ML22186A135

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2018 DB Ile Proposed Simulator Scenarios
ML22186A135
Person / Time
Site: Davis Besse Cleveland Electric icon.png
Issue date: 12/29/2017
From: Randy Baker
NRC/RGN-III/DRS/OLB
To:
FirstEnergy Nuclear Operating Co
Baker R
Shared Package
ML17068A444 List:
References
Download: ML22186A135 (44)
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Text

Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 11 Page 1 of 13 FENOC Facsimile Rev. 1 Facility:

Davis-Besse Scenario No.:

1 Op Test No.:

DB NRC 2018 Examiners:

Operators:

SRO ATC BOP Initial Conditions:

5% power / Mode 1 Rod Control Panel in Auto MFPT 2 in service MDFP is Unavailable while being aligned for AFW mode Turnover:

  • Reactor startup is in progress and currently at 5% (Mode 1 entered).
  • Continue a plant startup per DB-OP-06901, starting at Step 3.43.
  • Completed testing of both AFPTs for operability.

Planned:

  • Continue Reactor startup.
  • Complete line-ups for placing MDFP in AFW mode (currently in progress).
  • Complete venting of FW779 and FW780.

Critical tasks: 1. Trip All Reactor Coolant Pumps (CT1)

2. Initiate HPI Flow Balancing (CT2)

Event No.

Malf.

No.

Event Type*

Event Description 1

R-ATC/SRO Continue Reactor startup from 5% to 10%. Stabilize at 10%

to perform NIP to HBP comparison 2

N-BOP/SRO Place Main Feed Reg Valves in service (Open Block Valves) 3 C-BOP/SRO Rising Cond pressure - Vacuum Pump auto start fail 4

SRO (TS)

Inverter YV1 DC input failure (TS) 5 C-ATC/SRO Makeup Filter High diff press 6

I-BOP/SRO (TS)

SFAS CTMT Press transmitter fails low (TS) 7 C-ATC/SRO RCS Leak - trip Reactor at 100 inches 8

M-ALL LOCA 9

C-ATC/SRO HPI Pump trip requiring flow balancing (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Scenario Event Summary NUREG-1021, Revision 11 Page 2 of 13 FENOC Facsimile Rev. 1 DAVIS-BESSE 2018 NRC SCENARIO 1 The Crew will be allowed the opportunity to review the in progress DB-OP-06901, Plant Startup, procedure prior to entering Simulator and assuming control.

The Crew will take the watch with power stabilized at approximately 5% (Mode 1 entered). A reactor startup is in progress following a shutdown for bushing replacement on the Main Transformer. The MDFP is unavailable while in the process of being transferred to the Auxiliary Feedwater mode. Direction will be to increase power to 10%, stabilize for NIP to Heat Balance comparison and continue to 14% power (event 1).

An Equipment Operator will report the steps complete for venting the bonnets of the MFW Block Valves. The BOP RO will open the MFW Block Valves placing the Main Feedwater Control Valves in service (event 2).

When the Main Feedwater Control Valves are in service the Lead Evaluator will cue rising condenser pressure. The crew will identify rising pressure from trend recorder data or from receipt of annunciator alarms 15-1-F and/or 15-2-F, Hi/Lo Pressure Condenser Pressure Hi.

The Unit Supervisor will enter abnormal procedure DB-OP-02518, High Condenser Pressure.

The Mechanical Hogger will fail to auto start and the BOP will manually start the Mechanical Hogger. Condenser pressure will stabilize at less than 5.0 inches HgA and reactor power reduction to maintain less than or equal to 5.0 HgA will not be required (event 3).

At the Lead Evaluators cue, INV YV1-YV3 TRBL Annunciator alarm will be received and an Equipment Operator will report breaker D1P03 found in the tripped position. Inverter YV1 will be declared Inoperable. Tech Spec 3.8.7, Condition A, for Inverters-Operating will be entered (event 4).

At the Lead Evaluators cue annunciator 2-4-A, Letdown or MU Filter Differential Pressure Hi, will alarm due to high differential pressure across the #1 Makeup Filter (PDI MU13 greater than 25 psid). The crew will implement alarm procedure actions, validate #1 Makeup Filter differential pressure is high, and swap to #2 Makeup Filter using DB-OP-06006, Makeup and Purification System (event 5).

At the Lead Evaluators cue SFAS Channel 4 Containment Pressure Transmitter will fail low.

Annunciator 5-4-B, SFAS CTMT PRESS LO FAIL will alarm. The SRO will enter Tech Spec 3.3.5 Condition A and the BOP will trip the required Bistables in SFAS Channel 4 (event 6).

On Lead Evaluators cue an RCS leak will develop in Containment resulting in Pressurizer level dropping below 100 inches and requiring the ATC to trip the reactor per DB-OP-02522, Small RCS Leaks, immediate action (event 7).

When the reactor is tripped the RCS leak will increase resulting in a loss of Adequate Subcooling Margin which will require tripping of all 4 Reactor Coolant Pumps (CT-1) (event 8).

High Pressure Injection Pump 2 will trip requiring HPI Flow Balancing to be performed (CT-2)

(event 9).

When HPI Flow Balancing has been performed the scenario can be terminated.

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

1 Event #

1, 2 Page 3

of 13 Event

Description:

Power Increase / Place MFW Reg Valves In Service Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 3 of 13 FENOC Facsimile Rev. 1 Indications Available:

  • Power Range Nis
  • Core differential temperature SRO Direct increase reactor power to 10% and stabilize per DB-OP-06901, starting at Step 3.43 Perform NI Power and Heat Balance Power comparison ATC Increase reactor power to 10% at 35°F/hr Increase power using Reactor Demand Station Perform NI Power and Heat Balance Power comparison Booth Cue When directed by Lead Evaluator, role-play EO and report:

Steps 3.44.1.a and b of DB-OP-06901 are complete. FW 779 and FW 780 bonnets have been vented and are ready to be opened per steps 3.44.2 through 3.44.7 BOP Open MFW Block Valves, FW779 and FW 780 Open SP 6B to 5%, Close SP 6B Open FW 780 (Takes ~ 2 minutes to stroke)

Open SP 6A to 5%, Close SP 6A Open FW 779 (Takes ~ 2 minutes to stroke)

SRO Note: It is not necessary to wait for full power increase prior to proceeding to next event Direct increase reactor power to 14% and stabilize per DB-OP-06901, starting at Step 3.43 Perform NI Power and Heat Balance Power comparison On Lead Evaluators discretion insert Event 3, rising condenser pressure

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

1 Event #

3 Page 4

of 13 Event

Description:

Rising Condenser Pressure - Mechanical Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 4 of 13 FENOC Facsimile Rev. 1 Indications Available:

  • HP PR 530 rising (trend recorder)
  • LP-PR 541 rising (trend recorder)

Crew NOTE: May recognize prior to alarms Recognize indications of slowly increasing condenser pressure SRO Implement DB-OP-02518, High Condenser Pressure BOP Verify the Mechanical Hogger Starts at 4.5 inches HgA LP Condenser (Auto start is failed)

  • Position switch HIS1005 to START (Condenser pressure will stop increasing and slowly improve)

BOP Verify proper Circ Water Pump operation BOP Verify Condenser Vacuum Breakers are Closed (HIS634)

BOP Check proper operation of Gland Sealing Steam system SRO Request assistance to determine the cause (Attachment 1)

SRO Notify the Shift Manager to refer to Notification requirements On Lead Evaluators discretion, proceed to Event 4, Inverter YV1 DC input failure

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

1 Event #

4 Page 5

of 13 Event

Description:

Inverter YV1 DC input failure Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 5 of 13 FENOC Facsimile Rev. 1 Indications Available 1-6-A INV YV1-YV3 TRBL D1P03 Red Light is Off CREW Respond to DB-OP-02001, Electrical Distribution Alarm Panel 1 Annunciators, alarm 1-6-A CREW Recognize Inverter YV1 DC input failure D1P03 red light is off SRO Refer to DB-OP-06319, Instrument AC System Procedure, Sect. 5.1, Response to INV YV1 TRBL Alarms Booth Cue Role Play as Equipment Operator and report: Breaker D1P03 for Inverter YV1 is tripped. Inverter YV1 indications are normal SRO Declare Inverter YV1 Inoperable. Enter TS 3.8.7 Inverters Operating, Condition A SRO Contact Electrical Maintenance to investigate When Tech Spec has been declared proceed to Event 5, Makeup Filter high differential pressure

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

1 Event #

5 Page 6

of 13 Event

Description:

Makeup Filter high differential pressure Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 6 of 13 FENOC Facsimile Rev. 1 Indications Available:

PDI MU13 indicates >25 PSID 2-4-A LETDOWN OR MU FILT P HI CREW Recognize Makeup Filter high differential pressure for in service Makeup Filter 1 (indications available listed above)

ATC Implement DP-OP-02002 Letdown/Makeup Alarm Panel 2 Annunciators for 2-4-A LETDOWN OR MU FILT P HI ATC Validate Makeup Filter high differential pressure with PDI MU13 indicating >25 psid SRO Direct placing Makeup Filter 2 in service in accordance with DB-OP-06006, Makeup and Purification System SRO/ATC Verify Makeup Filter 2 is not aligned as the Purification Demin Filter SM CUE If necessary, Role-play Shift Manager and inform the SRO that Makeup Filter 2 has been verified to not be aligned as the Purification Demin Filter ATC Swap to Makeup Filter 2 ATC Open MU12B, MAKEUP FILTER 2 INLET ISOLATION, using HISMU12B.

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

CREW Ensure work request initiated to have filter replaced (alarm procedure guidance)

On Lead Evaluators discretion proceed to Event 6, SFAS CTMT Press transmitter fails low

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

1 Event #

6 Page 7

of 13 Event

Description:

SFAS CTMT Press transmitter fails low Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 7 of 13 FENOC Facsimile Rev. 1 Indications Available:

5-4-B, SFAS CTMT PRESS LO FAIL CREW Refer to DB-OP-02005, Primary Instrumentation Alarm Panel SRO Determine SFAS 4 Channel CTMT Pressure is INOPERABLE.

PI M403 is failed low and BA 408 is tripped (Red light lit) in SFAS Channel 4 cabinet.

SRO REFER TO Technical Specifications 3.3.5 and Table 3.3.5-1 Parameters 3 and 4 and take action as required. Enters Condition A, one (1) hour to trip channel.

SRO Direct action IAW DB-OP-06405, SFAS, Section 4.1 for tripping the Inoperable SFAS Instrument String Trip Bistable.

SRO Direct circling SFAS Channel 4 indicating the Inoperable SFAS Instrument String Trip Bistable selected.

SRO Determines bistable(s), BA409 and BA410, are required to be tripped to achieve the desired results BOP Perform actions for an Inoperable SFAS Instrument String Trip Bistable BOP Obtains the door key for the designated SFAS cabinet.

(Key 28)

BOP Depress the TEST pushbutton on the trip bistable(s) listed in Step 4.1.3 (BA409 and BA410) AND verify the TRIP light is ON.

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

1 Event #

6 Page 8

of 13 Event

Description:

SFAS CTMT Press transmitter fails low Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 8 of 13 FENOC Facsimile Rev. 1 SFAS CTMT PRESS LO FAIL (cont.)

BOP Verify the associated 1/5 lights on the output modules for all four SFAS Channels are ON.

BOP Verify the SFAS cabinet door is closed and locked.

BOP Return the SFAS door key.

Proceed to Event 7, 8 and 9 - RCS leak, LOCA and HPI Flow Balancing

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

1 Event #

7, 8 & 9 Page 9

of 13 Event

Description:

RCS Leak, LOCA and HPI Flow Balancing Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 9 of 13 FENOC Facsimile Rev. 1 Indications Available:

Increasing Makeup flow Lowering Pressurizer level Lowering Makeup Tank level CREW Recognize RCS leak ATC Trip Reactor per immediate actions of DB-OP-02522, Small RCS Leaks (Pressurizer level < 100 inches)

ATC Perform DB-OP-02000 Immediate Actions

  • Manually trip the reactor
  • Verify power decreasing in the intermediate range
  • Manually trip the turbine SRO Route to DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture CREW Recognize SCM is < 20 °F
  • Critical Task ATC Implement Specific Rule 2, LSCM
  • Trip RCPs when SCM is lost Select Incores on the PAM Panel BOP Implement Specific Rule 4, Steam Generator Control Verify both SG levels are increasing to 124 inches ATC Implement Specific Rule 6, C1/D1/EDGs Verify both EDGs are running Verify C1 and D1 are energized Verify both CCW Pumps are running Verify both Service Water Pumps are running

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

1 Event #

7, 8 & 9 Page 10 of 13 Event

Description:

RCS Leak, LOCA and HPI Flow Balancing Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 10 of 13 FENOC Facsimile Rev. 1 Event 7 & 8, LOCA and HPI Flow Balancing continued CREW Check for Symptom direction

  • Recognize loss of subcooling margin SRO Implement DB-OP-02000, Section 5 ATC Verify RCPs are tripped ATC Implement Attachment 8, Place MU/HPI/LPI in Service
  • Start/Verify running both CCW Pumps
  • Recognize only HPI Pump 1 is running
  • Refer to attachment 11 for HPI flow balancing
  • Critical Task ATC
  • Implement Attachment 11, HPI Flow Balancing Close MU 6421 Verify HP 2C and HP 2D are open Determine FYI HP3C has a lower flow than FYI HP3D Throttle HP 2D until FYI HP3C is acceptable per Figure 3 Open MU 6421
  • Monitor RCS Pressure
  • Start both LPI Pumps
  • Open DH 64 and DH 63
  • Transfer MU Pump suctions to the BWST
  • Set Pressurizer Level Controller to 100 inches
  • Start/Verify running the second MU Pump
  • Lock MU Pump suctions on the BWST
  • Isolate Letdown
  • Verify Pressurizer heaters are off
  • Open MU 6421
  • Open MU 6419 Direct an Equipment Operator to open MU6423B ATC Control MU\\HPI\\LPI per specific Rule 3 and Attachment 13

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

1 Event #

7, 8 & 9 Page 11 of 13 Event

Description:

RCS Leak, LOCA and HPI Flow Balancing Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 11 of 13 FENOC Facsimile Rev. 1 Event 7 & 8, LOCA and HPI Flow Balancing continued ATC Verify proper SFAS actuation

  • Recognize HPI Pump 2 has tripped BOP Verify proper SFRCS actuation BOP Verify proper SG level control BOP Realign AFW if an SFRC low pressure trip occurs ATC Check for LPI flow into the RCS When HPI flow balancing has been performed the scenario can be terminated

NUREG-1021, Revision 11 Page 12 of 13 FENOC Facsimile Rev. 1 Justification for Critical Tasks A. Trip all Reactor Coolant Pumps. (CT-1)

When Subcooling Margin is lost all Reactor Coolant Pumps are required to be stopped immediately. Continued RCP operation during certain small break LOCA accidents could lead to fuel clad failure.

B. Initiate High Pressure Injection (CT-2)

Following the Reactor trip High Pressure Injection Pump 1, Line 1-2 will develop an unisolable leak and HPI Pump 2 will trip after starting on Safety Features Actuation System Level 2. This will require High Pressure Injection Train 1 flows to be balanced to minimize flow out of the broken line.

NUREG-1021, Revision 11 Page 13 of 13 FENOC Facsimile Rev. 1 SIMULATOR SETUP INFORMATION

1.

Simulator Setup a) 5% Power b)

DB-OP-06901, complete up to Step 3.43 c)

Makeup filter 1 in service with elevated differential pressure d)

Unisolable leak on HPI Line 1-2 increases on Reactor trip e)

High Pressure Injection Pump 2 trips upon SFAS Level 2 actuation f)

SPDS HUS Curve on front monitor g)

Magnetic tag OPEN on ABS34620 h)

Emergency Feedwater Pump OOS

2.

Procedures a)

DB-OP-06901, Plant Startup b)

DB-OP-02518, High Condenser Pressure c)

DB-OP-06251, Station and Instrument Air d)

DB-OP-02001, Electrical Distribution Alarm Panel e)

DB-OP-06319, Instrument AC System Procedure f)

DP-OP-02002, Letdown/Makeup Alarm Panel g)

DB-OP-06006, Makeup and Purification System h)

DB-OP-02005, Primary Instrumentation Alarm Panel i)

DB-OP-06405, Safety Features Actuation System j)

DB-OP-02522, Small RCS Leaks k)

DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture

2)

For Simulator Instructor:

a)

None b)

Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 11 Page 1 of 16 FENOC Facsimile Rev. 1 Facility:

Davis-Besse Scenario No.:

2 Op Test No.:

DB NRC 2018 Examiners:

Operators:

SRO ATC BOP Initial Conditions:

100% Power Turnover: Maintain 100% Power Routine activities Planned: Add 50 gallons of water to the Makeup Tank (MUT) to verify proper operation of batch controller (FIN request)

Critical tasks: 1. Shutdown the Reactor - ATWS (CT-24)

2. Initiate MU/HPI PORV Cooling (CT-14)

Event No.

Malf.

No.

Event Type*

Event Description 1

N-ATC/SRO Add 50 gal of water to the RCS Makeup tank 2

C-BOP/SRO (TS) NI Power Range NI5 fails low 3

I-ATC/SRO Selected PZR Level Transmitter fails Low 4

C-BOP/SRO (TS) Isolable steam Leak - loss AFP 5

C-BOP/SRO Main Feed Turbine Pump 1 High Vibrations 6

R-ATC/SRO MFP Runback fails - reduce power 7

Major Loss of all Feedwater - ATWS (Momentarily de-energize 480 Volt Unit Substations E2 and F2) 8 C-ATC/SRO STBY MUP trips - establish MU/HPI PORV Cooling (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Scenario Event Summary NUREG-1021, Revision 11 Page 2 of 16 FENOC Facsimile Rev. 1 DAVIS-BESSE 2018 NRC SCENARIO 2 The crew will take the watch with power at 100%. The ATC will add 50 gallons of water to the Makeup Tank (MUT) to verify proper operation of batch controller (event 1).

The Lead Evaluator will cue Power Range NI 5 to fail low which will cause RPS Ch 2 to trip on

//flow. The SRO will enter DB-OP-02505, NI Failures, and enter Technical Specification 3.3.1 Condition A, and will direct the BOP to place RPS Channel 2 in Manual Bypass (event 2).

The Lead Evaluator will cue the selected PZR Level instrument failure which will fail low over two minutes. Annunciator 4-2-E, 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 (event 3).

The Lead Evaluator will cue an isolable steam leak which will result in the loss of #2 AFP. The crew will respond to annunciator 12-2-A, SG 1 to AFP 2 Mn Stm Press Lo, and implement abnormal procedure DB-OP-02525, Steam Leaks. The steam leak will be determined to be in AFPT Room 2, and attachment 1 of DB-OP-02525 will be used to isolate the steam leak. The Unit Supervisor will review applicable Technical Specifications and enter 3.7.5 Condition A and B for Inoperable Steam Supply (event 4).

The Lead Evaluator will then cue Main Feedwater Pump Turbine (MFPT) 1 High Vibrations. The SRO will direct the BOP to trip MFPT #1 as directed by DB-OP-02010 Feedwater Alarm Panel 10 (event 5).

When MFPT 1 is tripped the auto runback will fail requiring the ATC to place HIC ICS13, SG/RX DEMAND, in HAND and perform the runback at 20% / minute to 55% power per DB-OP-06401, Integrated Control System Operating Procedure (event 6).

The Lead Evaluator will then cue the loss of all feedwater event. Main Feedwater Pump 2 will trip. AFW Pump 1 will start and the Motor Driven Feedwater pump will fail to start. The CREW will determine an ATWS has occurred. The ATC will be required to momentarily de-energize 480 Volt Unit Substations E2 and F2 to de-energize the CRDMs and shut down the reactor (CT-24) (event 7).

The Crew will stabilize the plant and route through DB-OP-02000 supplemental section.

After 10 minutes the remaining AFW Pump will trip resulting in a loss of all feedwater.

The ATC will start the standby Makeup Pump per specific rule 4.

The SRO will enter Section 6, Lack of Heat Transfer and direct the ATC to prepare for MU/HPI Cooling. One minute after the standby Makeup Pump is started Annunciator Alarm 2-1-B, MU PMP 1 LUBE OIL PRESS LO, will sound and the standby Makeup Pump will trip. The CREW will determine Specific Rule 4 applies and the SRO will direct immediate initiation of MU/HPI PORV Cooling (CT-14) (event 8).

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

1 Page 3

of 15 Event

Description:

Add water to the RCS Makeup Tank Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 3 of 16 FENOC Facsimile Rev. 1 Indications Available:

Batch Controller Makeup Tank level SRO Direct addition of 50 gallons from the Clean Waste Monitor tank to the RCS Makeup tank, IAW DB-OP-06001, Boron Concentration Control ATC Determine MU39, Batch Flow Control Valve, position.

Depress and release:

DISPLAY (lower)

VALVE CE Valve % should indicate 0 Verify MU23 closed using HC MU23 Verify WC 3526 closed using HIS 3526 Estimate the time for batch completion (~ 4 minutes)

ATC Program Batch Controller using following keystroke sequence:

BATCH SET

  1. keys equating to 50 ENTER Exit BATCH SET mode by depressing DISPLAY Display batch size by depressing BATCH Repeat a through e if not correct Verify desired batch size indicated ATC Reset indicated total on the Batch Controller:

DISPLAY (lower)

TOTAL TOTAL RESET Display FLOW RATE DISPLAY (upper) ZERO RATE

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

1 Page 4

of 15 Event

Description:

Add water to the RCS Makeup Tank Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 4 of 16 FENOC Facsimile Rev. 1 Add water to the RCS Makeup tank (contd)

ATC Enable Batch Controller by pressing RUN ATC Open MU 40 using HIS MU40 ATC Open WC 3526 using HIS 3526 ATC When Batch is complete:

Verify MU 40 closed Close WC 3526 Notify Unit Supervisor batch operations complete On Lead Evaluators discretion proceed to Event 2, Power Range NI5 fail low

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

2 Page 5

of 15 Event

Description:

Power Range NI5 fail low Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 5 of 16 FENOC Facsimile Rev. 1 Indications Available:

  • 5-3-I RPS FLUX-FLUX-FLOW TRIP CREW Identify symptoms of an NI failure
  • 5-3-I RPS FLUX-FLUX-FLOW TRIP SRO Route to DB-OP-02505, NI Failures ATC Recognize NI 5 has failed low NI panel indicator NI5 failed low SRO Refer to Tech Specs:

SRO Directs placing RPS 2 in Manual Bypass per DB-OP-06403, Reactor Protective System (RPS) and Nuclear Instrumentation (NI) Operating Procedure BOP Place RPS Channel 2 in bypass

  • Obtain RPS Manual Bypass key and Ch2 door key
  • Rotate the MANUAL-BYPASS KEY SWITCH to actuate the manual bypass relay in RPS Channel 2
  • Check MANUAL-BYPASS light is BRIGHT
  • Check SUB-SYSTEM light is DIM
  • Place the Power Range Test Module in TEST OPERATE At Lead Evaluators discretion procced to Event 3, Pressurizer Level Transmitter Failure

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

3 Page 6

of 15 Event

Description:

PZR Level Transmitter fails low over 2 minutes Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 6 of 16 FENOC Facsimile Rev. 1 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 SRO Implement DB-OP-02513, Pressurizer System Abnormal Operations, for Failure of Selected Pressurizer Level or Temperature Instruments ATC Place MU 32 in HAND and control PZR level ATC Compare Pressurizer level instruments and select a functional alternate level instrument:

LTRC14-1 (L772) X instrument OR LTRC14-3 (L773) Y instrument SRO If NNI-Y instrument selected refer to DB-OP-06407 for non-preferred selector switch alignment ATC Return MU 32 to automatic control SRO IF Pressurizer Level is greater than 228 inches, then refer to Technical Specification 3.4.9 Condition A Booth Cue Role play Work Week Manager/I&C as necessary to investigate pressurizer level transmitter failure Procced to Event 4, Isolable steam leak - Loss of AFP 2

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

4 Page 7

of 15 Event

Description:

Isolable steam leak - Loss of AFP 2 Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 7 of 16 FENOC Facsimile Rev. 1 Indications Available:

12-2-A SG 1 TO AFPT 2 MN STM PRESS LO P012 AFPT 2 STM IN LOW PRESS Fire alarms CREW Recognize a steam leak in AFPT Room 2

  • 12-2-A SG 1 TO AFPT 2 MN STM PRESS LO
  • Fire alarms SRO Implement DB-OP-02525, Steam Leaks ATC Monitor reactor power
  • Lower power as needed to maintain 100%

SRO Direct Shift Manager to refer to RA-EP-01500, Emergency Classification BOP Determine the leak location is in AFPT Room 2 based on annunciator 12-2-A, P012, and/or fire alarms SRO Direct BOP to perform DB-OP-02525, Steam Leaks Attachment 1, Isolation of Main Steam Line 1 to AFPT 2 Leak BOP Attempt to isolate the leak as follows:

  • Close MS 107A
  • Verify MS 107 is closed
  • Verify MS 106 is closed BOP Recognize annunciator 12-2-A is extinguished - Notify the US that the leak is isolated and to GO TO Attachment 8 for continued operation SRO Go to Attachment 8, Evaluation for Continued Operation Isolable steam leak - Loss of AFP 2 continued

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

4 Page 8

of 15 Event

Description:

Isolable steam leak - Loss of AFP 2 Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 8 of 16 FENOC Facsimile Rev. 1 SRO Request Equipment Operator(s) open breakers for MS107 (BF1124) and MS107A (BF1188) per Attachment 9 SRO Direct Maintenance/Engineering to investigate the area for extent of damage SRO Review Technical Specification for AFP 2 inoperable - Declare AFP 2 Inoperable. Enter TS 3.7.5, Condition A & B and direct energize blue TS Operability light SRO Request Radiation Protection survey the area SRO Direct Shift Manager to review for Notification requirements, and review for Classification per RA-EP-01500, Emergency Classification:

On Lead Evaluators discretion, when Tech Spec declared proceed to Event 5 & 6, Main Feed Pump Turbine 1 High Vibrations/Auto Runback Failure

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

5 & 6 Page 9

of 15 Event

Description:

Main Feed Pump Turbine 1 High Vibrations/Auto Runback Failure Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 9 of 16 FENOC Facsimile Rev. 1 Indications Available:

10-3-A MFP 1 OR BFP 1 BEARING VIB HI V650 MFP, MFPT, GEAR OR BFP 1 BRG VIB V657 MFP, MFPT, GEAR OR BFP 1 BRG VIB Excessive vibration reading from ZJR 2538 CREW Recognize high vibrations on MFPT 1 BOP Refer to Annunciator Response DB-OP-02010 BOP Trip MFPT 1 (setpoint is 5 mils)

CREW Recognize automatic runback to 55% is not occurring SRO Implement DB-OP-06401, Integrated Control System Operating Procedure for MFPT Trip runback SRO Direct the ATC to place HIC ICS13, SG/RX DEMAND station in HAND and perform the runback at 20% / minute to 55% power ATC Place HIC ICS13, SG/RX DEMAND station in HAND and perform the runback at 20% / minute to 55% power ATC IF the pressurizer spray valve was operated, THEN verify RC2, PRESSURIZER SPRAY VALVE is in AUTO AND closed ATC/BOP Perform a NIP/HBP comparison for the current power level ATC Return HIC ICS13, SG/RX DEMAND to Auto Proceed to Event 7 & 8, Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

7 & 8 Page 10 of 15 Event

Description:

Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 10 of 16 FENOC Facsimile Rev. 1 Indications Available:

8-4-B MFPT 2 TRIP CREW Recognize loss of Main Feedwater CREW Recognize Reactor trip should have occurred but did not trip

  • Critical Task ATC Perform DB-OP-02000 immediate actions Attempt to manually trip reactor, attempt to use key switch Report failure of manual pushbuttons and key switch to trip reactor
  • De-energize E2 and F2 Re-energize E2 and F2 Verify power decreasing on the Intermediate Range Manually trip the turbine SRO Implement DB-OP-02000 SRO/ATC Verify immediate actions:

Trip the Reactor Verify power decreasing Trip the turbine Verify all Turbine Stop Valves OR Control Valves are closed CREW Check for Specific Rule or Symptom Direction BOP Implement Specific Rule 4 BOP Enable MDFP Discharge Valves HIS 6459 HIS6460

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

7 & 8 Page 11 of 15 Event

Description:

Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 11 of 16 FENOC Facsimile Rev. 1 Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling - continued BOP Close both MDFP discharge valves LIC 6459 LIC 6460 BOP Attempt to start the MDFP - MDFP does not start SRO NOTE: During the performance of supplemental section (10 minutes following reactor trip) a loss of all feedwater will occur Continue with DB-OP-02000 Section 4, Supplemental

1. Check Group 1-7 Rods inserted
2. Direct ATC to perform attachment 1 Primary inventory control
3. Direct BPO to perform Attachment 2 SG inventory and pressure control actions
4. Check for NNI power available (all 4 NNI Power lights lit)
5. Check for ICS Power available (ICS annunciators off/hand auto stations lit)
6. Check for Instrument Air available
7. Check for SFAS not actuated and not required
8. Check for proper SFRCS actuation (isolation trip)
9. Check for adequate SCM
10. Check for proper Primary to Secondary Heat Transfer
11. Verify MSL rad monitors in gross
12. Check SGTR does not exist
13. Direct performing Attachment 26 Electrical actions CREW Note: AFP 1 will trip 10 minutes following reactor trip Recognize AFPT Trip (annunciator alarm)

BOP Use Attachment 5 to attempt to restore a source of feedwater ATC Start the standby Makeup Pump 1 NOTE: The standby Makeup Pump will trip on low oil pressure after 1 minute

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

7 & 8 Page 12 of 15 Event

Description:

Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 12 of 16 FENOC Facsimile Rev. 1 Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling - continued ATC Recognize Makeup Pump 1 has tripped 2-1-B MUP 1 LUBE OIL PRESS LO SRO Go to Attachment 4 for aligning MU/HPI/PORV Cooling

  • Critical Task ATC
  • Trip all but one RCP NOTE: RCP 2-2 left running to maximize spray flow
  • Critical Task ATC Implement Attachment 8, Place MU/HPI/LPI in Service
  • *Start/Verify running both CCW Pumps
  • *Start both HPI Pumps
  • *Start both LPI Pumps
  • *Open DH 64
  • *Open DH 63
  • Transfer MU Pump 1 suction to the BWST-MU6405 - not critical since MUP 1 is not running
  • *Transfer MU Pump 2 Suction to the BWST-MU3971
  • *Set Pressurizer Level Controller to 100 inches
  • Critical Task ATC
  • Place all PZR Heaters in OFF
  • Critical Task ATC Lock MU Pump suctions on the BWST
  • MU 6405 - not critical since MUP 1 is not running
  • *MU 3971
  • Critical Task ATC
  • Close MU6409
  • Critical Task ATC
  • Open MU6420 ATC Verify Open MU6422

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

7 & 8 Page 13 of 15 Event

Description:

Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 13 of 16 FENOC Facsimile Rev. 1 Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling - continued ATC Close MU6407 - not critical since MUP 1 is not running

  • Critical Task ATC
  • Close MU6406 ATC Verify RC11 is open
  • Critical Task ATC
  • Lock open the PORV SRO/ATC Specific Rule 6 check for EDGs running on SFAS initiate:

Check for EDGs running and proper cooling

  • Critical Task ATC Open Loop 1 High Point Vents
  • RC4608B
  • RC4608A
  • Critical Task ATC Open Loop 2 High Point Vents
  • RC4610B
  • RC4610A
  • Critical Task ATC Open PZR High Point Vents
  • RC200
  • RC239A CREW Check for entry into PTS Criteria, REFER to Specific Rule 5 ATC Close either of the following to isolate letdown:

MU2B, LETDOWN ISO MU3, LETDOWN CLRS OUTLET

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

2 Event #

7 & 8 Page 14 of 15 Event

Description:

Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 14 of 16 FENOC Facsimile Rev. 1 Loss of all Feedwater/ATWS/Initiate MU//HPI/PORV Cooling - continued ATC Prevent transfer of CTMT Normal Sump to the Auxiliary Building by performing the following:

Close DR 2012A, CTMT NORMAL SUMP Close DR 2012B, CTMT NORMAL SUMP SRO GO TO Section 12, MU/HPI PORV Cooldown NOTE: If subcooling margin is lost prior to terminating the scenario a new Critical Task will be developed to stop the remaining Reactor Coolant Pump per Specific Rule 2, Actions for loss of Subcooling Margin When MU/HPI/PORV cooling is in progress and at Lead Evaluators discretion the scenario can be terminated

NUREG-1021, Revision 11 Page 15 of 16 FENOC Facsimile Rev. 1 Justification for Critical Tasks A. Shutdown the Reactor - ATWS (CT-24)

When Main Feedwater is lost the Reactor will fail to trip by either automatically, the Reactor trip pushbuttons or the CRDM Key switch. This will require 480V Unit Substations E2 and F2 to be momentarily de-energized to shut down the reactor B. Establish MU/HPI Cooling (CT-14)

MU/HPI cooling is required to be established immediately when only one makeup pump is available during a loss of all feedwater. Establishing MU/HPI cooling will prevent the RCS pressure from exceeding the shut off head of the HPI pump.

NUREG-1021, Revision 11 Page 16 of 16 FENOC Facsimile Rev. 1 SIMULATOR SETUP INFORMATION

1.

Simulator Setup a) 100% Power b)

Loss of MFPT Runback fails c)

ATWS (require de-energize E2/F2) d)

AFPT 1 trips 10 minutes following reactor trip e)

MDFP fails to start f)

STBY MUP trips on low oil pressure 1 minute after start g)

EFW Pump OOS

2.

Procedures a)

DB-OP-06001, Boron Concentration Control b)

DB-OP-02005, Primary Instrumentation Alarm Panel c)

DB-OP-02505, NI Failures d)

DB-OP-06403, Reactor Protective System (RPS) and Nuclear Instrumentation (NI) Operating Procedure e)

DB-OP-02513, Pressurizer System Abnormal Operations f)

DB-OP-02012, STM GEN/SFRCS Alarm Panel g)

DB-OP-02525, Steam Leaks h)

DB-OP-06401, Integrated Control System Operating Procedure i)

DB-OP-02010, Feedwater Alarm Panel j)

DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture

2)

For Simulator Instructor:

a)

None b)

Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 11 Page 1 of 15 FENOC Facsimile Rev. 1 Facility:

Davis-Besse Scenario No.:

3 Op Test No.:

DB NRC 2018 Examiners:

Operators:

SRO ATC BOP Initial Conditions:

70% Power RCP 1-1 shutdown due to high vibrations (3 days ago)

Turnover: Maintain 70% Power Planned: Swap Main Feed Pump Turbine Main Oil Pumps per the Monthly Activity Log Critical tasks: 1. Isolate RCS Leak Path (CT-3)

2. Minimize SCM (CT-7)

Event No.

Malf.

No.

Event Type*

Event Description 1

N-BOP/SRO Swap MFPT Main Oil Pumps 2

C-BOP/SRO Main Seal Oil Pump Shaft Shear 3

C-ATC/SRO (TS)

PORV fails open 4

C-BOP/SRO TPCW Pump High Bearing Temperature 5

R-ATC/SRO (TS)

Steam Generator Tube Leak 6

C-ATC/SRO Loss of ICS DC - Trip Reactor 7

Major Steam Generator Tube Rupture 8

C-ATC/SRO Pressurizer Spray and Block Valves Fail Open (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Scenario Event Summary NUREG-1021, Revision 11 Page 2 of 15 FENOC Facsimile Rev. 1 DAVIS-BESSE 2018 NRC SCENARIO 3 The Crew will take the watch with power at 70% and RCP 1-1 shutdown three days ago due to high vibrations. Following shift turnover the Crew will swap running Main Feed Pump Turbine Main Oil Pumps as required by the Monthly Activity Log (event 1).

After the MFPT Oil Pumps are swapped the Lead Evaluator will cue the Main Seal Oil Pump shaft shear. The Emergency Seal Oil Pump (ESOP) will Auto start, but the Main Seal Oil pump will continue to run. The crew will respond to ESOP Annunciator(s) 16-1-H. An EO will be sent to investigate and report a Main Seal Oil Pump shaft shear. The BOP will turn off the Main Seal Oil Pump. (event 2).

When the Main Seal Oil Pump is stopped the Lead Evaluator will cue the PORV to fail open.

The crew will respond with immediate actions to isolate the PORV IAW DB-OP-02513, PRESSURIZER SYSTEM ABNORMAL OPERATION (CT-3). The SRO will declare the PORV Inoperable, enter T.S. 3.4.11 Condition A, and direct opening breaker BE1602 for RC11, PORV Block Valve (event 3).

The Lead Evaluator will cue #1 TPCW pump upper motor bearing high oil temperature requiring pump shutdown and start of standby pump. The crew will diagnose the trend and shutdown #1 TPCW Pump and start the standby TPCW Pump. The system procedure may be used to swap pumps or the abnormal may be used after stopping #1 TPCW Pump (event 4).

The Lead Evaluator will then cue indications of a tube leak in #2 Steam Generator (approximately 25 gpm). The crew will respond to annunciator 12-1-B, MN STM LINE 2 RAD HI, in accordance with DB-OP-06012, STM GEN/SFRCS Alarm Panel 12 Annunciator and then enter DB-OP-02531, STEAM GENERATOR TUBE LEAK. The crew will evaluate the SG leakage and determine the leak rate is in excess of T.S. 3.4.13 (TS) and start a rapid shutdown (event 5).

When a rapid shutdown is in progress the Lead Evaluator will cue a loss of ICS DC power which will require the crew to implement immediate actions of DB-OP-02532 and trip the reactor and manually initiate and isolate SFRCS. The crew will then implement the Emergency Procedure DB-OP-02000 (event 6).

After the Reactor is tripped the Lead Evaluator will cue the tube leak to increase to a tube rupture at approximately 400 gpm. The Unit Supervisor will implement the Emergency Procedure by routing to section 8 for Steam Generator Tube Rupture. (event 7)

The BOP will control RCS temperature using the AVVs and the ATC will begin depressurizing the Reactor Coolant System to minimum subcooling margin (CT-7). When the RCS spray valve is opened it will fail and the spray valve block valve will also fail to close. The SRO will direct the ATC to shut down the loop 2 RCP 2-2 and RCP 2-1 to reduce spray flow to zero per DB-OP-02000, Table 5 or DB-OP- 02513, Pressurizer Abnormal Attachment 1 (event 8).

When the RCS Pressure reduction is controlled the scenario can be terminated.

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

1 Page 3

of 15 Event

Description:

Swap running MFPT Main Oil Pumps Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 3 of 15 FENOC Facsimile Rev. 1 Indications Available:

PI 1206 Lube Oil System HDR Pressure 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 Cue PI 1194 indicates 238 psig. PI 1216 indicates 12 psig. PI 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

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

1 Page 4

of 15 Event

Description:

Swap running MFPT Main Oil Pumps Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 4 of 15 FENOC Facsimile Rev. 1 Swap MFPT Main Oil Pumps - continued BOP Verify Equipment Operator standing by to monitor oil pressures 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 Cue PI 1246 indicates 238 psig. PI 1259 indicates 12 psig. PI 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 Proceed to Event 2, Main Seal Oil Pump shaft shears

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

2 Page 5

of 15 Event

Description:

Main Seal Oil Pump shaft shears Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 5 of 15 FENOC Facsimile Rev. 1 Indications Available:

  • 16-1-H ESOP ON
  • 16-2-H Seal Oil P CREW Recognize indications SRO Implements DB-OP-02016, Generator Alarm Panel 16 Annunciators CREW Dispatch an Operator to the Seal Oil Room to Investigate BOOTH CUE Role play as Equipment Operator to report: The Main Seal Oil Pump shaft is sheared. (if asked) ESOP parameters are normal.

BOP Stop Main Seal Oil Pump SRO Refer to DB-OP-02035, Generator Seal Oil Alarm Panel 35 Annunciators SRO Direct removal of the Seal Oil Vacuum Tank from service Procced to Event 3, PORV Fails Open

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

3 Page 6

of 15 Event

Description:

PORV Fails Open Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 6 of 15 FENOC Facsimile Rev. 1 Indications Available:

(4-1 -D) PZR RLF VLV OPEN (4-2-D) PZR QUENCH TK PRESS HI (4-3-D) PZR QUENCH TK LVL HI CREW Identify that the PORV has failed OPEN ATC Take actions to Isolate the PORV to prevent a reactor trip

  • Critical Task ATC
  • Close RC11, PORV Block, using HISRC11 CREW Monitor plant indications for isolation of the PORV SRO Implement DB-OP-02513, Pressurizer Systems Abnormal Operating Procedure Section 4.4 Leaking PORV SRO Refer to Tech Spec 3.4.11 Pressurizer Pilot Operated Relief Valve (PORV)
  • Enter 3.4.11 Condition A

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

3 Page 7

of 15 Event

Description:

PORV Fails Open Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 7 of 15 FENOC Facsimile Rev. 1 PORV Fails Open Event 3 continued Note DNBR Tech Spec 3.4.1 may be entered and exited during this scenario ATC Verify proper Quench Tank operation. Refer to DB-OP-06004, Quench Tank SRO Notify Shift Manager to consult with Plant Management as necessary to confirm that normal operation may continue:

REFER TO Technical Requirements Manual for Reactor Coolant System Vents 8.4.4 and determine Conditions met due to RC239A and RC200 available REFER TO DB-OP-00002, Operations Section Event/Incident Notifications and Actions REFER TO DB-OP-01200, Reactor Coolant System Leakage Management REFER TO NOP-OP-1010, Operational Decision Making REFER TO DB-OP-06003, Pressurizer System Operations (Operation with PORV Block closed)

Procced to Event 4, TPCW High bearing temperature

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

4 Page 8

of 15 Event

Description:

TPCW High bearing temperature Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 8 of 15 FENOC Facsimile Rev. 1 Indications Available:

T159 TPCW Pump 1 Upper Motor Bearing Oil Temperature CREW Recognize computer alarm T159 indicating high temperature TPCW Pump 1 Upper Motor Bearing Oil Temperature BOP Dispatch Equipment Operator to evaluate TPCW Pump 1 Booth Cue Equipment Operator reports:

There is no oil level indicated in TPCW Pump 1 upper motor bearing sight glass and there is a loud sound appearing to come from the bearing SRO Direct stopping TPCW Pump 1 BOP Stop TPCW Pump 1 using HIS627 SRO Direct placing TPCW Pump 3 in service per DB-OP-06263, Turbine Plant Cooling Water Operating Procedure NOTE: Abnormal Procedure DB-OP-02514, TURBINE PLANT COOLING WATER MALFUNCTIONS may be entered by the crew which will provide guidance to start the standby pump NOTE: Starting standby TPCW Pump not required prior to continuing with scenario.

BOP Start TPCW Pump 3 using HIS629 Proceed to Event 5, Steam Generator Tube Leak

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

5 Page 9

of 15 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 9 of 15 FENOC Facsimile Rev. 1 Indications Available:

  • Increasing Makeup flow Crew Recognize indications of a SG tube leak
  • Increasing Makeup flow SRO Route to DB-OP-02531, Steam Generator Tube Leak ATC Calculate a leak rate (~25 gpm). REFER to Attachment 1, Steam Generator Tube Leak Calculation Crew Determine SG 2 has the tube leak (~25 gpm)

Note: If >50 gpm is calculated the crew will route to OP2000 SRO Notify SM to refer to EP Classification, Offsite Dose assessment, and notification requirements SRO Enter TS 3.4.13, RCS Operational Leakage, Condition B for primary to secondary leakage Enter TS 3.4.17, SG Tube Integrity, Condition B SRO Direct a plant shutdown per DB-OP-02504, Rapid Shutdown,, Power Reduction Actions ICS Full Automatic ATC Begin plant shutdown

  • Set rate of change as directed
  • Select target Power - 20% RTP for Low level limits
  • Monitor Power

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

5 Page 10 of 15 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 10 of 15 FENOC Facsimile Rev. 1 Steam Generator Tube Leak, Event 5 continued SRO Direct BOP to perform Attachment 6, BOP Actions SRO Notify EOs to commence Attachment 15, Field Actions SRO/RO Review/Direct DB-OP-02504, Attachment 16, Three Reactor Coolant Pump Operation:

Set the minimum load limit on the load control panel to 13% during 3 RCP operation Prior to the first SG going on Low Level Limits, verify the S/G LOAD RATIO H/A station is in HAND with a demand of 0°F Tc The SG in the Loop with 1 running RCP will go on Low Level Limits at ~ 40% RTP. This will result in an increase in Tc as power reduction continues. Once the second Steam Generator goes on Low Level Limit control, at ~

22% RTP, the Tc will begin to reduce toward zero as power reduction continues Power Range Nuclear Instruments may vary significantly from actual power during power reduction. A core tilt will exist due to Tc once the first Steam Generator reaches Low Level Limit Control. Monitor NIs, Core T, and Feedwater flow.

SRO Notify Load Dispatcher SRO Notify Chemistry to monitor polisher operation and sample for isotopic analysis of iodine per TS 3.4.16 SRO Notify SM to complete required notifications When Tech Spec has been declared and desired reactivity manipulation has been observed proceed to Events 6, 7 & 8, Loss of ICS DC, SGTR and Spray Failure

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

6, 7 & 8 Page 11 of 15 Event

Description:

Loss of ICS DC, SGTR and Pressurizer Spray and Block Failure Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 11 of 15 FENOC Facsimile Rev. 1 Indications Available:

ICS IN TRACK (14-6-D)

ICS 24 VDC BUS TRIP (14-1-C)

ICS H/A Station Lights OFF CREW Recognize a loss of ICS DC Power ICS IN TRACK (14-6-D)

ICS 24 VDC BUS TRIP (14-1-C)

ICS H/A Station Lights OFF ATC Implement immediate actions per DB-OP-02532, Loss of ICS power:

Trip the Reactor Verify power decreasing Trip the turbine ATC Manually actuate initiate & isolation of SFRCS SRO Implement DB-OP-02000 SRO/ATC Verify immediate actions:

Trip the Reactor Verify power decreasing Trip the turbine Verify all Turbine Stop Valves OR Control Valves are closed CREW Check for Specific Rule or Symptom Direction CREW Check for Symptom Mitigation section implementation Note: When pressurizer level is recovering from the reactor trip the lead evaluator SG leak will increase to a tube rupture when reactor CREW Recognize increase in leak rate indicates a SG Tube Rupture Increased MU Flow Lower than expected AFW Flow

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

6, 7 & 8 Page 12 of 15 Event

Description:

Loss of ICS DC, SGTR and Pressurizer Spray and Block Failure Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 12 of 15 FENOC Facsimile Rev. 1 SGTR and Pressurizer Spray and Block Failure events continued SRO Route to DB-OP-02000, Section 8 ATC/BOP 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
  • Open DH 64 and DH 63
  • Transfer MU Pump suctions to the BWST
  • Set Pressurizer level to 100 Inches SRO Verify DB-OP-02531 Attachments are in progress
  • Direct Chemistry to perform Attachment 2
  • Direct Radiation Protection to perform Attachment 3
  • Direct an Equipment Operator/Field Supervisor to perform BOP If the Aux Boiler is running then direct an Equipment Operator/Field Supervisor to transfer Aux Steam and Gland Steam to the Aux Boiler ATC Turn off all Pressurizer heaters SRO Route to step 8.40 ATC Use Pressurizer Spray to reduce RCS pressure to Minimize Subcooling Margin ATC When directed use Pressurizer Spray to reduce RCS pressure to maintain minimum adequate subcooling margin Verify RC10 PZR Spray Block Valve is open Open RC2 PZR Spray Valve Cycle RC2 and control PZR Heaters as necessary to maintain RCS Pressure

Appendix D Operator Action Form ES-D-2 Op Test No.:

2018 Scenario #

3 Event #

6, 7 & 8 Page 13 of 15 Event

Description:

Loss of ICS DC, SGTR and Pressurizer Spray and Block Failure Time Position Applicants Actions or Behavior NUREG-1021, Revision 11 Page 13 of 15 FENOC Facsimile Rev. 1 SGTR and Pressurizer Spray and Block Failure events continued ATC Block SFAS low RCS pressure trips ATC Control MU/HPI to maintain Pressurizer level 80 to 120 inches BOP Begin a RCS cooldown using the Atmospheric Vent Valves Open AVVs to achieve 100 °F/hr C/D rate ATC Recognize RC2, Pressurizer Spray Valve fails to close ATC Attempt to close RC10 PZR Spray Block Valve

  • Determine RC10 is failed open SRO Direct stopping RCPs to reduce spray flow. Refer to one of the following for PZR Spray Flow vs RCP combination:
  • Attachment 1 of DB-OP-02513, PZR System Abnormal
  • Table 5, DB-OP-02000 RPS, SFAS, SFRCS Trip or SG Tube Rupture SRO Note: One RCP in Loop 1 and 0 RCPs in loop 2 equates to 0% of full spray flow. Stopping all RCPs would also result in 0% spray flow but is not preferred Direct stopping RCPs to leave a maximum of 1 RCP in RCS Loop 1
  • Critical Task ATC
  • Stop pressure reduction by stopping RCPs as directed to result in 0% Pressurizer spray flow When 0% Pressurizer spray flow has been achieved following Spray malfunction the scenario can be terminated

NUREG-1021, Revision 11 Page 14 of 15 FENOC Facsimile Rev. 1 Justification for Critical Tasks A. Isolate RCS Leak Path (CT-3)

When the PORV fails open it will become and RCS leak path which must be isolated by closing the PORV Block valve B. Minimize SCM (CT-7)

The Pressurizer spray valve will be required to be open to reduce RCS pressure to allow for isolation of the Steam Generator with the tube rupture. When pressure control is attempted the spray valve and the spray block valve will be failed open requiring the RCP running pump combination to be reduced to one RCP in RCS Loop 1 or less to achieve 0% spray flow and stop the pressure reduction

NUREG-1021, Revision 11 Page 15 of 15 FENOC Facsimile Rev. 1 SIMULATOR SETUP INFORMATION

1.

Simulator Setup a) 70% Power b)

RCP 1-1 OOS c)

MFPT 1 Main Oil Pump 1 in service d)

MFPT 2 Main Oil Pump 2 in service e)

TPCW Pump 1 in service f)

RC2 fails open when opened for pressure reduction and RC10 is failed open LIZ28API90%&& Red Light On Spray Valve==1 (add label to make spray valve and block valve fail open) g)

EFW OOS

2.

Procedures a)

DB-OP-06224, Main Feed Pump and Turbine b)

DB-OP-02016, Generator Alarm Panel 16 c)

DB-OP-02035, Generator Seal Oil Alarm Panel 35 d)

DB-OP-02513, Pressurizer Systems Abnormal Operating Procedure e)

DB-OP-06004, Quench Tank f)

DB-OP-06003, Pressurizer System Operations g)

DB-OP-06263, Turbine Plant Cooling Water Operating Procedure h)

DB-OP-02514, Turbine Plant Cooling Water Malfunctions i)

DB-OP-02531, Steam Generator Tube Leak j)

DB-OP-02504, Rapid Shutdown k)

DB-OP-02532, Loss of ICS power l)

DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture

2)

For Simulator Instructor:

a)

None b)

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