19 (Heatup to 557 Degrees F), the following step restores LH to Throttle Valves.

3.29.6 IF TV/GV hot calibration NOT complete, notify IAE to begin/resume performing TV/GV hot calibration.

Person Notified Date Time LI 3.29.7 Reset Main Turbine per OPI1/A/6300/OO1 (Turbine Generator Startup/Shutdown).

NOTE: Steps 3.29.8 - 3.29.10 may be performed in any order or concuffently.

3.29.8 Calibrate Power Range NIS channels to maintain Power Mismatch (NIs vs BETP) +/- 1% for each Power Range channel.

3.29.9 IF required for IAE to tune Process Control Systems, HOLD at 12 - 18%

RTP until IAE gathers data on Process Control Systems.

LI 3.29.10 Roll Main Turbine to 1800 rpm per OP/1/A16300/001 (Turbine Generator Startup/Shutdown).

NOTE: Engineering will determine if PT/1/A14250/004 C (Turbine OPC and Mechanical Overspeed Trip Test) is to be performed with Turbine Generator at 1800 rpm or at greater than 112MWE.

3.29.11 Notify Engineering to determine if and when PT/i /A/4250/004 C (Turbine OPC and Mechanical Overspeed Trip Test) will be performed.

Person Notified Date Time Unit 1

Enclosure 4.1 OP/l/A/6looIoo3 Power Increase Page 18 of 45 3.29.12 j PT/1/A14250/004 C (Turbine OPC and Mechanical Overspeed Trip Test) will be performed with Turbine Generator at 1800 rpm, complete the following:

El 3.29.12.1 Maintain 12-18%RTP.

El 3.29.12.2 Perform PTI1/A14250/004 C (Turbine OPC and Mechanical Overspeed Trip Test).

3.29.12.3 WhEN PT/1/A!4250/004 C (Turbine OPC and Mechanical Overspeed Trip Test) complete, perform TV/GV Transfer and place Voltage Regulator in service per OP/1/A/6300/00i (Turbine Generator Startup/Shutdown).

3.29.13 performing Generator / Automatic Voltage Regulator (AVR) testing, complete the following:

3.29.13.1 IF performed, HOLD until Step 3.29.12 complete.

3.29.13.2 Ensure TV/GV Transfer complete and Voltage Regulator placed in service per OP/1/A/6300/001 (Turbine Generator Startup/Shutdown).

3.29.13.3 HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.29.14 IF required to perform Main Generator Flux Mapping, notity Maintenance Main Generator Team to perform mapping.

/

Person Notified Date Time 3.29.15 HOLD until Step 3.29.13 complete.

3.29.16 Ensure TV/GV Transfer complete and Voltage Regulator placed in service per OP/i /A/6300/00 1 (Turbine Generator Startup/Shutdown).

El 3.29.17 Close Generator MODs per OP/i/A/6300/001 (Turbine Generator Startup/Shutdown).

El 3.29.18 Synchronize Generator and load Generator to 120 MWE per OP/i /A/6300/00 1 (Turbine Generator Startup/Shutdown).

Unit 1

Enclosure 4.1 QP/l/A/6100/003 Power Increase Page 19 of 45 3.29.19 WHEN Main Generator Breakers closed, record the following values and notify System Engineer:

LI 1A Main Generator Breaker Air Compressor Pilot Valve Counter LI 1 B Main Generator Breaker Air Compressor Pilot Valve Counter LI Date/Time 1A Main Generator Breaker Closed I U Date/Time lB Main Generator Breaker Closed I Person Notified Date Time 3.29.20 IF performing Generator! Automatic Voltage Regulator (AVR) testing on line at 15% RTP, HOLD until Generator! AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power Increase Page 20 of 45 NOTE:

• IF Turbine Generator holds for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> at 112 MWE for PT/i /A14250/004 C (Turbine OPC and Mechanical Overspeed Trip Test), Reactor Core Flux Mapping may be performed during the hold.

• IF Turbine Generator holds for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> at 112 MWE for PT/i /A14250/004 C (Turbine OPC and Mechanical Overspeed Trip Test), Generator / Automatic Voltage Regulator (AVR) testing may be performed during the hold.

3.29.21 PT/i/A/4250/004 C (Turbine OPC and Mechanical Overspeed Trip Test) to be performed following load increase to greater than 112 MWe, perform the following:

El 3.29.21.1 Maintain 12i8%RTP.

3.29.21.2 performing Generator / Automatic Voltage Regulator (AVR) testing, HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.29.21.3 IF required to perform 15% RTP Reactor Core Flux Mapping during 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> hold at greater than 112 MWE, perform flux mapping.

3.29.21.4 j required to perform Main Generator Flux Mapping, notity Maintenance Main Generator Team to perform mapping.

Person Notified Date Time 3.29.21.5 HOLD until Steps 3.29.21.2 and 3.29.21.3 complete.

El 3.29.21.6 Shutdown Generator per OP/i /A/6300/00 1 (Turbine Generator Startup/Shutdown).

El 3.29.21.7 Perform PT/1/A/4250/004 C (Turbine OPC and Mechanical Overspeed Trip Test).

El 3.29.2 1.8 Startup Turbine and parallel Generator per OP/i /A/6300/00 1 (Turbine Generator Startup/Shutdown).

Unit 1

Enclosure 4.1 0P/1/A/6100/003 Power Increase Page 21 of 45 3.29.22 WhEN steam dumps close, perform the following:

3.29.22.1 IF C-7A Loss of Load Intlk Cond Dump on 1SI-18 lit, perform the following:

A. Momentarily place Steam Dump Select to C-7A Reset.

LI B. Check C-7A Loss of Load Intlk Cond Dump dark.

3.29.22.2 Place Steam Dump Select to T-AVG.

3.29.22.3 Place STM PRESS CONTROLLER to auto.

3.29.22.4 Set STM PRESS CONTROLLER setpoint at 1092 psig (1090- 1095).

3.29.23 Perform the following:

3.29.23.1 Monitor the following while opening iSP-i (SM to CF Pump 1A Iso!) and 1SP-2 (SM to CF Pump lB Iso!): (PIP 09-6340)

LI M1A0723 (Ui H/P Steam to 1A CFPT Press)

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

NOTE: iSP-i (SM to CF Pump 1A Isol) and 1SP-2 (SM to CF Pump lB Isol) are physically located such that verifying the position is difficult. ( PIP 09-6340 3.29.23.2 Open:

• iSP-i (SM to CFPump lAIsol) cv

• 1SP-2 (SM to CF Pump lB Isol) cv 3.29.23.3 Check the following for corresponding increase in steam pressure with iSP-i (SM to CF Pump 1A Isol) and 1SP-2 (SM to CF Pump lB Iso!) open: (PIP 09-6340)

LI M1A0723 (Ui HIP Steam to 1A CFPT Press)

LI M1A0729 (Ui HIP Steam to lB CFPT Press)

LI 3.29.24 Check operating CF Pump greater than 3600 rpm and in auto per OP/i /A/6250/00 1 (Condensate and Feedwater System).

Unit 1

___________ _________/_________

Enclosure 4.1 OP/1/A/6100/003 Power Increase Page 22 of 45 3.29 .25 15% RTP Reactor Core Flux Map performed, notify Nuclear Engineering to perform the following:

El 3.29.25.1 Evaluate flux mapping data.

0 3.29.25.2 Determine allowed power increase.

El 3.29.25.3 Record limiting power level per Nuclear Engineering procedure:

%RTP Person Notified Date Time 3.29.26 Ensure TV/GV hot calibrations complete (Step 3.29.6).

IAE 3.29.27 HOLD at 12 - 18% RTP until Step 3.29.25 completed.

3.29 .28 Complete Enclosure 4.8 (Guidelines For Power Increase).

SRO Unit 1

Enclosure 4.1 OP/l/A/6 100/003 Power In crease Page 23 of 45 3.30 Increase Reactor Power to 30% RTP as follows:

3.30.1 Notify IAE to stand by for periodic adjustments of Power Range NI channels.

c*ck C1Vc\ \On /__

Person Iified Date Time 3.30.2 IF AT ANY TIME Power Mismatch % (Excore/Thermal Power Mismatch) indicates greater than 4% during power increase, perform the following:

U 3.30.2.1 Stop power increase.

3.30.2.2 Have IAE calibrate each Power Range NI Channel to +/-1% Power Mismatch (NIs vs BETP).

3.30.2.3 WHEN calibration complete, continue with power increase.

U 3.30.3 Begin power increase to 30% RTP.

U 3.30.4 Load turbine per OP/1/A/6300/001 A (Turbine-Generator Load Change).

NOTE: IF OAC out of service, monitoring 1A and lB XFMR Oil Temps may be performed at local gauges.

3.30.5 WHEN M1A0913 (1A XFMR Oil Temp) indicates greater than 45°C, ensure cooling groups energized on 1A Main Transformer:

• Circuit 1

• Circuit 2

• Circuit 3

• Circuit 4

• Circuit 5

• Circuit 6

• Circuit 7

• Circuit 8 Unit 1

Enclosure 4.1 OP/1/A/6 100/003 Power Increase Page 24 of 45 3.3 0.6 WREN M1A0925 (lB XFMR Oil Temp) indicates greater than 45°C, ensure cooling groups energized on lB Main Transformer:

• Circuit 1

• Circuit 2

• Circuit 3

• Circuit 4

• Circuit 5

• Circuit 6

• Circuit 7

• Circuit 8 3.30.7 Place Exh Hood Spray in MAN.

3.30.8 WHEN C-5 Lo Turb Impulse Press Rod Block dark, CRD Bank Select may be placed in AUTO.

3.30.9 WHEN Turbine limp Press greater than 75 psig, check P-13 Turbine Not At Power dark. (1SI-18) 3.30.10 Prior to 20% RTP, ensure Main Feedwater flow to all S/Os through CF nozzles per OP/1/A/6250/001 (Condensate and Feedwater System).

Unit 1

Enclosure 4.1 OP/l/A/61001003 Power Increase Page 25 of 45 NOTE:

• At approximately 18% CF flow, each S/G will transition from LOW POWER mode to HIGH POWER mode.

• SIG HIGH POWER mode includes validated steam flow, validated feedwater flow, validated N/R level, and N/R level setpoint to calculate the feedwater flow demand for that SIG.

• CF Flow, in percent flow, is indicated on DCS Feedwater Overview Graphic for all four SIGs.

3.30.11 AFTER exceeding 18% CF flow, check each S/G in HIGH POWER mode as follows:

El 3.30.11.1 On DCS Workstation, select Steam Generator A Level graphic El 3.30.11.2 On Steam Generator A Level graphic, check HIGH POWER lit.

El 3.30.11.3 On DCS Workstation, select Steam Generator B Level graphic El 3.30.11.4 On Steam Generator B Level graphib, check HIGH POWER lit.

El 3.30.11.5 On DCS Workstation, select Steam Generator C Level graphic El 3.30.11.6 On Steam Generator C Level graphic, check HIGH POWER lit.

El 3.30.11.7 On DCS Workstation, select Steam Generator D Level graphic El 3.30.11.8 On Steam Generator D Level graphic, check HIGH POWER lit.

3.30.12 Ensure BB Pump in service per OP/1/A/6250/008 (Steam Generator Blowdown).

3.30.13 Initiate maximum BB flow for S/G cleanup while maintaining NC System temperature by throttling the following:

• 1BB-123 (A S/G BB Flow Control)

• 1BB-124 (B S/G BB Flow Control)

• 1BB-125 (C S/G BB Flow Control)

• 1BB-126 (D S/G BB Flow Control)

El 3.30.14 Adjust letdown to desired flow per OP/1/A/6200/001 A (Chemical and Volume Control System Letdown).

Unit 1

Enclosure 4.1 oP/l/A/6100/o03 Power Increase Page 26 of 45 CAUTION: j lAS-li (SM to AS Header Control) is to supply AS Header, anticipate an increase in Reactor Power or a decrease in NC System temperature when opening lAS- 12 (SM to AS).

3.30.15 Align AS as follows:

3.30.15.1 Slowly open 1AS-12 (Main Steam to Aux Steam).

3.30.15.2 Open 1AS-9 (C Htr Bleed to Aux Steam).

3.30.15.3 j Aux Electric Boilers no longer required, perform following:

A. Close 1AS-120 (Aux Elec Blr A & B to AS Isol).

LI B. Shutdown Aux Electric Boilers per OP/1/B/6250/007 B (Auxiliary Electric Boiler).

NOTE: Steam Seal Supply should remain on AS for improved efficiency.

3.30.16 IF conditions require, transfer Steam Seal Supply to SM as follows:

3.30.16.1 Slowly open 1TL-3 (SM to Steam Seal Isol).

3.30.16.2 Close 1TL-21 (AS to Steam Seal Isol).

3.30.17 WHEN Turbine impulse pressure is greater than 200 psig:

3.30.17.1 Ensure Turb Drn Vlvs Cntrl in AUTO.

LI 3.30.17.2 Check all turbine drain valves closed.

3.30.18 Ensure second Hotwell Pump operating.

3.30.19 Ensure standby Hotwell Pump in AUTO.

3.30.20 Ensure second CM Booster Pump operating.

3.30.21 Ensure standby CM Booster Pump in AUTO.

LI 3.30.22 Close valves per OP/1/B/6250/004 (Feedwater Heater Vents, Drains and Bleed System), Enclosure 4.4 (Startup Vent Valve Checklist).

Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power Increase Page 27 of 45 NOTE:

• At approximately 30% steam flow, all S/G CF Bypass Valves will go closed and S/G level will be controlled by S/G CF Valves and CF Pump Turbine speed demand.

SM Flow, in percent flow, is indicated on DCS Feedwater Overview Graphic for all four S!Gs.

3.30.23 At greater than 30% steam flow from each S!G, check the following valves in auto and closed:

LI 1CF-1O4AB (1A S/G CF Contrl Bypass)

LI 1CF-1O5AB (lB S/G CF Contri Bypass)

LI 1CF-1O6AB (1C S!G CF Contri Bypass)

LI 1CF-1O7AB (1D S/G CF Contri Bypass)

LI 3.30.24 Check S!G levels stable and at program for current power level.

3.30.25 HOLD at 30% RTP and concurrently perform the following:

3.30.25.1 j required to tune Process Control Systems, perform the IAE following:

A. HOLDat3O%RTP LI B. Allow IAE to gather data on Process Control Systems.

3.30.25.2 IF performing Generator! Automatic Voltage Regulator (AVR) testing at 30% RTP, HOLD until Generator! AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.30.25.3 IF 30% RTP Reactor Core Flux Map to be performed, notify Nuclear Engineering to perform the following:

LI A. Perform flux mapping.

LI B. Evaluate flux mapping data.

LI C. Determine allowed power increase.

LI D. Record limiting power level per Nuclear Engineering procedure:  % RTP Person Notified Date Time Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power Increase Page 28 of 45 3.31 Increase power to 50% RTP as follows:

3.31.1 Notify Secondary Chemistry to verify secondary water chemistry acceptable for operation greater than 50% RTP Person Notified Date Time El 3.3 1.2 Maintain control rods within insertion and withdrawal limits per COLR.

NOTE: Maintaining AFD within Nuclear Engineering recommended limits prevents AFD exceeding Tech Spec Limits (Limit and Precaution 1.8).

El 3.31.3 Maintain AFD within target band per OP/1/A161001022 (Unit 1 Data Book),

Enclosure 4.3, Graph(s) 1.1.

3.31.4 IF initial startup following refueling outage, check Bank D Control Rods greater than or equal to 200 steps withdrawn.

3.31.5 Notify IAE to stand by for periodic adjustments of Power Range NI channels.

Person Notified Date Time 3.31.6 IF AT ANY TIME Power Mismatch % (Excore/Thermal Power Mismatch) indicates greater than 4% during power increase, perform the following:

El 3.31.6.1 Stop power increase.

3.3 1.6.2 Have IAE calibrate each Power Range NI Channel to +/-1% Power Mismatch (NIs vs BETP).

3.31.6.3 WHEN calibration complete, continue with power increase.

El 3.3 1.7 Begin power increase to 50% RTP.

El 3.31.8 Maintain one pen selected to PR channel on Nuclear Power (%) recorder.

(1 ENB CR9450)

El 3.3 1.9 Maintain other pen as desired on Nuclear Power (%) recorder.

(1 ENB CR9450)

Unit 1

Enclosure 4.1 OP/1/A/6 100/003 Power Increase Page 29 of 45 NOTE: To prevent tripping BB Pump on low BB Tank level, 1BB-238 (SIG BB Demineralizers) and 1BB-44 (Blowdown Blowoff Recirc Control) must be allowed time to reposition while positioning flow control valves in substeps of 3.3 1.10.

3.31.10 WhEN plant conditions permit, swap Blowdown Blowoff Tank Vent from the Condenser to D Heater Extraction as follows:

El 3.31.10.1 Record the following:

El 1BB-123 (A S/G BB Flow Control)________ lbs rnfhr El 1BB-124 (B S/G BB Flow Control) lbs rn/hr El 1BB-125 (C S/G BB Flow Control) lbs rnlhr El 1BB-126 (D S/G BB Flow Control)________ lbs ni/hr 3.3 1.10.2 Throttle the following to minimum flow (20007000 lbs m/hr) over 15 minutes:

• 1BB-123 (A S/G BB Flow Control)

• 1BB-124 (B S/G BB Flow Control)

• 1BB-125 (C S/G BB Flow Control)

• 1BB-126 (D S/G BB Flow Control) 3.3 1.10.3 Place 1BB-98 & 100 BB Tank Vent D Htr/Cond to D HTR.

El 3.3 1.10.4 Check open 1BB-98 (Blowdown Blowoff Tank Vent to D Heater Extraction Isol).

El 3.3 1.10.5 Check closed 1BB-100 (Blowdown Blowoff Tank Vent to Condenser).

3.31.10.6 Throttle the following to positions recorded in Step 3.31.10.1 or as directed by Secondary Chemistry over 15 minutes:

• 1BB-123 (A SIG BB Flow Control)

• 1BB-124 (B S/G BB Flow Control)

• 1BB-125 (C S/G BB Flow Control)

• 1BB-126 (D S/G BB Flow Control)

Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power In crease Page 30 of 45 NOTE: Power increase may continue while performing Step 3.31.11.

3.31.11 WhEN 35% RTP, transfer to GV Sequential Valve Mode as follows:

3.31.11.1 Ensure MW OUT lit.

3.31.11.2 EnsureIMPJN lit.

3.31.11.3 Depress STNGLE/SEQUENTIAL.

NOTE:

• A digital clock will appear on the DEH OIU Graphic 200 and indicate the amount of time left in the Single Valve / Sequential Valve Transfer.

Speed Loop will be automatically removed from service at intiation of transfer and will be automatically placed back in service following transfer.

3.31.11.4 Depress START/HALT to begin transfer.

3.31.11.5 Ensure SPEED OUT lit.

3.3 1.11.6 WHEN transfer is complete, perform the following:

A. Ensure SPEED IN lit.

B. Place Turbine in MANUAL.

C. Ensure IMP OUT lit.

D. Place Turbine in OPERATOR AUTO.

E. Select MW IN.

3.3 1.12 Ensure the following valves greater than 25% open and controlling S/G levels at program level:

• 1CF-32AB (1A S/G CF Control)

• 1CF-23AB (lB S/G CF Control)

• 1CF-2OAB (1C S/G CF Control)

• 1 CF-i 7AB (1 D S/G CF Control)

LI 3.31.13 Adjust Turbine load per OP/1/A16300/001 A (Turbine-Generator Load Change).

Unit 1

Enclosure 4.1 OP/l/A/6100/003 Power In crease Page 31 of 45 3.31.14 Perform the following to start the third Hotwell Pump:

3.31.14.1 Notify Secondary Chemistry of the following:

• Third Hotwell Pump is about to be started

• Check Polishing Demineralizers bypassed or isolated (PIP M99-2044}

• Monitor Polishing Demineralizers for signs of pressure induced damage after Hotwell Pump start (PIP M99-1828}

Person Notified Date Time U 3.31.14.2 Place third Hotwell Pump in service per OPI1/A/6250/001 (Condensate and Feedwater System).

NOTE: AMSAC will automatically UNBLOCK when Turbine Impulse Pressure increases to 290 psig.

3.3 1.15 Prior to 40% Turbine load (290 psig Impulse Pressure), check all AMSAC S/G Low Flow status lights dark. (1SI-4) 3.31.16 WHEN Turbine load greater than 40% (290 psig Impulse Pressure), begin aligning MSRs per OPI1/B/6250/01 1 (Moisture Separator Reheater Operation).

3.31.17 WHEN Turbine Impulse Pressure 295 305 psig, check AMSAC ACTUATION BLOCK/UNBLOCK as follows:

3.3 1.17.1 IF UNBLOCK dark, reset as follows:

U A. Check all AMSAC S/G LOW FLOW status lights dark.

El B. Check S/G PATH CLSD >30 SEC dark.

C. Depress UNBLOCK for AMSAC ACTUATION BLOCK/UNBLOCK.

U 3.3 1.17.2 Check UNBLOCK lit.

Unit 1

Enclosure 4.1 0PI1IAI6100I003 Power Increase Page 32 of 45 3.31.18 WhEN 40% RTP, perform the following:

NOTE: Steps 3.31.18.1 and 3.31.18.2 can be pefformed concurrently.

3.3 1.18.1 Notify RP to adjust setpoints for the following: (PIP 99-5073)

• 1EMF.-71 (SIG A Leakage Hi Rad)

• 1EMF-72 (SIG B Leakage Hi Rad)

• 1EMF-73 (SIG C Leakage Hi Rad)

• 1EMF-74 (SIG D Leakage Hi Rad)

Person Notified Date Time 3.3 1.18.2 IF 1HM-95 (AS to A & B CF Pumps) is open, close by concurrently performing the following:

LI A. Check operating CF Pump in auto.

B. Monitor OAC Graphic for operating CF Pump:

Li 1A CF PUMP DETAIL LI lB CF PUMP DETAIL C. On operating CF Pump Turbine, monitor LP GOV CNTRLand HP GOV CNTRL positions.

NOTE:

• 1HM-95 will almost be closed before an effect is seen. (approximately 90% closed)

• On operating CF Pump, LP Gov. demand will be 100% before HP Gov begins to open.

D. Slowly pulse 1HM-95 (AS to A & B CF Pumps) closed. (R.M.)

E. Monitor the following on CF Pump graphic:

LI LP Gov position LI HP Gov position LI Decrease in LP Steam Supply Pressure Unit 1

Enclosure 4.1 oP/l/A/6100/o03 Power Increase Page 33 of 45 F. IF any of the following occur, perform the following:

• Operating CF Pump speed decreases

• Operating CF Pump discharge pressure decrease

1. Stop closing 1HM-95.

2. Place operating CF Pump Turbine LP GOV CNTRL and HP GOV CNTRL in manual.

LI 3. Stabilize operating CF Pump speed / discharge pressure.

4. Continue to close 1HM-95 while maintaining operating CF Pump speed / discharge pressure.

5. WHEN 1HM-95 closed, place operating CF Pump governors in auto per OP/1/A/6250/001 (Condensate and Feedwater System).

CAUTION: Generator / Automatic Voltage Regulator (AVR) testing must be performed prior to reactor power exceeding permissive P-8.

3.31.19 performing Generator / Automatic Voltage Regulator (AVR) testing at 45% RTP, perform the following:

3.31.19.1 HOLD at 45% RTP until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.31.19.2 WHEN Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup, begin power increase to 50% RTP.

3.31.20 performing Generator Reactive Limits Verification testing at 45 50% RTP, perform the following:

LI 3.31.20.1 Perform applicable sections of PT/1/B/4350/001 C (Generator Reactive Limits Verification Test).

3.3120.2 HOLD until Testing Personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

Unit 1

Enclosure 4.1 OP/l/A./6 1001003 Power Increase Page 34 of 45 NOTE: Steps 3.3 1.21 and 3.31.22 may be performed concurrently as long as conditions for both steps are met. {PIP 08-2768) 3.3 1.21 WhEN 48 56% RTP, place second CF Pump in service as follows:

LI 3.3 1.21.1 Maintain constant Reactor Power.

U 3.31.21.2 Check CF Pump supplying CF Header in auto.

El 3.31.21.3 Start second CF Pump per OP!1/A/6250/001 (Condensate and Feedwater System), Enclosure 4.17 (CF Pump Reset! Startup),

Section 3.4 (1A CF Pump Startup) or Section 3.5 (lB CF Pump Startup).

3.31 .2 1.4 WHEN CF Pump operation stabilized, continue power increase.

CAUTION: Reactor Power ramp rate is limited by Fuel Maneurvering Limits (Data Book Section 1.3). The recommended load rate for unconditioned fuel above 50% power is 3% / hour, but shall never exceed 4% / hour, 7% / 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, 10% / 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> or a 3% step change. {PIP 08-27681 3.31.22 Prior to 50% RTP, perform the following concurrently:

3.31.22.1 Ensure proper secondary water chemistry for operation greater CHM than 50% RTP.

El 3.31.22.2 Evaluate air ejector off gas and nozzle operation per OP/1/B/6300/006 (Main Vacuum and Vacuum Priming System).

El 3.3 1.22.3 Record highest value:

o 1A Main Generator Breaker Air Compressor Pilot Valve Counter

• lB Main Generator Breaker Air Compressor Pilot Valve Counter

• Date/Time of counter readings 3.3 1.22.4 Notify System Engineer to calculate Main Generator Breaker air leakage using counter readings from Step 3.29.19 and Step 3.3 1.22.3.

Person Notified Date Time Unit 1

Enclosure 4.1 OP/l/A/6loo/oo3 Power In crease Page 35 of 45 3.3 1.22.5 Notify TCC (Transmission Control Center) (382-9401 or 382-9402) to check amperage output balanced on both busses to switchyard.

I Person Notified Date Time NOTE: Maintaining AFD within Nuclear Engineering recommended limits prevents AFD exceeding Tech Spec Limits (Limit and Precaution 1.8).

LI 3.3 1.22.6 Maintain AFD within target band per OP/1/A16100/022 (Unit 1 Data Book), Enclosure 4.3, Graph(s) 1.1.

3.31.22.7 j Power Range detectors have been replaced AND startup is IAE NOT an Initial Cycle Startup, check the following:

LI New detector current data inserted LI Power Range High Flux (High Range) setpoints at 109%

3.3 1.22.8 IF Initial Cycle Startup, perform the following:

A. Notify Reactor Engineering to determine if Power Range NI calibration is required prior to 50% RTP.

Person Notified Date Time B. IF Power Range NI calibration is required prior to 50% RTP, perform the following:

LI 1. Stop power increase.

2. Have IAE calibrate desired Power Range NI Channel(s).

3. WHEN calibration complete, continue power increase.

NOTE: Quadrant Power Tilt Ratio (QPTR) is NOT applicable until calibration of the Power Range NIs is completed subsequent to refueling. (TS 3.2.4)

C. Check QPTR less than or equal to 1.02.

3.31.22.9 IF NOT Initial Cycle Startup, check QPTR less than or equal to 1.02.

LI 3.31.22.10 Check P-8 Hi Pwr Lo Flo Reactor Trip Blocked dark. (1SI-18)

Unit 1

Enclosure 4.1 OPI1IAI6100/003 Power In crease Page 36 of 45 3.32 Increase power to 95% RTP as follows:

U 3.32.1 Maintain control rods within insertion and withdrawal limits per COLR.

NOTE: Maintaining AFD within Nuclear Engineering recommended limits prevents AFD exceeding Tech Spec Limits (Limit and Precaution 1.8).

U 3.32.2 Maintain AFD within target band per OP/1/A/6100/022 (Unit 1 Data Book),

Enclosure 4.3, Graph(s) 1.1.

3.32.3 Notify IAE to stand by for periodic adjustments of Power Range NI channels.

Person Notified Date Time 3.32.4 IF AT ANY TIME Power Mismatch % (Excore/Thermal Power Mismatch) indicates greater than 4% during power increase, perform the following:

LI 3.32.4.1 Stop power increase.

3.32.4.2 Have IAE calibrate each Power Range NI Channel to +/-1% Power Mismatch (NIs vs BETP).

3.32.4.3 WHEN calibration complete, continue power increase.

U 3.32.5 Begin power increase to 95% RTP 3.3 2.6 Prior to exceeding 56% Main Turbine power, perform the following:

3.32.6.1 Notify System Engineer to determine if Main Generator Breakers air leakage has been calculated, based on Engineering review.

Person Notified Date Time 3.32.6.2 System Engineer desires cycling 1A Main Generator Breaker, perform the following:

A. Ensure Main Turbine power less than 56%.

LI B. Maintain Main Turbine power less than 56%.

C. Open 1A Main Generator Breaker.

D. Close 1A Main Generator Breaker.

Unit 1

Enclosure 4.1 OP/11A161001003 Power Increase Page 37 of 45 3.32.6.3 IF System Engineer desires cycling lB Main Generator Breaker, perform the following:

A. Ensure Main Turbine power less than 56%.

El B. Maintain Main Turbine power less than 56%.

C. Open 1 B Main Generator Breaker.

D. Close lB Main Generator Breaker.

3.32.7 At 70% RTP or as directed by Secondary Chemistry, perform the following:

El 3.32.7.1 Begin placing C HDT Pumps in service per OPI1/B/62501004 (Feedwater Heater Vents, Drains, and Bleed System).

3.32.7.2 WHEN C HDT Pumps are in service, stop one Hotwell Pump per OP/1/A/6250/001 (Condensate and Feedwater System).

3.32.8 At 77-80% RTP, enable OTDT DCS alarming as follows:

El 3.32.8.1 On DCS graphics, select MAINTENANCE MENU.

El 3.32.8.2 Select TAVG, DELTA T INPUTS & ALARM CHECKING graphic.

3.32.8.3 Select ON for the following:

El NCAA 5422 El NCAA 5462 El NCAA 5502 El NCAA 5542 El OTDELTAT-FAIL Unit 1

Enclosure 4.1 OP/l/A/6loo/0o3 Power Increase Page 38 of 45 3.32.9 IF initial startup, perform the following:

3.32.9.1 Notify Nuclear Engineering to evaluate power increase to 78% RTP.

Person Notified Date Time El 3.32.9.2 Record limiting power level per Nuclear Engineering procedure:

%RTP El 3.32.9.3 Begin power increase to desired power level.

3.32.9.4 HOLD at desired power level until Reactor Core Flux Mapping completed.

3.32.9.5 Notify Nuclear Engineering to evaluate allowed power increase.

Person Notified Date Time El 3.32.9.6 Record desired power level.  % RTP 3.32.10 IF performing Generator I Automatic Voltage Regulator (AVR) testing at 78% RTP, HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

El 3.32.11 Continue power increase to 95% RTP.

Unit 1

Enclosure 4.1 oP/l/A/6loo/oo3 Power Increase Page 39 of 45 CAUTION: iF CF Feed Reg Valves modulate less than 25%, potential exists to activate AMSAC.

Power increase may continue at OSMs discretion.

NOTE:

• At approximately 85% steam flow from each SIG, all SIG CF Bypass valves will ramp open (approximately 2 minute ramp) to 100% open position. SIG CF Valves will modulate to control SIG level.

S/G SM Flow, in percent, can be monitored on DCS Feedwater Overview Graphic for all four S/Gs.

3.32.12 At greater than 85% steam flow from each S/G, ensure the following valves in auto and open:

• 1CF-1O4AB (1A S/G CF Cntrl Vlv Bypass)

• 1CF-1O5AB (lB S/G CF Cntrl Vlv Bypass)

• 1CF-1O6AB (1C S/G CF Cntrl Vlv Bypass)

• ICF-1O7AB (1D S/G CF Cntrl Vlv Bypass) 3.32.13 WHEN at 976 MWE, check AS supply transferred from SM to C Heater Bleed by checking lAS-il (SM Supply to Aux Steam Control) closed.

3.32.14 IF lAS-i 1 failed to close, coordinate with SRO to establish required setpoint on 1 AS- 11 controller to allow valve to close.

3.32.15 WHEN 85% RTP, place G Htr Drn Tank Pumps in service per OP/i/B/6250/004 (Feedwater Heater Vents, Drains, and Bleed System).

Unit 1

Enclosure 4.1 oP/1IA/61001003 Power Increase Page 40 of 45 3.32.16 j startup is from a trip, shutdown, or load reduction to less than 90% RTP, perform the following:

3.32.16.1 HOLD at 90% RTP.

3.32.16.2 Notify Nuclear Engineering to evaluate performing PT/0/A/41 50/006 (Thermal Power Output Calculation).

Person Notified Date Time 3.32.16.3 IF performing Generator / Automatic Voltage Regulator (AVR) testing at 90% RTP, HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.32.17 Notify IAE to stand by for periodic adjustments of Power Range NI channels.

Person Notified Date Time NOTE: Step 3.3 1.19 is applicable for operation greater than 90% RTP.

3.32.18 IF AT ANY TIME Power Mismatch  % (Excore/Thermal Power Mismatch) indicates greater than 1.5% during power increase, perform the following:

Li 3.32.18.1 Stop power increase.

CAUTION: Allowing NC System temperature to change while calibrating NIs can result in a non-conservative adjustment which can result in exceeding 100% RTP.

(PIP 03-2117}

Li 3.32.18.2 Maintain steady state power and temperature.

3.32.18.3 Have IAE calibrate each Power Range NI Channel to +/-1% Power Mismatch (NIs vs BETP).

3.32.18.4 WHEN calibration complete, continue power increase.

Unit 1

Enclosure 4.1 OPI1/A161001003 Power Increase Page 41 of 45 NOTE: Nuclear Engineering may perform PT101A141501003 (Thermal Power Output Measurement) between 85 95% RTP.

3.32.19 IF startup is from a refueling outage, perform the following:

3.32.19.1 HOLD at 95% RTP.

3.32.19.2 Ensure PT/O/A/4150/003 (Thermal Power Output Measurement)

RX ENG completed.

3.32.19.3 IF performing Generator / Automatic Voltage Regulator (AVR) testing at 95% RTP, HOLD until Generator / AVR personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

3.32.20 Notify Maintenance to remove Limited Access signs used for startup per Model Work Order 0433323.

Person Notified Date Time Unit 1

Enclosure 4.1 oP/lIAI6looIoo3 Power Increase Page 42 of 45 3.32.21 WHEN 95% RTP, perform the following:

3.32.21.1 Ensure cooling groups energized on 1A Main Transformer:

• Circuit 1

• Circuit 2

• Circuit 3

• Circuit 4

• Circuit 5

• Circuit 6

• Circuit 7

• Circuit 8 3.32.21.2 Ensure cooling groups energized on lB Main Transformer:

• Circuit I

• Circuit 2

• Circuit 3

• Circuit 4

• Circuit 5

• Circuit 6

• Circuit 7

• Circuit 8 Unit 1

Enclosure 4.1 0P111A161001003 Power Increase Page 43 of 45 3.33 Increase power to 100% RTP as follows:

1f 3.33.1 Begin power increase to 100% RTP.

3.33.2 IF AT ANY TIME 1AD-6, E10 (Loop D/T Deviation) is received, perform the following:

3.33.2.1 Notify Reactor Engineering to evaluate.

Person Notified Date Time 3.33.2.2 Determine impact on power escalation.

CRS 3.33.2.3 IF power escalation CANNOT commence due to alarms, notify IAE to calibrate DJT channels.

I Person Notified Date Time C 3.33.3 Maintain control rods within insertion and withdrawal limits per COLR.

NOTE: Maintaining A within Nuclear Engineering recommended limits prevents AFD exceeding Tech Spec Limits (Limit and Precaution 1.8).

[

C 3.33.4 Maintain AFD within target band per OP/1/A/6100/022 (Unit 1 Data Book),

Enclosure 4.3, Graph(s) 1.1.

NOTE: Dilution rates for reaching and maintaining 100% power may change significantly based on change in Xenon worth.

O 3.33.5 Generate Xenon Prediction printout per OAC or REACT to determine expected changes in dilution rates. {PIP-99-0669) 3.33.6 WHEN 98% RTP, perform the following:

3.33.6.1 Depress MW INIMW OUT.

3:33.6.2 Ensure lit MW OUT.

O 3.33.6.3 Adjust Turbine load per OPIl/A163001001 A (Turbine-Generator Load Change).

Unit 1

Enclosure 4.1 OP/1/A/6100/003 Power In crease Page 44 of 45 3.33.7 j performing Generator Reactive Limits Verification testing at 98% RTP, perform the following:

LI 3.33.7.1 Perform applicable sections of PT! 1 /B!43 50/001 C (Generator Reactive Limits Verification Test).

3.33.7.2 HOLD until Testing Personnel are ready for Operations to continue with Unit 1 Turbine Generator startup.

NOTE: The intent of the following hold step is to allow a more controlled final approach to 100% power.

3.33.8 WHEN 99.5% RTP, perform the following: {PIP 06-0754) 3.33.8.1 HOLD power escalation for at least 10 minutes to allow for Xenon and AFD oscillations to be seen.

3.33.8.2 WHEN at least 10 minutes have elapsed, continue power increase.

3.33.9 WHEN 100% RTP, perform the following:

CAUTION: Maximum #4 Governor Valve position is 45% with feedback loops out of service to ensure valve maintained within its controlling band.

3.33.9.1 Ensure #4 Governor Valve less than 45% open unless advised by System Engineer.

LI 3.33.9.2 Check 100% RTP at 3411 MWT. (M1P1355) 3.33.9.3 IF necessary, have IAE calibrate each Power Range NI channel to +/-1% Power Mismatch (NIs vs BETP).

LI 3.33.9.4 Suspend logging Fuel Maneuvering Limit on RO Turnover Checklist.

El 3.33.9.5 Remove Pzr Htr Groups A, B and D from service per Enclosure 4.6 (Operation of Pzr Heaters).

Unit 1

Enclosure 4.1 OP/1/Ai6100/003 Power Increase Page 45 of 45 3.33.10 WHEN Nuclear Power (PR) instruments indicate 100%, perform the following:

3.33.10.1 Check the following between iO 75 - 10225%: {PIP-98-2017 El 1A W/R Neutron Flux (%) (1ENBPI951O)

El lB W/R Neutron Flux (%) (IENBPI952O) 3.33.10.2 outside of range, notify IAE to perform IP/0/A132071006 A SRO (Gamma-Metrics Neutron Flux Monitor Calorimetric Adjustments).

Person Notified Date Time LI 3.33.11 Maintain proper NC System parameters by operating Pzr Htr Groups as required per Enclosure 4.6 (Operation of Pzr Heaters).

End of Enclosure Unit 1