ML16049A498

Initial Exam 2015-301 Draft Simulator Scenarios

ML16049A498
Person / Time
Site:	Farley
Issue date:	02/18/2016
From:	Division of Reactor Safety II
To:	Southern Nuclear Operating Co
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Download: ML16049A498 (405)

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Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #2 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 7/20/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 2 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1 Section 4.1 - through step 23 is complete. Ramp on hold while investigating Feed water Dissolved Oxygen. 1B MDAFWP tagged out.

Turnover:

• Reactor power - 95%, Impulse Loop is NOT in service, MOL, Cb 977 ppm.

• UOP-3.1 Section 4.1 - through step 23 is complete.

• Ramp on hold while Chemistry investigates Feedwater Dissolved Oxygen.

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

Event Malf. Event Event No. No. Type* Description 1 xmt/ I (RO) LT-112, VCT LVL, fails high.

lt112 2 preset I (BOP) R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

malf/r/

MAL-RMS2T 3 malf/n/ I (BOP) N-41A, Power Range, Loses Instrument power.

MAL-TS (SRO) TS - 3.3.1 Cond D,E,T,U NIS11A 4 R (RO) Chemistry report that dissolved Oxygen exceeds Action Level 2.

N (BOP) Requests ramp down to less than 48% power.

5 cmfmalf/ C (RO) 1C Charging pump trips on overload.

cCVP01C_

TS (SRO) TS - 3.5.2 Cond A d_c1 6 caep file C (BOP) 1B SGFP begins to oscillate. Will trip after attempts are made to control in manual. This will require a fast ramp. (P-CT) malf/f/

MAL-FWM11B 7 malf/f/ M (ALL) 1A SGFP trips requiring a Reactor trip.

MAL-FWM11A 7 Preset/ C (RO) Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) trigger 1 C (BOP) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

8 malf /r/ M (ALL) LBLOCA after exiting FRP-S.1.

RCS2A C (BOP) preset Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT)

Terminate on transition to ESP-1.3.

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario 2 Presets Form ES-D-1 EVENT TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-220 (Base IC-60)

Impulse loop NOT in service.

rst 220 0 0 Generic setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc2.txt 0 0 Freeze Xe set crxefast=0 0 0 RUN PRESETS setup Tag out 1B MDAFW pump

• irf cAFP01B_d_cd1 open 2 RCV-3028 does not close on High Radiation

• imf ccch3028_cc1 closed imf ccch3028_cc4 closed 7 1A crdm set fails to trip:

• imf c52mga_cr3 7 RTBs fail to open

• imf cbkrxtrp_cc21 closed imf cbkrxtrp_cc22 closed 7 Main Turbine will not trip Automatically

• imf mal-tur2 7 Prevent Manual trip of main turbine

• imf mal-tur24 7 GV2 will not close completely. GV2 reaches 25% going *TRG 1 closed, it sticks at 25% open.

trg 1 "imf mal-tur15f 25 0"

PRESETS 7 MSIVs will not close on MSLIAS

• imf cRSH001A_cc5 open imf cMSH002A_d_cc5 open imf cRSH001B_cc5 open imf cMSH002B_d_cc5 open imf cRSH001C_cc5 open imf cMSH002C_d_cc5 open 8 Phase B fails to automatically actuate

• imf cCTMTSPR_cc1 open imf cCTMTSPR_cc2 open imf cCTMTSPR_cc5 open imf cCTMTSPR_cc9 open imf cCTMTSPR_cc10 open imf cCTMTSPR_cc13 open Triggers and Commands 6 Monitor GV 2 position *TRG 1 trgset 1 "rehgvpz(2) <= 25"

MCB setup OVATION Clear OVATION alarms OVATION Verify Impulse Loop is NOT in service Place danger TAG ON 1B MDAFW Pump HS on MCB Place tag on 1B MDAFWP HS Unit 1 Train B Bypass & Inoperable Status Ind Panel on AFW Switch in ON EPB - AFW SYSTEM Switch in ON Provide a marked up copy of UOP-3.1 UOP-3.1 Section 4.1 - up through step 23 marked off Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Un Freeze Xe set crxefast=1 Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl

MCB setup If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 Start of LT-112, VCT LVL, fails high.

exam /

NRC CUE imf lt112 100 15 2 NRC R-17B, CCW, Fails High. RCV-3028, CCW SRG TK CUE VENT, fails to close.

imf mal-rms2t 1e+006 3 NRC N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U CUE mal-nis11a 4 NRC Chemistry report that dissolved Oxygen exceeds Action Level CUE 2. Requests ramp down to less than 48% power.

5 NRC 1C Charging pump trips on overload. TS - 3.5.2 Cond A CUE imf ccvp01c_d_c02 6 NRC 1B SGFP begins to oscillate. Will trip after the 1B SGFP CUE speed is stable or after fast ramp initiated whichever is first.

cae 2105nrcscen2.cae imf mal-fwm11b

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC 1A SGFP trips requiring a Reactor trip.

CUE imf mal-fwm11a 7 N/A Reactor fails to trip. Require entry into FRP-S.1. preset Turbine fails to trip in Manual and GV2 will not close. TRG1 Requires the MSIVs to be shut.

8 1 LBLOCA after exiting FRP-S.1.

minute imf mal-rcs2a after exit of FRP-S.1 or Neither Phase B nor Containment Spray will automatically preset NRC actuate and requires manual actuation.

CUE NRC END OF EXAM:

CUE Transition to ESP-1.3 Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen2grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 IF REQUESTED Open RX trip breakers imf cbkrxtrp_cc21 open imf cbkrxtrp_cc22 open (3 minutes after requested) cae Turbine_Bldg_MSRs.cae (10 minutes after requested, SOP-0.0 actions for a Rx trip/Safety Injection) 9.1.7 RNO of EEP-0 cae 2015_TB_MSDP_iso.cae (5 minute after requested) 8 IF REQUESTED Close ECCS Disconnects cae eccs_disc_delayed.cae (3 minutes after requested)

Acknowledge MH1 Go to Control Room Fire Panel on the PANEL MAP and select CONTROL ROOM FIRE PANEL then CLICK the ACK button.

(3 minutes after requested)

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the inform supervision) cue and that type of communications 1 IF REQUESTED HP: We will perform surveys on the CCW system.

HP: 5 minutes after requested: All radiation levels in the vicinity of CCW are background.

2 NO ADDITIONAL REQUIRED 3 IF REQUESTED SSS: We will place the OTT bistables for N41 in TRIP SSS/U2: I will perform STP-37.0 for Unit 1.

4 CUE Chemistry: Feedwater Dissolved Oxygen has exceeded action level 2.

IF REQUESTED Chemistry: Recommend reducing power to <48%.

IF REQUESTED Chemistry: Feedwater Dissolved Oxygen is 12 ppb.

IF REQUESTED Shift Manager (or other Plant Leadership): I concur with Chemistrys request to lower power to <48%.

IF REQUESTED Shift Manager: (if asked what power level to stop). What is your recommended power level to reduce to? ----- I concur.

5 IF REQUESTED RAD 1 SO: 3 minutes after requested - 1C Charging pump is not running. No obvious problems noted.

ROVER: 3 minutes after requested - DG-06 has an overcurrent trip flag.

SSS: We will brief then shift 1B Charging pump to B train.

SSS: We will brief and then rackout 1C Charging pump breaker.

6 IF REQUESTED TB SO: 3 minutes after requested - A contractor said he may have made contact with the 1B SGFP with a scaffold pole.

TB SO: 5 minutes after requested: All Feedwater heater dumps and drains appear to operating normally.

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

7 IF REQUESTED ROVER: 3 minutes after requested - The unit 1 reactor trip breakers are open TB SO: 10 minutes after requested - SOP-0.0 actions for a Rx trip/Safety Injection are complete.

RAD 1 SO: I will verify SFP cooling in service per SOP-54.0 8 IF REQUESTED SSS: I will coordinate the performance of step 6 of EEP-1.

SSS: I will Close recirculation valve disconnects using ATTACHMENT 1.

SSS: I will establish 1A and 1B post LOCA containment hydrogen analyzers - IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.

U2: Once MH1 is acknowledged - Fire alarm has been acknowledged. It was 1A-22 CTMT.

Appendix D Scenario 2 Detailed Summary Form ES-D-1 Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1 Section 4.1 - through step 23 is complete. Ramp on hold while investigating Feed water Dissolved Oxygen. 1B MDAFWP tagged out.

Turnover:

• Reactor power - 95%, Impulse Loop is NOT in service, MOL, Cb 977 ppm.

• UOP-3.1 Section 4.1 - through step 23 is complete.

• Ramp on hold while Chemistry investigates Feedwater Dissolved Oxygen.

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

Event 1: LT-112, VCT LVL Fails HIGH.

Verifiable actions: RO will place LCV-115A, VCT HI LVL DIVERT VLV, in the VCT position and control level using LCV-115A or LK-112 in manual.

Event 2: R-17B, CCW, fails high. RCV-3028, CCW SRG TK VENT fails to close.

Verifiable actions: BOP will close RCV-3028 manually.

Event 3: N-41A, Power Range, loses Instrument power.

Verifiable actions: BOP will operate the ROD STOP BYPASS switch, COMPARATOR CHANNEL DEFEAT switch, UPPER SECTION switch on the Detector Current Comparator Drawer, LOWER SECTION switch on the Detector Current Comparator Drawer and reset the rate trip for N-41. BOP will remove the AC Control Power Fuses on the A drawer for N-41A.

SRO - Tech Spec: 3.3.1 Cond D,E,T,U Event 4: Chemistry report that dissolved Oxygen exceeds Action Level 2. Requests ramp down to less than 48% power Verifiable actions: RO will use rods and boron to ramp down. BOP will place impulse loop in service and insert ramp target and begin ramp.

Event 5: 1C Charging pump trips on overload.

Verifiable actions: RO will secure letdown and start 1A Charging pump per AOP-16, CVCS Malfunction. The next event will be inserted prior to placing letdown back in service. SRO - Tech Spec: 3.5.2 Cond A.

Event 6: 1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert a fast ramp using Ovation.

Verifiable actions: BOP will take manual control of the 1B SGFP controller. When the 1B SGFP trips, the BOP will insert a fast ramp using Ovation controls.

(P-CT) If the SGWL falls to 28% NR in one SG, a Rx trip is called for but will not occur due to being blocked. Also, if SGWL reaches 82% NR, a turbine trip is called for but will not occur due to being blocked but a trip of both SGFPs will occur and the FRVs will close. This will cause an early entry into FRP-S.1. Critical task is to initiate a Reactor shutdown per FRP-S.1 if limits are exceeded.

Event 7: 1A SGFP trips which will require a manual Reactor trip. Reactor does not trip from the Main Control Room and the Main Turbine will not trip In Auto/Manual and the #2 GV will not close completely. FRP-S.1 entry required.

Verifiable actions: RO will insert rods and emergency borate (CT-52). BOP will shut MSIVs to isolate the turbine.

Appendix D Scenario 2 Detailed Summary Form ES-D-1 Event 8: A Large Break LOCA occurs upon exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate.

Verifiable actions: BOP manually initiates Phase B and Containment Spray (Same Switches). (CT)

Terminate at transition to ESP-1.3

Appendix D Scenario 2 Critical Tasks Form ES-D-1

_____ 1. Do not allow the dispatch of the SO to locally trip the RX trip breakers and or Main Turbine to interfere with the initiation of insertion of negative reactivity by one of the following methods.

• Insert control rods

• Establish emergency boration flow to the RCS (CT-52)

_____ 2. Initiate at least one train of Containment Spray prior to exiting FRP-Z.1 or prior to the end of the scenario.

This critical task comes from the comments section of CT-3, manually actuate containment cooling. For plants that rely on containment spray to remove iodine from the containment internal atmosphere, a separate plant-specific critical task specifically directed at manually actuating at least one train of containment spray may be appropriate. In such a case, the plant should prepare a separate critical task that justifies manual actuation of at least one train of containment spray on the basis of iodine removal assumptions made in the FSAR . (CT-PLANT BASED)

SCENARIO At power power instrument and component failures with a loss of feed with an ATWT OBJECTIVE/ followed by a LBLOCA. The team should be able to:

OVERVIEW:

• respond to a LT-112 failure

• respond to a loss of power to N-41A

• ramp down in response to out of specification chemistry

• restore charging flow after the trip of the running pump

• take manual control of 1B SGFP speed and perform a rapid power reduction on a loss of the 1B SGFP

• insert negative reactivity and close MSIVs in response to an ATWT with a loss of feed

• manually actuate Phase B.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 3

2. Abnormal events (2-4) 5

3. Major transients (1-2) 2

4. EOPs entered/requiring substantive actions (1-2) 1

5. EOP contingencies requiring substantive actions (0-2) 1

6. Critical tasks (2-3) 3

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 1, 95% RTP, MOL 10000 MWD/MTU, 977 ppm Cb, -2181 pcm Xe A Trn O/S / A Trn Protected / SFPC on A Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 167 hours0.00193 days <br />0.0464 hours <br />2.761243e-4 weeks <br />6.35435e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. Impulse loop is NOT in service

3. UOP-3.1, Section 4.1 through Step 23 is complete.

4. 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

5. Ramp is on hold while Chemistry investigates Feedwater Dissolved Oxygen.

6.

7.

8.

9.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas) 1B MDAFW pump - 3.7.5 Cond B LCO status (planned- entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago) #1 RHT Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __1___ Page 1 of 3 Event

Description:

LT-112, VCT LVL, fails high. Cause Letdown to divert to the RHT until manual action taken Indications Available

- Actual VCT level going down - DF3, VCT LVL HI-LO

- Auto make up may occur - LCV115A divert to the HU TANK Time Position Applicants Actions or Behavior Comments RO Announces alarm. May diagnose malfunction SRO Directs ARP entry ARP-1.4, DF3, VCT LVL HI-LO ver 54.2 RO 1 Determine if level is high or low as indicated by LI-115 and LI-112B on the MCB. {CMT 0006813}

RO 2 Steps 2 and 3 are N/A IF actual level is high, THEN:

3 IF actual level is low, THEN SRO 4 This step is N/A IF the alarm is due to a Charging or Letdown malfunction, THEN go to FNP AOP-16.0, CVCS MALFUNCTION to address the loss of letdown flow.

RO 5 Observe CHG HDR PRESS indicator PI-121 and the running Charging Pump Motor Ammeter to ensure proper pump operation. (SOER 97-1) {CMT 0006813}

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __1___ Page 2 of 3 Event

Description:

LT-112, VCT LVL, fails high. Cause Letdown to divert to the RHT until manual action taken Time Position Applicants Actions or Behavior Comments RO 6 Refer to FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM.

RO 7 This step is N/A IF LI-115 has failed high, THEN:

RO 8.

IF LI-112 has failed high, THEN:

8.1 Place Q1E21LCV115A, VCT HI LVL DIVERT VLV in the VCT position.

8.2 Manually makeup to VCT, as required to restore level.

8.3 Place LK-112 VCT level controller to manual and adjust to 0 demand.

8.4 Control VCT level by ONE of the following methods:

8.4.1 Alternately place Q1E21LCV115A, VCT HI LVL DIVERT VLV between VCT, AUTO, and RHT positions, as required.

8.4.2 Place Q1E21LCV115A, VCT HI LVL DIVERT VLV inAUTO and manually adjust LK112 VCT level controller to maintain level.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __1___ Page 3 of 3 Event

Description:

LT-112, VCT LVL, fails high. Cause Letdown to divert to the RHT until manual action taken Time Position Applicants Actions or Behavior Comments 8.5 This step is N/A IF VCT level decreases to 5%, THEN align charging pump suction to the RWST by the following:

8.5.1 RWST TO CHG PUMP

[ ] Q1E31LCV115B open.

[ ] Q1E21LCV115D open.

8.5.2 VCT OUTLET ISO

[ ] Q1E21LCV115C closed.

[ ] Q1E21LCV115E closed RO 8.5.3 Refer to FNP-1-AOP-1.0, FNP-1-AOP-2.0 and/or FNP-1-AOP-17.1 as appropriate.

SRO/RO 9 Steps 9 & 10 are N/A IF LI-115 has failed low, THEN:

10 IF LI-112 has failed low, THEN:

11 Contact SM. Has RO/BOP IF LI-112 or LI-115 has failed, THEN contact appropriate initiate steps to have the personnel instrumentation repaired. (SOER 97-1 At Lead Examiners discretion move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 1 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Indications Available

-FH1, RMS HI-RAD R-17A in ALARM Time Position Applicants Actions or Behavior Comments RO Announce alarm BOP Acknowledges RAD Monitor panel and announces R-17A in alarm SRO Directs ARP entry ARP-1.6, FH1, RMS HI-RAD ,ver 72.1 BOP 1 Check indications on radiation monitoring system console and determine which radiation monitor channel indicates high activity.

BOP 2 BOP closes RCV-3028 Insure that any automatic actions, associated with the alarmed channel, have occurred.

BOP 3 Perform the following general actions as appropriate.

3.1 Determine the source or cause of the high activity and correct or isolate as required.

3.2 Determine the validity of the high activity indication as follows:

3.2.1 Verify that the instrument is aligned May check alignment IAW for normal operation and is functioning SOP-45 on Page 5 properly.

Page 1 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 2 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Time Position Applicants Actions or Behavior Comments BOP 3.2.2 Steps 3.2.2 - 3.2.3 are N/A IF R10, R11, OR R12 has caused an invalid alarm, notify Electrical/I&C System Engineering Supervisor 3.2.2 IF a known problem exists such that the detector is saturated, THEN momentarily pull the affected detectors fuses (located on the front of the drawer) to clear the condition.

3.2.3 If requested to disable a remote audible alarm, refer to FNP-1-SOP-45.0, P&L 3.6.

3.2.4 Calls HP and has them Sample or survey the affected system or conduct survey.

area as required. {CMT 0008755}.

3.2.5 IF R-10, R11 or R12 are in an alarm or a This step is N/A fault condition, THEN submit a CR to request Engineering Support perform the applicable portion of FNP ETP-227.0, RAD MONITOR RM 2000 CONTROL PANEL OPERATION to obtain required data.

BOP 3.3 Do not allow personnel to enter the May make an affected area without the approval of the announcement Health Physics Department.

3.4 IF high activity indication is due to No LCO exists instrument failure, THEN refer to Technical Specifications, section 3.3.3, 3.4.15 and TRM TR 13.3.4.

Page 2 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 3 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Time Position Applicants Actions or Behavior Comments 3.5 Steps 3.5 - 3.8 are N/A IF high activity indication of RCS leakage is present AND accompanied by either decreasing pressurizer level, OR decreasing VCT level, THEN go to FNP AOP-1.0, RCS LEAKAGE.

3.6 IF high activity indication of Steam Generator Tube Leakage is present, THEN go to FNP-1-AOP-2.0, STEAM GENERATOR TUBE LEAKAGE.

3.7. IF ARDA activated and not required, THEN have counting room stop the automated dose assessment per FNP-0-EIP-9.1, AUTOMATED DOSE ASSESSMENT METHOD.

3.8 WHEN radiation levels have decreased below alarm setpoint, THEN reset the appropriate HI radiation alarm on the RAD monitor drawer BOP 4 R-17A requires step 4.16 In addition to the general actions perform supplementary steps indicated in the ACTIONS column of the following table. (Some of the radiation monitors included in the table do not input into this alarm but are included for reference).

Page 3 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 4 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Time Position Applicants Actions or Behavior Comments NOTE: IF CCW surge tank vents are closed for reasons other than an actual high radiation alarm, THEN with Shift Supervisor concurrence, the CCW surge tank vents should be cycled once every shift (eight hours) and documented in the Control room Log.

BOP 4.16 IF R-17A OR R-17B alarms, THEN perform the following:

4.16.1 Should have been closed at IF alarm is due to CCW Suction rad step 2. May be closed monitor R-17A or R- here.

17B being failed low (low alarm lit), THEN close CCW Surge Tank vent valve Q1P17HV3028, using handswitches for both Q1P17SV3028A and Q1P17SV3028B, with SS concurrence.

4.16.2 Monitor CCW pump operation while the CCW surge tank vents are closed.

4.16.3 WHEN desired to open the CCW surge tank vent valve Q1P17HV3028, THEN simultaneously place handswitches for both Q1P17SV3028A and Q1P17SV3028B to open until the red light is lit.

Page 4 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 5 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Time Position Applicants Actions or Behavior Comments SOP-45, RADIATION MONITORING SYSTEM, ver 47 BOP 4.1 Aligning Radiation Monitoring System for Normal Operation:

4.1.1 Verify the appropriate radiation 4.1.1 is N/A monitoring recorders in operation per Section 4.2.

BOP 4.1.2 This step is N/A For R-22, verify alignment has been performed per FNP-1-IMP-227.47, Valve Alignment for Operation of Unit 1 RE0011/12 and RE0021/22 (OR 1 317).

BOP 4.1.3 Perform the following to verify drawers aligned for monitors listed in Table A:

4.1.3.1 Verify operation selector in OPERATE.

4.1.3.2 Verify range selector in WIDE.

4.1.3.3 Verify drawer indicating lights as follows:

a. Power Light - ON

b. Channel Test Light - OFF

c. High Alarm Light - OFF

d. Low Alarm Light - OFF BOP 4.1.4 This step is N/A Align the drawer for R21 as follows:

At Lead Examiners discretion move to next event Page 5 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 1 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Indications Available

-NI41B, PR1 PERCENT FULL POWER IS - The following alarms 0% FB4/FB5, PR UPPER/LOWER DET HI FLUX

-NI41C, PR1 PERCENT FLUX DIFF IS DEV OR AUTO DEF 0% FC1, PR HI FLUX-HIGH RNG RX TRIP ALERT

- NI41 DRAWER - No indication on FC3, PR HI FLUX RATE ALERT UPPER and LOWER DET FC5, PR CH DEV

- NI41 DRAWER - (5 power all bistable FF5, COMP ROD SEQ/DEV OR PR FLUX TILT lights lit)

Time Position Applicants Actions or Behavior Comments RO Announces alarms and/or diagnoses malfunction SRO Announces AOP-100 entry AOP-100, INSTRUMENTATION MALFUNCTION, ver 15 RO 1 This step is N/A IF N-44 has failed, THEN place rods in manual.

BOP 2 STOP any load change in progress.

RO 3 P-10 bistables on TSLB3 Within one hour, check P-10 interlock in and Bypass and permissive the required state for existing unit panel lights will be LIT conditions. (TS 3.3.1 Function 17e)

RO 4 P-7, P-8, P-9 Bistables light Within one hour, check the following on TSLB3 are LIT.

interlocks are in the required state for existing unit conditions: (TS 3.3.1 Bypass and Permissive Function 17b, c, d) Panel 4 P-7, P-8, P-9 lights OUT

• P-7

• P-8

• P-9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 2 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments RO 5 Check THERMAL POWER -

GREATER THAN OR EQUAL TO 75%.

SRO 6 IF required, THEN perform FNP-1-STP-122.0, QUADRANT POWER TILT MEASUREMENT WITH AN INOPERABLE EXCORE DETECTOR as required by Tech Spec SR 3.2.4.2 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 6

OR Reduce power to <75% thermal power within 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.

BOP 7 IF required, THEN perform the following:

77 a)

Select the affected channel on:

• ROD STOP BYPASS switch (Misc Control and Indication Panel)

• COMPARATOR CHANNEL DEFEAT switch (Comparator and Rate Drawer)

• UPPER SECTION switch (Detector Current Comparator Drawer)

• LOWER SECTION switch (Detector Current Comparator Drawer) b)

Reset rate trip on the A drawer for the affected channel by placing Rate Mode switch in RESET AND allow to spring return to NORMAL.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 3 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments RO/BOP 8 No action required Restore Tavg to program as necessary:

• Adjust turbine load

• Use of control rods

• Dilution/Boration RO 9 Check N-44 OPERABLE. This step is N/A 99 9.1 IF desired AND with Shift Supervisors concurrence, place RODS in AUTO.

RO 10 This step is N/A IF N-43 has failed AND it is desired to use the R-70s to determine the presence of elevated activity in the Steam Generators, THEN have Counting Room personnel place the R-70s in the ME mode per FNP-0-CCP-31, LEAK RATE DETERMINATION.

RO 11 Monitor operable Power Range Channels on NR-45B.

SRO 12 SRO contacts SM and has Submit a condition report on the failed RO/BOP contact instrument channel, and notify the Work appropriate personnel Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO 13 Contacts SSS to trip Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, place the inoperable Bistables - May not occur Power Range Channel in trip by since they have 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to performing the following: (TS 3.3.1) perform this action

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 4 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments BOP a)

Remove the AC Control Power Fuses on the A drawer for the affected channel.

SSS b)

Trip overtemperature delta-T bistables for affected channel by operation of the applicable TEST SWITCHES:

SRO 14 This step is N/A IF the plant computer is inoperable OR annunciator FC4 is otherwise inoperable, THEN within one hour perform FNP-1-STP-37.0, POWER DISTRIBUTION SURVEILLANCE.

SRO 15 Contacts SM Notify the Shift Manager.

SRO Initiate the applicable actions of the following Technical Specifications:

17 16

• Table 3.3.1-1 Function 2

• Table 3.3.1-1 Function 3

• Table 3.3.1-1 Function 6

• Table 3.3.1-1 Function 17 b, c, d, e

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 5 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments TECHNICAL SPECIFICATION 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1-1.

ACTIONS Function 2a, 3, - Condition D SRO CONDITION REQUIRED ACTION COMPLETION TIME D. One Power --------------------NOTE-----------

Range Neutron The inoperable channel may Flux channel be bypassed for up to 12 inoperable.. hours for surveillance testing and setpoint adjustment of other channels.

D.1.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND D.1.2 Reduce THERMAL POWER to 75% RTP. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> OR D.2.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND D.2.2 -----------NOTE------------

Only required to be performed when the Power Range Neutron Flux input to QPTR is inoperable.

Perform SR 3.2.4.2. Once per 12 hrs OR D.3 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 6 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments Function 6 - Condition E SRO CONDITION REQUIRED ACTION COMPLETION TIME E. One channel ------------------NOTE------------

inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.

E.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR E.2 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> Function 17b, c, d - Condition U SRO CONDITION REQUIRED ACTION COMPLETION TIME U. One or more U.1 Verify interlock is in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> channels required state for existing unit inoperable. conditions.

OR U.2 Be in MODE 2. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> Function 17e - Condition T SRO CONDITION REQUIRED ACTION COMPLETION TIME T. One or more T.1 Verify interlock is in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> channels required state for inoperable. existing unit conditions.

OR T.2 Be in MODE 3. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> At Lead Examiners discretion move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 1 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Indications Available N/A Time Position Applicants Actions or Behavior Comments SRO Receives call from Chemistry that Action If SRO call SM for Level 2 has been exceeded for Feedwater concurrence. SM concurs Dissolved Oxygen AOP-25, Abnormal Primary or Secondary Chemistry, ver 21.1 SRO 1 This procedure is entered upon notification by Chemistry that abnormal primary or secondary chemistry exists which could exceed chemistry control limits.

1.1 For a dissolved oxygen excursion proceed to step 2.

2 IF Chemistry reports that condensate pump discharge or feedwater dissolved oxygen is increasing or has exceeded an action level value, THEN perform the following:

2.1 Has SSS coordinate Begin investigating for the source of the performance of Attachment dissolved oxygen using 1 ATTACHMENT 1, DISSOLVED OXYGEN SOURCES as a guide while continuing in this procedure.

2.2 Chemistry request power IF dissolved oxygen has exceeded the reduction <48%

Action Level 2 value, THEN Consult with Chemistry and determine if a power reduction to less than or equal to 48% power is desired.

FNP-1-UOP-3.1, POWER OPERATION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 2 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments 2.2.1 Commences ramp down IF required, THEN reduce power to less than or equal to 48% in accordance with 2.3 N/A IF between 12% and 48% power, AND feedwater dissolved oxygen exceeds 100 ppb for more than 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />, THEN, power escalation should be halted until oxygen is less than 100 ppb.

2.4 Determine desired dissolved oxygen level and coordinate with Chemistry and Engineering Support to implement the appropriate corrective action plan UOP-3.1, Power Operation, Section 4.4, ver 122 BOP 1 Review and perform the following as required BOP a This step is N/A If Turbine Overspeed Test is to be performed, Refer To Section 3.0 Precaution and Limitation 1.l prior to commencing ramp...

BOP b For normal load reductions, a ramp rate restriction of 2 MW/min (14% per hour) will apply............................................................

BOP c This step is N/A When conditions warrant a ramp rate of greater than 2 MW/min, notify the Shift Manager as soon as conditions permit.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 3 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments BOP d This step is N/A Enter FNP-1-AOP-17.1, RAPID TURBINE POWER REDUCTION in conjunction with this procedure for ramp rates greater than 5 MW/min.........

BOP e This step is N/A Ramp as slow as possible if known fuel leak exists. Power decreases should follow the guidance found in Attachment 1, Special Load Rate Limitations.

BOP f This step is N/A If a power reduction is being performed due to entry into Technical Specifications 3.4.16, adjust the ramp rate to meet the shutdown requirements of the specification.

BOP g This step is N/A If a reactor shutdown is NOT for a refueling outage, record criticality data in the Control Room Log prior to load decrease.

BOP h Maintain valve position limit 115% while ramping or at 100%.

BOP i This step is N/A Maintain valve position 8 to 10% above valve position demand when holding for more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at some power level less than 100%.

BOP j This step is N/A Flush and sample AFW pump suction piping as required by FNP-1-SOP-22.0, Auxiliary Feedwater System, prior to initiation of AFW flow to the SGs.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 4 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments BOP 2 BOP place IMP loop in While ramping between 97% and 20% service per step 2 power, verify the IMP PRESS LOOP in service as follows:

BOP a Verify Turbine on HOLD. ..............

BOP b Check Ovation point, 1ST STG IMPLS PRESS, has stable indication.

BOP c On LOOP STATUS of page 5551, press SELECT BOP d On popup 7053, press IMP BOP e On popup 7059, press IMP LOOP IN.

BOP f On LOOP STATUS of page 5551, check IMPULSE displays YES BOP 3 On page 5551, perform the following to set desired load target and load rate.................

a On RAMP INTERFACE section, press MODIFY b

On TARGET SELECTION section of BOP inserts ramp to <48%

popup 7055, enter desired target using one of the following methods:

• Using predefined buttons.

• Using CUSTOM button to enter custom rate

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 5 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 6 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments c

On RAMP INTERFACE section of page 5551, check desired target appears under TARGET.

d On page 5551, check HOLD button has gold background e

IF desired to change load rate, on RAMP INTERFACE section of page 5551 press MODIFY.

(1)

On popup 7055, enter desired rate by either of the following Using predefined buttons.

Using predefined buttons.

(2)

On RAMP INTERFACE section of page 5551, check desired rate appears under RATE.

4 Inform other Control Room operators load will be changed.

5 Press GO to commence ramp.

BOP 6 Verify proper SGFP speed control.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 7 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments RO 7 Attempt to maintain the axial flux difference within + 5% from the target value by making adjustments in rod height and/or boron concentration as necessary..........

RO Uses Borations to lower Tavg during the ramp SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix B, v60.1 RO 1.1 From reactivity briefing IF necessary, THEN set the boric acid sheet integrator to the desired quantity.

RO 1.2 IF necessary, THEN adjust LTDN TO VCT FLOW LK 112 setpoint as desired.

1.3 Position the MKUP MODE CONT SWITCH to STOP.

1.4 Position the MKUP MODE SEL SWITCH to BOR.

1.5 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 8 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments RO 1.6 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.7 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.8 This step is N/A If desired to clear the line of acid, perform the applicable steps of Appendix B Section 2.0.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 9 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments Note: If the crew decides to remain lined up for repetitive borations, then steps 1.9 -

1.11 are N/A. Repetitive boration steps are listed in Appendix C below.

RO 1.9 Position the MKUP MODE SEL SWITCH to AUTO.

1.10 Position the MKUP MODE CONT SWITCH to START.

1.11 IF LK 112 setpoint was adjusted per Step 1.2, THEN return setpoint to that required for current conditions.

SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix C, v60.1 RO 1.1 IF necessary, THEN set FIS-113 Boric Acid Batch Integrator to the desired quantity.

1.2 The Reactor Makeup Control system has been previously aligned for Boration.

1.3 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 10 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments RO 1.4 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.5 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.6 IF repetitive borations are no longer required THEN verify the system is aligned for Automatic makeup per Steps 1.9 through 1.11 of Appendix B.

SOP-41.0, Control Rod Drive and Postion Indication System, Ver 37 OPERATOR AID FOR CONTROL ROD MOVEMENT RO 1 Place ROD CONTROL BANK SELECTOR SWITCH in MAN.

RO 2 Check indicated control rod speed is approximately 48 steps per minute on SI-408.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 11 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments RO 3 Insert OR withdraw Control Rods using the CONTROL ROD MOTION switch.

RO 4 When desired, place rod control in AUTO as follows:

RO 4.1 Verify Tavg within 1°F of Tref.

RO 4.2 Place the ROD CONTROL BANK SELECTOR SWITCH in AUTO.

RO 4.3 Check indicated control rod speed is approximately 8 steps per minute on SI-408.

After the ramp or at the Lead Examiners discretion then move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 1 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Indications Available

- FI-122A, CHG FLOW goes to 0 -The following ALARMS

- 1C CHG PUMP amber light and green EA2, CHG HDR FLOW HI-LO light LIT. EB1, CHG PUMP OVERLOAD TRIP Time Position Applicants Actions or Behavior Comments RO Announces alarms and / or diagnoses malfunction SRO Directs entry into ARP ARP-1.5, EB1, CHG PUMP OVERLOAD TRIP, ver 58.2 SRO 1 Enter FNP-1-AOP-16.0, CVCS Transitions to AOP-16 MALFUNCTION, while performing the remaining steps of this ARP.

RO 2 Observe CHG HDR press indicator PI-121 and the running charging pump motor ammeter to ensure proper pump operation. (Ref. SOER 97-1) 3 RO/BOP Notify appropriate personnel to locate and Contacts ROVER and RAD correct the cause of the pump 1 SOs.

trip.

SRO 4 Refer To Technical Specifications LCOs 3.5.2 and 3.5.3, and Technical Requirements TRs 13.1.2, 13.1.3, 13.1.4, and 13.1.5.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 2 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments AOP-16, CVCS MALFUNCTION, ver 20 RO 1 Verify CHG flow adequate to cool letdown

[] CHG FLOW - FI-122A

[] LTDN HX OUTLET FLOW - FI-150

[] REGEN HX OUTLET TEMP - TI-140 RO 1 (RNO)

Isolate Normal Letdown as follows:

1.1 (RNO)

Verify closed all LTDN ORIF ISOs:

[] Q1E21HV8149A

[] Q1E21HV8149B

[] Q1E21HV8149B BOP 2 Stop any load change in progress RO 3 This step is N/A If charging line rupture occurs then go to attachment 2 4

Monitor VCT level 5

Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation PI-121 and ammeter for chg pump

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 3 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 5 (RNO)

IF VCT level reduces to 5%, THEN perform the following:

5.1 Open RWST TO CHG PUMP valves

[] Q1E21LCV115B

[] Q1E21LCV115D 5.2 Close VCT OUTLET ISO valves

[] Q1E21LCV115C

[] Q1E21LCV115E RO 6 1C Charging pump is not Check charging pump - RUNNING running RO 6 (RNO)

Start an available charging pump as follows:

6.1 Check VCT level and pressure adequate.

6.2 Verify charging suction flowpath aligned:

VCT OUTLET ISO valves

[] Q1E21LCV115C - OPEN

[] Q1E21LCV115E - OPEN OR RWST TO CHG PUMP valves

[] Q1E21LCV115B - OPEN

[] Q1E21LCV115D - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 4 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 6.3 (RNO)

Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB.

RO 6.4 (RNO)

Check open minflow isolation for charging pump to be started

• 1A CHG PUMP MINIFLOW ISO Q1E21MOV8109A RO 6.5 (RNO)

Verify CHG PUMP MINIFLOW ISO, Q1E21MOV8106, is open RO 6.6 (RNO)

Verify the following are closed;

[] CHG FLOW FK 122

[] SEAL WTR INJECTION HIK 186 RO 6.7 (RNO)

Verify a CCW pump is running in same train aligned to supplycharging pump to be started RO 6.8 (RNO)

Start selected charging pump RO 6.9 (RNO)

Observe CHG HDR PRESS indicator PI 121 and motor ammeter to check proper pump operation RO 6.10 (RNO)

WHEN charging pump comes up to speed.

THEN check auxiliary oil pump stops as indicated by white light NOT being illuminated on MCB.

Time Position Applicants Actions or Behavior Comments

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 5 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A RO 6.11 (RNO)

Adjust SEAL WTR INJECTION HIK 186 to maintain 6-13 gpm seal injection flow to each RCP RO 6.12 (RNO)

IF all seal cooling lost to any RCP, THEN go to AOP-4.1, ABNORMAL REACTOR COOLANT PUMP SEAL LEAKAGE RO 7 Check Charging flow FK-122 controlling in AUTO with flow indicated RO 7 (RNO)

IF required. THEN take manual control of charging flow:

RO 7.1 (RNO)

Place FK-122 in manual and adjust as required to maintain pressurizer level at program level.

RO 7.2 (RNO)

Adjust SEAL WTR INJECTION HIK-186 as required to maintain RCP seal injection flow 6-13 gpm RO 7.3 (RNO) If manual control of charging This step is N/A not accomplished. THEN refer to ATT 1, MANUAL CONTROL OF CHARGING RO 8 Check to following annunciator -CLEAR

[] DE3 LTDN ORIF ISO VLV REL LINE TEMP HI

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 6 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 9 Determine Status of Normal Letdown:

9.1 Check normal CVCS letdown -

AFFECTED BY MALFUNCTION

• LTDN HX OUTLET FLOW, FI-150 - NO FLOW INDICATED RO 9.2 Minimize RCS makeup:

9.2.1 Manually close FK-122 9.2.2 Minimize seal injection between 6-13 gpm 9.2.3 Direct Chemistry to shutdown the zinc addition system (ZAS)

RO 9.3 Dispatched personnel Dispatch personnel to investigate cause of earlier letdown malfunction RO 9.4 This step is N/A If desired due to plant conditions, place excess letdown on service

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 7 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 10 Determine if normal letdown should be re-established:

10.1 Check normal letdown malfunction(s) -

CORRECTED 10.2 Verify all letdown orifice isolation valves -

CLOSED LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C RO 10.3 Place LTDN HX OUTLET TEMP TK-144 on service:

[] Place controller in AUTO

[] Set to maintain temp 90 (Pot setting 2.7) to 115°F (Pot setting 4.35)

RO 10.4 Verify VCT HI LVL DIVERT VLV LCV-115A alignment:

[] Position indicator VCT light - LIT

[] Handswitch in-AUTO RO 10.5 Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143

[] Handswitch in - VCT

[] VCT light - LIT

[] DEMIN light - NOT LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 8 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 10.6 N/A IF necessary, THEN OPEN both LTDN LINE PENE RM ISOs from the Penetration Room Isolation Panel.

[] Q1E21HV8175A

[] Q1E21HV8175B RO 10.7 Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN RO 10.8 Verify LTDN LINE ISO valves - OPEN

[] Q121LCV459

[] Q121LCV460 RO 10.9 Verify LP LETDN PRESS PK 145 on service:

[] Place controller in MANUL

[] Adjust demand signal o 50% or less RO 10.10 Initiate minimum charging flow:

10.10.1 Verify CHG FLOW FK 122 in MAN 10.10.2 Establish minimum charging flow based on orifices to be placed on service:

• 1 Orifice - 18 gpm or

• 2 Orifices - 40 gpm RO 10.11 Establish approx. 60 gpm letdown flow by OPENING:

Q1E21HV8149B OR Q1E21HV8149C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 9 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 10.12 If desired place the second orifice on service by opening Q1E21HV8149A RO 10.13 Initiate actions to restore letdown flow to demins per SOP-2.1 RO 10.14 IF all backup heaters energized due to pressurizer level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing RO 10.15 Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure -

BETWEEN 260-450 psig 10.15.1 Set controller between 4.3 and 7.5 10.15.2 Check letdown flow - STABLE 10.15.3 Place PK 145 in AUTO 10.15.4 Control Letdown pressure as desired RO 10.16 Control LTDN HX OUTLET TEMP TK 144 to maintain Letdown temperature 90 to 115°F

[] TI-116 VCT TEMP

[] TI-143 DIVERT LTDN HX TEMP

[] TI-144 CCW LTDN HX TEMP

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 10 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 10.17 Refer to SOP-2.1 for further guidance on Letdown system control RO 11 Determine status of letdown flow:

11.1 Check letdown flow - ESTABLISHED

• Normal letdown flow OR

• Excess letdown flow RO 11.2 Go to procedure and step in effect TECHNICAL SPECIFICATION 3.5.2, ECCSOperating Two ECCS trains shall be OPERABLE.

B Train ECCS is INOPERABLE until the 1B chg pump is aligned to B Train and the 1C Chg pump is tagged out or a jumper is installed to permit the 1B Chg pump to auto start CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore train(s) to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> trains OPERABLE status.

Inoperable AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

At the discretion of the Lead Examiner move to Event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 1 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Indications Available

- 1B SGFP speed oscillation When the 1B SGFP trips:

- JF1 / 2 / 3, 1A /1B/ 1C/ SG LVL DEV -1B SGFP speed to 0 rpm

-KC3, 1A OR 1B SGFP TRIPPED

- VARIOUS OTHER FEED SYSTEM ALARMS Time Position Applicants Actions or Behavior Comments BOP Announces alarms and recognizes malfunction SRO Enters AOP-13, Condensate and Feedwater Malfunction Note: AOP-13 allows going directly to the appropriate step based on malfunction.

The crew may choose to call the 1B SGFP tripped. See Step 3.5 RNO.

If this occurs, they will insert a rapid ramp per the IOA of AOP-13 (page 5). In this case, it is intended that we will trip the 1B SGFP if a rapid ramp is initiated (GO button depressed)

AOP-13, Condensate and Feedwater Malfunction, ver 39.1 BOP 3 Check indication of any SGFP malfunction

-Any SGFP speed abnormal

- SGFP discharge Pressure - low 1A(1B) SGFP DISCH PRESS PI 4018A(B)

- Feedwater header pressure - low FW HDR PRESS PI 508

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 2 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 3.1 Potential Critical Task -

Take manual control of SGFP(s) Maintain SGWL to prevent speed controllers as necessary to a Rx trip caused by a control speed and restore feedwater turbine trip.

header pressure above steam header pressure.

- SGFP master controller

- SK-509A OR SGFP individual controllers as needed.

- SK-509B

- SK-509C BOP 3.2 Take manual control of the affected feedwater regulating valves or bypass valves as necessary to control SG level.

- 1A SG FW FLOW FK-478

- 1B SG FW FLOW FK-488

- 1C SG FW FLOW FK-498 OR

- 1A SG BYPASS FLOW FK-479

- 1B SG BYPASS FLOW FK-489

- 1C SG BYPASS FLOW FK-499 3.3 Check no reactor protection system automatic actions required or set points being approached.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 3 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 3.4 IF a ramp is in progress, THEN place Turbine on HOLD 3.5 Verify adequate SGFP function restored.

3.6 Maintain SG narrow range level approximately 65%.

3.7 Check SGFP speed control instrumentation - NORMAL PI-464A PI-508

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 4 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments 3.8 Adjust speed back to within the normal operating range for the feed flow/steam flow DP required for the existing power level Approximate DP can be determined from the following MCB indications.

3.9 Check Hotwell level maintained 30 to 24 by HOTWELL LEVEL controller (CP-4055F) in Auto.

Trip 1B SGFP once speed control is regained

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 5 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments SRO Direct immediate operator actions of AOP-13 due to the 1B SGFP trip BOP 1 Check only one SGFP - RUNNING 1.1 Check generator load GREATER THAN 540 MW 1.2 Check rapid turbine load reduction required.

BOP 1.3 On Ovation Page 5551, TURBINE CONTROL SYSTEM - OPERATION PANEL, perform the following:

1.3.1 Press red ENABLE button on SGFP TRIP RUNBACK section.

1.3.2 On SGFP TRIP RUNBACK section, check the following:

[ ] ENABLE turns gold

[ ] RUNBACK ENABLED is displayed 1.3.3 On RAMP INTERFACE section, check the following:

[ ] TARGET of "540" MW

[ ] Appropriate RATE for current MW load is displayed 1.3.4 Press GO BOP 1.4 Monitor for correct Ovation response

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 6 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 1.5 Potential critical task -

Reduce reactor power to match Loss of SGWL control turbine power. could result in an auto Rx trip due to low SGWL or a 1.5.1 required trip due to a FW Verify rod control in MANUAL. isolation on high SGWL.

1.5.2 Reduce reactor power and control RCS TAVG.

Manual Rod Control Manual boration per FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM.

Emergency boration per FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM Figure 6.

1.6 Check proper operation of the steam dumps.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 7 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 1.7

[CA] Verify steam generator narrow range levels remain greater than 28%.

1.7.1 Verify automatic operation of the feedwater regulating valves adequate.

1A SG FW FLOW FK 478 1B SG FW FLOW FK 488 1C SG FW FLOW FK 498 1.7.2 Monitor feedwater flow and steam flow.

1.7.3 Verify that feedwater and steam flow trend to approximately equal values for the target, turbine load.

BOP 1.8

[CA] Maintain SG narrow range level approximately 65%.

RO 1.9 Check LOSS OF LOAD INTERLOCK C-7A on the BYP & PERMISSIVES panel NOT illuminated.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 8 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 1.9 (RNO)

IF C-7A is to be reset, THEN perform the following 1.9 1.9.1 Verify that all steam dump valves indicate closed.

1.9.1 1.9.2 Verify 0 demand on STM HDR PRESS controller PK 464 and STM DUMP DEMAND TI408 1.9.2 1.9.3 Place STM DUMP INTLK TRAIN A and TRAIN B to OFF RESET 1.9.3 1.9.4 Place STM DUMP MODE SEL TRAINS A-B to RESET and then release to spring return to TAVG.

RO 1.10 Check reactor power change < 15%

RO 1.10 (RNO)

Notify Shift Radiochemist to sample the RCS per FNP-1-STP-746.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 9 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments RO 1.11 Check parameters within limits for continued at power operation.

Pressurizer level greater than 15%

Pressurizer pressure greater than 2100 psig SG narrow range levels 35%-75%

TAVG 541F - 580F Control rod bank position Lo-Lo Annunciator FE2 Clear Delta I within limits specified in the COLR RO 1.12 Check Hotwell level maintained 30 to 24 by HOTWELL LEVEL controller (CP-4055F) in Auto.

At Lead Examiners discretion, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 1 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Indications Available The following will be in alarm: - SGFP Speed Decreasing 1A or 1B SGFP Tripped (KC3) - Feed Flow Decreasing SG LVL DEV (JF1, JF2, JF3) - FRV-controller FK-496, 497, 498 demand SG LO LVL (JA1, JA2, JA3) increasing SG STM Flow > Feed Flow (JB1, JB2, JB3) - SG Levels decreasing Time Position Applicants Actions or Behavior Comments BOP Recognizes the tripped SGFP, announces and takes immediate operator actions of AOP-13 SRO Directs immediate operator actions of AOP-13 if not performed by RO/BOP AOP-13, Condensate and Feedwater Malfunction, v 37 BOP 1 Check only one SGFP - RUNNING BOP 1 (RNO)

Proceed to step 2 BOP 2 Check Both SGFPs - TRIPPED 2.1 Check Reactor Power - LESS THAN 5%.

RO 2.1 (RNO)

Trip the reactor and go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

Note: the RX will not trip and the crew will perform their immediate operator actions of FRP-S.1

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 2 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments SRO Reactor trip Direct the reactor trip and enter EEP-0 EEP-0.0, Reactor Trip or Safety Injection, ver 45 1 Immediate Action steps of Check reactor trip. EEP-0 Check all reactor trip breakers and reactor NOTE: Reactor will NOT trip bypass breakers - OPEN. trip Check nuclear power - FALLING.

check rod bottom lights - LIT.

1.2 (RNO)

TRIP CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR RNO: Reactor is not

[] N1C11E005A tripped by RTBs or CRDM

[] N1C11E005B MG sets.

1. (RNO) FRP-S.1 entered RO Recognize the Rx did not trip and announces and take immediate operator actions of FRP-S.1 SRO If not performed by the RO or BOP, then direct the performance of the immediate operator actions of FRP-S.1 FRP-S.1, RESPONSE TO NUCLEAR POWER GENERATION/ATWT, ver 28 1 Since this was done in Check reactor trip. AOP-13, the crew may not

[] Reactor trip and bypass breakers - re-perform it.

OPEN

[] Nuclear power - FALLING

[] IF DRPI available, THEN rod bottom lights - LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 3 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 1 (RNO) Since this was done in Perform the following. AOP-13, the crew may not re-perform it.

1.1 Manually trip reactor.

1.2 IF reactor can NOT be tripped, THEN trip both MG set supply breakers.

[] N1C11E005A

[] N1C11E005B 1.3 (RNO) Critical Task - Insert 1.3 IF reactor is still NOT rods: or can emergency tripped, THEN perform the following. borate Insert control rods in manual control.

OR Verify rods insert in AUTO at greater than 48 steps per minute.

2 Check turbine tripped 2( RNO) Note: MSIV closure will be 2.1 Place main turbine emergency to TRIP required for at least 5 seconds.

2.2 IF turbine can NOT be tripped, THEN reduce GV position demand signal to zero from Ovation page 5551.

[] on GV CLOSE INTERFACE. press SELECT

[] on Popup 7079, GV MANUAL CLOSE INTERFACE press RAPID

[] on Popup 7079, GV MANUAL CLOSE INTERFACE press FUNCT ENABLE

[]on Popup 7079, GV MANUAL CLOSE INTERFACE press and hold close arrow (V) until GVs indicate CLOSED.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 4 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 2.3 IF steam flow to main turbine is NOT secured, THEN close all main steam line isolation and bypass valves.

2.4 IF any MSIV fails to close THEN place the associated test switch in the TEST position.

Note: The SRO may direct early action to open Rx trip breakers per step 7.1 (RNO) 3 Verify AFW pumps - RUNNING.

3.1 MDAFWPs - RUNNING

[] 1A amps > 0

[] 1B amps > 0 3.2 TDAFWP - RUNNING IF NECESSARY TDAFWP STM SUPP FROM 1B(1C) SG

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 at 100%

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 5 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 4 Critical Task - Emergency Initiate Emergency Boration of borate or insert rods the RCS.

4.1 IF safety injection in progress, THEN go to step 4.7.

4.2 Verify at least one CHG PUMP -

RUNNING.

4.3 Start a boric acid transfer pump.

BATP

[] 1A

[] 1B 4.4 Align normal boration.

EMERG BORATE TO CHG PUMP SUCT

[] Q1E21MOV8104 open 4.5 Establish adequate letdown.

4.5.1 Verify 45 GPM letdown orifice - IN SERVICE.

LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 6 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 4.5.2 Verify one 60 GPM letdown orifice - IN SERVICE.

LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B open

[] Q1E21HV8149C open 4.6 Establish adequate charging flow.

IF boration is from boric acid storage tank, THEN verify charging flow -

GREATER THAN 40 GPM.

OR IF boration is from the RWST, THEN verify charging flow -

GREATER THAN 92 GPM.

4.7 Verify emergency boration flow adequate.

4.7.1 IF normal emergency boration flow path aligned, THEN check emergency boration flow greater than 30 GPM.

BORIC ACID EMERG BORATE

[] FI 110

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 7 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 4.7.2 IF manual emergency boration flow path aligned, THEN check boric acid flow greater than 30 GPM.

MAKEUP FLOW TO CHG/VCT

[] BA FI 113 4.7.3 IF boration is from the RWST, THEN verify charging OR HHSI flow - GREATER THAN 92 GPM.

4.8 Check pressurizer pressure LESS THAN 2335 psig.

5 Verify containment ventilation isolation.

5.1 Verify containment purge dampers - CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 8 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 5.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 5.3 Stop MINI PURGE SUPP/EXH FAN.

6 Check SI actuated.

6.1 Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB-1 1-1 lit

[] MLB-1 11-1 lit 6 (RNO)

[CA] IF an SI signal is actuated during this procedure, THEN initiate ATTACHMENT 1, indication. AUTOMATIC SAFETY INJECTION VERIFICATION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 9 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 7 Check the following trips.

7.1 Verify all reactor trip and and reactor trip bypass OPEN.

7.1 (RNO) Contacts the ROVER 7.1 Locally open the reactor trip reactor trip bypass breakers 7.2 MSIVs are closed Check turbine - TRIPPED.

[] TSLB2 14-1 lit

[] TSLB2 14-2 lit TURB BLDG)

[] TSLB2 14-3 lit

[] TSLB2 14-4 lit 8

[CA] Check if reactor still critical.

Check power range indication

- GREATER THAN OR EQUAL TO 5%.

PR1(2,3,4)

PERCENT FULL POWER

[] NI 41B

[] NI 42B

[] NI 43B

[] NI 44B OR Check any intermediate range startup rate - POSITIVE.

IR1(2)

S/U RATE

[] NI 35D

[] NI 36D 8 (RNO)

Go to procedure and step in effect.

At discretion of lead examiner move to next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 1 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Indications Available

- PRZR Level lowering Numerous Annunciator and alarms.

- RCS Presure lowering

- Automatic SI

-RVLIS all RED Time Position Applicants Actions or Behavior Comments Note: Once the LBLOCA Occurs, the SRO will direct the immediate operator actions of EEP-0.0. Will go to FRP-Z.1 EEP-0.0, Reactor Trip or Safety Injection, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 2 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit RO/BOP 3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

4.2 Verify both trains of SI- ACTUATED.

[] MLB1 1-1 AND MLB1 11-1 lit Per SOP-0.8, TRANSIENT RESPONSE PROCEDURE USER'S GUIDE, the operator may start CS pumps to back up ESF equipment and the Orange path may not exist.

SRO Directs entry into FRP-P.1 FRP-P.1, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK CONDITIONS, v 20 RO 1 Adverse numbers will apply.

Checjk RCS pressure - GREATER THAN Adverse number are in { }.

275psig {435psig}

RO 1(RNO)

IF LHSI flow greater than1.5x103 gpm, THEN return to procedure and step in effect.

SRO Exits FRP-P.1 and Enters FRP-Z.1 or EEP-0

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 3 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments FRP-Z.1, RESPONSE TO HIGH CONTAINMENT PRESSURE, ver 15 RO 1 Verify PHASE A CTMT ISO.

1.1 Verify PHASE A CTMT ISO -

ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 1.2 Check all MLB-2 lights - LIT.

2 Verify containment ventilation isolation.

2.1 Verify containment purge dampers - CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 2.2 Verify containment mini purge dampers - CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 2.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 4 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 3 Critical task - CS must be

[CA] Check if containment spray actuated manually. May is required. be performed earlier when recognized by operators.

3.1 Containment pressure - HAS RISEN TO GREATER THAN 27 psig. in effect.

3.2 Verify PHASE B CTMT ISO -

ACTUATED.

[] MLB-3 1-1 lit

[] MLB-3 6-1 lit 3.3 Verify containment spray pumps

- RUNNING.

3.4 Check containment spray flow in both trains - GREATER THAN 0 gpm.

CS FLOW

[] FI 958A

[] FI 958B 3.5 Check all MLB-3 lights - LIT.

3.6 Stop all RCPs.

RCP

[] 1A

[] 1B

[] 1C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 5 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 4

Verify containment fan cooler alignment.

4.1 Verify all available containment fan coolers -

STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED

[] 1A

[] 1B

[] 1C

[] 1D 4.2 Verify associated emergency service water outlet valves -

OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D 5

Verify main steam line 5 isolation and bypass valves 6

Check if feed flow should be isolated to any SG.

6.1 Return to procedure and step in effect

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 6 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-0.0, Reactor Trip or Safety Injection, ver 45 RO/BOP 5 See page below Verify actuation signal automatic actions using ATTACHMENT 2, AUTOMATIC ACTIONS VERIFICATION.

RO/BOP 6

[CA] Check containment pressure - HAS REMAINED LESS THAN 27 psig.

CTMT PRESS

[] PR 950 6(RNO)

Perform the following.

6.1 Verify PHASE B CTMT ISO -

ACTUATED.

CTMT PRESS

[] PR 950 [] MLB-3 1-1 lit

[] MLB-3 6-1 lit 6.2 Stop all RCPs.

RCP

[] 1A

[] 1B

[] 1C 6.3 Verify PHASE B CTMT ISO alignment.

6.3.1 Check All MLB-3 lights lit.

6.3.2 IF any MLB-3 light NOT lit, THEN verify PHASE B CTMT ISO using ATTACHMENT 5, PHASE B CONTAINMENT ISOL

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 7 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 6.4 Critical task - CS must be Check containment spray. actuated manually. May be done in FRP-Z.1 or by 6.4.1 operators during IOAs.

Check containment spray flow in both trains greater than 0 gpm.

CS FLOW

[] FI 958A

[] FI 958B 6.4.2 IF containment spray flow in both trains NOT greater than 0 gpm, THEN verify containment spray pump suction valves open.

RWST TO 1A(1B) CS PUMP

[] Q1E13MOV8817A

[] Q1E13MOV8817B 6.4.3 IF unable to establish spray flow in a train, THEN secure containment spray pump in affected train.

[] CS RESET TRN A(B) containment spray signals - RESET (Annunciator EE4 clear).

[] CTMT SPRAY PUMP 1A(B) -

STOPPED in affected train RO/BOP 7 Announce "Unit 1 reactor trip and safety injection."

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 8 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO/BOP 8 Check AFW status.

8.1 Check secondary heat sink available.

[] Total feed flow to SGs - pumps started.

GREATER THAN 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B TDAFWP STM SUPP

[] FI 3229C FROM 1B(1C) SG AFW TOTAL FLOW

[] FI 3229

[] Narrow range level in at least one SG - GREATER THAN 31%{48%}

8.2 WHEN all SG narrow range levels less than 31%{48%},

THEN maintain total AFW flow greater than 395 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 9 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 8.3 WHEN at least two SG narrow range levels greater than 28%

AND TDAFWP NOT required, THEN stop TDAFWP 8.4

[CA] WHEN SG narrow range level greater than 31%{48%},

THEN maintain SG narrow range level 31%-65%{48%-65%}.

8.4.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 10 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 8.4.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted RO 9 Check RCS temperature.

-IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547F.

TAVG 1A(1B,1C) RCS LOOP

[] TI 412D 9.1.1 Verify steam dumps closed.

[] TI 422D

[] TI 432D OR IF no RCP running, THEN check RCS cold leg temperature - STABLE AT OR closed.

APPROACHING 547F.

RCS COLD LEG TEMP RECORDER

[] TR 410

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 11 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 9 (RNO)

Perform the following.

9.1 IF RCS temperature less than 547F and falling, THEN perform the following. IF RCS temperature greater than 547F and rising, THEN proceed to RNO Step 9.2.

9.1.1 Verify steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[] B TRN in OFF RESET 9.1.2 Verify atmospheric reliefs closed 1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A

[] PC 3371B

[] PC 3371C 9.1.3 IF cooldown continues, THEN control total AFW flow to stop RCS cooldown.

9.1.4 IF MSIVs are closed THEN proceed to Contacts TB SO step 9.1.9 9.1.9 IF main steam lines isolated AND gland steam supplied from Unit 1, THEN break condenser vacuum.

COND VAC BKR MAN ISO (155 ft, TURB BLDG)

[] N1N51V518A open

[] N1N51V518B open COND VAC BKR VLVS

[] N1N51V519A/519B open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 12 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 9.2 This step is N/A IF RCS temperature greater than 547F and rising, THEN perform the following.

RO 10 Check pressurizer PORVs and spray valves.

10.1

[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

10.1.1 Verify both PRZR PORVs indicate CLOSED 10.1.2 Check PRZR PORV temperature STABLE OR FALLING

[] PORV Temp TI-463 10.1.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 10.2

[CA] WHEN pressurizer pressure less than 2260 psig, spray flow. THEN verify normal pressurizer spray valves closed OR closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C

[] PK 444D 10.3 Check any PRZR PORV ISO - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 13 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 11 Check RCP criteria.

11.1 Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16F{45F}

SUBCOOLED IN CETC MODE.

RO 12 Monitor charging pump miniflow criteria.

12.1 Control charging pump miniflow valves based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

[] PI 402A

[] PI 403A RO 13 Check SGs not faulted.

13.1 Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 14 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 14 Check SGs not ruptured.

- Check secondary radiation indication - NORMAL.

[] R-15 SJAE EXH

[] R-19 SGBD SAMPLE

[] R-23A SGBD HX OUTLET

[] R-23B SGBD TO DILUTION

[] R-15B TURB BLDG VNTL (BOP)

[] R-15C TURB BLDG VNTL (BOP)

[] R-60A MS ATMOS REL (BOP)

[] R-60B MS ATMOS REL (BOP)

[] R-60C MS ATMOS REL (BOP)

[] R-60D TDAFWP EXH (BOP)

- No SG level rising in an uncontrolled manner.

15 Check RCS intact.

Check containment radiation -

NORMAL.

[] R-2 CTMT 155 ft

[] R-7 SEAL TABLE

[] R-27A CTMT HIGH RANGE (BOP)

[] R-27B CTMT HIGH RANGE (BOP)

Check containment pressure -

LESS THAN 3 psig.

Check containment ECCS sump level - LESS THAN 0.4 ft.

15(RNO)

Go to FNP-1-EEP-1, LOSS OF REACTOR OR SECONDARY COOLANT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 15 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-1, LOSS OF REACTOR OR SECONDARY COOLANT, ver 31 RO 1 Check RCP criteria. RCPs will already be Check SUB COOLED MARGIN MONITOR secured indication - GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

BOP 2 Check SGs not faulted.

Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

BOP 3 Check intact SG levels.

3.1 Check any intact SG narrow range level -

GREATER THAN 31%{48%}.

3.2 WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG narrow range level 31%-65%{48%-65%}.

3.2.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD 3.2.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted Time Position Applicants Actions or Behavior Comments

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 16 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP (step 4) Check secondary radiation indication - NORMAL.

Checks rad monitors RO 5 Check pressurizer PORVs 5.1 Check any PRZR PORV ISO - power available 5.2

[CA} WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.

5.2.1

[] Verify both PRZR PORVs - CLOSED 5.2.2 Check PRZR PORV temperature STABLE OR FALLING.

[] PORV Temp TI-463 5.2.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 5.3

[] Check at least one PRZR PORV ISO -

OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 17 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments SRO 6 NOTE: These steps will be Perform the following within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of start passed off to the SSS of event.

6.1 Close recirculation valve disconnects using ATTACHMENT 1.

6.2 Establish 1A and 1B post LOCA containment hydrogen analyzers IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.

6.3 Plot hydrogen concentration on FIGURE 1.

6.4 Check containment hydrogen concentration - LESS THAN 3.5%.

6.5 Check containment hydrogen concentration - LESS THAN 0.5%.

SRO 7 Evaluate SI termination criteria 7.1 Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

7.2 Check secondary heat sink available.

[] >395 gpm AFW flow OR

[] > 31%{48%} SGNR level 7.3 Check RCS pressure - STABLE OR RISING

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 18 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 7.4 Check pressurizer level GREATER THAN 13%{43%}.

Continue to step 8 since a known LOCA exists RO 8 Check containment spray system.

8.1 Check any CS PUMP - STARTED.

8.2 Reset containment spray signals.

CS RESET

[] A TRN

[] B TRN 8.3

[CA] WHEN containment spray recirculation flow has been aligned for at least 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, AND containment pressure is less than 16 psig, THEN stop both CS PUMPs.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 19 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 9 Check if LHSI Pumps should be stopped.

9.1 Check RCS pressure - GREATER THAN 275 psig{435 psig}

[] PT-402 AND 403 9.1.1 (RNO)

Establish CCW flow to RHR Hxs CCW TO 1A(1B) RHR HX

[] Q1P17MOV3185A open

[] Q1P17MOV3185B open 9.1.2 (RNO)

Proceed to step 11 BOP 11

[CA] Verify 4160 V busses energized.

11.1 Perform ATTACHMENT 4, VERIFYING 4160 V BUSSES ENERGIZED.

RO 12 Check diesel generators.

12.1

[CA] Monitor any loaded diesel generator for proper voltage, frequency and load.

12.2

[CA] Secure any unloaded diesel generators using FNP-0-SOP-38.0,DIESEL GENERATORS.

SRO 13 Begin evaluation of plant status.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 20 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 13.1 Verify cold leg recirculation capability

- AVAILABLE.

13.1.1 Train A equipment available:

1A RHR Pump CTMT SUMP TO 1A RHR PUMP Q1E11MOV8811A CTMT SUMP TO 1A RHR PUMP Q1E11MOV8812A 1A RHR HX TO CHG PUMP SUCT Q1E11MOV8706A CCW TO 1A RHR HX Q1P17MOV3185A OR 13.1.2 Train B equipment available:

1B RHR Pump CTMT SUMP TO 1B RHR PUMP Q1E11MOV8811B CTMT SUMP TO 1B RHR PUMP Q1E11MOV8812B 1B RHR HX TO CHG PUMP SUCT Q1E11MOV8706B CCW TO 1B RHR HX Q1P17MOV3185B 13.2 Begin taking ECCS logs.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 21 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 13.3 Evaluate RCS sampling requirements.

13.3.1 Consult TSC staff to evaluate need for RCS sampling.

13.3.2 IF RCS sample required, THEN direct Chemistry to sample RCS using FNP-0-CCP-1300, CHEMISTRY AND ENVIRONMENTAL ACTIVITIES DURING A RADIOLOGICAL ACCIDENT 13.4 Check no intersystem outside CTMT.

13.4.1 Check auxiliary building radiation -

NORMAL.

[] R-3 RADIOCHEMISTRY LAB

[] R-4 1C CHG PUMP RM

[] R-5 SFP RM

[] R-6 SAMPLE RM AREA

[] R-8 DRUMMING STATION

[] R-10 PRF.

[] R-17A OR R-17B CCW 13.4.2 Check auxiliary building room sumps - HI LVL ALARMS CLEAR AND NO SUMP PUMPS RUNNING IN AUTO. (BOP)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 22 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 13.4.3 Check WHT and FDT levels -

NO EXCESSIVE OR UNEXPLAINED LEVEL RISE.

13.4.4 Check PI600A(B) 1A(1B) RHR PUMP DISCH PRESS - LESS THAN 450 psig 13.5 Verify at least one train of PRF in operation using FNP-1-SOP-60.0, PENETRATION ROOM FILTRATION SYSTEM.

13.6 Verify VCT level - GREATER THAN 5%.

RO 14 Check LHSI flow in progress.

14.1 Check RCS pressure - LESS THAN 275 psig{435 psig}.

1C(1A) LOOP RCS NR PRESS

[] PI 402B

[] PI 403B 14.2 Verify both LHSI flows - GREATER THAN 1.5x103 gpm.

1A(1B) aligned.

RHR HDR FLOW

[] FI 605A RHR PUMPS

[] FI 605B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 23 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 15 Check when to transfer to cold leg recirculation.

15.1 Check RWST level - LESS THAN RWST LVL

[] LI 4075A

[] LI 4075B 15.2 Go to FNP-1-ESP-1.3, TRANSFER TO COLD LEG RECIRCULATION.

Expected exam termination point

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 24 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 2, ver 45 1

Verify one CHG PUMP in each train -

BOP STARTED.

[] A train (1A or 1B) amps > 0

[] B train (1C or 1B) amps > 0 BOP 2 Verify RHR PUMPs - STARTED.

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP 3 Verify Safety Injection Flow.

3.1 Check HHSI flow - GREATER THAN 0 gpm.

[] FI 943 BOP 3.2 Operator should proceed to Check RCS pressure - LESS THAN step 4 275 psig{435 psig}.

BOP 4 Verify each SW train - HAS TWO SW PUMPs STARTED.

[] A train (1A,1B or 1C)

[] B train (1D,1E or 1C)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 25 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 5 Verify each train of CCW - STARTED.

5.1 Verify one CCW PUMP in each train-STARTED.

A train HX 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 26 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 6 Verify containment ventilation isolation.

6.1 Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 6.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 6.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 27 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 7 Verify containment fan cooler alignment.

7.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[] 1A

[] 1B B train

[] 1C

[] 1D 7.2 Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 28 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 8 Verify AFW Pumps - STARTED.

8.1 Verify both MDAFW Pumps - STARTED

[] 1A MDAFW Pump amps > 0

[] 1B MDAFW Pump amps > 0 AND

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 29 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 8.2 Check TDAFW Pump start required.

8.3 Verify TDAFWP started.

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

8.4 Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 30 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 9 Verify main feedwater status.

Verify main feedwater flow control and bypass valves - CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[] FCV 488

[] FCV 498 9.2 Verify both SGFPs - TRIPPED.

9.3 Verify SG blowdown - ISOLATED.

1A(1B,1C) SGBD ISO

[] Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample - ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 31 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 10 Check no MSL isolation actuation signal present.

BOP 10 (RNO)

Perform the following.

10.1 Verify main steam line isolation and bypass valves closed.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYP

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 32 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 11 Verify PHASE A CTMT ISO.

11.1 Verify PHASE A CTMT ISO - ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO BOP 12 Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP 13 Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11E005A

[] N1C11E005B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 33 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 14 Secure secondary components.

14.1 Stop both heater drain pumps.

HDP

[] 1A

[] 1B 14.2 Check any condensate pump started.

14.2.1 IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 14.3 IF condensate pump operating, Will call TBSO to THEN verify backup cooling aligned to accomplish this.

condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP 15 Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN BOP 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810 - OPEN

[] 914 - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 34 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 17 Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 35 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 4, ver 45 BOP 1 Verify two trains of ECCS equipment aligned.

1.1 - 1.4

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 closed 1.5

[] Verify two trains of battery chargers -

energized

[] A Train (1A or 1C) amps > 0

[] B Train (1B or 1C) amps > 0 1.6 Verify two trains of ESF equipment aligned.

1.6.1 Check all MLB-1 lights LIT 1.6.2 Verify charging pump suction and discharge valves - OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 36 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B 1.8 WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP 1.9 Call Radside SO Verify SFP Cooling in service per SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of EEP-0, Attachment 4

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 37 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-1, LOSS OF REACTOR OR SECONDARY COOLANT ATT 4, ver 31 BOP 1 Verify 4160 V busses energized.

1.1 Check offsite power - AVAILABLE 1.2-1.5 Check the following closed DF01 DF02 DG15 DG02 1.6 Verify all RCP busses - ENERGIZED.

1.7 Check 1E 4160V bus - ENERGIZED 1.8 Check 1D 4160V bus - ENERGIZED 1.9 Establish power to 1A 600 V LC emergency section loads.

1.9.1 Place handswitch for pressurizer heater group 1A in OFF.

1.9.2 Verify open BKR EA08-1.

1.9.3 Verify closed BKRs ED08-1 and EA09-1.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 38 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 1.9.4 WHEN pressurizer heater group 1A operation is desired, THEN place HTR GRP 1A BLOCKING BYPASS SW to BYPASS.

1.9.5 IF required, THEN manually energize pressurizer heater group 1A.

1.10 Verify 1C air compressor in service.

1.11 Check INST AIR PRESS PI 4004B - -

GREATER THAN 85 psig.

1.12 Verify instrument air aligned to containment. (BOP)

IA TO PENE RM

[] N1P19HV3825 open

[] N1P19HV3885 open IA TO CTMT

[] Q1P19HV3611 open End of EEP-1 ATT 4

Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #3 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 07/21/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 3 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1 Section 4.1 - complete through step 23, Ramp on hold while investigating Feed water Dissolved Oxygen, 1B MDAFWP tagged out.

Turnover:

• 95% power, Impulse Loop not in service, MOL, Cb 977 ppm.

• Ramp to 100%. , UOP-3.1 Section 4.1 - complete through step 23.

• Ramp on hold while investigating Feed water Dissolved Oxygen

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond A (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

Event Malf. No. Event Event No.

Type* Description 1 N (BOP) Shift from 1C to 1B CCW pump running for adding oil to the 1C CCW pump.

2 cmfmalf / C (BOP) 1A Reactor Cavity Cooling fans trips.

cVH3310A_d_co1 3 cnh/ I (RO) PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can be PK4 manually closed. (P-CT) 44D-A /

4 cnh/ C (BOP) FCV-488, 1B SG FW FLOW, closes in auto. Can be manually re-FK488-A/ opened.

(P-CT) 5 malf/r R (RO) Rod F2 drops to the bottom of the core.

MAL-ROD517 TS (SRO) TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A 6 cnh/ C (RO) LK-459F, PRZR LVL, fails low.

LK459F-A 7 cmfmalf / TS (SRO) DC control power breaker for DG08, 1B DG output breaker, trips.

cBK1DG08_d_cp1 TS - 3.8.1 Cond B 8 malf/r/ M (ALL) Rod F14 drops to the bottom of the core. Requires a Reactor trip.

MAL-ROD523 Rod P10 is stuck. Emergency boration required.

preset C (RO) 9 malf/r/ M (ALL) 1C SGTR @ 300 gpm after emergency boration started in ESP-MAL-RCS4C 0.1. (CT-18, CT-19)

Terminate when RCS cooldown is completed.

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario Presets Form ES-D-1 EVENT TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-221 (Base IC-60) rst 221 0 0 Generic setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc3.txt 0 0 Freeze Xe set crxefast=0 0 0 RUN PRESETS setup Tag out 1B MDAFW pump

• irf cAFP01B_d_cd1 open 8 Rod P10 stuck

• imf mal-rod124 Triggers and Commands

MCB setup OVATION Clear OVATION alarms Place danger TAG ON 1B MDAFW Pump HS on MCB Place tag on 1B MDAFWP HS Provide a marked up copy of UOP-3.1 UOP-3.1 Section 4.1 - up through step 23 marked off Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms Unit 1 Train B Bypass & Inoperable Status Ind Panel on AFW Switch in ON EPB - AFW SYSTEM Switch in ON IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Unfreeze Xe set crxefast=1 Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0

MCB setup VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 Start of Shift from 1C to 1B CCW pump running.

exam 2 NRC 1A Reactor Cavity Cooling fans trips.

CUE imf chv3310a_d_co1 3 NRC PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can CUE be manually closed.

imf pk444d-a 10 15 4 NRC FCV-488, 1B SG FW FLOW, closes in auto. Can be CUE manually re-opened.

imf fk488-a 0 60 5 NRC Rod F2 drops to the bottom of the core. Ramp down TS CUE - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A.

imf mal-rod517 6 NRC LK-459F, PRZR LVL, fails low.

CUE imf lk459f-a 0 15 7 NRC DC control power breaker for DG08, 1B DG output CUE breaker, trips. TS - 3.8.1 Cond B imf cbk1dg08_d_cp1

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 8 NRC Rod F14 drops to the bottom of the core. Requires a CUE Reactor trip.

imf mal-rod523 Rod P10 is stuck. Emergency boration required. preset 9 NRC 1C SGTR @ 300 gpm after emergency boration started CUE in ESP-0.1.

imf mal-rcs4c 300 120 NRC END OF EXAM:

CUE RCS Cooldown completed Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen3grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 NONE REQUIRED 8 IF REQUESTED cae Turbine_Bldg_MSRs.cae (10 minutes after requested, SOP-0.0 actions for a Rx trip/Safety Injection) 9.1.7 RNO of EEP-0 cae 2015_TB_MSDP_iso.cae (5 minute after requested) 9 IF REQUESTED 3 minutes after requested - Perform step 3.4.1 of EEP-3.0 at the HSDP.

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the inform supervision) cue and that type of communications 1 NO ADDITIONAL REQUIRED 2 NO ADDITIONAL REQUIRED 3 NO ADDITIONAL REQUIRED 4 IF REQUESTED ROVER: 3 minutes after requested - No obvious problems noted with 1B FRV.

5 IF REQUESTED MAINT: We do not want you to disconnect the lift coil until troubleshooting is completed but we have determined that the use of rods in manual is acceptable.

SSS/RX ENG: Fuel preconditioning is 95%.

U2/SSS: I will perform STP-7.0 for Unit 1. (Booth Operator will use IPC and report back QPTR in 5 minutes.)

6 NO ADDITIONAL REQUIRED 7 IF REQUESTED DB SO: 3 minutes after requested - DG08 control power breaker is tripped.

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

8 IF REQUESTED TB SO: 10 minutes after requested - SOP-0.0 actions for a Rx trip/Safety Injection are complete.

RAD 1 SO: I will verify SFP cooling in service per SOP-54.0 HP: We will monitor main steam lines for high radiation using FNP-0-RCP-25, HEALTH PHYSICS ACTIVITIES DURING A RADIOLOGICAL ACCIDENT.

Chemistry: We will sample SGs for gross activity using FNP-0-CCP-31, LEAK RATE DETERMINATION.

ROVER: 3 minutes after requested - Step 3.4.1 of EEP-3.0 is complete.

Counting room: We will perform FNP-0-CCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.

Appendix D Scenario Detailed Summary Form ES-D-1 Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1 Section 4.1 - complete through step 23, Ramp on hold while investigating Feed water Dissolved Oxygen, 1B MDAFWP tagged out.

Turnover:

• 95% power, Impulse Loop not in service, MOL, Cb 977 ppm.

• Ramp to 100%. , UOP-3.1 Section 4.1 - complete through step 23.

• Ramp on hold while investigating Feed water Dissolved Oxygen

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond A (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

EVENT 1: Shift from 1C to 1B CCW pump running for adding oil to the 1C CCW pump.

Verifiable actions: The BOP opens MOV-3185A, CCW TO 1A RHR HX, Simultaneously starts the 1B CCW pump and stops the 1C CCW pump.

Event 2: The 1A Reactor Cavity Cooling fan trips.

Verifiable actions: BOP starts the 1B Reactor Cavity Cooling fan.

Event 3: PCV-444D, 1B LOOP SPRAY VLV, opens in auto Verifiable actions: RO takes manual control of PK-444D and closes it. RO may energize additional Pressurizer heaters.

(P-CT) If the RO does not close PCV-444D and control RCS pressure, a low pressure Reactor trip will occur.

(Similar to Audit) On the Audit exam the Spray valve drifts open in manual and is stuck open.

Event 4: FCV-488, 1B SG FW FLOW, closes in auto.

Verifiable actions: BOP will manually open FCV-488 and restore SGWL in the 1B SG.

(P-CT) If the BOP fails to properly control SGWL a LOLO Level Reactor trip will occur if 1 SG reaches 28% or if 1 SG reaches 82% a turbine trip will occur causing a reactor trip.

Event 5: Rod F2 (Control Bank C) will drop to the bottom of the core.

Verifiable actions: RO will use rods and boron to reduce power to <50%.

SRO - Tech Spec: 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A.

Event 6: LK-459F, PRZR LVL, fails low.

Verifiable actions: RO will have to take manual control of LK-459F or FK-122 to control pressurizer level.

Event 7: DC control power breaker for DG08, 1B DG output breaker, trips.

Verifiable actions: SRO Tech Spec: 3.8.1 Cond B Event 8: F14 Rod drops to the bottom of the core which requires a Reactor trip. Rod P10 is stuck and an Emergency boration required.

Verifiable actions: RO emergency borates for one rod stuck.

Event 9: A 300 gpm SGTR develops on the 1C SG.

Verifiable actions: Isolate the ruptured SG (CT-18) and Control Initial RCS cooldown (CT-19).

Similar to Audit - Audit exam is 450 gpm leak and on the 1A SG which does not require isolation of the TDAFWP steam supplies at the HSDP.

Terminate when RCS cooldown is completed.

Appendix D Scenario Critical Tasks Form ES-D-1

_____ 1. Isolate feedwater flow into and steam flow from the ruptured SG before a transition to ECA-3.1 occurs. Failure would be a required transition to ECP-3.1.

(CT-18)

_____ 2. Establish/maintain an RCS temperature so that transition from E-3 does not occur because the RCS temperature is in either of the following conditions:

Too high to maintain minimum required subcooling.

OR Below the RCS temperature that causes an extreme (RED path) or a severe (ORANGE path) challenge to the subcriticality and/or the integrity CSF. (CT-19)

SCENARIO At power power instrument and component failures with a SGTR.

OBJECTIVE/ The team should be able to:

OVERVIEW:

• BOP will shift running CCW pumps

• respond to a tripped Rx Cavity Cooling fan

• respond to a failure of B loop Spray Valve

• respond to a failed Feedwater Regulating Valve

• ramp down in response to a dropped control rod

• respond to LK-459F failing low.

• evaluate Technical Specifications for a tripped control power breaker

• trip the Rx in response to a second dropped rod

• emergency borate due to a stuck rod

• isolate a SG and cooldown the plant in response to a SGTR Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 1

2. Abnormal events (2-4) 5

3. Major transients (1-2) 2

4. EOPs entered/requiring substantive actions (1-2) 1

5. EOP contingencies requiring substantive actions (0-2) 0

6. Critical tasks (2-3) 4

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 1, 95% RTP, 977 ppm Cb, MOL 10000 MWD/MTU, -2181 pcm Xe A Trn O/S / A Trn Protected / SFPC on A Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 167 hours0.00193 days <br />0.0464 hours <br />2.761243e-4 weeks <br />6.35435e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. Start 1B CCW Pump and secure 1C CCW pump in preparation for oil addition to 1C CCW pump prior to ramp.

3. UOP-3.1, Section 4.1 through Step 23 is complete.

4. Impulse loop is NOT in service.

5. Ramp is on hold while Chemistry investigates Feedwater Dissolved Oxygen.

6. 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

7.

8.

9.

10.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas) 1B MDAFW pump - 3.7.5 Cond B LCO status (planned- entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago) #1 RHT Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __1___ Page 1 of 2 Event

Description:

Shift from 1C to 1B CCW pump running for oil addition to 1C CCW pump.

Indications Available N/A Time Position Applicants Actions or Behavior Comments SOP-23, COMPONENT COOLING WATER SYSTEM, ver 94.2 BOP 4.7 Shifting CCW Pumps on the On-Service Train BOP 4.7.1 Monitor CCW flow annunciators and RCP thermal barrier valves during and after this evolution.

BOP 4.7.2 IF A Train is the on service train, THEN open CCW TO 1A RHR HX Q1P17MOV3185A.

BOP 4.7.3 This step is N/A IF B Train is the on service train, THEN open CCW TO 1B RHR HX Q1P17MOV3185B.

BOP 4.7.4 Simultaneously start the Standby CCW pump and stop the on service CCW pump.

BOP 4.7.5 Verify the proper flow response on the appropriate flow indicator.

FI 3043AA FI 3043BA, FI 3043CA BOP 4.7.6 IF A Train is the on service train, THEN close CCW TO 1A RHR HX Q1P17MOV3185A unless required to support RHR operation.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __1___ Page 2 of 2 Event

Description:

Shift from 1C to 1B CCW pump running for oil addition to 1C CCW pump.

Time Position Applicants Actions or Behavior Comments BOP 4.7.7 This step is N/A IF B Train is the on service train, THEN close CCW TO 1B RHR HX Q1P17MOV3185B unless required to support RHR operation.

BOP 4.7.8 This step is N/A IF placing 1B CCW pump in service to replace an inoperable CCW pump, THEN perform one of the following.

(Otherwise 1B CCW pump will not sequence on following a SI/LOSP)

At the discretion of the Lead Examiner, move to the next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __2___ Page 1 of 2 Event

Description:

1A Reactor Cavity Cooling fans trips.

Indications Available

- BD1, 1A RX CAV CLG FAN FAULT

- BD3, BOTH RX CAV CLG FANS STOPPED Time Position Applicants Actions or Behavior Comments ARP-1.2, BD3, BOTH RX CAV CLG FANS STOPPED BOP 1 IF one of the reactor cavity cooling fans has tripped, THEN start the other fan.

BOP 2 This step is N/A IF no cavity cooling is available, then the unit should be shutdown to at least hot standby within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. Subsequent monitoring of the cavity area around the NI's is then needed to determine if further cooldown is needed.

3 Reviews SOP-12.1, for any Refer to FNP-1-SOP-12.1, additional actions (there are CONTAINMENT AIR COOLING SYSTEM. none) 4 Notify appropriate personnel to locate and Contacts SSS to write CR correct the cause of the alarm as soon as etc possible.

ARP-1.2, BD1, 1A RX CAV CLG FAN FAULT, ver 45 BOP 1 Start 1B RX CAV CLG FAN.

BOP 2 Fan is not running IF still running, THEN stop 1A RX CAV CLG FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __2___ Page 2 of 2 Event

Description:

1A Reactor Cavity Cooling fans trips.

Time Position Applicants Actions or Behavior Comments BOP 3 IF no cavity cooling is available, THEN the unit should be shutdown to at least hot standby within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

Subsequent monitoring of the cavity area around the NI's is then needed to determine if further cooldown is needed.

4 Refer to FNP-1-SOP-12.1, Reviews SOP-12.1, for any CONTAINMENT AIR COOLING SYSTEM. additional actions (there are none) 5 Refer to FNP-1-ARP-1.2, Location BD3, if Goes to BD3 if not done no Reactor Cavity Cooling Fan running.

6 Notify appropriate personnel to locate and Contacts SSS to write CR correct the cause of the alarm etc as soon as possible.

At discretion of Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __3___ Page 1 of 3 Event

Description:

PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can be manually closed. (P-CT).

Indications Available

- RCS Pressure lowers - HD1, PRZR PRESS REL VLV 445A OR B/U

- PCV-444D demand goes to 100% HTRS ON, in ALARM

- PCV-444D light go OUT Time Position Applicants Actions or Behavior Comments RO Announce alarm and/or recognizes malfunction and takes immediate operator action SRO Direct entry in AOP-100 if not done by operators AOP-100, INSTRUMENTATION MALFUNCTION, ver 15 RO 1 IF required to stabilize RCS pressure, Immediate operator action.

THEN take manual control of the following equipment. Potential Critical Task - If

• Power operated relief valves PCV-444D not closed a

[ ] PRZR PORV Q1B31PCV445A low pressure Rx trip will

[ ] PRZR PORV Q1B31PCV444B occur OR If RCS pressure fall below

[ ] PRZR BLOCK VLV Q1B31MOV8000A 2209 psig then LCO - 3.4.1

[ ] PRZR BLOCK VLV Q1B31MOV8000B will be entered - Page 3

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __3___ Page 2 of 3 Event

Description:

PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can be manually closed. (P-CT).

Time Position Applicants Actions or Behavior Comments RO 2 IF pressurizer pressure is decreasing This step is N/A due to a mechanically stuck open spray valve PCV444C or PCV444D, THEN perform the following:

RO 3 This step is N/A IF PORV is open and pressurizer pressure is less than 2310 psig, THEN close the PORV.

RO 4 This step is N/A IF an alarm was caused by a CONTROL instrument (PT-444/445) OR component failure, THEN perform the following as required to restore RCS pressure to desired value.

RO 5 This step is N/A IF a PROTECTION instrument failure has occurred, THEN determine which pressure channel has caused the alarm.

SRO 6 LCO-3.4.1 may apply Refer to Tech Specs for LCO requirements that exist.

SRO 7 Notify the Shift Manager. Contacts SM 77 8

[CA] WHEN plant conditions permit, THEN restore components to automatic control.

8 9

Submit a Condition Report and notify the Work Week Coordinator (Maintenance Has RO/BOP contact ATL on backshifts). appropriate personnel

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __3___ Page 3 of 3 Event

Description:

PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can be manually closed. (P-CT).

Time Position Applicants Actions or Behavior Comments RO 10 This step is N/A IF the pressurizer power operated relief valves operated, THEN perform the following:

SRO 11 Go to procedure and step in effect.

TECHNICAL SPECIFICATION 3.4.1 - RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits 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 the COLR. The minimum RCS total flow rate shall be 263,400 GPM when using the precision heat balance method, 264,200 GPM when using the elbow tap method, and the limit specified in the COLR.

APPLICABILITY: MODE 1.

Condition A SRO CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore RCS DNB RCS DNB parameter(s) to within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> parameters not limit.

within limits..

At discretion of Lead Examiner, move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __4___ Page 1 of 3 Event

Description:

FCV-488, 1B SG FW FLOW, closes in auto. Can be manually re-opened. (P-CT).

Indications Available

- FCV-488 demand goes to 0 The following in ALARM

- 1B SGWL lowering JF2, 1B SG LVL DEV JG1, 1A SG FEDD FLOW>STM FLOW JG3, 1C SG FEDD FLOW>STM FLOW JB2, 1b SG STM FLOW > FEED FLOW Time Position Applicants Actions or Behavior Comments BOP Announces alarms and/or recognizes malfunction and take immediate operator actions of AOP-100 SRO Direct AOP entry if not performed by operators AOP-100, INSTRUMENTATION MALFUNCTION, ver 15 BOP 1 Potential critical task -

[CA] Maintain SG level at the referenced Loss of SGWL control will level of 65%. result in an automatic Rx 11 trip or a los of feed 1.1 requiring a Rx trip.

IF required, THEN, take manual control of SGFP speed control as necessary to restore SG level to 65%

.1 SGFP master controller

[ ] SK-509A OR SGFP individual controllers as needed.

[ ] SK-509B

[ ] SK-509C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __4___ Page 2 of 3 Event

Description:

FCV-488, 1B SG FW FLOW, closes in auto. Can be manually re-opened. (P-CT).

Time Position Applicants Actions or Behavior Comments 1.2 IF required, THEN take manual control of the affected feedwater regulating valves or bypass valves.

1.2

[ ] 1A SG FW FLOW FK-478

[ ] 1B SG FW FLOW FK-488

[ ] 1C SG FW FLOW FK-498 OR

[ ] 1A SG BYPASS FLOW FK-479

[ ] 1B SG BYPASS FLOW FK-489

[ ] 1C SG BYPASS FLOW FK-499 1.3 A loss of main feedwater IF a loss of main feedwater has occurred, will not occur if the FRV is THEN perform the actions required by opened FNP-1-AOP-13.0, LOSS OF MAIN FEEDWATER.

SRO 2 Normal trip criteria is 80%

IF adverse trend in SG level exists, rising and 30% lowering THEN establish trip criteria.

2 BOP 3 IF a ramp is in progress, THEN place Turbine on HOLD.

4 This step is N/A Determine if an instrument failure has occurred.

4 4.1 Check for a failed or erroneous indications from the following steam flow or feed flow indicators.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __4___ Page 3 of 3 Event

Description:

FCV-488, 1B SG FW FLOW, closes in auto. Can be manually re-opened. (P-CT).

Time Position Applicants Actions or Behavior Comments 4.2 This step is N/A Check for failed or erroneous readings on the following SG pressure indicators:

4.3 This step is N/A IF the alarm(s) was due to a SGWLC System controlling channel failure, THEN select the unaffected channel for STM FLOW AND FW FLOW for the SG associated with the failure.

5 No LCO entries Refer to Tech Specs 3.3.1, 3.3.2 & 3.3.3 for any LCO requirements.

SRO 6 Contacts SM Notify the Shift Manager.

7 N/A

[CA] WHEN plant conditions permit, THEN return systems to automatic control.

7 Directs RO/BOP to contact SRO 8 appropriate personnel Submit a condition report for the failed instrument, and notify the Notify the Work Week Coordinator (Maintenance ATL on backshifts)of the condition report.

8 SRO 9 Go to procedure and step in effect.

At discretion of Lead Examiner, move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 1 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Indications Available

- Rx power initially lowers The following ALARMS -

- Neg SUR FE3, ROD AT BOTTOM

- RCS pressure lowering FF5, COMP ALARM ROD SEQ/DEV OR PR

- tavg LOWERING FLUX TILT FB4, PR UPPER DET HI FLUX DEV OR AUTO DEF FB5, PR LOWER DET HI FLUX DEV OR AUTO DEF FC5, PR CH DEV Time Position Applicants Actions or Behavior Comments RO Announces alarms and dropped rod SRO Enters AOP-19 Note: AOP-19 allows entry into specific sections based on malfunction AOP-19, MALFUNCTION OF ROD CONTROL SYSTEM BOP 1 Stop any turbine loading changes.

RO 2 Check the following:

-DRPI - AVAILABLE.

-Only one Rod dropped by observing DRPI.

3 Check rod misaligned greater than 45 steps.

4 Cond B Initiate TS 3.1.4.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 2 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments 5 RO / BOP coordinates the Maintain Tavg at program by performing restoring Tavg to Tref -

the following as appropriate: Page 10 3.4 Adjus t Turbine loa d.3.4 Dilute or bora te . 3.4 Us e m a nua l Rod control.

RO 6 Maintain power distribution when greater than or equal to 50% power:

4 6.1 AFD - WITHIN LIMITS SPECIFIED IN THE COLR.

6.2 QPTR - LESS THAN OR EQUAL TO 1.02.

6.2 RNO Initiate TS 3.2.4 TS 3.2.4 at Page 7 SRO 7 Perform the following:

7.1 Initiate action to determine cause and repair Rod Control malfunction.

7.2 With Maintenances concurrence Maintenance will request disconnect lift coil for the dropped rod. the lift coil NOT operated

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 3 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments RO 8 Record the following in the Unit Control Log.

Re cord the following in the Unit Control Log.

Droppe d Rod numbe r.

Initia l P owe r Le ve l.

Affe cte d group s te p counte r pos ition.

RO 9 FC3 is clear & bistables not Check Annunciator FC3, PR Hi Flux illuminated Rate Alert is clear.

TS LB-2 NI Hi rate bistables not illuminated.

RO/BOP 10 See Event 6 for Ramp Reduce Thermal Power to less than 75%

within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from time of Rod drop using FNP-1-UOP-3.1, POWER OPERATION.

NOTE: Step 10 and event 6 run concurrently - Event 7 & 8 will be inserted as desired by Lead Examiner after desired ramp and demonstration of use of SOP-2.3 APP A SRO 11 Contact SSS or RX Check fuel preconditioned power level Engineering. Fuel is greater than or equal to 90% per Reactor preconditioned to 95%

Engineering.

11.1 Continue power reduction to less than 50% RTP as soon as possible.

Once 5% ramp is performed and event 6 &

7 are completed then at NRC CUE - insert 2nd Rod drop Event 8

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 4 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments 12 Check if rod retrieval should be initiated:

12.1 Time of dropped rod known.

12.2 Direct cause of dropped rod known and corrective action taken.

12.2 (RNO)

Perform the following:

12.2.1 Consult Reactor Engineering and Operations Management.

12.2.2 Do not continue until one of the following is satisfied:

a) IF recovery plan developed to retrieve dropped rod, THEN continue with Step 13.

-OR-b)

IF decision made to initiate a unit shutdown, THEN go to FNP-1-UOP-3.1, POWER OPERATION.

ARP-1.6, FF5, COMP ALARM ROD SEQ/DEV OR PR FLUX TILT, ver 72.1 BOP 1 N/A IF a plant transient is in progress, THEN place turbine load on "HOLD.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 5 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments RO/SRO 2 IF rod control is in automatic, THEN Determines a dropped rod determine whether rod sequence is proper occurs or improper.

2.1 If not in manual then places IF rod sequence is improper, THEN rods in Manual transfer to manual rod control.

2.2 Refer to FNP-1-AOP-19.0, AOP-19 already in progress MALFUNCTION OF ROD CONTROL SYSTEM.

RO/SRO 3 Determine cause of the alarm 3.1 IF the IPC is available, THEN using the Applications Menu, click on IPC Annunciation button.

3.2 Click on RODS displayed under WINDOW FF5, to determine cause of validity of the alarm.

3.3 Using the Applications Menu, click on IPC Annunciation button.

3.4 A tilt exists Click on TILT displayed under WINDOW FF5, to determine cause of validity of the alarm.

3.5 Note the time of the alarm from the IPC ALARM display.

3.6 Start a manual timer to alarm within 45 minutes of the time recorded in the above step.

3.7 IF the plant computer is inoperable to any Emergency Response Facility THEN restore plant computer within TRM 13.13.1 time limit.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 6 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments 3.8 Calls U2 or SSS to perform IF the plant computer is inoperable OR annunciator FF5 is otherwise inoperable, THEN within one hour perform FNP-1-STP-37.0, POWER DISTRIBUTION SURVEILLANCE (PLANT COMPUTER INOPERABLE) and all appropriate data sheets. {CMT 0008883}

RO/SRO 4. Tilt exists Determine if a Quadrant Power Tilt exists.

5. Dropped rod exists IF a Quadrant Power Tilt exists, THEN check indications for a dropped or misaligned Rod.

6. Already in AOP-19 IF a Rod Misposition exists, THEN refer to FNP-1-AOP-19.0, MALFUNCTION OF ROD CONTROL SYSTEM.

RO/SRO 7.

Closely monitor individual rod position during control rod movement to ensure correct rod control system and control rod position indicator response.

(NSAL-93-007) 8.

Notify appropriate personnel to determine Contacts SM, SS etc and correct the cause of the Rod Control System malfunction.

9. Tech Specs on Page 7 Refer to the Technical Specifications sections on Power Distribution Limits and Reactivity Control.

10.

Refer to TRM 13.13.1 for loss of event N/A assessment capability for the TSC if the IPC Host link goes down or the IPC is non-functional.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 7 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A TECHNICAL SPECIFICATION 3.1.4 Rod Group Alignment Limits 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.

APPLICABILITY: MODES 1 and 2.

Condition B SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One rod not B.1 Restore rod to within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within alignment limits.

alignment limits. OR B.2.1.1 Verify SDM to be 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within the limits provided 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 B.2.2 Reduce THERMAL 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> POWER to 75% RTP.

AND B.2.3 Verify SDM to be within Once per the limits provided in the 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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.

AND 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> B.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 8 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A TECHNICAL SPECIFICATION 3.2.4 QUADRANT POWER TILT RATIO (QPTR)

LCO 3.2.4 The QPTR shall be <1.02.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP.

Condition A CONDITION REQUIRED ACTION COMPLETION TIME A. QPTR A.1 Limit THERMAL 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after each QPTR POWER to 3% below determination not within RTP for each 1% of limit QPTR > 1.00.

AND A.2 Determine QPTR. Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND A.3 Perform SR 3.2.1.1 and 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after achieving equilibrium SR 3.2.2.1. conditions with THERMAL POWER AND limited by Required Action A.1 AND Once per 7 days thereafter A.4 Reevaluate safety Prior to increasing analyses and confirm THERMAL POWER results remain valid for above the limit of duration of operation Required Action A.1 under this condition.

AND A.5

---

NOTES-----------

1. Perform Required Action A.5 only after Required Action A.4 is completed.

2. Required Action A.6 shall be completed if Required Action A.5 is performed.

Normalize excore Prior to increasing detectors to restore THERMAL POWER QPTR to within limits. above the limit of AND Required Action A.1 A.6

---

NOTE------------

Perform Required Action A.6 only after Required Action A.5 is completed.

---

24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after achieving equilibrium Perform SR 3.2.1.1 and conditions at RTP SR 3.2.2.1. OR Within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after increasing THERMAL POWER above the limit of Required Action A.1

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 9 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A TECHNICAL SPECIFICATION 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits 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 the COLR. The minimum RCS total flow rate shall be 263,400 GPM when using the precision heat balance method, 264,200 GPM when using the elbow tap method, and the limit specified in the COLR.

APPLICABILITY: MODE 1.

---

NOTE------------------------------------------------------

Pressurizer pressure limit does not apply during:

a. THERMAL POWER ramp > 5% RTP per minute; or

b. THERMAL POWER step > 10% RTP.

Condition A CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RCS DNB A.1 Restore RCS DNB parameter(s) 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> parameters not within to within limits. limit.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 10 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments SOP-41.0, Control Rod Drive and Postion Indication System, Ver 37 OPERATOR AID FOR CONTROL ROD MOVEMENT RO 1 Place ROD CONTROL BANK SELECTOR SWITCH in MAN.

RO 2 Check indicated control rod speed is approximately 48 steps per minute on SI-408.

RO 3 Insert OR withdraw Control Rods using the CONTROL ROD MOTION switch.

RO 4 When desired, place rod control in AUTO as follows:

RO 4.1 Verify Tavg within 1°F of Tref.

RO 4.2 Place the ROD CONTROL BANK SELECTOR SWITCH in AUTO.

RO 4.3 Check indicated control rod speed is approximately 8 steps per minute on SI-408.

UOP-3.1, Power Operation, Section 4.4, ver 122 BOP 1 Review and perform the following as required

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 11 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments BOP a This step is N/A If Turbine Overspeed Test is to be performed, Refer To Section 3.0 Precaution and Limitation 1.l prior to commencing ramp...

BOP b For normal load reductions, a ramp rate restriction of 2 MW/min (14% per hour) will apply............................................................

BOP c This step is N/A When conditions warrant a ramp rate of greater than 2 MW/min, notify the Shift Manager as soon as conditions permit.

BOP d This step is N/A Enter FNP-1-AOP-17.1, RAPID TURBINE POWER REDUCTION in conjunction with this procedure for ramp rates greater than 5 MW/min.........

BOP e This step is N/A Ramp as slow as possible if known fuel leak exists. Power decreases should follow the guidance found in Attachment 1, Special Load Rate Limitations.

BOP f This step is N/A If a power reduction is being performed due to entry into Technical Specifications 3.4.16, adjust the ramp rate to meet the shutdown requirements of the specification.

BOP g This step is N/A If a reactor shutdown is NOT for a refueling outage, record criticality data in the Control Room Log prior to load decrease.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 12 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments BOP h Maintain valve position limit 115% while ramping or at 100%.

BOP i This step is N/A Maintain valve position 8 to 10% above valve position demand when holding for more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at some power level less than 100%.

BOP j This step is N/A Flush and sample AFW pump suction piping as required by FNP-1-SOP-22.0, Auxiliary Feedwater System, prior to initiation of AFW flow to the SGs.

BOP 2 BOP place IMP loop in While ramping between 97% and 20% service per step 2 power, verify the IMP PRESS LOOP in service as follows:

BOP a Verify Turbine on HOLD. ..............

BOP b Check Ovation point, 1ST STG IMPLS PRESS, has stable indication.

BOP c On LOOP STATUS of page 5551, press SELECT BOP d On popup 7053, press IMP BOP e On popup 7059, press IMP LOOP IN.

BOP f On LOOP STATUS of page 5551, check IMPULSE displays YES

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 13 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments BOP 3 On page 5551, perform the following to set desired load target and load rate.................

a On RAMP INTERFACE section, press MODIFY b

On TARGET SELECTION section of BOP inserts ramp to <48%

popup 7055, enter desired target using one of the following methods:

• Using predefined buttons.

• Using CUSTOM button to enter custom rate c

On RAMP INTERFACE section of page 5551, check desired target appears under TARGET.

d On page 5551, check HOLD button has gold background e

IF desired to change load rate, on RAMP INTERFACE section of page 5551 press MODIFY.

(1)

On popup 7055, enter desired rate by either of the following Using predefined buttons.

Using predefined buttons.

(2)

On RAMP INTERFACE section of page 5551, check desired rate appears under RATE.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 14 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments 4

Inform other Control Room operators load will be changed.

5 Press GO to commence ramp.

BOP 6 Verify proper SGFP speed control.

RO 7 Attempt to maintain the axial flux difference within + 5% from the target value by making adjustments in rod height and/or boron concentration as necessary..........

RO Uses Borations to lower Tavg during the ramp SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix B, v60.1 RO 1.1 From reactivity briefing IF necessary, THEN set the boric acid sheet integrator to the desired quantity.

RO 1.2 IF necessary, THEN adjust LTDN TO VCT FLOW LK 112 setpoint as desired.

1.3 Position the MKUP MODE CONT SWITCH to STOP.

1.4 Position the MKUP MODE SEL SWITCH to BOR.

1.5 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 15 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments RO 1.6 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.7 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.8 This step is N/A If desired to clear the line of acid, perform the applicable steps of Appendix B Section 2.0.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 16 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments Note: If the crew decides to remain lined up for repetitive borations, then steps 1.9 -

1.11 are N/A. Repetitive boration steps are listed in Appendix C below.

RO 1.9 Position the MKUP MODE SEL SWITCH to AUTO.

1.10 Position the MKUP MODE CONT SWITCH to START.

1.11 IF LK 112 setpoint was adjusted per Step 1.2, THEN return setpoint to that required for current conditions.

SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix C, v60.1 RO 1.1 IF necessary, THEN set FIS-113 Boric Acid Batch Integrator to the desired quantity.

1.2 The Reactor Makeup Control system has been previously aligned for Boration.

1.3 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 17 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments RO 1.4 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.5 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.6 IF repetitive borations are no longer required THEN verify the system is aligned for Automatic makeup per Steps 1.9 through 1.11 of Appendix B.

After the ramp or at the Lead Examiners discretion then move to the next event.

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 1 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Indications Available:

FI-122 goes to 0 gpm The following alarms LK-459F demand goes to 0 EA2 - CHG HDR FLOW HI-LO Pzr Level lowers DE1 - REGEN HX LTDN FLOW DISCH TEMP HI DC4 - SEAL WTR INJ FILTER HIGH DP Time Pos. Expected Actions/Behavior Comments SRO Direct BOP to reference ARPs BOP Performs actions of ARPs (most probably addresses ARPs by priority first)

ARPs direct entry into AOP-16.

When LK-459F failure recognized, AOP-100 will be recommended.

AOP-100, Instrumentation Malfunction, version 15, section 1.2 SRO SRO will direct entry to AOP-100. This is an expected action Place ramp on HOLD but not procedurally required by AOP-100, sect 1.2 RO 1 Checks pressurizer level on or trending to program value. (Actual PRZR level increasing)

RNO: manual control of charging flow taken

- FK-122, CHG FLOW CONTROLLER, in manual and charging flow reduced

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 2 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 1 (RNO) Take manual control of Pzr If required, THEN take manual control level using either controller of charging.

FK-122 in Manual LK-459 in Manual RO 2 Check RCP seal injection flows

- Adjusts SI flow to 6-13 gpm by using HIK-186, SEAL WTR INJECTION CONTROLLER.

SRO/ 3 Determines that no Level RO Determine if a PRZR level transmitter / instrument has failed indicator loop has failed.

LI-459, LI-460, or LI-461 SRO/ 4 RO Check letdown in service Letdown in service in

- Orifice isolation valves one or more service unless isolated due open HV-8149A,B,C, LTDN ORIF to loss of charging flow then ISO VLVS the RNO applies. Otherwise

- Flow indicated on FI-150, LTDN HX go to Step 4.2 (pg 5)

OUTLET FLOW.

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 3 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 4 (RNO)

Establish normal letdown as follows.

a)

Verify closed all letdown orifice isolation valves.

LTDN ORIF ISO 45 GPM

[ ] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[ ] Q1E21HV8149B

[ ] Q1E21HV8149C RO b)

Place LTD HX OUTLET TEMP TK 144 on service:

[ ] Place controller in AUTO

[ ] Set to maintain temperature 90°F (Pot setting 2.7) to 115°F (Pot setting 4.35) 4.3 c)

Verify VCT HI LVL DIVERT VLV LCV-115A alignment:

[ ] Position indicator VCT light - LIT

[ ] Handswitch in - AUTO d)

Verify LTDN HI TEMP DIVERT LVL Q1E21TCV143:

[ ] Handswitch in - VCT

[ ] VCT light - LIT

[ ] DEMIN light - NOT LIT

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 4 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments e) This is N/A IF necessary, THEN OPEN both LTDN LINE PENE RM ISO's Q1E21HV8175A and B from the Penetration Room Isolation Panel.

f)

Verify open LTDN LINE CTMT ISO Q1E21HV8152 g)

Verify open both LTDN LINE ISO Q1E21LCV459 and Q1E21LCV460.

h)

Verify LP LTDN PRESS PK 145 in MANUAL and adjust the demand signal to 50% or less.

i)

Verify CHG FLOW FK 122 is in MAN AND establish the required minimum charging flow for one orifice to be placed on service. (18 gpm) j)

OPEN LTDN ORIF ISO 60 GPM Q1E21HV8149B or C to establish approximately 60 gpm Letdown flow. This is N/A k)

IF letdown flow was lost with auxiliary spray in service, THEN refer to TRM 13.4.2.

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 5 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 4.2 If Letdown was not Check Letdown flow indicated. removed, this is the next 4.2 step after 4.1

[ ] FI-150 LTDN HX OUTLET FLOW.

RO 4.3 Proceed to step 6.

RO 5 Check Letdown flow established.

5.1 Check Letdown flow indicated. 5.1 5.1

[ ] FI-150 LTDN HX OUTLET FLOW.

5.2 IF Letdown flow established, THEN place LP LTDN PRESS PK-145 in AUTO as follows:

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 6 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 5.2.1 Verify that LP LTDN PRESS PK 145 is set between 4.3-7.5 to maintain the desired Letdown Pressure between 260-450 psig.

5.2.2 Place LP LTDN PRESS PK 145 in AUTO and verify that Letdown pressure is maintained at the desired value.

5.2.3 Verify that LTDN HX OUTLET TEMP TK 144 is maintaining Letdown temperature at approximately 100F.5.2.32.3

[ ] TI-116 VCT TEMP

[ ] TI-143 DIVERT LTDN HX TEMP

[ ] TI-144 CCW LTDN HX TEMP 5.2.4 See FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION, for further guidance on Charging or Letdown system.

SRO 6 N/A Refer to Tech Specs 3.3.1 & 3.3.3 determine any LCO requirements.

SRO 7 Notify Shift Manager

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 7 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO (step 8) WHEN plant conditions permit THEN restore components to automatic control as follows:

8.1 This step is N/A Restore charging flow control to automatic per FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION.

8.18.1 8.2 Restore control of pressurizer heaters. .2

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP SRO (step 9) Submit a Condition Report for failed channel and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the Condition Report.

SRO 10 Go to procedure and step in effect.

At the discretion of the Lead Examiner move to the next event

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 8 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments AOP-16, CVCS Malfunction, Ver 20 RO 1 Charging is not adequate Verify CHG flow adequate to cool letdown

[] CHG FLOW - FI-122A

[] LTDN HX OUTLET FLOW - FI-150

[] REGEN HX OUTLET TEMP - TI-140 RO 1 (RNO)

Isolate Normal Letdown as follows:

1.1 Verify closed all LTDN ORIF ISOs:

[] Q1E21HV8149A

[] Q1E21HV8149B

[] Q1E21HV8149B RO 2 Stop any load change in progress RO 3 This step is N/A If charging line rupture occurs then go to attachment 2 4

Monitor VCT level Indicates proper operation 5

Observe CHG HDR PRESS and MOTOR charging pump is running AMPS to ensure proper charging pump operation PI-121 and ammeter for chg pump 6

Check charging pump - RUNNING

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 9 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 7 FK-122 is ZERO demand Check charging flow FK-122 controlling in AUTO with flow indicated RO 7(RNO)

Take manual control of charging flow 7.1 Place FK-122 in manual 7.2 Adjust SEAL WTR INJECTION HIK_186 as required to maintain RCP seal inection flow 6-13 gpm 7.3 If manual control of charging not This step is N/A accomplished.

Refer to attachment 1. MANUAL CONTROL OF CHARGING 8

Check to following annunciator -CLEAR

[] DE3 LTDN ORIF ISO VLV REL LINE TEMP HI 9

Determine Status of Normal Letdown:

9.1 Check normal CVCS letdown -

AFFECTED BY MALFUNCTION

• LTDN HX OUTLET FLOW, FI-150 - NO FLOW INDICATED

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 10 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 11 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 9.2 Minimize RCS makeup:

9.2.1 Manually close FK-122 9.2.2 Minimize seal injection between 6-13 gpm 9.2.3 Direct Chemistry to shutdown the zinc addition system (ZAS)

RO 9.3 Dispatched personnel earlier Dispatch personnel to investigate cause of letdown malfunction RO 9.4 This step is N/A If desired due to plant conditions, place excess letdown on service RO 10 Determine if normal letdown should be re-established:

10.1 Check normal letdown malfunction(s) -

CORRECTED 10.2 Verify all letdown orifice isolation valves -

CLOSED LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 12 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 10.3 Place LTDN HX OUTLET TEMP TK-144 on service:

[] Place controller in AUTO

[] Set to maintain temp 90 (Pot setting 2.7) to 115°F (Pot setting 4.35)

RO 10.4

[] Position indicator VCT light - LIT

[] Handswitch in-AUTO RO 10.5 Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143

[] Handswitch in - VCT

[] VCT light - LIT

[] DEMIN light - NOT LIT RO 10.6 This is N/A IF necessary, THEN OPEN both LTDN LINE PENE RM ISOs from the Penetration Room Isolation Panel.

[] Q1E21HV8175A

[] Q1E21HV8175B RO 10.7 Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN RO 10.8 Verify LTDN LINE ISO valves - OPEN

[] Q121LCV459

[] Q121LCV460 RO 10.9 Verify LP LETDN PRESS PK 145 on service:

[] Place controller in MANUL

[] Adjust demand signal o 50% or less

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 13 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 10.10 Initiate minimum charging flow:

10.10.

Verify CHG FLOW FK 122 in MAN 10.10.2 Establish minimum charging flow based on orifices to be placed on service:

• 1 Orifice - 18 gpm or

• 2 Orifices - 40 gpm RO 10.11 Establish approx. 60 gpm letdown flow by OPENING:

Q1E21HV8149B OR Q1E21HV8149C RO 10.12 If desired place the second orifice on service by opening Q1E21HV8149A RO 10.13 Very time consuming and will Initiate actions to restore letdown flow to not be done during the demins per SOP-2.1 scenario

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 14 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 10.14 IF all backup heaters energized due to pzrr level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing RO 10.15 Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure - BETWEEN 260-450 psig 10.15.1 Set controller between 4.3 and 7.5 10.15.

Check letdown flow - STABLE 10.15.3 Place PK 145 in AUTO 10.15.4 Control Letdown pressure as desired RO 10.16 Control LTDN HX OUTLET TEMP TK 144 to maintain Letdown temperature 90 to 115°F

[] TI-116 VCT TEMP

[] TI-143 DIVERT LTDN HX TEMP

[] TI-144 CCW LTDN HX TEMP RO 10.17 Refer to SOP-2.1 for further guidance on Letdown system control RO 11 Determine status of letdown flow:

11.1 Check letdown flow - ESTABLISHED

• Normal letdown flow OR

• Excess letdown flow

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 15 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 11.2 Go to procedure and step in effect At the discretion of the Lead Examiner move to the next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __7___ Page 1 of 2 Event

Description:

DC control power breaker for DG08, 1B DG output breaker, trips. TS - 3.8.1 Cond B.

Indications Available 1B DG output Breaker DG-08 Green light VA4 - 1B DG BKR 52-DG08 LOSS OF DC goes out Time Position Applicants Actions or Behavior Comments BOP Announce alarm SRO Directs ARP Entry ARP-2.1, VA4, 1B DG BKR 52-DG08 LOSS OF DC, ver 35.2 BOP 1 Contacts SSS/DB SO to Notify the appropriate plant personnel to investigate determine and correct the cause of the undervoltage condition.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __7___ Page 2 of 2 Event

Description:

DC control power breaker for DG08, 1B DG output breaker, trips. TS - 3.8.1 Cond B.

TECHNICAL SPECIFICATION 3.8.1 AC SourcesOperating LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electrical Power Distribution System; and

b. Two diesel generator (DG) sets capable of supplying the onsite Class 1E power distribution subsystem(s); and

c. Automatic load sequencers for Train A and Train B.

APPLICABILITY: MODES 1, 2, 3, and 4.

Condition B SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One DG set ------------------NOTE-------------

inoperable. ------

LCO 3.0.4c is applicable when only one of the three DGs is inoperable.

B.1 Perform SR 3.8.1.1 for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> the required offsite AND circuit(s). Once per 8 AND hours thereafter B.2 Declare required 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from feature(s) supported by discovery of the inoperable DG set Condition B inoperable when its concurrent with required redundant inoperability of feature(s) is inoperable. redundant required feature(s)

AND B.3.1 Determine OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> DG set is not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.6 for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE DG set.

AND B.4 Restore DG set to 10 days OPERABLE status. AND 13 days from discovery of failure to meet LCO After 5% ramp and completion Event 6 and this event, insert Event 8 at Lead Examiners discretion

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 1 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Indications Available

- Rx power initially lowers The following ALARMS -

- Neg SUR FE3, ROD AT BOTTOM

- RCS pressure lowering FE4, TWO OR MORE RODS AT BOTTOM

- tavg LOWERING Time Position Applicants Actions or Behavior Comments SRO Returns to Step 1 of AOP-19 Section 1.3 Note: AOP-19 allows entry into specific sections based on malfunction AOP-19, MALFUNCTION OF ROD CONTROL SYSTEM v30 BOP 1 Stop any turbine loading changes.

RO 2 Check the following:

- DRPI - AVAILABLE.

- Only one Rod dropped by observing DRPI.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 2 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments 2 (RNO)

Perform the following:

2.1 Trip the Reactor.

2.2 Go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 3 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit RO/BOP 3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

RO/BOP 4.1 (RNO)

Check SI required 4.1.1 (RNO)

IF any setpoint and coincidence shown in the coincidence shown in the reached or exceeded, THEN SI is required.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 4 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO/BOP 4.1.2 (RNO) This step is N/A IF SI is required, THEN actuate SI.

SRO 4.1.3 (RNO)

IF SI NOT required, THEN go to FNP-1-ESP-0.1, REACTOR TRIP RESPONSE.

ESP-0.1, RX TRIP RESPONSE ver 34 RO 1 Check RCS temperature

- Stable at or approaching 547°F

- TAVG 1A(1B,1C) RCS LOOP

[] TI 412D

[] TI 422D STM DUMP

[] TI 432D BOP 2 NOTE: this is a continuing WHEN RCS average temperature less action step than 554°F, THEN verify feedwater status.

- Verify FRVs closed 2.2 MDAFWP AUTO/DEFEAT

[] 1A in DEFEAT

[] 1B in DEFEAT 2.3 Verify BOTH SGFPs tripped 2.4 Verify total AFW flow to the SGs >395 gpm RO 3 Verify ALL RX TRIP breakers OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 5 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 4 Rod P-10 is stuck Check emergency Boration not required

- All rods FULLY INSERTED

- RCS Tavg >525°F RO 4 (RNO)

Emergency borate RCS.

RO 4.1 Start a boric acid transfer pump BATP

[] 1A

[] 1B RO 4.2 Establish emergency boration flow path.

4.2.1 Align normal emergency boration flow path.

EMERG BORATE TO CHG PUMP SUCT

[] Q1E21MOV8104 open 4.2.2 IF normal emergency This step is N/A boration flow path NOT available, THEN align manual emergency boration flow path.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 6 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 4.3 Establish adequate letdown.

4.3.1 Verify 45 gpm letdown orifice in service.

LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A open 4.3.2 Verify one 60 gpm letdown orifice in service.

LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B open

[] Q1E21HV8149C open RO 4.4 Verify emergency boration flow adequate.

4.4.1 Verify charging flow greater than 40 gpm.

4.4.2 IF normal emergency boration flow path aligned, THEN check emergency boration flow greater than 30 gpm.

BORIC ACID EMERG BORATE

[] FI 110 Insert Event 9 here

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 7 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments 4.4.3 Steps 4.4.3 -4.4.4 are N/A IF manual emergency boration flow path aligned, THEN check boric acid flow greater than 30 gpm.

MAKEUP FLOW TO CHG/VCT

[] BA FI 113 4.4.4 IF charging flow less than 40 gpm OR boration flow less than 30 gpm, THEN verify boration flow path using ATTACHMENT 1.

RO 4.5 2500 gal required IF any control rod NOT fully inserted, THEN borate at least 2,500 gallons (200 ppm) for each control rod not fully inserted, up to a maximum of 17,309 gallons.

2500 gal. per stuck rod x No. rods not inserted

= gal. boration req'd

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 8 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 4.6 IF TAVG less than 525F, Step 4.6-4.8 are N/A THEN borate an additional 70 gallons for each °F less than 525F, per the calculation below:

525F

- ___F (indicated TAVG)

= __°F x 70 gal. per F

= gal. boration req'd 4.7 IF DRPI power lost due to loss of B Train power, THEN align DRPI main power supply to NORMAL at Rod Position Indication Dist.

Panel (139' Electrical Penetration Room).

4.8 WHEN emergency boration complete, THEN stop emergency boration using FNP-1-AOP-27.0, EMERGENCY BORATION.

BOP 5 Announce Unit 1 Reactor Trip RO Recognizes Pressurizer level falling RO Takes action per FOLDOUT PAGE May go to AOP-2 (Next Page)

See event 9 for follow on actions

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 9 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments AOP-2 SG Tube Leakage, ver 35 RO 1

[CA] Maintain pressurizer level stable at normal programmed value.

RO 1.1 Control charging flow with FCV-122.

1.1

[ ] FK-122 adjusted as required.

RO 1.2 IF required, THEN reduce letdown by closing one or more of the letdown orifice isolation valves.

1.2

[ ] Q1E21HV8149A-closed

[ ] Q1E21HV8149B-closed

[ ] Q1E21HV8I49C-closed RO 1 (RNO) May not transition until Perform the following. Step 2 1

a)

Trip the reactor.

b)

WHEN the reactor is tripped, THEN actuate SI.

c)

Go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 10 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 1.3 IF plant conditions permit, THEN determine RCS leak rate using FNP-1-STP-9.0, RCS LEAKAGE TEST.

1.3 (RNO)

With pressurizer level on program, determine RCS leak rate from CVCS flow balance.

1.3

______(charging flow FCV122 in auto)

+______(seal injection flow)

-______(letdown flow)

-______(#1 seal leakoff flow)

=______(RCS leak rate)

RO 2

[CA] Maintain VCT level greater than 20%.

RO 2.1 Verify reactor makeup system - IN AUTOMATIC.

2.1 OR 2.2 Manually control reactor makeup system using FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 11 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 2 (RNO)

Perform the following.

1 a)

Trip the reactor.

b)

WHEN the reactor is tripped, THEN actuate SI.

c)

Go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 1 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Indications Available

- Pzr level falling - SGWL rising in 1C SG Time Position Applicants Actions or Behavior Comments Note: May elect to SI and go to EEP-0 before 4% PRZR level Note: The following action is from ESP-0.1 FOLDOUT PAGE.

RO 1 Monitor SI Criteria Greater than 16F subcooled in CETC mode and PRZR level above 4%.

RO 1.1 (RNO)

Verify SI actuated, check for CSF red or orange paths, go to FNP-1-EEP-0.

EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 2 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit RO/BOP 3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

4.2 Verify both trains of SI- ACTUATED.

[] MLB1 1-1 AND MLB1 11-1 lit RO/BOP 5 Page 19 Verify actuation signal automatic actions using ATTACHMENT 2, AUTOMATIC ACTIONS VERIFICATION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 3 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO/BOP 6

[CA] Check containment pressure - HAS REMAINED LESS THAN 27 psig.

CTMT PRESS

[] PR 950 RO/BOP 7 Announce "Unit 1 reactor trip and safety injection."

RO/BOP 8 Check AFW status.

8.1 Check secondary heat sink available.

[] Total feed flow to SGs - pumps started.

GREATER THAN 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B TDAFWP STM SUPP

[] FI 3229C FROM 1B(1C) SG AFW TOTAL FLOW

[] FI 3229

[] Narrow range level in at least one SG - GREATER THAN 31%{48%}

8.2 WHEN all SG narrow range levels less than 31%{48%},

THEN maintain total AFW flow greater than 395 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 4 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 8.3 WHEN at least two SG narrow range levels greater than 28%

AND TDAFWP NOT required, THEN stop TDAFWP 8.4

[CA] WHEN SG narrow range level greater than 31%{48%},

THEN maintain SG narrow range level 31%-65%{48%-65%}.

8.4.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 5 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 8.4.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted RO 9 Check RCS temperature.

-IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547F.

TAVG 1A(1B,1C) RCS LOOP

[] TI 412D 9.1.1 Verify steam dumps closed.

[] TI 422D

[] TI 432D OR IF no RCP running, THEN check RCS cold leg temperature - STABLE AT OR closed.

APPROACHING 547F.

RCS COLD LEG TEMP RECORDER

[] TR 410

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 6 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 9 (RNO)

Perform the following.

9.1 IF RCS temperature less than 547F and falling, THEN perform the following. IF RCS temperature greater than 547F and rising, THEN proceed to RNO Step 9.2.

9.1.1 Verify steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[] B TRN in OFF RESET 9.1.2 Verify atmospheric reliefs closed 1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A

[] PC 3371B

[] PC 3371C 9.1.3 IF cooldown continues, THEN control total AFW flow to stop RCS cooldown.

9.1.4 IF MSIVs are closed THEN proceed to step 9.1.9 Contacts TB SO 9.1.9 IF main steam lines isolated AND gland steam supplied from Unit 1, THEN break condenser vacuum.

COND VAC BKR MAN ISO (155 ft, TURB BLDG)

[] N1N51V518A open

[] N1N51V518B open COND VAC BKR VLVS

[] N1N51V519A/519B open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 7 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 9.2 This step is N/A IF RCS temperature greater than 547F and rising, THEN perform the following.

RO 10 Check pressurizer PORVs and spray valves.

10.1

[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

10.1.1 Verify both PRZR PORVs indicate CLOSED 10.1.2 Check PRZR PORV temperature STABLE OR FALLING

[] PORV Temp TI-463 10.1.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 10.2

[CA] WHEN pressurizer pressure less than 2260 psig, spray flow. THEN verify normal pressurizer spray valves closed OR closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C

[] PK 444D 10.3 Check any PRZR PORV ISO - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 8 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 11 Check RCP criteria.

11.1 Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16F{45F}

SUBCOOLED IN CETC MODE.

RO 12 Monitor charging pump miniflow criteria.

12.1 Control charging pump miniflow valves based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

[] PI 402A

[] PI 403A RO 13 Check SGs not faulted.

13.1 Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 9 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 14 Check SGs not ruptured.

- Check secondary radiation indication - NORMAL.

[] R-15 SJAE EXH

[] R-19 SGBD SAMPLE

[] R-23A SGBD HX OUTLET

[] R-23B SGBD TO DILUTION

[] R-15B TURB BLDG VNTL (BOP)

[] R-15C TURB BLDG VNTL (BOP)

[] R-60A MS ATMOS REL (BOP)

[] R-60B MS ATMOS REL (BOP)

[] R-60C MS ATMOS REL (BOP)

[] R-60D TDAFWP EXH (BOP)

- No SG level rising in an uncontrolled manner.

SRO 14 Go to FNP-1-EEP-3, STEAM GENERATOR TUBE RUPTURE.

EEP-3.0, SGTR, ver 27 RO 1 Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication - > 16°F{45°F} SUBCOOLED IN CETC MODE.

BOP 2 NOTE: this is a continuing

[CA} Identify ruptured SG(s). action step Check any SG level - RISING IN AN UNCONTROLLED MANNER

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 10 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO/RO 3 NOTE: this is a continuing WHEN ruptured SG(s) identified, THEN action step isolate flow from ruptured SG(s).

1C SG is ruptured 3.1 Verify ruptured SG(s) atmospheric relief valve - ALIGNED.

- PC3371C, 1C MS ATMOS REL VLV, set 8.25 and in auto 3.2 Verify 3371C, 1C MS ATMOS REL VLV, is closed 3.3 Isolate steam supply from 1C SG to TDAFWP:

3.3.1 Check 1B or 1C SG(s) ruptured.

3.3.2 Direct counting room to perform FNP CCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.

3.3.3 Check at least one MDAFWP running and no TDAFWP auto start signals present

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 11 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments 3.3.4 Stop the TDAFWP from the MCB 3.3.5 Check TDAFWP steam supply valves closed.

3.3.6 Initiate actions to isolate the TDAFW steam supply from the ruptured SG while continuing with step 3.6.

BOP 3.4 Check 1C SG ruptured.

3.4.1 Establish LOCAL control from hot Contact SSS and shutdown panel AND Isolate TDAFWP coordinates performance steam supply from 1C SG.

[] TDAFWP STM SUPP FROM 1C SG Q1N12HV3235B in LOCAL.

(HSDP-F)

[] TDAFWP STM SUPP FROM 1C SG Q1N12HV3235B in STOP and release. (HSDP-D)

SRO/ 3.5 This Step is N/A BOP Check 1B SG ruptured.

BOP 3.6 Verify blowdown from ruptured SG(s) -

ISOLATED.

3.7 Verify at least one SG MSIV on 1C SG closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 12 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 4 NOTE: this is a continuing WHEN ruptured SG(s) NR level greater action step than 31% THEN perform the following:

4.1 Isolate AFW flow to ruptured SG(s) using Critical task - Isolate SG FCVs.

- FCV 3227C in MOD, and closed

- HV 3328C in MOD and closed SRO 5 Check ruptured SG(s) pressure GREATER THAN 250 psig.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 13 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO 6 Perform RCS cooldown. Determine required CETCs for cooldown based on ruptured SG pressure.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 14 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO 6.2 Display the hottest core exit thermocouple.

6.2.1 IF the plant computer is available, THEN display HIGHEST CORE EXIT TEMP CHAN A and CHAN B on one of the following displays.

- 1TC1

- STA

- Other display 6.3 Critical task - Cooldown WHEN P-12 light lit (543F),

THEN perform the following.

6.3.1 Block low steam line pressure SI.

STM LINE PRESS SI BLOCK - RESET

[] A TRN to BLOCK

[] B TRN to BLOCK 6.3.2 Verify blocked indication.

BYP & PERMISSIVE STM LINE ISOL.

SAFETY INJ.

[] TRAIN A BLOCKED light lit

[] TRAIN B BLOCKED light lit 6.3.3 Bypass the steam dump interlock.

STM DUMP INTERLOCK

[] A TRN to BYP INTLK

[] B TRN to BYP INTLK

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 15 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO Will direct these steps:

6.4 IF condenser available, THEN dump steam to condenser from intact SGs at maximum attainable rate.

BYP & PERMISSIVE COND AVAIL

[] C-9 light lit STM DUMP

[] MODE SEL A-B TRN in STM PRESS STM DUMP INTERLOCK

[] A TRN in ON

[] B TRN in ON STM HDR

[] PK 464 adjusted RO 6.5 Continue to step 7 until Check hottest CETCs less than required CETCs are < required temperature. temp.

6.6 Stop the cooldown 6.7

[CA] Maintain core exit T/Cs - LESS THAN REQUIRED TEMPERATURE.

Note: Once required CETC temperature met, it will be the expected exam termination point

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 16 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 7 Check intact SG levels.

7.1 Check any intact SG narrow range level -

GREATER THAN 31%{48%}.

7.2

[CA] WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG narrow range level 31%-65%{48%-65%}.

7.2.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD 7.2.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 17 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 8 Check pressurizer PORVs 8.1 Check any PRZR PORV ISO - power available 8.2

[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.

8.2.1 Verify both PRZR PORVs - CLOSED 8.2.2 Check PRZR PORV temperature STABLE OR FALLING.

[] PORV Temp TI-463 8.2.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 8.3 Check at least one PRZR PORV ISO -

OPEN BOP 9 Verify SI - RESET.

MLB-1 1-1 not lit (A TRN) and MLB-1 11-1 not lit (B TRN) 10 Verify PHASE A CTMT ISO - RESET.

MLB-2 1-1 not lit and MLB-2 11-1 not lit

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 18 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 11 Check PHASE B CTMT ISO - RESET.

RO 12 IF instrument air available, THEN establish instrument air to containment.

Verify at least one air compressor started.

AIR COMPRESSOR

[] 1A

[] 1B

[] 1C Check INST AIR PRESS PI 4004B greater than 85 psig.

Check instrument air to containment.

IA TO CTMT

[] MLB-3 1-2 NOT lit IA TO PENE RM PRESS LO

[] Annunciator KD1 clear RO 13

[CA] Check if LHSI Pumps should be stopped.

13.1 RHR pumps - ANY RUNNING SUCTION ALIGNED TO RWST.

Take HS to stop.

13.2 Check RCS pressure - GREATER THAN 275 psig{435 psig} on PT-402 AND 403, 1A/1C LOOP RCS WR PRESS.

13.3 Secure any running RHR pumps

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 19 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO 14 Check if Cooldown should be stopped.

14.1 Check hottest core exit T/Cs - LESS THAN REQUIRED Temperature. RNO Do NOT proceed until 14.2 hottest core exit T/Cs -

Stop RCS cooldown LESS THAN REQUIRED TEMPERATURE.

14.3 Stop RCS cooldown Maintain core exit T/Cs - LESS THAN REQUIRED TEMPERATURE.

EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 2, ver 45 1

Verify one CHG PUMP in each train -

BOP STARTED.

[] A train (1A or 1B) amps > 0

[] B train (1C or 1B) amps > 0 BOP 2 Verify RHR PUMPs - STARTED.

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP 3 Verify Safety Injection Flow.

3.1 Check HHSI flow - GREATER THAN 0 gpm.

[] FI 943 BOP 3.2 Operator should proceed to Check RCS pressure - LESS THAN step 4 275 psig{435 psig}.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 20 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 4 Verify each SW train - HAS TWO SW PUMPs STARTED.

[] A train (1A,1B or 1C)

[] B train (1D,1E or 1C)

BOP 5 Verify each train of CCW - STARTED.

5.1 Verify one CCW PUMP in each train-STARTED.

A train HX 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 21 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 6 Verify containment ventilation isolation.

6.1 Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 6.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 6.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 22 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 7 Verify containment fan cooler alignment.

7.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[] 1A

[] 1B B train

[] 1C

[] 1D 7.2 Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 23 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 8 Verify AFW Pumps - STARTED.

8.1 Verify both MDAFW Pumps - STARTED

[] 1A MDAFW Pump amps > 0

[] 1B MDAFW Pump amps > 0 AND

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 24 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments 8.2 Check TDAFW Pump start required.

8.3 Verify TDAFWP started.

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

8.4 Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 25 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 9 Verify main feedwater status.

Verify main feedwater flow control and bypass valves - CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[] FCV 488

[] FCV 498 9.2 Verify both SGFPs - TRIPPED.

9.3 Verify SG blowdown - ISOLATED.

1A(1B,1C) SGBD ISO

[] Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample - ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 26 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 10 Check no MSL isolation actuation signal present.

10 (RNO)

Perform the following.

10.1 Verify main steam line isolation and bypass valves closed.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYP

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 27 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments 11 Verify PHASE A CTMT ISO.

BOP 11.1 Verify PHASE A CTMT ISO - ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO BOP 12 Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP 13 Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11E005A

[] N1C11E005B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 28 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 14 Secure secondary components.

14.1 Stop both heater drain pumps.

HDP

[] 1A

[] 1B 14.2 Check any condensate pump started.

14.2.1 IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 14.3 IF condensate pump operating, Will call TBSO to THEN verify backup cooling aligned to accomplish this.

condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP 15 Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN BOP 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810 - OPEN

[] 914 - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 29 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 17 Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 30 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 4, ver 45 1

Verify two trains of ECCS equipment aligned.

1.1 - 1.4

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 closed 1.5

[] Verify two trains of battery chargers -

energized

[] A Train (1A or 1C) amps > 0

[] B Train (1B or 1C) amps > 0 1.6 Verify two trains of ESF equipment aligned.

1.6.1 Check all MLB-1 lights LIT 1.6.2 Verify charging pump suction and discharge valves - OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 31 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B 1.8 WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP 1.9 Call Radside SO Verify SFP Cooling in service per SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of Attachment 4

Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #4 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 7/22/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 4 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 4% power, EOL, Cb 530 ppm, UOP-1.2 Section 4 through step 65 is complete, B Train On Service.

Turnover:

• 4% power, EOL, Cb 530 ppm

• UOP-1.2 Section 4 through step 65 is complete. Disconnect 915 is coupled and closed.

• Raise power to 12% and roll the Main turbine.

• Aux steam aligned to Unit 2

• 1A SGFP on service

• All MODE 1 STPs are completed and permission to enter MODE 1 has been granted.

• B Train On Service, B Train protected.

• Current Risk Assessment is GREEN and projected is GREEN Event Malf. No. Event Event No. Type* Description 1 cnh/ I (BOP) FK-489, 1B SG FW BYP FLOW fails open in auto. Can be FK498-A manually controlled. (P-CT) 2 R (RO) Raise power to 12% using rods and Steam Dumps.

N (BOP) 3 cmfmalf/ TS (SRO) 1B Pressurizer Heater breaker trips.

cPC2028C_co1 TS - 3.4.9 Cond B 4 xmt/ I (RO) PT-445, PRZR PRESS, fails high. PCV-445A is stuck open pt445 TS (SRO) and cannot be closed.

preset TS - 3.4.11 Cond B (P-CT) 5 xmt/ I (RO) PK-145, LP LTDN PRESS, fails high (valve full close). PCV-PK145 145 cannot be opened.

preset 6 xmt/ I (BOP) PT-464, STM HDR PRESS, fails high. (P-CT)

PT464 TS- 3.4.2 Cond A 7 malf/m/ M (ALL) Main Steam Line Break on 1B SG inside Containment MAL-MSS1B preset C (RO) Automatic SI Blocked (CT-2)

C (BOP) HV-7614B, 1B SGBD ISO, fails to close automatically on preset MDAFWP auto start Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario 4 Presets Form ES-D-1 EVENT # TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-222 (Base IC-48) 0 0 Generic setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc4.txt 0 0 RUN PRESETS 4 PCV-445A stuck open *TRG 1 trg 1 imf rrc445a-s 100 0 5 PCV-145 cannot be opened in Manual *TRG 2 trg 2 imf pk-145-m 10 0 7 HV-7614B fails to close on MDAFWP auto start

• imf cMS7614B_d_cc3 closed imf cMS7614B_d_cc4 closed 7 Block Automatic SI

• imf csftyinj_cc1 open imf csftyinj_cc11 open Triggers and Commands 4 Monitor PCV-445A position *TRG 1 trgset 1 "rrc445a == 1" 5 Monitor PCV-145 position *TRG 2 trgset 2 "rcvp145 == 0"

MCB setup OVATION Clear OVATION alarms Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms Provide marked up copy of , UOP-1.2 Section 4 step 66 UOP-1.2 IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 NRC FK-489, 1B SG FW BYP FLOW fails open in auto. Can be CUE manually controlled. (P-CT) imf fk498-a 10 30 2 Raise power to 12%

3 NRC 1B Pressurizer Heater breaker trips.

CUE TS - 3.4.9 Cond B imf cPC2028C_co1 4 NRC PT-445, PRZR PRESS, fails high. PCV-445A is stuck open CUE and cannot be closed.

TS - 3.4.11 Cond B (P-CT) imf pt445 2500 30 TRG 1 5 NRC PK-145, LP LTDN PRESS, fails high (valve full close). PCV-CUE 145 cannot be opened.

imf pk145-a 10 30 TRG 2 6 NRC PT-464, STM HDR PRESS, fails high. (P-CT)

CUE TS- 3.4.2 Cond A imf pt464 1200 60 EVENT# TIME EVENT DESCRIPTION COMMAND

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC Main Steam Line Break on 1B SG inside Containment CUE imf mal-mss1b 6 60 Automatic SI Blocked (CT-2) preset HV-7614B, 1B SGBD ISO, fails to close automatically on preset MDAFWP auto start NRC END OF EXAM:

CUE 1B SG is isolated Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen4grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED .

4 IF REQUESTED Open FU-K4 irf crc800a_d_cd1 open (3 minutes after requested) 5 NONE REQUIRED 6 NONE REQUIRED 7 IF REQUESTED SOP-0.0 actions for a Rx trip cae Turbine_Bldg_MSRs.cae (10 minutes after requested) 9.1.7 RNO of EEP-0 EEP-0 step 9.1.7 RNO cae 2015_TB_MSDP_iso.cae (5 minutes after requested)

ROVER/SSS: 3 minutes after requested - Perform Step 4.5.1 of EEP-2.0 at HSDP (See Next Page)

Close Q1N23V017B irf loa-afw007 0 30 (3 minutes after requested)

Acknowledge MH1 Go to Control Room Fire Panel on the PANEL MAP and select CONTROL ROOM FIRE PANEL then CLICK the ACK button. (3 minutes after requested)

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the inform supervision) cue and that type of communications 1 NO ADDITIONAL REQUIRED 2 NO ADDITIONAL REQUIRED 3 IF REQUESTED ROVER: 3 minutes after requested - EC-11 is open, no obvious problems noted 4 IF REQUESTED RAD 1 SO: 3 minutes after requested - FU-K4 is open 5 IF REQUESTED SSS or RAD 1 SO: Acknowledge to place RCDT on recirc.

NOTE: No action required. next event will occur before excess letdown will be placed on service.

6 NO ADDITIONAL REQUIRED 7 IF REQUESTED TB SO: 10 minutes after requested - SOP-0.0 actions for a Rx trip/Safety Injection are complete.

TBSO: I will perform step 9.1.9 (RNO) of EEP-0 for Unit 1 RAD 1 SO: I will verify SFP cooling in service per SOP-54.0 ROVER/SSS: 3 minutes after requested - Step 4.5 of EEP-2.0 at HSDP complete.

ROVER/SSS: 3 minutes after requested - V017B is closed.

U2: Once MH1 is acknowledged - Fire alarm has been acknowledged. It was 1A-22 CTMT.

Appendix D Scenario 4 Detailed Summary Form ES-D-1 Initial Conditions: 4% power, EOL, Cb 530 ppm, UOP-1.2 Section 4 through step 65 is complete, B Train On Service.

Turnover:

• 4% power, EOL, Cb 530 ppm

• UOP-1.2 Section 4 through step 65 is complete. Disconnect 915 is coupled and closed.

• Raise power to 12% and roll the Main turbine.

• Aux steam aligned to Unit 2

• 1A SGFP on service

• All MODE 1 STPs are completed and permission to enter MODE 1 has been granted.

• B Train On Service, B Train protected.

• Current Risk Assessment is GREEN and projected is GREEN Event 1: FK-489, 1B SG FW BYP FLOW fails open in auto.

Verifiable actions: BOP takes manual control of FK-489 and restores SGWL.

(P-CT) If the BOP does not control SGWL then a LOLO SGWL Reactor trip will occur if 1B SG level lowers to 28% and the SGFP will trip if 1B SGWL reaches the HIHI setpoint of 82%

which will require a Reactor trip due to a loss of feed above 5% power.

Event 2: Ramp up to 12% .

Verifiable actions: RO uses rods and BOP uses Steam Dumps to raise power to 12%.

(SIMILAR to AUDIT) - On the audit exam, at 8% power, a trigger will cause PT-508 (FW Header Pressure) to fail HIGH. Discussed with Chief Examiner.

Event 3: 1B Pressurizer Heaters breaker trips.

Verifiable actions: SRO - Tech Specs: 3.4.9 Cond B Event 4: PT-445, PRZR PRESS, fails high. PCV-445A will be stuck open.

Verifiable actions: RO will attempt to close PCV-445A and when it cant be closed, MOV8000A, PRZR PORV ISO will be closed. Pressurizer heaters should be already on but if secured then the RO will energize Pressurizer heaters. SRO - Tech Specs: 3.4.11 Cond B (P-CT) If the RO does not get the block valve closed promptly, a Low Pressure Reactor trip will occur.

(SIMILAR to AUDIT) - The opposite PT fails high on the audit exam which requires the Spray Valves to be closed and Pressurizer Heaters to be energized. Also, the PORV closes on the Audit exam and is leaking by which is Tech Spec 3.4.11 Cond A.

Event 5: PK-145, LP LTDN PRESS, fails high (valve full close). PCV-145 cannot be opened.

Verifiable actions: RO will attempt to take manual control of PCV-145 and control letdown pressure. Once the RO recognizes that PCV-145 is stuck, the RO will isolate letdown by closing the letdown orifice isolations.

Event 6: PT-464, STM HDR PRESS, fails high.

Verifiable actions: BOP takes control of SFGP speed and lowers back to normal. Steam dumps will open fully until P-12. BOP will have to control them manually using manual control of PK-464. SRO - Tech Specs: TS- 3.4.2 Cond A (P-CT) If the BOP does not control SGWL then a LOLO SGWL Reactor trip will occur if 1B SG level lowers to 28% and the SGFP will trip if 1B SGWL reaches the HIHI setpoint of 82%

which will require a Reactor trip due to a loss of feed above 5% power.

(SIMILAR to AUDIT) - PK-464 fails high on the audit but at a higher power level (25%) which does not affect the steam dumps since they are in Tavg mode at the higher power.

Event 7: A Main Steam Line Break occurs on the 1B SG inside Containment. Automatic SI is blocked and HV7614B, 1B SGBD ISO will not automatically close.

Verifiable actions: Manually actuate SI (CT-2) and close HV-7614B.

(SIMILAR to AUDIT) Audit exam requires a transition to ECP-2.1 due to MSIVs not closing.

Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Appendix D Scenario 4 Critical Tasks Form ES-D-1

_____ 1. Manually actuate at least one train of SIS-actuated safeguards before any of the following: (CT-2)

Transition to EEP-2.

_____ 2. Isolate the faulted SG before transition out of E-2. (CT17)

SCENARIO At power power instrument and component failures with a SLB inside Containment on OBJECTIVE/ the 1B SG. The team should be able to:

OVERVIEW:

• respond to FK-498, 1B SG FW BYP FLOW fails open in auto

• raise power to 12%

• Respond to a Pressurizer heater breaker trip

• respond to PT-445 failing high and a stuck open PORV

• isolate letdown in response to a failure of PK-145

• restore SGWL and Steam Dump control after the failure of PT-464

• respond to SLB inside Containment and manually actuate SI along with isolating the faulted SG.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 2

2. Abnormal events (2-4) 4

3. Major transients (1-2) 1

4. EOPs entered/requiring substantive actions (1-2) 1

5. EOP contingencies requiring substantive actions (0-2) 0

6. Critical tasks (2-3) 5

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 2, 4% RTP, 530 ppm Cb, EOL 20000 MWD/MTU, -13 pcm Xe B Trn O/S / B Trn Protected / SFPC on B Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 95 hours0.0011 days <br />0.0264 hours <br />1.570767e-4 weeks <br />3.61475e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. Aux steam aligned to Unit 2

3. Raise power to 12% and roll the Main Turbine.

4. UOP-1.2, Section 4 through Step 65 is complete

5. All MODE 1 STPs are completed and permission to enter MODE 1 has been granted.

6. Disconnect 915 is coupled and closed.

7.

8.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas)

LCO status None #1 RHT Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __1___ Page 1 of 4 Event

Description:

FK-489, 1B SG FW BYP FLOW fails open in auto. Can be manually controlled.

(P-CT)

Indications Available Annunciators: Recognize indications of FK-499 failing high:

- 1B SG LVL DEV (JF3) - 1B SG feed flow rising

- 1B SG FEED FLOW > STM FLOW - 1B SG NR level rising (JG3) - FRV bypass valve going full open

- 1B SG HI-HI LVL ALERT (JD3)

Time Position Applicants Actions or Behavior Comments AOP-100, section 1.5, version 11(possible AOP-13 entry)

RO/BOP Recognizes malfunction and announces then takes immediate operator action of AOP-100 SRO Instructs BOP/RO to perform Immediate Operator Actions of AOP-100 if not taken by the RO/BOP BOP 1 NOTE: Step 1 is an Maintain SG levels at 65%. Immediate Operator Action and a continuing action step 1.1 IF required, THEN, take manual control of SGFP speed control as necessary to restore SG level to 65%1.1

- SGFP master controller SK-509A OR

- SGFP individual controllers as needed.

[ ] SK-509B

[ ] SK-509C 1.2 IF required, THEN take manual control of the affected feedwater bypass valves 1.2

[ ] 1A SG FW FLOW FK-479

[ ] 1B SG FW FLOW FK-489

[ ] 1C SG FW FLOW FK-499

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __1___ Page 2 of 4 Event

Description:

FK-489, 1B SG FW BYP FLOW fails open in auto. Can be manually controlled.

(P-CT)

Time Position Applicants Actions or Behavior Comments SRO 1.3 This will not result in a loss If a loss of main feedwater occurs, then of MFW perform the actions of AOP-13, Loss of Main Feedwater SRO 2 Trip criteria expected:

If an adverse trend in SG level exists, then - Rx trip on low SG level establish Trip Criteria 28%

- Main Turbine and Feed Pump Trip @ 82% SG level Potential Critical task - If loss of SGWL control occurs, a Rx trip may be required due to a loss of feed above 5% Rx power AOP-13)

BOP 3 No ramp will be in progress IF a ramp is in progress, THEN place Turbine on HOLD

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __1___ Page 3 of 4 Event

Description:

FK-489, 1B SG FW BYP FLOW fails open in auto. Can be manually controlled.

(P-CT)

Time Position Applicants Actions or Behavior Comments SRO/ 4 NO instrument failure BOP Determine if an instrument failure has occurred occurred.

4.1 Check for a failed or erroneous indications from the following Steam flow or feed flow indicators.

STM FLOW FEED FLOW S/G CH III CH IV CH III CH IV A S/G FI-474 FI-475 FI-477 FI-476 B S/G FI-484 FI-485 FI-487 FI-486 C S/G FI-494 FI-495 FI-497 FI-496 4.2 Check for failed or erroneous readings on the following SG pressure indicators S/G CH II CH III CH IV A S/G PI-474 PI-475 PI-476 B S/G PI-484 PI-485 PI-486 C S/G PI-494 PI-495 PI-496 SRO/ 4.3 BOP IF the alarm(s) was due to a SGWLC No action required due to System controlling channel failure, THEN controller failure.

select the unaffected channel 4.3.1 Place the following handswitches to the appropriate channel III OR IV position as required:

4.3.2 Verify proper system response.

SRO 5 No LCO requirements Refer to Tech Specs 3.3.2 and 3.7.3 for any LCO requirements.

SRO 6 SM contacted Notify the Shift Manager

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __1___ Page 4 of 4 Event

Description:

FK-489, 1B SG FW BYP FLOW fails open in auto. Can be manually controlled.

(P-CT)

Time Position Applicants Actions or Behavior Comments SRO 7 This step is N/A WHEN plant conditions permit, THEN return systems to automatic control.

SRO 8 Has RO/BOP contact Submit a condition report on the failed appropriate personnel component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO 9 Go to procedure and step in effect.

At the discretion of the Lead Examiner move to Event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __2___ Page 1 of 4 Event

Description:

Raise power to 12%. Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2.

Indications Available

- Rx power rising Time Position Applicants Actions or Behavior Comments UOP-1.2, Startup of Unit from Hot Standby to Minimum Load, Section 4 Step 66, ver 110.1 RO 66 Manual adjustment of rods Begin to increase reactor power to greater (not more than 3 steps at a than 12% with following controls. time) See page 4 Stm dump control - adjust Manual adjustment of control rods PK-464 counterclockwise to Steam dumps in Steam Pressure release more steam, Control Mode decrease Tavg, pull rods and increase power SRO Monitor reactor power and Steam Dump Examiner NOTE: Diluting is adjustments as reactor power rises not procedurally required or expected and as such would not be a part of the reactivity plan BOP Will be reviewing UOP-1.2 and getting ready to roll the main turbine.

BOP 67 This step is N/A IF MTC is zero or positive, verify rods less than or equal to approximately D at 170 steps to ensure adequate rod worth for transient control while paralleling the Main Generator to the grid. (IR 2 129)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __2___ Page 2 of 4 Event

Description:

Raise power to 12%. Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2.

Time Position Applicants Actions or Behavior Comments RO 68 WHEN Nuclear at Power Permissive P-10 permissive status light is illuminated (2/4 power ranges greater than 10%), THEN perform the following: {CMT-0003695}

a Block the intermediate range reactor trip and overpower rod stop.

Place INTEMEDIATE RANGE BLOCK TRN A to BLOCK.

Place INTEMEDIATE RANGE BLOCK TRN B to BLOCK.

b On the Bypass and Permissive Panel verify the following:

The INTERM RANGE TRAIN A TRIP BLOCKED light illuminated.

The INTERM RANGE TRAIN B TRIP BLOCKED light illuminated.

c Block the power range low setting reactor trip.

Place POWER RANGE BLOCK TRN A to BLOCK.

Place POWER RANGE BLOCK TRN B to BLOCK.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __2___ Page 3 of 4 Event

Description:

Raise power to 12%. Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2.

Time Position Applicants Actions or Behavior Comments d

On the Bypass and Permissive Panel verify the following:

The POWER RANGE LOW SETTING TRAIN A TRIP BLOCKED light illuminated.

The POWER RANGE LOW SETTING TRAIN B TRIP BLOCKED light illuminated.

RO e Verify that Low Power Trip Block P-7 status light is not illuminated to ensure the unblocking of the following reactor trips.

Pressurizer Low Pressure Pressurizer High Water Level Loss of Flow-Two Loops RO f Verify NR-45B is in the desired speed, i.e.,

2nd speed (2 min/div) OR normal speed.

(10 min/div)

SRO g This step is N/A Direct qualified EM or OPS personnel to close disconnect switch 915 When 10-12% power is reached and at the discretion of the Lead Examiner move to event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __2___ Page 4 of 4 Event

Description:

Raise power to 12%. Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2.

Time Position Applicants Actions or Behavior Comments SOP-41.0, Control Rod Drive and Postion Indication System, Ver 37 OPERATOR AID FOR CONTROL ROD MOVEMENT RO 1 Place ROD CONTROL BANK SELECTOR SWITCH in MAN.

RO 2 Check indicated control rod speed is approximately 48 steps per minute on SI-408.

RO 3 Insert OR withdraw Control Rods using the CONTROL ROD MOTION switch.

RO 4 When desired, place rod control in AUTO as follows:

RO 4.1 Verify Tavg within 1°F of Tref.

RO 4.2 Place the ROD CONTROL BANK SELECTOR SWITCH in AUTO.

RO 4.3 Check indicated control rod speed is approximately 8 steps per minute on SI-408.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __3___ Page 1 of 2 Event

Description:

1B Pressurizer Heater breaker trips. TS - 3.4.9 Cond B.

Indications Available

- 1B PRZR HTR GROUP BACKUP H/S - - HD5, PRZR HTR BKR TRIPPED in ALARM Amber and Green light lit.

Time Position Applicants Actions or Behavior Comments ARP-1.8, HD5, PRZR HTR BKR TRIPPED, ver 35.6 RO 1 Determine which pressurizer heater group breaker has tripped.

RO 2 Refer to annunciator window HC1, PRZR PRESS HI-LO.

RO 3 IF required, THEN limit plant transients until the heaters can be returned to normal.

RO 4 Contacts Rover Notify appropriate personnel to determine and correct the cause of the breaker trip.

SRO 5 Refer to Technical Specification 3.4.9 for LCO requirements.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __3___ Page 2 of 2 Event

Description:

1B Pressurizer Heater breaker trips. TS - 3.4.9 Cond B.

TECHNICAL SPECIFICATION 3..4.9 Pressurizer The pressurizer shall be OPERABLE with:

a. Pressurizer water level 63.5% indicated; and

b. Two groups of pressurizer heaters OPERABLE with the capacity of each group 125 kW and capable of being powered from an emergency power supply.

APPLICABILITY: MODES 1, 2, and 3.

Condition B SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One required B.1 Restore required group of group of pressurizer heaters to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> pressurizer OPERABLE status.

heaters inoperable.

ARP-1.8, HC1, PRZR PRESS HI-LO, ver 35.6 RO 1 Check pressurizer pressure indications and determine if pressure is high or low.

RO 2 May energize additional Check the status of the following and take heaters to control pressure manual control as necessary:

2.1 Pressurizer spray valves.

2.2 Pressurizer power operated relief valves (PORVs).

2.3 Pressurizer heaters.

RO 3 This step is N/A IF an instrument failure has occurred, THEN go to FNP-1-AOP-100, INSTRUMENT MALFUNCTION.

At Lead Examiners discretion, move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 1 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Indications Available

- PT-445 goes to max scale -The following are in ALARM

- PCV-445A opens HA4, PRZR SAFETY VLV TEMP HI

- RCS pressure lowers HA5, PRZR PORV TEMP HI

-TI463, PORV is elevated HD1, PRZR PRESS REL VLV 445A OR B/U HTRS ON HC1, PRZR PRESS HI-LO Time Position Applicants Actions or Behavior Comments RO/BOP Recognizes malfunction and announces then performs immediate operator action of AOP-100 SRO If not done by RO/BOP direct immediate operator actions of AOP-100 AOP-100, INSTRUMENTATION MALFUNCTION, Section 1.1, ver 15 RO 1 Potential Critical Task -

IF required to stabilize RCS pressure, PCV-445A will not close.

THEN take manual control of the Must close the block following equipment. valve MOV-8000A or a low 1 pressure SI will occur and

• Power operated relief valves cause a Rx trip.

[ ] PRZR PORV Q1B31PCV445A

[ ] PRZR PORV Q1B31PCV444B OR

[ ] PRZR BLOCK VLV Q1B31MOV8000A

[ ] PRZR BLOCK VLV Q1B31MOV8000B

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 2 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Time Position Applicants Actions or Behavior Comments RO 2 This step is N/A IF pressurizer pressure is decreasing due to a mechanically stuck open spray valve PCV444C or PCV444D, THEN perform the following:

3 IF PORV is open and pressurizer pressure is less than 2310 psig, THEN close the PORV.

3 (RNO) Block valve may be closed IF the PORV will not close, in Step 1 THEN perform the following:

3° Potential Critical Task -

3.1 PCV-445A will not close.

IF pressurizer pressure is decreasing Must close the block due to a stuck open PORV, valve MOV-8000A or a low THEN close the associated PORV Block pressure SI will occur and Valve. cause a Rx trip 3.1 3.2 IF PORV Block valve will not close and reactor is critical, THEN trip the reactor and go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 3 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Time Position Applicants Actions or Behavior Comments 4

IF an alarm was caused by a CONTROL instrument (PT-444/445) OR component failure, THEN perform the following as required to restore RCS pressure to desired value.

44 4.1 Take manual control of the following as required:

• Power operated relief valves

[ ] PRZR PORV Q1B31PCV445

[ ] PRZR PORV Q1B31PCV444B OR

[ ] PRZR BLOCK VLV Q1B31MOV8000A

[ ] PRZR BLOCK VLV Q1B31MOV8000B

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP 4.2 IF B/U heaters automatically energized with pressure above 2210 psig, THEN verify the pressurizer master controller potentiometer setting using the plant curve book.

5 No protection channel has IF a PROTECTION instrument failure failed has occurred, THEN determine which pressure channel has caused the alarm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 4 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Time Position Applicants Actions or Behavior Comments 6

Refer to Tech Specs for LCO requirements that exist.

66

• Sections 3.3.1, 3.3.2, & 3.3.3 for instrument failures

• Section 3.4.1 for DNB limits

• Section 3.4.5 RCS Loops - Mode 3

• Section 3.4.11 PORVs Note: RCS pressure may not drop below 2209 psig TECHNICAL SPECIFICATION 3.4.1 - RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits 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 the COLR. The minimum RCS total flow rate shall be 263,400 G P M when using the precision heat balance method, when using 264, 200 G P M the elbow tap method, and the lim it specified in the C O LR APPLICABILITY: MODE 1.

Condition A SRO CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore RCS DNB RCS DNB parameter(s) to within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> parameters not limit.

within limits..

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 5 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

TECHNICAL SPECIFICATION 3.4.11 - Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

Condition B SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One PORV B.1 Close associated block inoperable and valve. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> not capable of AND 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> being B.2 Remove power from associated block 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> manually cycled. valve.

AND B.3 Restore PORV to OPERABLE status.

Time Position Applicants Actions or Behavior Comments SRO 7 Contacts SM Notify the Shift Manager.

7 87

[CA] WHEN plant conditions permit, THEN restore components to automatic control.

8 9

Submit a Condition Report and notify the Has RO/BOP contact Work Week Coordinator (Maintenance appropriate personnel ATL on backshifts).

RO/BOP 10 IF the pressurizer power operated relief valves operated, THEN perform the following:

1010 10.1 Refer to FNP-1-SOP-1.2, REACTOR COOLANT PRESSURE RELIEF Contact SSS to take actions SYSTEM, for cooldown of the pressurizer per these steps relief tank.

10.110.1 10.2 Refer to FNP-0-SOP-0.0, GENERAL INSTRUCTIONS TO OPERATIONS PERSONNEL, for reporting requirements.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 6 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Time Position Applicants Actions or Behavior Comments SRO 11 Go to procedure and step in effect.

SRO Direct that FU-K4 be opened to comply RAD 1 SO/SSS contacted with Tech Spec 3.4.11 Cond B At Lead Examiners discretion, move to next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __5___ Page 1 of 2 Event

Description:

PK-145, LP LTDN PRESS, fails high (valve full closed). PCV-145 cannot be opened.

Indications Available

- PK-145 demand goes to 100 - PI-145, LTDN HX OUTLET PRESS, goes to

- DE4, LTDN HX OULET PRESS HI max scale

- DE3, LTDN ORIF ISO VLV REL LINE TEMP HI Time Position Applicants Actions or Behavior Comments RO Announce Alarms. May diagnose condition SRO Directs entry in ARP ARP-1.4, DE4, LTDN HX OUTLET PRESS HI, ver 54.2 RO 1 Monitor LTDN HX Outlet Flow (FI-150) and LTDN HX Outlet Press (PI-145).

RO 2 Ensure proper orifice isolation valve selection.

RO 3 Attempts to open PCV-145 IF the high pressure is due to LP LTDN using PK-145 PRESS PK-145 malfunction, THEN place valve controller in manual and attempt to reduce the pressure.

RO 4 IF pressure can NOT be controlled manually with LP LTDN PK-145, THEN close LTDN ORIF ISO 45 (60) GPM Q1E21HV8149A, B, and C.

BOP 5. IF a ramp is in progress, THEN place turbine load on HOLD.

SRO 6. Go to FNP-1-AOP-16.0, CVCS MALFUNCTION to address the loss of letdown flow.

Insert next event upon entry in AOP-16

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __5___ Page 2 of 2 Event

Description:

PK-145, LP LTDN PRESS, fails high (valve full closed). PCV-145 cannot be opened.

Time Position Applicants Actions or Behavior Comments ARP-1.4 , DE3, LTDN ORIF ISO VLV REL LINE TEMP HI, ver 54.2 RO 1.

Monitor the LTDN ORIF ISO REL line to PRT Temperature (TI-141) and LTDN HX Outlet Press (PI- l45).

2 IF the high temperature is due to LP LTDN PCV-145 will not open press PK-145 malfunctions, THEN place valve controller in manual and adjust as required.

3 IF temperature continues to rise rapidly indicating a lifted relief valve, THEN close LTDN ORIF ISO 45 (60) GPM Q1E21HV8149A, B AND C.

BOP 4 IF a ramp is in progress, THEN place turbine load on HOLD.

SRO 5 Go to FNP-1-AOP-16.0, CVCS MALFUNCTION to address the loss of letdown flow.

Insert next event upon entry in AOP-16

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __6___ Page 1 of 4 Event

Description:

PT-464, STM HDR PRESS, fails high. This cause SGFP speed to increase and Steam Dumps to open until they interlock closed at P-12 (543F Tavg) (P-CT)

Indications Available

-PT-464 goes to max scale - RX power rises

-Stem Dumps open until they interlock - Feed flow increases closed - The following Alarms

- SGFP speed increases JF1/2/3, 1A/1B/1C SG LVL DEV JG1/2/3, 1A/1B/1C SG FEED FLOW > STM FLOW Time Position Applicants Actions or Behavior Comments AOP-100, INSTRUMENTATION MALFUNCTION, Section 1.4, ver 15 BOP 1 Potential Critical Task - IF

[CA] Maintain SG level at the referenced SGWL is not controlled, level of 65%. then a RX trip may be 1 required due to a loss of 1.1 feedwater.

IF required, THEN take manual control of SGFP speed control SGFP master controller

[ ] SK-509A OR SGFP individual controllers as needed.

[ ] SK-509B

[ ] SK-509C 1.2 IF required, THEN take manual control of the affected feedwater regulating valves or bypass valves.

.2

[ ] 1A SG FW FLOW FK-478

[ ] 1B SG FW FLOW FK-488

[ ] 1C SG FW FLOW FK-498 OR

[ ] 1A SG BYPASS FLOW FK-479

[ ] 1B SG BYPASS FLOW FK-489

[ ] 1C SG BYPASS FLOW FK-499

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __6___ Page 2 of 4 Event

Description:

PT-464, STM HDR PRESS, fails high. This cause SGFP speed to increase and Steam Dumps to open until they interlock closed at P-12 (543F Tavg) (P-CT)

Time Position Applicants Actions or Behavior Comments 1.3 IF a loss of main feedwater has Loss of feedwater should occurred, not occur THEN perform the actions required by FNP-1-AOP-13.0, LOSS OF MAIN FEEDWATER.

SRO 2 Sets trip criteria - Typically IF adverse trend in SG level exists, 30% low and 80% high THEN establish trip criteria.

2 3 No ramp in progress BOP IF a ramp is in progress, THEN place turbine on HOLD BOP 4 Adjust speed back to within the normal operating range for the feed flow/steam flow P required for the existing power level.

4 Approximate P can be determined from the following MCB indications.

[ ] SGFP DISCH PRESS PI4003

[ ] SG Pressure indications:

BOP 5 Check Steam Dumps in TAVG Mode.

[ ] STM DUMP MODE SEL A-B TRN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __6___ Page 3 of 4 Event

Description:

PT-464, STM HDR PRESS, fails high. This cause SGFP speed to increase and Steam Dumps to open until they interlock closed at P-12 (543F Tavg) (P-CT)

Time Position Applicants Actions or Behavior Comments 5 (RNO)

IF steam dumps in STM PRESS mode perform the following:

5.1 IF PT-464 failed OR PK-464 not functioning properly, THEN take manual control of PK-464 to control steam dumps as required.

5.1 STM HDR PRESS

[ ] PK-464 6 Contact SM Notify the Shift Manager.

6 7

[CA] WHEN plant conditions permit, THEN restore components to automatic control.

7 8

Submit a condition report on the failed Has RO/BOP contact instrument, and notify the Work Week appropriate personnel Coordinator (Maintenance ATL on backshifts) of the condition report.

9 Go to procedure and step in effect.

Note; RCS Tavg will recover above 541F when the Steam Dumps close

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __6___ Page 4 of 4 Event

Description:

PT-464, STM HDR PRESS, fails high. This cause SGFP speed to increase and Steam Dumps to open until they interlock closed at P-12 (543F Tavg) (P-CT)

TECHNICAL SPECIFICATION 3.4.2 RCS Minimum Temperature for Criticality 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature (Tavg) shall be 541°F.

APPLICABILITY: MODE 1, MODE 2 with keff 1.0.

Condition A SRO CONDITION REQUIRED ACTION COMPLETION TIME A. Tavg in one or A.1 Be in MODE 3. 30 minutes more RCS loops not within limit.

At discretion of Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 1 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Indications Available

- Rx power rises until trip - CTMT pressure rises

- Many Annunciators Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 2 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit RO/BOP 3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

RO/BOP 4.1 (RNO)

Check SI required 4.1.1 (RNO)

IF any setpoint and coincidence shown in the coincidence shown in the reached or exceeded, THEN SI is required.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 3 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO/BOP 4.1.2 (RNO) Critical task - Actuate SI IF SI is required, THEN actuate SI.

This step is N/A 4.1.3 (RNO)

IF SI NOT required, THEN go to FNP-1-ESP-0.1, REACTOR TRIP RESPONSE.

RO/BOP 4.2 Verify both trains of SI- ACTUATED

[] MLB1 1-1 AND MLB1 11-1 lit RO/BOP 5 See page 15 below Verify actuation signal automatic actions using ATTACHMENT 2, AUTOMATIC ACTIONS VERIFICATION.

RO/BOP 6

[CA] Check containment pressure - HAS REMAINED LESS THAN 27 psig.

CTMT PRESS

[] PR 950

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 4 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO 6 (RNO) 6 Perform the following.

6.1 Verify PHASE B CTMT ISO - ACTUATED.

[] MLB-3 1-1 lit

[] MLB-3 6-1 lit 6.2 Stop all RCPs.

RCP

[] 1A

[] 1B

[] 1C 6.3 Verify PHASE B CTMT ISO alignment.

6.3.1 Check All MLB-3 lights lit 6.3.2 all MLB 3 lights lit IF any MLB-3 light NOT lit, THEN verify PHASE B CTMT ISO using ATTACHMENT 5, PHASE B CONTAINMENT ISOLATION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 5 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO 6.4 CS actuates properly Check containment spray.

6.4.1 Check containment spray flow in both trains greater than 0 gpm.

CS FLOW

[] FI 958A

[] FI 958B 6.4.2 IF containment spray flow in both trains NOT greater than 0 gpm, THEN verify containment spray pump suction valves open.

RWST TO 1A(1B) CS PUMP

[] Q1E13MOV8817A

[] Q1E13MOV8817B 6.4.3 IF unable to establish spray flow in a train, THEN secure containment spray pump in affected train.

[] CS RESET TRN A(B) containment spray signals - RESET (Annunciator EE4 clear).

[] CTMT SPRAY PUMP 1A(B) -

STOPPED in affected train RO/BOP 7 Announce "Unit 1 reactor trip and safety injection."

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 6 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 8 Check AFW status.

8.1 Check secondary heat sink available.

[] Total feed flow to SGs - pumps started.

GREATER THAN 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B TDAFWP STM SUPP

[] FI 3229C FROM 1B(1C) SG AFW TOTAL FLOW

[] FI 3229

[] Narrow range level in at least one SG - GREATER THAN 31%{48%}

8.2 WHEN all SG narrow range levels less than 31%{48%},

THEN maintain total AFW flow greater than 395 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 7 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 8.3 WHEN at least two SG narrow range levels greater than 28%

AND TDAFWP NOT required, THEN stop TDAFWP 8.4

[CA] WHEN SG narrow range level greater than 31%{48%},

THEN maintain SG narrow range level 31%-65%{48%-65%}.

8.4.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 8 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 8.4.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted RO 9 Check RCS temperature.

-IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547F.

TAVG 1A(1B,1C) RCS LOOP

[] TI 412D 9.1.1 Verify steam dumps closed.

[] TI 422D

[] TI 432D OR IF no RCP running, THEN check RCS cold leg temperature - STABLE AT OR closed.

APPROACHING 547F.

RCS COLD LEG TEMP RECORDER

[] TR 410

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 9 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO/BOP 9 (RNO)

Perform the following.

9.1 IF RCS temperature less than 547F and falling, THEN perform the following. IF RCS temperature greater than 547F and rising, THEN proceed to RNO Step 9.2.

9.1.1 Verify steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[] B TRN in OFF RESET 9.1.2 Verify atmospheric reliefs closed 1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A

[] PC 3371B

[] PC 3371C 9.1.3 IF cooldown continues, THEN control total AFW flow to stop RCS cooldown.

9.1.4 IF MSIVs are closed THEN proceed to Contacts TB SO step

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 10 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 9.1.9 IF main steam lines isolated AND gland steam supplied from Unit 1, THEN break condenser vacuum.

COND VAC BKR MAN ISO (155 ft, TURB BLDG)

[] N1N51V518A open

[] N1N51V518B open COND VAC BKR VLVS

[] N1N51V519A/519B open 9.2 This step is N/A IF RCS temperature greater than 547F and rising, THEN perform the following.

RO 10 Check pressurizer PORVs and spray valves.

10.1

[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

10.1.1 Verify both PRZR PORVs indicate CLOSED 10.1.2 Check PRZR PORV temperature STABLE OR FALLING

[] PORV Temp TI-463 10.1.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 11 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO 10.2

[CA] WHEN pressurizer pressure less than 2260 psig, spray flow. THEN verify normal pressurizer spray valves closed OR closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C

[] PK 444D 10.3 Check any PRZR PORV ISO - OPEN RO 11 RCPs are secured Check RCP criteria.

11.1 Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16F{45F}

SUBCOOLED IN CETC MODE.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 12 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO 12 Monitor charging pump miniflow criteria.

12.1 Control charging pump miniflow valves based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

[] PI 402A

[] PI 403A BOP 13 Check SGs not faulted.

13.1 Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

SRO 13 (RNO)

Go to FNP-1-EEP-2, FAULTED STEAM GENERATOR ISOLATION

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 13 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments EEP-2, FAULTED SG ISOLATION, ver 15 BOP 1 Verify all MSIV and bypass valves -

CLOSED. Place handswitches for all MSIVs to the CLOSED position (6 total)

BOP 2 Only 1B SG will be blowing Check if any SG not faulted. down Check pressure in at least one SG -

STABLE OR RISING.

3 1B Identify the faulted SG 3.1 Check pressure in any SG- FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

BOP 4 Isolate all faulted SGs.

4.1 Verify 1B ARV closed - PC3371B minimum demand 4.2 Critical task - HV7614 Verify 1B SG Feed stop valves closed must be manually closed.

MOV3232B 4.3 Verify blowdown from all faulted SGs -

ISOLATED. HV 7614B 4.4 Since the fault is on the 1B SG, the crew will proceed to step 4.5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 14 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments SRO 4.5 Will call BOOTH operator to IF 1B SG faulted, then isolate TDAFWP have this accomplished steam supply from 1B SG

- IF TDAFWP NOT required, THEN isolate TDAFWP steam supply from 1B SG at hot shutdown panel.

BOP 4.6 Verify SG blowdown sample ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed BOP 5 Isolate AFW flow to all faulted SGs.

5.1 Close MDAFWP isolation valves to all faulted SGs. (BOP)

- Closes MOV3764B or MOV3764D BOP 5.2 Close TDAFWP flow control valves to all faulted SGs.

TDAFWP FCV 3228

[] RESET reset SRO 5.3 key Z-139 Call to SSS-P or TSC to have Q1N23V017B closed in the MSVR Critical task - This completes SG isolation

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 15 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 6 Check CST level greater than 5.3 feet 7

Check secondary radiation indication -

NORMAL.

SRO 8 Evaluate SI termination criteria

- Check SCMM indication -

GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

- Check secondary heat sink available.

>395 gpm AFW flow OR

> 31%{48%} SGNR level

- Check RCS pressure - STABLE OR RISING

- Check pressurizer level >

13%{43%}.

Expected exam termination

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 16 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 2, ver 45 1

Verify one CHG PUMP in each train -

BOP STARTED.

[] A train (1A or 1B) amps > 0

[] B train (1C or 1B) amps > 0 BOP 2 Verify RHR PUMPs - STARTED.

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP 3 Verify Safety Injection Flow.

3.1 Check HHSI flow - GREATER THAN 0 gpm.

[] FI 943 BOP 3.2 Operator should proceed to Check RCS pressure - LESS THAN step 4 275 psig{435 psig}.

BOP 4 Verify each SW train - HAS TWO SW PUMPs STARTED.

[] A train (1A,1B or 1C)

[] B train (1D,1E or 1C)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 17 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 5 Verify each train of CCW - STARTED.

5.1 Verify one CCW PUMP in each train-STARTED.

A train HX 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 18 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 6 Verify containment ventilation isolation.

6.1 Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 6.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 6.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 19 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 7 Verify containment fan cooler alignment.

7.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[] 1A

[] 1B B train

[] 1C

[] 1D 7.2 Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 20 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 8 Verify AFW Pumps - STARTED.

8.1 Verify both MDAFW Pumps - STARTED

[] 1A MDAFW Pump amps > 0

[] 1B MDAFW Pump amps > 0 AND

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 21 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments 8.2 Check TDAFW Pump start required.

8.3 Verify TDAFWP started.

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

8.4 Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 22 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 9 Verify main feedwater status.

Verify main feedwater flow control and bypass valves - CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[] FCV 488

[] FCV 498 9.2 Verify both SGFPs - TRIPPED.

9.3 Verify SG blowdown - ISOLATED.

1A(1B,1C) SGBD ISO

[] Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample - ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 23 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 10 Check no MSL isolation actuation signal present.

10 (RNO)

Perform the following.

10.1 Verify main steam line isolation and bypass valves closed.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYP

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 24 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments 11 Verify PHASE A CTMT ISO.

BOP 11.1 Verify PHASE A CTMT ISO - ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO BOP 12 Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP 13 Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11E005A

[] N1C11E005B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 25 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 14 Secure secondary components.

14.1 Stop both heater drain pumps.

HDP

[] 1A

[] 1B 14.2 Check any condensate pump started.

14.2.1 IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 14.3 IF condensate pump operating, Will call TBSO to THEN verify backup cooling aligned to accomplish this.

condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP 15 Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN BOP 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810 - OPEN

[] 914 - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 26 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 17 Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 27 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 4, ver 45 1

Verify two trains of ECCS equipment aligned.

1.1 - 1.4

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 closed 1.5

[] Verify two trains of battery chargers -

energized

[] A Train (1A or 1C) amps > 0

[] B Train (1B or 1C) amps > 0 1.6 Verify two trains of ESF equipment aligned.

1.6.1 Check all MLB-1 lights LIT 1.6.2 Verify charging pump suction and discharge valves - OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 28 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B 1.8 WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP 1.9 Call Radside SO Verify SFP Cooling in service per SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of Attachment 4

Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #5 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 7/22/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 5 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 100% power, MOL, Cb 915 ppm, A Train On Service, 1B MDAFW pump is tagged out.

Turnover:

• 100% power, MOL, Cb 915 ppm.

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

• CCW surge tank is low due to sampling. Refill CCW surge tank back to 45 in.

Event Malf. Event Event No. No. Type* Description 1 preset N (BOP) Refill CCW Surge Tank 2 xmt/ I (RO) PT-447, TURB FIRST STG PRESS, fails low.

PT447 TS - 3.3.1 Cond U, 3.3.2 Cond D TS (SRO) 3 R (RO) Shift Manger will direct ramp down to support Governor Valve testing.

4 xmt/ I (BOP) FT-475, 1A SG STM FLOW, fails low. (P-CT)

FT475 TS- 3.3.2 Cond D TS (SRO 5 pmps/ C (RO) 1C Charging pump experiences a sheared shaft.

NCVP01C TS - 3.5.2 Cond A TS (SRO)

-B 6 cCFCN1A C (BOP) 1A Condensate pump trips after receiving a high bearing temperature

_cc11 alarm and experiences degraded head. 1C Condensate pump will not automatically start. (P-CT) preset 7 malf/ M (ALL) Main Steam Line Break on downstream of the MSIVs MAL-MSS9 MSIVs will not automatically close if low steam line pressure is met.

preset C (BOP) MSIVs must be manually closed. (CT-12) 8 preset M (ALL) The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required.

Restore feed using Condensate pump. (CT-43)

Terminate upon exit from FRP-H.1

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario Presets Form ES-D-1 EVENT # TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-223 (Base IC-73)

CCW surge tank lowered to 37 in.

rst 223 0 0 Generic setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc5.txt 0 0 RUN PRESETS setup Tag out 1B MDAFW pump

• irf cAFP01B_d_cd1 open setup SIM IC will have CCW Surge Tank level lowered N/A 6 1A Condensate pump trips 5 minutes after the *TRG1 high bearing temperature alarm.

trg 1 "imf cCFCN1A_cc5 2 300" 6 1C Condensate pumps fails to auto start

• imf cCFCN1C_cc8 open imf cCFCN1C_cc9 open 6 1A Condensate pump degraded head *TRG 4 trg 4 imf ncfcn1a-d_th 20 300 7 MSIVs will not close on MSLIAS

• imf cRSH001A_cc5 open imf cMSH002A_d_cc5 open imf cRSH001B_cc5 open imf cMSH002B_d_cc5 open imf cRSH001C_cc5 open imf cMSH002C_d_cc5 open 8 TDAFW pump will trip *TRG2 imf MAL-FWM1C (2 0) 8 1A MDAW pump will trip on overload *TRG3 trg 3 "imf cafp01a_d_co2"

Triggers and Commands 6 Monitor 1A Condensate High Temperature alarm *TRG 4 trgset 4 "xnmkd10x >= 1" 6 Monitor 1A Condensate High Temperature alarm *TRG1 trgset 1 "xnmkd10x >= 1" 8 Monitor Rod 1 position *TRG2 trgset 2 "mcrfns(1) == 0" 8 Monitor Rod 2 position *TRG3 trgset 3 "mcrfns(2) == 0"

MCB setup OVATION Clear OVATION alarms Place danger TAG ON 1B MDAFW Pump HS on MCB Place tag on 1B MDAFWP HS Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms Unit 1 Train B Bypass & Inoperable Status Ind Panel on AFW Switch in ON EPB - AFW SYSTEM Switch in "ON IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 Start of Refill CCW surge tank exam 2 NRC PT-447, TURB FIRST STG PRESS , fails low CUE TS - 3.3.1 Cond U, 3.3.2 Cond D imf pt447 0 0 3 NRC Shift Manger will direct ramp down to support Governor CUE Valve testing.

4 NRC FT-475, 1A SG STM FLOW, fails low. (P-CT)

CUE TS- 3.3.2 Cond D imf ft475 0 15 5 NRC 1C Charging pump experiences a sheared shaft.

CUE TS - 3.5.2 Cond A imf NCVP01C-B 6 NRC 1A Condensate pump experiences degraded head and CUE trips 5 minutes after receiving a high bearing temperature alarm.

TRG3 imf kk4 failon preset 1C Condensate pump will not automatically start.

EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC Main Steam Line Break on downstream of the MSIVs CUE imf mal-mss9 3 120 MSIVs will not automatically close if low steam line preset pressure is met. MSIVs must be manually closed.

8 The Linkage on the TDAWFP will fail causing it to trip. TRG 2 & 3 1A MDAFWP Trips on Overload. FRP-H.1 entry is required.

NRC END OF EXAM:

CUE Restore feed using Condensate pump Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen5grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 IF REQUESTED cae Turbine_Bldg_MSRs.cae (10 minutes after requested, SOP-0.0 actions for a Rx trip/Safety Injection) 9.1.7 RNO of EEP-0 cae 2015_TB_MSDP_iso.cae (5 minute after requested)

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 8 IF REQUESTED Install jumpers per ATT1 of FRP-H.1 irf loa-cfw047 installed (5 minutes after requested)

Place requested AFW pumps in local at HSDP per step 5.3.1 (RNO) - DO NOT PERFORM STEP 5.3.2 (RNO)

(3 minutes after requested) (NEXT PAGE)

Place requested AFW pumps in local at HSDP per step 5.3.3.1 (RNO)

(3 minutes after requested) (NEXT PAGE)

Open V509 irf loa-cfw021 1 30 (3 minutes after requested)

Close V502A & 502B irf loa-cfw015 0 30 irf loa-cfw016 0 30 (3 minutes after requested)

Open FV-K2, FV-K3, FV-L2 irf cmf3232a_d_cd1 open irf cmf3232b_d_cd1 open irf cmf3232c_d_cd1 open (As required per comms with MCR)

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the cue and inform supervision) that type of communications 1 IF REQUESTED Chemistry: Acknowledges that CCW surge tank is being made up to.

2 IF REQUESTED Shift or Operations Manager: If the crew asks whether or not to reset C-7: What do you recommend?

Shift or Operations Manager: Agree with the crews recommendation on C-7: Do not reset C-7 or Reset C-7.

3 CUE Shift Manager: Ramp the unit to 90% for Governor Valve testing.

4 IF REQUESTED Shift Manager: If asked to place components in AUTO after the event: What do you recommend?

Shift Manager: Agree with the crews recommendation: Place (Component(s)) back in AUTO or Maintain (Component(s)) in MANUAL.

5 IF REQUESTED RAD 1 SO: 3 minutes after requested - 1C Charging pump motor is running but the pump is not rotating.

SSS: We will brief then shift 1B Charging pump to B train.

RAD 1 SO: 3 minutes after requested: FCV-122 is in the (current position). There are no obvious problems.

CHEM: We will secure the Zinc addition system.

SSS: We will brief and then rackout 1C Charging pump breaker.

6 IF REQUESTED U2 Operator: When requested - 1A Condensate pump thrust bearing is 187°F and slowly rising.

TB SO: 3 minutes after requested: The 1A Condensate pump appears normal TB SO: 3 minutes after requested (after pump tripped): 1A Condensate pump not running. No abnormal indications.

ROVER: 3 minutes after requested (after pump tripped): DA03 has an overcurrent trip flag

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

7 IF REQUESTED TBSO: 3 minutes after requested - There is no steam coming from any pipe on the MSVR roof SO (May be DB, TB or ROVER): 3 minutes after requested -

There is steam no coming from the MSVR grating TBSO: 3 minutes after requested - There is significant steam on the 155ft level of the Turbine Building. I cannot tell where it is coming from.

SSS: The 1B MDAFW pump is due back in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

TB SO: 10 minutes after requested - SOP-0.0 actions for a Rx trip/Safety Injection are complete.

RAD 1 SO: I will verify SFP cooling in service per SOP-54.0 8 IF REQUESTED ROVER: 3 minutes after requested - TDAFWP trip throttle valve linkage is broken and cannot be reset.

ROVER: 3 minutes after requested - 1A MDAWP is not running. No obvious problems noted.

ROVER: 3 minutes after requested - DF-10 has an overcurrent trip flag.

SSS: Align makeup to the CST from water treatment plant OR demin water system using FNP-1-SOP-5.0, DEMINERALIZED MAKEUP WATER SYSTEM, as necessary.

TB SO: 3 minutes after requested - Back up cooling is aligned to the Condensate pumps.

SSS: Coordinate performance of Step 5.3.1 through (XXX) RNO of FRP H.1 for the ( pumps asked for).

SSS: 3 minutes after place in local: The (pumps requested) did not start at the HSDP.

SSS: Coordinate performance of Step 5.3.3.1 of FRP H.1 for the (pumps asked for).

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

8 cont SSS: 5 Minutes after requested - Jumpers are install per ATT 1 of FRP-H.1 TB SO: 3 minutes after requested - V509 is open.

Action Buttons are TB SO: 3 minutes after requested - V502A & V502B are above closed.

RAD 1 SO: 3 minutes after requested - Standing by in the 139ft penetration room to operate breakers.

(When directed to open breakers, open the requested breakers using LOAs above and proper 3 way communications)

Appendix D Scenario Detailed Summary Form ES-D-1 Initial Conditions: 95% power, MOL, Cb 915ppm, A Train On Service, 1B MDAFW pump is tagged out.

Turnover:

• 95% power, MOL, Cb 915 ppm, ramping up.

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

• CCW surge tank is low due to sampling. Refill CCW surge tank back to 45 in.

EVENT 1: Refill the CCW Surge tank.

Verifiable actions: BOP will open 2 surge tank fill valves and monitor level. When level reaches 45 inches, the valves will be closed.

EVENT 2: PT-447, TURB FIRST STG PRESS, fails low.

Verifiable actions: RO will place rods in manual to stop rod motion. SRO - Tech Spec:

3.3.1 Cond U, 3.3.2 Cond D.

EVENT 3: Shift Manager directs a ramp down to support Governor Valve testing.

Verifiable actions: RO use rods and Boron to reduce power.

.EVENT 4: FT-475, 1A SG STM FLOW, fails low.

Verifiable actions: BOP takes manual control of 1A FRV and SGFP speed and restores SGWL. SRO - Tech Spec: 3.3.2 Cond D.

(P-CT) If the BOP fails to properly control SGWL a LOLO Level Reactor trip will occur if 1 SG reaches 28% or if 1 SG reaches 82% a turbine trip will occur causing a reactor trip.

EVENT 5: 1C Charging pump experience a sheared shaft.

Verifiable actions: RO isolates letdown by closing Letdown Orifice Isolations and starts another Charging pump. SRO - Tech Spec: 3.5.2 Cond A EVENT 6: 1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start.

Verifiable actions: BOP will start the standby Condensate pump manually.

(P-CT) If the BOP does not start the standby Condensate pump promptly, the SGFPs will trip on low suction pressure which wiil require a manual Reactor trip. If SGWL is not controlled after the Condensate pump is started a Rx trip may be required due to a FW isolation from overfeeding the SGs.

EVENT 7: Main Steam Line break downstream of the MSIVs.

Verifiable actions: BOP will have to close MSIVs. (CT-12)

EVENT 8: 1A MDAFW pump trips and the linkage on the TDAWF pump fails. FRP H.1 entry required.

Verifiable actions: Restore Feed using a Condensate pump. (CT-43)

Similar to Audit - Audit exam designed to restore feed using a SGFP.

Terminate on Exit from FRP-H.1

Appendix D Scenario Critical Tasks Form ES-D-1

_____ 1. Manually actuate main steamline isolation before a severe (ORANGE path) challenge develops to either the subcriticality or the integrity CSF or before transition to ECA-2.1 whichever happens first. (CT-12)

_____ 2. Establish feedwater flow into at least one SG [before RCS bleed and feed is required. (CT-43)

SCENARIO At power power instrument and component failures with a Steam Break outside OBJECTIVE/ Containment followed by a loss of Secondary Heat Sink.:

OVERVIEW:

• refill the CCW Surge Tank

• reduce reactor and turbine power

• respond to PT-447, TURB FIRST STG PRESS, failing low

• restore SGWL on a failure of FT-475, 1A SG STM FLOW, low

• respond to a Charging pump sheared shaft

• respond to a loss of Condensate pump

• respond to a Steam Break down stream of the MSIVs

• restore Secondary Heat Sink.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 2

2. Abnormal events (2-4) 4

3. Major transients (1-2) 2

4. EOPs entered/requiring substantive actions (1-2) 0

5. EOP contingencies requiring substantive actions (0-2) 1

6. Critical tasks (2-3) 4

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 1, 100% RTP, 915 ppm Cb, MOL 10000 MWD/MTU,

-2740pcm Xe (Equilibrium)

A Trn O/S / A Trn Protected / SFPC on A Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 167 hours0.00193 days <br />0.0464 hours <br />2.761243e-4 weeks <br />6.35435e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />

3. CCW surge tank low due to sampling. Refill to 45 in.

4.

5.

6.

7.

8.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas) 1B MDAFW pump - 3.7.5 Cond B LCO status (planned- entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago) #1 RHT Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __1___ Page 1 of 2 Event

Description:

Refill the CCW surge tank. The CCW Surge tank will be at 37 in due to sampling and the operating crew will be required to refill it.

Indications Available

- LI-3027A & B, CCW SRG TK LVL are reading 37 in.

Time Position Applicants Actions or Behavior Comments SOP-23.0, COMPONENT COOLING WATER SYSTEM, ver 94.2 BOP 4.18.1 Contacts Chemistry Notify Shift Chemist that the CCW surge tank is to be made up to.

BOP 4.18.2 Verify open CCW SRG TK VT valves:

(MCB)

Q1P17SV3028A Q1P17SV3028B BOP 4.18.3 Monitor CCW surge tank level indications.

LI-3027A LI-3027B BOP 4.18.4 Maintain level between 35 inches and 50 inches.

BOP 4.18.5 One of the 2 valves must be IF desired, THEN open MKUP TO CCW opened to fill the CCW FROM DW STOR TK Q1P17MOV3030A surge tank or the operator to add makeup to A portion of CCW surge can open BOTH valves.

tank.

BOP 4.18.6 IF desired, THEN open MKUP TO CCW FROM DW STOR TK Q1P17MOV3030B to add makeup to B portion of CCW surge tank.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __1___ Page 2 of 2 Event

Description:

Refill the CCW surge tank. The CCW Surge tank will be at 37 in due to sampling and the operating crew will be required to refill it.

Time Position Applicants Actions or Behavior Comments BOP 4.18.7 Will close the valves WHEN makeup addition is completed, opened in Steps 4.18.5 THEN close appropriate valve(s). and/or 4.18.6 MKUP TO CCW FROM DW STOR TK Q1P17MOV3030A.

MKUP TO CCW FROM DW STOR TK Q1P17MOV3030B.

After filling is completed or at the discretion of the Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __2___ Page 1 of 4 Event

Description:

PT-447, TURB FIRST STG PRESS, fails low.

Indications Available

- TAVG / TREF DEV (HF3) Indications of PT-447 failing low:

- HI STM FLOW ALERT (JB4) - PI-447 decreases to 0 psig

- TI-408A TAVG - TREF increases to +5°F

- TR-408 HIGH TAVG / TREF

- TREF Decreases to 547 °F

- Loss of Load Interlock C-7A light on BYP and Permissive Panel lights up

- TSLB4 channel 4 bi-stable lights 16-3; 17-3; 18-3, for loops 1; 2; & 3 Hi Steam Flow Illuminate

- Control Rods step in at 72 steps per minute IF ROD CONTROL IN AUTO Steam Dump Loss of Load Controller is armed.

Time Position Applicants Actions or Behavior Comments RO Recognizes rods moving in unexpectedly SRO If not taken by RO, directs immediate operator actions of AOP-19, Malfunction of Rod Control System ver 30 AOP-19.0, MALFUNCTION OF ROD CONTROL SYSTEM, ver 30 RO 1 Immediate operator action IF undesired rod motion occurring, THEN stop rod motion.

2 1.1 IF rod control in AUTO, THEN place rod control in MANUAL.

1.2 Check Rod motion - STOPPED.

RO 2 Evaluate undesired rod motion.

2.2 2.1 Check N-44 Operable YES 2.2.1 2.2 Check selected Pimp channel NO Operable.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __2___ Page 2 of 4 Event

Description:

PT-447, TURB FIRST STG PRESS, fails low.

Time Position Applicants Actions or Behavior Comments SRO 2.2 Section 1.3 Go to FNP-1-AOP-100.0, INSTRUMENTATION MALFUNCTION, ver 15 AOP-100, INSTRUMENTATION MALFUNCTION, Section 1.3, ver 15 RO 1 Check no load rejection in progress.

RO 2 IF the selected channel of Pimp has failed, THEN select the unaffected channel.

3 2.1 Verify control rods in MANUAL.

2.2 FIRST STG IMPULSE PRESS SEL SWITCH PS/446Z

[ ] PT-446 (CH-III) selected OR

[ ] PT-447 (CH-IV) selected 2.3 Check C5 permissive light on.

LOW TURB IMPULSE PRESS AUTO ROD WDRL

[ ] BLOCKED C lit RO/BOP 3 Uses rods, boron, turbine IF required, controls to restore Tavg THEN restore Tavg to programmed value.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __2___ Page 3 of 4 Event

Description:

PT-447, TURB FIRST STG PRESS, fails low.

Time Position Applicants Actions or Behavior Comments 4

Refer to Tech Spec 3.3.1 & 3.3.2 for LCO See below requirements.

TECHNICAL SPECIFICATION 3.3.1, Reactor Trip System (RTS) Instrumentation The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

Table 3.3.1-1 Reactor Trip System Instrumentation Function 17f - Turbine Impulse Pressure, P-13 Applicable in Mode 1 2 required channels condition U SRO CONDITION REQUIRED ACTION COMPLETION TIME U. One channel U.1 Verify interlock is in inoperable. required state for existing unit 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> conditions.

OR M.2 Be in Mode 2. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> TECHNICAL SPECIFICATION 3.3.2, Engineered Safety Feature Actuation System (ESFAS)

Instrumentation The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE.

Table 3.3.2-1 ESFAS Instrumentation Function 4e - High Steam Flow in Two steam lines Applicable in Mode 1 required channels- 2 per steam line condition D SRO CONDITION REQUIRED ACTION COMPLETION TIME D. One channel -----------------NOTE-----------

inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.

D.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR D.2.1 Be in mode 3 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> AND D.2.2 Be in mode 4 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br />

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __2___ Page 4 of 4 Event

Description:

PT-447, TURB FIRST STG PRESS, fails low.

Time Position Applicants Actions or Behavior Comments 5 Contacts SM Notify the Shift Manager RO 6

[CA] WHEN Tavg is within +/-1°F of Tref AND plant conditions permit, THEN return rod control to auto.

RO 7 Has RO/BOP contact Submit a condition report documenting appropriate personnel the failure and notify the Work Week Coordinator (Maintenance ATL on back shifts) of the condition report.

SRO 8 This should not be IF PT-447 failed, AND it is desired to reset performed C-7A, THEN go to FNP-1-SOP-18.0, STEAM DUMP SYSTEM.

SRO 9 Go to procedure and step in effect.

At Lead Examiners discretion, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 1 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Indications Available Rx power lowering.

Time Position Applicants Actions or Behavior Comments SRO Directs the RO / BOP to commence ramp down to <90%

UOP-3.1, Power Operation, Section 8, ver 120 BOP 1.

Review and perform the following as required BOP a This step is N/A If Turbine Overspeed Test is to be performed, Refer To Section 3.0 Precaution and Limitation 1.l prior to commencing ramp...

BOP b For normal load reductions, a ramp rate restriction of 2 MW/min (14% per hour) will apply............................................................

BOP c This step is N/A When conditions warrant a ramp rate of greater than 2 MW/min, notify the Shift Manager as soon as conditions permit.

BOP d This step is N/A Enter FNP-1-AOP-17.1, RAPID TURBINE POWER REDUCTION in conjunction with this procedure for ramp rates greater than 5 MW/min.........

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 2 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments BOP e This step is N/A Ramp as slow as possible if known fuel leak exists. Power decreases should follow the guidance found in Attachment 1, Special Load Rate Limitations.

BOP f This step is N/A If a power reduction is being performed due to entry into Technical Specifications 3.4.16, adjust the ramp rate to meet the shutdown requirements of the specification.

BOP g This step is N/A If a reactor shutdown is NOT for a refueling outage, record criticality data in the Control Room Log prior to load decrease.

BOP h Maintain valve position limit 115% while ramping or at 100%.

BOP i This step is N/A Maintain valve position 8 to 10% above valve position demand when holding for more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at some power level less than 100%.

BOP j This step is N/A Flush and sample AFW pump suction piping as required by FNP-1-SOP-22.0 ,

Auxiliary Feedwater System, prior to initiation of AFW flow to the SGs.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 3 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments BOP 2 BOP place IMP loop in While ramping between 97% and 20% service per step 2 power, verify the IMP PRESS LOOP in service as follows:

BOP a Verify Turbine on HOLD. ..............

BOP b Check Ovation point, 1ST STG IMPLS PRESS, has stable indication.

BOP c On LOOP STATUS of page 5551, press SELECT BOP d On popup 7053, press IMP BOP e On popup 7059, press IMP LOOP IN.

BOP f On LOOP STATUS of page 5551, check IMPULSE displays YES BOP 3 On page 5551, perform the following to set desired load target and load rate.................

a On RAMP INTERFACE section, press MODIFY b

On TARGET SELECTION section of BOP inserts ramp to <90%

popup 7055, enter desired target using one of the following methods:

• Using predefined buttons.

• Using CUSTOM button to enter custom rate

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 4 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments c

On RAMP INTERFACE section of page 5551, check desired target appears under TARGET.

d On page 5551, check HOLD button has gold background e

IF desired to change load rate, on RAMP INTERFACE section of page 5551 press MODIFY.

(1)

On popup 7055, enter desired rate by either of the following Using predefined buttons.

Using predefined buttons.

(2)

On RAMP INTERFACE section of page 5551, check desired rate appears under RATE.

4 Inform other Control Room operators load will be changed.

5 Press GO to commence ramp.

BOP 6 Verify proper SGFP speed control.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 5 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments RO 7 Attempt to maintain the axial flux difference within + 5% from the target value by making adjustments in rod height and/or boron concentration as necessary...........

RO Uses Borations to lower Tavg during the ramp SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix B, v60.1 RO 1.1 From reactivity briefing IF necessary, THEN set the boric acid sheet integrator to the desired quantity.

RO 1.2 IF necessary, THEN adjust LTDN TO VCT FLOW LK 112 setpoint as desired.

1.3 Position the MKUP MODE CONT SWITCH to STOP.

1.4 Position the MKUP MODE SEL SWITCH to BOR.

1.5 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 6 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments RO 1.6 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.7 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.8 This step is N/A If desired to clear the line of acid, perform the applicable steps of Appendix B Section 2.0.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 7 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments Note: If the crew decides to remain lined up for repetitive borations, then steps 1.9 -

1.11 are N/A. Repetitive boration steps are listed in Appendix C below.

RO 1.9 Position the MKUP MODE SEL SWITCH to AUTO.

1.10 Position the MKUP MODE CONT SWITCH to START.

1.11 IF LK 112 setpoint was adjusted per Step 1.2, THEN return setpoint to that required for current conditions.

SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix C, v60.1 RO 1.1 IF necessary, THEN set FIS-113 Boric Acid Batch Integrator to the desired quantity.

1.2 The Reactor Makeup Control system has been previously aligned for Boration.

1.3 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 8 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments RO 1.4 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.5 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.6 IF repetitive borations are no longer required THEN verify the system is aligned for Automatic makeup per Steps 1.9 through 1.11 of Appendix B.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 9 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments SOP-41.0, Control Rod Drive and Postion Indication System, Ver 37 OPERATOR AID FOR CONTROL ROD MOVEMENT RO 1 Place ROD CONTROL BANK SELECTOR SWITCH in MAN.

RO 2 Check indicated control rod speed is approximately 48 steps per minute on SI-408.

RO 3 Insert OR withdraw Control Rods using the CONTROL ROD MOTION switch.

RO 4 When desired, place rod control in AUTO as follows:

RO 4.1 Verify Tavg within 1°F of Tref.

RO 4.2 Place the ROD CONTROL BANK SELECTOR SWITCH in AUTO.

RO 4.3 Check indicated control rod speed is approximately 8 steps per minute on SI-408.

After the ramp or at the Lead Examiners discretion then move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 1 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Indications Available

- 1A SG FEED FLOW > STM FLOW (JG2) - Recognize indications of FT-485 failing low:

- 1A SG LVL DEV (JF2) FT-475 fails low - meter dropping to 0 1A FRV position closing

- SG NR level lowering Time Position Applicants Actions or Behavior Comments BOP Recognizes the malfunction and take Immediate Operator Actions of AOP-100, Section 1.5 SRO Directs Immediate Operator Actions of AOP-100 if not performed by the RO/BOP AOP-100, INSTRUMENTATION MALFUNCTION, Section 1.5, ver 15 1 Immediate Operator Action.

[CA] Maintain SG level at the referenced level of 65%. Potential Critical Task -

11 May lose SGWL control 1.1 and cause a Rx Trip.

IF required, THEN, take manual control of SGFP speed control as necessary to restore SG level to 65%

11.1 SGFP master controller

[ ] SK-509A OR SGFP individual controllers as needed.

[ ] SK-509B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 2 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Time Position Applicants Actions or Behavior Comments 1.2 IF required, Potential Critical Task -

THEN take manual control of the affected May lose SGWL control feedwater regulating valves or bypass and cause a Rx Trip valves.

1.2 1.2

[ ] 1A SG FW FLOW FK-478

[ ] 1B SG FW FLOW FK-488

[ ] 1C SG FW FLOW FK-498 OR

[ ] 1A SG BYPASS FLOW FK-479

[ ] 1B SG BYPASS FLOW FK-489

[ ] 1C SG BYPASS FLOW FK-499 1.3 This step is N/A unless 1.3 IF a loss of main feedwater has SGWL exceeds 82% and a occurred, FW isolation occurs THEN perform the actions required by FNP-1-AOP-13.0, LOSS OF MAIN FEEDWATER.

2 IF adverse trend in SG level exists, THEN establish trip criteria.

3 IF a ramp is in progress, THEN place Turbine on HOLD.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 3 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Time Position Applicants Actions or Behavior Comments 4 Determines 1A S/G CH-IV Determine if an instrument failure has has malfunctioned occurred.

4 4.1 Check for a failed or erroneous indications from the following steam flow or feed flow indicators.

4.2 This step is N/A Check for failed or erroneous readings on the following SG pressure indicators:

4.3 IF the alarm(s) was due to a SGWLC System controlling channel failure, THEN select the unaffected channel for STM FLOW AND FW FLOW for the SG associated with the failure.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 4 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Time Position Applicants Actions or Behavior Comments 4.3.1 Selects Channel III on Place the following handswitches to the FS/478Z and FS/478Y appropriate channel III OR IV position as required: ALL switches may be placed in Channel III position (either way is correct) 4.3.2 Verify proper system response.

5 See below Refer to Tech Specs 3.3.1, 3.3.2 & 3.3.3 for any LCO requirements.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 5 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

TECHNICAL SPECIFICATION 3.3.2, ESFAS Instrumentation The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE Table 3.3.2-1 ESFAS Instrumentation Function 4e - High steam flow in two steam lines coincident w/ lo-lo Tavg Applicable in Modes 1, 2 and 3 with MSIVs open required channels - 2 per stm line - condition D CONDITION REQUIRED ACTION COMPLETI ON TIME D. One channel D.1 ------NOTE--------

inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.

Place channel in trip. 72 hrs OR D.2.1 Be in MODE 3. 78 hrs AND D.2.2 Be in MODE 4. 84 hrs

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 6 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Time Position Applicants Actions or Behavior Comments 6

Notify the Shift Manager.

7 Requests SM permission to

[CA] WHEN plant conditions permit, place controllers in AUTO THEN return systems to automatic and then place them in control. AUTO 8

Submit a condition report for the failed Has RO/BOP contact the instrument, and notify the Notify the appropriate people Work Week Coordinator (Maintenance ATL on backshifts)of the condition report.

9 Go to procedure and step in effect.

At the discretion of the Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 1 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Indications Available

- EA2, CHG HDR FLOW HI-LO - FI-122 goes to 0

- DD1, RCP SEAL INJ FLOW LO - 1C Charging pumps amp lower

- VCT level rising

- PRZR level decreasing Time Position Applicants Actions or Behavior Comments RO Announces the alarms and / or recognizes the loss of flow and inform the SRO SRO Directs ARP entry RO Calls RAD 1 SO to investigate Note: when the crew determines that the 1C Charging pump has a sheared shaft, they may secure it since it is damaged.

Note: Crew may decide to secure letdown using the MCB placard. The steps are listed below. If they chose to go to AOP-16, they are on page 3 SOP-3.2, CVCS Plant Startup and Operation, ver 135 RO 1 Place PK-145 in MANUAL and adjust demand to less than or equal to 50%.

RO 2 Close LTDN ORIF ISO 45 GPM, Q1E21HV8149A AND LTDN ORIF ISO 60 GPM, HV8149B OR HV8149C, as applicable.

RO 3 Close LTDN LINE ISO, Q1E21LCV459 and Q1E21LCV460 RO 4 Place FK-122 in MANUAL and adjust to 0% (closed).

RO 5 Verify SEAL WTR INJECTION HIK 186 adjusted.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 2 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 6 Refer To SOP-2.1 when time permits.

ARP-1.5, EA2, CHG HDR FLOW HI-LO, ver 58.2 RO 1 This step is N/A IF the alarm is due to a high flow condition coincident with selecting a different control channel on LS/459Z, THEN consideration should be given to refer to FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION, section 4.6, Charging Flow Control and take manual control of pressurizer level until system equilibrium is restored and pressurizer level control can be returned to automatic.

RO 2 This step is N/A IF desired to control a rapidly rising pressurizer level, THEN close Q1E21MOV8107 or Q1E21MOV8108, CHG PUMPS TO REGENERATIVE HX.

2.1 Remove letdown from service using the MCB Operator Aid (plaque) OR FNP SOP-2.1, Chemical and Volume Control System Plant Startup and Operation.

SRO For a CVCS malfunction during normal plant operations, Go To FNP-1-AOP-16.0, CVCS MALFUNCTION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 3 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments ARP-1.4, DD1, RCP SEAL INJ FLOW LO, ver 54.2 RO 1 IF a loss of seal injection flow has occurred AND a loss of Component Cooling Water to the Thermal Barrier Heat Exchanger has occurred AND at least one method of seal cooling cannot be immediately restored, THEN go to FNP AOP-4.1, ABNORMAL REACTOR COOLANT PUMP SEAL LEAKAGE.

RO 2 Determine the cause of the alarm.

SRO 3 For a CVCS malfunction, go to FNP AOP-16.0, CVCS MALFUNCTION AOP-16.0, CVCS MALFUNCTION, ver 20 RO 1 Verify CHG flow adequate to cool letdown

[] CHG FLOW - FI-122A

[] LTDN HX OUTLET FLOW - FI-150

[] REGEN HX OUTLET TEMP - TI-140 RO 1 (RNO)

Isolate Normal Letdown as follows:

1.1 (RNO)

Verify closed all LTDN ORIF ISOs:

[] Q1E21HV8149A

[] Q1E21HV8149B

[] Q1E21HV8149B RO 2 Stop any load change in progress

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 4 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 3 This step is N/A If charging line rupture occurs then go to attachment 2 4

Monitor VCT level 5

Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation PI-121 and ammeter for chg pump RO 5 (RNO)

IF VCT level reduces to 5%, THEN perform the following:

5.1 Open RWST TO CHG PUMP valves

[] Q1E21LCV125B

[] Q1E21LCV125D 5.2 Close VCT OUTLET ISO valves

[] Q1E21LCV125C

[] Q1E21LCV125E RO 6 Crew will have to determine Check charging pump - RUNNING that the 1C Charging pump is effectively not running or they may have secured it earlier

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 5 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 6 (RNO)

Start an available charging pump as follows:

6.1 Check VCT level and pressure adequate.

6.2 Verify charging suction flowpath aligned:

VCT OUTLET ISO valves

[] Q1E21LCV125C - OPEN

[] Q1E21LCV125E - OPEN OR RWST TO CHG PUMP valves

[] Q1E21LCV125B - OPEN

[] Q1E21LCV125D - OPEN RO 6.3 (RNO)

Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB.

RO 6.4 (RNO)

Check open minflow isolation for charging pump to be started

• 1A CHG PUMP MINIFLOW ISO Q1E21MOV8109A RO 6.5 (RNO)

Verify CHG PUMP MINIFLOW ISO, Q1E21MOV8106, is open RO 6.6 (RNO)

Verify the following are closed;

[] CHG FLOW FK 122

[] SEAL WTR INJECTION HIK 186

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 6 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 6.7 (RNO)

Verify a CCW pump is running in same train aligned to supplycharging pump to be started RO 6.8 (RNO)

Start selected charging pump RO 6.9 (RNO)

Observe CHG HDR PRESS indicator PI 121 and motor ammeter to check proper pump operation RO 6.10 (RNO)

WHEN charging pump comes up to speed.

THEN check auxiliary oil pump stops as indicated by white light NOT being illuminated on MCB.

RO 6.12 (RNO)

Adjust SEAL WTR INJECTION HIK 186 to maintain 6-13 gpm seal injection flow to each RCP RO 6.12 (RNO) This step is N/A IF all seal cooling lost to any RCP, THEN go to AOP-4.1, ABNORMAL REACTOR COOLANT PUMP SEAL LEAKAGE RO 7 Check Charging flow FK-122 controlling in AUTO with flow indicated RO 7 (RNO)

IF required. THEN take manual control of charging flow:

RO 7.1 (RNO)

Place FK-122 in manual and adjust as required to maintain pressurizer level at program level.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 7 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 7.2 (RNO)

Adjust SEAL WTR INJECTION HIK-186 as required to maintain RCP seal injection flow 6-13 gpm RO 7.3 (RNO) If manual control of charging This step is N/A not accomplished. THEN refer to ATT 1, MANUAL CONTROL OF CHARGING RO 8 Check to following annunciator -CLEAR

[] DE3 LTDN ORIF ISO VLV REL LINE TEMP HI RO 9 Determine Status of Normal Letdown:

9.1 Check normal CVCS letdown -

AFFECTED BY MALFUNCTION

• LTDN HX OUTLET FLOW, FI-150 - NO FLOW INDICATED

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 8 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 9.2 Minimize RCS makeup:

9.2.1 Manually close FK-122 9.2.2 Minimize seal injection between 6-13 gpm 9.2.3 Direct Chemistry to shutdown the zinc addition system (ZAS)

RO 9.3 Dispatched personnel Dispatch personnel to investigate cause of earlier letdown malfunction RO 9.4 This step is N/A If desired due to plant conditions, place excess letdown on service RO 10 Determine if normal letdown should be re-established:

10.1 Check normal letdown malfunction(s) -

CORRECTED 10.2 Verify all letdown orifice isolation valves -

CLOSED LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 9 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 10.3 Place LTDN HX OUTLET TEMP TK-144 on service:

[] Place controller in AUTO

[] Set to maintain temp 90 (Pot setting 2.7) to 125°F (Pot setting 4.35)

RO 10.4

[] Position indicator VCT light - LIT

[] Handswitch in-AUTO RO 10.5 Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143

[] Handswitch in - VCT

[] VCT light - LIT

[] DEMIN light - NOT LIT RO 10.6 IF necessary, THEN OPEN both LTDN LINE PENE RM ISOs from the Penetration Room Isolation Panel.

[] Q1E21HV8175A

[] Q1E21HV8175B RO 10.7 Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN RO 10.8 Verify LTDN LINE ISO valves - OPEN

[] Q121LCV459

[] Q121LCV460 RO 10.9 Verify LP LETDN PRESS PK 145 on service:

[] Place controller in MANUL

[] Adjust demand signal o 50% or less Time Position Applicants Actions or Behavior Comments

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 10 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

RO 10.10 Initiate minimum charging flow:

10.10.1 Verify CHG FLOW FK 122 in MAN 10.10.2 Establish minimum charging flow based on orifices to be placed on service:

• 1 Orifice - 18 gpm or

• 2 Orifices - 40 gpm RO 10.12 Establish approx. 60 gpm letdown flow by OPENING:

Q1E21HV8149B OR Q1E21HV8149C RO 10.12 If desired place the second orifice on service by opening Q1E21HV8149A RO 10.13 Will take no action at this Initiate actions to restore letdown flow to time, very time consuming demins per SOP-2.1 RO 10.14 IF all backup heaters energized due to pressurizer level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 11 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 10.15 Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure -

BETWEEN 260-450 psig 10.15.1 Set controller between 4.3 and 7.5 10.15.2 Check letdown flow - STABLE 10.15.3 Place PK 145 in AUTO 10.15.4 Control Letdown pressure as desired RO 10.16 Control LTDN HX OUTLET TEMP TK 144 to maintain Letdown temperature 90 to 125°F

[] TI-126 VCT TEMP

[] TI-143 DIVERT LTDN HX TEMP

[] TI-144 CCW LTDN HX TEMP RO 10.7 Refer to SOP-2.1 for further guidance on Letdown system control RO 11 Determine status of letdown flow:

11.1 Check letdown flow - ESTABLISHED

• Normal letdown flow OR

• Excess letdown flow SRO 11.2 Go to procedure and step in effect

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 12 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments TECHNICAL SPECIFICATION 3.5.2, ECCSOperating Two ECCS trains shall be OPERABLE.

B Train ECCS is INOPERABLE until the 1B chg pump is aligned to B Train and the 1C Chg pump is tagged out or a jumper is installed to permit the 1B Chg pump to auto start Condition A CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore train(s) to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> trains OPERABLE status.

Inoperable AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

At the discretion of the Lead Examiner move to Event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 1 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Indications Available

- KK4, BRG MON PNL ALARM - SGFP suction pressure falls after the 1A Condensate pump trips

- SGFPs trip if no action taken Time Position Applicants Actions or Behavior Comments ARP-1.10, KK4, BRG MON PNL ALARM, ver 72.1 BOP 1 Call U2 operator and Determine the bearing in the alarmed receives the temperature as condition by checking the front panel 187°F and slowly rising LED'S.

BOP 2 SRO may elect to start 1C IF possible, THEN start a standby Condensate pump here component and remove the alarming Component from service.

BOP 3 IF a standby component is NOT available, THEN notify the Shift Supervisor of the alarm and let him evaluate the plant conditions and recommend a course of action to be taken.

BOP 4 Periodically monitor Bearing and determine if temperature is increasing or has stabilized.

BOP 5 Notify appropriate personnel to investigate and repair.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 2 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments NOTE: SOP-0.8, Transient Response Procedure User's Guide, allows the operator to simply start the 1C Condensate pump. This is the expected action and an entry into AOP-13 may only be performed to address other plant parameters out of specification.

4.2.8.3 Operators are expected to take manual action to address non-ESF components which fail to actuate (with the exception of starting a DG, closing a DG output breaker or starting a charging pump) when systems parameters indicate that actuation should have occurred unless the manual action would create a condition that would not mitigate a transient. No permission is required prior to acting. Operators are also expected to take manual action to secure components which do not have support conditions. The Shift Supervisor should be informed as soon as possible after initiating the manual action.

AOP-13, Condensate and Feedwater Malfunction, ver 37 NOTE: AOP-13 can be entered directly at the step for the malfunction BOP 6 Check SGFP suction pressure -

ABNORMAL.

a Check SGFP suction pressure stabilizes above 275 psig.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 3 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP 6a (RNO) Potential critical task - If Perform the following the 1C Condensate pump is not started then a SGFP (1) trip (both pumps) will Verify standby condensate pump occur and a Rx trip will be started. required.

(2)

IF suction pressure still falling, THEN reduce turbine load rapidly using FNP-1-AOP-17.1, RAPID TURBINE POWER REDUCTION.

(3)

IF SGFP(s) trip occurs, THEN return to Step 1.

(4)

If SGFP speed is elevated return to Step 3 OBSERVE CAUTION prior to Step 3.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 4 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP 3 Potential critical task- If Check indication of any SGFP SGWL is not controlled a malfunction RX trip may be required due to overfeeding the

- Any SGFP speed abnormal SGs

- SGFP discharge Pressure - low 1A(1B) SGFP DISCH PRESS PI 4018A(B)

-Feedwater header pressure - low FW HDR BOP a Take manual control of SGFP(s) speed controllers as necessary to control speed and restore feedwater header pressure above steam header pressure.

SGFP master controller

[] SK-509A OR SGFP individual controllers as needed.

[] SK-509B

[] SK-509C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 5 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP b Take manual control of the affected feedwater regulating valves or bypass valves as necessary to control SG level.

[] 1A SG FW FLOW FK-478

[] 1B SG FW FLOW FK-488

[] 1C SG FW FLOW FK-498 OR

[] 1A SG BYPASS FLOW FK-479

[] 1B SG BYPASS FLOW FK-489

[] 1C SG BYPASS FLOW FK-499 BOP c Check no reactor protection system automatic actions required or set points being approached.

BOP d IF a ramp is in progress, THEN place Turbine on HOLD BOP e Verify adequate SGFP function restored.

BOP f Maintain SG narrow range level approximately 65%.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 6 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP g Check SGFP speed control instrumentation - NORMAL

[] PI-464A

[] PI-508

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 7 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP h Adjust speed back to within the normal operating range for the feed flow/steam flow DP for the existing power level.

Approximate DP can be determined from the following MCB indications.

[] SGFP DISCH PRESS PI4003

[]SG Pressure indications BOP i Check Hotwell level maintained 30 to 24 by HOTWELL LEVEL controller (CP-4055F) in Auto.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 8 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP 4 Check main feed regulating valve(s) automatic control inadequate.

a Take manual control of the affected main feedwater regulating valves or bypass valves as necessary to control SG level.

[] 1A SG FW FLOW FK-478

[] 1B SG FW FLOW FK-488

[] 1C SG FW FLOW FK-498 OR

[] 1A SG BYPASS FLOW FK-479

[] 1B SG BYPASS FLOW FK-489

[] 1C SG BYPASS FLOW FK-499 BOP b Maintain SG narrow range level approximately 65%.

BOP c Check main feedwater regulating valve control instrumentation -

NORMAL

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 9 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP 5 RNO - Go to step 6 Check Feedwater Heaters operation adversely affected.

BOP 6 RNO - Go to step 7 Check SGFP suction pressure -

ABNORMAL.

BOP 7 Verify plant conditions stable a

Verify Reactor power within limits

- DT < 100% value (Computer points TC0429, TC0449, & TC0469)

- Thermal Power < 2775 MWt (Computer point QC4621M6)

- NIs less than 100%

BOP b Stabilize TAVG by adjusting rod position and/or boron concentration.

- Manual Rod Control

- Manual boration per FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM.

- Emergency boration per FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM Figure 6.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 10 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP c Verify automatic operation of the feedwater regulating valves.

[] 1A SG FW FLOW FK 478

[] 1B SG FW FLOW FK 488

[]1C SG FW FLOW FK 498 d

Verify SG narrow range levels maintained approximately 65%.

e Monitor feedwater flow and steam flow.

f Verify that feedwater and steam flow trend to approximately equal values for the target, turbine load.

BOP g Check LOSS OF LOAD INTERLOCK C-7A on the BYP & PERMISSIVES panel NOT illuminated.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 11 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP h Check reactor power change < 15%

i Check parameters within limits for continued at power operation.

- Pressurizer level greater than 15%

- Pressurizer pressure greater than 2100 psig

- SG narrow range levels 35%-75%

- TAVG 541F - 580F

- Control rod bank position Lo-Lo Annunciator FE2 Clear

- Delta I within limits specified in the COLR BOP j Check condensate and feedwater function stabilized.

BOP k Check Hotwell level maintained 30 to 24 by HOTWELL LEVEL controller (CP-4055F) in Auto.

BOP l Refer to FNP-1-SOP-21.0 and perform any local actions required to secure any tripped SGFP and its auxiliary systems.

BOP m Adjust reactor power and turbine load to maintain as necessary to maintain REACTOR THERMAL POWER 1 HOUR AVG (Computer point QC4621HR8)< 2775 MWt.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 12 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP n Check reactor power remained below 100%.

BOP o Go to procedure and step in effect SRO Notifies Shift Manager.

SRO Once stabilized, directs any controller in MANUAL back to AUTO if no malfunction existed.

At discretion of Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 1 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Indications Available

- MH1, FIRE - MSVR - RCS pressure lowering

- Rx power rising - Feed system demand increasing (FRV / SGFP Speed)

Time Position Applicants Actions or Behavior Comments AOP-14, SECONDARY SYSTEM LEAKAGE, ver 11 1 SRO should go to Step 2 IF leakage is such that significant hazard and not trip here to personnel or equipment exists OR leakage rate is unstable and is worsening, THEN:

1.1 Trip the reactor.

1.2 WHEN reactor trip is verified, THEN close MSIVs and bypass valves.

1.3 Go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 2 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 2 SRO should go to Step 3

[CA] Monitor plant status for safe and not trip here operation.

• Pressurizer level GREATER THAN 15%

AND

• Pressurizer pressure GREATER THAN 2000 psig AND

• Steam generator pressure GREATER THAN 650 psig AND

• Containment pressure LESS THAN 2 psig AND

• IF main generator on line, THEN (check reactor power) - (turbine power + any steam dump power) mismatch LESS THAN 10%.

AND

• IF main generator off line, THEN check reactor power less than ~ 15%.

AND

• Leakage is small in magnitude such that no significant hazard to personnel or equipment exists.

AND

• Leakage rate is relatively stable and is not rapidly worsening.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 3 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 3

Identify SECONDARY leakage source. 3 2

3.1 Check SG atmospheric relief valves CLOSED.

3.2 Contact TB SO to look at Check Main Steam Safety valves - MSVR roof CLOSED.

3.3 Check no abnormal steam leakage in Main Steam Valve Room.

3.3.1 Check Main Steam Valve Room by observing external grating prior to entry.

3.3.2 IF accessible, THEN check Main Steam Valve Room.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 4 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 3.3 (RNO)

Perform the following.

a) Isolate affected components consistent with plant operating requirements.

b) IF steam leakage cannot be isolated AND the plant is in Mode 3, THEN verify the reactor is tripped.

2.3.2 c) IF steam leakage cannot be isolated AND the steam leakage has resulted in a reactor power increase of > 1%, THEN verify the reactor tripped.

d) IF reactor tripped, THEN CLOSE SG Critical Task - If not main steam isolation and bypass valves. manually closed, the MSIVs will not close on low steam line pressure.

e) This step is N/A IF SG main steam isolation and bypass valves did not close, THEN place associated test switch to TEST position.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 5 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments f) IF reactor trip required, THEN go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 6 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 3.2 (RNO) This step will not be

[CA] Try to restore power to performed based on deenergized 4160 V ESF bus using FNP- scenario conditions 1-AOP-5.0, LOSS OF A OR B TRAIN ELECTRICAL POWER, as time permits while continuing with this available lights lit procedure.

3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 7 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments RO/BOP 4.1 (RNO)

Check SI required 4.1.1 (RNO)

IF any setpoint and coincidence shown in the coincidence shown in the reached or exceeded, THEN SI is required.

RO/BOP 4.1.2 (RNO)

IF SI is required, THEN actuate SI.

4.1.3 (RNO)

IF SI NOT required, THEN go to FNP-1-ESP-0.1, REACTOR TRIP RESPONSE.

RO/BOP 4.2 Verify both trains of SI- ACTUATED

[] MLB1 1-1 AND MLB1 11-1 lit

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 8 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments RO/BOP 5 See page 10 below Verify actuation signal automatic actions using ATTACHMENT 2, AUTOMATIC ACTIONS VERIFICATION.

RO/BOP 6

[CA] Check containment pressure - HAS REMAINED LESS THAN 27 psig.

CTMT PRESS

[] PR 950 RO/BOP 7 Announce "Unit 1 reactor trip and safety injection."

RO/BOP 8 Check AFW status.

8.1 Check secondary heat sink available.

[] Total feed flow to SGs - pumps started.

GREATER THAN 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B TDAFWP STM SUPP

[] FI 3229C FROM 1B(1C) SG AFW TOTAL FLOW

[] FI 3229

[] Narrow range level in at TDAFWP least one SG - GREATER THAN SPEED CONT 31%{48%}

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 9 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments RO/BOP 8.1 (RNO) Attempts to start the Perform the following. TDAFWP pump.

Dispatches personnel to 8.1.1 Verify all available AFW pumps investigate the TDAFWP started. and 1A MDAFW pump.

May call and ask how long MDAFWP the 1B MDAFW pump will

[] 1A amps > 0 be OOS (12 hrs)

[] 1B amps > 0 TDAFWP STM SUPP

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWPSPEED CONT

[] SIC 3405 adjusted to 100%

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 10 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments SRO 8.1.2 (RNO) EXITS EEP-0.0 and Goes Verify total AFW flow to FRP-H.1 greater than 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B

[] FI 3229C AFW TOTAL FLOW

[] FI 3229 8.1.3 IF total AFW flow less than 395 gpm, AND all SG narrow range levels less than or equal to 31%(48%),

THEN go to FNP-1-FRP-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK.

EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 2, ver 45 1

Verify one CHG PUMP in each train -

BOP STARTED.

[] A train (1A or 1B) amps > 0

[] B train (1C or 1B) amps > 0 BOP 2 Verify RHR PUMPs - STARTED.

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 11 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 3 Verify Safety Injection Flow.

3.1 Check HHSI flow - GREATER THAN 0 gpm.

[] FI 943 BOP 3.2 Operator should proceed to Check RCS pressure - LESS THAN step 4 275 psig{435 psig}.

BOP 4 Verify each SW train - HAS TWO SW PUMPs STARTED.

[] A train (1A,1B or 1C)

[] B train (1D,1E or 1C)

BOP 5 Verify each train of CCW - STARTED.

5.1 Verify one CCW PUMP in each train-STARTED.

A train HX 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 12 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 6 Verify containment ventilation isolation.

6.1 Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 6.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 6.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 13 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 7 Verify containment fan cooler alignment.

7.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[] 1A

[] 1B B train

[] 1C

[] 1D 7.2 Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 14 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 8 Verify AFW Pumps - STARTED.

8.1 Verify both MDAFW Pumps - STARTED

[] 1A MDAFW Pump amps > 0

[] 1B MDAFW Pump amps > 0 AND

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 15 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 8.1 (RNO)

Verify MDAFW Pumps deliver flow to each SG.

8.1.1 Manually start MDAFW Pumps 8.1.2 Verify AFW flow path to AND each SG.

[] Q1N23HV3227A in MOD

[] Q1N23HV3227B in MOD

[] Q1N23HV3227C in MOD MDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3227AA open

[] HIC 3227BA open

[] HIC 3227CA open AFW TO 1A(1B,1C) SG STOP VLV

[] Q1N23MOV3350A open

[] Q1N23MOV3350B open

[] Q1N23MOV3350C open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764A open

[] Q1N23MOV3764D open

[] Q1N23MOV3764F open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764E open

[] Q1N23MOV3764B open

[] Q1N23MOV3764C open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 16 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 8.2 Check TDAFW Pump start required. TDAFWP pump will not start. May go directly to step 9

8.3 Verify TDAFWP started.

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

8.4 Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 17 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 9 Verify main feedwater status.

Verify main feedwater flow control and bypass valves - CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[] FCV 488

[] FCV 498 9.2 Verify both SGFPs - TRIPPED.

9.3 Verify SG blowdown - ISOLATED.

1A(1B,1C) SGBD ISO

[] Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample - ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 18 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 10 Check no MSL isolation actuation signal present.

10 (RNO)

Perform the following.

10.1 Verify main steam line isolation and bypass valves closed.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYP

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 19 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 11 Verify PHASE A CTMT ISO.

BOP 11.1 Verify PHASE A CTMT ISO - ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO BOP 12 Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP 13 Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11E005A

[] N1C11E005B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 20 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 14 Secure secondary components.

14.1 Stop both heater drain pumps.

HDP

[] 1A

[] 1B 14.2 Check any condensate pump started.

14.2.1 IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 14.3 IF condensate pump operating, Will call TBSO to THEN verify backup cooling aligned to accomplish this.

condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP 15 Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN BOP 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810 - OPEN

[] 914 - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 21 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 17 Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 22 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 4, ver 45 1

Verify two trains of ECCS equipment aligned.

1.1 - 1.4

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 closed 1.5

[] Verify two trains of battery chargers -

energized

[] A Train (1A or 1C) amps > 0

[] B Train (1B or 1C) amps > 0 1.6 Verify two trains of ESF equipment aligned.

1.6.1 Check all MLB-1 lights LIT 1.6.2 Verify charging pump suction and discharge valves - OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 23 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B 1.8 WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP 1.9 Call Radside SO Verify SFP Cooling in service per SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of Attachment 4

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 1 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Indications Available

- AFW flow < 395 GPM - SG NR level - 2 SG < 31%

Time Position Applicants Actions or Behavior Comments FRP-H.1, Response to Loss of Secondary Heat Sink, ver 27 SRO 1 Check secondary heat sink -REQUIRED.

1.1 - 1.2 o Check RCS pressure > any non-faulted SG pressure on PT-402/403 o Check RCS hot leg temperatures >

350°F on TR 413 SRO 2 Directs monitoring of bleed and feed criteria 2.1 - 2.2

- Check at least two SG wide range levels GREATER THAN 12%.

- Check pressurizer pressure < 2235 psig SRO 3 NOTE: Calls I&C Direct I&C to defeat feedwater isolation signal by installing jumpers per ATTACHMENT 1.

BOP 4 Check CST level > 5.3 feet and call for makeup to CST as required

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 2 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments BOP 5 NOTE: continuing action Try to establish AFW flow to at least one step SG.

5.1 Verifies blowdown isolated from all SGs 5.2 Verifies SG blowdown sample valves isolated 5.3 Recognizes AFW pumps not available MAY DIRECT RNO action 5.3 (RNO) to start 1A MDAFWP/

PERFORM local start from Hot shutdown TDAWFP from HSDP.

panels.

BOP 5.4 Verify at least one flow path to at least one SG ALIGNED Checks OPEN MDAFP to 1A/B/C SG (where X = respective SG A, B or C)

- HV3227X MDAFW TO SG MOD

- HIC3227XA MDAFW FCVsadjusted

- HV3228X TDAFW to SG MOD

- HIC3228XA TDAFW FCVs adjusted

- MOV-3350X SG AFW STOP vlvOPEN

- MOV3764X MDAFW to SG ISOOPEN 5.5

[CA] Check total AFW flow to SGs greater than 395 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 3 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments SRO 5.5 (RNO) 5.5.1 WHEN any feed flow established AND at least one SG narrow range level greater than 31%{48%} THEN go to procedure and step in effect 5.5.2 Continue efforts to establish AFW flow. WHEN FLOW established AND level >31% THEN exit.

5.5.3 Pproceed to step 6 RO 6 Stops all RCPs SRO 7 With MSIVs closed, may go Try to establish main feedwater flow to to step 9 here intact SGs with one SGFP.

BOP 7.1 Verify at least one CNDS PUMP started NOTE: will call TB SO to 7.1.1 verify Verify Back up cooling is aligned to the condensate pumps BOP 7.2 Check intact SGs MSIVs open

- HV 3369A and B and C

- HV 3370A and B and C SRO 7.2 IF no intact SGs main steam line isolation valves open, THEN proceed to Step 9.

OBSERVE CAUTION PRIOR TO STEP 9.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 4 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments RO 9

[CA] Try to establish condensate flow to intact SGs.

9.1 IF SI has not actuated since Rx trip then reset FWI 9.1 (RNO)

Verify SI RESET

[] MLB-1 1-1 not lit

[] MLB-1 11-1 not lit SRO 9.2 Call SSS Check feedwater isolation signal to intact SGs main feedwater regulating bypass valves defeated per ATTACHMENT 1.

BOP 9.3 Verify all main feedwater flow control and bypass valves - CLOSED IN MANUAL FK-478, 488, 498 FK-479, 489, 499 BOP 9.4 Contact TBSO Verify backup cooling to condensate pumps per FNP-1-SOP-21.0 BOP 9.5 Locally open SGFP BYP N1N21V509.

(155 ft, TURB BLDG)

SRO 9.6 Locally isolate SGFP miniflow valves. (155 ft, TURB BLDG) SGFP 1A(1B) RECIRC FCV INLET ISO

[] N1N21V502A closed

[] N1N21V502B closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 5 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments SRO 9.7 Contact SSS Perform the following.

9.7.1 Dispatch personnel to 1V 600 V MCC. (139 ft, AUX BLDG electrical penetration room)

BOP 9.7.2 Place Handswitch for main feedwater stop valves to intact SGs to OPEN and hold in that position.

BOP 9.7.3 Coordinates with RAD 1 SO WHEN main feedwater stop valves to - (Booth) intact SGs open, THEN direct personnel to open associated breakers. (139 ft, AUX BLDG electrical penetration room).

BOP 9.7.4 WHEN associated breaker open, THEN allow main feedwater stop valve handswitch to spring return.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 6 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments RO 9.8 Reduce PRZR pressure to less than 1950 psig.

9.8.1 This step is N/A Check either condition for using auxiliary spray satisfied.

[] Normal letdown in available, service.

OR

[] No PRZR PORV available.

RO 9.8.1 (RNO)

Perform the following.

[] If normal letdown secured and a PRZR PORV available, THEN open only one PRZR PORV to reduce PRZR pressure to less than 1950 psig.

AND

[] Proceed to step 9.9 RO 9.9 9.9 Maintain PRZR pressure at 1900-1950 psig.

9.9.1 (RNO)

IF using a PRZR PORV, THEN open only one PRZR PORV to control PRZR pressure.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 7 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments RO 9.10 WHEN pressurizer pressure less than 2000 psig, THEN perform the following.

9.10.1 Block low pressurizer pressure SI.

PRZR PRESS SI BLOCK - RESET

[] A TRN to BLOCK

[] B TRN to BLOCK 9.10.2 Verify blocked indication.

BYP & PERMISSIVE PRZR. SAFETY INJECTION

[] TRAIN A BLOCKED light lit

[] TRAIN B BLOCKED light lit RO 9.11 WHEN P-12 light lit (543F), THEN perform the following.

9.11.1 Block low steam line pressure SI.

STM LINE PRESS SI BLOCK - RESET

[] A TRN to BLOCK

[] B TRN to BLOCK 9.11.2 Verify blocked indication.

BYP & PERMISSIVE STM LINE ISOL.

SAFETY INJ.

[] TRAIN A BLOCKED light lit

[] TRAIN B BLOCKED light lit

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 8 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments BOP 9.11.3 Bypass the steam dump interlock.

STM DUMP INTERLOCK

[] A TRN to BYP INTLK

[] B TRN to BYP INTLK BOP 9.12 (RNO)

Dump steam to atmosphere.

9.12.1 Direct counting room to perform FNP Contacts Counting room CCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.

9.12.2 IF normal air available, THEN control atmospheric relief valves to dump steam from at least one intact SG at maximum attainable rate. []

1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A adjusted

[] PK 464 adjusted [] PC 3371B adjusted

[] PC 3371C adjusted BOP 9.13 WHEN SG(s) pressure reduced to less than 540 psig, THEN stop pressure reduction.

9.14 Maintain SG(s) pressure -

STABLE AT EXISTING VALUE.

9.15 Verify at least one CNDS PUMP

- STARTED.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 9 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments BOP 9.16 Check SGFP BYP N1N21V509 - OPEN.

(155 ft, TURB BLDG)

BOP 9.17 Critical Task - Restore Initially open feedwater regulating bypass feed flow using a valves just off the closed seat to initiate Condensate pump.

flow and minimize any water hammer.

9.1.8 Control feedwater regulating bypass valves to supply main feedwater to at least on intact SG RO/BOP 10.1 Verify feed flow to at least one SG

- Rising SGWL OR

- CETC - FALLING BOP 10.2 Check at least one SG NR level -

GREATER than 31%

BOP 10.2 (RNO)

Continue feeding at least one SG to restore SG NR to > 31%

SRO 10.3 Go to procedure and step in effect.

Terminate exam

Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #6 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 7/22/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 6 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1, Section 4.1 through Step 23 is complete, Ramp on hold while investigating Feed water Dissolved Oxygen, 1A MDAFWP tagged out.

Turnover:

• 95% power, Impulse Loop NOT in service, MOL, Cb 977 ppm.

• UOP-3.1, Section 4.1 through Step 23 is complete. Ramp to 100%.

• Ramp on hold while investigating Feed water Dissolved Oxygen

• A Train On Service, B Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1A MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

• TS 3.5.1 Cond B (Unplanned) entered 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ago due to low 1A Accumulator pressure. Leak repaired.

Raise 1A Accumulator pressure.

Event Malf. No. Event Type* Event No. Description 1 preset N (BOP) Raise 1A Accumulator pressure.

2 cmfmalf/ C (BOP) 1B Service Water pump trips.

cNCPSW1B_d_

TS (SRO) TS-3.7.8 Cond A, 3.8.1 Cond B co2 3 ann/ N (RO) Fill 1C RCP standpipe.

da3 4 xmt/ I (BOP) PT3371B fails high.

pt3371B TS (SRO) TS-3.3.4 Cond A 5 malf/ C (RO) RCS to Letdown leak.

MAL-CCW4 6 cnh/ I (RO) PK-444A, PRZR PRESS REFERENCE, fails high.

pk444a-a 7 malf/ M (ALL) Loss of Offsite Power.

MAL-EPS1 preset 1B DG fails to auto start.

malf/d/ 1-2A DG trips on Low oil pressure 5 minutes after MAL-DSG006 reaching 500 rpm - Loss of all AC.

preset C (BOP) TDAFW pump fails to start. Will start manually.(CT-23) preset C (RO) 2C DG fails to start.

Terminate when power restored using 1B DG (CT-24)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario 6 Presets Form ES-D-1 EVENT # TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-225 (Base IC-60) 1A Accumulator pressure lowered to 598 psig.

Impulse loop not in service rst 225 0 0 Generis setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc6.txt 0 Freeze Xe set crxefast=0 0 0 RUN PRESETS setup Tag out 1A MDAFW pump

• irf cAFP01A_d_cd1 open setup SIM IC will have the 1A Accumulator pressure lowered 7 1B DG Auto start block

• imf MAL-DSG017 7 Prevent TDAFWP auto start

• imf cMS3235B-cc1 open imf cms3235b_cc2 open imf cms3235a_cc1 open imf cms3235a_cc2 open 7 2C DG Push Button fails to start the DG

• irf LOA-EPB005 false 7 1-2A DG trips on low oil pressure *TRG 1 imf MAL-DSG006 (1 300)

Triggers and Commands 1 Monitor 1-2A DG speed *TRG 1 trgset 1 X42D016M > 0.5

MCB setup OVATION Clear OVATION alarms OVATION Verify the Impulse Loop is NOT in service Place danger TAG ON 1A MDAFW Pump HS on MCB Place tag on 1A MDAFWP HS Unit 1 Train A Bypass & Inoperable Status Ind Panel on AFW Switch in ON EPB - AFW SYSTEM Switch in "ON Provide a marked up copy of UOP-3.1 UOP-3.1 Section 4.1 - through step 23 Provide a marked up copy of ARP CD1 (provided) Marked up copy of ARP CD1 Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Unfreeze Xe set crxefast=1 Perform Booth Operators Setup Checklist

MCB setup Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 Start of Raise 1A Accumulator pressure.

exam 2 NRC 1B Service Water pump trips.

CUE TS-3.7.8 Cond A, 3.8.1 Cond B imf cNCPSW1B_d_co2 3 NRC DA3, 1C RCP STANDPIPE LO. Fill 1C RCP standpipe.

CUE imf jcvl408l-o 1 NOTE: Clear alarm 1 minute after filling begins.

dmf jcvl408l-o 4 NRC PT3371B fails high.

CUE TS-3.3.4 Cond A xmt pt3371B 1200 15 5 NRC RCS to Letdown leak.

CUE imf MAL-CCW4 10 60 6 NRC PK-444A, PRZR PRESS REFERENCE, fails high.

CUE imf pk444a-a 0 15

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC Loss of Offsite Power.

CUE imf MAL-EPS1 1 0 preset 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 5 minutes after it TRG 1 reaches 500 RPM - Loss of all AC.

preset TDAFW pump fails to start. Will start manually.(CT-23)

NRC END OF EXAM:

CUE Terminate when power restored on the 1B DG Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen6grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 IF REQUESTED Place RCDT on recirc 3 minutes after requested.

irf loa-wps002 start 6 NONE REQUIRED 7 IF REQUESTED

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the inform supervision) cue and that type of communications 1 IF REQUESTED RAD 1 SO: 3 minutes after requested - N1E21HV3938A and B are open.

OUTSIDE SO: N2 banks are at 1800 psig.

RAD 1 SO: 3 minutes after requested - N1E21HV3938A and B are closed 2 IF REQUESTED OUTSIDE SO: 3 minutes after requested - DK-03 has an overcurrent trip flag.

OUTSIDE SO: 3 minutes after requested - 1B SW pump is not running. No obvious problems noted.

OUTSIDE SO: 3 minutes after requested - 1C SW pump breaker check is SAT.

SSS/OUTSIDE SO: Will brief then rack out 1B SW pump breaker 3 NO ADDITIONAL EXPECTED 4 CUE If the crew fails to see the steam leak, 5 minutes after failing PT-3371B then provide the following:

DB SO: I was walking toward the ready room and saw steam issuing from the top of the MSVR.

IF REQUESTED TBSO: 3 minutes after requested and PC3371B still open:

There is steam coming from the roof of the MSVR IF REQUESTED TBSO: 3 minutes after requested and PC3371B closed: There is no steam coming from the roof of the MSVR CUE: ROVER: 3 minutes after PCV-3371B is discovered by the crew: I was walking by HSDP Alpha and noticed 1B SG pressure PI3371B pegged high.

SM/OPS Dir: Continue plant operation with PC-3371B in its current status.

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

5 IF REQUESTED HP: We will post the CCW Surge tank area as required.

RAD 1 SO: 3 minutes after requested - RCDT is on Recirc.

IF REQUESTED Counting room: I will sample SGs for radioactivity using FNP CCP-31, LEAK RATE DETERMINATION.

6 NO ADDITIONAL EXPECTED 7 IF REQUESTED DB SO: 3 minutes after requested 2A DG tripped on low oil pressure.

DB SO: 3 minutes after requested - There were no problems found on inspection of 1B DG. The only alarm is Service Water Low Flow (Window 22).

U2 (Booth operator coming out to floor): U2 has adequate Alpha train service water.

DB SO: 3 minutes after Mode 4 start requested: There are no obvious problems with the (DG selected) but the Mode Selector switch is stuck and cannot be placed in Mode 4.

DB SO: 3 minutes after requested: 1B DG lube oil alarm is clear.

Appendix D Scenario 6 Detailed Summary Form ES-D-1 Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1, Section 4.1 through Step 23 is complete, Ramp on hold while investigating Feed water Dissolved Oxygen, 1A MDAFWP tagged out.

Turnover:

• 95% power, Impulse Loop NOT in service, MOL, Cb 977 ppm.

• UOP-3.1, Section 4.1 through Step 23 is complete. Ramp to 100%.

• Ramp on hold while investigating Feed water Dissolved Oxygen

• A Train On Service, B Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1A MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

• TS 3.5.1 Cond B (Unplanned) entered 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ago due to low 1A Accumulator pressure. Leak repaired.

Raise 1A Accumulator pressure.

EVENT 1: Raise 1A Accumulator pressure.

Verifiable actions: BOP will operate valves to raise 1A Accumulator pressure.

EVENT 2: 1B Service Water pump trips.

Verifiable actions: BOP starts the 1C SW pump. SRO - Tech Spec: 3.7.8 Cond A, 3.8.1 Cond B until the 1C SW pump is aligned to auto start for the 1B SW pump.

EVENT 3: DA3, 1C RCP STANDPIPE LVL LO alarm.

Verifiable actions: RO will operate valves to fill the standpipe.

EVENT 4: PT-3371B fails high.

Verifiable actions: BOP takes manual control of PC-3371B, 1B MS ATMOS REL VLV and closes it. SRO - Tech Spec: TS-3.3.4 Cond A EVENT 5: RCS to Letdown leak.

Verifiable actions: RO may take manual control of Charging to determine leak rate. Once identified, the RO isolates letdown.

EVENT 6: PK-444A, PRZR PRESS REFERENCE, fails high.

Verifiable actions: RO takes manual control of PK-444A or manual control of Pressurizer heaters and spray to lower RCS pressure.

Similar to Audit - PK-444A fails LOW on the Audit opening spray valves and PCV-444B, PRZR PORV. RO must close the sprays and PORV as well as energize heaters to raise pressure.

EVENT 7: Loss of Offsite Power: 1B DG fails to auto start and 1-2A will trip on low oil pressure 5 minutes after it reaches 500 RPM requiring entry into ECP-0.0, Loss of ALL AC. TDAFW pump fails to start automatically and 2C DG wont start at the EPB Verifiable actions: BOP Starts TDAWF pump. (CT-23). RO starts 1B DG to restore power. (CT-24)

Similar to Audit - Audit exam has 2C DG starting (1st DG tried) and Service Water pumps have to be started. The TDAFW pump will also auto start on the Audit exam.

Appendix D Scenario 6 Critical Tasks Form ES-D-1

_____ 1. Establish the minimum required AFW flow rate to the SGs before SG dryout occurs. (CT-23)

_____ 2. Energize at least one ac emergency bus [before placing safeguards equipment handswitches in the pull-to-lock position. (CT-24)

SCENARIO At power instrument and component failures with a Loss of All AC.

OBJECTIVE/

• raise 1A Accumulator pressure OVERVIEW:

• respond to trip of 1B SW pump

• refill 1C RCP standpipe

• respond to a failed transmitter that causes a SG Atmospheric valve to open

• isolate letdown in response to an RCS to Letdown HX leak

• respond to a PK-444A, PRZR PRESS REFERENCE failing high

• restore power in response to a loss of All AC.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 2

2. Abnormal events (2-4) 4

3. Major transients (1-2) 1

4. EOPs entered/requiring substantive actions (1-2) 0

5. EOP contingencies requiring substantive actions (0-2) 1

6. Critical tasks (2-3) 2

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 1, 95% RTP, 977 ppm Cb, MOL 10000 MWD/MTU, -2181 pcm Xe A Trn O/S / B Trn Protected / SFPC on A Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 167 hours0.00193 days <br />0.0464 hours <br />2.761243e-4 weeks <br />6.35435e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. 1A MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />

3. Leak repaired on 1A Accumulator. Raise 1A Accumulator pressure to the normal range.

4. Impulse loop is NOT in service.

5. UOP-3.1, Section 4.1 through Step 23 is complete.

6. Ramp is on hold while Chemistry investigates Feedwater Dissolved Oxygen.

7.

8.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas) 1A MDAFW pump - 3.7.5 Cond B (planned- entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago)

LCO status 1A accumulator - 3.5.1 Cond B (unplanned- #1 RHT entered12 hours ago)

Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __1___ Page 1 of 2 Event

Description:

Raise 1A Accumulator Pressure. 1A Accumulator is 605 psig and will be raised to 625 psig per SOP-8.0, Safety Injection System.

Indications Available

• 1A Accumulator pressure indicates ~600 psig

• ANN CD1 - 1A ACCUM PRESS HI-LO in alarm Time Position Applicants Actions or Behavior Comments ANN CD1 - 1A ACCUM PRESS HI-LO BOP 4.2.a) 2)

Restore 1A Accumulator pressure to normal.

SOP-8.0, SAFETY INJECTION SYSTEM - ACCUMULATORS v 42.0 BOP 4.5.1 SO reports 1800 psig IF increasing accumulator nitrogen pressure after establishing nitrogen atmosphere per Section 4.4, THEN ensure the high pressure nitrogen banks are greater than 1000 psig.

BOP 4.5.2.1 This has been Ensure nitrogen atmosphere has been established during established in 1A accumulator. plant startup BOP 4.5.2.2 Verify ACCUM N2 VENT HIK936(Q1E21V092) closed.

BOP 4.5.2.3 Contacts RAD SO to Open OR check open the following valves on open these valves the PRIP:

ACCUM N2 SUPPLY ISOLATION, N1E21HV3938A.

ACCUM N2 SUPPLY ISOLATION, N1E21HV3938B.

BOP 4.5.2.4 Opens the valve Open OR check open ACCUM N2 SUPP ISO Q1E21HV8880, (Q1E21V059).

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __1___ Page 2 of 2 Event

Description:

Raise 1A Accumulator Pressure. 1A Accumulator is 605 psig and will be raised to 625 psig per SOP-8.0, Safety Injection System.

Time Position Applicants Actions or Behavior Comments BOP 4.5.2.5 Open 1A ACCUM N2 SUPP/VT ISO Q1E21HV8875A.

BOP 4.5.2.6 Monitor accumulator pressure AND verify the pressure in accumulator 1A is the only accumulator which shows an increase in pressure.

BOP 4.5.2.7 WHEN pressure increases to approximately 625 psig, THEN close 1A ACCUM N2 SUPP/VT ISO, Q1E21HV8875A.(Q1E21V047A).

BOP 4.5.2.8 This step is N/A IF pressure is to be increased in another accumulator immediately, THEN proceed to Section 4.5.3 or 4.5.4.

BOP 4.5.2.9 Contacts RAD SO to Close the following valves on the PRIP: close these valves ACCUM N2 SUPPLY ISOLATION, N1E21HV3938A.

ACCUM N2 SUPPLY ISOLATION, N1E21HV3938B.

BOP 4.5.2.10 Close ACCUM N2 SUPP ISO Q1E21HV8880 (Q1E21V059).

At the discretion of the Lead Examiner move to next event .

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 1 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

Indications Available

• SW PUMP TRIPPED (AE4)

• PI-3001A SW TO CCW HX PRESS, reading low

• Recognize indications 1E SW PUMP TRIP

- Yellow flag above 1E SW pump handswitch Time Position Applicants Actions or Behavior Comments BOP Announce alarm and enter ARP-AE4 SRO Direct entry into ARP ARP-1.1 AE4, SW PUMP TRIPPED, ver 55.1 BOP 1 Check Indications and determine which SW pump tripped BOP 2 Start the 1C SW pump SRO 3 if entered actions listed REFER to AOP-10, version 17. below (pg 2)

SRO 4 Direct SSS entry into SOP-24.0 step 4.6 to align 1C SW pump for auto start to replace the 1E SW pump BOP 5 Sends SSS and/or Outside Dispatch personnel to the 1B SW pump SO and breaker DL04, 1B SW PUMP 4160V BREAKER

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 2 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

Time Position Applicants Actions or Behavior Comments SRO 6 Has RO/BOP call and have Return the Service Water electrical and CR initiated.

component lineup to normal as soon as possible.

SRO 7 Refer to Technical Specification 3.7.8 for LCO requirements with a loss of train A or B service water.

AOP-10.0, LOSS OF SERVICE WATER, v 17 BOP 1 Checks affected SW 4160V supply breakers closed.

[] BKR DF02 CLOSED

[] BKR DG02 CLOSED BOP 2 1C SW pump already IF SW PUMP tripped. started THEN start any available SW pump in the affected train SRO 3 Check pressure in both SW trains >60 psig, then go to procedure and step in affect.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 3 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

Time Position Applicants Actions or Behavior Comments TECHNICAL SPECIFICATION 3.7.8 - Service Water System (SWS)

Two SWS trains shall be OPERABLE.

SRO 3.7.8 Condition A applies due to the 1B SW pump being tripped and the 1C SW pump not being selected to auto start for the 1E SW pump CONDITION REQUIRED COMPLETION ACTION TIME A. One SWS A.1 -NOTES----- 72 hrs train inoperable. 1. Enter applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources Operating," for emergency DG made inoperable by SWS.

Restore SWS train to OPERABLE status.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 4 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

TECHNICAL SPECIFICATION 3.8.1 - 3 AC SourcesOperating SRO From 3.7.8 Condition A above, 3.8.1 has to be entered. Condition B applies.

SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One DG set B.1 Perform SR 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> The bolded conditions are the most likely inoperable 3.8.1.1 for the AND path the SRO will evoke.

required offsite Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> B.1 and B.2 and B.3.1 circuit(s). Thereafter AND B.2 Declare 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from required discovery of feature(s) Condition B supported by concurrent with the inoperable inoperability of DG set redundant required inoperable feature(s) when its required redundant feature(s) is inoperable AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> B.3.1 Determine OPERABLE DG set is not inoperable due to common cause failure.

OR 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> B.3.2 Perform SR 3.8.1.6 for OPERABLE DG set.

AND 10 days B.4 Restore DG AND 13 days from set to discovery of failure OPERABLE to meet LCO status

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 5 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

Time Position Applicants Actions or Behavior Comments SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report SRO Inform the SM of the failure and Tech Spec entry After Tech Spec analysis and at the discretion of the Lead Examiner move to next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __3___ Page 1 of 1 Event

Description:

Fill 1C RCP standpipe. Upon receipt of DA3, the RO will fill the 1C RCP Standpipe.

Indications Available

• DA3, 1C RCP STANDPIPE LVL LO Time Position Applicants Actions or Behavior Comments BOP Announce alarm and enter ARP-AE4 SRO Direct entry into ARP ARP-1.4, DA3, 1C RCP STANDPIPE LVL LO, ver 54.2 RO 1 Open RMW TO PRT ISO Q1B13HV8028 RO 2 Open 1C RCP STANDPIPE FILL ISO N1E21HV8168C RO 3 Alarm will clear 1 minute Fill standpipe until the alarm clears after filling begins RO 4 Close 1C RCP STANDPIPE FILL ISO N1E21HV8168C RO 5 Close RMW TO PRT ISO Q1B13HV8028.

At discretion of the lead examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __4___ Page 1 of 3 Event

Description:

PT-3371B fails HIGH causing PC-3371B, 1B MS ATMOS REL VLV to fully open.

This will cause a rise in Rx power and lower Tavg. If the crew does not recognize the event in 5 minutes then the Diesel Building SO will call into the MCR and report steam from the top of the MSVR Indications Available

• PC-3371B fully open

• Rx power rise

• Tavg lowers

• RCS pressure will lower Time Position Applicants Actions or Behavior Comments NOTE: The SRO may direct the BOP to close PC-3371B without the use of AOP-14, SECONDARY SYSTEM LEAKAGE.

AOP-14, SECONDARY SYSTEM LEAKAGE, ver 11 SRO 1 SRO should not direct the Checks IF leakage is such that significant Rx tripped at this time hazard to personnel or equipment exists OR leakage rate is unstable and is worsening, THEN:

2 SRO should not direct the RO

• Pressurizer level > 15% Rx tripped at this time AND

• Pressurizer pressure > 2000 psig AND BOP

• Steam generator pressure >650 psig AND

• Containment pressure < 2 psig RO AND

• IF main generator off line, THEN check reactor power less than ~ 15%.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __4___ Page 2 of 3 Event

Description:

PT-3371B fails HIGH causing PC-3371B, 1B MS ATMOS REL VLV to fully open.

This will cause a rise in Rx power and lower Tavg. If the crew does not recognize the event in 5 minutes then the Diesel Building SO will call into the MCR and report steam from the top of the MSVR Time Position Applicants Actions or Behavior Comments NOTE:

- Steps 3.1 through 3.10 are intended to locate and isolate the leak if possible and stabilize the plant.

- Applicable steps to isolate leakage sources may be performed whenever a leakage source is identified and further identification actions may be terminated when all sources have been identified.

- Based on judgment plant shutdown may be commenced by proceeding to step 9. Steps 3 through 8 should then be performed concurrently with plant shutdown.

- FNP-0-SOP-0.0 contains documentation and reporting requirements for SG safety valves which have lifted.

BOP 3.1 Check SG atmospheric relief valves CLOSED.

BOP 3.1.1.a) RNO PC-3371B Closed in IF SG pressure less than 1035 psig, manual THEN close affected atmospheric relief valve(s) using one of the following (presented in suggested order but any option may be used).

PC-3371B adjusted closed BOP 3.1.2 (RNO) This step is N/A IF PRIMARY TO SECONDARY LEAKAGE greater than 50 gpd exists, THEN direct Counting Room to perform FNP-0-CCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.

SRO 4 Secondary Leak is isolated

[CA] Check secondary leak NOT isolated.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __4___ Page 3 of 3 Event

Description:

PT-3371B fails HIGH causing PC-3371B, 1B MS ATMOS REL VLV to fully open.

This will cause a rise in Rx power and lower Tavg. If the crew does not recognize the event in 5 minutes then the Diesel Building SO will call into the MCR and report steam from the top of the MSVR Time Position Applicants Actions or Behavior Comments SRO 4 (RNO) 4.1 Contacts SM or Ops Consult operations manager to evaluate Director continued plant operation with isolated components.

3.1 4.2 Evaluate actions required by applicable Tech Spec below Technical Specifications.

3.2 4.3 Go to procedure and step in effect.

Tech Spec 3.3.4, Remote Shutdown System The Remote Shutdown System Functions in Table 3.3.4-1 shall be OPERABLE.

SRO 3.3.4 Condition A applies because the 1B SG pressure instrument has failed. Table 3.3.4-1 function 2 requires 1 SG pressure instr per SG CONDITION REQUIRED COMPLETION ACTION TIME A. One or more A.1 Restore 30 days required required Functions Function inoperable. to OPERABLE status.

SRO Submit a condition report on the failed component, and notify the Work Week Coordinator of the condition report SRO Inform the SM of the failure and Tech Spec entry At discretion of the lead examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 1 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Indications Available

• FH1, RMS HIGH RAD

• CCW Surge tank rising

• R-17B, CCW in alarm

• FI-122A, CHG FLOW rising

• Pressurizer level lowering Time Position Applicants Actions or Behavior Comments BOP Announce alarm and enter ARP-FH1 SRO Direct entry into ARP ARP-1.6, FH1, RMS HIGH RAD, ver 72.1 BOP 1 Check indications on radiation monitoring system console and determine which radiation monitor channel indicates high activity. R-17B BOP 2 Insure that any automatic actions, associated with the alarmed channel, have occurred. Insures RCV-3028 is closed BOP 3 Perform the following general actions as appropriate.

3.3 May contact HP and/or Do not allow personnel to enter the make an announcement affected area without the approval of the Health Physics Department.

BOP 3.5 IF high activity indication of RCS leakage is present AND accompanied by either decreasing pressurizer level, OR decreasing VCT level, THEN go to FNP AOP-1.0, RCS LEAKAGE.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 2 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments AOP-1, RCS LEAKAGE, ver 23 RO 1

[CA] Maintain pressurizer level 1 Perform the following. stable at or near programmed level.

[] Control charging flow.

OR

[] Reduce letdown flow.

OR

[] IF required to maintain PRZR level, THEN isolate letdown.

RO 2

[CA] Maintain VCT level greater than 20%.

2.1 Verify reactor makeup system -

IN AUTOMATIC.

OR 2.2 Control reactor makeup system using FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL VCT SYSTEM REACTOR MAKEUP CONTROL OUTLET ISO SYSTEM.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 3 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments RO 3 Determine RCS leak rate.

3.1 Determine RCS leak rate from CVCS flow balance.

______(charging flow)

+______(seal injection flow)

-______(letdown flow)

-______(#1 seal leakoff flow)

=______(RCS leak rate) 3.2 Initial conditions are not met IF plant conditions are stable, THEN determine RCS leak rate using FNP-1-STP-9.0, RCS LEAKAGE TEST.

SRO 4

[CA] WHEN RCS leak rate Not a Tech Spec.

determined, THEN evaluate required actions using Technical Specifications.

SRO 5 Contacts SM

[CA] WHEN RCS leak rate determined, THEN evaluate event classification and notification requirements using FNP-0-EIP-8, NON-EMERGENCY NOTIFICATIONS and NMP-EP-110, EMERGENCY CLASSIFICATION DETERMINATION AND INITIAL ACTION.

SRO 6 N/A

[CA] WHEN RCS leak rate greater than 50 gpm, THEN align 1A and 1B post LOCA containment hydrogen analyzers for service using Attachment 1.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 4 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments NOTE:

- The intent of step 7 is to provide a systematic leakage search plan. Steps 7.2 through 7.12 may be done in any order.

- IF at anytime the location of an RCS leak is discovered or reported, THEN actions to isolate the leak should be taken immediately.

- WHEN all leakage sources have been identified, THEN continue with step 8 and further leakage identification actions may be terminated.

RO 7 Identify RCS leakage source.

7.1 Frequently monitor CVCS flow balance as the actions of steps 7.2 through 7.12 are taken.

7.1.1 Determine RCS leak rate from CVCS flow balance.

______(charging flow)

+______(seal inj flow)

-______(letdown flow)

-______(#1 seal lkof flow)

=______(RCS leak rate)

Based on the note prior to step 7 and indications available, Step 7.7 is the first logical step to perform.

RO 7.7 Check CCW system.

7.7.1 Check CCW surge tank radiation -

NORMAL

[] R-17A CCW

[] R-17B CCW RO 7.7.2 Check CCW surge tank level - NO UNEXPLAINED LEVEL RISE.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 5 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments RO 7.7 (RNO)

Perform the following.

a) Secure normal letdown.

RO 7.7. (RNO) Place Excess letdown on b) service per SOP-2.7. Steps IF CCW parameters return to normal, are below PAGE 6 THEN establish excess letdown using, FNP-1-SOP-2.7, CHEMICAL AND VOLUME CONTROL SYSTEM EXCESS LETDOWN.

c) Return to step 3 RO 3 Leakrate is zero Determine RCS leak rate.

3.1 Determine RCS leak rate from CVCS flow balance.

______(charging flow)

+______(seal injection flow)

-______(letdown flow)

-______(#1 seal leakoff flow)

=______(RCS leak rate) 3.2 IF plant conditions are stable, THEN determine RCS leak rate using FNP-1-STP-9.0, RCS LEAKAGE TEST.

RO 8 Leak isolated in step 7.7

[CA] WHEN the RCS leakage source identified, THEN take appropriate actions to isolate the leak.

RO 9 Stable plant conditions must

[CA] WHEN RCS leakage source be obtained isolated, THEN determine the post isolation leak rate per FNP-1-STP-9.0, RCS LEAKAGE TEST.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 6 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments SRO 9.1 IF RCS leak rate satisfactory, THEN go to procedure in effect.

After AOP-1 Step 9 is commenced at Lead Examiners discretion, move to next event.

SOP-2.7, Chemical and Volume Control System Excess Letdown, ver 13 Section 4.1 RO 1 Directs Rad 1 SO to Verify RCDT system in operation and on recirc perform this action per FNP-1-SOP-50.0, Liquid Waste Processing System, Reactor Coolant Drain Tank (RCDT) Operation.

RO 2 Performed with Step 1 Notify Radside SO to expect an increase in RCDT level.

RO 3 Verify CCW TO EXC LTDN/RCDT HXS, Q1P17HV3095 OPEN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 7 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments RO 4 Verify CCW FROM EXC LTDN/RCDT HXS, Q1P17HV3443 OPEN.

RO 5 Verify CCW FROM EXC LTDN/RCDT HXS, Q1P17HV3067 OPEN.

RO 6 Verify EXC LTDN HX DISCH, Q1E21HCV137 CLOSED (HIK-137 at 0%).

RO 7 Open EXC LTDN ISO, Q1E21HV8153.

RO 8 Open EXC LTDN ISO, Q1E21HV8154.

RO 9 Place EXC LTDN DIVERT VLV, 1E21HV8143 to RCDT.

RO 10 Using HIK-137, slowly throttle open EXC LTDN HX DISCH, Q1E21HCV137 to establish Excess Letdown flow not to exceed 165F Excess Letdown Heat Exchanger outlet temperature as indicated on TI-139, EXC LTDN HX OUTLET TEMP.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __6__ Page 1 of 3 Event

Description:

PK-444A, PRZR PRESS REFERENCE, fails high. Causes pressure to rise until manual control taken or a PORV lifts.

Indications Available

• All Pressurizer heaters energize.

• RCS pressure rises

• Spray valves close if open

• PK-444A demand goes to 100%

Time Position Applicants Actions or Behavior Comments AOP-100, INSTRUMENTATION MALFUNCTION, ver 15 Note: Step 1 and 2 are immediate operator actions RO 1 IF required to stabilize RCS pressure, THEN take manual control of the following equipment.

11

• Power operated relief valves

[ ] PRZR PORV Q1B31PCV445A

[ ] PRZR PORV Q1B31PCV444B OR

[ ] PRZR BLOCK VLV Q1B31MOV8000A

[ ] PRZR BLOCK VLV Q1B31MOV8000B

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP RO 2 This step is N/A IF pressurizer pressure is decreasing due to a mechanically stuck open spray valve PCV444C or PCV444D, THEN perform the following:

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __6__ Page 2 of 3 Event

Description:

PK-444A, PRZR PRESS REFERENCE, fails high. Causes pressure to rise until manual control taken or a PORV lifts.

Time Position Applicants Actions or Behavior Comments RO 3 IF PORV is open and pressurizer pressure is less than 2310 psig, THEN close the PORV.

RO 4 IF an alarm was caused by a CONTROL instrument (PT-444/445) OR component failure, THEN perform the following as required to restore RCS pressure to desired value.

4.1 Take manual control of the following as required:

• Power operated relief valves

[ ] PRZR PORV Q1B31PCV445

[ ] PRZR PORV Q1B31PCV444B OR

[ ] PRZR BLOCK VLV Q1B31MOV8000A

[ ] PRZR BLOCK VLV Q1B31MOV8000B

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP RO 4.2 Verifies PK-444A at IF B/U heaters automatically energized ~ 9.25 with pressure above 2210 psig, THEN verify the pressurizer master controller potentiometer setting using the plant curve book.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __6__ Page 3 of 3 Event

Description:

PK-444A, PRZR PRESS REFERENCE, fails high. Causes pressure to rise until manual control taken or a PORV lifts.

Time Position Applicants Actions or Behavior Comments RO 5 This step is N/A IF a PROTECTION instrument failure has occurred, THEN determine which pressure channel has caused the alarm.

RO 6 This step is N/A Refer to Tech Specs for LCO requirements that exist.

SRO 7 Contacts Shift Manager Notify the Shift Manager SRO 8 This step is N/A

[CA] WHEN plant conditions permit, THEN restore components to automatic control.

SRO 9 Has RO/BOP contact Submit a Condition Report and notify the SSS/WWC Work Week Coordinator (Maintenance ATL on backshifts).

RO 10 This step is N/A IF the pressurizer power operated relief valves operated, THEN perform the following:

SRO 11 Go to procedure and step in effect.

At discretion of the lead examiner, move to the next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 1 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Indications Available Annunciators: Recognize indications of Loss of ALL AC power

• Many and various *RCPs tripped

• EPB power indication lights not LIT *Components not running Time Position Applicants Actions or Behavior Comments Note: Some or all of EEP-0.0 Immediate Operator Actions will be perfomed before ECP-0.0 is entered EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 2 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit BOP 3.2 (RNO) This step will not be

[CA] Try to restore power to performed based on deenergized 4160 V ESF bus using FNP- scenario conditions 1-AOP-5.0, LOSS OF A OR B TRAIN ELECTRICAL POWER, as time permits while continuing with this available lights lit procedure.

3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

RO/BOP 4.1 (RNO)

Check SI required 4.1.1 IF any setpoint and coincidence shown in the coincidence shown in the reached or exceeded, THEN SI is required.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 3 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments ECP-0.0, LOSS OF ALL AC POWER, ver 26 SRO Recognize Loss of all AC and direct IOAs of ECP-0.

RO 1 Immediate Operator actions Check reactor tripped. of ECP-0 are steps 1 and 2

[] Check reactor trip and reactor trip bypass breakers - OPEN.

[] Nuclear power - FALLING 2

Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT 3

Verify RCS isolated.

3.1 Verify normal letdown isolated.

3.1.1 Verify all letdown line orifice isolation valves - CLOSED.

LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 4 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments OR ECP-0.0 Step 3 Continued 3.1.2 Verify letdown line isolation valves -

CLOSED.

LTD LINE ISO

[] Q1E21LCV459

[] Q1E21LCV460 3.2 WHEN RCS pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

3.3 Verify excess letdown line - ISOLATED.

EXC LTDN ISO VLV

[] Q1E21HV8153 closed

[] Q1E21HV8154 closed 3.4 Verify all reactor vessel head vent valves -

CLOSED.

RX VESSEL HEAD VENT OUTER ISO

[] Q1B13SV2213A

[] Q1B13SV2213B RX VESSEL HEAD VENT INNER ISO

[] Q1B13SV2214A

[] Q1B13SV2214B RO 4

Verify total AFW flow GREATER THAN 395 gpm.

AFW TOTAL FLOW

[] FI 3229

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 5 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments 4 (RNO) Critical task - start the TDAFW pump 4.1(RNO)

Verify TDAFWP running.

TDAFWP STM SUPP FROM 1B(1C) SG

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

Place TDAFWP STM SUPP FROM 1B SG HV3235A/26 AND TDAFWP STM SUPP FROM 1C SG to the START position RO 4.2(RNO) Step is N/A IF TDAFWP NOT running, THEN locally verify TDAFWP TRIP THROTTLE VLV Q1N12MOV3406 open. (100 ft, AUX BLDG TDAFWP room)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 6 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments RO 4.3 (RNO) 4.3 Verify AFW flow path to each SG.

TDAFWP FCV 3228

[] RESET reset TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open RO/BOP 5

[CA] Restore power to any emergency bus.

5.1 Verify supply breakers for major loads on emergency 4160 V busses - OPEN.

On EPB

[] BKR DF01 (1A S/U XFMR TO 1F 4160 V BUS)

[] BKR DF15 (1B S/U XFMR TO 1F 4160 V BUS)

[] BKR DF-13-1 (1F 4160 V BUS TIE TO 1H 4160 V BUS)

[] BKR DG01 (1A S/U XFMR TO 1G 4160 V BUS)

[] BKR DG15 (1B S/U XFMR TO 1G 4160 V BUS

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 7 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments RO/BOP 5.1 (continued) Load shed list continued

[] 1C CCW PUMP BKR DF-04-1 from above

[] 1B CCW PUMP BKR DF-05-1 Components on MCB and

[] 1B CCW PUMP BKR DG-05-1 may be verified by RO

[] 1A CCW PUMP BKR DG-04-1

[] 1A SW PUMP BKR DK-03-1

[] 1B SW PUMP BKR DK-04-1

[] 1C SW PUMP BKR DK-05-1

[] 1C SW PUMP BKR DL-05-1

[] 1D SW PUMP BKR DL-03-1

[] 1E SW PUMP BKR DL-04-1

[] #4 RW PUMP BKR DJ-03-1

[] #5 RW PUMP BKR DJ-04-1

[] #8 RW PUMP BKR DH-03-1

[] #9 RW PUMP BKR DH-04-1

[] #10 RW PUMP BKR DH-05-1

[] 1B CRDM CLG FAN BKR ED-11-1

[] 1A CRDM CLG FAN BKR EE-13-1

[] 1A CS PUMP BKR DF-11-1

[] 1B CS PUMP BKR DG-11-1

[] 1A RHR PUMP BKR DF-09-1

[] 1B RHR PUMP BKR DG-09-1

[] 1A CHG PUMP BKR DF-06-1

[] 1B CHG PUMP A TRN BKR DF-07-1

[] 1B CHG PUMP B TRN BKR DG-07-1

[] 1C CHG PUMP BKR DG-06-1

[] 1A MDAFWP BKR DF-10-1

[] 1B MDAFWP BKR DG-10-1

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 8 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments RO/BOP 5.2 NO Check 1-2A, 1C or 1B diesel generator running for Unit 1.

5.2 (RNO) Perform the following 5.2.1 Perform 2C DG SBO start as follows:

5.2.1.1 2C DG MSS in MODE 1 5.2.1.2 2C DG USS in UNIT 1 5.2.1.3 When load shed has been competed then 2C DG will NOT start depress START PB for 2C DG 5.2.1.4 Verify 2C DG stsrts Note; Since 2C DG failed to start, 5.2.1.5 - 5.2.1.8 (RNO) are N/A RO/BOP 5.2.2 (RNO) 1B DG will be selected IF unable to start 2C diesel generator AND Critical Task - Start the energize 1G 4160V bus, THEN start any 1B DG diesel generator.

RO/BOP 5.2.2.1 (RNO) 1B DG starts Start 1B diesel generator from EPB in Mode 2 using START pushbutton.

5.3 Check 1-2A, 1C or 1B diesel generator output.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 9 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments 5.3.1 Verify diesel generator frequency 62 Hz.

5.3.2 Verify diesel generator voltage - 4.0-4.3 kV 5.4 Check DG08 closed 5.5 IF 1F 4160 V bus energized, THEN proceed to step 5.7.

RO/BOP 5.7 Verify adequate SW flow.

5.7.1 Verify two SW PUMPS in energized train - RUNNING.

[] A Train (1A, 1B or 1C)

[] B Train (1D, 1E or 1C) 5.7.2 IF A train energized, THEN verify SW TO/FROM DG BLDG - A HDR Q1P16V519/537 open.

5.7.3 IF B train energized, THEN verify SW TO/FROM DG BLDG - B HDR Q1P16V518/536 open. Contacts TB SO 5.7.4 Check no running diesel generator lube oil temperature annunciator in alarm. (155 ft, DG BLDG local control panel)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 10 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments SRO 5.8 IF 1F OR 1G 4160 V energized, THEN go to procedure and step in effect and implement function restoration procedures as necessary.

At discretion of Lead Examiner, terminate the exam

Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #2 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 7/20/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 2 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1 Section 4.1 - through step 23 is complete. Ramp on hold while investigating Feed water Dissolved Oxygen. 1B MDAFWP tagged out.

Turnover:

• Reactor power - 95%, Impulse Loop is NOT in service, MOL, Cb 977 ppm.

• UOP-3.1 Section 4.1 - through step 23 is complete.

• Ramp on hold while Chemistry investigates Feedwater Dissolved Oxygen.

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

Event Malf. Event Event No. No. Type* Description 1 xmt/ I (RO) LT-112, VCT LVL, fails high.

lt112 2 preset I (BOP) R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

malf/r/

MAL-RMS2T 3 malf/n/ I (BOP) N-41A, Power Range, Loses Instrument power.

MAL-TS (SRO) TS - 3.3.1 Cond D,E,T,U NIS11A 4 R (RO) Chemistry report that dissolved Oxygen exceeds Action Level 2.

N (BOP) Requests ramp down to less than 48% power.

5 cmfmalf/ C (RO) 1C Charging pump trips on overload.

cCVP01C_

TS (SRO) TS - 3.5.2 Cond A d_c1 6 caep file C (BOP) 1B SGFP begins to oscillate. Will trip after attempts are made to control in manual. This will require a fast ramp. (P-CT) malf/f/

MAL-FWM11B 7 malf/f/ M (ALL) 1A SGFP trips requiring a Reactor trip.

MAL-FWM11A 7 Preset/ C (RO) Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) trigger 1 C (BOP) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

8 malf /r/ M (ALL) LBLOCA after exiting FRP-S.1.

RCS2A C (BOP) preset Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT)

Terminate on transition to ESP-1.3.

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario 2 Presets Form ES-D-1 EVENT TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-220 (Base IC-60)

Impulse loop NOT in service.

rst 220 0 0 Generic setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc2.txt 0 0 Freeze Xe set crxefast=0 0 0 RUN PRESETS setup Tag out 1B MDAFW pump

• irf cAFP01B_d_cd1 open 2 RCV-3028 does not close on High Radiation

• imf ccch3028_cc1 closed imf ccch3028_cc4 closed 7 1A crdm set fails to trip:

• imf c52mga_cr3 7 RTBs fail to open

• imf cbkrxtrp_cc21 closed imf cbkrxtrp_cc22 closed 7 Main Turbine will not trip Automatically

• imf mal-tur2 7 Prevent Manual trip of main turbine

• imf mal-tur24 7 GV2 will not close completely. GV2 reaches 25% going *TRG 1 closed, it sticks at 25% open.

trg 1 "imf mal-tur15f 25 0"

PRESETS 7 MSIVs will not close on MSLIAS

• imf cRSH001A_cc5 open imf cMSH002A_d_cc5 open imf cRSH001B_cc5 open imf cMSH002B_d_cc5 open imf cRSH001C_cc5 open imf cMSH002C_d_cc5 open 8 Phase B fails to automatically actuate

• imf cCTMTSPR_cc1 open imf cCTMTSPR_cc2 open imf cCTMTSPR_cc5 open imf cCTMTSPR_cc9 open imf cCTMTSPR_cc10 open imf cCTMTSPR_cc13 open Triggers and Commands 6 Monitor GV 2 position *TRG 1 trgset 1 "rehgvpz(2) <= 25"

MCB setup OVATION Clear OVATION alarms OVATION Verify Impulse Loop is NOT in service Place danger TAG ON 1B MDAFW Pump HS on MCB Place tag on 1B MDAFWP HS Unit 1 Train B Bypass & Inoperable Status Ind Panel on AFW Switch in ON EPB - AFW SYSTEM Switch in ON Provide a marked up copy of UOP-3.1 UOP-3.1 Section 4.1 - up through step 23 marked off Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Un Freeze Xe set crxefast=1 Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl

MCB setup If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 Start of LT-112, VCT LVL, fails high.

exam /

NRC CUE imf lt112 100 15 2 NRC R-17B, CCW, Fails High. RCV-3028, CCW SRG TK CUE VENT, fails to close.

imf mal-rms2t 1e+006 3 NRC N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U CUE mal-nis11a 4 NRC Chemistry report that dissolved Oxygen exceeds Action Level CUE 2. Requests ramp down to less than 48% power.

5 NRC 1C Charging pump trips on overload. TS - 3.5.2 Cond A CUE imf ccvp01c_d_c02 6 NRC 1B SGFP begins to oscillate. Will trip after the 1B SGFP CUE speed is stable or after fast ramp initiated whichever is first.

cae 2105nrcscen2.cae imf mal-fwm11b

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC 1A SGFP trips requiring a Reactor trip.

CUE imf mal-fwm11a 7 N/A Reactor fails to trip. Require entry into FRP-S.1. preset Turbine fails to trip in Manual and GV2 will not close. TRG1 Requires the MSIVs to be shut.

8 1 LBLOCA after exiting FRP-S.1.

minute imf mal-rcs2a after exit of FRP-S.1 or Neither Phase B nor Containment Spray will automatically preset NRC actuate and requires manual actuation.

CUE NRC END OF EXAM:

CUE Transition to ESP-1.3 Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen2grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 IF REQUESTED Open RX trip breakers imf cbkrxtrp_cc21 open imf cbkrxtrp_cc22 open (3 minutes after requested) cae Turbine_Bldg_MSRs.cae (10 minutes after requested, SOP-0.0 actions for a Rx trip/Safety Injection) 9.1.7 RNO of EEP-0 cae 2015_TB_MSDP_iso.cae (5 minute after requested) 8 IF REQUESTED Close ECCS Disconnects cae eccs_disc_delayed.cae (3 minutes after requested)

Acknowledge MH1 Go to Control Room Fire Panel on the PANEL MAP and select CONTROL ROOM FIRE PANEL then CLICK the ACK button.

(3 minutes after requested)

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the inform supervision) cue and that type of communications 1 IF REQUESTED HP: We will perform surveys on the CCW system.

HP: 5 minutes after requested: All radiation levels in the vicinity of CCW are background.

2 NO ADDITIONAL REQUIRED 3 IF REQUESTED SSS: We will place the OTT bistables for N41 in TRIP SSS/U2: I will perform STP-37.0 for Unit 1.

4 CUE Chemistry: Feedwater Dissolved Oxygen has exceeded action level 2.

IF REQUESTED Chemistry: Recommend reducing power to <48%.

IF REQUESTED Chemistry: Feedwater Dissolved Oxygen is 12 ppb.

IF REQUESTED Shift Manager (or other Plant Leadership): I concur with Chemistrys request to lower power to <48%.

IF REQUESTED Shift Manager: (if asked what power level to stop). What is your recommended power level to reduce to? ----- I concur.

5 IF REQUESTED RAD 1 SO: 3 minutes after requested - 1C Charging pump is not running. No obvious problems noted.

ROVER: 3 minutes after requested - DG-06 has an overcurrent trip flag.

SSS: We will brief then shift 1B Charging pump to B train.

SSS: We will brief and then rackout 1C Charging pump breaker.

6 IF REQUESTED TB SO: 3 minutes after requested - A contractor said he may have made contact with the 1B SGFP with a scaffold pole.

TB SO: 5 minutes after requested: All Feedwater heater dumps and drains appear to operating normally.

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

7 IF REQUESTED ROVER: 3 minutes after requested - The unit 1 reactor trip breakers are open TB SO: 10 minutes after requested - SOP-0.0 actions for a Rx trip/Safety Injection are complete.

RAD 1 SO: I will verify SFP cooling in service per SOP-54.0 8 IF REQUESTED SSS: I will coordinate the performance of step 6 of EEP-1.

SSS: I will Close recirculation valve disconnects using ATTACHMENT 1.

SSS: I will establish 1A and 1B post LOCA containment hydrogen analyzers - IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.

U2: Once MH1 is acknowledged - Fire alarm has been acknowledged. It was 1A-22 CTMT.

Appendix D Scenario 2 Detailed Summary Form ES-D-1 Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1 Section 4.1 - through step 23 is complete. Ramp on hold while investigating Feed water Dissolved Oxygen. 1B MDAFWP tagged out.

Turnover:

• Reactor power - 95%, Impulse Loop is NOT in service, MOL, Cb 977 ppm.

• UOP-3.1 Section 4.1 - through step 23 is complete.

• Ramp on hold while Chemistry investigates Feedwater Dissolved Oxygen.

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

Event 1: LT-112, VCT LVL Fails HIGH.

Verifiable actions: RO will place LCV-115A, VCT HI LVL DIVERT VLV, in the VCT position and control level using LCV-115A or LK-112 in manual.

Event 2: R-17B, CCW, fails high. RCV-3028, CCW SRG TK VENT fails to close.

Verifiable actions: BOP will close RCV-3028 manually.

Event 3: N-41A, Power Range, loses Instrument power.

Verifiable actions: BOP will operate the ROD STOP BYPASS switch, COMPARATOR CHANNEL DEFEAT switch, UPPER SECTION switch on the Detector Current Comparator Drawer, LOWER SECTION switch on the Detector Current Comparator Drawer and reset the rate trip for N-41. BOP will remove the AC Control Power Fuses on the A drawer for N-41A.

SRO - Tech Spec: 3.3.1 Cond D,E,T,U Event 4: Chemistry report that dissolved Oxygen exceeds Action Level 2. Requests ramp down to less than 48% power Verifiable actions: RO will use rods and boron to ramp down. BOP will place impulse loop in service and insert ramp target and begin ramp.

Event 5: 1C Charging pump trips on overload.

Verifiable actions: RO will secure letdown and start 1A Charging pump per AOP-16, CVCS Malfunction. The next event will be inserted prior to placing letdown back in service. SRO - Tech Spec: 3.5.2 Cond A.

Event 6: 1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert a fast ramp using Ovation.

Verifiable actions: BOP will take manual control of the 1B SGFP controller. When the 1B SGFP trips, the BOP will insert a fast ramp using Ovation controls.

(P-CT) If the SGWL falls to 28% NR in one SG, a Rx trip is called for but will not occur due to being blocked. Also, if SGWL reaches 82% NR, a turbine trip is called for but will not occur due to being blocked but a trip of both SGFPs will occur and the FRVs will close. This will cause an early entry into FRP-S.1. Critical task is to initiate a Reactor shutdown per FRP-S.1 if limits are exceeded.

Event 7: 1A SGFP trips which will require a manual Reactor trip. Reactor does not trip from the Main Control Room and the Main Turbine will not trip In Auto/Manual and the #2 GV will not close completely. FRP-S.1 entry required.

Verifiable actions: RO will insert rods and emergency borate (CT-52). BOP will shut MSIVs to isolate the turbine.

Appendix D Scenario 2 Detailed Summary Form ES-D-1 Event 8: A Large Break LOCA occurs upon exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate.

Verifiable actions: BOP manually initiates Phase B and Containment Spray (Same Switches). (CT)

Terminate at transition to ESP-1.3

Appendix D Scenario 2 Critical Tasks Form ES-D-1

_____ 1. Do not allow the dispatch of the SO to locally trip the RX trip breakers and or Main Turbine to interfere with the initiation of insertion of negative reactivity by one of the following methods.

• Insert control rods

• Establish emergency boration flow to the RCS (CT-52)

_____ 2. Initiate at least one train of Containment Spray prior to exiting FRP-Z.1 or prior to the end of the scenario.

This critical task comes from the comments section of CT-3, manually actuate containment cooling. For plants that rely on containment spray to remove iodine from the containment internal atmosphere, a separate plant-specific critical task specifically directed at manually actuating at least one train of containment spray may be appropriate. In such a case, the plant should prepare a separate critical task that justifies manual actuation of at least one train of containment spray on the basis of iodine removal assumptions made in the FSAR . (CT-PLANT BASED)

SCENARIO At power power instrument and component failures with a loss of feed with an ATWT OBJECTIVE/ followed by a LBLOCA. The team should be able to:

OVERVIEW:

• respond to a LT-112 failure

• respond to a loss of power to N-41A

• ramp down in response to out of specification chemistry

• restore charging flow after the trip of the running pump

• take manual control of 1B SGFP speed and perform a rapid power reduction on a loss of the 1B SGFP

• insert negative reactivity and close MSIVs in response to an ATWT with a loss of feed

• manually actuate Phase B.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 3

2. Abnormal events (2-4) 5

3. Major transients (1-2) 2

4. EOPs entered/requiring substantive actions (1-2) 1

5. EOP contingencies requiring substantive actions (0-2) 1

6. Critical tasks (2-3) 3

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 1, 95% RTP, MOL 10000 MWD/MTU, 977 ppm Cb, -2181 pcm Xe A Trn O/S / A Trn Protected / SFPC on A Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 167 hours0.00193 days <br />0.0464 hours <br />2.761243e-4 weeks <br />6.35435e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. Impulse loop is NOT in service

3. UOP-3.1, Section 4.1 through Step 23 is complete.

4. 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

5. Ramp is on hold while Chemistry investigates Feedwater Dissolved Oxygen.

6.

7.

8.

9.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas) 1B MDAFW pump - 3.7.5 Cond B LCO status (planned- entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago) #1 RHT Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __1___ Page 1 of 3 Event

Description:

LT-112, VCT LVL, fails high. Cause Letdown to divert to the RHT until manual action taken Indications Available

- Actual VCT level going down - DF3, VCT LVL HI-LO

- Auto make up may occur - LCV115A divert to the HU TANK Time Position Applicants Actions or Behavior Comments RO Announces alarm. May diagnose malfunction SRO Directs ARP entry ARP-1.4, DF3, VCT LVL HI-LO ver 54.2 RO 1 Determine if level is high or low as indicated by LI-115 and LI-112B on the MCB. {CMT 0006813}

RO 2 Steps 2 and 3 are N/A IF actual level is high, THEN:

3 IF actual level is low, THEN SRO 4 This step is N/A IF the alarm is due to a Charging or Letdown malfunction, THEN go to FNP AOP-16.0, CVCS MALFUNCTION to address the loss of letdown flow.

RO 5 Observe CHG HDR PRESS indicator PI-121 and the running Charging Pump Motor Ammeter to ensure proper pump operation. (SOER 97-1) {CMT 0006813}

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __1___ Page 2 of 3 Event

Description:

LT-112, VCT LVL, fails high. Cause Letdown to divert to the RHT until manual action taken Time Position Applicants Actions or Behavior Comments RO 6 Refer to FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM.

RO 7 This step is N/A IF LI-115 has failed high, THEN:

RO 8.

IF LI-112 has failed high, THEN:

8.1 Place Q1E21LCV115A, VCT HI LVL DIVERT VLV in the VCT position.

8.2 Manually makeup to VCT, as required to restore level.

8.3 Place LK-112 VCT level controller to manual and adjust to 0 demand.

8.4 Control VCT level by ONE of the following methods:

8.4.1 Alternately place Q1E21LCV115A, VCT HI LVL DIVERT VLV between VCT, AUTO, and RHT positions, as required.

8.4.2 Place Q1E21LCV115A, VCT HI LVL DIVERT VLV inAUTO and manually adjust LK112 VCT level controller to maintain level.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __1___ Page 3 of 3 Event

Description:

LT-112, VCT LVL, fails high. Cause Letdown to divert to the RHT until manual action taken Time Position Applicants Actions or Behavior Comments 8.5 This step is N/A IF VCT level decreases to 5%, THEN align charging pump suction to the RWST by the following:

8.5.1 RWST TO CHG PUMP

[ ] Q1E31LCV115B open.

[ ] Q1E21LCV115D open.

8.5.2 VCT OUTLET ISO

[ ] Q1E21LCV115C closed.

[ ] Q1E21LCV115E closed RO 8.5.3 Refer to FNP-1-AOP-1.0, FNP-1-AOP-2.0 and/or FNP-1-AOP-17.1 as appropriate.

SRO/RO 9 Steps 9 & 10 are N/A IF LI-115 has failed low, THEN:

10 IF LI-112 has failed low, THEN:

11 Contact SM. Has RO/BOP IF LI-112 or LI-115 has failed, THEN contact appropriate initiate steps to have the personnel instrumentation repaired. (SOER 97-1 At Lead Examiners discretion move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 1 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Indications Available

-FH1, RMS HI-RAD R-17A in ALARM Time Position Applicants Actions or Behavior Comments RO Announce alarm BOP Acknowledges RAD Monitor panel and announces R-17A in alarm SRO Directs ARP entry ARP-1.6, FH1, RMS HI-RAD ,ver 72.1 BOP 1 Check indications on radiation monitoring system console and determine which radiation monitor channel indicates high activity.

BOP 2 BOP closes RCV-3028 Insure that any automatic actions, associated with the alarmed channel, have occurred.

BOP 3 Perform the following general actions as appropriate.

3.1 Determine the source or cause of the high activity and correct or isolate as required.

3.2 Determine the validity of the high activity indication as follows:

3.2.1 Verify that the instrument is aligned May check alignment IAW for normal operation and is functioning SOP-45 on Page 5 properly.

Page 1 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 2 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Time Position Applicants Actions or Behavior Comments BOP 3.2.2 Steps 3.2.2 - 3.2.3 are N/A IF R10, R11, OR R12 has caused an invalid alarm, notify Electrical/I&C System Engineering Supervisor 3.2.2 IF a known problem exists such that the detector is saturated, THEN momentarily pull the affected detectors fuses (located on the front of the drawer) to clear the condition.

3.2.3 If requested to disable a remote audible alarm, refer to FNP-1-SOP-45.0, P&L 3.6.

3.2.4 Calls HP and has them Sample or survey the affected system or conduct survey.

area as required. {CMT 0008755}.

3.2.5 IF R-10, R11 or R12 are in an alarm or a This step is N/A fault condition, THEN submit a CR to request Engineering Support perform the applicable portion of FNP ETP-227.0, RAD MONITOR RM 2000 CONTROL PANEL OPERATION to obtain required data.

BOP 3.3 Do not allow personnel to enter the May make an affected area without the approval of the announcement Health Physics Department.

3.4 IF high activity indication is due to No LCO exists instrument failure, THEN refer to Technical Specifications, section 3.3.3, 3.4.15 and TRM TR 13.3.4.

Page 2 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 3 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Time Position Applicants Actions or Behavior Comments 3.5 Steps 3.5 - 3.8 are N/A IF high activity indication of RCS leakage is present AND accompanied by either decreasing pressurizer level, OR decreasing VCT level, THEN go to FNP AOP-1.0, RCS LEAKAGE.

3.6 IF high activity indication of Steam Generator Tube Leakage is present, THEN go to FNP-1-AOP-2.0, STEAM GENERATOR TUBE LEAKAGE.

3.7. IF ARDA activated and not required, THEN have counting room stop the automated dose assessment per FNP-0-EIP-9.1, AUTOMATED DOSE ASSESSMENT METHOD.

3.8 WHEN radiation levels have decreased below alarm setpoint, THEN reset the appropriate HI radiation alarm on the RAD monitor drawer BOP 4 R-17A requires step 4.16 In addition to the general actions perform supplementary steps indicated in the ACTIONS column of the following table. (Some of the radiation monitors included in the table do not input into this alarm but are included for reference).

Page 3 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 4 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Time Position Applicants Actions or Behavior Comments NOTE: IF CCW surge tank vents are closed for reasons other than an actual high radiation alarm, THEN with Shift Supervisor concurrence, the CCW surge tank vents should be cycled once every shift (eight hours) and documented in the Control room Log.

BOP 4.16 IF R-17A OR R-17B alarms, THEN perform the following:

4.16.1 Should have been closed at IF alarm is due to CCW Suction rad step 2. May be closed monitor R-17A or R- here.

17B being failed low (low alarm lit), THEN close CCW Surge Tank vent valve Q1P17HV3028, using handswitches for both Q1P17SV3028A and Q1P17SV3028B, with SS concurrence.

4.16.2 Monitor CCW pump operation while the CCW surge tank vents are closed.

4.16.3 WHEN desired to open the CCW surge tank vent valve Q1P17HV3028, THEN simultaneously place handswitches for both Q1P17SV3028A and Q1P17SV3028B to open until the red light is lit.

Page 4 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __2___ Page 5 of 5 Event

Description:

R-17B, CCW, Fails High. RCV-3028, CCW SRG TK VENT, fails to close.

Time Position Applicants Actions or Behavior Comments SOP-45, RADIATION MONITORING SYSTEM, ver 47 BOP 4.1 Aligning Radiation Monitoring System for Normal Operation:

4.1.1 Verify the appropriate radiation 4.1.1 is N/A monitoring recorders in operation per Section 4.2.

BOP 4.1.2 This step is N/A For R-22, verify alignment has been performed per FNP-1-IMP-227.47, Valve Alignment for Operation of Unit 1 RE0011/12 and RE0021/22 (OR 1 317).

BOP 4.1.3 Perform the following to verify drawers aligned for monitors listed in Table A:

4.1.3.1 Verify operation selector in OPERATE.

4.1.3.2 Verify range selector in WIDE.

4.1.3.3 Verify drawer indicating lights as follows:

a. Power Light - ON

b. Channel Test Light - OFF

c. High Alarm Light - OFF

d. Low Alarm Light - OFF BOP 4.1.4 This step is N/A Align the drawer for R21 as follows:

At Lead Examiners discretion move to next event Page 5 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 1 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Indications Available

-NI41B, PR1 PERCENT FULL POWER IS - The following alarms 0% FB4/FB5, PR UPPER/LOWER DET HI FLUX

-NI41C, PR1 PERCENT FLUX DIFF IS DEV OR AUTO DEF 0% FC1, PR HI FLUX-HIGH RNG RX TRIP ALERT

- NI41 DRAWER - No indication on FC3, PR HI FLUX RATE ALERT UPPER and LOWER DET FC5, PR CH DEV

- NI41 DRAWER - (5 power all bistable FF5, COMP ROD SEQ/DEV OR PR FLUX TILT lights lit)

Time Position Applicants Actions or Behavior Comments RO Announces alarms and/or diagnoses malfunction SRO Announces AOP-100 entry AOP-100, INSTRUMENTATION MALFUNCTION, ver 15 RO 1 This step is N/A IF N-44 has failed, THEN place rods in manual.

BOP 2 STOP any load change in progress.

RO 3 P-10 bistables on TSLB3 Within one hour, check P-10 interlock in and Bypass and permissive the required state for existing unit panel lights will be LIT conditions. (TS 3.3.1 Function 17e)

RO 4 P-7, P-8, P-9 Bistables light Within one hour, check the following on TSLB3 are LIT.

interlocks are in the required state for existing unit conditions: (TS 3.3.1 Bypass and Permissive Function 17b, c, d) Panel 4 P-7, P-8, P-9 lights OUT

• P-7

• P-8

• P-9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 2 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments RO 5 Check THERMAL POWER -

GREATER THAN OR EQUAL TO 75%.

SRO 6 IF required, THEN perform FNP-1-STP-122.0, QUADRANT POWER TILT MEASUREMENT WITH AN INOPERABLE EXCORE DETECTOR as required by Tech Spec SR 3.2.4.2 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 6

OR Reduce power to <75% thermal power within 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.

BOP 7 IF required, THEN perform the following:

77 a)

Select the affected channel on:

• ROD STOP BYPASS switch (Misc Control and Indication Panel)

• COMPARATOR CHANNEL DEFEAT switch (Comparator and Rate Drawer)

• UPPER SECTION switch (Detector Current Comparator Drawer)

• LOWER SECTION switch (Detector Current Comparator Drawer) b)

Reset rate trip on the A drawer for the affected channel by placing Rate Mode switch in RESET AND allow to spring return to NORMAL.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 3 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments RO/BOP 8 No action required Restore Tavg to program as necessary:

• Adjust turbine load

• Use of control rods

• Dilution/Boration RO 9 Check N-44 OPERABLE. This step is N/A 99 9.1 IF desired AND with Shift Supervisors concurrence, place RODS in AUTO.

RO 10 This step is N/A IF N-43 has failed AND it is desired to use the R-70s to determine the presence of elevated activity in the Steam Generators, THEN have Counting Room personnel place the R-70s in the ME mode per FNP-0-CCP-31, LEAK RATE DETERMINATION.

RO 11 Monitor operable Power Range Channels on NR-45B.

SRO 12 SRO contacts SM and has Submit a condition report on the failed RO/BOP contact instrument channel, and notify the Work appropriate personnel Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO 13 Contacts SSS to trip Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, place the inoperable Bistables - May not occur Power Range Channel in trip by since they have 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to performing the following: (TS 3.3.1) perform this action

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 4 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments BOP a)

Remove the AC Control Power Fuses on the A drawer for the affected channel.

SSS b)

Trip overtemperature delta-T bistables for affected channel by operation of the applicable TEST SWITCHES:

SRO 14 This step is N/A IF the plant computer is inoperable OR annunciator FC4 is otherwise inoperable, THEN within one hour perform FNP-1-STP-37.0, POWER DISTRIBUTION SURVEILLANCE.

SRO 15 Contacts SM Notify the Shift Manager.

SRO Initiate the applicable actions of the following Technical Specifications:

17 16

• Table 3.3.1-1 Function 2

• Table 3.3.1-1 Function 3

• Table 3.3.1-1 Function 6

• Table 3.3.1-1 Function 17 b, c, d, e

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 5 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments TECHNICAL SPECIFICATION 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1-1.

ACTIONS Function 2a, 3, - Condition D SRO CONDITION REQUIRED ACTION COMPLETION TIME D. One Power --------------------NOTE-----------

Range Neutron The inoperable channel may Flux channel be bypassed for up to 12 inoperable.. hours for surveillance testing and setpoint adjustment of other channels.

D.1.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND D.1.2 Reduce THERMAL POWER to 75% RTP. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> OR D.2.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND D.2.2 -----------NOTE------------

Only required to be performed when the Power Range Neutron Flux input to QPTR is inoperable.

Perform SR 3.2.4.2. Once per 12 hrs OR D.3 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __3___ Page 6 of 6 Event

Description:

Event

Description:

N-41A, Power Range, Loses power. TS - 3.3.1 Cond D,E,T,U.

Time Position Applicants Actions or Behavior Comments Function 6 - Condition E SRO CONDITION REQUIRED ACTION COMPLETION TIME E. One channel ------------------NOTE------------

inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.

E.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR E.2 Be in MODE 3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> Function 17b, c, d - Condition U SRO CONDITION REQUIRED ACTION COMPLETION TIME U. One or more U.1 Verify interlock is in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> channels required state for existing unit inoperable. conditions.

OR U.2 Be in MODE 2. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> Function 17e - Condition T SRO CONDITION REQUIRED ACTION COMPLETION TIME T. One or more T.1 Verify interlock is in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> channels required state for inoperable. existing unit conditions.

OR T.2 Be in MODE 3. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> At Lead Examiners discretion move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 1 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Indications Available N/A Time Position Applicants Actions or Behavior Comments SRO Receives call from Chemistry that Action If SRO call SM for Level 2 has been exceeded for Feedwater concurrence. SM concurs Dissolved Oxygen AOP-25, Abnormal Primary or Secondary Chemistry, ver 21.1 SRO 1 This procedure is entered upon notification by Chemistry that abnormal primary or secondary chemistry exists which could exceed chemistry control limits.

1.1 For a dissolved oxygen excursion proceed to step 2.

2 IF Chemistry reports that condensate pump discharge or feedwater dissolved oxygen is increasing or has exceeded an action level value, THEN perform the following:

2.1 Has SSS coordinate Begin investigating for the source of the performance of Attachment dissolved oxygen using 1 ATTACHMENT 1, DISSOLVED OXYGEN SOURCES as a guide while continuing in this procedure.

2.2 Chemistry request power IF dissolved oxygen has exceeded the reduction <48%

Action Level 2 value, THEN Consult with Chemistry and determine if a power reduction to less than or equal to 48% power is desired.

FNP-1-UOP-3.1, POWER OPERATION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 2 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments 2.2.1 Commences ramp down IF required, THEN reduce power to less than or equal to 48% in accordance with 2.3 N/A IF between 12% and 48% power, AND feedwater dissolved oxygen exceeds 100 ppb for more than 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />, THEN, power escalation should be halted until oxygen is less than 100 ppb.

2.4 Determine desired dissolved oxygen level and coordinate with Chemistry and Engineering Support to implement the appropriate corrective action plan UOP-3.1, Power Operation, Section 4.4, ver 122 BOP 1 Review and perform the following as required BOP a This step is N/A If Turbine Overspeed Test is to be performed, Refer To Section 3.0 Precaution and Limitation 1.l prior to commencing ramp...

BOP b For normal load reductions, a ramp rate restriction of 2 MW/min (14% per hour) will apply............................................................

BOP c This step is N/A When conditions warrant a ramp rate of greater than 2 MW/min, notify the Shift Manager as soon as conditions permit.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 3 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments BOP d This step is N/A Enter FNP-1-AOP-17.1, RAPID TURBINE POWER REDUCTION in conjunction with this procedure for ramp rates greater than 5 MW/min.........

BOP e This step is N/A Ramp as slow as possible if known fuel leak exists. Power decreases should follow the guidance found in Attachment 1, Special Load Rate Limitations.

BOP f This step is N/A If a power reduction is being performed due to entry into Technical Specifications 3.4.16, adjust the ramp rate to meet the shutdown requirements of the specification.

BOP g This step is N/A If a reactor shutdown is NOT for a refueling outage, record criticality data in the Control Room Log prior to load decrease.

BOP h Maintain valve position limit 115% while ramping or at 100%.

BOP i This step is N/A Maintain valve position 8 to 10% above valve position demand when holding for more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at some power level less than 100%.

BOP j This step is N/A Flush and sample AFW pump suction piping as required by FNP-1-SOP-22.0, Auxiliary Feedwater System, prior to initiation of AFW flow to the SGs.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 4 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments BOP 2 BOP place IMP loop in While ramping between 97% and 20% service per step 2 power, verify the IMP PRESS LOOP in service as follows:

BOP a Verify Turbine on HOLD. ..............

BOP b Check Ovation point, 1ST STG IMPLS PRESS, has stable indication.

BOP c On LOOP STATUS of page 5551, press SELECT BOP d On popup 7053, press IMP BOP e On popup 7059, press IMP LOOP IN.

BOP f On LOOP STATUS of page 5551, check IMPULSE displays YES BOP 3 On page 5551, perform the following to set desired load target and load rate.................

a On RAMP INTERFACE section, press MODIFY b

On TARGET SELECTION section of BOP inserts ramp to <48%

popup 7055, enter desired target using one of the following methods:

• Using predefined buttons.

• Using CUSTOM button to enter custom rate

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 5 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 6 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments c

On RAMP INTERFACE section of page 5551, check desired target appears under TARGET.

d On page 5551, check HOLD button has gold background e

IF desired to change load rate, on RAMP INTERFACE section of page 5551 press MODIFY.

(1)

On popup 7055, enter desired rate by either of the following Using predefined buttons.

Using predefined buttons.

(2)

On RAMP INTERFACE section of page 5551, check desired rate appears under RATE.

4 Inform other Control Room operators load will be changed.

5 Press GO to commence ramp.

BOP 6 Verify proper SGFP speed control.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 7 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments RO 7 Attempt to maintain the axial flux difference within + 5% from the target value by making adjustments in rod height and/or boron concentration as necessary..........

RO Uses Borations to lower Tavg during the ramp SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix B, v60.1 RO 1.1 From reactivity briefing IF necessary, THEN set the boric acid sheet integrator to the desired quantity.

RO 1.2 IF necessary, THEN adjust LTDN TO VCT FLOW LK 112 setpoint as desired.

1.3 Position the MKUP MODE CONT SWITCH to STOP.

1.4 Position the MKUP MODE SEL SWITCH to BOR.

1.5 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 8 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments RO 1.6 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.7 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.8 This step is N/A If desired to clear the line of acid, perform the applicable steps of Appendix B Section 2.0.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 9 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments Note: If the crew decides to remain lined up for repetitive borations, then steps 1.9 -

1.11 are N/A. Repetitive boration steps are listed in Appendix C below.

RO 1.9 Position the MKUP MODE SEL SWITCH to AUTO.

1.10 Position the MKUP MODE CONT SWITCH to START.

1.11 IF LK 112 setpoint was adjusted per Step 1.2, THEN return setpoint to that required for current conditions.

SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix C, v60.1 RO 1.1 IF necessary, THEN set FIS-113 Boric Acid Batch Integrator to the desired quantity.

1.2 The Reactor Makeup Control system has been previously aligned for Boration.

1.3 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 10 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments RO 1.4 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.5 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.6 IF repetitive borations are no longer required THEN verify the system is aligned for Automatic makeup per Steps 1.9 through 1.11 of Appendix B.

SOP-41.0, Control Rod Drive and Postion Indication System, Ver 37 OPERATOR AID FOR CONTROL ROD MOVEMENT RO 1 Place ROD CONTROL BANK SELECTOR SWITCH in MAN.

RO 2 Check indicated control rod speed is approximately 48 steps per minute on SI-408.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: __2___ Event No.: __4___ Page 11 of 11 Event

Description:

Chemistry report that dissolved Oxygen exceeds Action Level 2.

Time Position Applicants Actions or Behavior Comments RO 3 Insert OR withdraw Control Rods using the CONTROL ROD MOTION switch.

RO 4 When desired, place rod control in AUTO as follows:

RO 4.1 Verify Tavg within 1°F of Tref.

RO 4.2 Place the ROD CONTROL BANK SELECTOR SWITCH in AUTO.

RO 4.3 Check indicated control rod speed is approximately 8 steps per minute on SI-408.

After the ramp or at the Lead Examiners discretion then move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 1 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Indications Available

- FI-122A, CHG FLOW goes to 0 -The following ALARMS

- 1C CHG PUMP amber light and green EA2, CHG HDR FLOW HI-LO light LIT. EB1, CHG PUMP OVERLOAD TRIP Time Position Applicants Actions or Behavior Comments RO Announces alarms and / or diagnoses malfunction SRO Directs entry into ARP ARP-1.5, EB1, CHG PUMP OVERLOAD TRIP, ver 58.2 SRO 1 Enter FNP-1-AOP-16.0, CVCS Transitions to AOP-16 MALFUNCTION, while performing the remaining steps of this ARP.

RO 2 Observe CHG HDR press indicator PI-121 and the running charging pump motor ammeter to ensure proper pump operation. (Ref. SOER 97-1) 3 RO/BOP Notify appropriate personnel to locate and Contacts ROVER and RAD correct the cause of the pump 1 SOs.

trip.

SRO 4 Refer To Technical Specifications LCOs 3.5.2 and 3.5.3, and Technical Requirements TRs 13.1.2, 13.1.3, 13.1.4, and 13.1.5.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 2 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments AOP-16, CVCS MALFUNCTION, ver 20 RO 1 Verify CHG flow adequate to cool letdown

[] CHG FLOW - FI-122A

[] LTDN HX OUTLET FLOW - FI-150

[] REGEN HX OUTLET TEMP - TI-140 RO 1 (RNO)

Isolate Normal Letdown as follows:

1.1 (RNO)

Verify closed all LTDN ORIF ISOs:

[] Q1E21HV8149A

[] Q1E21HV8149B

[] Q1E21HV8149B BOP 2 Stop any load change in progress RO 3 This step is N/A If charging line rupture occurs then go to attachment 2 4

Monitor VCT level 5

Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation PI-121 and ammeter for chg pump

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 3 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 5 (RNO)

IF VCT level reduces to 5%, THEN perform the following:

5.1 Open RWST TO CHG PUMP valves

[] Q1E21LCV115B

[] Q1E21LCV115D 5.2 Close VCT OUTLET ISO valves

[] Q1E21LCV115C

[] Q1E21LCV115E RO 6 1C Charging pump is not Check charging pump - RUNNING running RO 6 (RNO)

Start an available charging pump as follows:

6.1 Check VCT level and pressure adequate.

6.2 Verify charging suction flowpath aligned:

VCT OUTLET ISO valves

[] Q1E21LCV115C - OPEN

[] Q1E21LCV115E - OPEN OR RWST TO CHG PUMP valves

[] Q1E21LCV115B - OPEN

[] Q1E21LCV115D - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 4 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 6.3 (RNO)

Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB.

RO 6.4 (RNO)

Check open minflow isolation for charging pump to be started

• 1A CHG PUMP MINIFLOW ISO Q1E21MOV8109A RO 6.5 (RNO)

Verify CHG PUMP MINIFLOW ISO, Q1E21MOV8106, is open RO 6.6 (RNO)

Verify the following are closed;

[] CHG FLOW FK 122

[] SEAL WTR INJECTION HIK 186 RO 6.7 (RNO)

Verify a CCW pump is running in same train aligned to supplycharging pump to be started RO 6.8 (RNO)

Start selected charging pump RO 6.9 (RNO)

Observe CHG HDR PRESS indicator PI 121 and motor ammeter to check proper pump operation RO 6.10 (RNO)

WHEN charging pump comes up to speed.

THEN check auxiliary oil pump stops as indicated by white light NOT being illuminated on MCB.

Time Position Applicants Actions or Behavior Comments

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 5 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A RO 6.11 (RNO)

Adjust SEAL WTR INJECTION HIK 186 to maintain 6-13 gpm seal injection flow to each RCP RO 6.12 (RNO)

IF all seal cooling lost to any RCP, THEN go to AOP-4.1, ABNORMAL REACTOR COOLANT PUMP SEAL LEAKAGE RO 7 Check Charging flow FK-122 controlling in AUTO with flow indicated RO 7 (RNO)

IF required. THEN take manual control of charging flow:

RO 7.1 (RNO)

Place FK-122 in manual and adjust as required to maintain pressurizer level at program level.

RO 7.2 (RNO)

Adjust SEAL WTR INJECTION HIK-186 as required to maintain RCP seal injection flow 6-13 gpm RO 7.3 (RNO) If manual control of charging This step is N/A not accomplished. THEN refer to ATT 1, MANUAL CONTROL OF CHARGING RO 8 Check to following annunciator -CLEAR

[] DE3 LTDN ORIF ISO VLV REL LINE TEMP HI

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 6 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 9 Determine Status of Normal Letdown:

9.1 Check normal CVCS letdown -

AFFECTED BY MALFUNCTION

• LTDN HX OUTLET FLOW, FI-150 - NO FLOW INDICATED RO 9.2 Minimize RCS makeup:

9.2.1 Manually close FK-122 9.2.2 Minimize seal injection between 6-13 gpm 9.2.3 Direct Chemistry to shutdown the zinc addition system (ZAS)

RO 9.3 Dispatched personnel Dispatch personnel to investigate cause of earlier letdown malfunction RO 9.4 This step is N/A If desired due to plant conditions, place excess letdown on service

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 7 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 10 Determine if normal letdown should be re-established:

10.1 Check normal letdown malfunction(s) -

CORRECTED 10.2 Verify all letdown orifice isolation valves -

CLOSED LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C RO 10.3 Place LTDN HX OUTLET TEMP TK-144 on service:

[] Place controller in AUTO

[] Set to maintain temp 90 (Pot setting 2.7) to 115°F (Pot setting 4.35)

RO 10.4 Verify VCT HI LVL DIVERT VLV LCV-115A alignment:

[] Position indicator VCT light - LIT

[] Handswitch in-AUTO RO 10.5 Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143

[] Handswitch in - VCT

[] VCT light - LIT

[] DEMIN light - NOT LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 8 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 10.6 N/A IF necessary, THEN OPEN both LTDN LINE PENE RM ISOs from the Penetration Room Isolation Panel.

[] Q1E21HV8175A

[] Q1E21HV8175B RO 10.7 Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN RO 10.8 Verify LTDN LINE ISO valves - OPEN

[] Q121LCV459

[] Q121LCV460 RO 10.9 Verify LP LETDN PRESS PK 145 on service:

[] Place controller in MANUL

[] Adjust demand signal o 50% or less RO 10.10 Initiate minimum charging flow:

10.10.1 Verify CHG FLOW FK 122 in MAN 10.10.2 Establish minimum charging flow based on orifices to be placed on service:

• 1 Orifice - 18 gpm or

• 2 Orifices - 40 gpm RO 10.11 Establish approx. 60 gpm letdown flow by OPENING:

Q1E21HV8149B OR Q1E21HV8149C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 9 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 10.12 If desired place the second orifice on service by opening Q1E21HV8149A RO 10.13 Initiate actions to restore letdown flow to demins per SOP-2.1 RO 10.14 IF all backup heaters energized due to pressurizer level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing RO 10.15 Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure -

BETWEEN 260-450 psig 10.15.1 Set controller between 4.3 and 7.5 10.15.2 Check letdown flow - STABLE 10.15.3 Place PK 145 in AUTO 10.15.4 Control Letdown pressure as desired RO 10.16 Control LTDN HX OUTLET TEMP TK 144 to maintain Letdown temperature 90 to 115°F

[] TI-116 VCT TEMP

[] TI-143 DIVERT LTDN HX TEMP

[] TI-144 CCW LTDN HX TEMP

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __5___ Page 10 of 10 Event

Description:

1C Charging pump trips on overload. Crew will isolate letdown, start the opposite train pump and restore letdown. TS - 3.5.2 Cond A Time Position Applicants Actions or Behavior Comments RO 10.17 Refer to SOP-2.1 for further guidance on Letdown system control RO 11 Determine status of letdown flow:

11.1 Check letdown flow - ESTABLISHED

• Normal letdown flow OR

• Excess letdown flow RO 11.2 Go to procedure and step in effect TECHNICAL SPECIFICATION 3.5.2, ECCSOperating Two ECCS trains shall be OPERABLE.

B Train ECCS is INOPERABLE until the 1B chg pump is aligned to B Train and the 1C Chg pump is tagged out or a jumper is installed to permit the 1B Chg pump to auto start CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore train(s) to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> trains OPERABLE status.

Inoperable AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

At the discretion of the Lead Examiner move to Event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 1 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Indications Available

- 1B SGFP speed oscillation When the 1B SGFP trips:

- JF1 / 2 / 3, 1A /1B/ 1C/ SG LVL DEV -1B SGFP speed to 0 rpm

-KC3, 1A OR 1B SGFP TRIPPED

- VARIOUS OTHER FEED SYSTEM ALARMS Time Position Applicants Actions or Behavior Comments BOP Announces alarms and recognizes malfunction SRO Enters AOP-13, Condensate and Feedwater Malfunction Note: AOP-13 allows going directly to the appropriate step based on malfunction.

The crew may choose to call the 1B SGFP tripped. See Step 3.5 RNO.

If this occurs, they will insert a rapid ramp per the IOA of AOP-13 (page 5). In this case, it is intended that we will trip the 1B SGFP if a rapid ramp is initiated (GO button depressed)

AOP-13, Condensate and Feedwater Malfunction, ver 39.1 BOP 3 Check indication of any SGFP malfunction

-Any SGFP speed abnormal

- SGFP discharge Pressure - low 1A(1B) SGFP DISCH PRESS PI 4018A(B)

- Feedwater header pressure - low FW HDR PRESS PI 508

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 2 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 3.1 Potential Critical Task -

Take manual control of SGFP(s) Maintain SGWL to prevent speed controllers as necessary to a Rx trip caused by a control speed and restore feedwater turbine trip.

header pressure above steam header pressure.

- SGFP master controller

- SK-509A OR SGFP individual controllers as needed.

- SK-509B

- SK-509C BOP 3.2 Take manual control of the affected feedwater regulating valves or bypass valves as necessary to control SG level.

- 1A SG FW FLOW FK-478

- 1B SG FW FLOW FK-488

- 1C SG FW FLOW FK-498 OR

- 1A SG BYPASS FLOW FK-479

- 1B SG BYPASS FLOW FK-489

- 1C SG BYPASS FLOW FK-499 3.3 Check no reactor protection system automatic actions required or set points being approached.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 3 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 3.4 IF a ramp is in progress, THEN place Turbine on HOLD 3.5 Verify adequate SGFP function restored.

3.6 Maintain SG narrow range level approximately 65%.

3.7 Check SGFP speed control instrumentation - NORMAL PI-464A PI-508

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 4 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments 3.8 Adjust speed back to within the normal operating range for the feed flow/steam flow DP required for the existing power level Approximate DP can be determined from the following MCB indications.

3.9 Check Hotwell level maintained 30 to 24 by HOTWELL LEVEL controller (CP-4055F) in Auto.

Trip 1B SGFP once speed control is regained

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 5 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments SRO Direct immediate operator actions of AOP-13 due to the 1B SGFP trip BOP 1 Check only one SGFP - RUNNING 1.1 Check generator load GREATER THAN 540 MW 1.2 Check rapid turbine load reduction required.

BOP 1.3 On Ovation Page 5551, TURBINE CONTROL SYSTEM - OPERATION PANEL, perform the following:

1.3.1 Press red ENABLE button on SGFP TRIP RUNBACK section.

1.3.2 On SGFP TRIP RUNBACK section, check the following:

[ ] ENABLE turns gold

[ ] RUNBACK ENABLED is displayed 1.3.3 On RAMP INTERFACE section, check the following:

[ ] TARGET of "540" MW

[ ] Appropriate RATE for current MW load is displayed 1.3.4 Press GO BOP 1.4 Monitor for correct Ovation response

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 6 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 1.5 Potential critical task -

Reduce reactor power to match Loss of SGWL control turbine power. could result in an auto Rx trip due to low SGWL or a 1.5.1 required trip due to a FW Verify rod control in MANUAL. isolation on high SGWL.

1.5.2 Reduce reactor power and control RCS TAVG.

Manual Rod Control Manual boration per FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM.

Emergency boration per FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM Figure 6.

1.6 Check proper operation of the steam dumps.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 7 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 1.7

[CA] Verify steam generator narrow range levels remain greater than 28%.

1.7.1 Verify automatic operation of the feedwater regulating valves adequate.

1A SG FW FLOW FK 478 1B SG FW FLOW FK 488 1C SG FW FLOW FK 498 1.7.2 Monitor feedwater flow and steam flow.

1.7.3 Verify that feedwater and steam flow trend to approximately equal values for the target, turbine load.

BOP 1.8

[CA] Maintain SG narrow range level approximately 65%.

RO 1.9 Check LOSS OF LOAD INTERLOCK C-7A on the BYP & PERMISSIVES panel NOT illuminated.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 8 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments BOP 1.9 (RNO)

IF C-7A is to be reset, THEN perform the following 1.9 1.9.1 Verify that all steam dump valves indicate closed.

1.9.1 1.9.2 Verify 0 demand on STM HDR PRESS controller PK 464 and STM DUMP DEMAND TI408 1.9.2 1.9.3 Place STM DUMP INTLK TRAIN A and TRAIN B to OFF RESET 1.9.3 1.9.4 Place STM DUMP MODE SEL TRAINS A-B to RESET and then release to spring return to TAVG.

RO 1.10 Check reactor power change < 15%

RO 1.10 (RNO)

Notify Shift Radiochemist to sample the RCS per FNP-1-STP-746.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __6__ Page 9 of 9 Event

Description:

1B SGFP speed will begin to oscillate. The BOP will control speed in manual. When the 1B SGFP speed is stable, the 1B SGFP will trip. The 1B SGFP will trip which will require a fast ramp to <540 MW. The fast ramp will require the BOP to insert the fast ramp using Ovation controls.

Time Position Applicants Actions or Behavior Comments RO 1.11 Check parameters within limits for continued at power operation.

Pressurizer level greater than 15%

Pressurizer pressure greater than 2100 psig SG narrow range levels 35%-75%

TAVG 541F - 580F Control rod bank position Lo-Lo Annunciator FE2 Clear Delta I within limits specified in the COLR RO 1.12 Check Hotwell level maintained 30 to 24 by HOTWELL LEVEL controller (CP-4055F) in Auto.

At Lead Examiners discretion, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 1 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Indications Available The following will be in alarm: - SGFP Speed Decreasing 1A or 1B SGFP Tripped (KC3) - Feed Flow Decreasing SG LVL DEV (JF1, JF2, JF3) - FRV-controller FK-496, 497, 498 demand SG LO LVL (JA1, JA2, JA3) increasing SG STM Flow > Feed Flow (JB1, JB2, JB3) - SG Levels decreasing Time Position Applicants Actions or Behavior Comments BOP Recognizes the tripped SGFP, announces and takes immediate operator actions of AOP-13 SRO Directs immediate operator actions of AOP-13 if not performed by RO/BOP AOP-13, Condensate and Feedwater Malfunction, v 37 BOP 1 Check only one SGFP - RUNNING BOP 1 (RNO)

Proceed to step 2 BOP 2 Check Both SGFPs - TRIPPED 2.1 Check Reactor Power - LESS THAN 5%.

RO 2.1 (RNO)

Trip the reactor and go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

Note: the RX will not trip and the crew will perform their immediate operator actions of FRP-S.1

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 2 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments SRO Reactor trip Direct the reactor trip and enter EEP-0 EEP-0.0, Reactor Trip or Safety Injection, ver 45 1 Immediate Action steps of Check reactor trip. EEP-0 Check all reactor trip breakers and reactor NOTE: Reactor will NOT trip bypass breakers - OPEN. trip Check nuclear power - FALLING.

check rod bottom lights - LIT.

1.2 (RNO)

TRIP CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR RNO: Reactor is not

[] N1C11E005A tripped by RTBs or CRDM

[] N1C11E005B MG sets.

1. (RNO) FRP-S.1 entered RO Recognize the Rx did not trip and announces and take immediate operator actions of FRP-S.1 SRO If not performed by the RO or BOP, then direct the performance of the immediate operator actions of FRP-S.1 FRP-S.1, RESPONSE TO NUCLEAR POWER GENERATION/ATWT, ver 28 1 Since this was done in Check reactor trip. AOP-13, the crew may not

[] Reactor trip and bypass breakers - re-perform it.

OPEN

[] Nuclear power - FALLING

[] IF DRPI available, THEN rod bottom lights - LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 3 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 1 (RNO) Since this was done in Perform the following. AOP-13, the crew may not re-perform it.

1.1 Manually trip reactor.

1.2 IF reactor can NOT be tripped, THEN trip both MG set supply breakers.

[] N1C11E005A

[] N1C11E005B 1.3 (RNO) Critical Task - Insert 1.3 IF reactor is still NOT rods: or can emergency tripped, THEN perform the following. borate Insert control rods in manual control.

OR Verify rods insert in AUTO at greater than 48 steps per minute.

2 Check turbine tripped 2( RNO) Note: MSIV closure will be 2.1 Place main turbine emergency to TRIP required for at least 5 seconds.

2.2 IF turbine can NOT be tripped, THEN reduce GV position demand signal to zero from Ovation page 5551.

[] on GV CLOSE INTERFACE. press SELECT

[] on Popup 7079, GV MANUAL CLOSE INTERFACE press RAPID

[] on Popup 7079, GV MANUAL CLOSE INTERFACE press FUNCT ENABLE

[]on Popup 7079, GV MANUAL CLOSE INTERFACE press and hold close arrow (V) until GVs indicate CLOSED.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 4 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 2.3 IF steam flow to main turbine is NOT secured, THEN close all main steam line isolation and bypass valves.

2.4 IF any MSIV fails to close THEN place the associated test switch in the TEST position.

Note: The SRO may direct early action to open Rx trip breakers per step 7.1 (RNO) 3 Verify AFW pumps - RUNNING.

3.1 MDAFWPs - RUNNING

[] 1A amps > 0

[] 1B amps > 0 3.2 TDAFWP - RUNNING IF NECESSARY TDAFWP STM SUPP FROM 1B(1C) SG

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 at 100%

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 5 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 4 Critical Task - Emergency Initiate Emergency Boration of borate or insert rods the RCS.

4.1 IF safety injection in progress, THEN go to step 4.7.

4.2 Verify at least one CHG PUMP -

RUNNING.

4.3 Start a boric acid transfer pump.

BATP

[] 1A

[] 1B 4.4 Align normal boration.

EMERG BORATE TO CHG PUMP SUCT

[] Q1E21MOV8104 open 4.5 Establish adequate letdown.

4.5.1 Verify 45 GPM letdown orifice - IN SERVICE.

LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 6 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 4.5.2 Verify one 60 GPM letdown orifice - IN SERVICE.

LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B open

[] Q1E21HV8149C open 4.6 Establish adequate charging flow.

IF boration is from boric acid storage tank, THEN verify charging flow -

GREATER THAN 40 GPM.

OR IF boration is from the RWST, THEN verify charging flow -

GREATER THAN 92 GPM.

4.7 Verify emergency boration flow adequate.

4.7.1 IF normal emergency boration flow path aligned, THEN check emergency boration flow greater than 30 GPM.

BORIC ACID EMERG BORATE

[] FI 110

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 7 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 4.7.2 IF manual emergency boration flow path aligned, THEN check boric acid flow greater than 30 GPM.

MAKEUP FLOW TO CHG/VCT

[] BA FI 113 4.7.3 IF boration is from the RWST, THEN verify charging OR HHSI flow - GREATER THAN 92 GPM.

4.8 Check pressurizer pressure LESS THAN 2335 psig.

5 Verify containment ventilation isolation.

5.1 Verify containment purge dampers - CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 8 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 5.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 5.3 Stop MINI PURGE SUPP/EXH FAN.

6 Check SI actuated.

6.1 Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB-1 1-1 lit

[] MLB-1 11-1 lit 6 (RNO)

[CA] IF an SI signal is actuated during this procedure, THEN initiate ATTACHMENT 1, indication. AUTOMATIC SAFETY INJECTION VERIFICATION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __7__ Page 9 of 9 Event

Description:

1A SGFP trips requiring a Reactor trip and Reactor fails to trip. Requires entry into FRP-S.1. (CT-52) Turbine fails to trip in Manual and GV2 will not close. Requires the MSIVs to be shut.

Time Position Applicants Actions or Behavior Comments 7 Check the following trips.

7.1 Verify all reactor trip and and reactor trip bypass OPEN.

7.1 (RNO) Contacts the ROVER 7.1 Locally open the reactor trip reactor trip bypass breakers 7.2 MSIVs are closed Check turbine - TRIPPED.

[] TSLB2 14-1 lit

[] TSLB2 14-2 lit TURB BLDG)

[] TSLB2 14-3 lit

[] TSLB2 14-4 lit 8

[CA] Check if reactor still critical.

Check power range indication

- GREATER THAN OR EQUAL TO 5%.

PR1(2,3,4)

PERCENT FULL POWER

[] NI 41B

[] NI 42B

[] NI 43B

[] NI 44B OR Check any intermediate range startup rate - POSITIVE.

IR1(2)

S/U RATE

[] NI 35D

[] NI 36D 8 (RNO)

Go to procedure and step in effect.

At discretion of lead examiner move to next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 1 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Indications Available

- PRZR Level lowering Numerous Annunciator and alarms.

- RCS Presure lowering

- Automatic SI

-RVLIS all RED Time Position Applicants Actions or Behavior Comments Note: Once the LBLOCA Occurs, the SRO will direct the immediate operator actions of EEP-0.0. Will go to FRP-Z.1 EEP-0.0, Reactor Trip or Safety Injection, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 2 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit RO/BOP 3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

4.2 Verify both trains of SI- ACTUATED.

[] MLB1 1-1 AND MLB1 11-1 lit Per SOP-0.8, TRANSIENT RESPONSE PROCEDURE USER'S GUIDE, the operator may start CS pumps to back up ESF equipment and the Orange path may not exist.

SRO Directs entry into FRP-P.1 FRP-P.1, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK CONDITIONS, v 20 RO 1 Adverse numbers will apply.

Checjk RCS pressure - GREATER THAN Adverse number are in { }.

275psig {435psig}

RO 1(RNO)

IF LHSI flow greater than1.5x103 gpm, THEN return to procedure and step in effect.

SRO Exits FRP-P.1 and Enters FRP-Z.1 or EEP-0

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 3 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments FRP-Z.1, RESPONSE TO HIGH CONTAINMENT PRESSURE, ver 15 RO 1 Verify PHASE A CTMT ISO.

1.1 Verify PHASE A CTMT ISO -

ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 1.2 Check all MLB-2 lights - LIT.

2 Verify containment ventilation isolation.

2.1 Verify containment purge dampers - CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 2.2 Verify containment mini purge dampers - CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 2.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 4 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 3 Critical task - CS must be

[CA] Check if containment spray actuated manually. May is required. be performed earlier when recognized by operators.

3.1 Containment pressure - HAS RISEN TO GREATER THAN 27 psig. in effect.

3.2 Verify PHASE B CTMT ISO -

ACTUATED.

[] MLB-3 1-1 lit

[] MLB-3 6-1 lit 3.3 Verify containment spray pumps

- RUNNING.

3.4 Check containment spray flow in both trains - GREATER THAN 0 gpm.

CS FLOW

[] FI 958A

[] FI 958B 3.5 Check all MLB-3 lights - LIT.

3.6 Stop all RCPs.

RCP

[] 1A

[] 1B

[] 1C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 5 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 4

Verify containment fan cooler alignment.

4.1 Verify all available containment fan coolers -

STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED

[] 1A

[] 1B

[] 1C

[] 1D 4.2 Verify associated emergency service water outlet valves -

OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D 5

Verify main steam line 5 isolation and bypass valves 6

Check if feed flow should be isolated to any SG.

6.1 Return to procedure and step in effect

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 6 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-0.0, Reactor Trip or Safety Injection, ver 45 RO/BOP 5 See page below Verify actuation signal automatic actions using ATTACHMENT 2, AUTOMATIC ACTIONS VERIFICATION.

RO/BOP 6

[CA] Check containment pressure - HAS REMAINED LESS THAN 27 psig.

CTMT PRESS

[] PR 950 6(RNO)

Perform the following.

6.1 Verify PHASE B CTMT ISO -

ACTUATED.

CTMT PRESS

[] PR 950 [] MLB-3 1-1 lit

[] MLB-3 6-1 lit 6.2 Stop all RCPs.

RCP

[] 1A

[] 1B

[] 1C 6.3 Verify PHASE B CTMT ISO alignment.

6.3.1 Check All MLB-3 lights lit.

6.3.2 IF any MLB-3 light NOT lit, THEN verify PHASE B CTMT ISO using ATTACHMENT 5, PHASE B CONTAINMENT ISOL

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 7 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 6.4 Critical task - CS must be Check containment spray. actuated manually. May be done in FRP-Z.1 or by 6.4.1 operators during IOAs.

Check containment spray flow in both trains greater than 0 gpm.

CS FLOW

[] FI 958A

[] FI 958B 6.4.2 IF containment spray flow in both trains NOT greater than 0 gpm, THEN verify containment spray pump suction valves open.

RWST TO 1A(1B) CS PUMP

[] Q1E13MOV8817A

[] Q1E13MOV8817B 6.4.3 IF unable to establish spray flow in a train, THEN secure containment spray pump in affected train.

[] CS RESET TRN A(B) containment spray signals - RESET (Annunciator EE4 clear).

[] CTMT SPRAY PUMP 1A(B) -

STOPPED in affected train RO/BOP 7 Announce "Unit 1 reactor trip and safety injection."

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 8 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO/BOP 8 Check AFW status.

8.1 Check secondary heat sink available.

[] Total feed flow to SGs - pumps started.

GREATER THAN 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B TDAFWP STM SUPP

[] FI 3229C FROM 1B(1C) SG AFW TOTAL FLOW

[] FI 3229

[] Narrow range level in at least one SG - GREATER THAN 31%{48%}

8.2 WHEN all SG narrow range levels less than 31%{48%},

THEN maintain total AFW flow greater than 395 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 9 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 8.3 WHEN at least two SG narrow range levels greater than 28%

AND TDAFWP NOT required, THEN stop TDAFWP 8.4

[CA] WHEN SG narrow range level greater than 31%{48%},

THEN maintain SG narrow range level 31%-65%{48%-65%}.

8.4.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 10 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 8.4.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted RO 9 Check RCS temperature.

-IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547F.

TAVG 1A(1B,1C) RCS LOOP

[] TI 412D 9.1.1 Verify steam dumps closed.

[] TI 422D

[] TI 432D OR IF no RCP running, THEN check RCS cold leg temperature - STABLE AT OR closed.

APPROACHING 547F.

RCS COLD LEG TEMP RECORDER

[] TR 410

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 11 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 9 (RNO)

Perform the following.

9.1 IF RCS temperature less than 547F and falling, THEN perform the following. IF RCS temperature greater than 547F and rising, THEN proceed to RNO Step 9.2.

9.1.1 Verify steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[] B TRN in OFF RESET 9.1.2 Verify atmospheric reliefs closed 1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A

[] PC 3371B

[] PC 3371C 9.1.3 IF cooldown continues, THEN control total AFW flow to stop RCS cooldown.

9.1.4 IF MSIVs are closed THEN proceed to Contacts TB SO step 9.1.9 9.1.9 IF main steam lines isolated AND gland steam supplied from Unit 1, THEN break condenser vacuum.

COND VAC BKR MAN ISO (155 ft, TURB BLDG)

[] N1N51V518A open

[] N1N51V518B open COND VAC BKR VLVS

[] N1N51V519A/519B open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 12 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 9.2 This step is N/A IF RCS temperature greater than 547F and rising, THEN perform the following.

RO 10 Check pressurizer PORVs and spray valves.

10.1

[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

10.1.1 Verify both PRZR PORVs indicate CLOSED 10.1.2 Check PRZR PORV temperature STABLE OR FALLING

[] PORV Temp TI-463 10.1.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 10.2

[CA] WHEN pressurizer pressure less than 2260 psig, spray flow. THEN verify normal pressurizer spray valves closed OR closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C

[] PK 444D 10.3 Check any PRZR PORV ISO - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 13 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 11 Check RCP criteria.

11.1 Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16F{45F}

SUBCOOLED IN CETC MODE.

RO 12 Monitor charging pump miniflow criteria.

12.1 Control charging pump miniflow valves based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

[] PI 402A

[] PI 403A RO 13 Check SGs not faulted.

13.1 Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 14 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 14 Check SGs not ruptured.

- Check secondary radiation indication - NORMAL.

[] R-15 SJAE EXH

[] R-19 SGBD SAMPLE

[] R-23A SGBD HX OUTLET

[] R-23B SGBD TO DILUTION

[] R-15B TURB BLDG VNTL (BOP)

[] R-15C TURB BLDG VNTL (BOP)

[] R-60A MS ATMOS REL (BOP)

[] R-60B MS ATMOS REL (BOP)

[] R-60C MS ATMOS REL (BOP)

[] R-60D TDAFWP EXH (BOP)

- No SG level rising in an uncontrolled manner.

15 Check RCS intact.

Check containment radiation -

NORMAL.

[] R-2 CTMT 155 ft

[] R-7 SEAL TABLE

[] R-27A CTMT HIGH RANGE (BOP)

[] R-27B CTMT HIGH RANGE (BOP)

Check containment pressure -

LESS THAN 3 psig.

Check containment ECCS sump level - LESS THAN 0.4 ft.

15(RNO)

Go to FNP-1-EEP-1, LOSS OF REACTOR OR SECONDARY COOLANT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 15 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-1, LOSS OF REACTOR OR SECONDARY COOLANT, ver 31 RO 1 Check RCP criteria. RCPs will already be Check SUB COOLED MARGIN MONITOR secured indication - GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

BOP 2 Check SGs not faulted.

Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

BOP 3 Check intact SG levels.

3.1 Check any intact SG narrow range level -

GREATER THAN 31%{48%}.

3.2 WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG narrow range level 31%-65%{48%-65%}.

3.2.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD 3.2.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted Time Position Applicants Actions or Behavior Comments

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 16 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP (step 4) Check secondary radiation indication - NORMAL.

Checks rad monitors RO 5 Check pressurizer PORVs 5.1 Check any PRZR PORV ISO - power available 5.2

[CA} WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.

5.2.1

[] Verify both PRZR PORVs - CLOSED 5.2.2 Check PRZR PORV temperature STABLE OR FALLING.

[] PORV Temp TI-463 5.2.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 5.3

[] Check at least one PRZR PORV ISO -

OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 17 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments SRO 6 NOTE: These steps will be Perform the following within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of start passed off to the SSS of event.

6.1 Close recirculation valve disconnects using ATTACHMENT 1.

6.2 Establish 1A and 1B post LOCA containment hydrogen analyzers IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.

6.3 Plot hydrogen concentration on FIGURE 1.

6.4 Check containment hydrogen concentration - LESS THAN 3.5%.

6.5 Check containment hydrogen concentration - LESS THAN 0.5%.

SRO 7 Evaluate SI termination criteria 7.1 Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

7.2 Check secondary heat sink available.

[] >395 gpm AFW flow OR

[] > 31%{48%} SGNR level 7.3 Check RCS pressure - STABLE OR RISING

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 18 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 7.4 Check pressurizer level GREATER THAN 13%{43%}.

Continue to step 8 since a known LOCA exists RO 8 Check containment spray system.

8.1 Check any CS PUMP - STARTED.

8.2 Reset containment spray signals.

CS RESET

[] A TRN

[] B TRN 8.3

[CA] WHEN containment spray recirculation flow has been aligned for at least 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, AND containment pressure is less than 16 psig, THEN stop both CS PUMPs.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 19 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 9 Check if LHSI Pumps should be stopped.

9.1 Check RCS pressure - GREATER THAN 275 psig{435 psig}

[] PT-402 AND 403 9.1.1 (RNO)

Establish CCW flow to RHR Hxs CCW TO 1A(1B) RHR HX

[] Q1P17MOV3185A open

[] Q1P17MOV3185B open 9.1.2 (RNO)

Proceed to step 11 BOP 11

[CA] Verify 4160 V busses energized.

11.1 Perform ATTACHMENT 4, VERIFYING 4160 V BUSSES ENERGIZED.

RO 12 Check diesel generators.

12.1

[CA] Monitor any loaded diesel generator for proper voltage, frequency and load.

12.2

[CA] Secure any unloaded diesel generators using FNP-0-SOP-38.0,DIESEL GENERATORS.

SRO 13 Begin evaluation of plant status.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 20 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 13.1 Verify cold leg recirculation capability

- AVAILABLE.

13.1.1 Train A equipment available:

1A RHR Pump CTMT SUMP TO 1A RHR PUMP Q1E11MOV8811A CTMT SUMP TO 1A RHR PUMP Q1E11MOV8812A 1A RHR HX TO CHG PUMP SUCT Q1E11MOV8706A CCW TO 1A RHR HX Q1P17MOV3185A OR 13.1.2 Train B equipment available:

1B RHR Pump CTMT SUMP TO 1B RHR PUMP Q1E11MOV8811B CTMT SUMP TO 1B RHR PUMP Q1E11MOV8812B 1B RHR HX TO CHG PUMP SUCT Q1E11MOV8706B CCW TO 1B RHR HX Q1P17MOV3185B 13.2 Begin taking ECCS logs.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 21 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 13.3 Evaluate RCS sampling requirements.

13.3.1 Consult TSC staff to evaluate need for RCS sampling.

13.3.2 IF RCS sample required, THEN direct Chemistry to sample RCS using FNP-0-CCP-1300, CHEMISTRY AND ENVIRONMENTAL ACTIVITIES DURING A RADIOLOGICAL ACCIDENT 13.4 Check no intersystem outside CTMT.

13.4.1 Check auxiliary building radiation -

NORMAL.

[] R-3 RADIOCHEMISTRY LAB

[] R-4 1C CHG PUMP RM

[] R-5 SFP RM

[] R-6 SAMPLE RM AREA

[] R-8 DRUMMING STATION

[] R-10 PRF.

[] R-17A OR R-17B CCW 13.4.2 Check auxiliary building room sumps - HI LVL ALARMS CLEAR AND NO SUMP PUMPS RUNNING IN AUTO. (BOP)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 22 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 13.4.3 Check WHT and FDT levels -

NO EXCESSIVE OR UNEXPLAINED LEVEL RISE.

13.4.4 Check PI600A(B) 1A(1B) RHR PUMP DISCH PRESS - LESS THAN 450 psig 13.5 Verify at least one train of PRF in operation using FNP-1-SOP-60.0, PENETRATION ROOM FILTRATION SYSTEM.

13.6 Verify VCT level - GREATER THAN 5%.

RO 14 Check LHSI flow in progress.

14.1 Check RCS pressure - LESS THAN 275 psig{435 psig}.

1C(1A) LOOP RCS NR PRESS

[] PI 402B

[] PI 403B 14.2 Verify both LHSI flows - GREATER THAN 1.5x103 gpm.

1A(1B) aligned.

RHR HDR FLOW

[] FI 605A RHR PUMPS

[] FI 605B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 23 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments RO 15 Check when to transfer to cold leg recirculation.

15.1 Check RWST level - LESS THAN RWST LVL

[] LI 4075A

[] LI 4075B 15.2 Go to FNP-1-ESP-1.3, TRANSFER TO COLD LEG RECIRCULATION.

Expected exam termination point

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 24 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 2, ver 45 1

Verify one CHG PUMP in each train -

BOP STARTED.

[] A train (1A or 1B) amps > 0

[] B train (1C or 1B) amps > 0 BOP 2 Verify RHR PUMPs - STARTED.

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP 3 Verify Safety Injection Flow.

3.1 Check HHSI flow - GREATER THAN 0 gpm.

[] FI 943 BOP 3.2 Operator should proceed to Check RCS pressure - LESS THAN step 4 275 psig{435 psig}.

BOP 4 Verify each SW train - HAS TWO SW PUMPs STARTED.

[] A train (1A,1B or 1C)

[] B train (1D,1E or 1C)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 25 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 5 Verify each train of CCW - STARTED.

5.1 Verify one CCW PUMP in each train-STARTED.

A train HX 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 26 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 6 Verify containment ventilation isolation.

6.1 Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 6.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 6.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 27 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 7 Verify containment fan cooler alignment.

7.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[] 1A

[] 1B B train

[] 1C

[] 1D 7.2 Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 28 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 8 Verify AFW Pumps - STARTED.

8.1 Verify both MDAFW Pumps - STARTED

[] 1A MDAFW Pump amps > 0

[] 1B MDAFW Pump amps > 0 AND

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 29 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 8.2 Check TDAFW Pump start required.

8.3 Verify TDAFWP started.

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

8.4 Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 30 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 9 Verify main feedwater status.

Verify main feedwater flow control and bypass valves - CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[] FCV 488

[] FCV 498 9.2 Verify both SGFPs - TRIPPED.

9.3 Verify SG blowdown - ISOLATED.

1A(1B,1C) SGBD ISO

[] Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample - ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 31 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 10 Check no MSL isolation actuation signal present.

BOP 10 (RNO)

Perform the following.

10.1 Verify main steam line isolation and bypass valves closed.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYP

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 32 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 11 Verify PHASE A CTMT ISO.

11.1 Verify PHASE A CTMT ISO - ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO BOP 12 Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP 13 Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11E005A

[] N1C11E005B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 33 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 14 Secure secondary components.

14.1 Stop both heater drain pumps.

HDP

[] 1A

[] 1B 14.2 Check any condensate pump started.

14.2.1 IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 14.3 IF condensate pump operating, Will call TBSO to THEN verify backup cooling aligned to accomplish this.

condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP 15 Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN BOP 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810 - OPEN

[] 914 - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 34 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments BOP 17 Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 35 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 4, ver 45 BOP 1 Verify two trains of ECCS equipment aligned.

1.1 - 1.4

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 closed 1.5

[] Verify two trains of battery chargers -

energized

[] A Train (1A or 1C) amps > 0

[] B Train (1B or 1C) amps > 0 1.6 Verify two trains of ESF equipment aligned.

1.6.1 Check all MLB-1 lights LIT 1.6.2 Verify charging pump suction and discharge valves - OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 36 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B 1.8 WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP 1.9 Call Radside SO Verify SFP Cooling in service per SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of EEP-0, Attachment 4

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 37 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments EEP-1, LOSS OF REACTOR OR SECONDARY COOLANT ATT 4, ver 31 BOP 1 Verify 4160 V busses energized.

1.1 Check offsite power - AVAILABLE 1.2-1.5 Check the following closed DF01 DF02 DG15 DG02 1.6 Verify all RCP busses - ENERGIZED.

1.7 Check 1E 4160V bus - ENERGIZED 1.8 Check 1D 4160V bus - ENERGIZED 1.9 Establish power to 1A 600 V LC emergency section loads.

1.9.1 Place handswitch for pressurizer heater group 1A in OFF.

1.9.2 Verify open BKR EA08-1.

1.9.3 Verify closed BKRs ED08-1 and EA09-1.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___2__ Event No.: __8__ Page 38 of 38 Event

Description:

LBLOCA after exiting FRP-S.1. Neither Phase B nor Containment Spray will automatically actuate and requires manual actuation. (CT-3)

Time Position Applicants Actions or Behavior Comments 1.9.4 WHEN pressurizer heater group 1A operation is desired, THEN place HTR GRP 1A BLOCKING BYPASS SW to BYPASS.

1.9.5 IF required, THEN manually energize pressurizer heater group 1A.

1.10 Verify 1C air compressor in service.

1.11 Check INST AIR PRESS PI 4004B - -

GREATER THAN 85 psig.

1.12 Verify instrument air aligned to containment. (BOP)

IA TO PENE RM

[] N1P19HV3825 open

[] N1P19HV3885 open IA TO CTMT

[] Q1P19HV3611 open End of EEP-1 ATT 4

Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #3 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 07/21/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 3 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1 Section 4.1 - complete through step 23, Ramp on hold while investigating Feed water Dissolved Oxygen, 1B MDAFWP tagged out.

Turnover:

• 95% power, Impulse Loop not in service, MOL, Cb 977 ppm.

• Ramp to 100%. , UOP-3.1 Section 4.1 - complete through step 23.

• Ramp on hold while investigating Feed water Dissolved Oxygen

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond A (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

Event Malf. No. Event Event No.

Type* Description 1 N (BOP) Shift from 1C to 1B CCW pump running for adding oil to the 1C CCW pump.

2 cmfmalf / C (BOP) 1A Reactor Cavity Cooling fans trips.

cVH3310A_d_co1 3 cnh/ I (RO) PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can be PK4 manually closed. (P-CT) 44D-A /

4 cnh/ C (BOP) FCV-488, 1B SG FW FLOW, closes in auto. Can be manually re-FK488-A/ opened.

(P-CT) 5 malf/r R (RO) Rod F2 drops to the bottom of the core.

MAL-ROD517 TS (SRO) TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A 6 cnh/ C (RO) LK-459F, PRZR LVL, fails low.

LK459F-A 7 cmfmalf / TS (SRO) DC control power breaker for DG08, 1B DG output breaker, trips.

cBK1DG08_d_cp1 TS - 3.8.1 Cond B 8 malf/r/ M (ALL) Rod F14 drops to the bottom of the core. Requires a Reactor trip.

MAL-ROD523 Rod P10 is stuck. Emergency boration required.

preset C (RO) 9 malf/r/ M (ALL) 1C SGTR @ 300 gpm after emergency boration started in ESP-MAL-RCS4C 0.1. (CT-18, CT-19)

Terminate when RCS cooldown is completed.

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario Presets Form ES-D-1 EVENT TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-221 (Base IC-60) rst 221 0 0 Generic setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc3.txt 0 0 Freeze Xe set crxefast=0 0 0 RUN PRESETS setup Tag out 1B MDAFW pump

• irf cAFP01B_d_cd1 open 8 Rod P10 stuck

• imf mal-rod124 Triggers and Commands

MCB setup OVATION Clear OVATION alarms Place danger TAG ON 1B MDAFW Pump HS on MCB Place tag on 1B MDAFWP HS Provide a marked up copy of UOP-3.1 UOP-3.1 Section 4.1 - up through step 23 marked off Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms Unit 1 Train B Bypass & Inoperable Status Ind Panel on AFW Switch in ON EPB - AFW SYSTEM Switch in ON IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Unfreeze Xe set crxefast=1 Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0

MCB setup VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 Start of Shift from 1C to 1B CCW pump running.

exam 2 NRC 1A Reactor Cavity Cooling fans trips.

CUE imf chv3310a_d_co1 3 NRC PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can CUE be manually closed.

imf pk444d-a 10 15 4 NRC FCV-488, 1B SG FW FLOW, closes in auto. Can be CUE manually re-opened.

imf fk488-a 0 60 5 NRC Rod F2 drops to the bottom of the core. Ramp down TS CUE - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A.

imf mal-rod517 6 NRC LK-459F, PRZR LVL, fails low.

CUE imf lk459f-a 0 15 7 NRC DC control power breaker for DG08, 1B DG output CUE breaker, trips. TS - 3.8.1 Cond B imf cbk1dg08_d_cp1

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 8 NRC Rod F14 drops to the bottom of the core. Requires a CUE Reactor trip.

imf mal-rod523 Rod P10 is stuck. Emergency boration required. preset 9 NRC 1C SGTR @ 300 gpm after emergency boration started CUE in ESP-0.1.

imf mal-rcs4c 300 120 NRC END OF EXAM:

CUE RCS Cooldown completed Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen3grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 NONE REQUIRED 8 IF REQUESTED cae Turbine_Bldg_MSRs.cae (10 minutes after requested, SOP-0.0 actions for a Rx trip/Safety Injection) 9.1.7 RNO of EEP-0 cae 2015_TB_MSDP_iso.cae (5 minute after requested) 9 IF REQUESTED 3 minutes after requested - Perform step 3.4.1 of EEP-3.0 at the HSDP.

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the inform supervision) cue and that type of communications 1 NO ADDITIONAL REQUIRED 2 NO ADDITIONAL REQUIRED 3 NO ADDITIONAL REQUIRED 4 IF REQUESTED ROVER: 3 minutes after requested - No obvious problems noted with 1B FRV.

5 IF REQUESTED MAINT: We do not want you to disconnect the lift coil until troubleshooting is completed but we have determined that the use of rods in manual is acceptable.

SSS/RX ENG: Fuel preconditioning is 95%.

U2/SSS: I will perform STP-7.0 for Unit 1. (Booth Operator will use IPC and report back QPTR in 5 minutes.)

6 NO ADDITIONAL REQUIRED 7 IF REQUESTED DB SO: 3 minutes after requested - DG08 control power breaker is tripped.

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

8 IF REQUESTED TB SO: 10 minutes after requested - SOP-0.0 actions for a Rx trip/Safety Injection are complete.

RAD 1 SO: I will verify SFP cooling in service per SOP-54.0 HP: We will monitor main steam lines for high radiation using FNP-0-RCP-25, HEALTH PHYSICS ACTIVITIES DURING A RADIOLOGICAL ACCIDENT.

Chemistry: We will sample SGs for gross activity using FNP-0-CCP-31, LEAK RATE DETERMINATION.

ROVER: 3 minutes after requested - Step 3.4.1 of EEP-3.0 is complete.

Counting room: We will perform FNP-0-CCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.

Appendix D Scenario Detailed Summary Form ES-D-1 Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1 Section 4.1 - complete through step 23, Ramp on hold while investigating Feed water Dissolved Oxygen, 1B MDAFWP tagged out.

Turnover:

• 95% power, Impulse Loop not in service, MOL, Cb 977 ppm.

• Ramp to 100%. , UOP-3.1 Section 4.1 - complete through step 23.

• Ramp on hold while investigating Feed water Dissolved Oxygen

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond A (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

EVENT 1: Shift from 1C to 1B CCW pump running for adding oil to the 1C CCW pump.

Verifiable actions: The BOP opens MOV-3185A, CCW TO 1A RHR HX, Simultaneously starts the 1B CCW pump and stops the 1C CCW pump.

Event 2: The 1A Reactor Cavity Cooling fan trips.

Verifiable actions: BOP starts the 1B Reactor Cavity Cooling fan.

Event 3: PCV-444D, 1B LOOP SPRAY VLV, opens in auto Verifiable actions: RO takes manual control of PK-444D and closes it. RO may energize additional Pressurizer heaters.

(P-CT) If the RO does not close PCV-444D and control RCS pressure, a low pressure Reactor trip will occur.

(Similar to Audit) On the Audit exam the Spray valve drifts open in manual and is stuck open.

Event 4: FCV-488, 1B SG FW FLOW, closes in auto.

Verifiable actions: BOP will manually open FCV-488 and restore SGWL in the 1B SG.

(P-CT) If the BOP fails to properly control SGWL a LOLO Level Reactor trip will occur if 1 SG reaches 28% or if 1 SG reaches 82% a turbine trip will occur causing a reactor trip.

Event 5: Rod F2 (Control Bank C) will drop to the bottom of the core.

Verifiable actions: RO will use rods and boron to reduce power to <50%.

SRO - Tech Spec: 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A.

Event 6: LK-459F, PRZR LVL, fails low.

Verifiable actions: RO will have to take manual control of LK-459F or FK-122 to control pressurizer level.

Event 7: DC control power breaker for DG08, 1B DG output breaker, trips.

Verifiable actions: SRO Tech Spec: 3.8.1 Cond B Event 8: F14 Rod drops to the bottom of the core which requires a Reactor trip. Rod P10 is stuck and an Emergency boration required.

Verifiable actions: RO emergency borates for one rod stuck.

Event 9: A 300 gpm SGTR develops on the 1C SG.

Verifiable actions: Isolate the ruptured SG (CT-18) and Control Initial RCS cooldown (CT-19).

Similar to Audit - Audit exam is 450 gpm leak and on the 1A SG which does not require isolation of the TDAFWP steam supplies at the HSDP.

Terminate when RCS cooldown is completed.

Appendix D Scenario Critical Tasks Form ES-D-1

_____ 1. Isolate feedwater flow into and steam flow from the ruptured SG before a transition to ECA-3.1 occurs. Failure would be a required transition to ECP-3.1.

(CT-18)

_____ 2. Establish/maintain an RCS temperature so that transition from E-3 does not occur because the RCS temperature is in either of the following conditions:

Too high to maintain minimum required subcooling.

OR Below the RCS temperature that causes an extreme (RED path) or a severe (ORANGE path) challenge to the subcriticality and/or the integrity CSF. (CT-19)

SCENARIO At power power instrument and component failures with a SGTR.

OBJECTIVE/ The team should be able to:

OVERVIEW:

• BOP will shift running CCW pumps

• respond to a tripped Rx Cavity Cooling fan

• respond to a failure of B loop Spray Valve

• respond to a failed Feedwater Regulating Valve

• ramp down in response to a dropped control rod

• respond to LK-459F failing low.

• evaluate Technical Specifications for a tripped control power breaker

• trip the Rx in response to a second dropped rod

• emergency borate due to a stuck rod

• isolate a SG and cooldown the plant in response to a SGTR Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 1

2. Abnormal events (2-4) 5

3. Major transients (1-2) 2

4. EOPs entered/requiring substantive actions (1-2) 1

5. EOP contingencies requiring substantive actions (0-2) 0

6. Critical tasks (2-3) 4

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 1, 95% RTP, 977 ppm Cb, MOL 10000 MWD/MTU, -2181 pcm Xe A Trn O/S / A Trn Protected / SFPC on A Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 167 hours0.00193 days <br />0.0464 hours <br />2.761243e-4 weeks <br />6.35435e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. Start 1B CCW Pump and secure 1C CCW pump in preparation for oil addition to 1C CCW pump prior to ramp.

3. UOP-3.1, Section 4.1 through Step 23 is complete.

4. Impulse loop is NOT in service.

5. Ramp is on hold while Chemistry investigates Feedwater Dissolved Oxygen.

6. 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

7.

8.

9.

10.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas) 1B MDAFW pump - 3.7.5 Cond B LCO status (planned- entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago) #1 RHT Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __1___ Page 1 of 2 Event

Description:

Shift from 1C to 1B CCW pump running for oil addition to 1C CCW pump.

Indications Available N/A Time Position Applicants Actions or Behavior Comments SOP-23, COMPONENT COOLING WATER SYSTEM, ver 94.2 BOP 4.7 Shifting CCW Pumps on the On-Service Train BOP 4.7.1 Monitor CCW flow annunciators and RCP thermal barrier valves during and after this evolution.

BOP 4.7.2 IF A Train is the on service train, THEN open CCW TO 1A RHR HX Q1P17MOV3185A.

BOP 4.7.3 This step is N/A IF B Train is the on service train, THEN open CCW TO 1B RHR HX Q1P17MOV3185B.

BOP 4.7.4 Simultaneously start the Standby CCW pump and stop the on service CCW pump.

BOP 4.7.5 Verify the proper flow response on the appropriate flow indicator.

FI 3043AA FI 3043BA, FI 3043CA BOP 4.7.6 IF A Train is the on service train, THEN close CCW TO 1A RHR HX Q1P17MOV3185A unless required to support RHR operation.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __1___ Page 2 of 2 Event

Description:

Shift from 1C to 1B CCW pump running for oil addition to 1C CCW pump.

Time Position Applicants Actions or Behavior Comments BOP 4.7.7 This step is N/A IF B Train is the on service train, THEN close CCW TO 1B RHR HX Q1P17MOV3185B unless required to support RHR operation.

BOP 4.7.8 This step is N/A IF placing 1B CCW pump in service to replace an inoperable CCW pump, THEN perform one of the following.

(Otherwise 1B CCW pump will not sequence on following a SI/LOSP)

At the discretion of the Lead Examiner, move to the next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __2___ Page 1 of 2 Event

Description:

1A Reactor Cavity Cooling fans trips.

Indications Available

- BD1, 1A RX CAV CLG FAN FAULT

- BD3, BOTH RX CAV CLG FANS STOPPED Time Position Applicants Actions or Behavior Comments ARP-1.2, BD3, BOTH RX CAV CLG FANS STOPPED BOP 1 IF one of the reactor cavity cooling fans has tripped, THEN start the other fan.

BOP 2 This step is N/A IF no cavity cooling is available, then the unit should be shutdown to at least hot standby within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. Subsequent monitoring of the cavity area around the NI's is then needed to determine if further cooldown is needed.

3 Reviews SOP-12.1, for any Refer to FNP-1-SOP-12.1, additional actions (there are CONTAINMENT AIR COOLING SYSTEM. none) 4 Notify appropriate personnel to locate and Contacts SSS to write CR correct the cause of the alarm as soon as etc possible.

ARP-1.2, BD1, 1A RX CAV CLG FAN FAULT, ver 45 BOP 1 Start 1B RX CAV CLG FAN.

BOP 2 Fan is not running IF still running, THEN stop 1A RX CAV CLG FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __2___ Page 2 of 2 Event

Description:

1A Reactor Cavity Cooling fans trips.

Time Position Applicants Actions or Behavior Comments BOP 3 IF no cavity cooling is available, THEN the unit should be shutdown to at least hot standby within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

Subsequent monitoring of the cavity area around the NI's is then needed to determine if further cooldown is needed.

4 Refer to FNP-1-SOP-12.1, Reviews SOP-12.1, for any CONTAINMENT AIR COOLING SYSTEM. additional actions (there are none) 5 Refer to FNP-1-ARP-1.2, Location BD3, if Goes to BD3 if not done no Reactor Cavity Cooling Fan running.

6 Notify appropriate personnel to locate and Contacts SSS to write CR correct the cause of the alarm etc as soon as possible.

At discretion of Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __3___ Page 1 of 3 Event

Description:

PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can be manually closed. (P-CT).

Indications Available

- RCS Pressure lowers - HD1, PRZR PRESS REL VLV 445A OR B/U

- PCV-444D demand goes to 100% HTRS ON, in ALARM

- PCV-444D light go OUT Time Position Applicants Actions or Behavior Comments RO Announce alarm and/or recognizes malfunction and takes immediate operator action SRO Direct entry in AOP-100 if not done by operators AOP-100, INSTRUMENTATION MALFUNCTION, ver 15 RO 1 IF required to stabilize RCS pressure, Immediate operator action.

THEN take manual control of the following equipment. Potential Critical Task - If

• Power operated relief valves PCV-444D not closed a

[ ] PRZR PORV Q1B31PCV445A low pressure Rx trip will

[ ] PRZR PORV Q1B31PCV444B occur OR If RCS pressure fall below

[ ] PRZR BLOCK VLV Q1B31MOV8000A 2209 psig then LCO - 3.4.1

[ ] PRZR BLOCK VLV Q1B31MOV8000B will be entered - Page 3

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __3___ Page 2 of 3 Event

Description:

PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can be manually closed. (P-CT).

Time Position Applicants Actions or Behavior Comments RO 2 IF pressurizer pressure is decreasing This step is N/A due to a mechanically stuck open spray valve PCV444C or PCV444D, THEN perform the following:

RO 3 This step is N/A IF PORV is open and pressurizer pressure is less than 2310 psig, THEN close the PORV.

RO 4 This step is N/A IF an alarm was caused by a CONTROL instrument (PT-444/445) OR component failure, THEN perform the following as required to restore RCS pressure to desired value.

RO 5 This step is N/A IF a PROTECTION instrument failure has occurred, THEN determine which pressure channel has caused the alarm.

SRO 6 LCO-3.4.1 may apply Refer to Tech Specs for LCO requirements that exist.

SRO 7 Notify the Shift Manager. Contacts SM 77 8

[CA] WHEN plant conditions permit, THEN restore components to automatic control.

8 9

Submit a Condition Report and notify the Work Week Coordinator (Maintenance Has RO/BOP contact ATL on backshifts). appropriate personnel

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __3___ Page 3 of 3 Event

Description:

PCV-444D, 1B LOOP SPRAY VLV, opens in auto. Can be manually closed. (P-CT).

Time Position Applicants Actions or Behavior Comments RO 10 This step is N/A IF the pressurizer power operated relief valves operated, THEN perform the following:

SRO 11 Go to procedure and step in effect.

TECHNICAL SPECIFICATION 3.4.1 - RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits 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 the COLR. The minimum RCS total flow rate shall be 263,400 GPM when using the precision heat balance method, 264,200 GPM when using the elbow tap method, and the limit specified in the COLR.

APPLICABILITY: MODE 1.

Condition A SRO CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore RCS DNB RCS DNB parameter(s) to within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> parameters not limit.

within limits..

At discretion of Lead Examiner, move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __4___ Page 1 of 3 Event

Description:

FCV-488, 1B SG FW FLOW, closes in auto. Can be manually re-opened. (P-CT).

Indications Available

- FCV-488 demand goes to 0 The following in ALARM

- 1B SGWL lowering JF2, 1B SG LVL DEV JG1, 1A SG FEDD FLOW>STM FLOW JG3, 1C SG FEDD FLOW>STM FLOW JB2, 1b SG STM FLOW > FEED FLOW Time Position Applicants Actions or Behavior Comments BOP Announces alarms and/or recognizes malfunction and take immediate operator actions of AOP-100 SRO Direct AOP entry if not performed by operators AOP-100, INSTRUMENTATION MALFUNCTION, ver 15 BOP 1 Potential critical task -

[CA] Maintain SG level at the referenced Loss of SGWL control will level of 65%. result in an automatic Rx 11 trip or a los of feed 1.1 requiring a Rx trip.

IF required, THEN, take manual control of SGFP speed control as necessary to restore SG level to 65%

.1 SGFP master controller

[ ] SK-509A OR SGFP individual controllers as needed.

[ ] SK-509B

[ ] SK-509C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __4___ Page 2 of 3 Event

Description:

FCV-488, 1B SG FW FLOW, closes in auto. Can be manually re-opened. (P-CT).

Time Position Applicants Actions or Behavior Comments 1.2 IF required, THEN take manual control of the affected feedwater regulating valves or bypass valves.

1.2

[ ] 1A SG FW FLOW FK-478

[ ] 1B SG FW FLOW FK-488

[ ] 1C SG FW FLOW FK-498 OR

[ ] 1A SG BYPASS FLOW FK-479

[ ] 1B SG BYPASS FLOW FK-489

[ ] 1C SG BYPASS FLOW FK-499 1.3 A loss of main feedwater IF a loss of main feedwater has occurred, will not occur if the FRV is THEN perform the actions required by opened FNP-1-AOP-13.0, LOSS OF MAIN FEEDWATER.

SRO 2 Normal trip criteria is 80%

IF adverse trend in SG level exists, rising and 30% lowering THEN establish trip criteria.

2 BOP 3 IF a ramp is in progress, THEN place Turbine on HOLD.

4 This step is N/A Determine if an instrument failure has occurred.

4 4.1 Check for a failed or erroneous indications from the following steam flow or feed flow indicators.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __4___ Page 3 of 3 Event

Description:

FCV-488, 1B SG FW FLOW, closes in auto. Can be manually re-opened. (P-CT).

Time Position Applicants Actions or Behavior Comments 4.2 This step is N/A Check for failed or erroneous readings on the following SG pressure indicators:

4.3 This step is N/A IF the alarm(s) was due to a SGWLC System controlling channel failure, THEN select the unaffected channel for STM FLOW AND FW FLOW for the SG associated with the failure.

5 No LCO entries Refer to Tech Specs 3.3.1, 3.3.2 & 3.3.3 for any LCO requirements.

SRO 6 Contacts SM Notify the Shift Manager.

7 N/A

[CA] WHEN plant conditions permit, THEN return systems to automatic control.

7 Directs RO/BOP to contact SRO 8 appropriate personnel Submit a condition report for the failed instrument, and notify the Notify the Work Week Coordinator (Maintenance ATL on backshifts)of the condition report.

8 SRO 9 Go to procedure and step in effect.

At discretion of Lead Examiner, move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 1 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Indications Available

- Rx power initially lowers The following ALARMS -

- Neg SUR FE3, ROD AT BOTTOM

- RCS pressure lowering FF5, COMP ALARM ROD SEQ/DEV OR PR

- tavg LOWERING FLUX TILT FB4, PR UPPER DET HI FLUX DEV OR AUTO DEF FB5, PR LOWER DET HI FLUX DEV OR AUTO DEF FC5, PR CH DEV Time Position Applicants Actions or Behavior Comments RO Announces alarms and dropped rod SRO Enters AOP-19 Note: AOP-19 allows entry into specific sections based on malfunction AOP-19, MALFUNCTION OF ROD CONTROL SYSTEM BOP 1 Stop any turbine loading changes.

RO 2 Check the following:

-DRPI - AVAILABLE.

-Only one Rod dropped by observing DRPI.

3 Check rod misaligned greater than 45 steps.

4 Cond B Initiate TS 3.1.4.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 2 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments 5 RO / BOP coordinates the Maintain Tavg at program by performing restoring Tavg to Tref -

the following as appropriate: Page 10 3.4 Adjus t Turbine loa d.3.4 Dilute or bora te . 3.4 Us e m a nua l Rod control.

RO 6 Maintain power distribution when greater than or equal to 50% power:

4 6.1 AFD - WITHIN LIMITS SPECIFIED IN THE COLR.

6.2 QPTR - LESS THAN OR EQUAL TO 1.02.

6.2 RNO Initiate TS 3.2.4 TS 3.2.4 at Page 7 SRO 7 Perform the following:

7.1 Initiate action to determine cause and repair Rod Control malfunction.

7.2 With Maintenances concurrence Maintenance will request disconnect lift coil for the dropped rod. the lift coil NOT operated

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 3 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments RO 8 Record the following in the Unit Control Log.

Re cord the following in the Unit Control Log.

Droppe d Rod numbe r.

Initia l P owe r Le ve l.

Affe cte d group s te p counte r pos ition.

RO 9 FC3 is clear & bistables not Check Annunciator FC3, PR Hi Flux illuminated Rate Alert is clear.

TS LB-2 NI Hi rate bistables not illuminated.

RO/BOP 10 See Event 6 for Ramp Reduce Thermal Power to less than 75%

within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from time of Rod drop using FNP-1-UOP-3.1, POWER OPERATION.

NOTE: Step 10 and event 6 run concurrently - Event 7 & 8 will be inserted as desired by Lead Examiner after desired ramp and demonstration of use of SOP-2.3 APP A SRO 11 Contact SSS or RX Check fuel preconditioned power level Engineering. Fuel is greater than or equal to 90% per Reactor preconditioned to 95%

Engineering.

11.1 Continue power reduction to less than 50% RTP as soon as possible.

Once 5% ramp is performed and event 6 &

7 are completed then at NRC CUE - insert 2nd Rod drop Event 8

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 4 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments 12 Check if rod retrieval should be initiated:

12.1 Time of dropped rod known.

12.2 Direct cause of dropped rod known and corrective action taken.

12.2 (RNO)

Perform the following:

12.2.1 Consult Reactor Engineering and Operations Management.

12.2.2 Do not continue until one of the following is satisfied:

a) IF recovery plan developed to retrieve dropped rod, THEN continue with Step 13.

-OR-b)

IF decision made to initiate a unit shutdown, THEN go to FNP-1-UOP-3.1, POWER OPERATION.

ARP-1.6, FF5, COMP ALARM ROD SEQ/DEV OR PR FLUX TILT, ver 72.1 BOP 1 N/A IF a plant transient is in progress, THEN place turbine load on "HOLD.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 5 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments RO/SRO 2 IF rod control is in automatic, THEN Determines a dropped rod determine whether rod sequence is proper occurs or improper.

2.1 If not in manual then places IF rod sequence is improper, THEN rods in Manual transfer to manual rod control.

2.2 Refer to FNP-1-AOP-19.0, AOP-19 already in progress MALFUNCTION OF ROD CONTROL SYSTEM.

RO/SRO 3 Determine cause of the alarm 3.1 IF the IPC is available, THEN using the Applications Menu, click on IPC Annunciation button.

3.2 Click on RODS displayed under WINDOW FF5, to determine cause of validity of the alarm.

3.3 Using the Applications Menu, click on IPC Annunciation button.

3.4 A tilt exists Click on TILT displayed under WINDOW FF5, to determine cause of validity of the alarm.

3.5 Note the time of the alarm from the IPC ALARM display.

3.6 Start a manual timer to alarm within 45 minutes of the time recorded in the above step.

3.7 IF the plant computer is inoperable to any Emergency Response Facility THEN restore plant computer within TRM 13.13.1 time limit.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 6 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments 3.8 Calls U2 or SSS to perform IF the plant computer is inoperable OR annunciator FF5 is otherwise inoperable, THEN within one hour perform FNP-1-STP-37.0, POWER DISTRIBUTION SURVEILLANCE (PLANT COMPUTER INOPERABLE) and all appropriate data sheets. {CMT 0008883}

RO/SRO 4. Tilt exists Determine if a Quadrant Power Tilt exists.

5. Dropped rod exists IF a Quadrant Power Tilt exists, THEN check indications for a dropped or misaligned Rod.

6. Already in AOP-19 IF a Rod Misposition exists, THEN refer to FNP-1-AOP-19.0, MALFUNCTION OF ROD CONTROL SYSTEM.

RO/SRO 7.

Closely monitor individual rod position during control rod movement to ensure correct rod control system and control rod position indicator response.

(NSAL-93-007) 8.

Notify appropriate personnel to determine Contacts SM, SS etc and correct the cause of the Rod Control System malfunction.

9. Tech Specs on Page 7 Refer to the Technical Specifications sections on Power Distribution Limits and Reactivity Control.

10.

Refer to TRM 13.13.1 for loss of event N/A assessment capability for the TSC if the IPC Host link goes down or the IPC is non-functional.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 7 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A TECHNICAL SPECIFICATION 3.1.4 Rod Group Alignment Limits 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.

APPLICABILITY: MODES 1 and 2.

Condition B SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One rod not B.1 Restore rod to within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within alignment limits.

alignment limits. OR B.2.1.1 Verify SDM to be 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within the limits provided 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 B.2.2 Reduce THERMAL 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> POWER to 75% RTP.

AND B.2.3 Verify SDM to be within Once per the limits provided in the 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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.

AND 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> B.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 8 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A TECHNICAL SPECIFICATION 3.2.4 QUADRANT POWER TILT RATIO (QPTR)

LCO 3.2.4 The QPTR shall be <1.02.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP.

Condition A CONDITION REQUIRED ACTION COMPLETION TIME A. QPTR A.1 Limit THERMAL 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after each QPTR POWER to 3% below determination not within RTP for each 1% of limit QPTR > 1.00.

AND A.2 Determine QPTR. Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND A.3 Perform SR 3.2.1.1 and 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after achieving equilibrium SR 3.2.2.1. conditions with THERMAL POWER AND limited by Required Action A.1 AND Once per 7 days thereafter A.4 Reevaluate safety Prior to increasing analyses and confirm THERMAL POWER results remain valid for above the limit of duration of operation Required Action A.1 under this condition.

AND A.5

---

NOTES-----------

1. Perform Required Action A.5 only after Required Action A.4 is completed.

2. Required Action A.6 shall be completed if Required Action A.5 is performed.

Normalize excore Prior to increasing detectors to restore THERMAL POWER QPTR to within limits. above the limit of AND Required Action A.1 A.6

---

NOTE------------

Perform Required Action A.6 only after Required Action A.5 is completed.

---

24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after achieving equilibrium Perform SR 3.2.1.1 and conditions at RTP SR 3.2.2.1. OR Within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after increasing THERMAL POWER above the limit of Required Action A.1

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 9 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A TECHNICAL SPECIFICATION 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits 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 the COLR. The minimum RCS total flow rate shall be 263,400 GPM when using the precision heat balance method, 264,200 GPM when using the elbow tap method, and the limit specified in the COLR.

APPLICABILITY: MODE 1.

---

NOTE------------------------------------------------------

Pressurizer pressure limit does not apply during:

a. THERMAL POWER ramp > 5% RTP per minute; or

b. THERMAL POWER step > 10% RTP.

Condition A CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RCS DNB A.1 Restore RCS DNB parameter(s) 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> parameters not within to within limits. limit.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 10 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments SOP-41.0, Control Rod Drive and Postion Indication System, Ver 37 OPERATOR AID FOR CONTROL ROD MOVEMENT RO 1 Place ROD CONTROL BANK SELECTOR SWITCH in MAN.

RO 2 Check indicated control rod speed is approximately 48 steps per minute on SI-408.

RO 3 Insert OR withdraw Control Rods using the CONTROL ROD MOTION switch.

RO 4 When desired, place rod control in AUTO as follows:

RO 4.1 Verify Tavg within 1°F of Tref.

RO 4.2 Place the ROD CONTROL BANK SELECTOR SWITCH in AUTO.

RO 4.3 Check indicated control rod speed is approximately 8 steps per minute on SI-408.

UOP-3.1, Power Operation, Section 4.4, ver 122 BOP 1 Review and perform the following as required

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 11 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments BOP a This step is N/A If Turbine Overspeed Test is to be performed, Refer To Section 3.0 Precaution and Limitation 1.l prior to commencing ramp...

BOP b For normal load reductions, a ramp rate restriction of 2 MW/min (14% per hour) will apply............................................................

BOP c This step is N/A When conditions warrant a ramp rate of greater than 2 MW/min, notify the Shift Manager as soon as conditions permit.

BOP d This step is N/A Enter FNP-1-AOP-17.1, RAPID TURBINE POWER REDUCTION in conjunction with this procedure for ramp rates greater than 5 MW/min.........

BOP e This step is N/A Ramp as slow as possible if known fuel leak exists. Power decreases should follow the guidance found in Attachment 1, Special Load Rate Limitations.

BOP f This step is N/A If a power reduction is being performed due to entry into Technical Specifications 3.4.16, adjust the ramp rate to meet the shutdown requirements of the specification.

BOP g This step is N/A If a reactor shutdown is NOT for a refueling outage, record criticality data in the Control Room Log prior to load decrease.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 12 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments BOP h Maintain valve position limit 115% while ramping or at 100%.

BOP i This step is N/A Maintain valve position 8 to 10% above valve position demand when holding for more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at some power level less than 100%.

BOP j This step is N/A Flush and sample AFW pump suction piping as required by FNP-1-SOP-22.0, Auxiliary Feedwater System, prior to initiation of AFW flow to the SGs.

BOP 2 BOP place IMP loop in While ramping between 97% and 20% service per step 2 power, verify the IMP PRESS LOOP in service as follows:

BOP a Verify Turbine on HOLD. ..............

BOP b Check Ovation point, 1ST STG IMPLS PRESS, has stable indication.

BOP c On LOOP STATUS of page 5551, press SELECT BOP d On popup 7053, press IMP BOP e On popup 7059, press IMP LOOP IN.

BOP f On LOOP STATUS of page 5551, check IMPULSE displays YES

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 13 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments BOP 3 On page 5551, perform the following to set desired load target and load rate.................

a On RAMP INTERFACE section, press MODIFY b

On TARGET SELECTION section of BOP inserts ramp to <48%

popup 7055, enter desired target using one of the following methods:

• Using predefined buttons.

• Using CUSTOM button to enter custom rate c

On RAMP INTERFACE section of page 5551, check desired target appears under TARGET.

d On page 5551, check HOLD button has gold background e

IF desired to change load rate, on RAMP INTERFACE section of page 5551 press MODIFY.

(1)

On popup 7055, enter desired rate by either of the following Using predefined buttons.

Using predefined buttons.

(2)

On RAMP INTERFACE section of page 5551, check desired rate appears under RATE.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 14 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments 4

Inform other Control Room operators load will be changed.

5 Press GO to commence ramp.

BOP 6 Verify proper SGFP speed control.

RO 7 Attempt to maintain the axial flux difference within + 5% from the target value by making adjustments in rod height and/or boron concentration as necessary..........

RO Uses Borations to lower Tavg during the ramp SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix B, v60.1 RO 1.1 From reactivity briefing IF necessary, THEN set the boric acid sheet integrator to the desired quantity.

RO 1.2 IF necessary, THEN adjust LTDN TO VCT FLOW LK 112 setpoint as desired.

1.3 Position the MKUP MODE CONT SWITCH to STOP.

1.4 Position the MKUP MODE SEL SWITCH to BOR.

1.5 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 15 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments RO 1.6 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.7 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.8 This step is N/A If desired to clear the line of acid, perform the applicable steps of Appendix B Section 2.0.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 16 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments Note: If the crew decides to remain lined up for repetitive borations, then steps 1.9 -

1.11 are N/A. Repetitive boration steps are listed in Appendix C below.

RO 1.9 Position the MKUP MODE SEL SWITCH to AUTO.

1.10 Position the MKUP MODE CONT SWITCH to START.

1.11 IF LK 112 setpoint was adjusted per Step 1.2, THEN return setpoint to that required for current conditions.

SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix C, v60.1 RO 1.1 IF necessary, THEN set FIS-113 Boric Acid Batch Integrator to the desired quantity.

1.2 The Reactor Makeup Control system has been previously aligned for Boration.

1.3 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __5___ Page 17 of 17 Event

Description:

Rod F2 drops to the bottom of the core. Ramp down required.

TS - 3.1.4 Cond B, 3.2.4 Cond A, 3.4.1 Cond A Time Position Applicants Actions or Behavior Comments RO 1.4 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.5 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.6 IF repetitive borations are no longer required THEN verify the system is aligned for Automatic makeup per Steps 1.9 through 1.11 of Appendix B.

After the ramp or at the Lead Examiners discretion then move to the next event.

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 1 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Indications Available:

FI-122 goes to 0 gpm The following alarms LK-459F demand goes to 0 EA2 - CHG HDR FLOW HI-LO Pzr Level lowers DE1 - REGEN HX LTDN FLOW DISCH TEMP HI DC4 - SEAL WTR INJ FILTER HIGH DP Time Pos. Expected Actions/Behavior Comments SRO Direct BOP to reference ARPs BOP Performs actions of ARPs (most probably addresses ARPs by priority first)

ARPs direct entry into AOP-16.

When LK-459F failure recognized, AOP-100 will be recommended.

AOP-100, Instrumentation Malfunction, version 15, section 1.2 SRO SRO will direct entry to AOP-100. This is an expected action Place ramp on HOLD but not procedurally required by AOP-100, sect 1.2 RO 1 Checks pressurizer level on or trending to program value. (Actual PRZR level increasing)

RNO: manual control of charging flow taken

- FK-122, CHG FLOW CONTROLLER, in manual and charging flow reduced

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 2 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 1 (RNO) Take manual control of Pzr If required, THEN take manual control level using either controller of charging.

FK-122 in Manual LK-459 in Manual RO 2 Check RCP seal injection flows

- Adjusts SI flow to 6-13 gpm by using HIK-186, SEAL WTR INJECTION CONTROLLER.

SRO/ 3 Determines that no Level RO Determine if a PRZR level transmitter / instrument has failed indicator loop has failed.

LI-459, LI-460, or LI-461 SRO/ 4 RO Check letdown in service Letdown in service in

- Orifice isolation valves one or more service unless isolated due open HV-8149A,B,C, LTDN ORIF to loss of charging flow then ISO VLVS the RNO applies. Otherwise

- Flow indicated on FI-150, LTDN HX go to Step 4.2 (pg 5)

OUTLET FLOW.

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 3 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 4 (RNO)

Establish normal letdown as follows.

a)

Verify closed all letdown orifice isolation valves.

LTDN ORIF ISO 45 GPM

[ ] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[ ] Q1E21HV8149B

[ ] Q1E21HV8149C RO b)

Place LTD HX OUTLET TEMP TK 144 on service:

[ ] Place controller in AUTO

[ ] Set to maintain temperature 90°F (Pot setting 2.7) to 115°F (Pot setting 4.35) 4.3 c)

Verify VCT HI LVL DIVERT VLV LCV-115A alignment:

[ ] Position indicator VCT light - LIT

[ ] Handswitch in - AUTO d)

Verify LTDN HI TEMP DIVERT LVL Q1E21TCV143:

[ ] Handswitch in - VCT

[ ] VCT light - LIT

[ ] DEMIN light - NOT LIT

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 4 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments e) This is N/A IF necessary, THEN OPEN both LTDN LINE PENE RM ISO's Q1E21HV8175A and B from the Penetration Room Isolation Panel.

f)

Verify open LTDN LINE CTMT ISO Q1E21HV8152 g)

Verify open both LTDN LINE ISO Q1E21LCV459 and Q1E21LCV460.

h)

Verify LP LTDN PRESS PK 145 in MANUAL and adjust the demand signal to 50% or less.

i)

Verify CHG FLOW FK 122 is in MAN AND establish the required minimum charging flow for one orifice to be placed on service. (18 gpm) j)

OPEN LTDN ORIF ISO 60 GPM Q1E21HV8149B or C to establish approximately 60 gpm Letdown flow. This is N/A k)

IF letdown flow was lost with auxiliary spray in service, THEN refer to TRM 13.4.2.

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 5 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 4.2 If Letdown was not Check Letdown flow indicated. removed, this is the next 4.2 step after 4.1

[ ] FI-150 LTDN HX OUTLET FLOW.

RO 4.3 Proceed to step 6.

RO 5 Check Letdown flow established.

5.1 Check Letdown flow indicated. 5.1 5.1

[ ] FI-150 LTDN HX OUTLET FLOW.

5.2 IF Letdown flow established, THEN place LP LTDN PRESS PK-145 in AUTO as follows:

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 6 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 5.2.1 Verify that LP LTDN PRESS PK 145 is set between 4.3-7.5 to maintain the desired Letdown Pressure between 260-450 psig.

5.2.2 Place LP LTDN PRESS PK 145 in AUTO and verify that Letdown pressure is maintained at the desired value.

5.2.3 Verify that LTDN HX OUTLET TEMP TK 144 is maintaining Letdown temperature at approximately 100F.5.2.32.3

[ ] TI-116 VCT TEMP

[ ] TI-143 DIVERT LTDN HX TEMP

[ ] TI-144 CCW LTDN HX TEMP 5.2.4 See FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION, for further guidance on Charging or Letdown system.

SRO 6 N/A Refer to Tech Specs 3.3.1 & 3.3.3 determine any LCO requirements.

SRO 7 Notify Shift Manager

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 7 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO (step 8) WHEN plant conditions permit THEN restore components to automatic control as follows:

8.1 This step is N/A Restore charging flow control to automatic per FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION.

8.18.1 8.2 Restore control of pressurizer heaters. .2

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP SRO (step 9) Submit a Condition Report for failed channel and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the Condition Report.

SRO 10 Go to procedure and step in effect.

At the discretion of the Lead Examiner move to the next event

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 8 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments AOP-16, CVCS Malfunction, Ver 20 RO 1 Charging is not adequate Verify CHG flow adequate to cool letdown

[] CHG FLOW - FI-122A

[] LTDN HX OUTLET FLOW - FI-150

[] REGEN HX OUTLET TEMP - TI-140 RO 1 (RNO)

Isolate Normal Letdown as follows:

1.1 Verify closed all LTDN ORIF ISOs:

[] Q1E21HV8149A

[] Q1E21HV8149B

[] Q1E21HV8149B RO 2 Stop any load change in progress RO 3 This step is N/A If charging line rupture occurs then go to attachment 2 4

Monitor VCT level Indicates proper operation 5

Observe CHG HDR PRESS and MOTOR charging pump is running AMPS to ensure proper charging pump operation PI-121 and ammeter for chg pump 6

Check charging pump - RUNNING

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 9 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 7 FK-122 is ZERO demand Check charging flow FK-122 controlling in AUTO with flow indicated RO 7(RNO)

Take manual control of charging flow 7.1 Place FK-122 in manual 7.2 Adjust SEAL WTR INJECTION HIK_186 as required to maintain RCP seal inection flow 6-13 gpm 7.3 If manual control of charging not This step is N/A accomplished.

Refer to attachment 1. MANUAL CONTROL OF CHARGING 8

Check to following annunciator -CLEAR

[] DE3 LTDN ORIF ISO VLV REL LINE TEMP HI 9

Determine Status of Normal Letdown:

9.1 Check normal CVCS letdown -

AFFECTED BY MALFUNCTION

• LTDN HX OUTLET FLOW, FI-150 - NO FLOW INDICATED

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 10 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 11 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 9.2 Minimize RCS makeup:

9.2.1 Manually close FK-122 9.2.2 Minimize seal injection between 6-13 gpm 9.2.3 Direct Chemistry to shutdown the zinc addition system (ZAS)

RO 9.3 Dispatched personnel earlier Dispatch personnel to investigate cause of letdown malfunction RO 9.4 This step is N/A If desired due to plant conditions, place excess letdown on service RO 10 Determine if normal letdown should be re-established:

10.1 Check normal letdown malfunction(s) -

CORRECTED 10.2 Verify all letdown orifice isolation valves -

CLOSED LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 12 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 10.3 Place LTDN HX OUTLET TEMP TK-144 on service:

[] Place controller in AUTO

[] Set to maintain temp 90 (Pot setting 2.7) to 115°F (Pot setting 4.35)

RO 10.4

[] Position indicator VCT light - LIT

[] Handswitch in-AUTO RO 10.5 Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143

[] Handswitch in - VCT

[] VCT light - LIT

[] DEMIN light - NOT LIT RO 10.6 This is N/A IF necessary, THEN OPEN both LTDN LINE PENE RM ISOs from the Penetration Room Isolation Panel.

[] Q1E21HV8175A

[] Q1E21HV8175B RO 10.7 Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN RO 10.8 Verify LTDN LINE ISO valves - OPEN

[] Q121LCV459

[] Q121LCV460 RO 10.9 Verify LP LETDN PRESS PK 145 on service:

[] Place controller in MANUL

[] Adjust demand signal o 50% or less

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 13 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 10.10 Initiate minimum charging flow:

10.10.

Verify CHG FLOW FK 122 in MAN 10.10.2 Establish minimum charging flow based on orifices to be placed on service:

• 1 Orifice - 18 gpm or

• 2 Orifices - 40 gpm RO 10.11 Establish approx. 60 gpm letdown flow by OPENING:

Q1E21HV8149B OR Q1E21HV8149C RO 10.12 If desired place the second orifice on service by opening Q1E21HV8149A RO 10.13 Very time consuming and will Initiate actions to restore letdown flow to not be done during the demins per SOP-2.1 scenario

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 14 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 10.14 IF all backup heaters energized due to pzrr level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing RO 10.15 Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure - BETWEEN 260-450 psig 10.15.1 Set controller between 4.3 and 7.5 10.15.

Check letdown flow - STABLE 10.15.3 Place PK 145 in AUTO 10.15.4 Control Letdown pressure as desired RO 10.16 Control LTDN HX OUTLET TEMP TK 144 to maintain Letdown temperature 90 to 115°F

[] TI-116 VCT TEMP

[] TI-143 DIVERT LTDN HX TEMP

[] TI-144 CCW LTDN HX TEMP RO 10.17 Refer to SOP-2.1 for further guidance on Letdown system control RO 11 Determine status of letdown flow:

11.1 Check letdown flow - ESTABLISHED

• Normal letdown flow OR

• Excess letdown flow

Appendix D Operator Action Form ES-D-2 Op-Test No.: FA2015301 Scenario No.: __3___ Event No.: __6___ Page 15 of 15 Event

Description:

LK-459F fails low causing charging to go to 0 gpm.

Time Pos. Expected Actions/Behavior Comments RO 11.2 Go to procedure and step in effect At the discretion of the Lead Examiner move to the next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __7___ Page 1 of 2 Event

Description:

DC control power breaker for DG08, 1B DG output breaker, trips. TS - 3.8.1 Cond B.

Indications Available 1B DG output Breaker DG-08 Green light VA4 - 1B DG BKR 52-DG08 LOSS OF DC goes out Time Position Applicants Actions or Behavior Comments BOP Announce alarm SRO Directs ARP Entry ARP-2.1, VA4, 1B DG BKR 52-DG08 LOSS OF DC, ver 35.2 BOP 1 Contacts SSS/DB SO to Notify the appropriate plant personnel to investigate determine and correct the cause of the undervoltage condition.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __7___ Page 2 of 2 Event

Description:

DC control power breaker for DG08, 1B DG output breaker, trips. TS - 3.8.1 Cond B.

TECHNICAL SPECIFICATION 3.8.1 AC SourcesOperating LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electrical Power Distribution System; and

b. Two diesel generator (DG) sets capable of supplying the onsite Class 1E power distribution subsystem(s); and

c. Automatic load sequencers for Train A and Train B.

APPLICABILITY: MODES 1, 2, 3, and 4.

Condition B SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One DG set ------------------NOTE-------------

inoperable. ------

LCO 3.0.4c is applicable when only one of the three DGs is inoperable.

B.1 Perform SR 3.8.1.1 for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> the required offsite AND circuit(s). Once per 8 AND hours thereafter B.2 Declare required 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from feature(s) supported by discovery of the inoperable DG set Condition B inoperable when its concurrent with required redundant inoperability of feature(s) is inoperable. redundant required feature(s)

AND B.3.1 Determine OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> DG set is not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.6 for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE DG set.

AND B.4 Restore DG set to 10 days OPERABLE status. AND 13 days from discovery of failure to meet LCO After 5% ramp and completion Event 6 and this event, insert Event 8 at Lead Examiners discretion

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 1 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Indications Available

- Rx power initially lowers The following ALARMS -

- Neg SUR FE3, ROD AT BOTTOM

- RCS pressure lowering FE4, TWO OR MORE RODS AT BOTTOM

- tavg LOWERING Time Position Applicants Actions or Behavior Comments SRO Returns to Step 1 of AOP-19 Section 1.3 Note: AOP-19 allows entry into specific sections based on malfunction AOP-19, MALFUNCTION OF ROD CONTROL SYSTEM v30 BOP 1 Stop any turbine loading changes.

RO 2 Check the following:

- DRPI - AVAILABLE.

- Only one Rod dropped by observing DRPI.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 2 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments 2 (RNO)

Perform the following:

2.1 Trip the Reactor.

2.2 Go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 3 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit RO/BOP 3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

RO/BOP 4.1 (RNO)

Check SI required 4.1.1 (RNO)

IF any setpoint and coincidence shown in the coincidence shown in the reached or exceeded, THEN SI is required.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 4 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO/BOP 4.1.2 (RNO) This step is N/A IF SI is required, THEN actuate SI.

SRO 4.1.3 (RNO)

IF SI NOT required, THEN go to FNP-1-ESP-0.1, REACTOR TRIP RESPONSE.

ESP-0.1, RX TRIP RESPONSE ver 34 RO 1 Check RCS temperature

- Stable at or approaching 547°F

- TAVG 1A(1B,1C) RCS LOOP

[] TI 412D

[] TI 422D STM DUMP

[] TI 432D BOP 2 NOTE: this is a continuing WHEN RCS average temperature less action step than 554°F, THEN verify feedwater status.

- Verify FRVs closed 2.2 MDAFWP AUTO/DEFEAT

[] 1A in DEFEAT

[] 1B in DEFEAT 2.3 Verify BOTH SGFPs tripped 2.4 Verify total AFW flow to the SGs >395 gpm RO 3 Verify ALL RX TRIP breakers OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 5 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 4 Rod P-10 is stuck Check emergency Boration not required

- All rods FULLY INSERTED

- RCS Tavg >525°F RO 4 (RNO)

Emergency borate RCS.

RO 4.1 Start a boric acid transfer pump BATP

[] 1A

[] 1B RO 4.2 Establish emergency boration flow path.

4.2.1 Align normal emergency boration flow path.

EMERG BORATE TO CHG PUMP SUCT

[] Q1E21MOV8104 open 4.2.2 IF normal emergency This step is N/A boration flow path NOT available, THEN align manual emergency boration flow path.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 6 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 4.3 Establish adequate letdown.

4.3.1 Verify 45 gpm letdown orifice in service.

LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A open 4.3.2 Verify one 60 gpm letdown orifice in service.

LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B open

[] Q1E21HV8149C open RO 4.4 Verify emergency boration flow adequate.

4.4.1 Verify charging flow greater than 40 gpm.

4.4.2 IF normal emergency boration flow path aligned, THEN check emergency boration flow greater than 30 gpm.

BORIC ACID EMERG BORATE

[] FI 110 Insert Event 9 here

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 7 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments 4.4.3 Steps 4.4.3 -4.4.4 are N/A IF manual emergency boration flow path aligned, THEN check boric acid flow greater than 30 gpm.

MAKEUP FLOW TO CHG/VCT

[] BA FI 113 4.4.4 IF charging flow less than 40 gpm OR boration flow less than 30 gpm, THEN verify boration flow path using ATTACHMENT 1.

RO 4.5 2500 gal required IF any control rod NOT fully inserted, THEN borate at least 2,500 gallons (200 ppm) for each control rod not fully inserted, up to a maximum of 17,309 gallons.

2500 gal. per stuck rod x No. rods not inserted

= gal. boration req'd

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 8 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 4.6 IF TAVG less than 525F, Step 4.6-4.8 are N/A THEN borate an additional 70 gallons for each °F less than 525F, per the calculation below:

525F

- ___F (indicated TAVG)

= __°F x 70 gal. per F

= gal. boration req'd 4.7 IF DRPI power lost due to loss of B Train power, THEN align DRPI main power supply to NORMAL at Rod Position Indication Dist.

Panel (139' Electrical Penetration Room).

4.8 WHEN emergency boration complete, THEN stop emergency boration using FNP-1-AOP-27.0, EMERGENCY BORATION.

BOP 5 Announce Unit 1 Reactor Trip RO Recognizes Pressurizer level falling RO Takes action per FOLDOUT PAGE May go to AOP-2 (Next Page)

See event 9 for follow on actions

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 9 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments AOP-2 SG Tube Leakage, ver 35 RO 1

[CA] Maintain pressurizer level stable at normal programmed value.

RO 1.1 Control charging flow with FCV-122.

1.1

[ ] FK-122 adjusted as required.

RO 1.2 IF required, THEN reduce letdown by closing one or more of the letdown orifice isolation valves.

1.2

[ ] Q1E21HV8149A-closed

[ ] Q1E21HV8149B-closed

[ ] Q1E21HV8I49C-closed RO 1 (RNO) May not transition until Perform the following. Step 2 1

a)

Trip the reactor.

b)

WHEN the reactor is tripped, THEN actuate SI.

c)

Go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 10 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 1.3 IF plant conditions permit, THEN determine RCS leak rate using FNP-1-STP-9.0, RCS LEAKAGE TEST.

1.3 (RNO)

With pressurizer level on program, determine RCS leak rate from CVCS flow balance.

1.3

______(charging flow FCV122 in auto)

+______(seal injection flow)

-______(letdown flow)

-______(#1 seal leakoff flow)

=______(RCS leak rate)

RO 2

[CA] Maintain VCT level greater than 20%.

RO 2.1 Verify reactor makeup system - IN AUTOMATIC.

2.1 OR 2.2 Manually control reactor makeup system using FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __8___ Page 11 of 11 Event

Description:

Rod F14 drops to the bottom of the core. Requires a Reactor trip. Rod P10 is stuck.

Emergency boration required.

Time Position Applicants Actions or Behavior Comments RO 2 (RNO)

Perform the following.

1 a)

Trip the reactor.

b)

WHEN the reactor is tripped, THEN actuate SI.

c)

Go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 1 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Indications Available

- Pzr level falling - SGWL rising in 1C SG Time Position Applicants Actions or Behavior Comments Note: May elect to SI and go to EEP-0 before 4% PRZR level Note: The following action is from ESP-0.1 FOLDOUT PAGE.

RO 1 Monitor SI Criteria Greater than 16F subcooled in CETC mode and PRZR level above 4%.

RO 1.1 (RNO)

Verify SI actuated, check for CSF red or orange paths, go to FNP-1-EEP-0.

EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 2 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit RO/BOP 3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

4.2 Verify both trains of SI- ACTUATED.

[] MLB1 1-1 AND MLB1 11-1 lit RO/BOP 5 Page 19 Verify actuation signal automatic actions using ATTACHMENT 2, AUTOMATIC ACTIONS VERIFICATION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 3 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO/BOP 6

[CA] Check containment pressure - HAS REMAINED LESS THAN 27 psig.

CTMT PRESS

[] PR 950 RO/BOP 7 Announce "Unit 1 reactor trip and safety injection."

RO/BOP 8 Check AFW status.

8.1 Check secondary heat sink available.

[] Total feed flow to SGs - pumps started.

GREATER THAN 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B TDAFWP STM SUPP

[] FI 3229C FROM 1B(1C) SG AFW TOTAL FLOW

[] FI 3229

[] Narrow range level in at least one SG - GREATER THAN 31%{48%}

8.2 WHEN all SG narrow range levels less than 31%{48%},

THEN maintain total AFW flow greater than 395 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 4 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 8.3 WHEN at least two SG narrow range levels greater than 28%

AND TDAFWP NOT required, THEN stop TDAFWP 8.4

[CA] WHEN SG narrow range level greater than 31%{48%},

THEN maintain SG narrow range level 31%-65%{48%-65%}.

8.4.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 5 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 8.4.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted RO 9 Check RCS temperature.

-IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547F.

TAVG 1A(1B,1C) RCS LOOP

[] TI 412D 9.1.1 Verify steam dumps closed.

[] TI 422D

[] TI 432D OR IF no RCP running, THEN check RCS cold leg temperature - STABLE AT OR closed.

APPROACHING 547F.

RCS COLD LEG TEMP RECORDER

[] TR 410

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 6 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 9 (RNO)

Perform the following.

9.1 IF RCS temperature less than 547F and falling, THEN perform the following. IF RCS temperature greater than 547F and rising, THEN proceed to RNO Step 9.2.

9.1.1 Verify steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[] B TRN in OFF RESET 9.1.2 Verify atmospheric reliefs closed 1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A

[] PC 3371B

[] PC 3371C 9.1.3 IF cooldown continues, THEN control total AFW flow to stop RCS cooldown.

9.1.4 IF MSIVs are closed THEN proceed to step 9.1.9 Contacts TB SO 9.1.9 IF main steam lines isolated AND gland steam supplied from Unit 1, THEN break condenser vacuum.

COND VAC BKR MAN ISO (155 ft, TURB BLDG)

[] N1N51V518A open

[] N1N51V518B open COND VAC BKR VLVS

[] N1N51V519A/519B open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 7 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 9.2 This step is N/A IF RCS temperature greater than 547F and rising, THEN perform the following.

RO 10 Check pressurizer PORVs and spray valves.

10.1

[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

10.1.1 Verify both PRZR PORVs indicate CLOSED 10.1.2 Check PRZR PORV temperature STABLE OR FALLING

[] PORV Temp TI-463 10.1.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 10.2

[CA] WHEN pressurizer pressure less than 2260 psig, spray flow. THEN verify normal pressurizer spray valves closed OR closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C

[] PK 444D 10.3 Check any PRZR PORV ISO - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 8 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 11 Check RCP criteria.

11.1 Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16F{45F}

SUBCOOLED IN CETC MODE.

RO 12 Monitor charging pump miniflow criteria.

12.1 Control charging pump miniflow valves based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

[] PI 402A

[] PI 403A RO 13 Check SGs not faulted.

13.1 Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 9 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 14 Check SGs not ruptured.

- Check secondary radiation indication - NORMAL.

[] R-15 SJAE EXH

[] R-19 SGBD SAMPLE

[] R-23A SGBD HX OUTLET

[] R-23B SGBD TO DILUTION

[] R-15B TURB BLDG VNTL (BOP)

[] R-15C TURB BLDG VNTL (BOP)

[] R-60A MS ATMOS REL (BOP)

[] R-60B MS ATMOS REL (BOP)

[] R-60C MS ATMOS REL (BOP)

[] R-60D TDAFWP EXH (BOP)

- No SG level rising in an uncontrolled manner.

SRO 14 Go to FNP-1-EEP-3, STEAM GENERATOR TUBE RUPTURE.

EEP-3.0, SGTR, ver 27 RO 1 Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication - > 16°F{45°F} SUBCOOLED IN CETC MODE.

BOP 2 NOTE: this is a continuing

[CA} Identify ruptured SG(s). action step Check any SG level - RISING IN AN UNCONTROLLED MANNER

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 10 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO/RO 3 NOTE: this is a continuing WHEN ruptured SG(s) identified, THEN action step isolate flow from ruptured SG(s).

1C SG is ruptured 3.1 Verify ruptured SG(s) atmospheric relief valve - ALIGNED.

- PC3371C, 1C MS ATMOS REL VLV, set 8.25 and in auto 3.2 Verify 3371C, 1C MS ATMOS REL VLV, is closed 3.3 Isolate steam supply from 1C SG to TDAFWP:

3.3.1 Check 1B or 1C SG(s) ruptured.

3.3.2 Direct counting room to perform FNP CCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.

3.3.3 Check at least one MDAFWP running and no TDAFWP auto start signals present

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 11 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments 3.3.4 Stop the TDAFWP from the MCB 3.3.5 Check TDAFWP steam supply valves closed.

3.3.6 Initiate actions to isolate the TDAFW steam supply from the ruptured SG while continuing with step 3.6.

BOP 3.4 Check 1C SG ruptured.

3.4.1 Establish LOCAL control from hot Contact SSS and shutdown panel AND Isolate TDAFWP coordinates performance steam supply from 1C SG.

[] TDAFWP STM SUPP FROM 1C SG Q1N12HV3235B in LOCAL.

(HSDP-F)

[] TDAFWP STM SUPP FROM 1C SG Q1N12HV3235B in STOP and release. (HSDP-D)

SRO/ 3.5 This Step is N/A BOP Check 1B SG ruptured.

BOP 3.6 Verify blowdown from ruptured SG(s) -

ISOLATED.

3.7 Verify at least one SG MSIV on 1C SG closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 12 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 4 NOTE: this is a continuing WHEN ruptured SG(s) NR level greater action step than 31% THEN perform the following:

4.1 Isolate AFW flow to ruptured SG(s) using Critical task - Isolate SG FCVs.

- FCV 3227C in MOD, and closed

- HV 3328C in MOD and closed SRO 5 Check ruptured SG(s) pressure GREATER THAN 250 psig.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 13 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO 6 Perform RCS cooldown. Determine required CETCs for cooldown based on ruptured SG pressure.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 14 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO 6.2 Display the hottest core exit thermocouple.

6.2.1 IF the plant computer is available, THEN display HIGHEST CORE EXIT TEMP CHAN A and CHAN B on one of the following displays.

- 1TC1

- STA

- Other display 6.3 Critical task - Cooldown WHEN P-12 light lit (543F),

THEN perform the following.

6.3.1 Block low steam line pressure SI.

STM LINE PRESS SI BLOCK - RESET

[] A TRN to BLOCK

[] B TRN to BLOCK 6.3.2 Verify blocked indication.

BYP & PERMISSIVE STM LINE ISOL.

SAFETY INJ.

[] TRAIN A BLOCKED light lit

[] TRAIN B BLOCKED light lit 6.3.3 Bypass the steam dump interlock.

STM DUMP INTERLOCK

[] A TRN to BYP INTLK

[] B TRN to BYP INTLK

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 15 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO Will direct these steps:

6.4 IF condenser available, THEN dump steam to condenser from intact SGs at maximum attainable rate.

BYP & PERMISSIVE COND AVAIL

[] C-9 light lit STM DUMP

[] MODE SEL A-B TRN in STM PRESS STM DUMP INTERLOCK

[] A TRN in ON

[] B TRN in ON STM HDR

[] PK 464 adjusted RO 6.5 Continue to step 7 until Check hottest CETCs less than required CETCs are < required temperature. temp.

6.6 Stop the cooldown 6.7

[CA] Maintain core exit T/Cs - LESS THAN REQUIRED TEMPERATURE.

Note: Once required CETC temperature met, it will be the expected exam termination point

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 16 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 7 Check intact SG levels.

7.1 Check any intact SG narrow range level -

GREATER THAN 31%{48%}.

7.2

[CA] WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG narrow range level 31%-65%{48%-65%}.

7.2.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD 7.2.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 17 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments RO 8 Check pressurizer PORVs 8.1 Check any PRZR PORV ISO - power available 8.2

[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.

8.2.1 Verify both PRZR PORVs - CLOSED 8.2.2 Check PRZR PORV temperature STABLE OR FALLING.

[] PORV Temp TI-463 8.2.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 8.3 Check at least one PRZR PORV ISO -

OPEN BOP 9 Verify SI - RESET.

MLB-1 1-1 not lit (A TRN) and MLB-1 11-1 not lit (B TRN) 10 Verify PHASE A CTMT ISO - RESET.

MLB-2 1-1 not lit and MLB-2 11-1 not lit

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 18 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 11 Check PHASE B CTMT ISO - RESET.

RO 12 IF instrument air available, THEN establish instrument air to containment.

Verify at least one air compressor started.

AIR COMPRESSOR

[] 1A

[] 1B

[] 1C Check INST AIR PRESS PI 4004B greater than 85 psig.

Check instrument air to containment.

IA TO CTMT

[] MLB-3 1-2 NOT lit IA TO PENE RM PRESS LO

[] Annunciator KD1 clear RO 13

[CA] Check if LHSI Pumps should be stopped.

13.1 RHR pumps - ANY RUNNING SUCTION ALIGNED TO RWST.

Take HS to stop.

13.2 Check RCS pressure - GREATER THAN 275 psig{435 psig} on PT-402 AND 403, 1A/1C LOOP RCS WR PRESS.

13.3 Secure any running RHR pumps

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 19 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments SRO 14 Check if Cooldown should be stopped.

14.1 Check hottest core exit T/Cs - LESS THAN REQUIRED Temperature. RNO Do NOT proceed until 14.2 hottest core exit T/Cs -

Stop RCS cooldown LESS THAN REQUIRED TEMPERATURE.

14.3 Stop RCS cooldown Maintain core exit T/Cs - LESS THAN REQUIRED TEMPERATURE.

EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 2, ver 45 1

Verify one CHG PUMP in each train -

BOP STARTED.

[] A train (1A or 1B) amps > 0

[] B train (1C or 1B) amps > 0 BOP 2 Verify RHR PUMPs - STARTED.

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP 3 Verify Safety Injection Flow.

3.1 Check HHSI flow - GREATER THAN 0 gpm.

[] FI 943 BOP 3.2 Operator should proceed to Check RCS pressure - LESS THAN step 4 275 psig{435 psig}.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 20 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 4 Verify each SW train - HAS TWO SW PUMPs STARTED.

[] A train (1A,1B or 1C)

[] B train (1D,1E or 1C)

BOP 5 Verify each train of CCW - STARTED.

5.1 Verify one CCW PUMP in each train-STARTED.

A train HX 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 21 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 6 Verify containment ventilation isolation.

6.1 Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 6.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 6.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 22 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 7 Verify containment fan cooler alignment.

7.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[] 1A

[] 1B B train

[] 1C

[] 1D 7.2 Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 23 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 8 Verify AFW Pumps - STARTED.

8.1 Verify both MDAFW Pumps - STARTED

[] 1A MDAFW Pump amps > 0

[] 1B MDAFW Pump amps > 0 AND

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 24 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments 8.2 Check TDAFW Pump start required.

8.3 Verify TDAFWP started.

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

8.4 Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 25 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 9 Verify main feedwater status.

Verify main feedwater flow control and bypass valves - CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[] FCV 488

[] FCV 498 9.2 Verify both SGFPs - TRIPPED.

9.3 Verify SG blowdown - ISOLATED.

1A(1B,1C) SGBD ISO

[] Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample - ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 26 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 10 Check no MSL isolation actuation signal present.

10 (RNO)

Perform the following.

10.1 Verify main steam line isolation and bypass valves closed.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYP

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 27 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments 11 Verify PHASE A CTMT ISO.

BOP 11.1 Verify PHASE A CTMT ISO - ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO BOP 12 Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP 13 Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11E005A

[] N1C11E005B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 28 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 14 Secure secondary components.

14.1 Stop both heater drain pumps.

HDP

[] 1A

[] 1B 14.2 Check any condensate pump started.

14.2.1 IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 14.3 IF condensate pump operating, Will call TBSO to THEN verify backup cooling aligned to accomplish this.

condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP 15 Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN BOP 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810 - OPEN

[] 914 - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 29 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments BOP 17 Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 30 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 4, ver 45 1

Verify two trains of ECCS equipment aligned.

1.1 - 1.4

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 closed 1.5

[] Verify two trains of battery chargers -

energized

[] A Train (1A or 1C) amps > 0

[] B Train (1B or 1C) amps > 0 1.6 Verify two trains of ESF equipment aligned.

1.6.1 Check all MLB-1 lights LIT 1.6.2 Verify charging pump suction and discharge valves - OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___3__ Event No.: __9___ Page 31 of 31 Event

Description:

1C SGTR @ 300 gpm after emergency boration started in ESP-0.1. (CT-18, CT-19)

Time Position Applicants Actions or Behavior Comments 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B 1.8 WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP 1.9 Call Radside SO Verify SFP Cooling in service per SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of Attachment 4

Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #4 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 7/22/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 4 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 4% power, EOL, Cb 530 ppm, UOP-1.2 Section 4 through step 65 is complete, B Train On Service.

Turnover:

• 4% power, EOL, Cb 530 ppm

• UOP-1.2 Section 4 through step 65 is complete. Disconnect 915 is coupled and closed.

• Raise power to 12% and roll the Main turbine.

• Aux steam aligned to Unit 2

• 1A SGFP on service

• All MODE 1 STPs are completed and permission to enter MODE 1 has been granted.

• B Train On Service, B Train protected.

• Current Risk Assessment is GREEN and projected is GREEN Event Malf. No. Event Event No. Type* Description 1 cnh/ I (BOP) FK-489, 1B SG FW BYP FLOW fails open in auto. Can be FK498-A manually controlled. (P-CT) 2 R (RO) Raise power to 12% using rods and Steam Dumps.

N (BOP) 3 cmfmalf/ TS (SRO) 1B Pressurizer Heater breaker trips.

cPC2028C_co1 TS - 3.4.9 Cond B 4 xmt/ I (RO) PT-445, PRZR PRESS, fails high. PCV-445A is stuck open pt445 TS (SRO) and cannot be closed.

preset TS - 3.4.11 Cond B (P-CT) 5 xmt/ I (RO) PK-145, LP LTDN PRESS, fails high (valve full close). PCV-PK145 145 cannot be opened.

preset 6 xmt/ I (BOP) PT-464, STM HDR PRESS, fails high. (P-CT)

PT464 TS- 3.4.2 Cond A 7 malf/m/ M (ALL) Main Steam Line Break on 1B SG inside Containment MAL-MSS1B preset C (RO) Automatic SI Blocked (CT-2)

C (BOP) HV-7614B, 1B SGBD ISO, fails to close automatically on preset MDAFWP auto start Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario 4 Presets Form ES-D-1 EVENT # TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-222 (Base IC-48) 0 0 Generic setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc4.txt 0 0 RUN PRESETS 4 PCV-445A stuck open *TRG 1 trg 1 imf rrc445a-s 100 0 5 PCV-145 cannot be opened in Manual *TRG 2 trg 2 imf pk-145-m 10 0 7 HV-7614B fails to close on MDAFWP auto start

• imf cMS7614B_d_cc3 closed imf cMS7614B_d_cc4 closed 7 Block Automatic SI

• imf csftyinj_cc1 open imf csftyinj_cc11 open Triggers and Commands 4 Monitor PCV-445A position *TRG 1 trgset 1 "rrc445a == 1" 5 Monitor PCV-145 position *TRG 2 trgset 2 "rcvp145 == 0"

MCB setup OVATION Clear OVATION alarms Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms Provide marked up copy of , UOP-1.2 Section 4 step 66 UOP-1.2 IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 NRC FK-489, 1B SG FW BYP FLOW fails open in auto. Can be CUE manually controlled. (P-CT) imf fk498-a 10 30 2 Raise power to 12%

3 NRC 1B Pressurizer Heater breaker trips.

CUE TS - 3.4.9 Cond B imf cPC2028C_co1 4 NRC PT-445, PRZR PRESS, fails high. PCV-445A is stuck open CUE and cannot be closed.

TS - 3.4.11 Cond B (P-CT) imf pt445 2500 30 TRG 1 5 NRC PK-145, LP LTDN PRESS, fails high (valve full close). PCV-CUE 145 cannot be opened.

imf pk145-a 10 30 TRG 2 6 NRC PT-464, STM HDR PRESS, fails high. (P-CT)

CUE TS- 3.4.2 Cond A imf pt464 1200 60 EVENT# TIME EVENT DESCRIPTION COMMAND

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC Main Steam Line Break on 1B SG inside Containment CUE imf mal-mss1b 6 60 Automatic SI Blocked (CT-2) preset HV-7614B, 1B SGBD ISO, fails to close automatically on preset MDAFWP auto start NRC END OF EXAM:

CUE 1B SG is isolated Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen4grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED .

4 IF REQUESTED Open FU-K4 irf crc800a_d_cd1 open (3 minutes after requested) 5 NONE REQUIRED 6 NONE REQUIRED 7 IF REQUESTED SOP-0.0 actions for a Rx trip cae Turbine_Bldg_MSRs.cae (10 minutes after requested) 9.1.7 RNO of EEP-0 EEP-0 step 9.1.7 RNO cae 2015_TB_MSDP_iso.cae (5 minutes after requested)

ROVER/SSS: 3 minutes after requested - Perform Step 4.5.1 of EEP-2.0 at HSDP (See Next Page)

Close Q1N23V017B irf loa-afw007 0 30 (3 minutes after requested)

Acknowledge MH1 Go to Control Room Fire Panel on the PANEL MAP and select CONTROL ROOM FIRE PANEL then CLICK the ACK button. (3 minutes after requested)

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the inform supervision) cue and that type of communications 1 NO ADDITIONAL REQUIRED 2 NO ADDITIONAL REQUIRED 3 IF REQUESTED ROVER: 3 minutes after requested - EC-11 is open, no obvious problems noted 4 IF REQUESTED RAD 1 SO: 3 minutes after requested - FU-K4 is open 5 IF REQUESTED SSS or RAD 1 SO: Acknowledge to place RCDT on recirc.

NOTE: No action required. next event will occur before excess letdown will be placed on service.

6 NO ADDITIONAL REQUIRED 7 IF REQUESTED TB SO: 10 minutes after requested - SOP-0.0 actions for a Rx trip/Safety Injection are complete.

TBSO: I will perform step 9.1.9 (RNO) of EEP-0 for Unit 1 RAD 1 SO: I will verify SFP cooling in service per SOP-54.0 ROVER/SSS: 3 minutes after requested - Step 4.5 of EEP-2.0 at HSDP complete.

ROVER/SSS: 3 minutes after requested - V017B is closed.

U2: Once MH1 is acknowledged - Fire alarm has been acknowledged. It was 1A-22 CTMT.

Appendix D Scenario 4 Detailed Summary Form ES-D-1 Initial Conditions: 4% power, EOL, Cb 530 ppm, UOP-1.2 Section 4 through step 65 is complete, B Train On Service.

Turnover:

• 4% power, EOL, Cb 530 ppm

• UOP-1.2 Section 4 through step 65 is complete. Disconnect 915 is coupled and closed.

• Raise power to 12% and roll the Main turbine.

• Aux steam aligned to Unit 2

• 1A SGFP on service

• All MODE 1 STPs are completed and permission to enter MODE 1 has been granted.

• B Train On Service, B Train protected.

• Current Risk Assessment is GREEN and projected is GREEN Event 1: FK-489, 1B SG FW BYP FLOW fails open in auto.

Verifiable actions: BOP takes manual control of FK-489 and restores SGWL.

(P-CT) If the BOP does not control SGWL then a LOLO SGWL Reactor trip will occur if 1B SG level lowers to 28% and the SGFP will trip if 1B SGWL reaches the HIHI setpoint of 82%

which will require a Reactor trip due to a loss of feed above 5% power.

Event 2: Ramp up to 12% .

Verifiable actions: RO uses rods and BOP uses Steam Dumps to raise power to 12%.

(SIMILAR to AUDIT) - On the audit exam, at 8% power, a trigger will cause PT-508 (FW Header Pressure) to fail HIGH. Discussed with Chief Examiner.

Event 3: 1B Pressurizer Heaters breaker trips.

Verifiable actions: SRO - Tech Specs: 3.4.9 Cond B Event 4: PT-445, PRZR PRESS, fails high. PCV-445A will be stuck open.

Verifiable actions: RO will attempt to close PCV-445A and when it cant be closed, MOV8000A, PRZR PORV ISO will be closed. Pressurizer heaters should be already on but if secured then the RO will energize Pressurizer heaters. SRO - Tech Specs: 3.4.11 Cond B (P-CT) If the RO does not get the block valve closed promptly, a Low Pressure Reactor trip will occur.

(SIMILAR to AUDIT) - The opposite PT fails high on the audit exam which requires the Spray Valves to be closed and Pressurizer Heaters to be energized. Also, the PORV closes on the Audit exam and is leaking by which is Tech Spec 3.4.11 Cond A.

Event 5: PK-145, LP LTDN PRESS, fails high (valve full close). PCV-145 cannot be opened.

Verifiable actions: RO will attempt to take manual control of PCV-145 and control letdown pressure. Once the RO recognizes that PCV-145 is stuck, the RO will isolate letdown by closing the letdown orifice isolations.

Event 6: PT-464, STM HDR PRESS, fails high.

Verifiable actions: BOP takes control of SFGP speed and lowers back to normal. Steam dumps will open fully until P-12. BOP will have to control them manually using manual control of PK-464. SRO - Tech Specs: TS- 3.4.2 Cond A (P-CT) If the BOP does not control SGWL then a LOLO SGWL Reactor trip will occur if 1B SG level lowers to 28% and the SGFP will trip if 1B SGWL reaches the HIHI setpoint of 82%

which will require a Reactor trip due to a loss of feed above 5% power.

(SIMILAR to AUDIT) - PK-464 fails high on the audit but at a higher power level (25%) which does not affect the steam dumps since they are in Tavg mode at the higher power.

Event 7: A Main Steam Line Break occurs on the 1B SG inside Containment. Automatic SI is blocked and HV7614B, 1B SGBD ISO will not automatically close.

Verifiable actions: Manually actuate SI (CT-2) and close HV-7614B.

(SIMILAR to AUDIT) Audit exam requires a transition to ECP-2.1 due to MSIVs not closing.

Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Appendix D Scenario 4 Critical Tasks Form ES-D-1

_____ 1. Manually actuate at least one train of SIS-actuated safeguards before any of the following: (CT-2)

Transition to EEP-2.

_____ 2. Isolate the faulted SG before transition out of E-2. (CT17)

SCENARIO At power power instrument and component failures with a SLB inside Containment on OBJECTIVE/ the 1B SG. The team should be able to:

OVERVIEW:

• respond to FK-498, 1B SG FW BYP FLOW fails open in auto

• raise power to 12%

• Respond to a Pressurizer heater breaker trip

• respond to PT-445 failing high and a stuck open PORV

• isolate letdown in response to a failure of PK-145

• restore SGWL and Steam Dump control after the failure of PT-464

• respond to SLB inside Containment and manually actuate SI along with isolating the faulted SG.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 2

2. Abnormal events (2-4) 4

3. Major transients (1-2) 1

4. EOPs entered/requiring substantive actions (1-2) 1

5. EOP contingencies requiring substantive actions (0-2) 0

6. Critical tasks (2-3) 5

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 2, 4% RTP, 530 ppm Cb, EOL 20000 MWD/MTU, -13 pcm Xe B Trn O/S / B Trn Protected / SFPC on B Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 95 hours0.0011 days <br />0.0264 hours <br />1.570767e-4 weeks <br />3.61475e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. Aux steam aligned to Unit 2

3. Raise power to 12% and roll the Main Turbine.

4. UOP-1.2, Section 4 through Step 65 is complete

5. All MODE 1 STPs are completed and permission to enter MODE 1 has been granted.

6. Disconnect 915 is coupled and closed.

7.

8.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas)

LCO status None #1 RHT Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __1___ Page 1 of 4 Event

Description:

FK-489, 1B SG FW BYP FLOW fails open in auto. Can be manually controlled.

(P-CT)

Indications Available Annunciators: Recognize indications of FK-499 failing high:

- 1B SG LVL DEV (JF3) - 1B SG feed flow rising

- 1B SG FEED FLOW > STM FLOW - 1B SG NR level rising (JG3) - FRV bypass valve going full open

- 1B SG HI-HI LVL ALERT (JD3)

Time Position Applicants Actions or Behavior Comments AOP-100, section 1.5, version 11(possible AOP-13 entry)

RO/BOP Recognizes malfunction and announces then takes immediate operator action of AOP-100 SRO Instructs BOP/RO to perform Immediate Operator Actions of AOP-100 if not taken by the RO/BOP BOP 1 NOTE: Step 1 is an Maintain SG levels at 65%. Immediate Operator Action and a continuing action step 1.1 IF required, THEN, take manual control of SGFP speed control as necessary to restore SG level to 65%1.1

- SGFP master controller SK-509A OR

- SGFP individual controllers as needed.

[ ] SK-509B

[ ] SK-509C 1.2 IF required, THEN take manual control of the affected feedwater bypass valves 1.2

[ ] 1A SG FW FLOW FK-479

[ ] 1B SG FW FLOW FK-489

[ ] 1C SG FW FLOW FK-499

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __1___ Page 2 of 4 Event

Description:

FK-489, 1B SG FW BYP FLOW fails open in auto. Can be manually controlled.

(P-CT)

Time Position Applicants Actions or Behavior Comments SRO 1.3 This will not result in a loss If a loss of main feedwater occurs, then of MFW perform the actions of AOP-13, Loss of Main Feedwater SRO 2 Trip criteria expected:

If an adverse trend in SG level exists, then - Rx trip on low SG level establish Trip Criteria 28%

- Main Turbine and Feed Pump Trip @ 82% SG level Potential Critical task - If loss of SGWL control occurs, a Rx trip may be required due to a loss of feed above 5% Rx power AOP-13)

BOP 3 No ramp will be in progress IF a ramp is in progress, THEN place Turbine on HOLD

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __1___ Page 3 of 4 Event

Description:

FK-489, 1B SG FW BYP FLOW fails open in auto. Can be manually controlled.

(P-CT)

Time Position Applicants Actions or Behavior Comments SRO/ 4 NO instrument failure BOP Determine if an instrument failure has occurred occurred.

4.1 Check for a failed or erroneous indications from the following Steam flow or feed flow indicators.

STM FLOW FEED FLOW S/G CH III CH IV CH III CH IV A S/G FI-474 FI-475 FI-477 FI-476 B S/G FI-484 FI-485 FI-487 FI-486 C S/G FI-494 FI-495 FI-497 FI-496 4.2 Check for failed or erroneous readings on the following SG pressure indicators S/G CH II CH III CH IV A S/G PI-474 PI-475 PI-476 B S/G PI-484 PI-485 PI-486 C S/G PI-494 PI-495 PI-496 SRO/ 4.3 BOP IF the alarm(s) was due to a SGWLC No action required due to System controlling channel failure, THEN controller failure.

select the unaffected channel 4.3.1 Place the following handswitches to the appropriate channel III OR IV position as required:

4.3.2 Verify proper system response.

SRO 5 No LCO requirements Refer to Tech Specs 3.3.2 and 3.7.3 for any LCO requirements.

SRO 6 SM contacted Notify the Shift Manager

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __1___ Page 4 of 4 Event

Description:

FK-489, 1B SG FW BYP FLOW fails open in auto. Can be manually controlled.

(P-CT)

Time Position Applicants Actions or Behavior Comments SRO 7 This step is N/A WHEN plant conditions permit, THEN return systems to automatic control.

SRO 8 Has RO/BOP contact Submit a condition report on the failed appropriate personnel component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO 9 Go to procedure and step in effect.

At the discretion of the Lead Examiner move to Event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __2___ Page 1 of 4 Event

Description:

Raise power to 12%. Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2.

Indications Available

- Rx power rising Time Position Applicants Actions or Behavior Comments UOP-1.2, Startup of Unit from Hot Standby to Minimum Load, Section 4 Step 66, ver 110.1 RO 66 Manual adjustment of rods Begin to increase reactor power to greater (not more than 3 steps at a than 12% with following controls. time) See page 4 Stm dump control - adjust Manual adjustment of control rods PK-464 counterclockwise to Steam dumps in Steam Pressure release more steam, Control Mode decrease Tavg, pull rods and increase power SRO Monitor reactor power and Steam Dump Examiner NOTE: Diluting is adjustments as reactor power rises not procedurally required or expected and as such would not be a part of the reactivity plan BOP Will be reviewing UOP-1.2 and getting ready to roll the main turbine.

BOP 67 This step is N/A IF MTC is zero or positive, verify rods less than or equal to approximately D at 170 steps to ensure adequate rod worth for transient control while paralleling the Main Generator to the grid. (IR 2 129)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __2___ Page 2 of 4 Event

Description:

Raise power to 12%. Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2.

Time Position Applicants Actions or Behavior Comments RO 68 WHEN Nuclear at Power Permissive P-10 permissive status light is illuminated (2/4 power ranges greater than 10%), THEN perform the following: {CMT-0003695}

a Block the intermediate range reactor trip and overpower rod stop.

Place INTEMEDIATE RANGE BLOCK TRN A to BLOCK.

Place INTEMEDIATE RANGE BLOCK TRN B to BLOCK.

b On the Bypass and Permissive Panel verify the following:

The INTERM RANGE TRAIN A TRIP BLOCKED light illuminated.

The INTERM RANGE TRAIN B TRIP BLOCKED light illuminated.

c Block the power range low setting reactor trip.

Place POWER RANGE BLOCK TRN A to BLOCK.

Place POWER RANGE BLOCK TRN B to BLOCK.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __2___ Page 3 of 4 Event

Description:

Raise power to 12%. Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2.

Time Position Applicants Actions or Behavior Comments d

On the Bypass and Permissive Panel verify the following:

The POWER RANGE LOW SETTING TRAIN A TRIP BLOCKED light illuminated.

The POWER RANGE LOW SETTING TRAIN B TRIP BLOCKED light illuminated.

RO e Verify that Low Power Trip Block P-7 status light is not illuminated to ensure the unblocking of the following reactor trips.

Pressurizer Low Pressure Pressurizer High Water Level Loss of Flow-Two Loops RO f Verify NR-45B is in the desired speed, i.e.,

2nd speed (2 min/div) OR normal speed.

(10 min/div)

SRO g This step is N/A Direct qualified EM or OPS personnel to close disconnect switch 915 When 10-12% power is reached and at the discretion of the Lead Examiner move to event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __2___ Page 4 of 4 Event

Description:

Raise power to 12%. Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2.

Time Position Applicants Actions or Behavior Comments SOP-41.0, Control Rod Drive and Postion Indication System, Ver 37 OPERATOR AID FOR CONTROL ROD MOVEMENT RO 1 Place ROD CONTROL BANK SELECTOR SWITCH in MAN.

RO 2 Check indicated control rod speed is approximately 48 steps per minute on SI-408.

RO 3 Insert OR withdraw Control Rods using the CONTROL ROD MOTION switch.

RO 4 When desired, place rod control in AUTO as follows:

RO 4.1 Verify Tavg within 1°F of Tref.

RO 4.2 Place the ROD CONTROL BANK SELECTOR SWITCH in AUTO.

RO 4.3 Check indicated control rod speed is approximately 8 steps per minute on SI-408.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __3___ Page 1 of 2 Event

Description:

1B Pressurizer Heater breaker trips. TS - 3.4.9 Cond B.

Indications Available

- 1B PRZR HTR GROUP BACKUP H/S - - HD5, PRZR HTR BKR TRIPPED in ALARM Amber and Green light lit.

Time Position Applicants Actions or Behavior Comments ARP-1.8, HD5, PRZR HTR BKR TRIPPED, ver 35.6 RO 1 Determine which pressurizer heater group breaker has tripped.

RO 2 Refer to annunciator window HC1, PRZR PRESS HI-LO.

RO 3 IF required, THEN limit plant transients until the heaters can be returned to normal.

RO 4 Contacts Rover Notify appropriate personnel to determine and correct the cause of the breaker trip.

SRO 5 Refer to Technical Specification 3.4.9 for LCO requirements.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __3___ Page 2 of 2 Event

Description:

1B Pressurizer Heater breaker trips. TS - 3.4.9 Cond B.

TECHNICAL SPECIFICATION 3..4.9 Pressurizer The pressurizer shall be OPERABLE with:

a. Pressurizer water level 63.5% indicated; and

b. Two groups of pressurizer heaters OPERABLE with the capacity of each group 125 kW and capable of being powered from an emergency power supply.

APPLICABILITY: MODES 1, 2, and 3.

Condition B SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One required B.1 Restore required group of group of pressurizer heaters to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> pressurizer OPERABLE status.

heaters inoperable.

ARP-1.8, HC1, PRZR PRESS HI-LO, ver 35.6 RO 1 Check pressurizer pressure indications and determine if pressure is high or low.

RO 2 May energize additional Check the status of the following and take heaters to control pressure manual control as necessary:

2.1 Pressurizer spray valves.

2.2 Pressurizer power operated relief valves (PORVs).

2.3 Pressurizer heaters.

RO 3 This step is N/A IF an instrument failure has occurred, THEN go to FNP-1-AOP-100, INSTRUMENT MALFUNCTION.

At Lead Examiners discretion, move to next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 1 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Indications Available

- PT-445 goes to max scale -The following are in ALARM

- PCV-445A opens HA4, PRZR SAFETY VLV TEMP HI

- RCS pressure lowers HA5, PRZR PORV TEMP HI

-TI463, PORV is elevated HD1, PRZR PRESS REL VLV 445A OR B/U HTRS ON HC1, PRZR PRESS HI-LO Time Position Applicants Actions or Behavior Comments RO/BOP Recognizes malfunction and announces then performs immediate operator action of AOP-100 SRO If not done by RO/BOP direct immediate operator actions of AOP-100 AOP-100, INSTRUMENTATION MALFUNCTION, Section 1.1, ver 15 RO 1 Potential Critical Task -

IF required to stabilize RCS pressure, PCV-445A will not close.

THEN take manual control of the Must close the block following equipment. valve MOV-8000A or a low 1 pressure SI will occur and

• Power operated relief valves cause a Rx trip.

[ ] PRZR PORV Q1B31PCV445A

[ ] PRZR PORV Q1B31PCV444B OR

[ ] PRZR BLOCK VLV Q1B31MOV8000A

[ ] PRZR BLOCK VLV Q1B31MOV8000B

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 2 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Time Position Applicants Actions or Behavior Comments RO 2 This step is N/A IF pressurizer pressure is decreasing due to a mechanically stuck open spray valve PCV444C or PCV444D, THEN perform the following:

3 IF PORV is open and pressurizer pressure is less than 2310 psig, THEN close the PORV.

3 (RNO) Block valve may be closed IF the PORV will not close, in Step 1 THEN perform the following:

3° Potential Critical Task -

3.1 PCV-445A will not close.

IF pressurizer pressure is decreasing Must close the block due to a stuck open PORV, valve MOV-8000A or a low THEN close the associated PORV Block pressure SI will occur and Valve. cause a Rx trip 3.1 3.2 IF PORV Block valve will not close and reactor is critical, THEN trip the reactor and go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 3 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Time Position Applicants Actions or Behavior Comments 4

IF an alarm was caused by a CONTROL instrument (PT-444/445) OR component failure, THEN perform the following as required to restore RCS pressure to desired value.

44 4.1 Take manual control of the following as required:

• Power operated relief valves

[ ] PRZR PORV Q1B31PCV445

[ ] PRZR PORV Q1B31PCV444B OR

[ ] PRZR BLOCK VLV Q1B31MOV8000A

[ ] PRZR BLOCK VLV Q1B31MOV8000B

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP 4.2 IF B/U heaters automatically energized with pressure above 2210 psig, THEN verify the pressurizer master controller potentiometer setting using the plant curve book.

5 No protection channel has IF a PROTECTION instrument failure failed has occurred, THEN determine which pressure channel has caused the alarm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 4 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Time Position Applicants Actions or Behavior Comments 6

Refer to Tech Specs for LCO requirements that exist.

66

• Sections 3.3.1, 3.3.2, & 3.3.3 for instrument failures

• Section 3.4.1 for DNB limits

• Section 3.4.5 RCS Loops - Mode 3

• Section 3.4.11 PORVs Note: RCS pressure may not drop below 2209 psig TECHNICAL SPECIFICATION 3.4.1 - RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits 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 the COLR. The minimum RCS total flow rate shall be 263,400 G P M when using the precision heat balance method, when using 264, 200 G P M the elbow tap method, and the lim it specified in the C O LR APPLICABILITY: MODE 1.

Condition A SRO CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore RCS DNB RCS DNB parameter(s) to within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> parameters not limit.

within limits..

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 5 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

TECHNICAL SPECIFICATION 3.4.11 - Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

Condition B SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One PORV B.1 Close associated block inoperable and valve. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> not capable of AND 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> being B.2 Remove power from associated block 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> manually cycled. valve.

AND B.3 Restore PORV to OPERABLE status.

Time Position Applicants Actions or Behavior Comments SRO 7 Contacts SM Notify the Shift Manager.

7 87

[CA] WHEN plant conditions permit, THEN restore components to automatic control.

8 9

Submit a Condition Report and notify the Has RO/BOP contact Work Week Coordinator (Maintenance appropriate personnel ATL on backshifts).

RO/BOP 10 IF the pressurizer power operated relief valves operated, THEN perform the following:

1010 10.1 Refer to FNP-1-SOP-1.2, REACTOR COOLANT PRESSURE RELIEF Contact SSS to take actions SYSTEM, for cooldown of the pressurizer per these steps relief tank.

10.110.1 10.2 Refer to FNP-0-SOP-0.0, GENERAL INSTRUCTIONS TO OPERATIONS PERSONNEL, for reporting requirements.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __4___ Page 6 of 6 Event

Description:

PT-445, PRZR PRESS, fails high. PCV-445A is stuck open and cannot be closed.

TS - 3.4.11 Cond B (P-CT)

Time Position Applicants Actions or Behavior Comments SRO 11 Go to procedure and step in effect.

SRO Direct that FU-K4 be opened to comply RAD 1 SO/SSS contacted with Tech Spec 3.4.11 Cond B At Lead Examiners discretion, move to next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __5___ Page 1 of 2 Event

Description:

PK-145, LP LTDN PRESS, fails high (valve full closed). PCV-145 cannot be opened.

Indications Available

- PK-145 demand goes to 100 - PI-145, LTDN HX OUTLET PRESS, goes to

- DE4, LTDN HX OULET PRESS HI max scale

- DE3, LTDN ORIF ISO VLV REL LINE TEMP HI Time Position Applicants Actions or Behavior Comments RO Announce Alarms. May diagnose condition SRO Directs entry in ARP ARP-1.4, DE4, LTDN HX OUTLET PRESS HI, ver 54.2 RO 1 Monitor LTDN HX Outlet Flow (FI-150) and LTDN HX Outlet Press (PI-145).

RO 2 Ensure proper orifice isolation valve selection.

RO 3 Attempts to open PCV-145 IF the high pressure is due to LP LTDN using PK-145 PRESS PK-145 malfunction, THEN place valve controller in manual and attempt to reduce the pressure.

RO 4 IF pressure can NOT be controlled manually with LP LTDN PK-145, THEN close LTDN ORIF ISO 45 (60) GPM Q1E21HV8149A, B, and C.

BOP 5. IF a ramp is in progress, THEN place turbine load on HOLD.

SRO 6. Go to FNP-1-AOP-16.0, CVCS MALFUNCTION to address the loss of letdown flow.

Insert next event upon entry in AOP-16

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __5___ Page 2 of 2 Event

Description:

PK-145, LP LTDN PRESS, fails high (valve full closed). PCV-145 cannot be opened.

Time Position Applicants Actions or Behavior Comments ARP-1.4 , DE3, LTDN ORIF ISO VLV REL LINE TEMP HI, ver 54.2 RO 1.

Monitor the LTDN ORIF ISO REL line to PRT Temperature (TI-141) and LTDN HX Outlet Press (PI- l45).

2 IF the high temperature is due to LP LTDN PCV-145 will not open press PK-145 malfunctions, THEN place valve controller in manual and adjust as required.

3 IF temperature continues to rise rapidly indicating a lifted relief valve, THEN close LTDN ORIF ISO 45 (60) GPM Q1E21HV8149A, B AND C.

BOP 4 IF a ramp is in progress, THEN place turbine load on HOLD.

SRO 5 Go to FNP-1-AOP-16.0, CVCS MALFUNCTION to address the loss of letdown flow.

Insert next event upon entry in AOP-16

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __6___ Page 1 of 4 Event

Description:

PT-464, STM HDR PRESS, fails high. This cause SGFP speed to increase and Steam Dumps to open until they interlock closed at P-12 (543F Tavg) (P-CT)

Indications Available

-PT-464 goes to max scale - RX power rises

-Stem Dumps open until they interlock - Feed flow increases closed - The following Alarms

- SGFP speed increases JF1/2/3, 1A/1B/1C SG LVL DEV JG1/2/3, 1A/1B/1C SG FEED FLOW > STM FLOW Time Position Applicants Actions or Behavior Comments AOP-100, INSTRUMENTATION MALFUNCTION, Section 1.4, ver 15 BOP 1 Potential Critical Task - IF

[CA] Maintain SG level at the referenced SGWL is not controlled, level of 65%. then a RX trip may be 1 required due to a loss of 1.1 feedwater.

IF required, THEN take manual control of SGFP speed control SGFP master controller

[ ] SK-509A OR SGFP individual controllers as needed.

[ ] SK-509B

[ ] SK-509C 1.2 IF required, THEN take manual control of the affected feedwater regulating valves or bypass valves.

.2

[ ] 1A SG FW FLOW FK-478

[ ] 1B SG FW FLOW FK-488

[ ] 1C SG FW FLOW FK-498 OR

[ ] 1A SG BYPASS FLOW FK-479

[ ] 1B SG BYPASS FLOW FK-489

[ ] 1C SG BYPASS FLOW FK-499

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __6___ Page 2 of 4 Event

Description:

PT-464, STM HDR PRESS, fails high. This cause SGFP speed to increase and Steam Dumps to open until they interlock closed at P-12 (543F Tavg) (P-CT)

Time Position Applicants Actions or Behavior Comments 1.3 IF a loss of main feedwater has Loss of feedwater should occurred, not occur THEN perform the actions required by FNP-1-AOP-13.0, LOSS OF MAIN FEEDWATER.

SRO 2 Sets trip criteria - Typically IF adverse trend in SG level exists, 30% low and 80% high THEN establish trip criteria.

2 3 No ramp in progress BOP IF a ramp is in progress, THEN place turbine on HOLD BOP 4 Adjust speed back to within the normal operating range for the feed flow/steam flow P required for the existing power level.

4 Approximate P can be determined from the following MCB indications.

[ ] SGFP DISCH PRESS PI4003

[ ] SG Pressure indications:

BOP 5 Check Steam Dumps in TAVG Mode.

[ ] STM DUMP MODE SEL A-B TRN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __6___ Page 3 of 4 Event

Description:

PT-464, STM HDR PRESS, fails high. This cause SGFP speed to increase and Steam Dumps to open until they interlock closed at P-12 (543F Tavg) (P-CT)

Time Position Applicants Actions or Behavior Comments 5 (RNO)

IF steam dumps in STM PRESS mode perform the following:

5.1 IF PT-464 failed OR PK-464 not functioning properly, THEN take manual control of PK-464 to control steam dumps as required.

5.1 STM HDR PRESS

[ ] PK-464 6 Contact SM Notify the Shift Manager.

6 7

[CA] WHEN plant conditions permit, THEN restore components to automatic control.

7 8

Submit a condition report on the failed Has RO/BOP contact instrument, and notify the Work Week appropriate personnel Coordinator (Maintenance ATL on backshifts) of the condition report.

9 Go to procedure and step in effect.

Note; RCS Tavg will recover above 541F when the Steam Dumps close

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __6___ Page 4 of 4 Event

Description:

PT-464, STM HDR PRESS, fails high. This cause SGFP speed to increase and Steam Dumps to open until they interlock closed at P-12 (543F Tavg) (P-CT)

TECHNICAL SPECIFICATION 3.4.2 RCS Minimum Temperature for Criticality 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature (Tavg) shall be 541°F.

APPLICABILITY: MODE 1, MODE 2 with keff 1.0.

Condition A SRO CONDITION REQUIRED ACTION COMPLETION TIME A. Tavg in one or A.1 Be in MODE 3. 30 minutes more RCS loops not within limit.

At discretion of Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 1 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Indications Available

- Rx power rises until trip - CTMT pressure rises

- Many Annunciators Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 2 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit RO/BOP 3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

RO/BOP 4.1 (RNO)

Check SI required 4.1.1 (RNO)

IF any setpoint and coincidence shown in the coincidence shown in the reached or exceeded, THEN SI is required.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 3 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO/BOP 4.1.2 (RNO) Critical task - Actuate SI IF SI is required, THEN actuate SI.

This step is N/A 4.1.3 (RNO)

IF SI NOT required, THEN go to FNP-1-ESP-0.1, REACTOR TRIP RESPONSE.

RO/BOP 4.2 Verify both trains of SI- ACTUATED

[] MLB1 1-1 AND MLB1 11-1 lit RO/BOP 5 See page 15 below Verify actuation signal automatic actions using ATTACHMENT 2, AUTOMATIC ACTIONS VERIFICATION.

RO/BOP 6

[CA] Check containment pressure - HAS REMAINED LESS THAN 27 psig.

CTMT PRESS

[] PR 950

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 4 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO 6 (RNO) 6 Perform the following.

6.1 Verify PHASE B CTMT ISO - ACTUATED.

[] MLB-3 1-1 lit

[] MLB-3 6-1 lit 6.2 Stop all RCPs.

RCP

[] 1A

[] 1B

[] 1C 6.3 Verify PHASE B CTMT ISO alignment.

6.3.1 Check All MLB-3 lights lit 6.3.2 all MLB 3 lights lit IF any MLB-3 light NOT lit, THEN verify PHASE B CTMT ISO using ATTACHMENT 5, PHASE B CONTAINMENT ISOLATION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 5 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO 6.4 CS actuates properly Check containment spray.

6.4.1 Check containment spray flow in both trains greater than 0 gpm.

CS FLOW

[] FI 958A

[] FI 958B 6.4.2 IF containment spray flow in both trains NOT greater than 0 gpm, THEN verify containment spray pump suction valves open.

RWST TO 1A(1B) CS PUMP

[] Q1E13MOV8817A

[] Q1E13MOV8817B 6.4.3 IF unable to establish spray flow in a train, THEN secure containment spray pump in affected train.

[] CS RESET TRN A(B) containment spray signals - RESET (Annunciator EE4 clear).

[] CTMT SPRAY PUMP 1A(B) -

STOPPED in affected train RO/BOP 7 Announce "Unit 1 reactor trip and safety injection."

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 6 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 8 Check AFW status.

8.1 Check secondary heat sink available.

[] Total feed flow to SGs - pumps started.

GREATER THAN 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B TDAFWP STM SUPP

[] FI 3229C FROM 1B(1C) SG AFW TOTAL FLOW

[] FI 3229

[] Narrow range level in at least one SG - GREATER THAN 31%{48%}

8.2 WHEN all SG narrow range levels less than 31%{48%},

THEN maintain total AFW flow greater than 395 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 7 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 8.3 WHEN at least two SG narrow range levels greater than 28%

AND TDAFWP NOT required, THEN stop TDAFWP 8.4

[CA] WHEN SG narrow range level greater than 31%{48%},

THEN maintain SG narrow range level 31%-65%{48%-65%}.

8.4.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 8 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 8.4.2 Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted RO 9 Check RCS temperature.

-IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547F.

TAVG 1A(1B,1C) RCS LOOP

[] TI 412D 9.1.1 Verify steam dumps closed.

[] TI 422D

[] TI 432D OR IF no RCP running, THEN check RCS cold leg temperature - STABLE AT OR closed.

APPROACHING 547F.

RCS COLD LEG TEMP RECORDER

[] TR 410

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 9 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO/BOP 9 (RNO)

Perform the following.

9.1 IF RCS temperature less than 547F and falling, THEN perform the following. IF RCS temperature greater than 547F and rising, THEN proceed to RNO Step 9.2.

9.1.1 Verify steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[] B TRN in OFF RESET 9.1.2 Verify atmospheric reliefs closed 1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A

[] PC 3371B

[] PC 3371C 9.1.3 IF cooldown continues, THEN control total AFW flow to stop RCS cooldown.

9.1.4 IF MSIVs are closed THEN proceed to Contacts TB SO step

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 10 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 9.1.9 IF main steam lines isolated AND gland steam supplied from Unit 1, THEN break condenser vacuum.

COND VAC BKR MAN ISO (155 ft, TURB BLDG)

[] N1N51V518A open

[] N1N51V518B open COND VAC BKR VLVS

[] N1N51V519A/519B open 9.2 This step is N/A IF RCS temperature greater than 547F and rising, THEN perform the following.

RO 10 Check pressurizer PORVs and spray valves.

10.1

[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

10.1.1 Verify both PRZR PORVs indicate CLOSED 10.1.2 Check PRZR PORV temperature STABLE OR FALLING

[] PORV Temp TI-463 10.1.3 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 11 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO 10.2

[CA] WHEN pressurizer pressure less than 2260 psig, spray flow. THEN verify normal pressurizer spray valves closed OR closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C

[] PK 444D 10.3 Check any PRZR PORV ISO - OPEN RO 11 RCPs are secured Check RCP criteria.

11.1 Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16F{45F}

SUBCOOLED IN CETC MODE.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 12 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments RO 12 Monitor charging pump miniflow criteria.

12.1 Control charging pump miniflow valves based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

[] PI 402A

[] PI 403A BOP 13 Check SGs not faulted.

13.1 Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

SRO 13 (RNO)

Go to FNP-1-EEP-2, FAULTED STEAM GENERATOR ISOLATION

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 13 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments EEP-2, FAULTED SG ISOLATION, ver 15 BOP 1 Verify all MSIV and bypass valves -

CLOSED. Place handswitches for all MSIVs to the CLOSED position (6 total)

BOP 2 Only 1B SG will be blowing Check if any SG not faulted. down Check pressure in at least one SG -

STABLE OR RISING.

3 1B Identify the faulted SG 3.1 Check pressure in any SG- FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

BOP 4 Isolate all faulted SGs.

4.1 Verify 1B ARV closed - PC3371B minimum demand 4.2 Critical task - HV7614 Verify 1B SG Feed stop valves closed must be manually closed.

MOV3232B 4.3 Verify blowdown from all faulted SGs -

ISOLATED. HV 7614B 4.4 Since the fault is on the 1B SG, the crew will proceed to step 4.5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 14 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments SRO 4.5 Will call BOOTH operator to IF 1B SG faulted, then isolate TDAFWP have this accomplished steam supply from 1B SG

- IF TDAFWP NOT required, THEN isolate TDAFWP steam supply from 1B SG at hot shutdown panel.

BOP 4.6 Verify SG blowdown sample ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed BOP 5 Isolate AFW flow to all faulted SGs.

5.1 Close MDAFWP isolation valves to all faulted SGs. (BOP)

- Closes MOV3764B or MOV3764D BOP 5.2 Close TDAFWP flow control valves to all faulted SGs.

TDAFWP FCV 3228

[] RESET reset SRO 5.3 key Z-139 Call to SSS-P or TSC to have Q1N23V017B closed in the MSVR Critical task - This completes SG isolation

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 15 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 6 Check CST level greater than 5.3 feet 7

Check secondary radiation indication -

NORMAL.

SRO 8 Evaluate SI termination criteria

- Check SCMM indication -

GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

- Check secondary heat sink available.

>395 gpm AFW flow OR

> 31%{48%} SGNR level

- Check RCS pressure - STABLE OR RISING

- Check pressurizer level >

13%{43%}.

Expected exam termination

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 16 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 2, ver 45 1

Verify one CHG PUMP in each train -

BOP STARTED.

[] A train (1A or 1B) amps > 0

[] B train (1C or 1B) amps > 0 BOP 2 Verify RHR PUMPs - STARTED.

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP 3 Verify Safety Injection Flow.

3.1 Check HHSI flow - GREATER THAN 0 gpm.

[] FI 943 BOP 3.2 Operator should proceed to Check RCS pressure - LESS THAN step 4 275 psig{435 psig}.

BOP 4 Verify each SW train - HAS TWO SW PUMPs STARTED.

[] A train (1A,1B or 1C)

[] B train (1D,1E or 1C)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 17 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 5 Verify each train of CCW - STARTED.

5.1 Verify one CCW PUMP in each train-STARTED.

A train HX 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 18 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 6 Verify containment ventilation isolation.

6.1 Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 6.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 6.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 19 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 7 Verify containment fan cooler alignment.

7.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[] 1A

[] 1B B train

[] 1C

[] 1D 7.2 Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 20 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 8 Verify AFW Pumps - STARTED.

8.1 Verify both MDAFW Pumps - STARTED

[] 1A MDAFW Pump amps > 0

[] 1B MDAFW Pump amps > 0 AND

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 21 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments 8.2 Check TDAFW Pump start required.

8.3 Verify TDAFWP started.

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

8.4 Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 22 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 9 Verify main feedwater status.

Verify main feedwater flow control and bypass valves - CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[] FCV 488

[] FCV 498 9.2 Verify both SGFPs - TRIPPED.

9.3 Verify SG blowdown - ISOLATED.

1A(1B,1C) SGBD ISO

[] Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample - ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 23 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 10 Check no MSL isolation actuation signal present.

10 (RNO)

Perform the following.

10.1 Verify main steam line isolation and bypass valves closed.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYP

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 24 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments 11 Verify PHASE A CTMT ISO.

BOP 11.1 Verify PHASE A CTMT ISO - ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO BOP 12 Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP 13 Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11E005A

[] N1C11E005B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 25 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 14 Secure secondary components.

14.1 Stop both heater drain pumps.

HDP

[] 1A

[] 1B 14.2 Check any condensate pump started.

14.2.1 IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 14.3 IF condensate pump operating, Will call TBSO to THEN verify backup cooling aligned to accomplish this.

condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP 15 Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN BOP 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810 - OPEN

[] 914 - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 26 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments BOP 17 Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 27 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 4, ver 45 1

Verify two trains of ECCS equipment aligned.

1.1 - 1.4

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 closed 1.5

[] Verify two trains of battery chargers -

energized

[] A Train (1A or 1C) amps > 0

[] B Train (1B or 1C) amps > 0 1.6 Verify two trains of ESF equipment aligned.

1.6.1 Check all MLB-1 lights LIT 1.6.2 Verify charging pump suction and discharge valves - OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___4__ Event No.: __7___ Page 28 of 28 Event

Description:

Main Steam Line Break on 1B SG inside Containment.

Automatic SI Blocked (CT-2). HV-7614B, 1B SGBD ISO, fails to close automatically on MDAFWP auto start. Terminate when 1B SG is isolated (CT-17) and upon transition out of EEP-2.

Time Position Applicants Actions or Behavior Comments 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B 1.8 WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP 1.9 Call Radside SO Verify SFP Cooling in service per SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of Attachment 4

Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #5 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 7/22/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 5 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 100% power, MOL, Cb 915 ppm, A Train On Service, 1B MDAFW pump is tagged out.

Turnover:

• 100% power, MOL, Cb 915 ppm.

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

• CCW surge tank is low due to sampling. Refill CCW surge tank back to 45 in.

Event Malf. Event Event No. No. Type* Description 1 preset N (BOP) Refill CCW Surge Tank 2 xmt/ I (RO) PT-447, TURB FIRST STG PRESS, fails low.

PT447 TS - 3.3.1 Cond U, 3.3.2 Cond D TS (SRO) 3 R (RO) Shift Manger will direct ramp down to support Governor Valve testing.

4 xmt/ I (BOP) FT-475, 1A SG STM FLOW, fails low. (P-CT)

FT475 TS- 3.3.2 Cond D TS (SRO 5 pmps/ C (RO) 1C Charging pump experiences a sheared shaft.

NCVP01C TS - 3.5.2 Cond A TS (SRO)

-B 6 cCFCN1A C (BOP) 1A Condensate pump trips after receiving a high bearing temperature

_cc11 alarm and experiences degraded head. 1C Condensate pump will not automatically start. (P-CT) preset 7 malf/ M (ALL) Main Steam Line Break on downstream of the MSIVs MAL-MSS9 MSIVs will not automatically close if low steam line pressure is met.

preset C (BOP) MSIVs must be manually closed. (CT-12) 8 preset M (ALL) The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required.

Restore feed using Condensate pump. (CT-43)

Terminate upon exit from FRP-H.1

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario Presets Form ES-D-1 EVENT # TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-223 (Base IC-73)

CCW surge tank lowered to 37 in.

rst 223 0 0 Generic setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc5.txt 0 0 RUN PRESETS setup Tag out 1B MDAFW pump

• irf cAFP01B_d_cd1 open setup SIM IC will have CCW Surge Tank level lowered N/A 6 1A Condensate pump trips 5 minutes after the *TRG1 high bearing temperature alarm.

trg 1 "imf cCFCN1A_cc5 2 300" 6 1C Condensate pumps fails to auto start

• imf cCFCN1C_cc8 open imf cCFCN1C_cc9 open 6 1A Condensate pump degraded head *TRG 4 trg 4 imf ncfcn1a-d_th 20 300 7 MSIVs will not close on MSLIAS

• imf cRSH001A_cc5 open imf cMSH002A_d_cc5 open imf cRSH001B_cc5 open imf cMSH002B_d_cc5 open imf cRSH001C_cc5 open imf cMSH002C_d_cc5 open 8 TDAFW pump will trip *TRG2 imf MAL-FWM1C (2 0) 8 1A MDAW pump will trip on overload *TRG3 trg 3 "imf cafp01a_d_co2"

Triggers and Commands 6 Monitor 1A Condensate High Temperature alarm *TRG 4 trgset 4 "xnmkd10x >= 1" 6 Monitor 1A Condensate High Temperature alarm *TRG1 trgset 1 "xnmkd10x >= 1" 8 Monitor Rod 1 position *TRG2 trgset 2 "mcrfns(1) == 0" 8 Monitor Rod 2 position *TRG3 trgset 3 "mcrfns(2) == 0"

MCB setup OVATION Clear OVATION alarms Place danger TAG ON 1B MDAFW Pump HS on MCB Place tag on 1B MDAFWP HS Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms Unit 1 Train B Bypass & Inoperable Status Ind Panel on AFW Switch in ON EPB - AFW SYSTEM Switch in "ON IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 Start of Refill CCW surge tank exam 2 NRC PT-447, TURB FIRST STG PRESS , fails low CUE TS - 3.3.1 Cond U, 3.3.2 Cond D imf pt447 0 0 3 NRC Shift Manger will direct ramp down to support Governor CUE Valve testing.

4 NRC FT-475, 1A SG STM FLOW, fails low. (P-CT)

CUE TS- 3.3.2 Cond D imf ft475 0 15 5 NRC 1C Charging pump experiences a sheared shaft.

CUE TS - 3.5.2 Cond A imf NCVP01C-B 6 NRC 1A Condensate pump experiences degraded head and CUE trips 5 minutes after receiving a high bearing temperature alarm.

TRG3 imf kk4 failon preset 1C Condensate pump will not automatically start.

EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC Main Steam Line Break on downstream of the MSIVs CUE imf mal-mss9 3 120 MSIVs will not automatically close if low steam line preset pressure is met. MSIVs must be manually closed.

8 The Linkage on the TDAWFP will fail causing it to trip. TRG 2 & 3 1A MDAFWP Trips on Overload. FRP-H.1 entry is required.

NRC END OF EXAM:

CUE Restore feed using Condensate pump Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen5grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 IF REQUESTED cae Turbine_Bldg_MSRs.cae (10 minutes after requested, SOP-0.0 actions for a Rx trip/Safety Injection) 9.1.7 RNO of EEP-0 cae 2015_TB_MSDP_iso.cae (5 minute after requested)

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 8 IF REQUESTED Install jumpers per ATT1 of FRP-H.1 irf loa-cfw047 installed (5 minutes after requested)

Place requested AFW pumps in local at HSDP per step 5.3.1 (RNO) - DO NOT PERFORM STEP 5.3.2 (RNO)

(3 minutes after requested) (NEXT PAGE)

Place requested AFW pumps in local at HSDP per step 5.3.3.1 (RNO)

(3 minutes after requested) (NEXT PAGE)

Open V509 irf loa-cfw021 1 30 (3 minutes after requested)

Close V502A & 502B irf loa-cfw015 0 30 irf loa-cfw016 0 30 (3 minutes after requested)

Open FV-K2, FV-K3, FV-L2 irf cmf3232a_d_cd1 open irf cmf3232b_d_cd1 open irf cmf3232c_d_cd1 open (As required per comms with MCR)

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the cue and inform supervision) that type of communications 1 IF REQUESTED Chemistry: Acknowledges that CCW surge tank is being made up to.

2 IF REQUESTED Shift or Operations Manager: If the crew asks whether or not to reset C-7: What do you recommend?

Shift or Operations Manager: Agree with the crews recommendation on C-7: Do not reset C-7 or Reset C-7.

3 CUE Shift Manager: Ramp the unit to 90% for Governor Valve testing.

4 IF REQUESTED Shift Manager: If asked to place components in AUTO after the event: What do you recommend?

Shift Manager: Agree with the crews recommendation: Place (Component(s)) back in AUTO or Maintain (Component(s)) in MANUAL.

5 IF REQUESTED RAD 1 SO: 3 minutes after requested - 1C Charging pump motor is running but the pump is not rotating.

SSS: We will brief then shift 1B Charging pump to B train.

RAD 1 SO: 3 minutes after requested: FCV-122 is in the (current position). There are no obvious problems.

CHEM: We will secure the Zinc addition system.

SSS: We will brief and then rackout 1C Charging pump breaker.

6 IF REQUESTED U2 Operator: When requested - 1A Condensate pump thrust bearing is 187°F and slowly rising.

TB SO: 3 minutes after requested: The 1A Condensate pump appears normal TB SO: 3 minutes after requested (after pump tripped): 1A Condensate pump not running. No abnormal indications.

ROVER: 3 minutes after requested (after pump tripped): DA03 has an overcurrent trip flag

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

7 IF REQUESTED TBSO: 3 minutes after requested - There is no steam coming from any pipe on the MSVR roof SO (May be DB, TB or ROVER): 3 minutes after requested -

There is steam no coming from the MSVR grating TBSO: 3 minutes after requested - There is significant steam on the 155ft level of the Turbine Building. I cannot tell where it is coming from.

SSS: The 1B MDAFW pump is due back in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

TB SO: 10 minutes after requested - SOP-0.0 actions for a Rx trip/Safety Injection are complete.

RAD 1 SO: I will verify SFP cooling in service per SOP-54.0 8 IF REQUESTED ROVER: 3 minutes after requested - TDAFWP trip throttle valve linkage is broken and cannot be reset.

ROVER: 3 minutes after requested - 1A MDAWP is not running. No obvious problems noted.

ROVER: 3 minutes after requested - DF-10 has an overcurrent trip flag.

SSS: Align makeup to the CST from water treatment plant OR demin water system using FNP-1-SOP-5.0, DEMINERALIZED MAKEUP WATER SYSTEM, as necessary.

TB SO: 3 minutes after requested - Back up cooling is aligned to the Condensate pumps.

SSS: Coordinate performance of Step 5.3.1 through (XXX) RNO of FRP H.1 for the ( pumps asked for).

SSS: 3 minutes after place in local: The (pumps requested) did not start at the HSDP.

SSS: Coordinate performance of Step 5.3.3.1 of FRP H.1 for the (pumps asked for).

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

8 cont SSS: 5 Minutes after requested - Jumpers are install per ATT 1 of FRP-H.1 TB SO: 3 minutes after requested - V509 is open.

Action Buttons are TB SO: 3 minutes after requested - V502A & V502B are above closed.

RAD 1 SO: 3 minutes after requested - Standing by in the 139ft penetration room to operate breakers.

(When directed to open breakers, open the requested breakers using LOAs above and proper 3 way communications)

Appendix D Scenario Detailed Summary Form ES-D-1 Initial Conditions: 95% power, MOL, Cb 915ppm, A Train On Service, 1B MDAFW pump is tagged out.

Turnover:

• 95% power, MOL, Cb 915 ppm, ramping up.

• A Train On Service, A Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

• CCW surge tank is low due to sampling. Refill CCW surge tank back to 45 in.

EVENT 1: Refill the CCW Surge tank.

Verifiable actions: BOP will open 2 surge tank fill valves and monitor level. When level reaches 45 inches, the valves will be closed.

EVENT 2: PT-447, TURB FIRST STG PRESS, fails low.

Verifiable actions: RO will place rods in manual to stop rod motion. SRO - Tech Spec:

3.3.1 Cond U, 3.3.2 Cond D.

EVENT 3: Shift Manager directs a ramp down to support Governor Valve testing.

Verifiable actions: RO use rods and Boron to reduce power.

.EVENT 4: FT-475, 1A SG STM FLOW, fails low.

Verifiable actions: BOP takes manual control of 1A FRV and SGFP speed and restores SGWL. SRO - Tech Spec: 3.3.2 Cond D.

(P-CT) If the BOP fails to properly control SGWL a LOLO Level Reactor trip will occur if 1 SG reaches 28% or if 1 SG reaches 82% a turbine trip will occur causing a reactor trip.

EVENT 5: 1C Charging pump experience a sheared shaft.

Verifiable actions: RO isolates letdown by closing Letdown Orifice Isolations and starts another Charging pump. SRO - Tech Spec: 3.5.2 Cond A EVENT 6: 1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start.

Verifiable actions: BOP will start the standby Condensate pump manually.

(P-CT) If the BOP does not start the standby Condensate pump promptly, the SGFPs will trip on low suction pressure which wiil require a manual Reactor trip. If SGWL is not controlled after the Condensate pump is started a Rx trip may be required due to a FW isolation from overfeeding the SGs.

EVENT 7: Main Steam Line break downstream of the MSIVs.

Verifiable actions: BOP will have to close MSIVs. (CT-12)

EVENT 8: 1A MDAFW pump trips and the linkage on the TDAWF pump fails. FRP H.1 entry required.

Verifiable actions: Restore Feed using a Condensate pump. (CT-43)

Similar to Audit - Audit exam designed to restore feed using a SGFP.

Terminate on Exit from FRP-H.1

Appendix D Scenario Critical Tasks Form ES-D-1

_____ 1. Manually actuate main steamline isolation before a severe (ORANGE path) challenge develops to either the subcriticality or the integrity CSF or before transition to ECA-2.1 whichever happens first. (CT-12)

_____ 2. Establish feedwater flow into at least one SG [before RCS bleed and feed is required. (CT-43)

SCENARIO At power power instrument and component failures with a Steam Break outside OBJECTIVE/ Containment followed by a loss of Secondary Heat Sink.:

OVERVIEW:

• refill the CCW Surge Tank

• reduce reactor and turbine power

• respond to PT-447, TURB FIRST STG PRESS, failing low

• restore SGWL on a failure of FT-475, 1A SG STM FLOW, low

• respond to a Charging pump sheared shaft

• respond to a loss of Condensate pump

• respond to a Steam Break down stream of the MSIVs

• restore Secondary Heat Sink.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 2

2. Abnormal events (2-4) 4

3. Major transients (1-2) 2

4. EOPs entered/requiring substantive actions (1-2) 0

5. EOP contingencies requiring substantive actions (0-2) 1

6. Critical tasks (2-3) 4

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 1, 100% RTP, 915 ppm Cb, MOL 10000 MWD/MTU,

-2740pcm Xe (Equilibrium)

A Trn O/S / A Trn Protected / SFPC on A Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 167 hours0.00193 days <br />0.0464 hours <br />2.761243e-4 weeks <br />6.35435e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. 1B MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />

3. CCW surge tank low due to sampling. Refill to 45 in.

4.

5.

6.

7.

8.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas) 1B MDAFW pump - 3.7.5 Cond B LCO status (planned- entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago) #1 RHT Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __1___ Page 1 of 2 Event

Description:

Refill the CCW surge tank. The CCW Surge tank will be at 37 in due to sampling and the operating crew will be required to refill it.

Indications Available

- LI-3027A & B, CCW SRG TK LVL are reading 37 in.

Time Position Applicants Actions or Behavior Comments SOP-23.0, COMPONENT COOLING WATER SYSTEM, ver 94.2 BOP 4.18.1 Contacts Chemistry Notify Shift Chemist that the CCW surge tank is to be made up to.

BOP 4.18.2 Verify open CCW SRG TK VT valves:

(MCB)

Q1P17SV3028A Q1P17SV3028B BOP 4.18.3 Monitor CCW surge tank level indications.

LI-3027A LI-3027B BOP 4.18.4 Maintain level between 35 inches and 50 inches.

BOP 4.18.5 One of the 2 valves must be IF desired, THEN open MKUP TO CCW opened to fill the CCW FROM DW STOR TK Q1P17MOV3030A surge tank or the operator to add makeup to A portion of CCW surge can open BOTH valves.

tank.

BOP 4.18.6 IF desired, THEN open MKUP TO CCW FROM DW STOR TK Q1P17MOV3030B to add makeup to B portion of CCW surge tank.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __1___ Page 2 of 2 Event

Description:

Refill the CCW surge tank. The CCW Surge tank will be at 37 in due to sampling and the operating crew will be required to refill it.

Time Position Applicants Actions or Behavior Comments BOP 4.18.7 Will close the valves WHEN makeup addition is completed, opened in Steps 4.18.5 THEN close appropriate valve(s). and/or 4.18.6 MKUP TO CCW FROM DW STOR TK Q1P17MOV3030A.

MKUP TO CCW FROM DW STOR TK Q1P17MOV3030B.

After filling is completed or at the discretion of the Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __2___ Page 1 of 4 Event

Description:

PT-447, TURB FIRST STG PRESS, fails low.

Indications Available

- TAVG / TREF DEV (HF3) Indications of PT-447 failing low:

- HI STM FLOW ALERT (JB4) - PI-447 decreases to 0 psig

- TI-408A TAVG - TREF increases to +5°F

- TR-408 HIGH TAVG / TREF

- TREF Decreases to 547 °F

- Loss of Load Interlock C-7A light on BYP and Permissive Panel lights up

- TSLB4 channel 4 bi-stable lights 16-3; 17-3; 18-3, for loops 1; 2; & 3 Hi Steam Flow Illuminate

- Control Rods step in at 72 steps per minute IF ROD CONTROL IN AUTO Steam Dump Loss of Load Controller is armed.

Time Position Applicants Actions or Behavior Comments RO Recognizes rods moving in unexpectedly SRO If not taken by RO, directs immediate operator actions of AOP-19, Malfunction of Rod Control System ver 30 AOP-19.0, MALFUNCTION OF ROD CONTROL SYSTEM, ver 30 RO 1 Immediate operator action IF undesired rod motion occurring, THEN stop rod motion.

2 1.1 IF rod control in AUTO, THEN place rod control in MANUAL.

1.2 Check Rod motion - STOPPED.

RO 2 Evaluate undesired rod motion.

2.2 2.1 Check N-44 Operable YES 2.2.1 2.2 Check selected Pimp channel NO Operable.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __2___ Page 2 of 4 Event

Description:

PT-447, TURB FIRST STG PRESS, fails low.

Time Position Applicants Actions or Behavior Comments SRO 2.2 Section 1.3 Go to FNP-1-AOP-100.0, INSTRUMENTATION MALFUNCTION, ver 15 AOP-100, INSTRUMENTATION MALFUNCTION, Section 1.3, ver 15 RO 1 Check no load rejection in progress.

RO 2 IF the selected channel of Pimp has failed, THEN select the unaffected channel.

3 2.1 Verify control rods in MANUAL.

2.2 FIRST STG IMPULSE PRESS SEL SWITCH PS/446Z

[ ] PT-446 (CH-III) selected OR

[ ] PT-447 (CH-IV) selected 2.3 Check C5 permissive light on.

LOW TURB IMPULSE PRESS AUTO ROD WDRL

[ ] BLOCKED C lit RO/BOP 3 Uses rods, boron, turbine IF required, controls to restore Tavg THEN restore Tavg to programmed value.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __2___ Page 3 of 4 Event

Description:

PT-447, TURB FIRST STG PRESS, fails low.

Time Position Applicants Actions or Behavior Comments 4

Refer to Tech Spec 3.3.1 & 3.3.2 for LCO See below requirements.

TECHNICAL SPECIFICATION 3.3.1, Reactor Trip System (RTS) Instrumentation The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

Table 3.3.1-1 Reactor Trip System Instrumentation Function 17f - Turbine Impulse Pressure, P-13 Applicable in Mode 1 2 required channels condition U SRO CONDITION REQUIRED ACTION COMPLETION TIME U. One channel U.1 Verify interlock is in inoperable. required state for existing unit 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> conditions.

OR M.2 Be in Mode 2. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> TECHNICAL SPECIFICATION 3.3.2, Engineered Safety Feature Actuation System (ESFAS)

Instrumentation The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE.

Table 3.3.2-1 ESFAS Instrumentation Function 4e - High Steam Flow in Two steam lines Applicable in Mode 1 required channels- 2 per steam line condition D SRO CONDITION REQUIRED ACTION COMPLETION TIME D. One channel -----------------NOTE-----------

inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.

D.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR D.2.1 Be in mode 3 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> AND D.2.2 Be in mode 4 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br />

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __2___ Page 4 of 4 Event

Description:

PT-447, TURB FIRST STG PRESS, fails low.

Time Position Applicants Actions or Behavior Comments 5 Contacts SM Notify the Shift Manager RO 6

[CA] WHEN Tavg is within +/-1°F of Tref AND plant conditions permit, THEN return rod control to auto.

RO 7 Has RO/BOP contact Submit a condition report documenting appropriate personnel the failure and notify the Work Week Coordinator (Maintenance ATL on back shifts) of the condition report.

SRO 8 This should not be IF PT-447 failed, AND it is desired to reset performed C-7A, THEN go to FNP-1-SOP-18.0, STEAM DUMP SYSTEM.

SRO 9 Go to procedure and step in effect.

At Lead Examiners discretion, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 1 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Indications Available Rx power lowering.

Time Position Applicants Actions or Behavior Comments SRO Directs the RO / BOP to commence ramp down to <90%

UOP-3.1, Power Operation, Section 8, ver 120 BOP 1.

Review and perform the following as required BOP a This step is N/A If Turbine Overspeed Test is to be performed, Refer To Section 3.0 Precaution and Limitation 1.l prior to commencing ramp...

BOP b For normal load reductions, a ramp rate restriction of 2 MW/min (14% per hour) will apply............................................................

BOP c This step is N/A When conditions warrant a ramp rate of greater than 2 MW/min, notify the Shift Manager as soon as conditions permit.

BOP d This step is N/A Enter FNP-1-AOP-17.1, RAPID TURBINE POWER REDUCTION in conjunction with this procedure for ramp rates greater than 5 MW/min.........

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 2 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments BOP e This step is N/A Ramp as slow as possible if known fuel leak exists. Power decreases should follow the guidance found in Attachment 1, Special Load Rate Limitations.

BOP f This step is N/A If a power reduction is being performed due to entry into Technical Specifications 3.4.16, adjust the ramp rate to meet the shutdown requirements of the specification.

BOP g This step is N/A If a reactor shutdown is NOT for a refueling outage, record criticality data in the Control Room Log prior to load decrease.

BOP h Maintain valve position limit 115% while ramping or at 100%.

BOP i This step is N/A Maintain valve position 8 to 10% above valve position demand when holding for more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at some power level less than 100%.

BOP j This step is N/A Flush and sample AFW pump suction piping as required by FNP-1-SOP-22.0 ,

Auxiliary Feedwater System, prior to initiation of AFW flow to the SGs.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 3 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments BOP 2 BOP place IMP loop in While ramping between 97% and 20% service per step 2 power, verify the IMP PRESS LOOP in service as follows:

BOP a Verify Turbine on HOLD. ..............

BOP b Check Ovation point, 1ST STG IMPLS PRESS, has stable indication.

BOP c On LOOP STATUS of page 5551, press SELECT BOP d On popup 7053, press IMP BOP e On popup 7059, press IMP LOOP IN.

BOP f On LOOP STATUS of page 5551, check IMPULSE displays YES BOP 3 On page 5551, perform the following to set desired load target and load rate.................

a On RAMP INTERFACE section, press MODIFY b

On TARGET SELECTION section of BOP inserts ramp to <90%

popup 7055, enter desired target using one of the following methods:

• Using predefined buttons.

• Using CUSTOM button to enter custom rate

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 4 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments c

On RAMP INTERFACE section of page 5551, check desired target appears under TARGET.

d On page 5551, check HOLD button has gold background e

IF desired to change load rate, on RAMP INTERFACE section of page 5551 press MODIFY.

(1)

On popup 7055, enter desired rate by either of the following Using predefined buttons.

Using predefined buttons.

(2)

On RAMP INTERFACE section of page 5551, check desired rate appears under RATE.

4 Inform other Control Room operators load will be changed.

5 Press GO to commence ramp.

BOP 6 Verify proper SGFP speed control.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 5 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments RO 7 Attempt to maintain the axial flux difference within + 5% from the target value by making adjustments in rod height and/or boron concentration as necessary...........

RO Uses Borations to lower Tavg during the ramp SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix B, v60.1 RO 1.1 From reactivity briefing IF necessary, THEN set the boric acid sheet integrator to the desired quantity.

RO 1.2 IF necessary, THEN adjust LTDN TO VCT FLOW LK 112 setpoint as desired.

1.3 Position the MKUP MODE CONT SWITCH to STOP.

1.4 Position the MKUP MODE SEL SWITCH to BOR.

1.5 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 6 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments RO 1.6 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.7 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.8 This step is N/A If desired to clear the line of acid, perform the applicable steps of Appendix B Section 2.0.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 7 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments Note: If the crew decides to remain lined up for repetitive borations, then steps 1.9 -

1.11 are N/A. Repetitive boration steps are listed in Appendix C below.

RO 1.9 Position the MKUP MODE SEL SWITCH to AUTO.

1.10 Position the MKUP MODE CONT SWITCH to START.

1.11 IF LK 112 setpoint was adjusted per Step 1.2, THEN return setpoint to that required for current conditions.

SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM, Appendix C, v60.1 RO 1.1 IF necessary, THEN set FIS-113 Boric Acid Batch Integrator to the desired quantity.

1.2 The Reactor Makeup Control system has been previously aligned for Boration.

1.3 Position the MKUP MODE CONT SWITCH to START.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 8 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments RO 1.4 Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B opens.

BORIC ACID TO BLENDER Q1E21FCV113A opens.

Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

RO 1.5 Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR Q1E21FCV113B closes.

BORIC ACID TO BLENDER Q1E21FCV113A closes.

RO 1.6 IF repetitive borations are no longer required THEN verify the system is aligned for Automatic makeup per Steps 1.9 through 1.11 of Appendix B.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __3___ Page 9 of 9 Event

Description:

Shift Manager will direct ramp down to 90% to prepare for Governor Valve testing.

Using rods and boron, reduce power to <90%.

Time Position Applicants Actions or Behavior Comments SOP-41.0, Control Rod Drive and Postion Indication System, Ver 37 OPERATOR AID FOR CONTROL ROD MOVEMENT RO 1 Place ROD CONTROL BANK SELECTOR SWITCH in MAN.

RO 2 Check indicated control rod speed is approximately 48 steps per minute on SI-408.

RO 3 Insert OR withdraw Control Rods using the CONTROL ROD MOTION switch.

RO 4 When desired, place rod control in AUTO as follows:

RO 4.1 Verify Tavg within 1°F of Tref.

RO 4.2 Place the ROD CONTROL BANK SELECTOR SWITCH in AUTO.

RO 4.3 Check indicated control rod speed is approximately 8 steps per minute on SI-408.

After the ramp or at the Lead Examiners discretion then move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 1 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Indications Available

- 1A SG FEED FLOW > STM FLOW (JG2) - Recognize indications of FT-485 failing low:

- 1A SG LVL DEV (JF2) FT-475 fails low - meter dropping to 0 1A FRV position closing

- SG NR level lowering Time Position Applicants Actions or Behavior Comments BOP Recognizes the malfunction and take Immediate Operator Actions of AOP-100, Section 1.5 SRO Directs Immediate Operator Actions of AOP-100 if not performed by the RO/BOP AOP-100, INSTRUMENTATION MALFUNCTION, Section 1.5, ver 15 1 Immediate Operator Action.

[CA] Maintain SG level at the referenced level of 65%. Potential Critical Task -

11 May lose SGWL control 1.1 and cause a Rx Trip.

IF required, THEN, take manual control of SGFP speed control as necessary to restore SG level to 65%

11.1 SGFP master controller

[ ] SK-509A OR SGFP individual controllers as needed.

[ ] SK-509B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 2 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Time Position Applicants Actions or Behavior Comments 1.2 IF required, Potential Critical Task -

THEN take manual control of the affected May lose SGWL control feedwater regulating valves or bypass and cause a Rx Trip valves.

1.2 1.2

[ ] 1A SG FW FLOW FK-478

[ ] 1B SG FW FLOW FK-488

[ ] 1C SG FW FLOW FK-498 OR

[ ] 1A SG BYPASS FLOW FK-479

[ ] 1B SG BYPASS FLOW FK-489

[ ] 1C SG BYPASS FLOW FK-499 1.3 This step is N/A unless 1.3 IF a loss of main feedwater has SGWL exceeds 82% and a occurred, FW isolation occurs THEN perform the actions required by FNP-1-AOP-13.0, LOSS OF MAIN FEEDWATER.

2 IF adverse trend in SG level exists, THEN establish trip criteria.

3 IF a ramp is in progress, THEN place Turbine on HOLD.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 3 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Time Position Applicants Actions or Behavior Comments 4 Determines 1A S/G CH-IV Determine if an instrument failure has has malfunctioned occurred.

4 4.1 Check for a failed or erroneous indications from the following steam flow or feed flow indicators.

4.2 This step is N/A Check for failed or erroneous readings on the following SG pressure indicators:

4.3 IF the alarm(s) was due to a SGWLC System controlling channel failure, THEN select the unaffected channel for STM FLOW AND FW FLOW for the SG associated with the failure.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 4 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Time Position Applicants Actions or Behavior Comments 4.3.1 Selects Channel III on Place the following handswitches to the FS/478Z and FS/478Y appropriate channel III OR IV position as required: ALL switches may be placed in Channel III position (either way is correct) 4.3.2 Verify proper system response.

5 See below Refer to Tech Specs 3.3.1, 3.3.2 & 3.3.3 for any LCO requirements.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 5 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

TECHNICAL SPECIFICATION 3.3.2, ESFAS Instrumentation The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE Table 3.3.2-1 ESFAS Instrumentation Function 4e - High steam flow in two steam lines coincident w/ lo-lo Tavg Applicable in Modes 1, 2 and 3 with MSIVs open required channels - 2 per stm line - condition D CONDITION REQUIRED ACTION COMPLETI ON TIME D. One channel D.1 ------NOTE--------

inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.

Place channel in trip. 72 hrs OR D.2.1 Be in MODE 3. 78 hrs AND D.2.2 Be in MODE 4. 84 hrs

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __4___ Page 6 of 6 Event

Description:

FT-475, 1A SG STM FLOW, fails low. TS- 3.3.2 Cond D. 1A FRV will close, SGFP will lower and SG NR level will decrease.

Time Position Applicants Actions or Behavior Comments 6

Notify the Shift Manager.

7 Requests SM permission to

[CA] WHEN plant conditions permit, place controllers in AUTO THEN return systems to automatic and then place them in control. AUTO 8

Submit a condition report for the failed Has RO/BOP contact the instrument, and notify the Notify the appropriate people Work Week Coordinator (Maintenance ATL on backshifts)of the condition report.

9 Go to procedure and step in effect.

At the discretion of the Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 1 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Indications Available

- EA2, CHG HDR FLOW HI-LO - FI-122 goes to 0

- DD1, RCP SEAL INJ FLOW LO - 1C Charging pumps amp lower

- VCT level rising

- PRZR level decreasing Time Position Applicants Actions or Behavior Comments RO Announces the alarms and / or recognizes the loss of flow and inform the SRO SRO Directs ARP entry RO Calls RAD 1 SO to investigate Note: when the crew determines that the 1C Charging pump has a sheared shaft, they may secure it since it is damaged.

Note: Crew may decide to secure letdown using the MCB placard. The steps are listed below. If they chose to go to AOP-16, they are on page 3 SOP-3.2, CVCS Plant Startup and Operation, ver 135 RO 1 Place PK-145 in MANUAL and adjust demand to less than or equal to 50%.

RO 2 Close LTDN ORIF ISO 45 GPM, Q1E21HV8149A AND LTDN ORIF ISO 60 GPM, HV8149B OR HV8149C, as applicable.

RO 3 Close LTDN LINE ISO, Q1E21LCV459 and Q1E21LCV460 RO 4 Place FK-122 in MANUAL and adjust to 0% (closed).

RO 5 Verify SEAL WTR INJECTION HIK 186 adjusted.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 2 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 6 Refer To SOP-2.1 when time permits.

ARP-1.5, EA2, CHG HDR FLOW HI-LO, ver 58.2 RO 1 This step is N/A IF the alarm is due to a high flow condition coincident with selecting a different control channel on LS/459Z, THEN consideration should be given to refer to FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION, section 4.6, Charging Flow Control and take manual control of pressurizer level until system equilibrium is restored and pressurizer level control can be returned to automatic.

RO 2 This step is N/A IF desired to control a rapidly rising pressurizer level, THEN close Q1E21MOV8107 or Q1E21MOV8108, CHG PUMPS TO REGENERATIVE HX.

2.1 Remove letdown from service using the MCB Operator Aid (plaque) OR FNP SOP-2.1, Chemical and Volume Control System Plant Startup and Operation.

SRO For a CVCS malfunction during normal plant operations, Go To FNP-1-AOP-16.0, CVCS MALFUNCTION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 3 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments ARP-1.4, DD1, RCP SEAL INJ FLOW LO, ver 54.2 RO 1 IF a loss of seal injection flow has occurred AND a loss of Component Cooling Water to the Thermal Barrier Heat Exchanger has occurred AND at least one method of seal cooling cannot be immediately restored, THEN go to FNP AOP-4.1, ABNORMAL REACTOR COOLANT PUMP SEAL LEAKAGE.

RO 2 Determine the cause of the alarm.

SRO 3 For a CVCS malfunction, go to FNP AOP-16.0, CVCS MALFUNCTION AOP-16.0, CVCS MALFUNCTION, ver 20 RO 1 Verify CHG flow adequate to cool letdown

[] CHG FLOW - FI-122A

[] LTDN HX OUTLET FLOW - FI-150

[] REGEN HX OUTLET TEMP - TI-140 RO 1 (RNO)

Isolate Normal Letdown as follows:

1.1 (RNO)

Verify closed all LTDN ORIF ISOs:

[] Q1E21HV8149A

[] Q1E21HV8149B

[] Q1E21HV8149B RO 2 Stop any load change in progress

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 4 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 3 This step is N/A If charging line rupture occurs then go to attachment 2 4

Monitor VCT level 5

Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation PI-121 and ammeter for chg pump RO 5 (RNO)

IF VCT level reduces to 5%, THEN perform the following:

5.1 Open RWST TO CHG PUMP valves

[] Q1E21LCV125B

[] Q1E21LCV125D 5.2 Close VCT OUTLET ISO valves

[] Q1E21LCV125C

[] Q1E21LCV125E RO 6 Crew will have to determine Check charging pump - RUNNING that the 1C Charging pump is effectively not running or they may have secured it earlier

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 5 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 6 (RNO)

Start an available charging pump as follows:

6.1 Check VCT level and pressure adequate.

6.2 Verify charging suction flowpath aligned:

VCT OUTLET ISO valves

[] Q1E21LCV125C - OPEN

[] Q1E21LCV125E - OPEN OR RWST TO CHG PUMP valves

[] Q1E21LCV125B - OPEN

[] Q1E21LCV125D - OPEN RO 6.3 (RNO)

Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB.

RO 6.4 (RNO)

Check open minflow isolation for charging pump to be started

• 1A CHG PUMP MINIFLOW ISO Q1E21MOV8109A RO 6.5 (RNO)

Verify CHG PUMP MINIFLOW ISO, Q1E21MOV8106, is open RO 6.6 (RNO)

Verify the following are closed;

[] CHG FLOW FK 122

[] SEAL WTR INJECTION HIK 186

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 6 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 6.7 (RNO)

Verify a CCW pump is running in same train aligned to supplycharging pump to be started RO 6.8 (RNO)

Start selected charging pump RO 6.9 (RNO)

Observe CHG HDR PRESS indicator PI 121 and motor ammeter to check proper pump operation RO 6.10 (RNO)

WHEN charging pump comes up to speed.

THEN check auxiliary oil pump stops as indicated by white light NOT being illuminated on MCB.

RO 6.12 (RNO)

Adjust SEAL WTR INJECTION HIK 186 to maintain 6-13 gpm seal injection flow to each RCP RO 6.12 (RNO) This step is N/A IF all seal cooling lost to any RCP, THEN go to AOP-4.1, ABNORMAL REACTOR COOLANT PUMP SEAL LEAKAGE RO 7 Check Charging flow FK-122 controlling in AUTO with flow indicated RO 7 (RNO)

IF required. THEN take manual control of charging flow:

RO 7.1 (RNO)

Place FK-122 in manual and adjust as required to maintain pressurizer level at program level.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 7 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 7.2 (RNO)

Adjust SEAL WTR INJECTION HIK-186 as required to maintain RCP seal injection flow 6-13 gpm RO 7.3 (RNO) If manual control of charging This step is N/A not accomplished. THEN refer to ATT 1, MANUAL CONTROL OF CHARGING RO 8 Check to following annunciator -CLEAR

[] DE3 LTDN ORIF ISO VLV REL LINE TEMP HI RO 9 Determine Status of Normal Letdown:

9.1 Check normal CVCS letdown -

AFFECTED BY MALFUNCTION

• LTDN HX OUTLET FLOW, FI-150 - NO FLOW INDICATED

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 8 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 9.2 Minimize RCS makeup:

9.2.1 Manually close FK-122 9.2.2 Minimize seal injection between 6-13 gpm 9.2.3 Direct Chemistry to shutdown the zinc addition system (ZAS)

RO 9.3 Dispatched personnel Dispatch personnel to investigate cause of earlier letdown malfunction RO 9.4 This step is N/A If desired due to plant conditions, place excess letdown on service RO 10 Determine if normal letdown should be re-established:

10.1 Check normal letdown malfunction(s) -

CORRECTED 10.2 Verify all letdown orifice isolation valves -

CLOSED LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 9 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 10.3 Place LTDN HX OUTLET TEMP TK-144 on service:

[] Place controller in AUTO

[] Set to maintain temp 90 (Pot setting 2.7) to 125°F (Pot setting 4.35)

RO 10.4

[] Position indicator VCT light - LIT

[] Handswitch in-AUTO RO 10.5 Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143

[] Handswitch in - VCT

[] VCT light - LIT

[] DEMIN light - NOT LIT RO 10.6 IF necessary, THEN OPEN both LTDN LINE PENE RM ISOs from the Penetration Room Isolation Panel.

[] Q1E21HV8175A

[] Q1E21HV8175B RO 10.7 Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN RO 10.8 Verify LTDN LINE ISO valves - OPEN

[] Q121LCV459

[] Q121LCV460 RO 10.9 Verify LP LETDN PRESS PK 145 on service:

[] Place controller in MANUL

[] Adjust demand signal o 50% or less Time Position Applicants Actions or Behavior Comments

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 10 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

RO 10.10 Initiate minimum charging flow:

10.10.1 Verify CHG FLOW FK 122 in MAN 10.10.2 Establish minimum charging flow based on orifices to be placed on service:

• 1 Orifice - 18 gpm or

• 2 Orifices - 40 gpm RO 10.12 Establish approx. 60 gpm letdown flow by OPENING:

Q1E21HV8149B OR Q1E21HV8149C RO 10.12 If desired place the second orifice on service by opening Q1E21HV8149A RO 10.13 Will take no action at this Initiate actions to restore letdown flow to time, very time consuming demins per SOP-2.1 RO 10.14 IF all backup heaters energized due to pressurizer level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 11 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments RO 10.15 Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure -

BETWEEN 260-450 psig 10.15.1 Set controller between 4.3 and 7.5 10.15.2 Check letdown flow - STABLE 10.15.3 Place PK 145 in AUTO 10.15.4 Control Letdown pressure as desired RO 10.16 Control LTDN HX OUTLET TEMP TK 144 to maintain Letdown temperature 90 to 125°F

[] TI-126 VCT TEMP

[] TI-143 DIVERT LTDN HX TEMP

[] TI-144 CCW LTDN HX TEMP RO 10.7 Refer to SOP-2.1 for further guidance on Letdown system control RO 11 Determine status of letdown flow:

11.1 Check letdown flow - ESTABLISHED

• Normal letdown flow OR

• Excess letdown flow SRO 11.2 Go to procedure and step in effect

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __5___ Page 12 of 12 Event

Description:

1C Charging pump experiences a sheared shaft and cause low charging flow.

TS - 3.5.2 Cond A.

Time Position Applicants Actions or Behavior Comments TECHNICAL SPECIFICATION 3.5.2, ECCSOperating Two ECCS trains shall be OPERABLE.

B Train ECCS is INOPERABLE until the 1B chg pump is aligned to B Train and the 1C Chg pump is tagged out or a jumper is installed to permit the 1B Chg pump to auto start Condition A CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore train(s) to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> trains OPERABLE status.

Inoperable AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

At the discretion of the Lead Examiner move to Event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 1 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Indications Available

- KK4, BRG MON PNL ALARM - SGFP suction pressure falls after the 1A Condensate pump trips

- SGFPs trip if no action taken Time Position Applicants Actions or Behavior Comments ARP-1.10, KK4, BRG MON PNL ALARM, ver 72.1 BOP 1 Call U2 operator and Determine the bearing in the alarmed receives the temperature as condition by checking the front panel 187°F and slowly rising LED'S.

BOP 2 SRO may elect to start 1C IF possible, THEN start a standby Condensate pump here component and remove the alarming Component from service.

BOP 3 IF a standby component is NOT available, THEN notify the Shift Supervisor of the alarm and let him evaluate the plant conditions and recommend a course of action to be taken.

BOP 4 Periodically monitor Bearing and determine if temperature is increasing or has stabilized.

BOP 5 Notify appropriate personnel to investigate and repair.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 2 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments NOTE: SOP-0.8, Transient Response Procedure User's Guide, allows the operator to simply start the 1C Condensate pump. This is the expected action and an entry into AOP-13 may only be performed to address other plant parameters out of specification.

4.2.8.3 Operators are expected to take manual action to address non-ESF components which fail to actuate (with the exception of starting a DG, closing a DG output breaker or starting a charging pump) when systems parameters indicate that actuation should have occurred unless the manual action would create a condition that would not mitigate a transient. No permission is required prior to acting. Operators are also expected to take manual action to secure components which do not have support conditions. The Shift Supervisor should be informed as soon as possible after initiating the manual action.

AOP-13, Condensate and Feedwater Malfunction, ver 37 NOTE: AOP-13 can be entered directly at the step for the malfunction BOP 6 Check SGFP suction pressure -

ABNORMAL.

a Check SGFP suction pressure stabilizes above 275 psig.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 3 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP 6a (RNO) Potential critical task - If Perform the following the 1C Condensate pump is not started then a SGFP (1) trip (both pumps) will Verify standby condensate pump occur and a Rx trip will be started. required.

(2)

IF suction pressure still falling, THEN reduce turbine load rapidly using FNP-1-AOP-17.1, RAPID TURBINE POWER REDUCTION.

(3)

IF SGFP(s) trip occurs, THEN return to Step 1.

(4)

If SGFP speed is elevated return to Step 3 OBSERVE CAUTION prior to Step 3.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 4 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP 3 Potential critical task- If Check indication of any SGFP SGWL is not controlled a malfunction RX trip may be required due to overfeeding the

- Any SGFP speed abnormal SGs

- SGFP discharge Pressure - low 1A(1B) SGFP DISCH PRESS PI 4018A(B)

-Feedwater header pressure - low FW HDR BOP a Take manual control of SGFP(s) speed controllers as necessary to control speed and restore feedwater header pressure above steam header pressure.

SGFP master controller

[] SK-509A OR SGFP individual controllers as needed.

[] SK-509B

[] SK-509C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 5 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP b Take manual control of the affected feedwater regulating valves or bypass valves as necessary to control SG level.

[] 1A SG FW FLOW FK-478

[] 1B SG FW FLOW FK-488

[] 1C SG FW FLOW FK-498 OR

[] 1A SG BYPASS FLOW FK-479

[] 1B SG BYPASS FLOW FK-489

[] 1C SG BYPASS FLOW FK-499 BOP c Check no reactor protection system automatic actions required or set points being approached.

BOP d IF a ramp is in progress, THEN place Turbine on HOLD BOP e Verify adequate SGFP function restored.

BOP f Maintain SG narrow range level approximately 65%.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 6 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP g Check SGFP speed control instrumentation - NORMAL

[] PI-464A

[] PI-508

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 7 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP h Adjust speed back to within the normal operating range for the feed flow/steam flow DP for the existing power level.

Approximate DP can be determined from the following MCB indications.

[] SGFP DISCH PRESS PI4003

[]SG Pressure indications BOP i Check Hotwell level maintained 30 to 24 by HOTWELL LEVEL controller (CP-4055F) in Auto.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 8 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP 4 Check main feed regulating valve(s) automatic control inadequate.

a Take manual control of the affected main feedwater regulating valves or bypass valves as necessary to control SG level.

[] 1A SG FW FLOW FK-478

[] 1B SG FW FLOW FK-488

[] 1C SG FW FLOW FK-498 OR

[] 1A SG BYPASS FLOW FK-479

[] 1B SG BYPASS FLOW FK-489

[] 1C SG BYPASS FLOW FK-499 BOP b Maintain SG narrow range level approximately 65%.

BOP c Check main feedwater regulating valve control instrumentation -

NORMAL

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 9 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP 5 RNO - Go to step 6 Check Feedwater Heaters operation adversely affected.

BOP 6 RNO - Go to step 7 Check SGFP suction pressure -

ABNORMAL.

BOP 7 Verify plant conditions stable a

Verify Reactor power within limits

- DT < 100% value (Computer points TC0429, TC0449, & TC0469)

- Thermal Power < 2775 MWt (Computer point QC4621M6)

- NIs less than 100%

BOP b Stabilize TAVG by adjusting rod position and/or boron concentration.

- Manual Rod Control

- Manual boration per FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM.

- Emergency boration per FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL SYSTEM REACTOR MAKEUP CONTROL SYSTEM Figure 6.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 10 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP c Verify automatic operation of the feedwater regulating valves.

[] 1A SG FW FLOW FK 478

[] 1B SG FW FLOW FK 488

[]1C SG FW FLOW FK 498 d

Verify SG narrow range levels maintained approximately 65%.

e Monitor feedwater flow and steam flow.

f Verify that feedwater and steam flow trend to approximately equal values for the target, turbine load.

BOP g Check LOSS OF LOAD INTERLOCK C-7A on the BYP & PERMISSIVES panel NOT illuminated.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 11 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP h Check reactor power change < 15%

i Check parameters within limits for continued at power operation.

- Pressurizer level greater than 15%

- Pressurizer pressure greater than 2100 psig

- SG narrow range levels 35%-75%

- TAVG 541F - 580F

- Control rod bank position Lo-Lo Annunciator FE2 Clear

- Delta I within limits specified in the COLR BOP j Check condensate and feedwater function stabilized.

BOP k Check Hotwell level maintained 30 to 24 by HOTWELL LEVEL controller (CP-4055F) in Auto.

BOP l Refer to FNP-1-SOP-21.0 and perform any local actions required to secure any tripped SGFP and its auxiliary systems.

BOP m Adjust reactor power and turbine load to maintain as necessary to maintain REACTOR THERMAL POWER 1 HOUR AVG (Computer point QC4621HR8)< 2775 MWt.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __6___ Page 12 of 12 Event

Description:

1A Condensate pump experiences degraded head and trips 5 minutes after receiving a high bearing temperature alarm. 1C Condensate pump will not automatically start. (P-CT).

Time Position Applicants Actions or Behavior Comments BOP n Check reactor power remained below 100%.

BOP o Go to procedure and step in effect SRO Notifies Shift Manager.

SRO Once stabilized, directs any controller in MANUAL back to AUTO if no malfunction existed.

At discretion of Lead Examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 1 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Indications Available

- MH1, FIRE - MSVR - RCS pressure lowering

- Rx power rising - Feed system demand increasing (FRV / SGFP Speed)

Time Position Applicants Actions or Behavior Comments AOP-14, SECONDARY SYSTEM LEAKAGE, ver 11 1 SRO should go to Step 2 IF leakage is such that significant hazard and not trip here to personnel or equipment exists OR leakage rate is unstable and is worsening, THEN:

1.1 Trip the reactor.

1.2 WHEN reactor trip is verified, THEN close MSIVs and bypass valves.

1.3 Go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 2 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 2 SRO should go to Step 3

[CA] Monitor plant status for safe and not trip here operation.

• Pressurizer level GREATER THAN 15%

AND

• Pressurizer pressure GREATER THAN 2000 psig AND

• Steam generator pressure GREATER THAN 650 psig AND

• Containment pressure LESS THAN 2 psig AND

• IF main generator on line, THEN (check reactor power) - (turbine power + any steam dump power) mismatch LESS THAN 10%.

AND

• IF main generator off line, THEN check reactor power less than ~ 15%.

AND

• Leakage is small in magnitude such that no significant hazard to personnel or equipment exists.

AND

• Leakage rate is relatively stable and is not rapidly worsening.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 3 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 3

Identify SECONDARY leakage source. 3 2

3.1 Check SG atmospheric relief valves CLOSED.

3.2 Contact TB SO to look at Check Main Steam Safety valves - MSVR roof CLOSED.

3.3 Check no abnormal steam leakage in Main Steam Valve Room.

3.3.1 Check Main Steam Valve Room by observing external grating prior to entry.

3.3.2 IF accessible, THEN check Main Steam Valve Room.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 4 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 3.3 (RNO)

Perform the following.

a) Isolate affected components consistent with plant operating requirements.

b) IF steam leakage cannot be isolated AND the plant is in Mode 3, THEN verify the reactor is tripped.

2.3.2 c) IF steam leakage cannot be isolated AND the steam leakage has resulted in a reactor power increase of > 1%, THEN verify the reactor tripped.

d) IF reactor tripped, THEN CLOSE SG Critical Task - If not main steam isolation and bypass valves. manually closed, the MSIVs will not close on low steam line pressure.

e) This step is N/A IF SG main steam isolation and bypass valves did not close, THEN place associated test switch to TEST position.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 5 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments f) IF reactor trip required, THEN go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 6 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 3.2 (RNO) This step will not be

[CA] Try to restore power to performed based on deenergized 4160 V ESF bus using FNP- scenario conditions 1-AOP-5.0, LOSS OF A OR B TRAIN ELECTRICAL POWER, as time permits while continuing with this available lights lit procedure.

3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 7 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments RO/BOP 4.1 (RNO)

Check SI required 4.1.1 (RNO)

IF any setpoint and coincidence shown in the coincidence shown in the reached or exceeded, THEN SI is required.

RO/BOP 4.1.2 (RNO)

IF SI is required, THEN actuate SI.

4.1.3 (RNO)

IF SI NOT required, THEN go to FNP-1-ESP-0.1, REACTOR TRIP RESPONSE.

RO/BOP 4.2 Verify both trains of SI- ACTUATED

[] MLB1 1-1 AND MLB1 11-1 lit

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 8 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments RO/BOP 5 See page 10 below Verify actuation signal automatic actions using ATTACHMENT 2, AUTOMATIC ACTIONS VERIFICATION.

RO/BOP 6

[CA] Check containment pressure - HAS REMAINED LESS THAN 27 psig.

CTMT PRESS

[] PR 950 RO/BOP 7 Announce "Unit 1 reactor trip and safety injection."

RO/BOP 8 Check AFW status.

8.1 Check secondary heat sink available.

[] Total feed flow to SGs - pumps started.

GREATER THAN 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B TDAFWP STM SUPP

[] FI 3229C FROM 1B(1C) SG AFW TOTAL FLOW

[] FI 3229

[] Narrow range level in at TDAFWP least one SG - GREATER THAN SPEED CONT 31%{48%}

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 9 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments RO/BOP 8.1 (RNO) Attempts to start the Perform the following. TDAFWP pump.

Dispatches personnel to 8.1.1 Verify all available AFW pumps investigate the TDAFWP started. and 1A MDAFW pump.

May call and ask how long MDAFWP the 1B MDAFW pump will

[] 1A amps > 0 be OOS (12 hrs)

[] 1B amps > 0 TDAFWP STM SUPP

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWPSPEED CONT

[] SIC 3405 adjusted to 100%

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 10 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments SRO 8.1.2 (RNO) EXITS EEP-0.0 and Goes Verify total AFW flow to FRP-H.1 greater than 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B

[] FI 3229C AFW TOTAL FLOW

[] FI 3229 8.1.3 IF total AFW flow less than 395 gpm, AND all SG narrow range levels less than or equal to 31%(48%),

THEN go to FNP-1-FRP-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK.

EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 2, ver 45 1

Verify one CHG PUMP in each train -

BOP STARTED.

[] A train (1A or 1B) amps > 0

[] B train (1C or 1B) amps > 0 BOP 2 Verify RHR PUMPs - STARTED.

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 11 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 3 Verify Safety Injection Flow.

3.1 Check HHSI flow - GREATER THAN 0 gpm.

[] FI 943 BOP 3.2 Operator should proceed to Check RCS pressure - LESS THAN step 4 275 psig{435 psig}.

BOP 4 Verify each SW train - HAS TWO SW PUMPs STARTED.

[] A train (1A,1B or 1C)

[] B train (1D,1E or 1C)

BOP 5 Verify each train of CCW - STARTED.

5.1 Verify one CCW PUMP in each train-STARTED.

A train HX 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 12 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 6 Verify containment ventilation isolation.

6.1 Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 3198A

[] 3198B 6.2 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D 6.3 Stop MINI PURGE SUPP/EXH FAN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 13 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 7 Verify containment fan cooler alignment.

7.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[] 1A

[] 1B B train

[] 1C

[] 1D 7.2 Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 14 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 8 Verify AFW Pumps - STARTED.

8.1 Verify both MDAFW Pumps - STARTED

[] 1A MDAFW Pump amps > 0

[] 1B MDAFW Pump amps > 0 AND

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 15 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 8.1 (RNO)

Verify MDAFW Pumps deliver flow to each SG.

8.1.1 Manually start MDAFW Pumps 8.1.2 Verify AFW flow path to AND each SG.

[] Q1N23HV3227A in MOD

[] Q1N23HV3227B in MOD

[] Q1N23HV3227C in MOD MDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3227AA open

[] HIC 3227BA open

[] HIC 3227CA open AFW TO 1A(1B,1C) SG STOP VLV

[] Q1N23MOV3350A open

[] Q1N23MOV3350B open

[] Q1N23MOV3350C open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764A open

[] Q1N23MOV3764D open

[] Q1N23MOV3764F open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764E open

[] Q1N23MOV3764B open

[] Q1N23MOV3764C open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 16 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 8.2 Check TDAFW Pump start required. TDAFWP pump will not start. May go directly to step 9

8.3 Verify TDAFWP started.

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

8.4 Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 17 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 9 Verify main feedwater status.

Verify main feedwater flow control and bypass valves - CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[] FCV 488

[] FCV 498 9.2 Verify both SGFPs - TRIPPED.

9.3 Verify SG blowdown - ISOLATED.

1A(1B,1C) SGBD ISO

[] Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample - ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 18 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 10 Check no MSL isolation actuation signal present.

10 (RNO)

Perform the following.

10.1 Verify main steam line isolation and bypass valves closed.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYP

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 19 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 11 Verify PHASE A CTMT ISO.

BOP 11.1 Verify PHASE A CTMT ISO - ACTUATED.

[] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO BOP 12 Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP 13 Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11E005A

[] N1C11E005B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 20 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 14 Secure secondary components.

14.1 Stop both heater drain pumps.

HDP

[] 1A

[] 1B 14.2 Check any condensate pump started.

14.2.1 IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 14.3 IF condensate pump operating, Will call TBSO to THEN verify backup cooling aligned to accomplish this.

condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP 15 Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN BOP 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810 - OPEN

[] 914 - OPEN

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 21 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments BOP 17 Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 22 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ATT 4, ver 45 1

Verify two trains of ECCS equipment aligned.

1.1 - 1.4

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 closed 1.5

[] Verify two trains of battery chargers -

energized

[] A Train (1A or 1C) amps > 0

[] B Train (1B or 1C) amps > 0 1.6 Verify two trains of ESF equipment aligned.

1.6.1 Check all MLB-1 lights LIT 1.6.2 Verify charging pump suction and discharge valves - OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __7___ Page 23 of 23 Event

Description:

Main Steam Line Break on downstream of the MSIVs. MSIVs will not automatically close if low steam line pressure is met. MSIVs must be manually closed. (CT-12)

Time Position Applicants Actions or Behavior Comments 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B 1.8 WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP 1.9 Call Radside SO Verify SFP Cooling in service per SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of Attachment 4

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 1 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Indications Available

- AFW flow < 395 GPM - SG NR level - 2 SG < 31%

Time Position Applicants Actions or Behavior Comments FRP-H.1, Response to Loss of Secondary Heat Sink, ver 27 SRO 1 Check secondary heat sink -REQUIRED.

1.1 - 1.2 o Check RCS pressure > any non-faulted SG pressure on PT-402/403 o Check RCS hot leg temperatures >

350°F on TR 413 SRO 2 Directs monitoring of bleed and feed criteria 2.1 - 2.2

- Check at least two SG wide range levels GREATER THAN 12%.

- Check pressurizer pressure < 2235 psig SRO 3 NOTE: Calls I&C Direct I&C to defeat feedwater isolation signal by installing jumpers per ATTACHMENT 1.

BOP 4 Check CST level > 5.3 feet and call for makeup to CST as required

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 2 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments BOP 5 NOTE: continuing action Try to establish AFW flow to at least one step SG.

5.1 Verifies blowdown isolated from all SGs 5.2 Verifies SG blowdown sample valves isolated 5.3 Recognizes AFW pumps not available MAY DIRECT RNO action 5.3 (RNO) to start 1A MDAFWP/

PERFORM local start from Hot shutdown TDAWFP from HSDP.

panels.

BOP 5.4 Verify at least one flow path to at least one SG ALIGNED Checks OPEN MDAFP to 1A/B/C SG (where X = respective SG A, B or C)

- HV3227X MDAFW TO SG MOD

- HIC3227XA MDAFW FCVsadjusted

- HV3228X TDAFW to SG MOD

- HIC3228XA TDAFW FCVs adjusted

- MOV-3350X SG AFW STOP vlvOPEN

- MOV3764X MDAFW to SG ISOOPEN 5.5

[CA] Check total AFW flow to SGs greater than 395 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 3 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments SRO 5.5 (RNO) 5.5.1 WHEN any feed flow established AND at least one SG narrow range level greater than 31%{48%} THEN go to procedure and step in effect 5.5.2 Continue efforts to establish AFW flow. WHEN FLOW established AND level >31% THEN exit.

5.5.3 Pproceed to step 6 RO 6 Stops all RCPs SRO 7 With MSIVs closed, may go Try to establish main feedwater flow to to step 9 here intact SGs with one SGFP.

BOP 7.1 Verify at least one CNDS PUMP started NOTE: will call TB SO to 7.1.1 verify Verify Back up cooling is aligned to the condensate pumps BOP 7.2 Check intact SGs MSIVs open

- HV 3369A and B and C

- HV 3370A and B and C SRO 7.2 IF no intact SGs main steam line isolation valves open, THEN proceed to Step 9.

OBSERVE CAUTION PRIOR TO STEP 9.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 4 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments RO 9

[CA] Try to establish condensate flow to intact SGs.

9.1 IF SI has not actuated since Rx trip then reset FWI 9.1 (RNO)

Verify SI RESET

[] MLB-1 1-1 not lit

[] MLB-1 11-1 not lit SRO 9.2 Call SSS Check feedwater isolation signal to intact SGs main feedwater regulating bypass valves defeated per ATTACHMENT 1.

BOP 9.3 Verify all main feedwater flow control and bypass valves - CLOSED IN MANUAL FK-478, 488, 498 FK-479, 489, 499 BOP 9.4 Contact TBSO Verify backup cooling to condensate pumps per FNP-1-SOP-21.0 BOP 9.5 Locally open SGFP BYP N1N21V509.

(155 ft, TURB BLDG)

SRO 9.6 Locally isolate SGFP miniflow valves. (155 ft, TURB BLDG) SGFP 1A(1B) RECIRC FCV INLET ISO

[] N1N21V502A closed

[] N1N21V502B closed

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 5 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments SRO 9.7 Contact SSS Perform the following.

9.7.1 Dispatch personnel to 1V 600 V MCC. (139 ft, AUX BLDG electrical penetration room)

BOP 9.7.2 Place Handswitch for main feedwater stop valves to intact SGs to OPEN and hold in that position.

BOP 9.7.3 Coordinates with RAD 1 SO WHEN main feedwater stop valves to - (Booth) intact SGs open, THEN direct personnel to open associated breakers. (139 ft, AUX BLDG electrical penetration room).

BOP 9.7.4 WHEN associated breaker open, THEN allow main feedwater stop valve handswitch to spring return.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 6 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments RO 9.8 Reduce PRZR pressure to less than 1950 psig.

9.8.1 This step is N/A Check either condition for using auxiliary spray satisfied.

[] Normal letdown in available, service.

OR

[] No PRZR PORV available.

RO 9.8.1 (RNO)

Perform the following.

[] If normal letdown secured and a PRZR PORV available, THEN open only one PRZR PORV to reduce PRZR pressure to less than 1950 psig.

AND

[] Proceed to step 9.9 RO 9.9 9.9 Maintain PRZR pressure at 1900-1950 psig.

9.9.1 (RNO)

IF using a PRZR PORV, THEN open only one PRZR PORV to control PRZR pressure.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 7 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments RO 9.10 WHEN pressurizer pressure less than 2000 psig, THEN perform the following.

9.10.1 Block low pressurizer pressure SI.

PRZR PRESS SI BLOCK - RESET

[] A TRN to BLOCK

[] B TRN to BLOCK 9.10.2 Verify blocked indication.

BYP & PERMISSIVE PRZR. SAFETY INJECTION

[] TRAIN A BLOCKED light lit

[] TRAIN B BLOCKED light lit RO 9.11 WHEN P-12 light lit (543F), THEN perform the following.

9.11.1 Block low steam line pressure SI.

STM LINE PRESS SI BLOCK - RESET

[] A TRN to BLOCK

[] B TRN to BLOCK 9.11.2 Verify blocked indication.

BYP & PERMISSIVE STM LINE ISOL.

SAFETY INJ.

[] TRAIN A BLOCKED light lit

[] TRAIN B BLOCKED light lit

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 8 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments BOP 9.11.3 Bypass the steam dump interlock.

STM DUMP INTERLOCK

[] A TRN to BYP INTLK

[] B TRN to BYP INTLK BOP 9.12 (RNO)

Dump steam to atmosphere.

9.12.1 Direct counting room to perform FNP Contacts Counting room CCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.

9.12.2 IF normal air available, THEN control atmospheric relief valves to dump steam from at least one intact SG at maximum attainable rate. []

1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A adjusted

[] PK 464 adjusted [] PC 3371B adjusted

[] PC 3371C adjusted BOP 9.13 WHEN SG(s) pressure reduced to less than 540 psig, THEN stop pressure reduction.

9.14 Maintain SG(s) pressure -

STABLE AT EXISTING VALUE.

9.15 Verify at least one CNDS PUMP

- STARTED.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___5__ Event No.: __8___ Page 9 of 9 Event

Description:

The Linkage on the TDAWFP will fail causing it to trip. 1A MDAFWP Trips on Overload. FRP-H.1 entry is required. Restore feed using Condensate pump. (CT-43)

Time Position Applicants Actions or Behavior Comments BOP 9.16 Check SGFP BYP N1N21V509 - OPEN.

(155 ft, TURB BLDG)

BOP 9.17 Critical Task - Restore Initially open feedwater regulating bypass feed flow using a valves just off the closed seat to initiate Condensate pump.

flow and minimize any water hammer.

9.1.8 Control feedwater regulating bypass valves to supply main feedwater to at least on intact SG RO/BOP 10.1 Verify feed flow to at least one SG

- Rising SGWL OR

- CETC - FALLING BOP 10.2 Check at least one SG NR level -

GREATER than 31%

BOP 10.2 (RNO)

Continue feeding at least one SG to restore SG NR to > 31%

SRO 10.3 Go to procedure and step in effect.

Terminate exam

Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-38 NRC EXAM SCENARIO #6 FA2015301 Validation time:

Validated by:

TRN Supervisor Approval: Billy Thornton Date: 7/22/15 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario Outline Form ES-D-1 Facility: FARLEY Scenario No.: 6 Op-Test No.: FA2015-301 Examiners: ___________________________ Operators: ____________________________

Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1, Section 4.1 through Step 23 is complete, Ramp on hold while investigating Feed water Dissolved Oxygen, 1A MDAFWP tagged out.

Turnover:

• 95% power, Impulse Loop NOT in service, MOL, Cb 977 ppm.

• UOP-3.1, Section 4.1 through Step 23 is complete. Ramp to 100%.

• Ramp on hold while investigating Feed water Dissolved Oxygen

• A Train On Service, B Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1A MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

• TS 3.5.1 Cond B (Unplanned) entered 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ago due to low 1A Accumulator pressure. Leak repaired.

Raise 1A Accumulator pressure.

Event Malf. No. Event Type* Event No. Description 1 preset N (BOP) Raise 1A Accumulator pressure.

2 cmfmalf/ C (BOP) 1B Service Water pump trips.

cNCPSW1B_d_

TS (SRO) TS-3.7.8 Cond A, 3.8.1 Cond B co2 3 ann/ N (RO) Fill 1C RCP standpipe.

da3 4 xmt/ I (BOP) PT3371B fails high.

pt3371B TS (SRO) TS-3.3.4 Cond A 5 malf/ C (RO) RCS to Letdown leak.

MAL-CCW4 6 cnh/ I (RO) PK-444A, PRZR PRESS REFERENCE, fails high.

pk444a-a 7 malf/ M (ALL) Loss of Offsite Power.

MAL-EPS1 preset 1B DG fails to auto start.

malf/d/ 1-2A DG trips on Low oil pressure 5 minutes after MAL-DSG006 reaching 500 rpm - Loss of all AC.

preset C (BOP) TDAFW pump fails to start. Will start manually.(CT-23) preset C (RO) 2C DG fails to start.

Terminate when power restored using 1B DG (CT-24)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Scenario 6 Presets Form ES-D-1 EVENT # TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load IC-225 (Base IC-60) 1A Accumulator pressure lowered to 598 psig.

Impulse loop not in service rst 225 0 0 Generis setup:

bat Generic_Setup_EXAM.txt 0 0 Quick setup (all items with

• are included):

bat 2015nrc6.txt 0 Freeze Xe set crxefast=0 0 0 RUN PRESETS setup Tag out 1A MDAFW pump

• irf cAFP01A_d_cd1 open setup SIM IC will have the 1A Accumulator pressure lowered 7 1B DG Auto start block

• imf MAL-DSG017 7 Prevent TDAFWP auto start

• imf cMS3235B-cc1 open imf cms3235b_cc2 open imf cms3235a_cc1 open imf cms3235a_cc2 open 7 2C DG Push Button fails to start the DG

• irf LOA-EPB005 false 7 1-2A DG trips on low oil pressure *TRG 1 imf MAL-DSG006 (1 300)

Triggers and Commands 1 Monitor 1-2A DG speed *TRG 1 trgset 1 X42D016M > 0.5

MCB setup OVATION Clear OVATION alarms OVATION Verify the Impulse Loop is NOT in service Place danger TAG ON 1A MDAFW Pump HS on MCB Place tag on 1A MDAFWP HS Unit 1 Train A Bypass & Inoperable Status Ind Panel on AFW Switch in ON EPB - AFW SYSTEM Switch in "ON Provide a marked up copy of UOP-3.1 UOP-3.1 Section 4.1 - through step 23 Provide a marked up copy of ARP CD1 (provided) Marked up copy of ARP CD1 Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear recorders sv Recorder_Clear_New.uvl Freeze Simulator Unfreeze Xe set crxefast=1 Perform Booth Operators Setup Checklist

MCB setup Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON 1 Start of Raise 1A Accumulator pressure.

exam 2 NRC 1B Service Water pump trips.

CUE TS-3.7.8 Cond A, 3.8.1 Cond B imf cNCPSW1B_d_co2 3 NRC DA3, 1C RCP STANDPIPE LO. Fill 1C RCP standpipe.

CUE imf jcvl408l-o 1 NOTE: Clear alarm 1 minute after filling begins.

dmf jcvl408l-o 4 NRC PT3371B fails high.

CUE TS-3.3.4 Cond A xmt pt3371B 1200 15 5 NRC RCS to Letdown leak.

CUE imf MAL-CCW4 10 60 6 NRC PK-444A, PRZR PRESS REFERENCE, fails high.

CUE imf pk444a-a 0 15

EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC Loss of Offsite Power.

CUE imf MAL-EPS1 1 0 preset 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 5 minutes after it TRG 1 reaches 500 RPM - Loss of all AC.

preset TDAFW pump fails to start. Will start manually.(CT-23)

NRC END OF EXAM:

CUE Terminate when power restored on the 1B DG Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created exam2015sen6grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed then Clear recorders for exam security.

sv Recorder_Clear_New.uvl

LOCAL OPERATOR ACTIONS EVENT TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 IF REQUESTED Place RCDT on recirc 3 minutes after requested.

irf loa-wps002 start 6 NONE REQUIRED 7 IF REQUESTED

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

ALL As Required (Standard SSS, SM and Dispatcher/Work Week Coordinator:

communications to Repeat back failure, procedure entered, plant status, CR in the inform supervision) cue and that type of communications 1 IF REQUESTED RAD 1 SO: 3 minutes after requested - N1E21HV3938A and B are open.

OUTSIDE SO: N2 banks are at 1800 psig.

RAD 1 SO: 3 minutes after requested - N1E21HV3938A and B are closed 2 IF REQUESTED OUTSIDE SO: 3 minutes after requested - DK-03 has an overcurrent trip flag.

OUTSIDE SO: 3 minutes after requested - 1B SW pump is not running. No obvious problems noted.

OUTSIDE SO: 3 minutes after requested - 1C SW pump breaker check is SAT.

SSS/OUTSIDE SO: Will brief then rack out 1B SW pump breaker 3 NO ADDITIONAL EXPECTED 4 CUE If the crew fails to see the steam leak, 5 minutes after failing PT-3371B then provide the following:

DB SO: I was walking toward the ready room and saw steam issuing from the top of the MSVR.

IF REQUESTED TBSO: 3 minutes after requested and PC3371B still open:

There is steam coming from the roof of the MSVR IF REQUESTED TBSO: 3 minutes after requested and PC3371B closed: There is no steam coming from the roof of the MSVR CUE: ROVER: 3 minutes after PCV-3371B is discovered by the crew: I was walking by HSDP Alpha and noticed 1B SG pressure PI3371B pegged high.

SM/OPS Dir: Continue plant operation with PC-3371B in its current status.

COMMUNICATIONS SHEET EVENT TIME COMMUNICATION:

5 IF REQUESTED HP: We will post the CCW Surge tank area as required.

RAD 1 SO: 3 minutes after requested - RCDT is on Recirc.

IF REQUESTED Counting room: I will sample SGs for radioactivity using FNP CCP-31, LEAK RATE DETERMINATION.

6 NO ADDITIONAL EXPECTED 7 IF REQUESTED DB SO: 3 minutes after requested 2A DG tripped on low oil pressure.

DB SO: 3 minutes after requested - There were no problems found on inspection of 1B DG. The only alarm is Service Water Low Flow (Window 22).

U2 (Booth operator coming out to floor): U2 has adequate Alpha train service water.

DB SO: 3 minutes after Mode 4 start requested: There are no obvious problems with the (DG selected) but the Mode Selector switch is stuck and cannot be placed in Mode 4.

DB SO: 3 minutes after requested: 1B DG lube oil alarm is clear.

Appendix D Scenario 6 Detailed Summary Form ES-D-1 Initial Conditions: 95% power, Impulse Loop not in service, MOL, Cb 977 ppm, A Train On Service, UOP-3.1, Section 4.1 through Step 23 is complete, Ramp on hold while investigating Feed water Dissolved Oxygen, 1A MDAFWP tagged out.

Turnover:

• 95% power, Impulse Loop NOT in service, MOL, Cb 977 ppm.

• UOP-3.1, Section 4.1 through Step 23 is complete. Ramp to 100%.

• Ramp on hold while investigating Feed water Dissolved Oxygen

• A Train On Service, B Train protected.

• Current Risk Assessment is GREEN and projected is GREEN

• 1A MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• TS 3.7.5 Cond B (Planned) entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago.

• TS 3.5.1 Cond B (Unplanned) entered 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ago due to low 1A Accumulator pressure. Leak repaired.

Raise 1A Accumulator pressure.

EVENT 1: Raise 1A Accumulator pressure.

Verifiable actions: BOP will operate valves to raise 1A Accumulator pressure.

EVENT 2: 1B Service Water pump trips.

Verifiable actions: BOP starts the 1C SW pump. SRO - Tech Spec: 3.7.8 Cond A, 3.8.1 Cond B until the 1C SW pump is aligned to auto start for the 1B SW pump.

EVENT 3: DA3, 1C RCP STANDPIPE LVL LO alarm.

Verifiable actions: RO will operate valves to fill the standpipe.

EVENT 4: PT-3371B fails high.

Verifiable actions: BOP takes manual control of PC-3371B, 1B MS ATMOS REL VLV and closes it. SRO - Tech Spec: TS-3.3.4 Cond A EVENT 5: RCS to Letdown leak.

Verifiable actions: RO may take manual control of Charging to determine leak rate. Once identified, the RO isolates letdown.

EVENT 6: PK-444A, PRZR PRESS REFERENCE, fails high.

Verifiable actions: RO takes manual control of PK-444A or manual control of Pressurizer heaters and spray to lower RCS pressure.

Similar to Audit - PK-444A fails LOW on the Audit opening spray valves and PCV-444B, PRZR PORV. RO must close the sprays and PORV as well as energize heaters to raise pressure.

EVENT 7: Loss of Offsite Power: 1B DG fails to auto start and 1-2A will trip on low oil pressure 5 minutes after it reaches 500 RPM requiring entry into ECP-0.0, Loss of ALL AC. TDAFW pump fails to start automatically and 2C DG wont start at the EPB Verifiable actions: BOP Starts TDAWF pump. (CT-23). RO starts 1B DG to restore power. (CT-24)

Similar to Audit - Audit exam has 2C DG starting (1st DG tried) and Service Water pumps have to be started. The TDAFW pump will also auto start on the Audit exam.

Appendix D Scenario 6 Critical Tasks Form ES-D-1

_____ 1. Establish the minimum required AFW flow rate to the SGs before SG dryout occurs. (CT-23)

_____ 2. Energize at least one ac emergency bus [before placing safeguards equipment handswitches in the pull-to-lock position. (CT-24)

SCENARIO At power instrument and component failures with a Loss of All AC.

OBJECTIVE/

• raise 1A Accumulator pressure OVERVIEW:

• respond to trip of 1B SW pump

• refill 1C RCP standpipe

• respond to a failed transmitter that causes a SG Atmospheric valve to open

• isolate letdown in response to an RCS to Letdown HX leak

• respond to a PK-444A, PRZR PRESS REFERENCE failing high

• restore power in response to a loss of All AC.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 2

2. Abnormal events (2-4) 4

3. Major transients (1-2) 1

4. EOPs entered/requiring substantive actions (1-2) 0

5. EOP contingencies requiring substantive actions (0-2) 1

6. Critical tasks (2-3) 2

SHIFT SUPERVISOR RELIEF CHECKSHEET FARLEY NUCLEAR PLANT (ILT 038)

Unit 1 Shift Date Off-going SS: Oncoming SS: DAYS Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift. TARGET ZERO Security keys A, S, SW, D, X on key ring. SS (Off-going SS Initial)

Every Day, Every Job, Safely Unit Status: Mode 1, 95% RTP, 977 ppm Cb, MOL 10000 MWD/MTU, -2181 pcm Xe A Trn O/S / B Trn Protected / SFPC on A Trn; STPs/Evolutions: Shunt Rx OFF Service - Cap Bank in Auto-OFF Time to 200 deg F = 167 hours0.00193 days <br />0.0464 hours <br />2.761243e-4 weeks <br />6.35435e-5 months <br /> 109.1(no adj); 63.7___; STP-9.0 UIL = 0.022 gpm / IL = 0.307 gpm Status of Special Activities Log in to Web EOC at beginning of shift RCS and SI filters are 1 micron A SI Filter O/S Log comp measure actions in eSOMS.

Last CTMT batch release = two days ago General Information

1. Current Risk Assessment is GREEN and projected is GREEN

2. 1A MDAFW pump is tagged out for bearing replacement. Expected RTS is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />

3. Leak repaired on 1A Accumulator. Raise 1A Accumulator pressure to the normal range.

4. Impulse loop is NOT in service.

5. UOP-3.1, Section 4.1 through Step 23 is complete.

6. Ramp is on hold while Chemistry investigates Feedwater Dissolved Oxygen.

7.

8.

Equipment Status VCT H2 target - 25 to 30 psig MCB DEFICIENCIES/INDICATIONS OOC: MCB ALARMS LIT/nuisance/OOC:

Rad Monitors: CT fans OOS:

Reactivity Plan Waste Management Status: #3 WGDT- decaying (VCT gas) 1A MDAFW pump - 3.7.5 Cond B (planned- entered 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago)

LCO status 1A accumulator - 3.5.1 Cond B (unplanned- #1 RHT entered12 hours ago)

Night Orders None #2 RHT O/S Small tri-nuc secured Alarms Cut Out #3 RHT Large tri-nuc running Part II: Review Shift Complement.

LCOs Reviewed _SS__ (initials) reviewed as early in the shift as possible. MCB Walkdown once per shift__SS__ (initials).

Part III:

STP-1.0 Operator Logs Condition Report Control Room ELDS & GEN MD/Temp Mod EOOS Updated Keys Turned Relief has Reviewed/Signed Reviewed Queue Reviewed Log Reviewed Spreadsheet verified Reviewed N/S and Weekends Over Verified Quals Yes Yes Yes Yes Yes Yes Yes Yes Yes

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __1___ Page 1 of 2 Event

Description:

Raise 1A Accumulator Pressure. 1A Accumulator is 605 psig and will be raised to 625 psig per SOP-8.0, Safety Injection System.

Indications Available

• 1A Accumulator pressure indicates ~600 psig

• ANN CD1 - 1A ACCUM PRESS HI-LO in alarm Time Position Applicants Actions or Behavior Comments ANN CD1 - 1A ACCUM PRESS HI-LO BOP 4.2.a) 2)

Restore 1A Accumulator pressure to normal.

SOP-8.0, SAFETY INJECTION SYSTEM - ACCUMULATORS v 42.0 BOP 4.5.1 SO reports 1800 psig IF increasing accumulator nitrogen pressure after establishing nitrogen atmosphere per Section 4.4, THEN ensure the high pressure nitrogen banks are greater than 1000 psig.

BOP 4.5.2.1 This has been Ensure nitrogen atmosphere has been established during established in 1A accumulator. plant startup BOP 4.5.2.2 Verify ACCUM N2 VENT HIK936(Q1E21V092) closed.

BOP 4.5.2.3 Contacts RAD SO to Open OR check open the following valves on open these valves the PRIP:

ACCUM N2 SUPPLY ISOLATION, N1E21HV3938A.

ACCUM N2 SUPPLY ISOLATION, N1E21HV3938B.

BOP 4.5.2.4 Opens the valve Open OR check open ACCUM N2 SUPP ISO Q1E21HV8880, (Q1E21V059).

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __1___ Page 2 of 2 Event

Description:

Raise 1A Accumulator Pressure. 1A Accumulator is 605 psig and will be raised to 625 psig per SOP-8.0, Safety Injection System.

Time Position Applicants Actions or Behavior Comments BOP 4.5.2.5 Open 1A ACCUM N2 SUPP/VT ISO Q1E21HV8875A.

BOP 4.5.2.6 Monitor accumulator pressure AND verify the pressure in accumulator 1A is the only accumulator which shows an increase in pressure.

BOP 4.5.2.7 WHEN pressure increases to approximately 625 psig, THEN close 1A ACCUM N2 SUPP/VT ISO, Q1E21HV8875A.(Q1E21V047A).

BOP 4.5.2.8 This step is N/A IF pressure is to be increased in another accumulator immediately, THEN proceed to Section 4.5.3 or 4.5.4.

BOP 4.5.2.9 Contacts RAD SO to Close the following valves on the PRIP: close these valves ACCUM N2 SUPPLY ISOLATION, N1E21HV3938A.

ACCUM N2 SUPPLY ISOLATION, N1E21HV3938B.

BOP 4.5.2.10 Close ACCUM N2 SUPP ISO Q1E21HV8880 (Q1E21V059).

At the discretion of the Lead Examiner move to next event .

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 1 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

Indications Available

• SW PUMP TRIPPED (AE4)

• PI-3001A SW TO CCW HX PRESS, reading low

• Recognize indications 1E SW PUMP TRIP

- Yellow flag above 1E SW pump handswitch Time Position Applicants Actions or Behavior Comments BOP Announce alarm and enter ARP-AE4 SRO Direct entry into ARP ARP-1.1 AE4, SW PUMP TRIPPED, ver 55.1 BOP 1 Check Indications and determine which SW pump tripped BOP 2 Start the 1C SW pump SRO 3 if entered actions listed REFER to AOP-10, version 17. below (pg 2)

SRO 4 Direct SSS entry into SOP-24.0 step 4.6 to align 1C SW pump for auto start to replace the 1E SW pump BOP 5 Sends SSS and/or Outside Dispatch personnel to the 1B SW pump SO and breaker DL04, 1B SW PUMP 4160V BREAKER

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 2 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

Time Position Applicants Actions or Behavior Comments SRO 6 Has RO/BOP call and have Return the Service Water electrical and CR initiated.

component lineup to normal as soon as possible.

SRO 7 Refer to Technical Specification 3.7.8 for LCO requirements with a loss of train A or B service water.

AOP-10.0, LOSS OF SERVICE WATER, v 17 BOP 1 Checks affected SW 4160V supply breakers closed.

[] BKR DF02 CLOSED

[] BKR DG02 CLOSED BOP 2 1C SW pump already IF SW PUMP tripped. started THEN start any available SW pump in the affected train SRO 3 Check pressure in both SW trains >60 psig, then go to procedure and step in affect.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 3 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

Time Position Applicants Actions or Behavior Comments TECHNICAL SPECIFICATION 3.7.8 - Service Water System (SWS)

Two SWS trains shall be OPERABLE.

SRO 3.7.8 Condition A applies due to the 1B SW pump being tripped and the 1C SW pump not being selected to auto start for the 1E SW pump CONDITION REQUIRED COMPLETION ACTION TIME A. One SWS A.1 -NOTES----- 72 hrs train inoperable. 1. Enter applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources Operating," for emergency DG made inoperable by SWS.

Restore SWS train to OPERABLE status.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 4 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

TECHNICAL SPECIFICATION 3.8.1 - 3 AC SourcesOperating SRO From 3.7.8 Condition A above, 3.8.1 has to be entered. Condition B applies.

SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One DG set B.1 Perform SR 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> The bolded conditions are the most likely inoperable 3.8.1.1 for the AND path the SRO will evoke.

required offsite Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> B.1 and B.2 and B.3.1 circuit(s). Thereafter AND B.2 Declare 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from required discovery of feature(s) Condition B supported by concurrent with the inoperable inoperability of DG set redundant required inoperable feature(s) when its required redundant feature(s) is inoperable AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> B.3.1 Determine OPERABLE DG set is not inoperable due to common cause failure.

OR 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> B.3.2 Perform SR 3.8.1.6 for OPERABLE DG set.

AND 10 days B.4 Restore DG AND 13 days from set to discovery of failure OPERABLE to meet LCO status

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __2___ Page 5 of 5 Event

Description:

Event

Description:

1C SW Pump trips. SW pressure will lower but remain operable. 1C SW pump is available to start and then tech specs evaluated.

Time Position Applicants Actions or Behavior Comments SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report SRO Inform the SM of the failure and Tech Spec entry After Tech Spec analysis and at the discretion of the Lead Examiner move to next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __3___ Page 1 of 1 Event

Description:

Fill 1C RCP standpipe. Upon receipt of DA3, the RO will fill the 1C RCP Standpipe.

Indications Available

• DA3, 1C RCP STANDPIPE LVL LO Time Position Applicants Actions or Behavior Comments BOP Announce alarm and enter ARP-AE4 SRO Direct entry into ARP ARP-1.4, DA3, 1C RCP STANDPIPE LVL LO, ver 54.2 RO 1 Open RMW TO PRT ISO Q1B13HV8028 RO 2 Open 1C RCP STANDPIPE FILL ISO N1E21HV8168C RO 3 Alarm will clear 1 minute Fill standpipe until the alarm clears after filling begins RO 4 Close 1C RCP STANDPIPE FILL ISO N1E21HV8168C RO 5 Close RMW TO PRT ISO Q1B13HV8028.

At discretion of the lead examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __4___ Page 1 of 3 Event

Description:

PT-3371B fails HIGH causing PC-3371B, 1B MS ATMOS REL VLV to fully open.

This will cause a rise in Rx power and lower Tavg. If the crew does not recognize the event in 5 minutes then the Diesel Building SO will call into the MCR and report steam from the top of the MSVR Indications Available

• PC-3371B fully open

• Rx power rise

• Tavg lowers

• RCS pressure will lower Time Position Applicants Actions or Behavior Comments NOTE: The SRO may direct the BOP to close PC-3371B without the use of AOP-14, SECONDARY SYSTEM LEAKAGE.

AOP-14, SECONDARY SYSTEM LEAKAGE, ver 11 SRO 1 SRO should not direct the Checks IF leakage is such that significant Rx tripped at this time hazard to personnel or equipment exists OR leakage rate is unstable and is worsening, THEN:

2 SRO should not direct the RO

• Pressurizer level > 15% Rx tripped at this time AND

• Pressurizer pressure > 2000 psig AND BOP

• Steam generator pressure >650 psig AND

• Containment pressure < 2 psig RO AND

• IF main generator off line, THEN check reactor power less than ~ 15%.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __4___ Page 2 of 3 Event

Description:

PT-3371B fails HIGH causing PC-3371B, 1B MS ATMOS REL VLV to fully open.

This will cause a rise in Rx power and lower Tavg. If the crew does not recognize the event in 5 minutes then the Diesel Building SO will call into the MCR and report steam from the top of the MSVR Time Position Applicants Actions or Behavior Comments NOTE:

- Steps 3.1 through 3.10 are intended to locate and isolate the leak if possible and stabilize the plant.

- Applicable steps to isolate leakage sources may be performed whenever a leakage source is identified and further identification actions may be terminated when all sources have been identified.

- Based on judgment plant shutdown may be commenced by proceeding to step 9. Steps 3 through 8 should then be performed concurrently with plant shutdown.

- FNP-0-SOP-0.0 contains documentation and reporting requirements for SG safety valves which have lifted.

BOP 3.1 Check SG atmospheric relief valves CLOSED.

BOP 3.1.1.a) RNO PC-3371B Closed in IF SG pressure less than 1035 psig, manual THEN close affected atmospheric relief valve(s) using one of the following (presented in suggested order but any option may be used).

PC-3371B adjusted closed BOP 3.1.2 (RNO) This step is N/A IF PRIMARY TO SECONDARY LEAKAGE greater than 50 gpd exists, THEN direct Counting Room to perform FNP-0-CCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.

SRO 4 Secondary Leak is isolated

[CA] Check secondary leak NOT isolated.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __4___ Page 3 of 3 Event

Description:

PT-3371B fails HIGH causing PC-3371B, 1B MS ATMOS REL VLV to fully open.

This will cause a rise in Rx power and lower Tavg. If the crew does not recognize the event in 5 minutes then the Diesel Building SO will call into the MCR and report steam from the top of the MSVR Time Position Applicants Actions or Behavior Comments SRO 4 (RNO) 4.1 Contacts SM or Ops Consult operations manager to evaluate Director continued plant operation with isolated components.

3.1 4.2 Evaluate actions required by applicable Tech Spec below Technical Specifications.

3.2 4.3 Go to procedure and step in effect.

Tech Spec 3.3.4, Remote Shutdown System The Remote Shutdown System Functions in Table 3.3.4-1 shall be OPERABLE.

SRO 3.3.4 Condition A applies because the 1B SG pressure instrument has failed. Table 3.3.4-1 function 2 requires 1 SG pressure instr per SG CONDITION REQUIRED COMPLETION ACTION TIME A. One or more A.1 Restore 30 days required required Functions Function inoperable. to OPERABLE status.

SRO Submit a condition report on the failed component, and notify the Work Week Coordinator of the condition report SRO Inform the SM of the failure and Tech Spec entry At discretion of the lead examiner, move to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 1 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Indications Available

• FH1, RMS HIGH RAD

• CCW Surge tank rising

• R-17B, CCW in alarm

• FI-122A, CHG FLOW rising

• Pressurizer level lowering Time Position Applicants Actions or Behavior Comments BOP Announce alarm and enter ARP-FH1 SRO Direct entry into ARP ARP-1.6, FH1, RMS HIGH RAD, ver 72.1 BOP 1 Check indications on radiation monitoring system console and determine which radiation monitor channel indicates high activity. R-17B BOP 2 Insure that any automatic actions, associated with the alarmed channel, have occurred. Insures RCV-3028 is closed BOP 3 Perform the following general actions as appropriate.

3.3 May contact HP and/or Do not allow personnel to enter the make an announcement affected area without the approval of the Health Physics Department.

BOP 3.5 IF high activity indication of RCS leakage is present AND accompanied by either decreasing pressurizer level, OR decreasing VCT level, THEN go to FNP AOP-1.0, RCS LEAKAGE.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 2 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments AOP-1, RCS LEAKAGE, ver 23 RO 1

[CA] Maintain pressurizer level 1 Perform the following. stable at or near programmed level.

[] Control charging flow.

OR

[] Reduce letdown flow.

OR

[] IF required to maintain PRZR level, THEN isolate letdown.

RO 2

[CA] Maintain VCT level greater than 20%.

2.1 Verify reactor makeup system -

IN AUTOMATIC.

OR 2.2 Control reactor makeup system using FNP-1-SOP-2.3, CHEMICAL AND VOLUME CONTROL VCT SYSTEM REACTOR MAKEUP CONTROL OUTLET ISO SYSTEM.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 3 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments RO 3 Determine RCS leak rate.

3.1 Determine RCS leak rate from CVCS flow balance.

______(charging flow)

+______(seal injection flow)

-______(letdown flow)

-______(#1 seal leakoff flow)

=______(RCS leak rate) 3.2 Initial conditions are not met IF plant conditions are stable, THEN determine RCS leak rate using FNP-1-STP-9.0, RCS LEAKAGE TEST.

SRO 4

[CA] WHEN RCS leak rate Not a Tech Spec.

determined, THEN evaluate required actions using Technical Specifications.

SRO 5 Contacts SM

[CA] WHEN RCS leak rate determined, THEN evaluate event classification and notification requirements using FNP-0-EIP-8, NON-EMERGENCY NOTIFICATIONS and NMP-EP-110, EMERGENCY CLASSIFICATION DETERMINATION AND INITIAL ACTION.

SRO 6 N/A

[CA] WHEN RCS leak rate greater than 50 gpm, THEN align 1A and 1B post LOCA containment hydrogen analyzers for service using Attachment 1.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 4 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments NOTE:

- The intent of step 7 is to provide a systematic leakage search plan. Steps 7.2 through 7.12 may be done in any order.

- IF at anytime the location of an RCS leak is discovered or reported, THEN actions to isolate the leak should be taken immediately.

- WHEN all leakage sources have been identified, THEN continue with step 8 and further leakage identification actions may be terminated.

RO 7 Identify RCS leakage source.

7.1 Frequently monitor CVCS flow balance as the actions of steps 7.2 through 7.12 are taken.

7.1.1 Determine RCS leak rate from CVCS flow balance.

______(charging flow)

+______(seal inj flow)

-______(letdown flow)

-______(#1 seal lkof flow)

=______(RCS leak rate)

Based on the note prior to step 7 and indications available, Step 7.7 is the first logical step to perform.

RO 7.7 Check CCW system.

7.7.1 Check CCW surge tank radiation -

NORMAL

[] R-17A CCW

[] R-17B CCW RO 7.7.2 Check CCW surge tank level - NO UNEXPLAINED LEVEL RISE.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 5 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments RO 7.7 (RNO)

Perform the following.

a) Secure normal letdown.

RO 7.7. (RNO) Place Excess letdown on b) service per SOP-2.7. Steps IF CCW parameters return to normal, are below PAGE 6 THEN establish excess letdown using, FNP-1-SOP-2.7, CHEMICAL AND VOLUME CONTROL SYSTEM EXCESS LETDOWN.

c) Return to step 3 RO 3 Leakrate is zero Determine RCS leak rate.

3.1 Determine RCS leak rate from CVCS flow balance.

______(charging flow)

+______(seal injection flow)

-______(letdown flow)

-______(#1 seal leakoff flow)

=______(RCS leak rate) 3.2 IF plant conditions are stable, THEN determine RCS leak rate using FNP-1-STP-9.0, RCS LEAKAGE TEST.

RO 8 Leak isolated in step 7.7

[CA] WHEN the RCS leakage source identified, THEN take appropriate actions to isolate the leak.

RO 9 Stable plant conditions must

[CA] WHEN RCS leakage source be obtained isolated, THEN determine the post isolation leak rate per FNP-1-STP-9.0, RCS LEAKAGE TEST.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 6 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments SRO 9.1 IF RCS leak rate satisfactory, THEN go to procedure in effect.

After AOP-1 Step 9 is commenced at Lead Examiners discretion, move to next event.

SOP-2.7, Chemical and Volume Control System Excess Letdown, ver 13 Section 4.1 RO 1 Directs Rad 1 SO to Verify RCDT system in operation and on recirc perform this action per FNP-1-SOP-50.0, Liquid Waste Processing System, Reactor Coolant Drain Tank (RCDT) Operation.

RO 2 Performed with Step 1 Notify Radside SO to expect an increase in RCDT level.

RO 3 Verify CCW TO EXC LTDN/RCDT HXS, Q1P17HV3095 OPEN.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __5__ Page 7 of 7 Event

Description:

RCS to letdown leak. A leak in the Letdown HX will cause RCS to enter the CCW system.

Time Position Applicants Actions or Behavior Comments RO 4 Verify CCW FROM EXC LTDN/RCDT HXS, Q1P17HV3443 OPEN.

RO 5 Verify CCW FROM EXC LTDN/RCDT HXS, Q1P17HV3067 OPEN.

RO 6 Verify EXC LTDN HX DISCH, Q1E21HCV137 CLOSED (HIK-137 at 0%).

RO 7 Open EXC LTDN ISO, Q1E21HV8153.

RO 8 Open EXC LTDN ISO, Q1E21HV8154.

RO 9 Place EXC LTDN DIVERT VLV, 1E21HV8143 to RCDT.

RO 10 Using HIK-137, slowly throttle open EXC LTDN HX DISCH, Q1E21HCV137 to establish Excess Letdown flow not to exceed 165F Excess Letdown Heat Exchanger outlet temperature as indicated on TI-139, EXC LTDN HX OUTLET TEMP.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __6__ Page 1 of 3 Event

Description:

PK-444A, PRZR PRESS REFERENCE, fails high. Causes pressure to rise until manual control taken or a PORV lifts.

Indications Available

• All Pressurizer heaters energize.

• RCS pressure rises

• Spray valves close if open

• PK-444A demand goes to 100%

Time Position Applicants Actions or Behavior Comments AOP-100, INSTRUMENTATION MALFUNCTION, ver 15 Note: Step 1 and 2 are immediate operator actions RO 1 IF required to stabilize RCS pressure, THEN take manual control of the following equipment.

11

• Power operated relief valves

[ ] PRZR PORV Q1B31PCV445A

[ ] PRZR PORV Q1B31PCV444B OR

[ ] PRZR BLOCK VLV Q1B31MOV8000A

[ ] PRZR BLOCK VLV Q1B31MOV8000B

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP

[ ] 1E PRZR HTR GROUP BACKUP RO 2 This step is N/A IF pressurizer pressure is decreasing due to a mechanically stuck open spray valve PCV444C or PCV444D, THEN perform the following:

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __6__ Page 2 of 3 Event

Description:

PK-444A, PRZR PRESS REFERENCE, fails high. Causes pressure to rise until manual control taken or a PORV lifts.

Time Position Applicants Actions or Behavior Comments RO 3 IF PORV is open and pressurizer pressure is less than 2310 psig, THEN close the PORV.

RO 4 IF an alarm was caused by a CONTROL instrument (PT-444/445) OR component failure, THEN perform the following as required to restore RCS pressure to desired value.

4.1 Take manual control of the following as required:

• Power operated relief valves

[ ] PRZR PORV Q1B31PCV445

[ ] PRZR PORV Q1B31PCV444B OR

[ ] PRZR BLOCK VLV Q1B31MOV8000A

[ ] PRZR BLOCK VLV Q1B31MOV8000B

• Pressurizer Pressure Controller

[ ] PK-444A PRZR PRESS REFERENCE

• Pressurizer spray valves

[ ] PK-444C 1A Loop Spray vlv

[ ] PK-444D 1B Loop Spray vlv

• Pressurizer Heaters

[ ] 1A PRZR HTR GROUP BACKUP

[ ] 1B PRZR HTR GROUP BACKUP

[ ] 1C PRZR HTR GROUP VARIABLE

[ ] 1D PRZR HTR GROUP BACKUP RO 4.2 Verifies PK-444A at IF B/U heaters automatically energized ~ 9.25 with pressure above 2210 psig, THEN verify the pressurizer master controller potentiometer setting using the plant curve book.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __6__ Page 3 of 3 Event

Description:

PK-444A, PRZR PRESS REFERENCE, fails high. Causes pressure to rise until manual control taken or a PORV lifts.

Time Position Applicants Actions or Behavior Comments RO 5 This step is N/A IF a PROTECTION instrument failure has occurred, THEN determine which pressure channel has caused the alarm.

RO 6 This step is N/A Refer to Tech Specs for LCO requirements that exist.

SRO 7 Contacts Shift Manager Notify the Shift Manager SRO 8 This step is N/A

[CA] WHEN plant conditions permit, THEN restore components to automatic control.

SRO 9 Has RO/BOP contact Submit a Condition Report and notify the SSS/WWC Work Week Coordinator (Maintenance ATL on backshifts).

RO 10 This step is N/A IF the pressurizer power operated relief valves operated, THEN perform the following:

SRO 11 Go to procedure and step in effect.

At discretion of the lead examiner, move to the next event

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 1 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Indications Available Annunciators: Recognize indications of Loss of ALL AC power

• Many and various *RCPs tripped

• EPB power indication lights not LIT *Components not running Time Position Applicants Actions or Behavior Comments Note: Some or all of EEP-0.0 Immediate Operator Actions will be perfomed before ECP-0.0 is entered EEP-0.0, REACTOR TRIP OR SAFETY INJECTION, ver 45 RO/BOP 1 Check reactor trip.

[] Reactor trip and bypass breakers -

OPEN

[] Nuclear power - FALLING

[] IF DRPI available THEN rod bottom lights - LIT RO/BOP 2 Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT RO/BOP 3 Verify power to 4160 V ESF busses 3.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

[] 1F 4160V bus power available light - LIT

[] 1G 4160V bus power available light -

LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 2 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments RO/BOP 3.2 4160 V ESF busses - BOTH TRAINS ENERGIZED

[] A Train (1F & 1K) power available lights lit

[] B Train (1G & 1L) power available lights lit BOP 3.2 (RNO) This step will not be

[CA] Try to restore power to performed based on deenergized 4160 V ESF bus using FNP- scenario conditions 1-AOP-5.0, LOSS OF A OR B TRAIN ELECTRICAL POWER, as time permits while continuing with this available lights lit procedure.

3.3

[CA] Verify operating diesel generator(s) -

SUPPLIED FROM AT LEAST ONE SW PUMP RO/BOP 4 Check SI status 4.1 Check any SI actuated indication.

RO/BOP 4.1 (RNO)

Check SI required 4.1.1 IF any setpoint and coincidence shown in the coincidence shown in the reached or exceeded, THEN SI is required.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 3 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments ECP-0.0, LOSS OF ALL AC POWER, ver 26 SRO Recognize Loss of all AC and direct IOAs of ECP-0.

RO 1 Immediate Operator actions Check reactor tripped. of ECP-0 are steps 1 and 2

[] Check reactor trip and reactor trip bypass breakers - OPEN.

[] Nuclear power - FALLING 2

Check turbine trip.

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT

[] TSLB2 14 LIT 3

Verify RCS isolated.

3.1 Verify normal letdown isolated.

3.1.1 Verify all letdown line orifice isolation valves - CLOSED.

LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 4 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments OR ECP-0.0 Step 3 Continued 3.1.2 Verify letdown line isolation valves -

CLOSED.

LTD LINE ISO

[] Q1E21LCV459

[] Q1E21LCV460 3.2 WHEN RCS pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

3.3 Verify excess letdown line - ISOLATED.

EXC LTDN ISO VLV

[] Q1E21HV8153 closed

[] Q1E21HV8154 closed 3.4 Verify all reactor vessel head vent valves -

CLOSED.

RX VESSEL HEAD VENT OUTER ISO

[] Q1B13SV2213A

[] Q1B13SV2213B RX VESSEL HEAD VENT INNER ISO

[] Q1B13SV2214A

[] Q1B13SV2214B RO 4

Verify total AFW flow GREATER THAN 395 gpm.

AFW TOTAL FLOW

[] FI 3229

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 5 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments 4 (RNO) Critical task - start the TDAFW pump 4.1(RNO)

Verify TDAFWP running.

TDAFWP STM SUPP FROM 1B(1C) SG

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A > 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

Place TDAFWP STM SUPP FROM 1B SG HV3235A/26 AND TDAFWP STM SUPP FROM 1C SG to the START position RO 4.2(RNO) Step is N/A IF TDAFWP NOT running, THEN locally verify TDAFWP TRIP THROTTLE VLV Q1N12MOV3406 open. (100 ft, AUX BLDG TDAFWP room)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 6 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments RO 4.3 (RNO) 4.3 Verify AFW flow path to each SG.

TDAFWP FCV 3228

[] RESET reset TDAFWP TO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open RO/BOP 5

[CA] Restore power to any emergency bus.

5.1 Verify supply breakers for major loads on emergency 4160 V busses - OPEN.

On EPB

[] BKR DF01 (1A S/U XFMR TO 1F 4160 V BUS)

[] BKR DF15 (1B S/U XFMR TO 1F 4160 V BUS)

[] BKR DF-13-1 (1F 4160 V BUS TIE TO 1H 4160 V BUS)

[] BKR DG01 (1A S/U XFMR TO 1G 4160 V BUS)

[] BKR DG15 (1B S/U XFMR TO 1G 4160 V BUS

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 7 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments RO/BOP 5.1 (continued) Load shed list continued

[] 1C CCW PUMP BKR DF-04-1 from above

[] 1B CCW PUMP BKR DF-05-1 Components on MCB and

[] 1B CCW PUMP BKR DG-05-1 may be verified by RO

[] 1A CCW PUMP BKR DG-04-1

[] 1A SW PUMP BKR DK-03-1

[] 1B SW PUMP BKR DK-04-1

[] 1C SW PUMP BKR DK-05-1

[] 1C SW PUMP BKR DL-05-1

[] 1D SW PUMP BKR DL-03-1

[] 1E SW PUMP BKR DL-04-1

[] #4 RW PUMP BKR DJ-03-1

[] #5 RW PUMP BKR DJ-04-1

[] #8 RW PUMP BKR DH-03-1

[] #9 RW PUMP BKR DH-04-1

[] #10 RW PUMP BKR DH-05-1

[] 1B CRDM CLG FAN BKR ED-11-1

[] 1A CRDM CLG FAN BKR EE-13-1

[] 1A CS PUMP BKR DF-11-1

[] 1B CS PUMP BKR DG-11-1

[] 1A RHR PUMP BKR DF-09-1

[] 1B RHR PUMP BKR DG-09-1

[] 1A CHG PUMP BKR DF-06-1

[] 1B CHG PUMP A TRN BKR DF-07-1

[] 1B CHG PUMP B TRN BKR DG-07-1

[] 1C CHG PUMP BKR DG-06-1

[] 1A MDAFWP BKR DF-10-1

[] 1B MDAFWP BKR DG-10-1

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 8 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments RO/BOP 5.2 NO Check 1-2A, 1C or 1B diesel generator running for Unit 1.

5.2 (RNO) Perform the following 5.2.1 Perform 2C DG SBO start as follows:

5.2.1.1 2C DG MSS in MODE 1 5.2.1.2 2C DG USS in UNIT 1 5.2.1.3 When load shed has been competed then 2C DG will NOT start depress START PB for 2C DG 5.2.1.4 Verify 2C DG stsrts Note; Since 2C DG failed to start, 5.2.1.5 - 5.2.1.8 (RNO) are N/A RO/BOP 5.2.2 (RNO) 1B DG will be selected IF unable to start 2C diesel generator AND Critical Task - Start the energize 1G 4160V bus, THEN start any 1B DG diesel generator.

RO/BOP 5.2.2.1 (RNO) 1B DG starts Start 1B diesel generator from EPB in Mode 2 using START pushbutton.

5.3 Check 1-2A, 1C or 1B diesel generator output.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 9 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments 5.3.1 Verify diesel generator frequency 62 Hz.

5.3.2 Verify diesel generator voltage - 4.0-4.3 kV 5.4 Check DG08 closed 5.5 IF 1F 4160 V bus energized, THEN proceed to step 5.7.

RO/BOP 5.7 Verify adequate SW flow.

5.7.1 Verify two SW PUMPS in energized train - RUNNING.

[] A Train (1A, 1B or 1C)

[] B Train (1D, 1E or 1C) 5.7.2 IF A train energized, THEN verify SW TO/FROM DG BLDG - A HDR Q1P16V519/537 open.

5.7.3 IF B train energized, THEN verify SW TO/FROM DG BLDG - B HDR Q1P16V518/536 open. Contacts TB SO 5.7.4 Check no running diesel generator lube oil temperature annunciator in alarm. (155 ft, DG BLDG local control panel)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: FA2015301Scenario No.: ___6__ Event No.: __7__ Page 10 of 10 Event

Description:

Loss of Offsite Power. 1B DG fails to auto start.

1-2A DG trips on Low oil pressure 2 minutes after it reaches 500 RPM - Loss of all AC.

TDAFW pump fails to start but will start manually. 2C DG fails to start.

Time Position Applicants Actions or Behavior Comments SRO 5.8 IF 1F OR 1G 4160 V energized, THEN go to procedure and step in effect and implement function restoration procedures as necessary.

At discretion of Lead Examiner, terminate the exam