Latest revision as of 07:01, 31 October 2019

Text

2015 Davis-Besse Nuclear Power Station Initial License Examination As-Administered Simulator Scenarios
	ML15245A466
Person / Time
Site:	Davis Besse
Issue date:	06/22/2015
From:	; Division of Reactor Safety III
To:	; FirstEnergy Nuclear Operating Co
	Reeser, D W
Shared Package
ML15217A121	List: ML15217A601; ML15245A271; ML15245A465; ML15245A466;
References
	Download: ML15245A466 (79)
	v • d • e

Appendix D Scenario Outline Form ES-D-1 Facility: Davis-Besse Scenario No.: 1 Op Test No.: DB NRC 2015 Examiners: Operators: SRO ATC BOP Initial Conditions: 100% Power CCW Pump 1 and MUP 2 in service Turnover: Maintain 100% Power Critical tasks: 1. ATWS (CT24)

2. Establish FW flow and feed SGs (CT10)

Event Malf. Event Type* Event No. No. Description 1 SRO (TS) AFPT 1 Trip valve fails closed 2 C-BOP/SRO Circ Pump high stator temperature 3 I-ATC/SRO Pressurizer Level instrument failure 4 C-BOP/SRO Rising Condenser pressure C-ATC/SRO 5 Makeup Pump trip (TS) 6 R-ATC/SRO Loss of Letdown 7 C-ATC/SRO ATWS (trip pushbuttons fail) 8 M-All SG 1 stuck open safety 9 C-BOP/SRO AFPT 2 to SG 2 overfeed 10 C-ATC/SRO Spray valve fails open

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NUREG-1021, R9 Supp. 1 Page 1 of 16 FENOC Facsimile AG

Scenario Event Summary DAVIS-BESSE 2015 NRC SCENARIO 1 The Crew will take the watch with power at 100%. Following turnover the Lead Evaluator will cue the Auxiliary Feed Pump (AFP 1) Turbine Trip Throttle Valve (TTV) to fail closed and annunciator alarm, AFP1 TRBL, will come into alarm. The SRO will declare AFP 1 Inoperable and enter the applicable Tech Spec (TS).

After the AFP TS is entered, the Lead Evaluator can cue the Circulating Water Pump (CWP) stator temperature increase. The SRO will implement DB-OP-02517, Circulating Water System Malfunctions. The BOP will be directed to stop CWP 1 When CWP 1 is stopped the lead evaluator will cue the selected PZR Level instrument failure which will fail low over two minutes. Annunciator PZR LVL LO will alarm. The SRO will implement DB-OP-02513, PZR Abnormal Operations. The ATC will place PZR level control valve MU32 in manual, select the alternate instrument and return MU32 to automatic control.

After MU32 is returned to automatic control the Lead Evaluator will cue the rising condenser pressure. The SRO will implement DB-OP-02518, HIGH CONDENSER PRESSURE. The BOP will recognize the Mechanical Hogger (motor vacuum pump) has failed to auto start. The BOP will start the Mechanical Hogger and the pressure increase will stop.

The Lead Evaluator will then cue the Makeup Pump trip. The SRO will implement DB-OP-02512, Loss of RCS Makeup. The ATC will close MU2B, RCS Letdown, MU19 Seal injection and MU32 PZR level control. The SRO will enter the applicable TS for the Inoperable Makeup Pump. The ATC will start the standby Makeup pump and restore MU flow, Seal Injection flow and attempt to restore Letdown flow. The Letdown valve, MU2B, will be failed closed.

The SRO will implement DB-OP-02512, for Loss of Letdown Flowpath. When it is determined Letdown flow cannot be established the SRO will direct a plant shutdown per DB-OP-02504, Rapid Shutdown.

While the shutdown is in progress the Lead Evaluator can cue the CD2796 close failure which causes a loss of condensate flow. The Deaerator levels will drop causing a runback and as the Deaerator levels approach off scale low the SRO will direct tripping the Reactor, tripping both MFPTs and Steam Feed Rupture Control System (SFRCS) initiation and isolation per the Deaerator level alarm procedure DB-OP-02013, Alarm Panel 13 annunciators.

The ATC will attempt to trip the Reactor per DB-OP-02000. The trip buttons will not function and the ATC will de-energize E2 and F2 (CRD) to trip the Reactor (CT-24).

The ATC will trip both MFPT and initiate and isolate SFRCS (CT-10). SG1 safety will stick open. DB-OP-02000, Overcooling Section 7, will be entered. The Motor Driven Feed Pump will fail to start. AFPT 2 will start and feed at full flow with its discharge failed open. The BOP will be required to control SG2 level with AFPT 2 speed control (CT-10).

The BOP will control RCS temperature using SG2 AVV and the ATC will begin depressurizing the Reactor Coolant System to minimum subcooling margin. When the RCS spray valve is opened it will fail and the ATC will close the spray block. When the spray valve is isolated and SG2 level is controlled the scenario can be terminated.

NUREG-1021, R9 Supp. 1 Page 2 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 1 Page 3 of 16 Event

Description:

AFPT 1 Trip Throttle Valve (TTV) fails closed Time Position Applicants Actions or Behavior Event 1: AFPT 1 TTV Fails Closed Indications Available:

10-4-G, AFP 1 TRBL 10-2-G, AFPT 1 OVRSPD TRIP Computer Alarm Z001, AFPT 1 STOP/GOV/STM IN ISO VLVS CREW Recognize AFP 1 TRBL Annunciator Alarm Implement DB-OP-02010, Feedwater Alarm Panel 10 BOP Annunciators alarm 10-4-G, AFP 1 TRBL Diagnose AFPT 1 Trip Throttle Valve not fully open by CREW computer alarm Z001 BOP Dispatch Equipment Operator to inspect AFPT 1 Booth After 2 minutes role play as Equipment Operator and Cue report: AFPT 1 Trip Throttle Valve is tripped closed Direct opening AFPT 1 Trip Throttle Valve. Request SRO Maintenance assistance.

Role play as Equipment Operator and report: AFPT 1 Trip Booth Cue Throttle Valve will not reset and Maintenance requests it be tagged out for troubleshooting Declare AFPT 1 Inoperable. Enter TS 3.7.5, Condition B SRO

Direct energize blue TS Operability light Request Risk evaluation or refer to Risk Matrix and determine SRO risk level is Yellow (OPTIONAL)

On Lead Evaluators discretion, insert Event 2, Circulating Water Pump high temp NUREG-1021, R9 Supp. 1 Page 3 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 2 Page 4 of 16 Event

Description:

Circulating Water Pump 1 high stator temperature Time Position Applicants Actions or Behavior Event 2: Stop Circulating Water Pump 1 due to high stator temperature Indications Available:

11-3-E CIRC WATER PUMP TEMP HI T110 CWP 1 MTR STATOR TEMP T113 CWP 1 TRBL CWP 1 elevated amps Recognize symptoms of high stator temperature on Circulating CREW Water Pump 1 Refer to DB-OP-02011, Heat Sink Alarm Panel Annunciators

Direct an Equipment Operator to investigate Circ Water BOP Pump 1 locally

Trend computer point T110 Implement DB-OP-02517, Circulating Water System SRO Malfunction Role play as an Equipment Operator:- After 3 minutes Booth report Circ Water Pump 1 oil levels are normal, cooling Cue water lineups are normal, no excessive vibration and no obstructions are around the motor vents Stop Circ Water Pump 1 using DB-OP-02517, Attachment 1, BOP Shutdown of a Loop 1 Circ Water Pump Depress close on both Circ Water Loop 1 Pump Discharge Valves BOP

HIS856, Circ Water Pump 1 Discharge Valve

HIS861, Circ Water Pump 2 Discharge Valve When the Circ Water Pump Discharge Valves reach the throttled position, then depress close on the Discharge Valve BOP for Circ Water Pump 1

HIS856, Circ Water Pump 1 Discharge Valve NUREG-1021, R9 Supp. 1 Page 4 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 2 Page 5 of 16 Event

Description:

Circulating Water Pump 1 high stator temperature Time Position Applicants Actions or Behavior Event 2: Stop Circ Water Pump 1 due to high stator temperature - continued Verify HIS856, Circ Water Pump 1 Discharge Valve Closed BOP light comes on BOP Verify Circ Water Pump 1 has stopped (after time delay)

Monitor Reactor power ATC

Reduce Reactor Power to less than or equal to the 100%

If Condenser pressure reaches 5 inches HgA, then reduce CREW Reactor power to maintain Condenser pressure less than or equal to 5 inches HgA SRO Notify Chemistry of the change in alignment Booth Role play as Chemistry to shutdown/realign the Circ Water Cue Chemical Addition System and Chlorination System On Lead Evaluators discretion, proceed to Event 3, PZR Level Instrument Failure NUREG-1021, R9 Supp. 1 Page 5 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 3 Page 6 of 16 Event

Description:

PZR Level Transmitter fails low over 2 minutes Time Position Applicants Actions or Behavior Event 3: Pressurizer Level RC 14-2 fails low Indications Available:

Makeup flow increasing with no change in PZR level 4-2-E PZR LVL LO 4-1-E PZR LO LVL HTR TRIP MU 32 demand increasing CREW Recognize a Pressurizer level transmitter failure Implement DB-OP-02513, Pressurizer System Abnormal SRO Operations, for Failure of Selected Pressurizer Level or Temperature Instruments ATC Place MU 32 in HAND and control PZR level Compare Pressurizer level instruments and select a functional alternate level instrument:

ATC

LTRC14-1 (L772) X instrument OR

LTRC14-3 (L773) Y instrument If NNI-Y instrument selected refer to DB-OP-06407 for non-SRO preferred selector switch alignment ATC Return MU 32 to automatic control IF Pressurizer Level is greater than 228 inches, then refer to SRO Technical Specification 3.4.9 Condition A Booth Role play Work Week Manager/I&C as necessary to Cue investigate pressurizer level transmitter failure On Lead Evaluators discretion, proceed to Event 4 NUREG-1021, R9 Supp. 1 Page 6 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 4 Page 7 of 16 Event

Description:

Rising Condenser Pressure - vacuum pump auto start failure Time Position Applicants Actions or Behavior Event 4: Rising Condenser pressure Indications Available:

15-1-F HP CNDSR PRESS HI 15-2-F LP CNDSR PRESS HI 15-5-B DEHC MINOR ALARM CREW Recognize rising Condenser pressure NOTE: Crew may take actions prior to alarm Implement DB-OP-02015, TURBINE ALARM PANEL 15 BOP ANNUNCIATORS (alarm comes in at 5.7 inches HgA)

Check pressure at PR530

Check pressure at PR541 SRO Implement DB-OP-02518, HIGH CONDENSER PRESSURE Monitor Reactor Power ATC

Maintain Reactor Power 100% or less IF AT ANY TIME Condenser Pressure reaches 4.5 inches HgA BOP (LP Condenser), THEN verify the Mechanical Hogger Starts IF AT ANY TIME Condenser Pressure reaches 5 inches HgA ATC THEN reduce Reactor Power to maintain Condenser pressure less than or equal to 5 inches HgA Recognize Condenser Pressure reaches 4.5 inches HgA BOP (LP Condenser) and Mechanical Hogger has not started Start Mechanical Hogger BOP

HIS1005 Mechanical Hogger CREW Recognize condenser pressure rise has stopped On Lead Evaluators discretion, when Condenser pressure rise has been stopped, proceed to Event 5, Loss of RCS Makeup NUREG-1021, R9 Supp. 1 Page 7 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 5 Page 8 of 16 Event

Description:

Makeup Pump 2 Trip Time Position Applicants Actions or Behavior Event 5: Makeup Pump 2 Trip Indications Available:

6-5-C SEAL INJ FLOW LO 6-6-C SEAL INJ TOTAL FLOW Makeup Pump red RUN light OFF Zero Makeup flow MU32, Pressurizer Level Control Opening MU19, RCP Seal Injection Flow Control Opening CREW Recognize a loss of running RCS Makeup Pump Implement DB-OP-02512, Makeup and Purification System SRO Malfunctions for a loss of RCS Makeup Pump(s)

Isolate Letdown using MU 2B ATC

Depress close HISMU2B Verify CCW is being supplied to the RCPs using Attachment 1, BOP Verification Of CCW Flow To Reactor Coolant Pumps BOP Verify CCW Pump in service Verify CCW Non-Essential flow path to Containment available BOP

CC5095, Supply Open

CC5097, CTMT BLDG Return Open Verify CCW flow path to Containment available BOP

CC1411A Open

CC1411B Open Verify CCW return path from Containment available BOP

CC1407A Open

CC1407B Open NUREG-1021, R9 Supp. 1 Page 8 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 5 Page 9 of 16 Event

Description:

Makeup Pump 2 Trip Time Position Applicants Actions or Behavior Event 5: Makeup Pump 2 Trip - continued Verify Seal Cooling CCW Return flow path is available

RCP 1-1 CC4100 Open BOP

RCP 1-2 CC4200 Open

RCP 2-1 CC4300 Open

RCP 2-2 CC4400 Open

Check Annunciator Alarm 6-5-B, SEAL CCW FLOW BOP LOW is extinguished Notify SRO CCW flow is available to the Reactor Coolant BOP pumps Monitor Pressurizer level and compare to curve CC 4.3 ATC Anytime Pressurizer Level is less than 160 inches, trip the reactor and go to DB-OP-02000 ATC Isolate RCP Seal Injection by closing MU19 Place MU32 in Hand AND close MU32 to isolate the normal ATC Makeup flowpath Refer to DB-OP-02515, Reactor Coolant Pump and Motor SRO Abnormal Operation CREW Monitor RCP Seal parameters BOP/ATC Maintain Tave constant Refer to TRM 8.1.1, Boration Systems - Operating SRO Enter TRM 8.1.1, Nonconformance A NUREG-1021, R9 Supp. 1 Page 9 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 5 Page 10 of 16 Event

Description:

Makeup Pump 2 Trip Time Position Applicants Actions or Behavior Event 5: Makeup Pump 2 Trip - continued

Notify the Shift Manager to perform event notifications SRO

Dispatch Operator to investigate Booth Role play if asked to investigate Makeup Pump 2 trip -

report 50/59 relay target on MUP 2 breaker AD105 Cue Role play if asked no local pump problems observed Verify Makeup Pump did not indicate cavitation

No erratic amps, No erratic flow ATC

No erratic discharge pressure

Makeup pump did not empty BOP Dispatch Operator to monitor makeup pump start

1. Start Makeup Pump 1 oil pumps ATC

2. Start Makeup Pump Booth Role play as equipment Operator and report when Cue stationed at MUP and proper operation of MUP 1 ATC Restore Makeup flow - place MU32 in Automatic Restore Seal Injection flow:

Verify MU19 closed

Verify MU66A through D open ATC

Verify MU6408 Open

Verify MU6409 Open

Gradually over 2 minutes open MU19 to establish 12-15 gpm seal inject flow (minimum 3 gpm to any RCP)

Restore letdown - Attempt to open MU2B ATC

ATC reports MU2B will not open MU2B is triggered to be failed closed. Proceed to event 6 Loss of Letdown Flowpath NUREG-1021, R9 Supp. 1 Page 10 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 6 Page 11 of 16 Event

Description:

Loss of Letdown Flowpath - MU2B fails closed Time Position Applicants Actions or Behavior Event 6: Loss of Letdown Flowpath Indications Available:

MU2B will not open following Makeup Flow restoration ATC Reports to SRO Letdown cannot be restored SRO Implement DB-OP-02512 for Loss of Letdown Flowpath Contacts Equipment Operator and/or Maintenance to SRO determine cause of MU2B fail to open Booth MU2B failure to open appears to be a problem with the Cue valve SRO Request Chemistry to maximize sample flow ATC Open RC240A & RC240B Pressurizer liquid sample isolations Determines the response not obtained step applies for SRO restoring letdown flow and a shutdown is required.

Implement DB-OP-02504, Rapid Shutdown ULD with ICS in Automatic

At the LOAD CONTROL Panel, set the rate of change to the ATC rate specified by the Command SRO

Select the target RTP as determined by the Command SRO Monitor Reactor Power to confirm power is being reduced at CREW approximately the expected rate (NI vs. HBP)

IF Pressurizer Level is greater than 228 inches, then refer to SRO Technical Specification 3.4.9 Condition A On Lead Evaluators discretion, when reactivity manipulation is attained, proceed to event 7, Loss of Condensate/ATWS NUREG-1021, R9 Supp. 1 Page 11 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 7 Page 12 of 16 Event

Description:

Loss of Condensate flow and ATWS Time Position Applicants Actions or Behavior Loss of Condensate/ATWS Indications Available:

13-2-B CNDS PMP DISCH HDR PRESS FI578 COND PMP COMBINED FLOW indicates 0 MMPH CREW Recognize Condensate flow is lost BOP Implement DB-OP-02013 for 13-2-B BOP Dispatch an Operator to investigate CD2796 Booth Role play as Equipment Operator and report CD2796 is Cue closed and will not open BOP Implement DB-OP-02013 for low Deaerator level CREW Monitor proper runback when Deaerator levels reach 4 feet When Deaerator levels approach off scale low direct:

Trip Reactor SRO

Trip both MFPTs

Initiate and isolate SFRCS Perform DB-OP-02000 immediate actions

Attempt to manually trip reactor

Report failure of manual pushbuttons to trip reactor

Critical * *De-energize E2 and F2 ATC Task

Re-energize E2 and F2

Verify power decreasing on the Intermediate Range

Manually trip the turbine

*Manually actuate SFRCS Proceed to Events 8, 9 & 10 NUREG-1021, R9 Supp. 1 Page 12 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 8, 9 & 10 Page 13 of 16 Event

Description:

SG1 Safety sticks open, SG2 overfill and PZR Spray fails open Time Position Applicants Actions or Behavior Events 8, 9 & 10: SG1 Safety sticks open, SG2 overfill and PZR Spray fails open Indications Available:

SG1 Pressure lowering SG2 Level rising above setpoint RC2, PZR Spray valve not closing BOP Recognize no AFW flow to SG 1 Specific Rule 4 - Steam Generator Control - Refer to Attachment 5 to place the MDFP in service to feed SG 1

Enable both MDFP Discharge Valves BOP

Close both MDFP Discharge Valves

Attempt to start the MDFP

Recognize MDFP does not start Booth If asked, role play as Equipment Operator and report MDFP Cue breaker AD210 has overcurrent relay tripped CREW Recognize overcooling SG1 SRO Implement DB-OP-02000, section 7 Overcooling Implement Attachment 8, Place MU/HPI/LPI in Service

Start/Verify running both CCW Pumps

Start/Verify running both HPI Pumps

Verify open HP 2A, HP 2B, HP 2C and HP 2D

Start both LPI Pumps ATC

Open DH 64 and DH 63

Transfer Makeup Pump suctions, MU6405 & MU3971, to the BWST

Set Pressurizer Level Controller to 100 inches

Lock MU Pump suctions, MU6405 & MU3971, on the BWST

Verify Pressurizer heaters are off BOP Verify proper SFRCS. Refer to DB-OP-02000, Table 1 Events 8, 9 & 10: SG1 Safety sticks open, SG2 overfill and PZR Spray fails open NUREG-1021, R9 Supp. 1 Page 13 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 1 Event # 8, 9 & 10 Page 14 of 16 Event

Description:

SG1 Safety sticks open, SG2 overfill and PZR Spray fails open Time Position Applicants Actions or Behavior CREW Diagnose stuck open safety SG1 Control SG2 AVV to maintain RCS temperature constant or BOP slowly lowering BOP Recognize SG2 above setpoint with full Aux Feedwater flow.

Control SG2 level by performing one or more of the following:

Critical BOP

Reduce AFPT 2 speed Task

Close AF599 Direct reducing RCS pressure to minimum adequate SRO subcooling margin.

ATC Begin to depressurize the RCS using Pressurizer Spray ATC Open RC2, Pressurizer Spray When attempting to stop depressurization recognize RC2 will ATC not close ATC Close RC10, Pressurizer Spray Valve Block Valve When SG2 Level control is established and the depressurization has been stopped the Scenario can be terminated NUREG-1021, R9 Supp. 1 Page 14 of 16 FENOC Facsimile AG

Justification for Critical Tasks A. Shutdown Reactor - ATWS (CT-24)

The Reactor will be required to be tripped when Deaerator levels are lost resulting in a loss of Feedwater. The Reactor trip pushbuttons will fail which will require the CRDMs to be de-energized by momentarily de-energizing buses E2 and F2 from the Control Room.

B. Establish FW flow and Feed SG (CT-10)

The Steam Feed Rupture Control System will be required to be manually actuated to provide feedwater from AFP 2 and Steam Generator level control will have to be manually controlled to prevent overfill of SG2 which would result in the loss of the remaining secondary heat removal source.

NUREG-1021, R9 Supp. 1 Page 15 of 16 FENOC Facsimile AG

SIMULATOR SETUP INFORMATION

1. Simulator Setup a) CCW Pump 1 and MUP 2 in service b) Mechanical Hogger Auto start failure c) MU2B fail to open after closure d) Auto Reactor trip prohibited e) Auto SFRCS initiate and isolate prohibited f) AFPT 2 Discharge valve failure g) Spray valve fails to close when manually opened

2. Procedures a) DB-OP-02010, Feedwater Alarm Panel 10 Annunciators for 10-4-G b) DB-OP-02011, Heat Sink Alarm Panel Annunciators, for 11-3-E c) DB-OP-02517, Circulating Water System Malfunction d) DB-OP-02513, Pressurizer System Abnormal for Level Instrument e) DB-OP-06221, Condensate System Procedure.

f) DB-OP-02015, TURBINE ALARM PANEL 15 ANNUNCIATORS g) DB-OP-02518, HIGH CONDENSER PRESSURE h) DB-OP-02012, Makeup and Purification System Malfunctions i) DB-OP-02013, Condensate and feedwater alarm panel annunciators j) DB-OP-02000, RPS, SFAS, SFRCS Trip, or Steam Generator Tube Rupture

2) For Simulator Instructor:

a) DB-OP-02518 Attachment 1 b) DB-OP-06006 Section 3.2, Starting Makeup Pump 1 NUREG-1021, R9 Supp. 1 Page 16 of 16 FENOC Facsimile AG

Appendix D Scenario Outline Form ES-D-1 Facility: Davis-Besse Scenario No.: 2 Op Test No.: DB NRC 2015 Examiners: Operators: SRO ATC BOP Initial Conditions:

100% Power

EDG 1 OOS Turnover: Maintain 100% Power Planned: Swap Main Feed Pump Turbine Main Oil Pumps per the Monthly Activity Log Critical tasks: 1. Establish Electrical Power Alignment (CT-8)

2. Initiate HPI (CT-2)

Event Malf. Event Type* Event No. No. Description 1 N-BOP/SRO Swap MFPT Oil Pumps 2 SRO (TS) Startup Transformer 02 Lockout 3 C-ATC/SRO Makeup Filter high differential pressure 4 I-BOP/SRO Deaerator level transmitter fails low 5 SRO (TS) Oil leak on Containment Spray Pump R-ATC/SRO RCP 1-1 high vibrations - reduce power 6

C-BOP/SRO FW auto re-ratio fails when trip RCP 7 C-ATC/SRO 3 Power Range NIs fail - Trip reactor 8 Major Loss of Offsite Power 9 Major RCS Leak 10 C-ATC/SRO EDG 2 trips after starting

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NUREG-1021, R9 Supp. 1 Page 1 of 17 FENOC Facsimile AG

Scenario Event Summary DAVIS-BESSE 2015 NRC SCENARIO 2 The Crew will take the watch with power at 100%. Following turnover the Crew will swap running Main Feed Pump Turbine Main Oil Pumps as directed by the Monthly Activity Log.

After the MFPT Oil Pumps are swapped the Lead Evaluator will cue the Startup Transformer 02 Lockout. SU XFMR 02 LOCKOUT will alarm and the SRO will enter the applicable Off-Site AC Sources Technical Specification (TS).

After the SRO has declared the TS for Off-Site AC Sources the Lead Evaluator will cue the Makeup Filter High Differential Pressure. LETDOWN OR MU FILT P HI will alarm and PDI MU13 will indicate >25 PSID. The ATC will implement DB-OP-02002, Letdown/Makeup Alarm Panel 2 Annunciators. The SRO will direct placing the standby Makeup filter in service in accordance with DB-OP-06006, Makeup and Purification System.

When the standby Makeup filter has been placed in service the Lead Evaluator will cue Deaerator Storage Tank 2 level, LT 420, control signal fails low. DEAR TK 1 LVL will alarm. The BOP will manually control Deaerator level by manually controlling CD-421 using LIC421.

Once LIC421 is placed in manual and level control is established the Lead Evaluator will cue the Containment Spray (CS) Pump 1 oil leak. An Equipment Operator will call the control room to report an oil leak on Containment Spray (CS) Pump 1. The SRO will declare the CS Pump Inoperable and enter the applicable TS.

After the SRO has declared the TS for the CS Pump, the Lead Evaluator will cue the RCP 1-1 high vibrations. MOTOR VIB HI and MONITOR SYSTEM TRBL will alarm. The SRO will implement DB-OP-02515, RCP Pump and Motor Abnormal. The SRO will implement DB-OP-02504, Rapid Shutdown to reduce power. The ATC will reduce power to less than 72% and RCP 1-1 will be stopped. When the RCP is stopped FW will fail to auto re-ratio and the BOP will be required to take loop demands to hand and auto re-ratio.

After RCP 1-1 is stopped the Lead Evaluator will cue the 3 of 4 Power Range Nuclear Instruments low failure. The SRO will implement DB-OP-02505, Nuclear Instrument Failures and direct the ATC to trip the Reactor.

When the Reactor is tripped a Loss of Offsite Power will occur and an RCS leak will develop.

EDG 2 will trip after starting. Since EDG 1 is OOS this will cause a blackout until the BOP starts Station Blackout Diesel Generator (SBODG) and powers 4160 buses D2 and D1 per 8 of DB-OP-02000 IAW Specific Rule 6. (CT-8)

DB-OP-02000 Loss of Subcooling Margin Section 5 will be entered. Train 2 Makeup and HPI will be placed in service after the SBODG is aligned to D2 and D1 buses. (CT-2)

Subcooling margin will be regained and HPI should be throttled. The SG Atmospheric Vent Valves will be controlled to maintain RCS temperature constant or slightly lowering.

The scenario can be terminated, at the Lead Evaluators discretion.

NUREG-1021, R9 Supp. 1 Page 2 of 17 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 1 Page 3 of 17 Event

Description:

Swap running MFPT Main Oil Pumps per the Monthly Activity Log Time Position Applicants Actions or Behavior Event 1: Swap running MFPT Main Oil Pumps SRO Direct BOP to swap running MFPT 1 and 2 Main Oil Pumps as directed by the Monthly Activity Log per DB-OP-06224,Main Feed Pump and Turbine, sections 3.23 and 3.24 BOP Swap MFPT 1 Main Oil Pumps BOP Verify Equipment Operator standing by to monitor oil pressures BOP 1. Start MFPT 1 Main Oil Pump 2, using HIS 1198 MAIN FEED PUMP 1 Main Oil Pump 2

2. Stop MFPT 1 Main Oil Pump 1, using HIS 1195, MAIN FEED PUMP 1 Main Oil Pump 1 BOP NOTE: Contacts Equipment Operator for local indications Check MFPT 1 Main Oil Pump pressure indications:

PI 1194 Hydraulic Oil Pressure is > 200 PSIG

PI 1216 Turbine Bearing Oil Pressure is > 10 PSIG

PI 1207 Pump Bearing Oil Pressure is > 10 PSIG

PI 2650 Control Oil Pressure is 52.5 - 62.5 PSIG

PI 1206 Lube Oil System HDR Pressure (CTRM) is between 10 and 16 PSIG Booth PI 1194 indicates 238 psig. PI 1216 indicates 12 psig. PI Cue 1207 indicates 12 psig PI 2650 indicates 55 psig.

BOP Verify the available MFPT 1 Main Oil Pumps are in AUTO START:

HIS 1195, MAIN FEED PUMP 1 Main Oil Pump 1

HIS 1198, MAIN FEED PUMP 1 Main Oil Pump 2 BOP Swap MFPT 2 Main Oil Pumps BOP Verify Equipment Operator standing by to monitor oil pressures NUREG-1021, R9, Supp. 1 Page 3 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 1 Page 4 of 17 Event

Description:

Swap running MFPT Main Oil Pumps per the Monthly Activity Log Time Position Applicants Actions or Behavior Event 1: Swap MFPT Main Oil Pumps - continued BOP 1. Start MFPT 2 Main Oil Pump 1, using HIS 1236, MAIN FEED PUMP 2 Main Oil Pump 1

2. Stop MFPT 2 Main Oil Pump 2, using HIS 1247, MAIN FEED PUMP 2 Main Oil Pump 2 BOP NOTE: Contacts Equipment Operator for local indications Check MFPT 1 Main Oil Pump pressure indications:

PI 1246 Hydraulic Oil Pressure is > 200 PSIG

PI 1259 Turbine Bearing Oil Pressure is > 10 PSIG

PI 1257 Pump Bearing Oil Pressure is > 10 PSIG

PI 2630 Control Oil Pressure is 52.5 - 62.5 PSIG

PI 1256 Lube Oil System HDR Pressure (CTRM) is between 10 and 16 PSIG Booth PI 1246 indicates 238 psig. PI 1259 indicates 12 psig. PI Cue 1257 indicates 12 psig PI 2630 indicates 55 psig.

BOP Verify the available MFPT 2 Main Oil Pumps are in AUTO START:

HIS 1236, MAIN FEED PUMP 1 Main Oil Pump 1

HIS 1247, MAIN FEED PUMP 1 Main Oil Pump 2 On Lead Evaluators discretion, insert Event 2 NUREG-1021, R9, Supp. 1 Page 4 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 2 Page 5 of 17 Event

Description:

Startup Transformer 02 Lockout Time Position Applicants Actions or Behavior Event 2: Startup Transformer 2 Lockout Indications Available:

1-1-G SU XFMR 02 LOCKOUT 1-2-G SU XFMR 02 DNGR ACB 34562 Open & ACB 34564 Open 81-B-65 Open & 81-B-67 Open CREW Recognize Startup Transformer 02 Lockout CREW Recognize loss of K bus ATC Implement DB-OP-02001, Electrical Distribution Panel 1 SRO Notify the Load Dispatcher K Bus is de-energized Booth Role play as Load Dispatcher: We are sending a crew to Cue investigate Direct Isolation of SU Transformer 02 SRO

Refer to DB-OP-06311, 345KV Switchyard Procedure SRO Dispatch Equipment Operator to investigate S/U Xfmr 02 Role play as Equipment Operator: Local Annunciator Booth Alarm (102-7-A) SUDDEN PRESSURE is in alarm. SU Cue Transformer 02 has no visible damage.

Implement DB-OP-2102, Startup Transformer 02 Alarm Panel SRO 102 Annunciators for alarm 102-7-A (same actions as transformer lockout)

ATC Transfer B bus reserve source selector switch to X01 NUREG-1021, R9, Supp. 1 Page 5 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 2 Page 6 of 17 Event

Description:

Startup Transformer 02 Lockout Time Position Applicants Actions or Behavior Event 2: Startup Transformer 2 Lockout - continued Refer to Tech Spec 3.8.1, AC Sources - Operating SRO

Enter TS 3.8.1, Condition A & D

Direct performance of DB-SC-03023, Off-Site Sources Another Operator will ensure completion and review of DB-SM Cue SC-03023, Off-Site Sources On Lead Evaluators discretion, when Tech Spec declared proceed to Event 3 NUREG-1021, R9, Supp. 1 Page 6 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 3 Page 7 of 17 Event

Description:

Makeup Filter high differential pressure Time Position Applicants Actions or Behavior Event 3: Makeup Filter high differential pressure Indications Available:

2-4-A LETDOWN OR MU FILT P HI PDI MU13 indicates >25 PSID Recognize Makeup Filter high differential pressure for in CREW service Makeup Filter 1 Implement DB-OP-02002, Letdown/Makeup Alarm Panel 2 ATC Annunciators Direct placing Makeup Filter 2 in service in accordance with SRO DB-OP-06006, Makeup and Purification System ATC Swap to Makeup Filter 2 Open MU12B, MAKEUP FILTER 2 INLET ISOLATION, using ATC HISMU12B.

Close MU12A, MAKEUP FILTER 1 INLET ISOLATION, using ATC HISMU12A.

On Lead Evaluators discretion, proceed to Event 4 NUREG-1021, R9, Supp. 1 Page 7 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 4 Page 8 of 17 Event

Description:

Deaerator level transmitter fails low over a ramp Time Position Applicants Actions or Behavior Event 4: Deaerator level transmitter fails low Indications Available:

13-4-C, DEAR STRG TK 1 LVL 13-4-D, DEAR STRG TK 2 LVL (may also alarm)

Level indicator failed low (Indicator to LIC CD421)

Actual Deaerator Level rising as LCV opens CREW Recognize Deaerator Storage Tank 1 level Diagnose high Deaerator Storage Tank 1 water level as BOP indicated at LI 202, DEAERATOR STORAGE TANK 1.

Implement DB-OP-02013, Condensate Feedwater Alarm Panel BOP Annunciators Verify the proper number of Condensate Pumps are in BOP operation for the present unit load BOP Diagnose Deaerator Storage Tank 1 level transmitter failure Manually control Deaerator 1 level by manually controlling CD-BOP 421 using LIC-421 and throttling closed (may also take CD-420 to manual for Deaerator 2)

Role play as an Equipment Operator to investigate CD420 Booth and CD421 Cue Report valves appear to be working normally Booth Role play as Maintenance/Work Week Manager/Field Cue Supervisor to initiate repair of level transmitter On Lead Evaluators discretion, proceed to Event 5 NUREG-1021, R9, Supp. 1 Page 8 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 5 Page 9 of 17 Event

Description:

Oil Leak On Containment Spray Pump 1 Time Position Applicants Actions or Behavior Event 5: Oil Leak on Containment Spray Pump 1 Indications Available:

Equipment Operator report Role play as Equipment operator and report Containment Booth Spray Pump 1 inboard bearing has a severe oil leak and no Cue level is indicated. The sight glass is broken and will need replaced.

SRO May contact Maintenance and/or Work Week Manager Booth If necessary, role play as maintenance and report Containment Spray Pump 1 will be required to be Cue removed from service to repair broken sight glass Declare Containment Spray Pump 1 Inoperable SRO

Enter Tech Spec 3.6.6, Condition A Dispatch Operator to remove close power fuses for BE111, SRO Containment Spray Pump 1 Booth Role play as Equipment Operator to remove close power Cue fuses for BE111, Containment Spray Pump 1 BOP Turn on CS Pump 1 Blue Operability Light On Lead Evaluators discretion after Tech Spec has been entered, proceed to Event 5 NUREG-1021, R9, Supp. 1 Page 9 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 7 Page 10 of 17 Event

Description:

Power Range Nuclear Instrument Failure Time Position Applicants Actions or Behavior Event 6: Reactor Coolant Pump 1 High Vibrations Indications Available:

6-1-A MOTOR VIB HI 6-5-A MONITOR SYSTEM TRBL CREW Recognize RCP 1-1 high vibrations SRO Implement DB-OP-02515, RCP and Motor Abnormal procedure Verify the RCP 1-1 motor conditions exceed operational limits CREW using the PPC or SPDS Implement DB-OP-02515 Attachment 1, Reactor Coolant Pump SRO Shutdown Implement DB-OP-02504, Rapid Shutdown SRO

Direct power reduction to 70%

ULD with ICS in Automatic

At the LOAD CONTROL Panel, set the rate of change to the ATC rate specified by the Command SRO

Select the target RTP as determined by the Command SRO Monitor Reactor Power to confirm power is being reduced at CREW approximately the expected rate (NI vs. HBP)

Monitor Regulating Rod Insertion Limits during the Shutdown ATC per Technical Specification 3.2.1 Attempt to maintain Axial Power Imbalance between 0 and ATC negative 20 percent using APSRs Perform Attachment 6, Balance of Plant Actions for Rapid BOP Shutdown NUREG-1021, R9, Supp. 1 Page 10 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 7 Page 11 of 17 Event

Description:

Power Range Nuclear Instrument Failure Time Position Applicants Actions or Behavior Event 6: Reactor Coolant Pump 1 High Vibrations - continued At approximately 90 percent power, notify the Field Supervisor BOP to remove the Auxiliary Feed Pump Turbine Main Steam Minimum flow lines from service When Condensate flow is less than 7.0 MPPH (FI578), then BOP establish two Condensate pumps in operation Notify the System Control Center (SCC) Load Dispatcher of the SRO unit load reduction BOP Place the Tc controller in Automatic ATC Reduce reactor power to < 72 percent ATC Stop RCP 1-1 BOP Verify proper Feedwater flow ratios of 2.4 to 1 Recognize auto re-ratio is not occurring:

Take both FW Loop Demands to Hand BOP

Ratio FW to approximately 2.38 MPPH on SG1

Ratio FW to approximately 5.74 MPPH on SG2 ATC Verify Tave control is on RCS Loop 2 Check RCS flow is greater than the flow required by TS 3.4.1, SRO DNB Limits. REFER TO DB-OP-03006, Miscellaneous Instrument Shift Checks. (Computer Point F744)

Notify I&C to reduce the RPS High Flux Trip setpoints within 10 SRO hours On Lead Evaluators discretion proceed to Event 7 Event 7: 3 Power Range NUREG-1021, R9, Supp. 1 Page 11 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 7 Page 12 of 17 Event

Description:

Power Range Nuclear Instrument Failure Time Position Applicants Actions or Behavior NIs fail low Indications Available:

5-3-5 ARTS T-G TRIP BYPASSED Power range NIs 5,6 and 7 indicate 0 CREW Recognize Power range NIs have failed low SRO Implement DB-OP-02505, Nuclear Instrumentation Failures Direct tripping the Reactor due to 3 of 4 Power Range SRO Instruments are in a condition that prevents automatic reactor protection GO TO DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube CREW Rupture Perform DB-OP-02000 immediate actions:

1. Manually trip the reactor

Depress the reactor trip pushbutton ATC 2. Verify reactor power is decreasing on the intermediate range

3. Manually trip the turbine

4. Depress the turbine trip pushbutton Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture SRO

Verify immediate actions

Check for Specific Rule or Symptom Mitigation Proceed to Events 8, 9 and 10 NUREG-1021, R9, Supp. 1 Page 12 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 8, 9 and 10 Page 13 of 17 Event

Description:

Loss of Offsite power, RCS Leak, EDG 2 trips after starting Time Position Applicants Actions or Behavior Event 8: Loss of Offsite Power Event 9: Reactor Coolant System Leak Event 10: Emergency Diesel Generator 2 trips Indications Available:

Loss of Control Room Lighting Loss of Subcooling Margin CREW Recognize loss of all AC Power Specific Rule 6

Recognize C1 and D1 are de-energized BOP

Recognize EDG 1 is OOS and EDG 2 has a fault

Dispatch an Equipment Operator to EDG 2 Energize D2 Bus by performing Attachment 28, Restore Power to C1 or D1 from the SBODG

Verify ABDD2 is open

Critical

Verify AD110 is open BOP Task

*Start the SBODG

Verify AD213 is closed

*Close AD 301 Energize C1

Verify HBBD is open

*Close ABDD2

*Close ABDC1

Critical BOP OR Task Energize D1

*Close AD110 NUREG-1021, R9, Supp. 1 Page 13 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 8, 9 and 10 Page 14 of 17 Event

Description:

Loss of Offsite power, RCS Leak, EDG 2 trips after starting Time Position Applicants Actions or Behavior Events 8, 9 and 10 continued Perform Specific Rule 4

Verify proper AFW actuation

Refer to Attachment 3 for AVV control BOP

Verify D2 Bus is energized

Verify an air compressor is running

Control RCS temperature constant or slightly lowering CREW DB-OP-02000 check for Symptoms SRO Route to Section 5, Loss of Subcooling Margin CREW Verify all RCPs are tripped Implement Attachment 8, Place MU/HPI/LPI in Service as equipment is available

Start/Verify running a CCW Pump

*Manually start a HPI Pump (auto start is failed)

*Open HP 2A and HP 2B OR HP 2C and HP 2D

Refer to Attachment 11, HPI Flow Balancing

Start a LPI Pump

Critical

Open DH 64 OR DH 63 BOP Task

Transfer a MU Pump suction to the BWST

Set Pressurizer Level Controller to 100 inches

Close MU 19

Close MU 32

*Start a Makeup Pump

*Control Pressurizer level using MU 32 or Alternate Injection Line ATC If Pressurizer level is < 40 inches and as equipment becomes NUREG-1021, R9, Supp. 1 Page 14 of 17 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 2 Event # 8, 9 and 10 Page 15 of 17 Event

Description:

Loss of Offsite power, RCS Leak, EDG 2 trips after starting Time Position Applicants Actions or Behavior available:

Lock the running MU Pump suction on the BWST

Isolate Letdown

Verify Pressurizer heaters are off

Open MU 6421 (if 2 Makeup Pumps are running)

Open MU 6419 (if 2 Makeup Pumps are running)

Direct an Equipment Operator to open MU6423B ATC Verify proper SFAS actuation BOP Verify proper SFRCS actuation BOP Verify proper SG level control BOP Realign AFW if an SFRCS low pressure trip occurs CREW Check for Overcooling CREW Check for ICC Conditions CREW Monitor for adequate Subcooling Margin When Subcooling Margin is regained throttle Makeup and/or ATC HPI as necessary per Specific Rule 3 Note: Not required to wait for subcooling margin to be regained to terminate scenario When DB-OP-02000, Attachment 8, Place HPI/LPI/MU is complete - Scenario may be terminated at Lead Evaluators discretion NUREG-1021, R9, Supp. 1 Page 15 of 17 FENOC Facsimile Rev. 1

Justification for Critical Tasks A. Electrical Power Alignment,(CT- 8)

Loss of Emergency Generator 2 with a loss of off-site power and Emergency Generator 1 out of service results in a station blackout. The Station Blackout Diesel Generator will be required to be placed in service to supply an essential bus.

B. Initiate High Pressure Injection (CT- 2)

The Reactor Coolant System Leak that develops following the loss of off-site power will result in a loss of subcooling margin. Once an essential bus is powered by the Station Blackout Diesel Generator High Pressure Injection will be required to be placed in service to restore Reactor Coolant System inventory and subcooling margin NUREG-1021, R9, Supp. 1 Page 16 of 17 FENOC Facsimile Rev. 1

SIMULATOR SETUP INFORMATION

1. Simulator Setup a) Emergency Diesel Generator 1 Out of Service b) Makeup Filter 1 in service c) EDG trip after auto start d) HPI auto start prohibited

2. Procedures a) DB-OP-02001, Electrical Distribution Panel 1 Annunciators b) DB-OP-2102, Startup Transformer 02 Alarm Panel 102 Annunciators for alarm 102-7-A c) DB-OP-06311, 345KV Switchyard Procedure d) DB-OP-02000, Letdown/Makeup Alarm Panel 2 Annunciators e) DB-OP-02013, Condensate Feedwater Alarm Panel Annunciators f) DB-OP-02515, RCP and Motor Abnormal procedure g) DB-OP-02504, Rapid Shutdown h) DB-OP-02000, RPS, SFAS, SFRCS Trip, or Steam Generator Tube Rupture

3. For Simulator Instructor:

a) DB-OP-06311, Switchyard, Main Transformer, Auxiliary Transformer and Startup Transformers, Section 3.17 b) DB-OP-02001 for 1-1-G c) DB-OP-02504, Rapid Shutdown Attachment 15

4. For Normal Evolution a) DB-OP-06224 Section 3.24 and 3.25 NUREG-1021, R9, Supp. 1 Page 17 of 17 FENOC Facsimile Rev. 1

Appendix D Scenario Outline Form ES-D-1 Facility: Davis-Besse Scenario No.: 3 Op Test No.: NRC 2015 Examiners: Operators: SRO ATC BOP Initial Conditions:

70% Power

RCP 1-1 OOS

EDG 1 OOS Turnover: Maintain 70% Power Planned: Perform MFPT 1 Stop Valve Test, DB-SS-04052 Critical tasks: 1. Establish FW flow and feed SGs (CT-10)

2. Control HPI (CT-5)

3. Close RC11 PORV Block Valve (Emergent)

Event Malf. Event Type* Event No. No. Description 1 N-BOP/SRO MFPT 1 Stop Valve Test, DB-SS-04052 2 C-ATC/SRO PORV Leakage (TS)

I-ATC/BOP 3 RCS Hot Leg RTD slowly drifts HI SRO 4 C-BOP MFPT Low Oil pressure - trip MFPT R-ATC 5 Dropped Rod - Power reduction SRO (TS) 6 Major SG Tube Rupture - trip Reactor 7 C-BOP/SRO Loss of Feedwater -SFRCS fails auto actuation 8 C-ATC/SRO PZR Spray valve fails closed

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NUREG-1021, R9 Supp. 1 Page 1 of 16 FENOC Facsimile AG

Scenario Event Summary DAVIS-BESSE 2015 NRC SCENARIO 3 The Crew will take the watch with power at 70% with 3 RCPs in operation. Following turnover the BOP will perform DB-SS-04052, MFPT 1 Stop Valve Test.

On cue from the Lead Evaluator, a leak will be introduced on the PZR Pressure Operated Relief Valve (PORV). The crew will respond to computer and Panel 9 annunciator alarms and isolate the PORV IAW DB-OP-02513, PRESSURIZER SYSTEM ABNORMAL OPERATION. The SRO will enter the applicable TS for the PORV.

When the SRO has declared the TS for the PORV, the Lead Evaluator will cue the selected Thot RTD transmitter (TT RC3A1) to slowly fail high. HOT LEG TEMP HIGH annunciator alarm will sound and the Integrated Control System (ICS) will begin reducing power to lower Tave.

The ATC will place the Rod Control Panel in manual and the BOP will place Feedwater Loop Demands in manual to stabilize the plant. The good instrument will be selected and Tave will be restored to 582 °F. Rod Control Panel and Feedwater Loop Demand control stations will then be returned to AUTO.

When ICS is returned to Auto the Lead Evaluator will cue the MFPT oil leak. MFPT 2 LUBE OIL TK LVL will alarm. The BOP will implement DB-OP-02010, Feedwater Alarm Panel 10 Annunciators. An Equipment Operator will report MFP 2 bearing oil header spraying oil and the pump making a squealing sound. The SRO will direct tripping the MFPT and ICS will run the plant back to 55% power OR direct power reduction to 55% and then tripping pump.

After the MFPT is removed from service the Lead Evaluator will cue the dropped control rod.

Alarms CRD LCO and CRD ASYMETRIC ROD will sound and a Rod bottom light will be ON.

The SRO will implement DB-OP-02516, CRD Malfunctions. The ATC will be directed to reduce power to 33% per DB-OP-02504, Rapid Shutdown. The SRO will enter the applicable TS for the Inoperable control rod.

After the TS has been declared for the Inoperable control rod the Lead Evaluator will cue the Steam Generator Tube Rupture. Alarms MN STM LINE 2 RAD HI and VAC SYS DISCH RAD HI will sound. Rising MU flow with lowering MUT level and PZR level will be observed. The SRO will implement DB-OP-02531, Steam Generator Tube Leak. The ATC will evaluate the leak to be greater than 50 gpm and the SRO will route to B-OP-02000, Section 8, SG Tube Rupture.

The BOP will place HPI/LPI/MU in service and the ATC will reduce power to SG low level limits.

The BOP will transfer steam loads from the Turbine to the Turbine Bypass Valves. When load is less than 50 MWe the ATC will trip the Reactor.

When the reactor is tripped the remaining MFPT will trip and Auxiliary Feedwater will fail to automatically actuate. The BOP will depress the SFRCS pushbuttons to initiate AFW and isolate Main Feedwater and Main Steam (CT-10).

The ATC will be directed to reduce RCS pressure to minimum subcooling margin. When this is attempted it will be recognized that the PZR spray valve is failed closed and the alternate PZR Vent Line method will be used. The ATC will control HPI to maintain RCS inventory (CT-5).

When the pressure reduction has begun the scenario can be terminated, at the Lead Evaluators discretion.

NUREG-1021, R9 Supp. 1 Page 2 of 16 FENOC Facsimile AG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 1 Page 3 of Event

Description:

Perform DB-SS-04052, MFPT 1 Stop Valves Periodic Test Time Position Applicants Actions or Behavior Event 1: Perform DB-SS-04052, MFPT 1 Stop Valves Periodic Test SRO Direct BOP to perform MFPT 1 Stop Valves Periodic Test BOP Verify Local Operator at MFPT 1 BOP Test HP Stop Valve Depress and hold HIS793, HP STOP VALVE TEST CLOSE BOP

Check HIS793 Green light ON, Red light OFF Booth Role play as Equipment Operator - Observed MFPT 1 HP Cue Stop Valve stroked smoothly Release HIS793, HP STOP VALVE TEST CLOSE BOP

Check HIS793 Red light ON, Green light OFF BOP Test LP Stop Valve Depress and hold HIS795, LP STOP VALVE TEST CLOSE BOP

Check amber TEST light ON, HIS Red light OFF Booth Role play as Equipment Operator - Observed MFPT 1 LP Cue Stop Valve stroked smoothly Release HIS795, LP STOP VALVE TEST CLOSE BOP

Check amber TEST light OFF, HIS Red light ON On Lead Evaluators discretion, insert Event 2 NUREG-1021, R9 Supp. 1 Page 3 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 2 Page 4 of Event

Description:

PORV Leakage Time Position Applicants Actions or Behavior Event 2: PORV Leakage Indications Available:

4-2-D, PZR QUENCH TANK PRESS HI 4-4-C, HOT LEG PRESS LO T773, RC PRZR PWR RLF OUT TEMP, RC12-1 rising RCS pressure lowering Refer to DB-OP-02004, Reactor Coolant Alarm Panel 4 ATC Annunciators Procedure CREW Recognize RCS pressure is lowering -

Diagnose PORV leakage due to computer point T773, RC CREW PRZR PWR RLF OUT TEMP, RC12-1 rising Implement DB-OP-02513, Pressurizer Systems Abnormal SRO Operating Procedure SRO Direct closure of RC11, PORV Block valve

CRITICAL Close PORV Block TASK ATC

Close RC11 using HISRC11, PORV BLOCK CREW Determine RCS leakage has stopped Refer to Tech Spec 3.4.11 Pressurizer Pilot Operated Relief Valve (PORV)

SRO

Declare PORV INOPERABLE

Enter 3.4.11 Condition A

Remove power from PORV Block valve Direct open breaker BE1602 for Pressurizer Pilot Operated SRO Relief Valve (PORV) Block Valve NUREG-1021, R9 Supp. 1 Page 4 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 2 Page 5 of Event

Description:

PORV Leakage Time Position Applicants Actions or Behavior Event 2: PORV Leakage - continued Booth Role play opening BE1602 for PORV Block Valve Cue SRO Refer to Tech Specs 3.4.13, RCS Operational Leakage SRO Refer to TRM 8.4.4, Reactor Coolant System Vents DNBR Tech Spec 3.4.1 may be entered and exited during Note this scenario On Lead Evaluators discretion, proceed to Event 3 NUREG-1021, R9 Supp. 1 Page 5 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 3 Page 6 of Event

Description:

Selected Thot RTD transmitter (TT RC3A1) slowly fails high Time Position Applicants Actions or Behavior Event 3: Selected Thot RTD transmitter (TT RC3A1) slowly fails high Indications Available:

4-2-B, HOT LEG TEMP HIGH 14-2-F ICS ULD TRBL 14-4-D, ICS FW LIMITED BY RX POWER 14-4-E, ICS INPUT MISMATCH 14-6-D, ICS IN TRACK 4-2-E, PZR LVL LO CREW Recognize ICS is reducing Rx power to lower Tave to 582°F Implement DB-OP-02526, Primary to Secondary Heat Transfer SRO Upset ATC Place Rod Control Panel in Manual and adjust power

Place BOTH FEEDWATER DEMAND H/A Stations in BOP HAND

Maintain Feedwater flow matched with Plant power Check DEHC Load Control Center is in Automatic AND BOP controlling Turbine Header Pressure 830 - 930 psig ATC Check RCS pressure between 2105 and 2205 psig

Place SG/RX Demand in Hand ATC

Place Reactor Demand in Hand BOP

Place SG Load Ratio (Tc) in Hand DNBR Tech Spec 3.4.1 may be entered and exited during Note this scenario NUREG-1021, R9 Supp. 1 Page 6 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 3 Page 7 of Event

Description:

Selected Thot RTD transmitter (TT RC3A1) slowly fails high Time Position Applicants Actions or Behavior Event 3: Selected Thot RTD transmitter (TT RC3A1) slowly fails high - continued Assign manual control responsibilities and control bands:

Insert or withdraw Control Rods to maintain Reactor Power within 1% of current power level

Adjust FW Flow to maintain RCS Tave within 2°F of current SRO temperature

Adjust FW Flow to maintain RCS cold leg differential temperature within 2 degrees of zero

Maintain Turbine Header Pressure within 10 psig of current pressure Refer to DB-OP-06407, Non-Nuclear Instrumentation System SRO Operating Procedure for transferring NNI Instrument Inputs to ICS Hand/Auto Stations Compare Hot Leg Temperature Indicators TI RC3A1 and T1 RC3B1 on RC Panel C5718 ATC

Select the good instrument TTRC3A3

Reset ICS Mismatch alarm14-4-E in cabinet area per DB-OP-02014, Panel 14 Annunciator alarms Return Tave to 582 °F ATC/BOP

Adjust FW Loop Demands

Adjust Rod positions SRO Implement DB-OP-02526 Att. 1, Return ICS Stations to AUTO

1. Place Rod Control Panel in AUTO ATC

2. Place Reactor Demand Station in AUTO BOP Place BOTH FEEDWATER DEMAND H/A Stations in AUTO ATC Place SG/RX Demand in AUTO On Lead Evaluators discretion, proceed to Event 4 NUREG-1021, R9 Supp. 1 Page 7 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 4 Page 8 of Event

Description:

MFPT Low Oil pressure - trip MFPT Time Position Applicants Actions or Behavior Event 4: MFPT Low Oil pressure - trip MFPT Indications Available:

10-3-D, MFPT 2 LUBE OIL TK LVL Implement DB-OP-02010, Feedwater Alarm Panel 10 BOP Annunciators BOP Dispatch Equipment Operator to investigate MFPT 2 Booth Role play as Local Operator: MFP 2 bearing oil header is Cue spraying oil and MFP is making a squealing noise.

Direct trip MFPT 2 immediately OR SRO

Direct power reduction to 55% to remove MFPT 2 from service

Refer to DB-OP-02504, Rapid Shutdown If directed to reduce power per Attachment 1, DB-OP-02504:

At the LOAD CONTROL panel, set the rate of change ATC specified by the SRO

Select the target RTP determined by the SRO BOP As directed by the SRO Trip MFPT 2 using HS798 Turbine Trip IF an ICS Runback occurs, THEN REFER TO DB-OP-06401, SRO Integrated Control System Operating Procedure If desired Scenario can continue while MFPT coasts down BOP

Lockout MFP 2 oil pumps SM If asked, refer to RA-EP-02850 for Hazardous Waste Spill On Lead Evaluators discretion, proceed to Event 5 NUREG-1021, R9 Supp. 1 Page 8 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 5 Page 9 of Event

Description:

Dropped Control Rod Time Position Applicants Actions or Behavior Event 5: Dropped Control Rod Indications Available:

Annunciator 5-1-E, CRD LCO Annunciator 5-2-E, CRD ASYMETRIC ROD Control Rod 5-8 Rod Bottom light ON CREW Recognize that a single Control Rod has inserted into the core SRO Implement DB-OP-02516, CRD Malfunctions SRO Direct Power reduction to 33% at 3% RTP per minute

Set ULD MAX LOAD LIMIT to 33% RTP ATC

Set ULD Rate of Change to 3% RTP per minute SRO Refer to DB-OP-02504, Rapid Shutdown If annunciator 4-2-E, PZR LEVEL LO alarms due to the ATC dropped rod Tave transient then reduce MU32 (PZR level control) set point to approximately 180 inches Monitor Reactor Power to confirm power is being reduced at CREW approximately the expected rate IF Pressurizer Level is greater than 228 inches, then refer to SRO Technical Specification 3.4.9 Condition A Monitor Regulating Rod Insertion Limits during the Shutdown ATC per Technical Specification 3.2.1 Perform Attachment 6, Balance of Plant Actions for Rapid Shutdown BOP

Stop LPFW Drain Pumps

Establish one Condensate Pump in operation

Place S/G Load Ratio H/A in Hand NUREG-1021, R9 Supp. 1 Page 9 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 5 Page 10 of Event

Description:

Dropped Control Rod Time Position Applicants Actions or Behavior Event 5: Dropped Control Rod - continued Notify Equipment Operators to commence Attachment 15, Field BOP Actions for Rapid Shutdown SRO Notify the Shift Manager to make notifications SRO Notify Reactor Engineering SRO Request I&C to investigate Refer to DB-OP-02516 Attachment 3 to determine Tech Spec applicability:

SRO

Tech Spec. 3.1.4 for the dropped rod, Condition A, verify SDM is within limits within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months On Lead Evaluators discretion, proceed to Event 6 NUREG-1021, R9 Supp. 1 Page 10 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 6 Page 11 of Event

Description:

Steam Generator Tube Rupture Time Position Applicants Actions or Behavior Event 6: Steam Generator Tube Rupture Indications Available:

12-1-B MN STM LINE 2 RAD HI 9-4-A VAC SYS DISCH RAD HI High activity on condenser off-gas radiation monitors High activity on either main steam line radiation monitor Increasing Makeup flow CREW Recognize indications of a tube leak SRO Implement DB-OP-02531, Steam Generator Tube Leak Calculate the leak rate using Attachment 1, Steam Generator ATC Tube Leak Rate Calculation (~300 gpm)

Route to DB-OP-02000, SFAS, RPS, SFRCS Trip or SG Tube SRO Rupture, Section 8 Monitor Pressurizer level ATC

Anytime Pressurizer level is <100 inches - trip Reactor Notify the Shift Manager to refer to RA-EP-01500, Emergency SRO Classification Implement Attachment 8, Place MU/HPI/LPI in Service

Start/Verify running both CCW Pumps

*Start/Verify running both HPI Pumps

Critical * *Verify open HP 2A, HP 2B, HP 2C and HP 2D BOP Task

Start both LPI Pumps

Open DH 64 and DH 63

Transfer MU Pump suctions to the BWST

Standby Makeup pump does not start ATC If Pressurizer <200 inches isolate Letdown - Close MU2B NUREG-1021, R9 Supp. 1 Page 11 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 6 Page 12 of Event

Description:

Steam Generator Tube Rupture Time Position Applicants Actions or Behavior Event 6: Steam Generator Tube Rupture - continued Place SG/RX in Hand and reduce power to place both SGs on ATC low level limits (~ 24% Power)

If called to investigate Makeup pump 1 failure to start Booth report overcurrent relay breaker AC105 overcurrent relay Cue actuated SRO Direct Chemistry to perform Attachment 2 SRO Direct Radiation Protection to perform Attachment 3 Direct an Equipment Operator/Field Supervisor to perform SRO Attachment 4 Trip the reactor prior to Pressurizer level going below 100 ATC inches or when less than 50 MWE When both SGs on low level limits BOP

Place Turbine Bypass valves in Hand

Reduce Generator load to less than 50 MWe ATC Trip Reactor BOP Place Turbine Bypass Valves in Auto Perform DB-OP-02000 Immediate Actions

Manually trip the reactor ATC

Verify power decreasing in the intermediate range

Manually trip the turbine NUREG-1021, R9 Supp. 1 Page 12 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 7&8 Page 13 of Event

Description:

Loss of all Feedwater and Pressurizer Spray Valve fails closed Time Position Applicants Actions or Behavior Event 7: Loss of Main Feedwater - SFRCS fails to actuate Event 8: Pressurizer Spray valve fails to open for pressure reduction CREW Implement Specific Rules

Critical Recognize Main Feedwater is lost and SFRCS is not actuated BOP Task

Manually Initiate and Isolate SFRCS CREW Check for Symptoms SRO Route to section 8 for SG Tube Rupture BOP Verify Attachment 8 is complete If Pressurizer Level is less than 40 inches:

Lock MU Pump suctions on the BWST ATC

Isolate Letdown

Verify Pressurizer heaters are off ATC Verify Pressurizer level controller set at 100 inches Verify DB-OP-02531 Attachments are in progress

Direct Chemistry to perform Attachment 2 SRO

Direct Radiation Protection to perform Attachment 3

Direct an Equipment Operator/Field Supervisor to perform Attachment 4 ATC Turn off all Pressurizer heaters When directed use Pressurizer Spray to reduce RCS pressure ATC

- Recognize the Spray valve would not open Route to step in Section 8.0 for using the Pressurizer Vent for SRO RCS pressure reduction Event 8: Pressurizer Spray valve fails to open for pressure reduction NUREG-1021, R9 Supp. 1 Page 13 of 16 FENOC Facsimile Rev. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 2015 Scenario # 3 Event # 7&8 Page 14 of Event

Description:

Loss of all Feedwater and Pressurizer Spray Valve fails closed Time Position Applicants Actions or Behavior ATC Start the Quench Tank Circ Pump ATC Block SFAS low RCS pressure trips when Block Permits light Reduce RCS pressure :

Pressurizer Vent Line Method

Critical * *Open RC 200 ATC Task

*Open RC 239A

Cycle RC 239A and Pressurizer Heaters to control RCS Pressure

Critical Throttle High Pressure Injection ATC Task

Control Pressurizer level by controlling MU and HPI When pressure reduction has begun the Scenario can be terminated NUREG-1021, R9 Supp. 1 Page 14 of 16 FENOC Facsimile Rev. 1

Justification for Critical Tasks A. Establish FW flow and feed SGs (CT-10)

When the Reactor is tripped the remaining Main Feedwater Pump will trip resulting in a loss of Main Feedwater. SFRCS will fail to automatically isolate and actuate Auxiliary Feedwater on Main Feedwater reverse differential pressure as required resulting in a loss of all feedwater. Manual actuation of the SFRCS pushbuttons will be required to restore secondary heat removal B. Control High Pressure Injection (CT-5)

A Steam Generator Tube Rupture will require High Pressure Injection to be placed in service and throttled to prevent violating the RPV P-T Limit by maintaining RCS inventory and minimum subcooling margin C. Close RC11, PORV Block Valve (Post Event Emergent Critical Task)

PORV (RC2A) leakage will require the closure of RC11 PORV Block Valve to prevent an uncontrolled depressurization of the Reactor Coolant System, over-pressurization of the Pressurizer Quench Tank, and subsequent radioactive release to the Containment.

NUREG-1021, R9 Supp. 1 Page 15 of 16 FENOC Facsimile Rev. 1

SIMULATOR SETUP INFORMATION

1. Simulator Setup a) 70% Power b) RCP 1-1 Out of Service c) Emergency Diesel Generator 1 Out of Service d) SFRCS Failure to auto trip on loss of Main Feedwater e) Makeup Pump 1 fails to start f) PZR Spray valve failed closed on Rx trip

2. Procedures a) DB-SS-04052, MFPT 1 Stop Valves Periodic Test b) DB-OP-02004, Reactor Coolant Alarm Panel 4 Annunciators Procedure c) DB-OP-02513, Pressurizer Systems Abnormal Operation Procedure d) DB-OP-02526, Primary to Secondary Heat Transfer Upset e) DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure f) DB-OP-02010, Feedwater Alarm Panel 10 Annunciators g) DB-OP-02504, Rapid Shutdown h) OP-06401, Integrated Control System Operating Procedure i) DB-OP-02516, CRD Malfunctions j) DB-OP-02531, Steam Generator Tube Leak k) DB-OP-02000, RPS, SFAS, SFRCS Trip, or Steam Generator Tube Rupture

2) For Simulator Instructor:

a) None NUREG-1021, R9 Supp. 1 Page 16 of 16 FENOC Facsimile Rev. 1

Appendix D Scenario Outline Form ES-D-1 Facility: Davis-Besse Scenario No.: 3 Op Test No.: NRC 2015 Examiners: Operators: SRO ATC BOP Initial Conditions:

70% Power

RCP 1-1 OOS

EDG 1 OOS Turnover: Maintain 70% Power Planned: Perform MFPT 1 Stop Valve Test, DB-SS-04052 Critical tasks: 1. Establish FW flow and feed SGs (CT-10)

2. Control HPI (CT-5)

3. Close RC11 PORV Block Valve (Emergent)

Event Malf. Event Type* Event No. No. Description 1 N-BOP/SRO MFPT 1 Stop Valve Test, DB-SS-04052 2 C-ATC/SRO PORV Leakage (TS)

I-ATC/BOP 3 RCS Hot Leg RTD slowly drifts HI SEE NOTE BELOW SRO 4 C-BOP MFPT Low Oil pressure - trip MFPT SEE NOTE BELOW R-ATC 5 Dropped Rod - Power reduction SEE NOTE BELOW SRO (TS) 6 Major SG Tube Rupture - trip Reactor 7 C-BOP/SRO Loss of Feedwater -SFRCS fails auto actuation 8 C-ATC/SRO PZR Spray valve fails closed NOTE - Events 3, 4, and 5 were not completed due to premature trip of the reactor caused by applicants failure to isolate the leaking PORV (Event 2)

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NUREG-1021, R9 Supp. 1 Page 1 of 16 FENOC Facsimile AG