ML14234A015

Initial Exam 2014-301 Final Simulator Scenarios

ML14234A015
Person / Time
Site:	North Anna
Issue date:	08/21/2014
From:	Division of Reactor Safety II
To:	Virginia Electric & Power Co (VEPCO)
References
50-338/14-301, 50-339/14-301
Download: ML14234A015 (257)

Text

Appendix D Scenario Outline Form ES-D-1 Facility: North Anna Power Station Scenario No.: (2014) NRC-2 Op-Test No.: 1 Examiners: ___________________________ Operators: _____________________________

___________________________ _____________________________

___________________________ _____________________________

Initial Conditions: Reactor is at approximately 49% power BOL. Unit was returned to power 2 days ago following work on the generator exciter. Power has been at 49% for several days due to a problem with a containment sump pump. The sump pump has been replaced and the unit as been cleared to increase power to 100%. 2-CC-P-1B was tagged out last shift for major maintenance and is not expected to be returned to service for several days.

Turnover: Shift orders are to transfer acid from "B" BAST to "A" BAST and then ramp the unit to 100%

power.

Event Malf. Event Event No. No. Type* Description 1 N (R) (S) Xfer acid from "B" to "A" BAST 2 N (B) Ramp unit up using normal ramping OP R (R) (S) 3 RC1901 I (R) (S) Pressurizer pressure transmitter fails high causing PORV to open.

RC0701 TS (S) Valve sticks open and block valve must be closed. (CT) 4 EL09 C (B) (S) Main generator voltage regulator fails high 5 C (R) (S) Steam dump fails open (isolable from control room) (CT) 6 MS1702 I (B) (S) "A" SG steam pressure channel III fails low (which also fails steam TS (S) flow) 7 EL10 C (ALL) G-12 opens causing a turbine/reactor trip 8 SI16 M (ALL) LOCA outside containment (CT) 9 C (B) (S) BIT inlets fail to open automatically or manually (CT)

The scenario can be terminated once the crew has isolated the leak in 1-ECA-1.2 and transitioned to 1-E-1.

(Event 9 occurs during event 8 and is numbered only for use on subsequent forms.)

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

DOMINION NORTH ANNA POWER STATION INITIAL LICENSED OPERATOR EXAMINATION SIMULATOR EXAMINATION GUIDE SCENARIO 2014 NRC 2 2014 NRC 2 Page 2 Revision 0

SIMULATOR EXAMINATION GUIDE EVENT DESCRIPTION

1. Xfer acid from "B" to "A" BAST

2. Ramp unit up using normal ramping OP

3. Pressurizer pressure transmitter fails high causing PORV to open. Valve sticks open and block valve must be closed. (CT)

4. Main generator voltage regulator fails high

5. Steam dump fails open (isolable from control room) (CT)

6. "A" SG steam pressure channel III fails low (which also fails steam flow)

7. G-12 opens causing a turbine/reactor trip

8. LOCA outside containment (CT) 9.

BIT inlets fail to open automatically or manually (CT)

Scenario Recapitulation:

Malfunctions after EOP entry 2 (LOCA outside containment, BIT valves fail to open automatically or manually)

Total Malfunctions 7 (Pressurizer pressure transmitter fails high causing PORV to open/valve sticks open, main generator voltage regulator fails high, steam dump fails open, failure of selected steam pressure channel, G-12 opens causing a turbine/reactor trip, LOCA outside containment, BIT valves fail to open automatically or manually)

Abnormal Events 4 (Pressurizer pressure transmitter fails high causing PORV to open/valve sticks open, main generator voltage regulator fails high, steam dump fails open, failure of selected steam pressure channel)

Major Transients 1 LOCA outside containment EOPs Entered 2 (ES-0.1, ECA-1.2)

EOP Contingencies 1 (ECA-1.2)

Critical Tasks 4 SCENARIO DURATION 135 Minutes 2014 NRC 2 Page 3 Revision 0

SIMULATOR EXAMINATION SCENARIO

SUMMARY

SCENARIO 2014 NRC2 Reactor is at approximately 49% power BOL. Unit was returned to power 2 days ago following work on the generator exciter. Power has been at 49% for several days due to a problem with a containment sump pump. The sump pump has been replaced and the unit has been cleared to increase power to 100%. 1-FW-P-2 was returned to operable last shift after work on the governor valve. Unit 2 is at 100% power. 2-CC-P-1B was tagged out for major maintenance last shift and is not expected to be returned to service for several days. Shift orders are to transfer acid from "B" BAST to "A" BAST and then ramp the unit to 100% power.

The first event will be a normal event of transferring acid from "B" BAST to "A" BAST.

The RO will use 0-OP-8.8, "Transferring Boric Acid," and transfer acid. This event will be briefed prior to the crew assuming the watch. Once the acid transfer is complete the next event can occur.

Next will be a unit power increase. This evolution will be briefed prior to the crew assuming the watch. The RO will use dilution and rods to increase reactor power. The BOP will ramp the turbine up. The power increase will be done in accordance with 1-OP-2.1, "Unit Operation from Mode 2 to Mode 1." Once enough of a power increase has been observed, the next event can occur.

The next event will be pressurizer pressure transmitter 1-RC-PT-1445 failing high, resulting in the opening of PRZR PORV 1-RC-PCV-1456. The crew will be expected to perform the immediate actions of 1-AP-44, "Loss of Reactor Coolant System Pressure," and attempt to close 1-RC-PCV-1456. The PORV will not close and the RO will perform the RNO action of closing the PORV block valve. After RCS pressure has been stabilized, the next event will occur.

At this time the main generator voltage regulator will fail. The crew will perform the actions of 1-AP-26, "Failure of Main Generator Regulator High," and place the voltage regulator switch in OFF. Once the system operator has been notified of the failure, the next event can occur.

Now, a steam dump valve will fail open. The crew will enter 1-AP-38, "Excessive Load Increase," and turn the steam dumps off. The crew will have an operator isolate air to the failed valve. Once power has been stabilized, the next event can occur.

Next, the channel III steam pressure transmitter for the "A" SG (PT-1475) fails low. This will cause the associated steam flow channel to also fail low. The crew will enter 1-AP-3, "Loss of Vital Instrumentation," and swap to an operable channel, refer to technical specifications, and notify the Instrument Department to place the channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. Once the channel is swapped and TS have been identified, the next event can occur.

At this time the generator output breaker will open and cause a reactor and turbine trip. The crew will enter 1-E-0, "Reactor Trip or Safety Injection," and perform the immediate operator actions. The crew will transition to 1-ES-0.1, "Reactor Trip Response. The next event can occur once the crew has transitioned.

A RCS leak outside containment will develop in the Safeguards. The check valves from the 2014 NRC 2 Page 4 Revision 0

RCS cold legs to the LHSI pumps will experience severe backleakage. The LHSI pump discharge check valves will hold causing relief valves 1-SI-RV-1845A, B, & C to lift. This will result in annunciator A-C1, SFGDS AREA SUMP HI/HI-HI LEVEL, and high and high-high alarms on 1-RM-VG-112/113. PRZR level will decrease. The crew will respond IAW 1-AP-16, "Increasing Primary Plant Leakage," and isolate letdown, then maximize charging flow. PRZR level will continue to decrease; the crew should respond IAW the 1-ES-0.1 CAP, manually initiate SI and return to 1-E-0. The BIT inlet valves will fail to open and the BIT will have to be bypassed until a valve can be opened locally. The crew will determine that there is a LOCA outside the containment and continue in 1-E-0 until directed to transition to 1-ECA-1.2, "LOCA Outside Containment." The scenario may be terminated after the completion of 1-ECA-1.2 or as directed by the lead evaluator.

2014 NRC 2 Page 5 Revision 0

SCENARIO TURNOVER SHEET Read the following to the crew:

Purpose: This examination is intended to evaluate the crews performance of various tasks associated with the Initial License Operator Training Program. All activities should be completed in accordance with approved operations standards.

1. You are on a day shift during the week.

2. A rough log should be maintained to aid in making reports and to help during briefs.

3. Respond to what you see. In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated and the crew informed.

Unit Status:

Unit 1 is at 49% power. Unit was returned to power 2 days ago following work on the generator exciter. Power has been at 49% for several days due to a problem with a containment sump pump. The sump pump has been replaced and the unit as been cleared to increase power to 100%. RCS boron is 1537 ppm and core age is 150 MWD/MTU. Aux steam is on unit 2.

Unit 2 is at 100% power.

Equipment Status:

1-FW-P-2 was returned to service last shift. Maintenance rule window is green. 2-CC-P-1B was tagged out last shift for major maintenance. It is expected to be out for several more days. Protected train is 2H.

Shift Orders:

Shift orders are to increase "A" BAST level to 90% by transferring acid from "B" BAST to "A" BAST and then ramp the unit to 100% power.

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EVENT 1: Given that the unit is at power and a transfer of boric acid from "B" BAST to "A" BAST is required, the RO will transfer acid in accordance with 0-OP-8.8, "Transferring Boric Acid."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• "B" BAST level decreases

• "A" BAST level increases RO instructs AB operator to open 1-CH-95.

RO opens 1-CH-HCV-1110.

RO closes 1-CH-HCV-1105.

RO places 1-CH-P-2B in FAST.

RO verifies desired level in "A" BAST has been reached.

RO places 1-CH-P-2B in OFF.

RO opens 1-CH-HCV-1105 to 20%.

RO instructs AB operator to close 1-CH-95.

RO places switch for 1-CH-P-2B in SLOW.

RO verifies level in "A" BAST is stable.

RO ensures control switch for 1-CH-P-2A in AUTO RO adjusts recirc valve 1-CH-HCV-1110 to 20%.

RO requests chemistry to sample "A" BAST.

NOTE: The next event can occur once Validation time: 15 minutes.

the acid transfer is complete, or as (Changed initial BAST level. Won't directed by the lead examiner. take as long with higher level.)

2014 NRC 2 Page 7 Revision 0

EVENT 2: Given that the unit is at 50% power and a power increase to 100% is desire, the crew will increase power in accordance with 1-OP-2.1, "Unit Operation from Mode 2 to Mode 1."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Reactor power increases

• Turbine power increases

• Tavg/Tref increase

• Generator megawatts increase BOP ramps down to get off limiter. Attachment 9 to 1-OP-2.1.

Step 6.

BOP adjusts limiter up. Step 7 BOP verifies/sets desired ramp rate (0.3% Step 1 per minute).

BOP increases turbine setter to desired Step 3 position.

BOP presses GO on turbine.

BOP monitors turbine ramp.

RO starts a dilution when required using 1- Attachments GOP-8.3.1 or 1-GOP-8.3.2.

RO monitors control rods. AFD NOTE: The next event can occur once Validation time: 28 minutes to ramp enough of a power increase has been about 10%.

observed, or as directed by the lead examiner. Make sure all 4 NIs are > 51%.

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EVENT 3: Given that the unit is at power, and the PRZR PORV has failed open and will not close, the crew will be expected to respond in accordance with 1-AP-44, "Loss of Reactor Coolant System Pressure."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciators C-D1, B-F7, B-E7, B-H6, and B-H2 are illuminated

• 1-RC-PCV-1456 indicates open

• 1-RC-PCV-1456 will not close RO identifies annunciator C-D1, PRZR SAFETY VALVE OR PORV OPEN.

RO identifies RCS pressure is decreasing.

US directs crew to perform actions of 1-AP-44.

CT1 Crew stops RCS pressure decrease. *Prior to a PRZR low pressure reactor IOAs

• Crew identifies PORV open. trip

• RO performs RNO step and attempts to close 1-RC-PCV-1456.

• RO closes PORV block valve 1-RC-MOV-1535.

IOA RO checks master controller is controlling properly.

IOA RO checks PRZR spray valves closed.

NOTE: At this time the RO should secure the dilution and the BOP should be directed to hold the ramp.

RO verifies all PRZR heaters energized.

RO checks 1-CH-HCV-1311 closed.

RO checks PRZR PORVs and safety valves closed.

• RO verifies RCS pressure stable or increasing.

RO verifies RCS pressure normal.

US refers to TS 3.4.1 for DNB 3.4.13 for RCS leakage. (Only applied while valve was open and unisolated.)

TS 3.4.11C and determines that the block valve must be de-energized within an hour.

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EVENT 3: Given that the unit is at power, and the PRZR PORV has failed open and will not close, the crew will be expected to respond in accordance with 1-AP-44, "Loss of Reactor Coolant System Pressure."

TIME EXPECTED ACTION INSTRUCTOR REMARKS Crew directs a watchstander to de-energize 1-RC-MOV-1535.

NOTE: The next event can occur once tech specs have been reviewed, or at the discretion of the lead examiner.

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EVENT 4: Given that the unit is at power, and the main generator voltage regulator has failed, the crew will be expected to respond in accordance with 1-AP-26, "Loss of Main Generator Voltage Control."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciator K-C1 illuminates

• Annunciator K-B4 may illuminate

• Generator output voltage increases BOP identifies annunciator K-C1, VOLTAGE REGULATOR CRITICAL FAILURE.

US directs entry into 1-AP-26.

IOA BOP identifies generator output voltage and MVARS increasing with MW stable.

IOA BOP places voltage regulator control switch to OFF.

IOA BOP adjusts generator output voltage using base adjust, if required so that:

Generator output voltage in the normal range MVARs not greater than 200 MVARs IN Crew notifies Dominion Energy Supply Market Operations Center that the voltage regulator is in base control and the PSS is not available and that PJM must be notified within 30 minutes.

Crew notifies system operator that the voltage regulator is in base control and the PSS is not available.

Crew maintains 500kV voltage schedule.

US directs condition reports be entered.

Crew initiates 1-MISC-32.

NOTE: The next event can occur after Validation time: 11 minutes Did not include acknowledging alarms in TB. This was done the crew has stabilized the plant, or at during the next event.

the direction of the lead examiner.

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EVENT 5: Given that the unit is at power and a steam dump has failed open, the crew will be expected to respond in accordance with 1-AP-38, "Excessive Load Increase."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• "C" steam dump shows mid-position

• Reactor power increases slightly (until dump is closed)

• Tave decreases slightly (until dump is closed)

• Megawatts decrease slightly (until dump is closed)

Crew identifies increase in reactor power, decrease in Tave, or steam dump red light lit.

US directs crew to enter 1-AP-38.

IOA RO all checks steam dumps closed. (NO)

CT2 RO takes steam dumps to OFF. RNO IOA Steam dump will close.

• Prior to receiving an automatic reactor trip on over power IOA BOP verifies all SG PORVs closed.

IOA Crew verifies reactor power less than or equal to 100% and stable.

RO verifies proper auto rod control.

RO energizes additional pressurizer heaters, as required to maintain RCS pressure.

• BOP checks turbine load control.

• RO maintains rods above limits and AFD within specifications.

Crew checks plant status stable:

• BOP checks main generator output is stable

• Crew verifies Tave on program with Tref.

BOP checks steam flow channel indications.

Crew turbine control in operator auto.

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EVENT 5: Given that the unit is at power and a steam dump has failed open, the crew will be expected to respond in accordance with 1-AP-38, "Excessive Load Increase."

TIME EXPECTED ACTION INSTRUCTOR REMARKS Crew checks plant steam systems:

• Crew checks SG PORVs are closed by SPDS and local indication

• Crew checks SG safeties are closed by SPDS indication and local indication

• BOP checks MSR inlet FCV operation is normal

• BOP checks 1-AS-PCV-105 operation is normal

• Crew checks plant steam system are intact.

NOTE: May request tagout or APC sheet before isolating the "C" steam dump.

Crew checks for RCS dilution.

Crew directs WCC/operator to isolate air to steam dump.

Crew verifies cause for load increase has been corrected.

RO checks steam dump interlock switches in OFF/RESET.

NOTE: If crew has isolated the failed Did not wait for this during validation.

steam dump then they may return steam dumps to Tave mode.

Crew verifies steam dumps available.

RO places steam dumps in Tave mode, if applicable:

• RO verifies both channels of first stage pressure are operable

• RO verifies both STEAM DUMP INTKL switches in OFF/RESET

• RO verifies P-E4 is NOT lit

• RO places MODE SELECTOR switch to Tave

• RO ensures steam dump demand is zero

• RO places both STEAM DUMP INTLK switches to ON Crew enters a CR to document the Reactivity Management event.

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EVENT 5: Given that the unit is at power and a steam dump has failed open, the crew will be expected to respond in accordance with 1-AP-38, "Excessive Load Increase."

TIME EXPECTED ACTION INSTRUCTOR REMARKS NOTE: The next event can occur once Validation time: 15 minutes.

the unit is stable, or at the direction of the lead examiner.

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EVENT 6: Given the plant is in mode one with indications of a failed steam pressure transmitter, the crew will respond in accordance with 1-AP-3, "Loss of Vital Instrumentation."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciators F-H1 illuminates

• Status light N-C3 and N-C4 illuminate

• 1-MS-PI-1475 fails down scale

• 1-MS-FI-1474 fails down scale

• "A" MFRV demand decreases BOP identifies annunciators F-H1, HI STM LINE P SG 1A LO.

BOP identifies 1-MS-PI-1475 failing low.

US directs the crew to enter 1-AP-3.

IOA BOP verifies redundant channels normal.

IOA BOP verifies SG level controlling channel normal. (NO)

• Steam flow

• Feed flow

• Steam generator level

• Steam pressure IOA BOP takes manual control of the "A" Main RNO Feed Reg Valve to control SG level.

IOA Crew verifies first stage pressure indications normal.

IOA RO verifies pressurizer level indications are normal.

RO verifies systems affected by PRZR level channels normal.

• Operable channel is selected

• Emergency bus backup heaters are restored

• Letdown is in service

• Pressurizer level control in auto

• Pressurizer control group heaters are not tripped.

Crew verifies both first stage pressure channels normal.

Crew verifies all SGWLC channels selected to an operable channel. (NO)

RO verifies rod control in manual. (NO) 2014 NRC 2 Page 15 Revision 0

EVENT 6: Given the plant is in mode one with indications of a failed steam pressure transmitter, the crew will respond in accordance with 1-AP-3, "Loss of Vital Instrumentation."

TIME EXPECTED ACTION INSTRUCTOR REMARKS RO places control rods in manual.

RO places steam dumps in OFF or steam SRO will most likely choose OFF pressure mode, as required.

BOP checks all MFRV bypass valves are in manual.

BOP places "B" and "C" MFRVs to manual.

Crew swaps to operable SGWLC channels on feed flow, steam flow and first-stage pressure..

BOP verifies all SG levels are on program and returns MFRVs to automatic when they are on program.

RO verifies steam dumps are available and This will depend on whether dumps places them in Tave Mode, if applicable: are ready to be returned to service

• Verifies both channels of first stage from event 5 failure.

pressure are operable

• Places both STEAM DUMP INTLK switches to OFF/RESET

• Verifies annunciator P-E4 is NOT lit (If it is lit then the steam dump mode selector switch is taken to reset.)

• Place mode selector switch to Tave

• Ensures steam dump demand is zero

• Places both STEAM DUMP INTLK switches to ON.

Crew verifies auto rod control desired.

• Tave and Tref within 1.5 degrees

• If not then adjusts Tave or Tref and then returns rods to Automatic.

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EVENT 6: Given the plant is in mode one with indications of a failed steam pressure transmitter, the crew will respond in accordance with 1-AP-3, "Loss of Vital Instrumentation."

TIME EXPECTED ACTION INSTRUCTOR REMARKS US review TS 3.3.2 Function 1e (SI. High delta P between steam lines),

Function 1f (SI. High steam line flow with low-low Tave),

Function 1g (SI. High steam line flow with low steam line pressure),

Function 4d (Steam line isolation. High steam flow with low-low Tave) , and Function 4e (Steam line isolation. High steam line flow with low steam line pressure)

Condition D (for all) - channel must be placed in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> These channels are not in ASDP 3.3.3 and 3.3.4 do not apply 3.3.9 require 2/3 Steam pressures and 1/2 steam TR 3.3.9 is not applicable flows per SG.

US directs RO to enter 1-MOP-55.77 and 1-MOP-55.79.

NOTE: The next event may occur after Validation time: 20 minutes, including placing steam dumps back in service after the failed dump the crew has identified channel trip was isolated.

requirements and the US has referred to tech specs, or as directed by the lead examiner.

2014 NRC 2 Page 17 Revision 0

EVENT 7: Given that the generator output breaker has opened causing a reactor trip, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• G-12 opens

• Reactor and turbine trips occur Crew identifies that a reactor and turbine trip have occurred.

US directs entry into 1-E-0.

IOA Crew verifies reactor trip:

• RO/BOP manually trip reactor

• RO checks reactor trip and bypass breakers are open

• RO checks rod bottom lights lit

• RO checks neutron flux decreasing.

IOA BOP verifies turbine trip:

• Manually trips turbine

• Verifies all turbine stop valves closed

• Resets reheaters

• Verifies MSR FCVs closed

• Verifies generator output breaker open IOA RO verifies both emergency busses are energized.

IOA Crew verifies that safety injection has not occurred and is not required.

• No LHSI pumps running

• No SI first out annunciator lit

• No low pressurizer pressure

• No high containment pressure

• No steamline differential pressure

• No high steam flow with low-lo Tave or low steam pressure NOTE: Continuous action pages for 1-E-0 and 1-ES-0.1 will direct closing and locking 1-CH-217, PG to the Unit 1 blender.

US directs transitions to 1-ES-0.1.

RO checks any RCPs running.

RO checks RCS Tave stable at or trending to desired temperature. (547°F on steam dumps) 2014 NRC 2 Page 18 Revision 0

EVENT 7: Given that the generator output breaker has opened causing a reactor trip, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection."

TIME EXPECTED ACTION INSTRUCTOR REMARKS BOP reduces AFW flow between generators to maintain >400 gpm.

BOP checks feedwater status:

• Checks RCS average temperature <

554°F

• Verifies MFRVs closed

• Verifies AFW pumps running

• Verifies total AFW flow 400 gpm.

BOP checks SG levels:

• Checks ALL SG NR levels > 11%.

(NO)

• Checks WR levels are increasing

• Controls feed flow to maintain narrow range levels between 23 and 33%.

RO verifies charging in service.

RO checks pressurizer level control:

• Level greater than 15%

• CC system in service

• Letdown in service

• Level between 20 and 29%.

RO checks pressurizer pressure control:

• Pressure > 1780 psig

• Pressure stable at or trending to 2235 psig NOTE: The next event can occur once the crew has checked pressurizer pressure control, or as directed by the lead examiner.

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EVENT 8: With the unit stabilized in 1-ES-0.1, "Reactor Trip Response," and indications exist of a SBLOCA outside containment, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection," and 1-ECA-1.2, "LOCA Outside Containment."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• RCS pressure and pressurizer level decrease

• Charging flow increases

• Annunciators A-C1, E-F8, then A-C4 illuminate

• Annunciator B-F8 may also illuminate

• Vent stack "B" radiation increases to alarm setpoint

• BIT inlet valves fail to open Crew identifies annunciator A-C1, SFGDS AREA SUMP HI/HI-HI LEVEL.

RO identifies charging flow increasing and PRZR level decreasing.

NOTE: Crew may or may not initially enter 1-AP-16.

NOTE: If crew dispatches an operator to check the safeguards building, the operator will report that the door is hot and steam is issuing from around the door seals.

Crew verifies unit is in Mode 1, 2, or 3. AP-16 steps RO verifies pressurizer level stable or increasing. (NO)

RO places 1-CH-FCV-1122 in manual and adjusts charging flow to control pressurizer level.

RO isolates letdown if pressurizer level is still decreasing:

Closes 1-CH-HCV-1200B Closes 1-CH-LCV-1460A/B NOTE: The US may use the CAP of 1-ES-0.1 and initiate SI and return to 1-E-0.

RO shifts charging pump suction to RWST if pressurizer level is still decreasing:

Opens 1-CH-MOV-1115B/D Closes 1-CH-MOV-1115C/E Crew returns to 1-E-0.

Crew identifies annunciator A-C4, AREA AMBIENT AIR TEMP HIGH.

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EVENT 8: With the unit stabilized in 1-ES-0.1, "Reactor Trip Response," and indications exist of a SBLOCA outside containment, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection," and 1-ECA-1.2, "LOCA Outside Containment."

TIME EXPECTED ACTION INSTRUCTOR REMARKS Crew identifies high temperature in U-1 SFGDS.

US directs crew to manually initiate SI and return to 1-E-0.

RO/BOP manually initiate SI.

Crew verifies 1-E-0 immediate operator actions.

RO reviews CAP items 1-5.

Crew determines that CAP item 2 applies. No SI flow is available.

Per CAP, crew initiates attachment 6 for manual verification of SI flowpath.

NOTE: The following steps are from Attachment attachment 6, "Manual Verification of SI Flowpath."

Crew verifies the following:.

1-CH-MOV-1115B/D open 1-CH-MOV-1115C/E closed 1-CH-MOV-1289A and or B closed 1-CH-TV-1884A/B/C closed Crew opens at least one BIT outlet valves 1-CH-MOV-1869C/D Crew attempts to open BIT inlet valves.

(NO) 1-CH-MOV-1867A/B CT3 Crew aligns BIT bypass: *Prior to exiting E-0 after safety

• BOP turns on control power for 1- injection initiated.

SI-MOV-1836. RNO

• BOP opens 1-SI-MOV-1836

• BOP verifies flow indicated through BIT bypass

• BOP dispatches operator to locally open BIT inlet

• BOP closes 1-SI-MOV-1836 when a BIT inlet has been locally opened.

US holds a transient crew brief.

US initiates attachment 4(5). Attachment 5 is initiated by attachment

4. These will most likely be given to the BOP. The SRO will read to the RO.

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EVENT 8: With the unit stabilized in 1-ES-0.1, "Reactor Trip Response," and indications exist of a SBLOCA outside containment, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection," and 1-ECA-1.2, "LOCA Outside Containment."

TIME EXPECTED ACTION INSTRUCTOR REMARKS Crew verifies SI flow.

HHSI cold leg SI flow indicated RCS pressure < 225 psig (NO)

Crew verifies AFW flow.

AFW flow to all SGs indicated Total AFW flow > 340 gpm (or level in at least one SG > 11%).

RO checks RCS Tave stable at or trending to 547°F.

• RO checks PRZR PORVs and spray valves.

• PORVs closed

• Spray valves responding to control pressure at 2235 psig or demand at zero and closed

• At least one PORV block valve open.

RO checks RCP trip and charging pump recirc criteria.

RCS subcooling < 25°F (NO)

BOP checks SGs not faulted.

• All SG pressures > 80 psig and under control of operator. (YES)

BOP checks SGs tubes are not ruptured:

(YES):

• Level in any SG increasing in an uncontrolled manner (NO, continue on)

Crew checks if RCS is intact inside containment: (YES)

• Containment pressure normal

• Containment recirc spray sump level normal

• Containment radiation normal.

NOTE: Crew will enter 0-AP-5.2 for the MGPI vent stack alarm as resources permit.

Crew checks for outside containment inventory loss.

• Vent stack radiation normal. (NO)

Crew determines cause of abnormal conditions is loss of RCS inventory outside containment.

2014 NRC 2 Page 22 Revision 0

EVENT 8: With the unit stabilized in 1-ES-0.1, "Reactor Trip Response," and indications exist of a SBLOCA outside containment, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection," and 1-ECA-1.2, "LOCA Outside Containment."

TIME EXPECTED ACTION INSTRUCTOR REMARKS US directs crew to transition to 1-ECA-1.2.

BOP verifies LHSI pump hot-leg valves closed:

1-SI-MOV-1890A and 1890B.

BOP verifies SI accumulator sample valves closed:

1-SI-HCV-1850B, D, F 1-SI-HCV-1850A, C, E CT4 Crew isolates LOCA outside *Before exiting 1-ECA-1.2 containment.

• BOP closes LHSI pump cold-leg injection valves 1-SI-MOV-1890C and 1890D.

• BOP closes LHSI pump discharge valves 1-SI-MOV 1864A and 1864B.

RO checks RCS pressure increasing.

(YES)

US directs crew to transition to 1-E-1.

NOTE: The scenario may be terminated Validation time 20 minutes from when event after the crew isolates the leak, or as 7 happened.

Total time: 135 minutes.

directed by the lead examiner.

2014 NRC 2 Page 23 Revision 0

REFERENCES PROCEDURE REV.

Operating Procedure 1-OP-8.8, "Transferring Boric Acid." 10 Operating Procedure 1-OP-2.1, "Unit Operation from Mode 2 to Mode 1." 113 Abnormal Procedure 1-AP-44, "Loss of RCS Pressure." 19 Abnormal Procedure 1-AP-3, "Loss of Vital Instrumentation." 26 Abnormal Procedure 1-AP-38, "Excessive Load Increase." 19 Abnormal Procedure 1-AP-26, "Loss of Main Generator Voltage Control." 12 Abnormal Procedure 1-AP-16, "Primary Plant Leakage." 29 Abnormal Procedure 0-AP-5.2, "MGP Radiation Monitoring System." 23 Maintenance Operating Procedure 1-MOP-55.77, "Steam Flow Instrumentation." 10 Maintenance Operating Procedure 1-MOP-77.79, "Steam Pressure 12 Instrumentation."

Emergency Operating Procedure 1-E-0, "Reactor Trip or Safety Injection." 46 Emergency Operating Procedure 1-ES-0.1, "Reactor Trip Response." 31 Emergency Contingency Action 1-ECA-1.2, "LOCA Outside Containment." 6 Station Annunciator Response Procedures. N/A Administrative Procedure PI-AA-5000, "Human Performance." 8 INPO, Guideline for Teamwork and Diagnostic Skill Development: INPO 88-003, Jan. 1988 INPO, ACAD 07-002 Simulator Training Guidelines Jan. 2007 2014 NRC 2 Page 24 Revision 0

ATTACHMENT 1 SIMULATOR OPERATOR'S COMPUTER PROGRAM 2014 NRC 2 Page 25 Revision 0

SIMULATOR OPERATOR'S COMPUTER PROGRAM 2014 NRC 2 Initial conditions

1. Recall IC 369

2. Ensure Tave(555-565), Tref, PDTT level, and VCT level are selected on trend recorders.

3. Place red sticker on 2-CC-P-1B.

4. 2H is the protected train.

5. Control rods at 160 steps.

6. Calorimetric selected to 0.

7. Copy of 0-OP-8.8 for booth.

PRELOADS PRIOR TO SCENARIO START CONDITION MALFUNCTION/OVERRIDE/ETC.

Tagout of 2-CC-P-1B Verify 2-CC-P-1A is running Place 2-CC-P-1B in PTL Remote functions:

U2_CCP1B_RACKIN = RACKOUT (False)

U2_CC_28 = 0 Lower level in "A" BAST Use tanks and stuff:

chm405(1)

Failure of BIT inlet MOVs Monitor:

SIMOV867_RATE(1) = 0 SIMOV867_RATE(2) = 0 "C" steam dump rate to 0 on Set up trigger on Trigger 7 reactor trip Set VTMS408C_R = 0 "C" steam dump red light is Set up on trigger 13 to occur on a reactor trip (RD1) overridden off Lamp override:

TCV408C_RED = OFF 2014 NRC 2 Page 26 Revision 0

SCENARIO EVENTS EVENT 1 Transfer acid from "B" BAST to "A" BAST MALFUNCTIONS/OVERRIDES When directed to perform lineup per 0-OP-8.8 step 5.1.4:

Open 1-CH-95 using trigger 1:

CH_95 = 100, Ramp = 30, Trigger = 1 When directed to secure lineup per 0-OP-8.8 step 5.1.11c :

Return CH_95 to 0 over 30 seconds using summary screen.

The next event can occur once the acid transfer is complete, or as directed by the lead examiner.

COMMUNICATIONS Report back when 1-CH-95 has been opened and also when it has been re-closed.

2014 NRC 2 Page 27 Revision 0

EVENT 2 Increase power MALFUNCTIONS/OVERRIDES The next event can occur once enough of a power increase has been observed, or as directed by the lead examiner.

Discussion that this can happen once both A-C7 and A-C8 have been cleared. All 4 PR NIs

> 51%.

COMMUNICATIONS 2014 NRC 2 Page 28 Revision 0

EVENT 3 PRZR PORV fails open MALFUNCTIONS/OVERRIDES Malfunctions:

RC0702, Delay time = 5, Ramp = 20, Severity = 1, Trigger = 3 RC1902, Delay time = 5, Trigger = 3 MOV control:

RCMOV535_RACKIN = RACKOUT, Trigger = 10 The next event can occur once tech specs have been reviewed, or at the discretion of the lead examiner.

COMMUNICATIONS When directed to de-energize 1-RC-MOV-1535, wait 5 minutes and then insert trigger 10 and report back.

2014 NRC 2 Page 29 Revision 0

EVENT 4 Main Generator Voltage Regulator Failure MALFUNCTIONS/OVERRIDES Malfunction:

EL09, Delay time = 5, Ramp = 35, Severity = 60, Trigger = 4 If need to reset K-B4:

V2KB4_W_RST = TRUE, Trigger = 12 NOTE: The next event can occur after the crew has stabilized the plant, or at the direction of the lead examiner.

COMMUNICATIONS The turbine building operator may be sent to look at voltage regulator panel. Can report that there are many messages and need electrical support.

Lead examiner will most likely not wait for any outside the MCR operators to show up. Check before going to get the AR.

When dispatched with AR for K-C1: The AVR system stabilizer in NOT on.

Circle the following: HLTH FBKPOST, HLTH FBKPRE, HLTH IOICUFAIL, and HLTH NOCTRLR See below for resetting ARs as this is required in AR for K-C1 also.

When dispatched with AR for K-B4: If need to reset K-B4: Use trigger 12 above.

Circle the following on AR for K-B4: FORCING, MXL, OVERVOLT 2014 NRC 2 Page 30 Revision 0

EVENT 5 Steam dump failure MALFUNCTIONS/OVERRIDES Remote Function MSTCV408C_DESD, Delay time = 5, Severity = 50, Trigger = 5 Setup a trigger 11 to close the valve when a steam dump switch is taken to OFF:

SD2A_OFF_RESET(1) == 1 .OR. SD2B_OFF_RESET == 1 Command: SET MSTCV408C_DESD = 0 The next event can occur once the unit is stable, or at the direction of the lead examiner.

COMMUNICATIONS When sent to investigate, the TB operator can report a 9 psig air demand signal on the valve.

If directed to isolate air: Wait 2 minutes and then report that air is isolated and regulator has been bled off for "C" steam dump. (1-IA-1213 is air isolation valve to "C" steam dump.)

If tagout has been requested to isolate air: wait at least 10 minutes. Then report (As WCC) that air has been isolated to "C" steam dump per an APC sheet (which you have in the WCC).

Tagout will be hung when ready. Steam dumps can be returned to service.

I&C will report that the air booster to the "C" steam dump has failed.

When sent to look at SG PORVs and safeties locally: wait 3 of 4 minutes and then report back that all are closed.

2014 NRC 2 Page 31 Revision 0

EVENT 6 "A" SG Press Ch III failure MALFUNCTIONS/OVERRIDES Malfunction:

MS1701, Delay time = 5, Ramp = 10, Severity = -1, Trigger = 6 The next event may occur after the crew has identified channel trip requirements and the US has referred to tech specs, or as directed by the lead examiner.

COMMUNICATIONS If sent to look at transmitter locally, wait 5 minutes and report that there are no obvious abnormalities with transmitter. (QSPH basement) 2014 NRC 2 Page 32 Revision 0

EVENT 7 G-12 opens causing a reactor/turbine trip MALFUNCTIONS/OVERRIDES Malfunction:

EL10, Delay time = 5, Trigger = 7 The next event can occur once the crew has checked pressurizer pressure control, or as directed by the lead examiner.

COMMUNICATIONS When sent to close and lock 1-CH-217: use ExremeView to close and report back within 5 minutes. Could also possibly be sent to stand by at valve.

2014 NRC 2 Page 33 Revision 0

EVENT 8 Inter-system LOCA MALFUNCTIONS/OVERRIDES Malfunction:

SI16, Delay time = 120, Ramp = 100, Severity = 75, Trigger = 8 If sent to open BIT valve(s) locally AFTER de-energizing it/them:

MOV Override: SI SIMOV867A_RACKIN = RACKOUT, Delay time = 60, Trigger = 15 SIMOV867A = 100, Delay time = 300, Ramp = 90, Trigger = 15 and/or SIMOV867B_RACKIN = RACKOUT, Delay time = 90, Trigger = 16 SIMOV867B = 100, Delay time = 400, Ramp = 90, Trigger = 16 If sent to open BIT valves locally WITHOUT de-energizing them then wait 5 minutes and then one at a time (as required) change the rates using the monitor screen:

SET SIMOV867_RATE(1) = 450 SET SIMOV867_RATE(2) = 450 The scenario may be terminated after the crew isolates the leak, or as directed by the lead examiner.

COMMUNICATIONS If sent to Safeguards, wait ~2 minutes and then report that door is hot. (If leak has already been isolated can report that there was a loud noise, but it has now stopped.)

When sent to manually open one of the BIT inlet valves use instructions above and report back when requested valve has been opened. (when timer has timed out)

If asked about cask drying for 0-AP-5.2: No cask drying is occurring.

2014 NRC 2 Page 34 Revision 0

ATTACHMENT 3 SCENARIO PERFORMANCE OBJECTIVES 2014 NRC 2 Page 35 Revision 0

EVENT 1 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power and a transfer of boric acid from "B" BAST to "A" BAST is required, the RO will transfer acid in accordance with 0-OP-8.8, "Transferring Boric Acid."

NORTH ANNA SPECIFIC TASKS:

None CRITICAL TASK:

N/A 2014 NRC 2 Page 36 Revision 0

EVENT 2 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at 50% power and a power increase to 100% is desire, the crew will increase power in accordance with 1-OP-2.1, "Unit Operation from Mode 2 to Mode 1."

NORTH ANNA SPECIFIC TASKS:

None CRITICAL TASK:

N/A 2014 NRC 2 Page 37 Revision 0

EVENT 3 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power, and the PRZR PORV has failed open and will not close, the crew will be expected to respond in accordance with 1-AP-44, "Loss of Reactor Coolant System Pressure."

NORTH ANNA SPECIFIC TASKS:

R634 Respond to a loss of Reactor Coolant System pressure.

CRITICAL TASK:

See next page 2014 NRC 2 Page 38 Revision 0

CT Statement:

Crew stops RCS pressure decrease.

Safety Significance:

Failure to close the block MOV under the postulated plant conditions constitutes "mis-operation or incorrect crew performance, which leads to degradation of any barrier to fission product release." The RCS fission product barrier can be restored to full integrity simply by closing the block MOV. Therefore, failure to close the MOV also represents a "demonstrated inability by the crew to take an action or combination of actions that would prevent a challenge to plant safety."

Cues:

Indication/annunciation of:

• RCS pressure decrease, and

• PRZR PORV open, and

• associated block MOV open Performance Indicator:

RO closes PORV block valve 1-RC-MOV-1535.

Feedback:

RCS pressure decrease stopped.

WOG

Reference:

Appendix B CT-10.

Conditions:

Prior to a PRZR low pressure reactor trip.

2014 NRC 2 Page 39 Revision 0

EVENT 4 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power, and the main generator voltage regulator has failed, the crew will be expected to respond in accordance with 1-AP-26, "Loss of Main Generator Voltage Control."

NORTH ANNA SPECIFIC TASKS:

R675 Respond to a failure of main generator voltage regulator high.

CRITICAL TASK:

N/A 2014 NRC 2 Page 40 Revision 0

EVENT 5 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power and a steam dump has failed open, the crew will be expected to respond in accordance with 1-AP-38, "Excessive Load Increase."

NORTH ANNA SPECIFIC TASKS:

R539 Perform the immediate operator actions in response to an excessive load increase CRITICAL TASK:

See Next page 2014 NRC 2 Page 41 Revision 0

CT Statement:

Crew stops power increase.

Safety Significance:

Failure to stop power increase and coolant temperature decrease would cause average coolant temperature to drop below the minimum temperature for criticality, and the following can not be assured: 1) Moderator temperature coefficient is within its analyzed temperature range, 2) Protective instrumentation is within its normal operating range, 3) P-12 interlock is above its setpoint, and 4) Compliance with Appendix G to 10 CFR part 50.

Cues:

Indication of power increase:

• Reactor power increasing.

• Steam flow increasing.

• Megawatts decreasing Performance Indicator:

RO places both steam dump interlock switches to off/reset.

Feedback:

Reactor power increase stopped Steam dumps indicate closed Steam flow decreased WOG

Reference:

None Conditions:

Prior to receiving an automatic reactor trip on over power.

2014 NRC 2 Page 42 Revision 0

EVENT 6 PERFORMANCE OBJECTIVES EVENT GOAL: Given the plant is in mode one with indications of a failed steam pressure transmitter, the crew will respond in accordance with 1-AP-3, "Loss of Vital Instrumentation."

NORTH ANNA SPECIFIC TASKS:

R626 Respond to a steam generator water level control channel failure.

CRITICAL TASK:

N/A 2014 NRC 2 Page 43 Revision 0

EVENT 7 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the generator output breaker has opened causing a reactor trip, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection."

NORTH ANNA SPECIFIC TASKS:

R185 Perform the immediate operator actions in response to a reactor trip or safety injection CRITICAL TASK:

N/A 2014 NRC 2 Page 44 Revision 0

EVENT 8 PERFORMANCE OBJECTIVES EVENT GOAL: With the unit stabilized in 1-ES-0.1, "Reactor Trip Response," and indications exist of a SBLOCA outside containment, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection," and 1-ECA-1.2, "LOCA Outside Containment."

NORTH ANNA SPECIFIC TASKS:

R520 Respond to increasing primary plant leakage.

R730 Verify safety injection flow R761 Respond to a LOCA outside containment.

CRITICAL TASK:

See following pages 2014 NRC 2 Page 45 Revision 0

CT Statement:

Crew aligns Charging pumps.

Safety Significance:

Failure to establish HHSI flow constitutes a "mis-operation or incorrect crew performance which leads to degraded ECCS capacity."

Cues:

Indication/annunciation of:

• reactor trip and safety injection

• no SI flow

• BIT inlet valves closed Performance Indicator:

RO manually opens 1-SI-MOV-1836.

Feedback:

HHSI flow to the cold legs is indicated.

WOG

Reference:

Based on Appendix B CT-7 Conditions:

Direction is given prior to exiting 1-E-0 after safety injection initiated.

2014 NRC 2 Page 46 Revision 0

CT Statement:

Crew isolates LOCA outside containment.

Safety Significance:

Failure to isolate a LOCA outside containment (that can be isolated) degrades containment integrity beyond the level of degradation irreparably by the postulated conditions. It also constitutes a "mis-operation or incorrect crew performance which leads to degradation of a barrier to fission product release" and eventually "to degraded ECCS capacity.

Cues:

Indication/annunciation that SI is actuated and is required AND Indication and/or annunciation of abnormally high temperature in the safeguards building AND Indication and/or annunciation of abnormally high sump level in the safeguards building Performance Indicator:

Crew closes LHSI pump Cold Leg Injection valves.

1-SI-MOV-1890C 1-SI-MOV-1890D Feedback:

RCS pressure increasing.

WOG

Reference:

Appendix B CT-32 Conditions:

Before exiting 1-ECA-1.2 2014 NRC 2 Page 47 Revision 0

ATTACHMENT 2 SIMULATOR PERFORMANCE DATASHEET

Scenario Performance Datasheet EVENT 1: Given that the unit is at power and a transfer of boric acid from "B" BAST to "A" BAST is required, the RO will transfer acid in accordance with 0-OP-8.8, "Transferring Boric Acid."

SPD Verified: __________ (Initials)

• "B" BAST level decreases

• "A" BAST level increases EVENT 2: Given that the unit is at 50% power and a power increase to 100% is desire, the crew will increase power in accordance with 1-OP-2.1, "Unit Operation from Mode 2 to Mode 1."

SPD Verified: __________ (Initials)

• Reactor power increases

• Turbine power increases

• Tavg/Tref increase

• Generator megawatts increase EVENT 3: Given that the unit is at power, and the PRZR PORV has failed open and will not close, the crew will be expected to respond in accordance with 1-AP-44, "Loss of Reactor Coolant System Pressure."

SPD Verified: __________ (Initials)

• Annunciators C-D1, B-F7, B-E7, B-H6, and B-H2 are illuminated

• 1-RC-PCV-1456 indicates open

• 1-RC-PCV-1456 will not close EVENT 4: Given that the unit is at power, and the main generator voltage regulator has failed, the crew will be expected to respond in accordance with 1-AP-26, "Loss of Main Generator Voltage Control."

SPD Verified: __________ (Initials)

• Annunciator K-C1 illuminates

• Annunciator K-B4 may illuminate

• Generator output voltage increases EVENT 5: Given that the unit is at power and a steam dump has failed open, the crew will be expected to respond in accordance with 1-AP-38, "Excessive Load Increase."

SPD Verified: __________ (Initials)

• "C" steam dump shows mid-position

• Reactor power increases slightly (until dump is closed)

• Tave decreases slightly (until dump is closed)

• Megawatts decrease slightly (until dump is closed) 2014 NRC 2 Date _________ Revision 0

Scenario Performance Datasheet EVENT 6: Given the plant is in mode one with indications of a failed steam pressure transmitter, the crew will respond in accordance with 1-AP-3, "Loss of Vital Instrumentation."

SPD Verified: __________ (Initials)

• Annunciators F-H1 illuminates

• Status light N-C3 and N-C4 illuminate

• 1-MS-PI-1475 fails down scale

• 1-MS-FI-1474 fails down scale

• "A" MFRV demand decreases EVENT 7: Given that the generator output breaker has opened causing a reactor trip, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection."

SPD Verified: __________ (Initials)

• G-12 opens

• Reactor and turbine trips occur EVENT 8: With the unit stabilized in 1-ES-0.1, "Reactor Trip Response," and indications exist of a SBLOCA outside containment, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection," and 1-ECA-1.2, "LOCA Outside Containment."

SPD Verified: __________ (Initials)

• RCS pressure and pressurizer level decrease

• Charging flow increases

• Annunciators A-C1, E-F8, then A-C4 illuminate

• Annunciator B-F8 may also illuminate

• Vent stack "B" radiation increases to alarm setpoint

• BIT inlet valves fail to open 2014 NRC 2 Date _________ Revision 0

SCENARIO TURNOVER SHEET Read the following to the crew:

Purpose: This examination is intended to evaluate the crews performance of various tasks associated with the Initial License Operator Training Program. All activities should be completed in accordance with approved operations standards.

1. You are on a day shift during the week.

2. A rough log should be maintained to aid in making reports and to help during briefs.

3. Respond to what you see. In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated and the crew informed.

Unit Status:

Unit 1 is at 49% power. Unit was returned to power 2 days ago following work on the generator exciter. Power has been at 49% for several days due to a problem with a containment sump pump. The sump pump has been replaced and the unit as been cleared to increase power to 100%. RCS boron is 1537 ppm and core age is 150 MWD/MTU.

Aux steam is on unit 2.

Unit 2 is at 100% power.

Equipment Status:

1-FW-P-2 was returned to service last shift. Maintenance rule window is green. 2-CC-P-1B was tagged out last shift for major maintenance. It is expected to be out for several more days. Protected train is 2H.

Shift Orders:

Shift orders are to increase "A" BAST level to 90% by transferring acid from "B" BAST to "A" BAST and then ramp the unit to 100% power.

Please prebrief the acid transfer and the unit ramp.

The RO has been designated to do the acid transfer.

The auxiliary building operator has been prebriefed to perform his actions in 0-OP-8.8.

He is standing by in the auxiliary building.

Rods are currently at 160 steps on "D" bank RCS boron is 1537 ppm Time in life is 150 MWD/MTU Tavg is 562°F Tref is 561 °F The reactor engineer has determined that it will take approximately 3050 gallons of water to reach 100% power, ARO.

• • • A Non-Controlled Document ***

Unit 1 OATC Protected This Sheet updated on: Today 2H Power: 49 GV Position 9  % BLOWDOWNS Boron: 1,537 ppm TURBINE REF: 46.6 1.0% on limiter CD: 2 GPM Dilutions: 1-3 7 gal 'A' BAST: 14,043 ppm SW: secured PG/°F Change: 36 Gls. IN PIPE: PG BC: Secured on U-1 BA/°F Change: 4.4 Gls. CATION BED: Secured S/G: Hi cap 60/60/60 BLEND RATIO: 8.1 to 1 Aux Stm Supply: U2 2nd PT Approximate 1-RC-PCV-1444J 56 % 1-RC-LCV-1459G 39 %

Outputs 1-CH-PCV-1145 80 % 1-CC-TCV-106 27 %

Limiting Actions: None Items Tagged: 2-CC-P-1B Items OOC:

Annunciators Lit 1-LOG-14:

Problems/OWA:

OD's OD-555: 1H EDG Mech Stop (Mushroom) Pushbutton may not work to stop 1H EDG OD-542: AFW Pipe Tunnel Missile Protection ODM's ODM-309: B&C RCP seals, < 0.8 seal leakoff (AR 1C-G8), PG < 90 °, RCS@175 ppm MISC Maintain VCT Pressure < 35 psig per Chemistry request 1-FW-P-2 returned to operable last shift. Previously tagged for work on governor valve.

Open Procedures:

PT's Days: PT's Nights:

Normal Nightlies

Reactivity Worksheet This calculation made on: Sunday June 1, 2014 13:54:34 Cycle Data file: N1C24 Cycle Data Updated: 9/25/2013 Core Burnup 150.0 MWD/MTU PG (blend)

RCS Cb 1,537 ppm 75 gpm BAST Cb 14,043 ppm 5.00 pot ITC -6.3 pcm/°F Boric Acid (blend)

PC -10.9 pcm/% 9.2 gpm Boron Coefficient -5.75 pcm/ppm 4.61 pot (ITEM 1) = ITC/Boron Coefficient = 1.10 ppm/°F (ITEM 2) = PC/Boron Coefficient = 1.90 ppm/%

PG needed to raise RCS temperature 1ºF*

50455.4

• ln (RCS CB/(RCS CB - ITEM 1)) 36 gallons of PG Boron needed to lower RCS temperature 1ºF 50455.4

• ln ((BAST CB - RCS CB) / (BAST CB - (RCS CB + ITEM 1)) 4.4 gallons of acid PG needed to raise Reactor Power 1%*

50455.4

• ln (RCS CB/(RCS CB - ITEM 2)) 62 gallons of PG Boron needed to lower Reactor Power 1%

50455.4

• ln ((BAST CB - RCS CB) / (BAST CB - (RCS CB + ITEM 2)) 7.7 gallons of acid BLEND RATIO CALCULATION (BAST CB - RCS CB) / RCS CB 8.1 to 1 ratio

• Denotes Calculations that have been corrected for B-10 RCS Makeup Table PG BA PG BA PG BA 120 gpm 14.7 gpm 80 gpm 9.8 gpm 40 gpm 4.9 gpm 8.00 pot 7.37 pot 5.33 pot 4.92 pot 2.67 pot 2.46 pot PG BA PG BA PG BA 110 gpm 13.5 gpm 70 gpm 8.6 gpm 30 gpm 3.7 gpm 7.33 pot 6.76 pot 4.67 pot 4.30 pot 2.00 pot 1.84 pot PG BA PG BA PG BA 100 gpm 12.3 gpm 60 gpm 7.4 gpm 20 gpm 2.5 gpm 6.67 pot 6.15 pot 4.00 pot 3.69 pot 1.33 pot 1.23 pot PG BA PG BA PG BA 90 gpm 11.1 gpm 50 gpm 6.1 gpm 10 gpm 1.2 gpm 6.00 pot 5.53 pot 3.33 pot 3.07 pot 0.67 pot 0.61 pot Prepared:________ Reviewed:________

Page 1 of 1 49% power reactivity sheet.xls

PROCEDURE NO:

0-OP-8.8 REVISION NO:

NORTH ANNA POWER STATION 10 PROCEDURE TYPE: UNIT NO:

OPERATING PROCEDURE 1&2 PROCEDURE TITLE:

TRANSFERRING BORIC ACID RX MAN REVISION

SUMMARY

FrameMaker template Rev. 030.

• Incorporated DCP 03-159, Boric Acid and PG Water Flow to Blender Integrator Modification / Unit 1. Added Reference 2.3.21. Added step 5.5.9.f, 5.5.15.b, and 5.5.17.b to operate the Unit 1 integrators.

PROBLEMS ENCOUNTERED: NO YES Note: If YES, note problems in remarks.

COMMON REMARKS: ________________________________________________________________________________________________

_________________________________________________________________________________________________________

_________________________________________________________________________________________________________

_________________________________________________________________________________________________________

_________________________________________________________________________________________________________

______________________________________________________________________________ (Use back for additional remarks.)

SRO: DATE:

CONTINUOUS USE

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 2 of 44 TABLE OF CONTENTS Section Page 1.0 PURPOSE 3

2.0 REFERENCES

4 3.0 INITIAL CONDITIONS 6 4.0 PRECAUTIONS AND LIMITATIONS 7 5.0 INSTRUCTIONS 8 5.1 Transferring Boric Acid From B BAST To The A Or C BAST 8 5.2 Transferring Boric Acid From A BAST To B BAST 13 5.3 Transferring Boric Acid From C BAST To B BAST 17 5.4 Transferring The Contents Of A, B, Or C BAST To The High Level Liquid Waste Tanks 21 5.5 Transferring The Contents Of A, B, Or C BAST To The Boron Recovery Tanks 27 ATTACHMENTS 1 Cross Connect Valve Lineup 41

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 3 of 44 1.0 PURPOSE To provide instructions for transferring boric acid.

The following synopsis is designed as an aid to understanding the procedure, and is not intended to alter or take the place of the actual purpose, instructions, or text of the procedure itself.

This procedure provides instructions for transferring boric acid. If a Boric Acid Storage Tank must be transferred due to increasing level, the Tank should be sampled to verify an unexpected dilution of the Tank is not occurring.

This procedure formerly contained a Section for swapping Boric Acid Storage Transfer Pump alignments. This Section has been deleted and replaced by the following individual procedures for each alignment option:

By procedure number:

• 0-OP-8.10, Alignment of 1-CH-P-2A on A Boric Acid Storage Tank To Unit 1

• 0-OP-8.11, Alignment of 1-CH-P-2B on B Boric Acid Storage Tank For Recirc Only

• 0-OP-8.12, Alignment of 1-CH-P-2C on B Boric Acid Storage Tank For Recirc Only

• 0-OP-8.13, Alignment of 1-CH-P-2D on C Boric Acid Storage Tank To Unit 2

• 0-OP-8.14, Alignment of 1-CH-P-2A on B Boric Acid Storage Tank To Unit 1

• 0-OP-8.15, Alignment of 1-CH-P-2B on A Boric Acid Storage Tank To Unit 1

• 0-OP-8.16, Alignment of 1-CH-P-2B on B Boric Acid Storage Tank To Unit 1

• 0-OP-8.17, Alignment of 1-CH-P-2C on B Boric Acid Storage Tank To Unit 2

• 0-OP-8.18, Alignment of 1-CH-P-2D on B Boric Acid Storage Tank To Unit 2

• 0-OP-8.19, Alignment of 1-CH-P-2C on C Boric Acid Storage Tank To Unit 2

• 0-OP-8.20, Alignment of 1-CH-P-2A on A Boric Acid Storage Tank For Recirc Only

• 0-OP-8.21, Alignment of 1-CH-P-2D on C Boric Acid Storage Tank For Recirc Only

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 4 of 44 By pump number:

• 0-OP-8.10, Alignment of 1-CH-P-2A on A Boric Acid Storage Tank To Unit 1

• 0-OP-8.14, Alignment of 1-CH-P-2A on B Boric Acid Storage Tank To Unit 1

• 0-OP-8.20, Alignment of 1-CH-P-2A on A Boric Acid Storage Tank For Recirc Only

• 0-OP-8.11, Alignment of 1-CH-P-2B on B Boric Acid Storage Tank For Recirc Only

• 0-OP-8.15, Alignment of 1-CH-P-2B on A Boric Acid Storage Tank To Unit 1

• 0-OP-8.16, Alignment of 1-CH-P-2B on B Boric Acid Storage Tank To Unit 1

• 0-OP-8.12, Alignment of 1-CH-P-2C on B Boric Acid Storage Tank For Recirc Only

• 0-OP-8.17, Alignment of 1-CH-P-2C on B Boric Acid Storage Tank To Unit 2

• 0-OP-8.19, Alignment of 1-CH-P-2C on C Boric Acid Storage Tank To Unit 2

• 0-OP-8.13, Alignment of 1-CH-P-2D on C Boric Acid Storage Tank To Unit 2

• 0-OP-8.18, Alignment of 1-CH-P-2D on B Boric Acid Storage Tank To Unit 2

• 0-OP-8.21, Alignment of 1-CH-P-2D on C Boric Acid Storage Tank For Recirc Only By tank number:

• 0-OP-8.10, Alignment of 1-CH-P-2A on A Boric Acid Storage Tank To Unit 1

• 0-OP-8.15, Alignment of 1-CH-P-2B on A Boric Acid Storage Tank To Unit 1

• 0-OP-8.20, Alignment of 1-CH-P-2A on A Boric Acid Storage Tank For Recirc Only

• 0-OP-8.11, Alignment of 1-CH-P-2B on B Boric Acid Storage Tank For Recirc Only

• 0-OP-8.12, Alignment of 1-CH-P-2C on B Boric Acid Storage Tank For Recirc Only

• 0-OP-8.14, Alignment of 1-CH-P-2A on B Boric Acid Storage Tank To Unit 1

• 0-OP-8.16, Alignment of 1-CH-P-2B on B Boric Acid Storage Tank To Unit 1

• 0-OP-8.17, Alignment of 1-CH-P-2C on B Boric Acid Storage Tank To Unit 2

• 0-OP-8.18, Alignment of 1-CH-P-2D on B Boric Acid Storage Tank To Unit 2

• 0-OP-8.13, Alignment of 1-CH-P-2D on C Boric Acid Storage Tank To Unit 2

• 0-OP-8.19, Alignment of 1-CH-P-2C on C Boric Acid Storage Tank To Unit 2

• 0-OP-8.21, Alignment of 1-CH-P-2D on C Boric Acid Storage Tank For Recirc Only

2.0 REFERENCES

2.1 Source Documents 2.1.1 UFSAR Section 4.3.2.5.1, Chemical Poison

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 5 of 44 2.2 Technical Specifications 2.2.1 TRM TR 3.1.1 2.2.2 TRM TR 3.1.2 2.3 Technical References 2.3.1 WATS 88-07, Surry LER-S2/88-008 2.3.2 11715 FM-95A, Chemical And Volume Control System 2.3.3 11715 FM-95B, Chemical And Volume Control System 2.3.4 11715-FM-86A, Boron Recovery System 2.3.5 11715-FM-87D, Liquid Waste System 2.3.6 11715-FM-88A, Refueling Purification System 2.3.7 12050-FM-95B, Chemical and Volume Control System 2.3.8 1-SC-5.18, Boric Acid Solubility vs Temperature 2.3.9 1-SC-5.22, High and Low Level Waste Drain Tanks 1-LW-TK-2A, B,-3A, B 2.3.10 1-SC-5.3, Boric Acid Tanks 1-CH-TK-1A, B, C 2.3.11 0-OP-16.1, Spent Fuel Pool Cooling And Purification System 2.3.12 1-OP-16.2, Unit 1 Reactor Cavity Purification 2.3.13 1-OP-16.4, Purification of Unit 1 Refueling Water Storage Tank 2.3.14 2-OP-16.2, Unit 2 Reactor Cavity Purification 2.3.15 2-OP-16.4, Purification of Unit 2 Refueling Water Storage Tank 2.3.16 1-OP-8.3, Boron Concentration Control 2.3.17 2-OP-8.3, Boron Concentration Control

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 6 of 44 2.3.18 DCP 01-008, Phase 2 PCS Installation and P-250 Removal - Unit 2 2.3.19 DCP 01-007, Phase 2 PCS Installation and P-250 Removal - Unit 1 2.3.20 DCP 03-160, Boric Acid and PG Water Flow to Blender Integrator Modification/NAPS/Unit 2 2.3.21 DCP 03-159, Boric Acid and PG Water Flow to Blender Integrator Modification / NAPS / Unit 1 2.4 Commitment Documents 2.4.1 CTS Assignment 02-94-0500, Commitment 002, Independent Control Switch Verification 2.4.2 CTS Assignment 02-90-2166, Commitment 001, Revise appropriate procedures to complete batching with the pumps in slow speed, time batching operation and use this time to control pump operation time during batch transfers to prevent pump cavitation and prevent operation of the pumps in fast speed with PG supplied to the pump suction.

2.4.3 Plant Issue N-2003-0800, Grating Slipped from Hand and Hit Operator 2.4.4 SAA009529; SAR000956: Reactivity Management 3.0 INITIAL CONDITIONS 3.1 Review the equipment status to verify station configuration supports the performance of this procedure.

3.2 The Heat Tracing System is in service for all piping and tanks that may be exposed to concentrated boric acid solution.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 7 of 44 4.0 PRECAUTIONS AND LIMITATIONS 4.1 Comply with the following guidelines when marking steps N/A:

• IF the conditional requirements of a step do not require the action to be performed, THEN mark the step N/A

• IF any other step is marked N/A, THEN have the SRO (or designee) approve the N/A and justify the N/A on the Procedure Cover Sheet 4.2 All operations should be performed in accordance with RWPs. Every effort should be made to maximize personnel safety while minimizing personnel exposure and area contamination, both surface and airborne. ALARA concepts should be used.

4.3 The time that a boric acid pump is stopped MUST be minimized unless it is the standby pump.

4.4 The Recirculation hand control valve for the boric acid pump and tank in service should be positioned in a manner to allow for sufficient recirculation flow for pump heat removal, but not so open that proper flow of boric acid, when in the emergency borate mode, would be hindered.

4.5 Minimize the time that a Boric Acid Transfer Pump is operated in FAST speed. This will prevent excessive shaft deflection and limit the wear on the seal face of the pump. (Reference 2.4.2) 4.6 WHEN transferring boric acid to the BASTs, THEN the appropriate unit OATC should monitor tank level to avoid receiving the Hi level alarm at 93%.

4.7 The following Tech Specs apply:

• TRM 3.1.1, Boration Flow Paths - Operating

• TRM 3.1.2, Boration Flow Paths - Shutdown

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 8 of 44 Init Verif 5.0 INSTRUCTIONS 5.1 Transferring Boric Acid From B BAST To The A Or C BAST

_______ 5.1.1 Verify Initial Conditions are satisfied.

_______ 5.1.2 Review Precautions and Limitations.

NOTE: This procedure could cause the B BAST to be pumped below Tech Spec level. SRO permission is required to perform this procedure and Tech Spec actions must be entered as required.

_______ 5.1.3 IF B BAST is in service to Unit 1 OR Unit 2, THEN obtain SRO approval for this transfer.

5.1.4 IF B BAST is in standby AND it is desired to transfer to the A BAST, THEN open the following valves:

_______

• 1-CH-95, Unit 1 BA Fltr Recirc to 1B Boric Acid Tk Isol Vv

_______

• 1-CH-HCV-1110, BORIC ACID TK A RECIRC VALVE CONT 5.1.5 IF B BAST is in service to Unit 1 AND it is desired to transfer to the A BAST, THEN open the following valves:

_______

• 1-CH-96, Unit 1 BA Fltr Recirc to 1A Boric Acid Tk Isol Vv

_______

• 1-CH-HCV-1110, BORIC ACID TK A RECIRC VALVE CONT

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 9 of 44 5.1.6 IF B BAST is in standby AND it is desired to transfer to C BAST, THEN open the following valves:

_______

• 1-CH-137, Unit 2 BA Fltr Recirc to 1B Boric Acid Tk Isol Vv

_______

• 1-CH-HCV-1104, BORIC ACID RECIRC FLOW 5.1.7 IF B BAST is in service to Unit 2 AND it is desired to transfer to C BAST, THEN open the following valves:

_______

• 1-CH-136, Unit 2 BA Fltr Recirc to 1C Boric Acid Tk Isol Vv

_______

• 1-CH-HCV-1104, BORIC ACID RECIRC FLOW

_______ 5.1.8 Close 1-CH-HCV-1105, BORIC ACID TK B RECIRC VALVE CONT.

_______ 5.1.9 Review transfer termination criteria:

• IF B BAST is in service to Unit 1 or Unit 2 with the Unit in Mode 1-4, THEN level should be maintained above 71% to prevent entry into the Action Statement of TRM 3.1.1.

• IF B BAST is in service to Unit 1 or Unit 2 with the Unit in Mode 5 or 6, THEN level should be maintained above 5% to prevent entry into the Action Statement of TRM 3.1.2.

• Level in A or C BAST should not exceed 98%, to prevent overflow.

5.1.10 Place the control switch for the transfer pump aligned to the B BAST in FAST. Mark the remaining pump N/A:

_______

• 1-CH-P-2B, B Boric Acid Storage Transfer Pump

_______

• 1-CH-P-2C, C Boric Acid Storage Transfer Pump

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 10 of 44 5.1.11 WHEN the transfer is complete, THEN do the following:

a. Place the control switch for the transfer pump aligned to the B BAST in OFF. Mark the remaining pump N/A:

_______

• 1-CH-P-2B, B Boric Acid Storage Transfer Pump

_______

• 1-CH-P-2C, C Boric Acid Storage Transfer Pump

_______ b. Open 1-CH-HCV-1105, Boric Acid Tk B Recirc Valve Cont, to 20%.

_______ c. IF B BAST is in standby AND transfer was to the A BAST, THEN close 1-CH-95, Unit 1 BA Fltr Recirc to 1B Boric Acid Tk Isol Vv.

_______ d. IF B BAST is in service to Unit 1 AND transfer was to the A BAST, THEN close 1-CH-96, Unit 1 BA Fltr Recirc to 1A Boric Acid Tk Isol Vv.

_______ e. IF B BAST is in standby AND transfer was to C BAST, THEN close 1-CH-137, Unit 2 BA Fltr Recirc to 1B Boric Acid Tk Isol Vv.

_______ f. IF B BAST is in service to Unit 2 AND transfer was to the C BAST, THEN close 1-CH-136, Unit 2 BA Fltr Recirc to 1C Boric Acid Tk Isol Vv.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 11 of 44 5.1.12 Place the control switch for the transfer pump that is aligned to B BAST in the required position:

a. IF B BAST is in standby, THEN place control switch in SLOW. Mark the remaining pump N/A: (Reference 2.4.1)

_______ _______

• 1-CH-P-2B, B BORIC ACID STORAGE TRANSFER PUMP

_______ _______

• 1-CH-P-2C, C BORIC ACID STORAGE TRANSFER PUMP

b. IF B BAST is in service, THEN place control switch in AUTO. Mark the remaining pump N/A: (Reference 2.4.1)

_______ _______

• 1-CH-P-2B, B Boric Acid Storage Transfer Pump

_______ _______

• 1-CH-P-2C, C Boric Acid Storage Transfer Pump 5.1.13 Verify the level of the affected BAST is stable. Mark the remaining indicators N/A:

_______

• 1-CH-LI-1106, 1A Boric Acid Tank Level Indicator

_______

• 1-CH-LI-1161, 1A Boric Acid Tank Level Indicator

_______

• 1-CH-LI-1102, 1C Boric Acid Tank Level Indicator

_______

• 1-CH-LI-1165, 1C Boric Acid Tank Level Indicator

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 12 of 44 5.1.14 Align the affected BAST for sampling as follows:

a. Ensure the control switch(es) for the on-service pump(s) is(are) in AUTO. Mark the remaining pumps N/A: (Reference 2.4.2)

_______

• 1-CH-P-2A, A Boric Acid Storage Transfer Pump

_______

• 1-CH-P-2B, B Boric Acid Storage Transfer Pump

_______

• 1-CH-P-2C, C Boric Acid Storage Transfer Pump

_______

• 1-CH-P-2D, D Boric Acid Storage Transfer Pump

b. Adjust the recirc valve for the affected BAST to 20%. Mark the remaining valve N/A:

_______

• 1-CH-HCV-1110, Boric Acid Tk A Recirc Valve Cont

_______

• 1-CH-HCV-1104, Boric Acid Tk C Recirc Valve

_______ c. Have Chemistry Department sample the affected BAST.

Completed by: ___________________________________________ Date: _________

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 13 of 44 5.2 Transferring Boric Acid From A BAST To B BAST

_______ 5.2.1 Verify Initial Conditions are satisfied.

_______ 5.2.2 Review Precautions and Limitations.

NOTE: This procedure could cause the A BAST to be pumped below Tech Spec level. SRO permission is required to perform this procedure and Tech Spec actions must be entered as required.

_______ 5.2.3 Obtain SRO approval for this transfer.

5.2.4 IF the A BAST is in service to Unit 1, THEN open the following:

_______

• 1-CH-95, Unit 1 BA Fltr Recirc to 1B Boric Acid Tk Isol Vv

_______

• 1-CH-HCV-1105, BORIC ACID TK B RECIRC VALVE CONT 5.2.5 IF 1-CH-P-2A is running on the A BAST for RECIRC ONLY, THEN open the following:

_______

• 1-CH-96, Unit 1 BA Fltr Recirc to 1A Boric Acid Tk Isol Vv

_______

• 1-CH-HCV-1105, Boric Acid Tk B Recirc Valve Cont

_______ 5.2.6 Close 1-CH-HCV-1110, Boric Acid Tk A Recirc Valve Cont.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 14 of 44

_______ 5.2.7 Review transfer termination criteria:

• IF A BAST is in service to Unit 1 with the Unit in Mode 1-4, THEN level should be maintained above 71% to prevent entry into the Action Statement of TRM 3.1.1.

• IF A BAST is in service to Unit 1 with the Unit in Mode 5 or 6, THEN level should be maintained above 5% to prevent entry into the Action Statement of TRM 3.1.2.

• Level in B BAST should not exceed 98%, to prevent overflow.

5.2.8 Place the control switch for the transfer pump aligned to the A BAST in FAST. Mark the remaining pump N/A:

_______

• 1-CH-P-2A, A Boric Acid Storage Transfer Pump

_______

• 1-CH-P-2B, B Boric Acid Storage Transfer Pump 5.2.9 When transfer is complete, THEN place the transfer pump aligned to the A BAST in OFF. Mark the remaining pump N/A:

_______

• 1-CH-P-2A, A Boric Acid Storage Transfer Pump

_______

• 1-CH-P-2B, B Boric Acid Storage Transfer Pump

_______ 5.2.10 Adjust 1-CH-HCV-1110, Boric Acid Tk A Recirc Valve Cont, to 20%.

_______ 5.2.11 IF A BAST is in service to Unit 1, THEN close 1-CH-95, Unit 1 BA Fltr Recirc to 1B Boric Acid Tk Isol Vv.

_______ 5.2.12 IF 1-CH-P-2A is aligned to the A BAST for RECIRC ONLY, THEN close 1-CH-96, Unit 1 BA Fltr Recirc to 1A Boric Acid Tk Isol Vv.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 15 of 44 5.2.13 Align the transfer pumps as follows:

a. IF in service to Unit 1, THEN place the control switch for the transfer pump aligned to A BAST in AUTO. Mark the remaining pump N/A:

(Reference 2.4.1)

_______ _______

• 1-CH-P-2A, A Boric Acid Storage Transfer Pump

_______ _______

• 1-CH-P-2B, B Boric Acid Storage Transfer Pump

_______ _______ b. IF 1-CH-P-2A, A BORIC ACID STORAGE TRANSFER PUMP, is aligned for RECIRC ONLY, THEN place the control switch in SLOW.

(Reference 2.4.1) 5.2.14 Verify the level of B BAST is stable:

_______

• 1-CH-LI-1108, 1B Boric Acid Tank Level Indicator

_______

• 1-CH-LI-1163, 1B Boric Acid Tank Level Indicator 5.2.15 Align B BAST for sampling as follows:

_______ _______ a. IF 1-CH-P-2B is aligned to B BAST in service to Unit 1, THEN place control switch in AUTO. (Reference 2.4.1)

b. IF B BAST is aligned for recirc only, THEN ensure the control switch for the pump aligned to B BAST is in SLOW. Mark the remaining pump N/A:

_______ _______

• 1-CH-P-2B, Boric Acid Storage Transfer Pump

_______ _______

• 1-CH-P-2C, C Boric Acid Storage Transfer Pump

_______ c. Adjust 1-CH-HCV-1105, Boric Acid Tk B Recirc Valve Cont, to 20%.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 16 of 44

_______ d. Have Chemistry Department sample B BAST.

Completed by: ___________________________________________ Date: _________

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 17 of 44 5.3 Transferring Boric Acid From C BAST To B BAST

_______ 5.3.1 Verify Initial Conditions are satisfied.

_______ 5.3.2 Review Precautions and Limitations.

NOTE: This procedure could cause C BAST to be pumped below Tech Spec level.

SRO permission is required to perform this procedure and Tech Spec actions must be entered as required.

_______ 5.3.3 Obtain SRO approval for this transfer.

5.3.4 IF C BAST is in service to Unit 2, THEN open the following:

_______

• 1-CH-137, Unit 2 BA Fltr Recirc to 1B Boric Acid Tk Isol Vv

_______

• 1-CH-HCV-1105, BORIC ACID TK B RECIRC VALVE CONT 5.3.5 IF 1-CH-P-2D is running on C BAST for RECIRC ONLY, THEN open the following:

_______

• 1-CH-136, Unit 2 BA Fltr Recirc to 1C Boric Acid Tk Isol Vv

_______

• 1-CH-HCV-1105, Boric Acid Tk B Recirc Valve Cont

_______ 5.3.6 Close 1-CH-HCV-1104, Boric Acid Recirc Flow.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 18 of 44

_______ 5.3.7 Review transfer termination criteria:

• IF C BAST is in service to Unit 2 with the Unit in Mode 1-4, THEN level should be maintained above 71% to prevent entry into the Action Statement of TRM 3.1.1.

• IF C BAST is in service to Unit 2 with the Unit in Mode 5 or 6, THEN level should be maintained above 5% to prevent entry into the Action Statement of TRM 3.1.2.

• Level in B BAST should not exceed 98%, to prevent overflow.

5.3.8 Place the control switch for the transfer pump aligned to C BAST in FAST. Mark the remaining pump N/A:

_______

• 1-CH-P-2D, D Boric Acid Storage Transfer Pump

_______

• 1-CH-P-2C, C Boric Acid Storage Transfer Pump 5.3.9 When transfer is complete, THEN place the transfer pump aligned to C BAST in OFF. Mark the remaining pump N/A:

_______

• 1-CH-P-2D, D Boric Acid Storage Transfer Pump

_______

• 1-CH-P-2C, C Boric Acid Storage Transfer Pump

_______ 5.3.10 Adjust 1-CH-HCV-1104, Boric Acid Recirc Flow, to 20%.

_______ 5.3.11 IF C BAST is in service to Unit 2, THEN close 1-CH-137, Unit 2 BA Fltr Recirc to 1B Boric Acid Tk Isol Vv.

_______ 5.3.12 IF 1-CH-P-2D is aligned to C BAST for RECIRC ONLY, THEN close 1-CH-136, Unit 2 BA Fltr Recirc to 1C Boric Acid Tk Isol Vv.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 19 of 44 5.3.13 Align the transfer pumps as follows:

a. IF in service to Unit 2, THEN place the control switch for the transfer pump aligned to C BAST in AUTO. Mark the remaining pump N/A:

(Reference 2.4.1)

_______ _______

• 1-CH-P-2D, D Boric Acid Storage Transfer Pump

_______ _______

• 1-CH-P-2C, C Boric Acid Storage Transfer Pump

_______ _______ b. IF 1-CH-P-2D, D BORIC ACID STORAGE TRANSFER PUMP, is aligned for RECIRC ONLY, THEN place the control switch in SLOW.

(Reference 2.4.1) 5.3.14 Verify the level of B BAST is stable:

_______

• 1-CH-LI-1108, 1B Boric Acid Tank Level Indicator

_______

• 1-CH-LI-1163, 1B Boric Acid Tank Level Indicator 5.3.15 Align B BAST for sampling as follows:

_______ _______ a. IF 1-CH-P-2C is aligned to B BAST in service to Unit 2, THEN place control switch in AUTO. (Reference 2.4.1)

b. IF B BAST is aligned for recirc only, THEN ensure the control switch for the pump aligned to B BAST is in SLOW. Mark the remaining pump N/A:

_______ _______

• 1-CH-P-2B, Boric Acid Storage Transfer Pump

_______ _______

• 1-CH-P-2C, C Boric Acid Storage Transfer Pump

_______ c. Adjust 1-CH-HCV-1105, Boric Acid Tk B Recirc Valve Cont, to 20%.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 20 of 44

_______ d. Have Chemistry Department sample B BAST.

Completed by: ___________________________________________ Date: _________

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 21 of 44 5.4 Transferring The Contents Of A, B, Or C BAST To The High Level Liquid Waste Tanks

_______ 5.4.1 Verify Initial Conditions are satisfied.

_______ 5.4.2 Review Precautions and Limitations.

5.4.3 Have Chemistry sample the boron concentration (Cb) for the designated BAST and record results, date, and time below. Mark remaining BAST N/A:

_______

• Cb for A BAST:_______________ ppm

_______

• Cb for B BAST:_______________ ppm

_______

• Cb for C BAST:_______________ ppm

_______

• Date: _______________ Time: _______________

5.4.4 Have Chemistry sample the Initial Cb for the High Level Liquid Waste Tanks. Record results, date, and time below:

_______

• Initial Cb for HLLWT:_______________ ppm

_______

• Date: _______________ Time: _______________

5.4.5 Record the level in the following High Level Liquid Waste Tanks:

_______

• 1-LW-TK-2A level:_______________%

_______

• 1-LW-TK-2B level:_______________%

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 22 of 44 5.4.6 Using 1-SC-5.22, High And Low Level Waste Drain Tanks 1-LW-TK-2A, B,-3A, B, AND the values recorded in Step 5.4.5, determine the volumes of the following tanks. Record the volumes below:

_______

• 1-LW-TK-2A volume:_______________ gal

_______

• 1-LW-TK-2B volume:_______________ gal

_______ 5.4.7 Using the values determined in Step 5.4.6, calculate the TOTAL initial volume (H) of the High Level Liquid Waste Tanks. Record the volume below:

____________ gals. + ____________ gals. = ____________ gal 1-LW-TK-2A 1-LW-TK-2B H

_______ _______ 5.4.8 Determine the maximum allowable BAST volume (P) that may be transferred by completing the following calculation:

H 1n ---------------------- = P B-i B - 7500 Where:

H= TOTAL initial volume in gallons (Step 5.4.7)

B= Cb for the affected BAST in ppm (Step 5.4.3) i= Initial Cb for HLLWT in ppm (Step 5.4.4)

P= Maximum allowable BAST volume to be transferred in gallons

______ gals. 1n ----------------------------------------------------- = ______ gals.

ppm - ppm

______ - 7500 5.4.9 Determine minimum allowed BAST level due to Cb in the HLLWT:

_______ a. Record level in the BAST being transferred:_______%

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 23 of 44

_______ b. Using 1-SC-5.3, Boric Acid Tanks 1-CH-TK-1A, B, C, convert level in step 5.4.9.a to gallons: _________________ gal

_______ c. Subtract (P) from step 5.4.8 from the value in step 5.4.9.b:

____________ gal - ____________ gal = ____________ gal from step 5.4.9.b from step 5.4.8

_______ d. Using 1-SC-5.3, Boric Acid Tanks 1-CH-TK-1A, B, C, convert level in step 5.4.9.c to percent:_______%

CAUTION Boric Acid Storage Tank level should be closely monitored during the transfer evolution. Avoid entry into TRM action statements based on low level.

_______ 5.4.10 Review transfer termination criteria:

• IF the BAST being drained is in service to Unit 1 or Unit 2 with the Unit in Mode 1-4, THEN level should be maintained above 71% to prevent entry into the Action Statement of TRM 3.1.1.

• IF the BAST being drained is in service to Unit 1 or Unit 2 with the Unit in Mode 5 or 6, THEN level should be maintained above 5% to prevent entry into the Action Statement of TRM 3.1.2.

• Level in the HLLWT should not exceed 97%

• Level in the BAST being drained should be maintained above the minimum level calculated in step 5.4.9.d.

5.4.11 IF A BAST will be transferred to the High Level Liquid Waste Tanks, THEN do the following:

_______ a. Establish communications between the Auxiliary Building Operator located at 1-CH-67, 1A Boric Acid Tank Drain To High Lvl Waste Isol Vv, and the Unit 1 OATC.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 24 of 44

_______ b. Slowly open 1-CH-67.

_______ _______ c. WHEN the desired volume of the A BAST has been transferred OR any transfer termination criteria is met, THEN close 1-CH-67.

5.4.12 IF B BAST will be transferred to the High Level Liquid Waste Tanks, THEN do the following:

_______ a. Establish communications between the Auxiliary Building Operator located at 1-CH-108, 1B Boric Acid Tank Drain To High Lvl Waste Isol Vv, and the Unit 1 OATC.

_______ b. Slowly open 1-CH-108.

_______ _______ c. WHEN the desired volume of the B BAST has been transferred OR any transfer termination criteria is met, THEN close 1-CH-108.

5.4.13 IF C BAST will be transferred to the High Level Liquid Waste Tanks, THEN do the following:

_______ a. Establish communications between the Auxiliary Building Operator located at 1-CH-126, 1C Boric Acid Tank Drain To High Lvl Waste Isol Vv, and the Unit 2 OATC.

_______ b. Slowly open 1-CH-126.

_______ _______ c. WHEN the desired volume of the C BAST has been transferred OR any transfer termination criteria is met, THEN close 1-CH-126.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 25 of 44 5.4.14 Do the following to flush the BAST drain line with PG:

a. Verify the following valves are closed:

_______

• 1-CH-67, 1A Boric Acid Tank Drain To High Lvl Waste Isol Vv

_______

• 1-CH-108, 1B Boric Acid Tank Drain To High Lvl Waste Isol Vv

_______

• 1-CH-126, 1C Boric Acid Tank Drain To High Lvl Waste Isol Vv

_______ b. Close 1-CH-434, Boric Acid Batch Tank To High Lvl Waste Isol Vv.

_______ c. Connect a hose between 1-CH-435, Boric Acid Batch Tk Ovfl Hose Conn Isol Valve, and 1-PG-334, Primary Grade Water Hose Conn Isol Valve.

_______ d. Open 1-PG-334, Primary Grade Water Hose Conn Isol Valve.

CAUTION To ensure boron dilution does not occur through the loop seals, the Boric Acid Storage Tank levels should be closely monitored during the flushing evolution.

_______ e. Slowly open 1-CH-435, Boric Acid Batch Tk Ovfl Hose Conn Isol Valve.

_______ _______ f. WHEN a 1% to 2% level increase is observed in the High Level Liquid Waste Tanks, THEN close 1-PG-334, Primary Grade Water Hose Conn Isol Valve.

_______ _______ g. Open 1-CH-434, Boric Acid Batch Tank To High Lvl Waste Isol Vv, to drain hose to Batch Tank.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 26 of 44

_______ h. Break hose connection at 1-PG-334, Primary Grade Water Hose Conn Isol Valve, and drain hose to Batch Tank.

_______ _______ i. Close 1-CH-435, Boric Acid Batch Tk Ovfl Hose Conn Isol Valve.

_______ j. Remove the PG supply hose from 1-CH-435 and store the hose.

Completed by: ___________________________________________ Date: _________

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 27 of 44 5.5 Transferring The Contents Of A, B, Or C BAST To The Boron Recovery Tanks

_______ 5.5.1 Verify Initial Conditions are satisfied.

_______ 5.5.2 Review Precautions and Limitations.

5.5.3 Ensure all of the following conditions are met:

_______

• The BAST to be transferred is the on-service tank

_______

• The RP IX is available for service

_______

• Resin Transfer is not in progress

_______

• Resin Transfer lines have been flushed with PG to remove any resin fines 5.5.4 IF the RP system is in operation, THEN secure using the applicable procedure. Mark the procedures not used N/A:

_______

• 0-OP-16.1, Spent Fuel Pool Cooling And Purification System

_______

• 1-OP-16.2, Unit 1 Reactor Cavity Purification

_______

• 1-OP-16.4, Purification of Unit 1 Refueling Water Storage Tank

_______

• 2-OP-16.2, Unit 2 Reactor Cavity Purification

_______

• 2-OP-16.4, Purification of Unit 2 Refueling Water Storage Tank

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 28 of 44

_______ _______ 5.5.5 Complete Attachment 1, Cross Connect Valve Lineup.

_______ 5.5.6 Ensure 1-RP-127, Spent Fuel Pit Inlet Isolation Valve (Fuel Bldg SW Corner, under grating) is sealed closed. (Reference 2.4.3)

_______ 5.5.7 Remove seal and close 1-RP-128, Spent Fuel Pit Inlet Isolation Valve (Fuel Bldg SW Corner, under grating). (Reference 2.4.3) 5.5.8 Align RP system as follows:

_______ a. Close 1-RP-65, 1B Refueling Purification Filter Outlet Isol Valve.

_______ b. Open 1-RP-66, 1B Refuel Prfcn Fltr To RP Ion Exch Isol Valve.

_______ c. Close 1-RP-74, Refuel Prfcn Ion Exch To 1A RP Filter Isol Valve.

_______ d. Open 1-RP-68, Refueling Purification Ion Exch Inlet Isol Valve.

_______ e. Close 1-RP-41, 1B Refuel Purification Filter Bypass Valve.

_______ f. Open 1-RP-80, Refuel Prfch Filters to Spent Fuel Pit Isol Vv.

_______ g. Open 1-RP-77, 1B Refueling Purification Filter Outlet Isol Valve.

(outside Nonregenerative HX cubicle)

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 29 of 44 5.5.9 Prepare the Unit Blender to be used for transfer. This will be the Blender which is being supplied by the BAST which will be transferred.

_______ a. Verify the blender will not be needed for the time needed for BAST transfer.

b. To prevent automatic actuation, do the following:

_______ 1. Place the BLENDER MODE selector switch in STOP.

_______ 2. Place the control switch for 1-CH-FCV-1113A (2-CH-FCV-2113A),

BORIC ACID TO BLENDER, in CLOSE.

c. IF Unit 1 Blender will be used, THEN do the following valve alignment:

_______ 1. Record the As-Found Blender Controller settings below:

Auto / Manual Controller Controller Name (circle one) Output Pot Setting Boric Acid To 1-CH-FC-1113A Blender Flow Auto / Manual __________ % ___________

Controller Primary Water 1-CH-FC-1114A To Blender Flow Auto / Manual __________ % ___________

Controller Primary Water To Blender Flow 1-CH-HFC-1114 __________ %

Controller (Half Station)

_______ 2. Close 1-CH-FCV-1113B, Blender Makeup To Chg Pp Suction

_______ 3. Close 1-CH-FCV-1114B, Blender Makeup To VCT

_______ 4. Close 1-CH-233, Boric Acid Blender to RWST High Hdr Isol Valve

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 30 of 44

_______ 5. Open 1-CH-232, Spent Fuel Pit Boric Acid Makeup Isol Valve

_______ 6. Open 1-CH-230, Boric Acid Blender To RWST And Fuel Pit Isol Vv

_______ 7. IF in Modes 3, 4, 5, or 6, THEN unlock AND open 1-CH-217, PG Supply To Boric Acid Blender Isolation Valve.

d. IF Unit 2 Blender will be used, THEN do the following valve alignment:

_______ 1. Record the As-Found Blender Controller settings below:

Auto / Manual Controller Controller Name (circle one) Output Pot Setting Boric Acid To 2-CH-FC-2113A Blender Flow Auto / Manual __________ % ___________

Controller Primary Water 2-CH-FC-2114A To Blender Flow Auto / Manual __________ % ___________

Controller Primary Water To Blender Flow 2-CH-HFC-2114 __________ %

Controller (Half Station)

_______ 2. Close 2-CH-FCV-2113B, Blender Makeup To Chg Pp Suction

_______ 3. Close 2-CH-FCV-2114B, Blender Makeup To VCT

_______ 4. Close 2-CH-148, Boric Acid Blender to RWST High Hdr Isol Valve

_______ 5. Open 2-CH-147, Spent Fuel Pit Boric Acid Makeup Isol Valve

_______ 6. Open 2-CH-145, Boric Acid Blender To RWST And Fuel Pit Isol Vv

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 31 of 44

_______ 7. IF in Modes 3, 4, 5, or 6, THEN unlock AND open 2-CH-140, PG Supply To Boric Acid Blender Isolation Valve.

NOTE: The Boron Concentration in the following Step is based on expected Auxiliary Building, Pipe Tunnel, and BRT Enclosure temperatures of at least 60°F. Abnormally low temperatures in any of these areas may require a lower Boron Concentration in the blend and will result in additional PG usage.

_______ e. Using the Station Curves, determine the flow rates for Boric Acid and PG to establish a Boron Concentration of approximately 7000 ppm.

NOTE: Integrator operation for 1-CH-DCC-1113, Boric Acid and PG Digital Controller, is provided in the Attachment of 1-OP-8.3, Boron Concentration Control.

f. IF Unit 1 Blender will be used, THEN adjust the integrator on 1-CH-DCC-1113, Boric Acid and PG Digital Controller, as follows:

• IF automatic integrator make-up termination is desired, THEN Set AND Enable [RUN] the following applicable integrator setpoint (SP) values to the required quantity to be added:

_______ ** Boric Acid

_______ ** PG Water

• IF automatic integrator make-up termination is NOT desired, THEN ensure the following applicable integrator setpoint (SP) values are Set AND Enabled [RUN] above the required quantity to be added:

_______ ** Boric Acid (maximum 3000)

_______ ** PG Water (maximum 30,000)

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 32 of 44 NOTE: Integrator operation for 2-CH-DCC-2113, Boric Acid and PG Digital Controller, is provided in the Attachment of 2-OP-8.3, Boron Concentration Control.

g. IF Unit 2 Blender will be used, THEN adjust the integrator on 2-CH-DCC-2113, Boric Acid and PG Digital Controller, as follows:

• IF automatic integrator make-up termination is desired, THEN Set AND Enable [RUN] the following applicable integrator setpoint (SP) values to the required quantity to be added:

_______ ** Boric Acid

_______ ** PG Water

• IF automatic integrator make-up termination is NOT desired, THEN ensure the following applicable integrator setpoint (SP) values are Set AND Enabled [RUN] above the required quantity to be added:

_______ ** Boric Acid (maximum 3000)

_______ ** PG Water (maximum 30,000)

_______ 5.5.10 Open 1-RP-70, 1-RP-I-1 Top Flushing Water Isol Valve.

5.5.11 Open valve for in-service Cesium Removal IX:

_______

• 1-LW-518, 1-BR-I-1A Top Flushing Water Isolation Valve

_______

• 1-LW-523, 1-BR-I-1B Top Flushing Water Isol Valve

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 33 of 44 CAUTION Boric Acid Storage Tank level should be closely monitored during the transfer evolution. Avoid entry into TRM action statements based on low level.

_______ 5.5.12 Review transfer termination criteria:

• IF the BAST being transferred is in service to a Unit in Mode 1-4, THEN level should be maintained above 71% to prevent entry into the Action Statement of TRM 3.1.1.

• IF the BAST being transferred is in service to a Unit in Mode 5 or 6, THEN level should be maintained above 5% to prevent entry into the Action Statement of TRM 3.1.2.

NOTE: Transfer will be expedited if the Gas Stripper Discharge Pumps are not running during the transfer.

5.5.13 Start transfer using blender as follows:

_______ a. Place BLENDER MODE selector switch in MANUAL.

_______ b. Place the BLENDER CONTROL switch in START.

_______ c. Place control switch for 1-CH-FCV-1113A (2-CH-FCV-2113A), Boric Acid To Blender, in AUTO.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 34 of 44

_______ d. Place control switch for 1-CH-FCV-1114A (2-CH-FCV-2114A),

Primary Wtr To Blender Flow, in AUTO.

e. Monitor Boric Acid and PG flow on the recorder or on PCS and adjust as necessary:

_______

• Boric Acid, using 1-CH-FC-1113A (2-CH-FC-2113A), Boric Acid To Blender Flow

_______

• PG, using 1-CH-FC-1114A (2-CH-FC-2114A), Primary Wtr To Blender Flow NOTE: IF the blend must be terminated, THEN transition should be made to Step 5.5.14.

_______ 5.5.14 Monitor BAST level and BRT level during transfer.

NOTE: The purpose of the following Step is to ensure the RP IX and piping are of a Boron Concentration that will not adversely affect RWST operability once the transfer has been completed.

5.5.15 WHEN BAST level is approximately one percent higher than desired, THEN adjust Blender concentration for approximately 2100 ppm as follows:

_______ a. Using the Station Curves, determine the flow rates for Boric Acid and PG to establish a Boron Concentration of approximately 2100 ppm.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 35 of 44 NOTE: Integrator operation for 1-CH-DCC-1113, Boric Acid and PG Digital Controller, is provided in the Attachment of 1-OP-8.3, Boron Concentration Control.

b. IF Unit 1 Blender will be used, THEN adjust the integrator on 1-CH-DCC-1113, Boric Acid and PG Digital Controller, as follows:

• IF automatic integrator make-up termination is desired, THEN Set AND Enable [RUN] the following applicable integrator setpoint (SP) values to the required quantity to be added:

_______ ** Boric Acid

_______ ** PG Water

• IF automatic integrator make-up termination is NOT desired, THEN ensure the following applicable integrator setpoint (SP) values are Set AND Enabled [RUN] above the required quantity to be added:

_______ ** Boric Acid (maximum 3000)

_______ ** PG Water (maximum 30,000)

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 36 of 44 NOTE: Integrator operation for 2-CH-DCC-2113, Boric Acid and PG Digital Controller, is provided in the Attachment of 2-OP-8.3, Boron Concentration Control.

c. IF Unit 2 Blender will be used, THEN adjust the integrator on 2-CH-DCC-2113, Boric Acid and PG Digital Controller, as follows:

• IF automatic integrator make-up termination is desired, THEN Set AND Enable [RUN] the following applicable integrator setpoint (SP) values to the required quantity to be added:

_______ ** Boric Acid

_______ ** PG Water

• IF automatic integrator make-up termination is NOT desired, THEN ensure the following applicable integrator setpoint (SP) values are Set AND Enabled [RUN] above the required quantity to be added:

_______ ** Boric Acid (maximum 3000)

_______ ** PG Water (maximum 30,000)

_______ d. Monitor Boric Acid and PG flow on the recorder or PCS and adjust as necessary:

_______

• Boric Acid, using 1-CH-FC-1113A (2-CH-FC-2113A), Boric Acid To Blender Flow

_______

• PG, using 1-CH-FC-1114A (2-CH-FC-2114A), Primary Wtr To Blender Flow

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 37 of 44 5.5.16 WHEN BAST reaches desired level OR the desired amount of Boric Acid has been transferred, THEN secure blend as follows:

_______ a. Place the BLENDER CONTROL switch in STOP.

_______ b. Place control switch for 1-CH-FCV-1113A (2-CH-FCV-2113A), Boric Acid To Blender, in CLOSE.

_______ c. Place control switch for 1-CH-FCV-1114A (2-CH-FCV-2114A),

Primary Wtr To Blender Flow, in CLOSE.

d. IF Unit 1 Blender was used, THEN do the following valve alignment:

_______ _______ 1. IF in Modes 3, 4, 5, or 6, THEN within 15 minutes of completing makeup, close AND lock 1-CH-217, PG Supply To Boric Acid Blender Isolation Valve.

_______ _______ 2. Close 1-CH-232, Spent Fuel Pit Boric Acid Makeup Isol Valve

_______ _______ 3. Close 1-CH-230, Boric Acid Blender To RWST And Fuel Pit Isol Vv

e. IF Unit 2 Blender was used, THEN do the following valve alignment:

_______ _______ 1. IF in Modes 3, 4, 5, or 6, THEN within 15 minutes of completing makeup, close AND lock 2-CH-140, PG Supply To Boric Acid Blender Isolation Valve.

_______ _______ 2. Close 2-CH-147, Spent Fuel Pit Boric Acid Makeup Isol Valve

_______ _______ 3. Close 2-CH-145, Boric Acid Blender To RWST And Fuel Pit Isol Vv

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 38 of 44 5.5.17 Return affected Blender to AUTO or condition requested by the Unit SRO.

To return to AUTO, do the following:

a. Place the following valves in AUTO:

_______

• 1-CH-FCV-1113B (2-CH-FCV-2113B), Blender Makeup To Chg Pp Suction

_______

• 1-CH-FCV-1114B (2-CH-FCV-2114B), Blender Makeup To VCT

_______

• 1-CH-FCV-1113A (2-CH-FCV-2113A), Boric Acid To Blender NOTE: Integrator operation for 1-CH-DCC-1113, Boric Acid and PG Digital Controller, is provided in the Attachment of 1-OP-8.3, Boron Concentration Control.

b. IF Unit 1 Blender was used, THEN ensure the following 1-CH-DCC-1113, Boric Acid and PG Digital Controller, integrator setpoint (SP) values are Set sufficiently high AND Enabled [RUN] to prevent stopping non-automatic make-up operations:

_______

• Boric Acid (maximum 3000)

_______

• PG Water (maximum 30,000)

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 39 of 44 NOTE: Integrator operation for 2-CH-DCC-2113, Boric Acid and PG Digital Controller, is provided in the Attachment of 2-OP-8.3, Boron Concentration Control.

c. IF Unit 2 Blender was used, THEN ensure the following 2-CH-DCC-2113, Boric Acid and PG Digital Controller, integrator setpoint (SP) values are Set sufficiently high AND Enabled [RUN] to prevent stopping non-automatic make-up operations:

_______

• Boric Acid (maximum 3000)

_______

• PG Water (maximum 30,000)

_______ d. Ensure that the switch for the on-service Boric Acid Transfer Pump is in AUTO.

_______ _______ e. Ensure the Blender Controller is returned to the As-Found settings recorded in Step 5.5.9.c.1 or 5.5.9.d.1.

_______ f. Perform Manual Makeup using 1(2)-OP-8.3, Boron Concentration Control for sufficient time period to adjust flow in Step 5.5.17.g.

g. Monitor Boric Acid and PG flow on the recorder or PCS and adjust as necessary:

_______

• Boric Acid, using 1-CH-FC-1113A (2-CH-FC-2113A), BORIC ACID TO BLENDER FLOW

_______

• PG, using 1-CH-FC-1114A (2-CH-FC-2114A), PRIMARY WTR TO BLENDER FLOW

_______ h. If desired, place Blender in Auto Makeup Mode using 1(2)-OP-8.3, Boron Concentration Control.

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 40 of 44 5.5.18 Close applicable valve for in-service Cesium Removal IX:

_______ _______

• 1-LW-518, 1-BR-I-1A Top Flushing Water Isolation Valve

_______ _______

• 1-LW-523, 1-BR-I-1B Top Flushing Water Isol Valve

_______ _______ 5.5.19 Close 1-RP-70, 1-RP-I-1 Top Flushing Water Isol Valve

_______ 5.5.20 Open 1-LW-493, Flush Water Supply Header Isolation Valve.

5.5.21 Return RP lineup to normal secured condition as follows:

_______ _______

• Close 1-RP-80, Refuel Prfch Filters to Spent Fuel Pit Isol Vv.

_______ _______

• Close 1-RP-77, 1B Refueling Purification Filter Outlet Isol Valve.

(outside Nonregenerative HX cubicle)

_______ _______

• Open 1-RP-65, 1B Refueling Purification Filter Outlet Isol Valve.

_______ _______

• Open 1-RP-74, Refuel Prfcn Ion Exch To 1A RP Filter Isol Valve.

_______ _______

• Open and seal 1-RP-128, Spent Fuel Pit Inlet Isolation Valve, located in SV the Fuel Bldg Southwest corner of the Spent Fuel Pool under the floor grating. (Reference 2.4.2)

_______ 5.5.22 Return the RP System to the status desired by the Unit SRO.

Completed by: ___________________________________________ Date: _________

ATTACHMENTS

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 41 of 44 (Page 1 of 4)

Attachment 1 Cross Connect Valve Lineup

1. Ensure the following valves are closed:

_______ _______

• 1-LW-500, 3B Deborating Demin Resin Disch Flush Wtr Sply Vv

_______ _______

• 1-CH-37, 3B Deborating Demin Outlet Backflush Isol Vv

_______ _______

• 1-CH-59, Deborating Demins Flush Water Isolation Valve

_______ _______

• 1-CH-54, 3A Deborating Demin Outlet Backflush Isol Vv

_______ _______

• 1-LW-496, 3A Deborating Demin Resin Disch Flush Wtr Sply Vv

_______ _______

• 1-LW-502, 1A Mixed Bed Demin Resin Disch Flush Wtr Sply Isol

_______ _______

• 1-CH-25, 1A Mixed Bed Demin Disch Backflush Isolation Valve

_______ _______

• 1-CH-26, 1A Mixed Bed Demin Flush Water Inlet Isol Valve

_______ _______

• 1-LW-505, 1B Mixed Bed Demin Resin Disch Flush Wtr Sply Isol

_______ _______

• 1-CH-17, 1B Mixed Bed Demin Flush Water Inlet Isol Valve

_______ _______

• 1-CH-16, 1B Mixed Bed Demin Disch Backflush Isolation Valve

_______ _______

• 1-LW-493, Flush Water Supply Header Isolation Valve

_______ _______

• 1-LW-508, 1-RP-I-1 Bottom Flushing Water Isol Valve

_______ _______

• 1-RP-72, RP Ion Exchanger Resin Flush Isolation Valve

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 42 of 44 (Page 2 of 4)

Attachment 1 Cross Connect Valve Lineup Ensure the following valves are closed (Cont):

_______ _______

• 1-LW-509, 1-RP-I-1 Flushing Water Isol Vv

_______ _______

• 1-LW-511, 1-RP-I-1 Flushing Water Recirc Isol Valve

_______ _______

• 1-LW-512, Cation Bed Demin Resin Disch Flush Wtr Sply Isol

_______ _______

• 1-CH-7, Cation Bed Demin Disch Backflush Isolation Valve

_______ _______

• 1-CH-8, Cation Bed Demin Flushing Water Supply Isol Valve

_______ _______

• 1-LW-516, 1-BR-I-1A Resin Disch Flushing Water Isol Valve

_______ _______

• 1-LW-518, 1-BR-I-1A Top Flushing Water Isolation Valve

_______ _______

• 1-LW-515, 1-BR-I-1A Bottom Flushing Water Isol Valve

_______ _______

• 1-LW-521, 1-BR-I-1B Resin Disch Flushing Water Isol Valve

_______ _______

• 1-LW-523, 1-BR-I-1B Top Flushing Water Isol Valve

_______ _______

• 1-LW-520, 1-BR-I-1B Bottom Flushing Water Isol Valve

_______ _______

• 1-LW-524, 1-BR-I-1B Flushing Water Recirc Isol Valve

_______ _______

• 1-BR-123, 1B Cesium Removal Ion Exch Outlet Isol Valve

_______ _______

• 2-LW-1, 1A Mixed Bed Demin Resin Disch Flush Wtr Sply Isol

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 43 of 44 (Page 3 of 4)

Attachment 1 Cross Connect Valve Lineup Ensure the following valves are closed (Cont):

_______ _______

• 2-CH-3, 1A Mixed Bed Demin Disch Backflush Isolation Valve

_______ _______

• 2-CH-4, 1A Mixed Bed Demin Flush Water Inlet Isol Valve

_______ _______

• 2-CH-13, 1B Mixed Bed Demin Flush Water Inlet Isol Valve

_______ _______

• 2-LW-4, 1B Mixed Bed Demin Resin Disch Flush Wtr Sply Isol

_______ _______

• 2-CH-12, 1B Mixed Bed Demin Disch Backflush Isolation Valve

_______ _______

• 1-LW-527, Liquid Waste Flush Water Supply Header Isol Valve

_______ _______

• 2-LW-7, Cation Bed Demin Resin Disch Flush Wtr Sply Isol

_______ _______

• 2-CH-24, Cation Bed Demin Disch Backflush Isolation Valve

_______ _______

• 2-CH-25, Cation Bed Demin Flushing Water Supply Isol Valve

_______ _______

• 2-LW-10, 3A Deborating Demin Resin Disch Flush Wtr Sply Vv

_______ _______

• 2-CH-37, 3A Deborating Demin Outlet Backflush Isol Vv

_______ _______

• 2-LW-13, 3B Deborating Demin Resin Disch Flush Wtr Sply Vv

_______ _______

• 2-CH-51, 3B Deborating Demin Outlet Backflush Isol Vv

_______ _______

• 2-CH-38, Deborating Demins Flushwater Isolation Valve

DOMINION 0-OP-8.8 North Anna Power Station Revision 10 Page 44 of 44 (Page 4 of 4)

Attachment 1 Cross Connect Valve Lineup Ensure the following valves are closed (Cont):

_______ _______

• 1-LW-525, Flush Water Supply To West Resin Disch Hdr

Appendix D Scenario Outline Form ES-D-1 Facility: North Anna Power Station Scenario No.: (2014) NRC-3 Op-Test No.: 1 Examiners: ___________________________ Operators: _____________________________

___________________________ _____________________________

___________________________ _____________________________

Initial Conditions: Unit is at 49% power BOL. Unit was returned to power 2 days ago following work on the generator exciter. Power has been at 49% for several days due to a problem with a containment sump pump. The sump pump has been replaced and the unit as been cleared to increase power to 100%. 1-FW-P-2 (terry turbine) was just returned to service last shift. 2-CC-P-1B was tagged out last shift for major maintenance and is not expected to be returned to service for several days.

Turnover: Shift orders are to swap charging pumps to "B" for an upcoming PT, then ramp the unit to 100% power.

Event Malf. Event Event No. No. Type* Description 1 N (R) (S) Swap charging pumps 2 N (B) Ramp unit up using turbine and dilution/rods R (R) (S) 3 NI0101 I (R) (S) Power range detector N-44 fails high causing control rods to step TS (S) in.

3a N (B) (S) N-44 is placed in trip (Normal) 4 CA0402 C (B) (S) Instrument air leak in containment. Standby compressor fails to start automatically. Relief valve reseats after containment has been isolated from outside IA system. (CT) 5 CH1201 I (R) (S) VCT level transmitter failure C (B) (S) 6 CC0201 Running CC pump trips with failure of standby pump to auto-start TS (S) 7 FW2201 M (ALL) Loss of Main Feed FW2202 FW2203 8 C (B) (S) Failure of turbine to trip automatically or manually (CT) 9 C (ALL) AFW pumps trip, degrade, or don't put water into generator (CT)

The scenario can be terminated once the crew has transitioned out of 1-FR-H.1 (Event 8 happens during event 7 and is numbered for use on subsequent forms. Events 8 and 9 happen after the reactor trip.)

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

DOMINION NORTH ANNA POWER STATION INITIAL LICENSED OPERATOR EXAMINATION SIMULATOR EXAMINATION GUIDE SCENARIO 2014 NRC 3 2014 NRC 3 Page 2 Revision 0

SIMULATOR EXAMINATION GUIDE EVENT DESCRIPTION

1. Swap charging pumps (Normal)

2. Ramp unit up using turbine and dilution/rods 3/3a. Power range detector N-44 fails high causing control rods to step in.

N-44 is placed in trip (Normal/BOP)

4. Instrument air leak in containment. Standby compressor fails to start automatically.

Relief valve reseats after containment has been isolated from outside IA system.

5. VCT level transmitter failure

6. Running CC pump trips with failure of standby pump to auto-start 7/8. Loss of Main Feed Failure of turbine to trip automatically or manually

9. Loss of secondary heat sink Scenario Recapitulation:

Malfunctions after EOP entry 2 (Turbine fails to trip automatically or manually, loss of AFW)

Total Malfunctions 7 (Failure of N-44, instrument air leak in containment/standby compressor fails to start automatically, VCT level transmitter failure, CC pump trips/standby pump fails to auto-start, loss of main feed, turbine fails to trip automatically or manually, loss of AFW.)

Abnormal Events 4 (Failure of N-44, instrument air leak in containment/standby compressor fails to start automatically, VCT level transmitter failure, CC pump trips/standby pump fails to auto-start)

Major Transients 1 (Loss of main feed)

EOPs Entered 2 (ES-0.1, FR-H.1)

EOP Contingencies 1 (FR-H.1)

Critical Tasks 3 SCENARIO DURATION 138 Minutes 2014 NRC 3 Page 3 Revision 0

SIMULATOR EXAMINATION SCENARIO

SUMMARY

SCENARIO 2014 NRC 3 Unit is at 49% power BOL. Unit was returned to power 2 days ago following work on the generator exciter. Power has been at 49% for several days due to a problem with a containment sump pump. The sump pump has been replaced and the unit as been cleared to increase power to 100%. 1-FW-P-2 (terry turbine) was returned to service last shift. 2-CC-P-1B was tagged out for major maintenance last shift and is not expected to be returned to service for several days. Shift orders are to swap charging pumps to "B" for an upcoming PT, then ramp the unit to 100%

power The first event will be a normal evolution of swapping charging pumps by the RO using 1-OP-8.9, "Transferring Running Pumps." This evolution can be pre-briefed so that the crew is prepared to do the swap. Once the charging pumps have been swapped, the next event can occur.

The next event will be a ramp up in power. This event can be pre-briefed. Once enough of a power increase has been seen, the next event can occur.

Power-range NI channel IV will fail high, causing control rods to insert. The crew should enter 1-AP-4.3, "Malfunction of Nuclear Instrumentation (Power Range)," and place control rods in MANUAL. The crew should place the channel in trip and withdraw control rods to there previous position to restore Tave. After the crew restores control rods to AUTO; or at the discretion of the lead evaluator, the next event can occur.

Now, a loss of instrument air inside containment will occur. The source of the leak will be a relief valve on the containment IA receiver that lifted and will not reseat. The crew will be expected to perform the actions of 1-AP-28, "Loss of Instrument Air," start all available air compressors, and isolate containment instrument air, which will isolate the leak from the rest of the station air. Once isolated, containment instrument air will continue to decrease where the relief valve will eventually reseat and air pressure will recover. After the crew identifies that containment instrument air pressure has recovered, the next event will occur.

VCT level transmitter, 1-CH-LT-1112, will fail high. The VCT divert valve will fail open.

The RO will use the annunciator response for VCT hi/lo level (C-A4) to manually close the divert valve. The crew will discuss the loss of auto-swapover to the RWST on low VCT level.

The next event will be a loss of component cooling. The running pump, 1-CC-P-1A will trip and the standby pump, 1-CC-P-1B will fail to auto start. The crew will be expected to respond IAW 1-AP-15, "Loss of Component Cooling," and start 1-CC-P-1B. After CC flow has been restored and TS have been reviewed, the next event can occur.

A feed line break will occur on the main feed pump suction line, resulting in a loss of all main feed pumps. Upon initiation of the reactor trip the crew should enter 1-E-0, "Reactor Trip or Safety Injection", and perform the required actions. The turbine will not trip, requiring the BOP to perform the RNO action to trip it. If the crew can quickly trip the main turbine, then safety injection 2014 NRC 3 Page 4 Revision 0

will not occur and the crew will transition to 1-ES-0.1, "Reactor Trip Response." Depending on crew speed, a safety injection may occur due to the turbine trip failure and the crew will remain in 1-E-0. The terry turbine will start and then trip. It will be reported that the linkage to the trip valve is broken.

The "A" motor-driven pump will be pumping water to the floor of the MSVH. The "B" motor-driven pump will degrade to the point where it is not putting water in the "B" SG. These failures will lead to the next event.

The crew will identify that they have no feed to the SGs and enter 1-FR-H.1, "Response to a Loss of Secondary Heat Sink." The crew will not be able to restore Main or Aux feedwater the first time through the procedure and will return to step 1. At this time the terry turbine trip valve will be repaired and the terry turbine will be restarted. The scenario can be terminated once the crew has transitioned out of FR-H.1.

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SCENARIO TURNOVER SHEET Read the following to the crew:

Purpose: This examination is intended to evaluate the crews performance of various tasks associated with the Initial License Operator Training Program. All activities should be completed in accordance with approved operations standards.

1. You are on a day shift during the week.

2. A rough log should be maintained to aid in making reports and to help during briefs.

3. Respond to what you see. In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated and the crew informed.

Unit Status:

Unit 1 is at 49% power. Unit was returned to power 2 days ago following work on the generator exciter. Power has been at 49% for several days due to a problem with a containment sump pump.

The sump pump has been replaced and the unit as been cleared to increase power to 100%. RCS boron is 1537 ppm and core age is 150 MWD/MTU. Aux steam is on unit 2.

Unit 2 is at 100% power.

Equipment Status:

1-FW-P-2 (terry turbine) was just returned to service last shift. 2-CC-P-1B was tagged out last shift for major maintenance. It is expected to be out for several more days. Maintenance rule window is green Protected train is 2H.

Shift Orders:

Swap charging pumps to "B" for an upcoming PT, then ramp the unit to 100% power 2014 NRC 3 Page 6 Revision 0

EVENT 1: Swap charging pumps to 1-CH- P-1B in service per 1-OP-8.9, "Transferring Running Charging Pumps."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Amps increase on "B" charging pump when started

• Amps decrease on "A" charging pump when stopped RO places "B" charging pump bearing Normal event temperatures on a short interval trend using PCS.

RO verifies with operator in AB that Aux oil pump for 1-CH-P-1B is in auto and running.

RO announces and starts 1-CH-P-1B.

RO verifies that 1-SW-TI-103B is < 128°F.

RO stops 1-CH-P-1A and places in AUTO-AFTER-STOP.

RO continues to monitor bearing temperatures on 1-CH-P-1B until stable, then returns trend interval to normal.

RO clears annunciator C-A7 by placing control switch in PTL and returning to After Stop. (per AR)

NOTE: The next event can occur once Validation time: 13 minutes the crew has swapped charging pumps.

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EVENT 2: Given that the unit is at approximately 49% power and the crew has been instructed to increase power, the crew will ramp the unit up in accordance with 1-OP-2.1, "Unit Startup from Mode 2 to Mode 1."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Reactor power increases

• Turbine power increases

• Tavg/Tref increase

• Generator megawatts increase BOP ramps down to get off limiter. Attachment 9 to 1-OP-2.1 attached.

Step 6.

BOP adjusts limiter up. Step 7 BOP verifies/sets desired ramp rate (0.3% Step 1 per minute).

BOP increases turbine setter to desired Step 3 position.

BOP presses GO on turbine.

BOP monitors turbine ramp.

RO starts a dilution when required using 1- GOPs attached GOP-8.3.1 or 1-GOP-8.3.2.

RO monitors control rods. AFD NOTE: The next event can occur once Validation time: 28 minutes to ramp enough of a power increase has been about 10%.

observed, or as directed by the lead examiner. Make sure all 4 NIs are >51%.

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EVENT 3/3a: Given that the unit is at power, and power-range channel IV has failed high resulting in rods stepping in, the crew will respond in accordance with 1-AP-4.3, "Malfunction of Nuclear Instrumentation (Power Range)."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Control rods step in

• Annunciators A-A7, A-B7, and A-D8 illuminate

• N-44 indication is failed high RO identifies control rods stepping in.

RO identifies annunciators for an NI failure are lit.

RO identifies N-44 failed high.

US directs entry into 1-AP-4.3.

IOA BOP stops power increase by holding the ramp.

IOA RO verifies N-44 not failed. (NO)

RO places control rods in MANUAL.

IOA BOP verifies MFRV bypass valves in MANUAL.

NOTE: The RO will stop the dilution.

Crew verifies the other three power-range instruments operable.

Crew verifies unit in mode 1.

Crew checks reactor trip interlocks: TS 3.3.1 Functions 18b, 18d, 18c

• Power >7% and P-G2 NOT lit hour permissives

• Power >10% and P-D2 lit

• Power >30% and P-F1 NOT lit Crew checks Tave within 1.5°F of Tref. There is a rod stop signal present until N-44 is placed in trip.

• RO maintains rods above insertion limit and AFD in spec.

BOP defeats N-44 Normal

• BOP selects N44 on the comparator and rate drawer

• BOP selects N-44 on the miscellaneous control and indication drawer for rod stop bypass and upper and lower sections

• BOP removes control power fuses 2014 NRC 3 Page 9 Revision 0

EVENT 3/3a: Given that the unit is at power, and power-range channel IV has failed high resulting in rods stepping in, the crew will respond in accordance with 1-AP-4.3, "Malfunction of Nuclear Instrumentation (Power Range)."

TIME EXPECTED ACTION INSTRUCTOR REMARKS Crew verifies N-43 selected on the N-16 status panel.

Crew notifies Chemistry that N-44 input to the OLCMS is unreliable.

Crew checks N-41, N-42 and N-43 not failed.

Crew checks N-44 failed.

Crew checks reactor power >5%.

Crew removes points from processing.

N0047A, N0048A, and N0052A US refers to Technical Specifications:

3.3.1 Function 2a/2b (Power range neuron flux high/low) Conditions D Function 3a/3b (Flux rate high positive/high negative) Condition E Conditions D Channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> and 75% power Condition E Channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. (Done by AP)

(Functions 18b (P-7),c (P-8),d (P-10) for the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> permissives are already checked per AP)

Crew adjusts control rods as required and places rod control in AUTO, as appropriate.

NOTE: The next event will occur after the Validation time 20 minutes, including brief.

crew restores control rods to AUTO, or as directed by the lead examiner.

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EVENT 4: Given that the unit is at power, and a loss of instrument air inside containment has occurred, the crew will be expected to respond in accordance with 1-AP-28, "Loss of Instrument Air."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciators F-F8, and J-E2 illuminates

• Instrument air and containment instrument air pressures decrease

• Compressors do not auto-start when required BOP identifies annunciators 1J-F8, SAND FLTR IS SUPPLY LO PRESS, and 1J-E2, CONT INST AIR HDR LOW PRESS OR COMP B TROUBLE.

Crew identifies decreasing IA pressure.

US directs entry into 1-AP-28.

CT2 BOP starts all available air *Prior to reaching the (manual reactor)

IOA compressors. trip set point of 70 PSIG.

Crew starts IA/SA compressors by placing them in HAND.

• BOP checks IA pressure <70 psig. (NO)

US directs BOP to continue monitoring IA RNO pressure.

Crew dispatches operators to determine cause for loss of IA.

Crew attempts to correct cause for loss of IA.

BOP verifies IA pressure >94 psig. (NO)

Crew determines IA pressure is NOT trending to >94 psig.

BOP closes 1-IA-TV-102A to isolate IA to This will isolate the containment IA containment. header. The relief valve will reseat.

Crew checks IA pressure outside containment increasing. (YES)

Crew monitors IA pressure inside containment decreasing, then increasing back to normal.

Crew checks RHR system in service.

Crew checks RCPs running.

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EVENT 4: Given that the unit is at power, and a loss of instrument air inside containment has occurred, the crew will be expected to respond in accordance with 1-AP-28, "Loss of Instrument Air."

TIME EXPECTED ACTION INSTRUCTOR REMARKS Crew verifies RCP temperatures normal.

Crew checks RCP seal cooling normal.

NOTE: Operators dispatched to investigate loss of IA will report that nothing abnormal was noted.

Crew checks PRZR PORV accumulator pressure normal.

RO maintains RCS pressure stable.

RO maintains PRZR level stable.

Crew checks containment IA pressure increasing.

Crew verifies containment IA pressure >75 psig.

NOTE: Crew may choose not to reopen 1-IA-TV-102A at this time or to locally isolate penetration and valve in air slowly per RNO.

BOP opens 1-IA-TV-102A.

Crew verifies containment cooling normal.

BOP verifies IA pressure >94 psig.

BOP returns air compressors to normal and directs unit 2 to do the same.

NOTE: The next event can occur after Validation time: 15 minutes, waited the crew verifies air pressure is returned for IA TV to be reopened. Brief.

to normal, or as directed by the lead examiner.

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EVENT 5: Given that the unit is at power and a failure of VCT level transmitter, 1-CH-LT-1112, the crew will respond in accordance with the applicable annunciator response.

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciator C-A4 illuminates

• 1-CH-LI-1112 will indicate off-scale high

• 1-CH-LCV-1112C output will go to zero

• VCT level will decrease

• "A" Stripper level will increase RO identifies annunciator C-A4, VCT HI-LO LEVEL L-112.

RO identifies 1-CH-LT-1112 is failed high and VCT is diverting to stripper.

NOTE: The following steps are from the annunciator response for C-A4.

(Attached)

US reads note in AR about 1-CH-LT-1112 failing high - loss of auto swapover capability on low VCT level, full divert to stripper.

RO places 1-CH-LCV-1112C in manual and raises output to 100%.

RO verifies VCT level > 5 %.

RO verifies charging flow normal and 1-CH-FCV-1122 is not failed.

RO verifies Letdown flow is normal.

RO verifies VCT makeup is not in progress.

RO verifies 1-CH-LCV-1115A in VCT position.

RO verifies all instrumentation is normal.

(NO)

US reviews TRM 3.3.9 for Reg Guide 1.97 instrumentation. (Not Applicable)

Crew evaluates plant parameters to determine if VCT or letdown line leaking or ruptured. (NO)

US reviews TS 3.4.13 (RCS leakage) which applied while letdown was diverting to the stripper.

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EVENT 5: Given that the unit is at power and a failure of VCT level transmitter, 1-CH-LT-1112, the crew will respond in accordance with the applicable annunciator response.

TIME EXPECTED ACTION INSTRUCTOR REMARKS US makes notifications about 1-CH-LT-1112 failure and requests instrument shop assistance along with CR.

NOTE: The next event will occur once Validation time: 10 minutes, including brief.

the unit has been stabilized, or as determined by the lead examiner.

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EVENT 6: Given that the unit is at power, and the running component cooling pump has tripped, the crew will be expected to respond in accordance with 1-AP-15, "Loss of Component Cooling."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciators G-F5, C-C1, C-C2, and C-C3 illuminate (also G-B3, but it doesn't lock in)

• 1-CC-P-1A trips (green and amber lights lit)

• 1-CC-P-1B fails to auto-start BOP identifies loss of 1-CC-P-1A.

NOTE: Crew may decide to start 1-CC-P-1B without waiting for the AP since it should have auto-started.

US directs crew to enter 1-AP-15.

• BOP checks CC head tank level stable or increasing.

BOP verifies at least one Unit 1 CC pump running. (NO)

BOP performs RNO step and starts 1-CC-P-1B.

BOP checks running CC pump amps are normal.

BOP checks CC flow normal US directs Safeguards watchstander and electricians to investigate "A" CC pump breaker. (An overcurrent drop will be reported.)

US directs auxiliary building operator to investigate cause of "A" CC pump trip and to verify "B" CC pumps are operating satisfactorily.

Crew directs operator to locally check SW to CC heat exchanger delta Ps.

US consults TS 3.7.19A. 7 days to return a required CC subsystem to operable.

TR 7.5 Condition A for MRule Defense In Depth Risk Management Actions (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />) and Mrule fire zones U1/U2 ESGR, U1&/2 Cable vault and tunnel and the Aux buildg.(14 days) and return to functional within 30 days.

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EVENT 6: Given that the unit is at power, and the running component cooling pump has tripped, the crew will be expected to respond in accordance with 1-AP-15, "Loss of Component Cooling."

TIME EXPECTED ACTION INSTRUCTOR REMARKS NOTE: The next event can occur once the CC system has been returned to normal, Validation time: 9 minutes, including brief.

or at the discretion of the lead examiner.

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EVENT 7/8: Given that the unit is at power and a loss of main feedwater, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciators F-B6 and G-F6 are illuminated

• Turbine does not trip automatically or manually

• 1-FW-P-2 starts and trips BOP identifies annunciator 1F-B6, MAIN FD PUMPS SUCT HDR LO PRESS.

BOP informs crew that feed pump suction pressure is rapidly decreasing.

NOTE: Once the crew has identified a problem, a security officer, or operator if one in the area, will call the MCR and inform the crew that there is a large amount of steam in the east end of the turbine building basement.

US directs crew to enter 1-E-0.

IOA RO/BOP trip the reactor.

• RO checks reactor trip and bypass breakers are open

• RO checks rod bottom lights lit

• RO checks neutron flux decreasing CT3 Crew manually trips the turbine by *Prior to a severe challenge (orange IOA performing the following: path) to subcriticality or integrity CSFs

• BOP simultaneously pushes both turbine OR transition to ECA-2.1.

trip pushbuttons.

• Places both EHC Pumps in PTL RNO

• Manually runs back the Turbine OR

• Closes the MSTVs and Bypass Valves

• BOP opens G-12 and EFB IOA RO verifies power to AC emergency busses.

NOTE: If SI actuates, crew will continue in 1-E-0 while securing secondary equipment.

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EVENT 7/8: Given that the unit is at power and a loss of main feedwater, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection."

TIME EXPECTED ACTION INSTRUCTOR REMARKS IOA Crew verifies that safety injection has not occurred and is not required.

• No LHSI pumps running

• No SI first out annunciator lit

• No low pressurizer pressure

• No high containment pressure

• No steamline differential pressure

• No high steam flow with low-lo Tave or low steam pressure (NO)

NOTE: Loss of terry turbine is covered in next event.

US directs team to transition to 1-ES-0.1.

NOTE: Crew may decide not to brief until they throttle AFW in 1-ES-0.1.

US holds transient crew brief.

NOTE: The turbine building flooding AP (39.1) may be used as guidance for securing pumps.

Crew secures condensate pumps, and HPs.

MFP switches are placed in PTL.

NOTE: The next event will occur automatically 3 minutes after the reactor is tripped.

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EVENT 9: Given that the unit has tripped and a total loss of main and auxiliary feedwater has occurred, the crew will respond in accordance with 1-FR-H.1, "Response to Loss of Secondary Heat Sink."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciators F-D8 is illuminated

• 1-FW-P-3B degrades over a period of time

• Steam driven aux feed pump has no discharge flow

• "C" SG WR level does not increase as expected BOP identifies annunciator F-D8, TURBINE DRIVEN AFW PUMP TROUBLE OR LUBE OIL TRBL, and informs crew.

BOP identifies that the "B" AFW pump has degraded flow.

BOP identifies that "C" SG WR level is not increasing as expected NOTE: If crew is in 1-E-0 due to SI they will not be able to transition until step 7.

Crew identifies red path condition on the Due to one SG's AFW flow going to the heat sink critical safety function. floor of the MSVH, the ERG monitor will still show sufficient AFW flow, thus it will not show a red path.

US directs crew to transition to 1-FR-H.1.

Crew checks if secondary heat sink is required.

• Crew checks bleed and feed is required.

(NO)

• Any 2 SG WR levels < 14%[24%]

NOTE: The operator dispatched to reset the overspeed trip valve will report that the linkage is bound (or broken) and mechanics are working on it.

NOTE: When dispatched, operator/mechanics will report "B" AFW pump is not flowing and there is a metallic sound coming from the pump.

NOTE: Once crew determines that AFW is not reaching "C" SG: security or an operator can report that there is water coming out of the door of the MSVH.

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EVENT 9: Given that the unit has tripped and a total loss of main and auxiliary feedwater has occurred, the crew will respond in accordance with 1-FR-H.1, "Response to Loss of Secondary Heat Sink."

TIME EXPECTED ACTION INSTRUCTOR REMARKS Crew tries to establish AFW flow.

• Crew checks SG blowdown and sample isolation valves closed

• Crew reviews control room indications to determine cause of AFW failure

• Crew starts at least one AFW pump from the control room

• Crew checks AFW flow to SGs > 340 gpm (NO)

NOTE: Crew may place 1-FW-P-3B in PTL. AMSAC will have to be reset first.

CT4 Crew stops reactor coolant pumps. *Prior to being required to initiate RCS bleed and feed.

RO places both spray valves in manual and closes them.

Crew dispatches an operator to locally restore or realign AFW using 1-AP-22 series.

Crew attempts to establish main feed flow to the SGs. (NO)

• Crew verifies one condensate pump is running or starts one (NO)

• Crew proceeds to step 14.

BOP checks SG wide range levels in 2/3 SGs less the 14%. (NO)

Crew returns to step 1.

NOTE: After the crew has cycled through 1-FR-H.1, the terry turbine can be returned to service.

Crew identifies that AFW flow is available to "A" SG.

Crew establishes at least 340 gpm to "A" SG.

Crew verifies that CETC are decreasing and SG WR level is increasing.

Crew returns to procedure and step in NOTE: RCS temperature was effect. decreasing prior to returning an AFW pump to service due to the low decay heat (55% BOL).

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EVENT 9: Given that the unit has tripped and a total loss of main and auxiliary feedwater has occurred, the crew will respond in accordance with 1-FR-H.1, "Response to Loss of Secondary Heat Sink."

TIME EXPECTED ACTION INSTRUCTOR REMARKS NOTE: The scenario can be terminated once the crew has transitioned out of Total time: 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> and 18 minutes.

FR-H.1, or as directed by the lead examiner.

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REFERENCES PROCEDURE REV.

1-OP-8.9, "Transferring Running Charging Pumps." 10 1-OP-2.1, "Unit Startup From Mode 2 to Mode 1." 113 Abnormal Procedure 1-AP-4.3, "Malfunction of Nuclear Instrumentation (Power 21 Range)"

Abnormal Procedure 1-AP-15, "Loss of Component Cooling." 23 Abnormal Procedure 1-AP-28, "Loss of Instrument Air." 34 Emergency Operating Procedure 1-E-0, "Reactor Trip or Safety Injection." 46 Functional Restoration Procedure 1-FR-H.1, "Response to Loss of Secondary Heat 22 Sink."

Station Annunciator Response Procedures. N/A Administrative Procedure PI-AA-5000, "Human Performance." 8 INPO, Guideline for Teamwork and Diagnostic Skill Development: INPO 88-003, Jan. 1988 INPO, ACAD 07-002 Simulator Training Guidelines Jan. 2007 2014 NRC 3 Page 22 Revision 0

ATTACHMENT 1 SIMULATOR OPERATOR'S COMPUTER PROGRAM 2014 NRC 3 Page 23 Revision 0

SIMULATOR OPERATOR'S COMPUTER PROGRAM 2014 NRC 3 Initial conditions

1. Recall IC 370

2. Ensure Tave(555-565), Tref, PDTT level, and VCT level are selected on trend recorders.

3. 2H is the protected train.

4. Place red sticker on 2-CC-P-1B switch

5. Control rods at 160 steps.

6. Calorimetric selected to 0.

PRELOADS PRIOR TO SCENARIO START CONDITION MALFUNCTION/OVERRIDE/ETC.

Tagout of 2-CC-P-1B Verify 2-CC-P-1A is running Place 2-CC-P-1B in PTL Remote functions:

U2_CCP1B_RACKIN = RACKOUT U2_CC_28 = 0 Failure of turbine to trip Malfunctions:

automatically or manually TU02 TU03 Block Auto Start of "B" CC Remote function:

Pump CCP1B_Auto_Defeat = T (Monitor point: CCP1_auto_defeat(2))

Failed auto-start of air Switch override:

compressors IAC1_AUTO = OFF SAC1_AUTO = OFF IAC2B_AUTO = OFF 2014 NRC 3 Page 24 Revision 0

SCENARIO EVENTS EVENT 1 Swap charging pumps MALFUNCTIONS/OVERRIDES The next event can occur once charging pumps are swapped, or at the direction of the lead evaluator.

COMMUNICATIONS Give communication that aux oil pump is in auto and running.

Give all communications required as AB operator for both charging pumps. This can include seal leakage - none, vibrations, etc.

Wait 3 or 4 minutes after "B" started to report condition.

Wait 3 or 4 minutes after "A" stopped to report condition.

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EVENT 2 Unit Ramp MALFUNCTIONS/OVERRIDES The next event can occur once enough of a power increase has been observed, or as directed by the lead examiner.

Discussion that this can happen once both A-C7 and A-C8 have been cleared. All 4 PR NIs

> 51%.

COMMUNICATIONS NOTE: During validation they did a 18 gpm dilution. Ramped up approximately 10% power.

When dilution was stopped they had put in 687 gallons of water.

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EVENT 3 Power range channel IV failure MALFUNCTIONS/OVERRIDES Malfunction:

NI0204, Delay time = 5, Ramp = 10, Severity = 1, Trigger = 3 The next event will occur after the crew restores control rods to AUTO, or as directed by the lead examiner.

COMMUNICATIONS If asked for permission to withdraw control rods to match Tave/Tref: wait 2 minutes and give permission from OMOC and/or Reactor Engineering.

NOTE: rods stepped to162 steps on D.

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EVENT 4 Loss of Instrument Air MALFUNCTIONS/OVERRIDES Malfunctions:

CA0402, Delay time = 5, Ramp = 60, Severity =20, Trigger = 4 CA02, Delay time = 5, Ramp = 60, Severity = 100, Trigger = 4 Check the following when the IA TV is closed:

CA0402 to be automatically deleted when crew closes containment isolation valve, after approximately 15 sec it will automatically delete malfunction CA02.

Can set up on triggers as follows:

(Deletes malfunction CA0402 when an IA trip valve is closed)

Trigger 14 TVIA102A_CLOSE(1)==1 .OR. TVIA102B_CLOSE==1 DMF CA0402 (Updates CA02 to 0 after 15 seconds when an IA trip valve is closed)

Trigger 15 TVIA102A_CLOSE(1)==1 .OR. TVIA102B_CLOSE==1 IMF CA02 (0 15) 0 Can delete the 1-IA-C-1 and 1-SA-C-1 air compressor overrides once they have been started in "HAND." This will make them look right after they are placed back in auto.

The next event can occur after the crew returns air pressure to normal, or as directed by the lead examiner.

COMMUNICATIONS Operators dispatched to investigate loss of IA will report that nothing abnormal was noted.

If asked to restore IA to containment using 1-IA-304, this is available on ExtremeView.

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EVENT 5 1-CH-LT-1112 fails high MALFUNCTIONS/OVERRIDES Malfunction:

CH1201, Delay time = 5, Ramp = 10, Severity = 1, Trigger = 5 The next event may occur once VCT level has been stabilized and TS reviewed, or as directed by the lead examiner.

COMMUNICATIONS If sent to look in VCT cube, can't see any water.

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EVENT 6 Loss of running CC pump/failure of standby pump to auto-start MALFUNCTIONS/OVERRIDES Malfunction:

CC0201, Delay time = 5, Trigger = 6 The next event can occur once the CC system has been returned to normal, or as directed by the lead examiner.

COMMUNICATIONS When sent to look at CC pump breaker (15H13), wait 3 minutes and report that it has an instantaneous overcurrent drop.

When sent to look at pumps in auxiliary building, wait 5 minutes and report that 1-CC-P-1A looks fine, just no longer running. 1-CC-P-1B is running fine with no leakage.

When asked to check CC heat exchanger delta Ps, they are unchanged from when you took logs (4 psid) 2014 NRC 3 Page 30 Revision 0

EVENT 7/8 Loss of MFW, reactor trip MALFUNCTIONS/OVERRIDES Malfunctions:

FW2101, Delay time = 5, Ramp = 30, Severity = 40, Trigger = 7 FW2102, Delay time = 15, Ramp = 45, Severity = 40, Trigger = 7 FW2103, Delay time = 25, Ramp = 60, Severity = 40, Trigger = 7 (Note: Making the severity of these too large or with too little of a ramp causes an MST abort.)

Alarm overrides:

V1DF8_W, Delay time = 70, Override = ON, Trigger = 7 V1DG8_W, Delay time = 100, Override = ON, Trigger = 7 V2GC8_W, Delay time = 105, Override = ON, Trigger = 7 V1AD3_W, Delay time = 110, Override = ON, Trigger = 7 Event 8, failure of turbine to trip automatically or manually, is pre-loaded.

The following will trip the terry turbine when flux has decreased to 10%. Verify that the pump trips before a heat sink is established.

Remote function:

MSTV115 = 0, Delay time = 60, Trigger =11 (RX23)

The following will cause a leak on AFW to "C" SG in the MSVH:

Malfunction:

FW1403, Delay time = 30, Ramp = 30, Severity = 100, Trigger = 7 Event 9 is pre-loaded on trigger 7 and will occur after 3 minutes.

COMMUNICATIONS A security officer (or operator if one has been dispatched to the area) will call the MCR on the gaitronics and inform the crew that there is a large amount of steam in the east end of the turbine building basement.

Once crew determines that AFW is not reaching "C" SG: security or an operator can report that there is water coming out of the door of the MSVH.

The operator dispatched to reset the overspeed trip valve will report that the throttle valve linkage is broken. Mechanics have been notified.

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EVENT 8 Loss of heat sink MALFUNCTIONS/OVERRIDES Malfunction:

FW1103, Delay time =180, Ramp = 300, Severity = 80, Trigger = 7 When crew has returned to step 1 of FR-H.1 and ready to return TT to service:

MSTV115 = 100, Ramp = 30 The scenario can be terminated once the crew has transitioned out of FR-H.1, or as directed by the lead examiner.

COMMUNICATIONS When dispatched, operator/mechanics after a sufficient amount of time (depending on whether you were already in the area) report that "B" AFW pump is not flowing and there is a metallic sound coming from the pump.

If sent: Mechanics think it probably has a cracked impeller.

Once crew determines that AFW is not reaching "C" SG: security or an operator can report that there is water coming out of the door of the MSVH.

If asked to look at leak in MSVH after leak has been isolated: Wait 5 minutes and then report that the location of the leak only affects the "C" SG.

The operator dispatched to reset the overspeed trip valve will report that the throttle valve linkage is broken. Mechanics have been contacted.

When TT trip valve has been repaired: Report that linkage is repaired and the valve has been reset.

2014 NRC 3 Page 32 Revision 0

ATTACHMENT 3 SCENARIO PERFORMANCE OBJECTIVES 2014 NRC 3 Page 33 Revision 0

EVENT 1 PERFORMANCE OBJECTIVES EVENT GOAL: Swap charging pumps to 1-CH- P-1B in service per 1-OP-8.9, "Transferring Running Charging Pumps."

NORTH ANNA SPECIFIC TASKS:

R593 Transfer the running charging pump.

CRITICAL TASK:

N/A 2014 NRC 3 Page 34 Revision 0

EVENT 2 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at approximately 49% power and the crew has been instructed to increase power, the crew will ramp the unit up in accordance with 1-OP-2.1, "Unit Startup from Mode 2 to Mode 1."

NORTH ANNA SPECIFIC TASKS:

R705 Dilute the RCS using the blender.

CRITICAL TASK:

N/A 2014 NRC 3 Page 35 Revision 0

EVENT 3 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power, and power-range channel IV has failed high resulting in rods stepping in, the crew will respond in accordance with 1-AP-4.3, "Malfunction of Nuclear Instrumentation (Power Range)."

NORTH ANNA SPECIFIC TASKS:

R494 Respond to a malfunction of the power-range nuclear instrumentation S70 Evaluate compliance with technical specifications CRITICAL TASK:

N/A 2014 NRC 3 Page 36 Revision 0

EVENT 4 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power, and a loss of instrument air inside containment has occurred, the crew will be expected to respond in accordance with 1-AP-28, "Loss of Instrument Air."

NORTH ANNA SPECIFIC TASKS:

R531 Respond to a loss of instrument air inside of containment.

CRITICAL TASK:

See next page.

2014 NRC 3 Page 37 Revision 0

CT Statement:

Crew starts all available air compressors.

Safety Significance:

Failure to start all available air compressors under the postulated plant conditions constitutes mis-operation or incorrect crew performance which leads to degradation of plant conditions which could result in a unit trip and/or safety injection. In this case, the instrument air pressure can be maintained above the trip set point by starting the air compressors.

Therefore, failure to start the air compressors also represents a "demonstrated inability by the crew to take an action or combination of actions that would prevent a challenge to plant safety."

Cues:

Instrument air low pressure alarm.

Meter indication of low instrument air pressure.

Performance Indicator:

BOP starts all available air compressors.

Feedback:

Instrument air pressure stabilizes above the trip set point.

WOG

Reference:

None Conditions:

Prior to reaching the (manual reactor) trip set point of 70 PSIG.

2014 NRC 3 Page 38 Revision 0

EVENT 5 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power and a failure of VCT level transmitter, 1-CH-LT-1112, the crew will respond in accordance with the applicable annunciator response.

NORTH ANNA SPECIFIC TASKS:

None CRITICAL TASK:

N/A 2014 NRC 3 Page 39 Revision 0

EVENT 6 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power, and the running component cooling pump has tripped, the crew will be expected to respond in accordance with 1-AP-15, "Loss of Component Cooling."

NORTH ANNA SPECIFIC TASKS:

None CRITICAL TASK:

N/A 2014 NRC 3 Page 40 Revision 0

EVENT 7 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power and a loss of main feedwater, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection."

NORTH ANNA SPECIFIC TASKS:

R185 Perform the immediate operator actions in response to a reactor trip or safety injection.

CRITICAL TASK:

See next page 2014 NRC 3 Page 41 Revision 0

CT Statement:

Crew manually trips the turbine.

Safety Significance:

Failure to trip the turbine under the postulated conditions would cause an additional RCS cooldown beyond that irreparably introduced by the scenario.

Cues:

Indication/annunciation that a reactor trip has occurred Indication that the turbine did not automatically or manually trip.

Indication of rapidly decreasing RCS temperatures Performance Indicator:

BOP places both EHC pumps in PTL OR manually runback turbine OR close MSTVs and bypass valves.

Feedback:

Annunciation/indication that all turbine stop valves are closed.

WOG

Reference:

E-0 Background Conditions:

Prior to a severe challenge (orange path) to subcriticality or integrity CSFs OR transition to ECA-2.1.

2014 NRC 3 Page 42 Revision 0

EVENT 9 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit has tripped and a total loss of main and auxiliary feedwater has occurred, the crew will respond in accordance with 1-FR-H.1, "Response to Loss of Secondary Heat Sink."

NORTH ANNA SPECIFIC TASKS:

R223 Initiate reactor coolant system bleed and feed in response to a loss of secondary heat sink.

CRITICAL TASK:

See Following Pages 2014 NRC 3 Page 43 Revision 0

CT Statement:

Crew stops Reactor Coolant Pumps.

Safety Significance:

Tripping the RCPs when entering this guideline "...can appreciably delay the need for bleed and feed and loss of secondary heat sink..." Failure to trip the RCPs "...can also reduce the effectiveness of bleed and feed. RCP heat input to the RCS will result in increased steam generation hindering the depressurization of the RCS during bleed and feed."

Cues:

Indication of:

• Reactor trip AND

• total feedwater flow less than 340 gpm, AND

• all SG levels less than 11%.

Performance Indicator:

RO/BOP places control switch(es) for all running RCPs in STOP.

Feedback:

Indication/annunciation of no RCPs running.

WOG

Reference:

FR-H.1 Background Conditions:

Prior to being required to initiate RCS bleed and feed.

2014 NRC 3 Page 44 Revision 0

ATTACHMENT 2 SIMULATOR PERFORMANCE DATASHEET

Scenario Performance Datasheet EVENT 1: Swap charging pumps to 1-CH- P-1B in service per 1-OP-8.9, "Transferring Running Charging Pumps."

SPD Verified: __________ (Initials)

• Amps increase on "B" charging pump when started

• Amps decrease on "A" charging pump when stopped EVENT 2: Given that the unit is at approximately 49% power and the crew has been instructed to increase power, the crew will ramp the unit up in accordance with 1-OP-2.1, "Unit Startup from Mode 2 to Mode 1."

SPD Verified: __________ (Initials)

• Reactor power increases

• Turbine power increases

• Tavg/Tref increase

• Generator megawatts increase EVENT 3: Given that the unit is at power, and power-range channel IV has failed high resulting in rods stepping in, the crew will respond in accordance with 1-AP-4.3, "Malfunction of Nuclear Instrumentation (Power Range)."

SPD Verified: __________ (Initials)

• Control rods step in

• Annunciators A-A7, A-B7, and A-D8 illuminate

• N-44 indication is failed high EVENT 4: Given that the unit is at power, and a loss of instrument air inside containment has occurred, the crew will be expected to respond in accordance with 1-AP-28, "Loss of Instrument Air."

SPD Verified: __________ (Initials)

• Annunciators F-F8, and J-E2 illuminates

• Instrument air and containment instrument air pressures decrease

• Compressors do not auto-start when required EVENT 5: Given that the unit is at power and a failure of VCT level transmitter, 1-CH-LT-1112, the crew will respond in accordance with the applicable annunciator response.

SPD Verified: __________ (Initials)

• Annunciator C-A4 illuminates

• 1-CH-LI-1112 will indicate off-scale high

• 1-CH-LCV-1112C output will go to zero

• VCT level will decrease

• "A" Stripper level will increase 2014 NRC 3 Date _________ Revision 0

Scenario Performance Datasheet EVENT 6: Given that the unit is at power, and the running component cooling pump has tripped, the crew will be expected to respond in accordance with 1-AP-15, "Loss of Component Cooling."

SPD Verified: __________ (Initials)

• Annunciators G-F5, C-C1, C-C2, and C-C3 illuminate (also G-B3, but it doesn't lock in)

• 1-CC-P-1A trips (green and amber lights lit)

• 1-CC-P-1B fails to auto-start EVENT 7/8: Given that the unit is at power and a loss of main feedwater, the crew will respond in accordance with 1-E-0, "Reactor Trip or Safety Injection."

SPD Verified: __________ (Initials)

• Annunciators F-B6 and G-F6 are illuminated

• Turbine does not trip automatically or manually

• 1-FW-P-2 starts and trips EVENT 9: Given that the unit has tripped and a total loss of main and auxiliary feedwater has occurred, the crew will respond in accordance with 1-FR-H.1, "Response to Loss of Secondary Heat Sink."

SPD Verified: __________ (Initials)

• Annunciators F-D8 is illuminated

• 1-FW-P-3B degrades over a period of time

• Steam driven aux feed pump has no discharge flow

• "C" SG WR level does not increase as expected 2014 NRC 3 Date _________ Revision 0

SCENARIO TURNOVER SHEET Read the following to the crew:

Purpose: This examination is intended to evaluate the crews performance of various tasks associated with the Initial License Operator Training Program. All activities should be completed in accordance with approved operations standards.

1. You are on a day shift during the week.

2. A rough log should be maintained to aid in making reports and to help during briefs.

3. Respond to what you see. In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated and the crew informed.

Unit Status:

Unit 1 is at 49% power. Unit was returned to power 2 days ago following work on the generator exciter. Power has been at 49% for several days due to a problem with a containment sump pump. The sump pump has been replaced and the unit as been cleared to increase power to 100%. RCS boron is 1537 ppm and core age is 150 MWD/MTU. Aux steam is on unit 2.

Unit 2 is at 100% power.

Equipment Status:

!-FW-P-2 (terry turbine) was just returned to service last shift. 2-CC-P-1B was tagged out last shift for major maintenance. It is expected to be out for several more days.

Maintenance rule window is green Protected train is 2H.

Shift Orders:

Swap charging pumps to "B" for an upcoming PT, then ramp the unit to 100% power

Please prebrief the charging pump swap and the unit ramp.

The RO has been designated to place 1-CH-P-1B in service and place 1-CH-P-1A in Auto.

Mike Brophy has a copy of 1-OP-8.9 and is available for the pump swap evolution. He has already done an initial look at 1-CH-P-1B and it has no obvious problems.

The purge of 1-CH-P-1B to the VCT was completed last shift Rods are currently at 160 steps on "D" bank RCS boron is 1537 ppm Time in life is 150 MWD/MTU Tave is currently 562°F Tref is currently 561°F The reactor engineer has determined that it will take approximately 3050 gallons of water to reach 100% power, ARO.

• • • A Non-Controlled Document ***

Unit 1 OATC Protected This Sheet updated on: Today 2H Power: 49 GV Position 9  % BLOWDOWNS Boron: 1,537 ppm TURBINE REF: 46.6 1.0% on limiter CD: 2 GPM Dilutions: 1-3 7 gal 'A' BAST: 14,043 ppm SW: secured PG/°F Change: 36 Gls. IN PIPE: PG BC: Secured on U-1 BA/°F Change: 4.4 Gls. CATION BED: Secured S/G: Hi cap 60/60/60 BLEND RATIO: 8.1 to 1 Aux Stm Supply: U2 2nd PT Approximate 1-RC-PCV-1444J 56 % 1-RC-LCV-1459G 39 %

Outputs 1-CH-PCV-1145 80 % 1-CC-TCV-106 27 %

Limiting Actions: None Items Tagged: 2-CC-P-1B Items OOC:

Annunciators Lit 1-LOG-14:

Problems/OWA:

OD's OD-555: 1H EDG Mech Stop (Mushroom) Pushbutton may not work to stop 1H EDG OD-542: AFW Pipe Tunnel Missile Protection ODM's ODM-309: B&C RCP seals, < 0.8 seal leakoff (AR 1C-G8), PG < 90 °, RCS@175 ppm MISC Maintain VCT Pressure < 35 psig per Chemistry request 1-FW-P-2 returned to operable last shift. Previously tagged for work on governor valve.

Open Procedures:

PT's Days: PT's Nights:

Normal Nightlies

Reactivity Worksheet This calculation made on: Sunday June 1, 2014 14:18:36 Cycle Data file: N1C24 Cycle Data Updated: 9/25/2013 Core Burnup 150.0 MWD/MTU PG (blend)

RCS Cb 1,537 ppm 75 gpm BAST Cb 14,043 ppm 5.00 pot ITC -6.3 pcm/°F Boric Acid (blend)

PC -10.9 pcm/% 9.2 gpm Boron Coefficient -5.75 pcm/ppm 4.61 pot (ITEM 1) = ITC/Boron Coefficient = 1.10 ppm/°F (ITEM 2) = PC/Boron Coefficient = 1.90 ppm/%

PG needed to raise RCS temperature 1ºF*

50455.4

• ln (RCS CB/(RCS CB - ITEM 1)) 36 gallons of PG Boron needed to lower RCS temperature 1ºF 50455.4

• ln ((BAST CB - RCS CB) / (BAST CB - (RCS CB + ITEM 1)) 4.4 gallons of acid PG needed to raise Reactor Power 1%*

50455.4

• ln (RCS CB/(RCS CB - ITEM 2)) 62 gallons of PG Boron needed to lower Reactor Power 1%

50455.4

• ln ((BAST CB - RCS CB) / (BAST CB - (RCS CB + ITEM 2)) 7.7 gallons of acid BLEND RATIO CALCULATION (BAST CB - RCS CB) / RCS CB 8.1 to 1 ratio

• Denotes Calculations that have been corrected for B-10 RCS Makeup Table PG BA PG BA PG BA 120 gpm 14.7 gpm 80 gpm 9.8 gpm 40 gpm 4.9 gpm 8.00 pot 7.37 pot 5.33 pot 4.92 pot 2.67 pot 2.46 pot PG BA PG BA PG BA 110 gpm 13.5 gpm 70 gpm 8.6 gpm 30 gpm 3.7 gpm 7.33 pot 6.76 pot 4.67 pot 4.30 pot 2.00 pot 1.84 pot PG BA PG BA PG BA 100 gpm 12.3 gpm 60 gpm 7.4 gpm 20 gpm 2.5 gpm 6.67 pot 6.15 pot 4.00 pot 3.69 pot 1.33 pot 1.23 pot PG BA PG BA PG BA 90 gpm 11.1 gpm 50 gpm 6.1 gpm 10 gpm 1.2 gpm 6.00 pot 5.53 pot 3.33 pot 3.07 pot 0.67 pot 0.61 pot Prepared:________ Reviewed:________

Page 1 of 1 49% power reactivity sheet.xls

PROCEDURE NO:

1-OP-8.9 REVISION NO:

NORTH ANNA POWER STATION 11 PROCEDURE TYPE: UNIT NO:

OPERATING PROCEDURE 1 PROCEDURE TITLE:

TRANSFERRING RUNNING CHARGING PUMPS REACT MGT REVISION

SUMMARY

Revised the procedure as follows for OP 14-0018 and OP 14-0116:

• Added a Note prior to Step 5.1.3 that It is not necessary to wait on sample results prior to continuing. Sample is for trending only.

• Added new Step 5.1.3.c that If VCT level does not decrease as expected, indicating that the sample line is plugged, terminate the purge and enter a CR.

• Made similar changes for Sections 5.2 and 5.3.

• On cover page special review bar, changed RX MAN to REACT MGT for consistency.

PROBLEMS ENCOUNTERED: NO YES Note: If YES, note problems in remarks.

UNIT ONE REMARKS: ________________________________________________________________________________________________

_________________________________________________________________________________________________________

_________________________________________________________________________________________________________

_________________________________________________________________________________________________________

_________________________________________________________________________________________________________

______________________________________________________________________________ (Use back for additional remarks.)

SRO: DATE:

CONTINUOUS USE

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 2 of 17 1.0 PURPOSE To provide instructions for transferring Charging Pumps when the pump to be started is operable. (References 2.4.1 and 2.4.3)

The following synopsis is designed as an aid to understanding the procedure, and is not intended to alter or take the place of the actual purpose, instructions, or text of the procedure itself.

To ensure the proper Charging Pump procedure selection, note the following:

• 1-OP-8.1, Chemical and Volume Control System, is used to align the Prestart Auxiliary Equipment for Charging Pumps, starting or transferring Charging Pumps when any RCS Tc is 280°F (including when on a VCT Float).

Necessary breaker manipulations are directed to 0-OP-26.9.

• 1-OP-8.9, Transferring Running Charging Pumps, is used to start and stop Charging Pumps when ALL RCS Tcs are > 280°F and when the Charging Pump being placed in service is already operable.

• 1-MOP-8.01, 8.02, and 8.03 (Charging Pump maintenance procedures), are used to remove/return Charging Pumps A, B, and C (respectively) from service for maintenance.

• 1-PT-14.1, 14.2, and 14.3 (Charging Pump periodic test procedures), are used to test Charging Pumps A, B, and C (respectively) for operability following major maintenance or as scheduled by surveillance test requirements.

This OP is designed to allow the Operator to quickly transfer the Operable Charging Pump to another Charging Pump. It has been accepted that for normal Charging Pump transfers, verification of Service Water, Auxiliary Building Central Area Exhaust System, and Charging Pump MOV alignments are not required. This acceptance is based on operability requirements being already verified in the appropriate MOPs and no Action Statements or Abnormal Status conditions being recorded that could impede operation of the selected Charging Pump (Generic Step _______ of procedure).

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 3 of 17

2.0 REFERENCES

2.1 Source Documents 2.1.1 UFSAR Section 9.3.4.1, Chemical and Volume Control System, Design Basis 2.2 Technical Specifications 2.2.1 Tech Spec 3.5.2 2.2.2 Tech Spec 3.5.3 2.2.3 TRM 3.1.1 2.3 Technical References 2.3.1 Memo from R. P. Brodie and J. Goerge to CH PP Task Team and Associates, dated 12-02-93, STREAMLINED CH PP TRANSFER PROCEDURE OP-8.9 2.3.2 REA 93-310, DCP 95-226, Charging Pump Interlock Removal 2.3.3 ET N-00-033, Rev. 0, Charging Pump Dilution/Boration 2.3.4 DCP 01-007, Phase 2 PCS Installation and P-250 Removal - Unit 1 2.4 Commitment Documents 2.4.1 OP-163, develop a Charging Pump package for review incorporating all the findings of Charging Pump Task Team.

2.4.2 CTS Assignment 02-94-0500, Commitment 003, Independent Verification of control switch position 2.4.3 CTS Assignment 02-93-2503, Commitment 002, Make CVCS procedures more specific and user friendly

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 4 of 17 2.4.4 License Amendment 242, Tech Spec Change N-029, Heat Up and Cooldown operating limits, PORV lift setpoints, LTOPS enable temperature 2.4.5 PI S-1998-2462, Boron Concentration in Charging Pump Different from RCS 2.4.6 TRM Change 094, Boration Flow Path 2.4.7 SAA009529; SAR000956: Reactivity Management 2.4.8 CA270886, Revise Procedures to Flush Iron From Charging Pumps 3.0 INITIAL CONDITIONS

_______ 3.1 Review the equipment status to check station configuration supports the performance of this procedure.

_______ 3.2 ALL RCS Tcs are > 280°F.

4.0 PRECAUTIONS AND LIMITATIONS 4.1 Comply with the following guidelines when marking steps N/A:

_______

• IF the conditional requirements of a step do not require the action to be performed, THEN mark the step N/A.

_______

• IF any other step is marked N/A, THEN have the SRO (or designee) approve the N/A and justify the N/A on the Procedure Cover Sheet.

_______ 4.2 This procedure should only be used to transfer Charging Pumps when the pump to be placed in service is already operable, or for transferring power supplies for C Charging Pump when C Charging Pump is available for service. IF breaker racking will be required for A or B Charging Pump starts, THEN 1-OP-8.1 Chemical and Volume Control System, should be used. (Reference 2.4.1)

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 5 of 17

_______ 4.3 The following Charging Pump motor starting limits must be observed:

• Motor cold 2 consecutive starts

• Motor hot 1 consecutive start

• Subsequent starts with motor running between starts 15 minutes apart

• Subsequent starts with motor idle between starts 60 minutes apart

_______ 4.4 The suction temperature of the Charging Pumps MUST NOT exceed 130°F.

_______ 4.5 One Seal Water Injection Filter MUST be in service at all times.

_______ 4.6 The total normal flow on any one Charging Pump is between 60 and 150 gpm.

_______ 4.7 Before a Charging Pump is started, PCS Group Display should be set on a short interval to trend bearing temperatures.

_______ 4.8 The following Tech Specs/TRM apply:

• Tech Spec 3.5.2

• Tech Spec 3.5.3

• TRM 3.1.1

_______ 4.9 Piping associated with a Charging Pump that has been secured for a significant period of time (60 days) could contain liquid that has a significant difference in Boron Concentration from current RCS Conditions. This difference can be eliminated by flushing the Charging Pump piping with liquid from the VCT.

(Reference 2.4.5)

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 6 of 17

_______ 4.10 The following chart will provide guidance to evaluate the impact on reactor power when starting a Charging Pump that has been idle for an extended period of time (60 days) and the boron concentration between the pump and RCS is different.

(Reference 2.4.5)

Time In Core  % Core Power Life RCS Boron CH Pp Boron Change BOL 1500 ppm +/- 240 ppm of RCS +/- 0.098%

MOL 800 ppm +/- 240 ppm of RCS +/- 0.071%

EOL 0 ppm + 240 ppm of RCS - 0.062%

BOL 1500 ppm 2600 ppm - 0.447%

EOL 0 ppm 2600 ppm -0.668%

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 7 of 17 Init Verif 5.0 INSTRUCTIONS 5.1 Transferring To 1-CH-P-1A CAUTION This procedure should only be used to transfer Charging Pumps when the pump to be placed in service is already operable. (Reference 2.4.1)

CAUTION The following Charging Pump motor starting limits must be observed:

• Motor cold two (2) consecutive starts

• Motor hot one (1) consecutive start

• Subsequent starts with motor running between starts 15 minutes apart

• Subsequent starts with motor idle between starts 60 minutes apart

_______ 5.1.1 Check Initial Conditions are satisfied.

_______ 5.1.2 Review Precautions and Limitations.

NOTE: If this procedure is being performed under emergency conditions the following step may be marked N/A.

NOTE: Thirty gallons of water will be flushed through the charging pump casing.

VCT level should be sufficiently high to accommodate an approximately 2 percent level decrease.

NOTE: It is not necessary to wait on sample results prior to continuing. Sample is for trending iron content.

5.1.3 Purge 1-CH-P-1A as follows: (Reference 2.4.8)

_______ a. Have Chemistry Department perform CH-11.250, Charging Pump Discharge: Sampling By Purging To Gas Stripper.

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 8 of 17

_______ b. Monitor VCT level for an approximately 2 percent level change.

c. IF VCT level does not decrease as expected, indicating that the sample line is plugged, THEN do the following:

_______ 1. Notify Chemistry Department to terminate sampling purge using CH-11.250, Charging Pump Discharge: Sampling By Purging To Gas Stripper.

_______ 2. Enter a Condition Report.

_______ 5.1.4 Place a PCS Group Display on a short interval to trend charging pump bearing temperatures.

_______ 5.1.5 Have the Unit SRO determine if the boron concentration in 1-CH-P-1A will SRO adversely affect Reactor Power. (Reference 2.4.5)

_______ 5.1.6 IF Reactor Power will be adversely affected, THEN take action to minimize SRO affect: (Reference 2.4.5)

• Adjust RCS boron to compensate.

• Adjust Reactor Power.

• Purge affected Charging Pump to Sample Sink using 1-MOP-8.01, 1-CH-P-1A, A Charging Pump.

_______ 5.1.7 Check the control switch for 1-CH-P-1A1, A Chg Pump Aux Oil Pump, is in AUTO and the pump is running.

_______ 5.1.8 Start 1-CH-P-1A.

NOTE: Regulating the temperature of the oil out of the oil cooler at less than 128°F will maintain a satisfactory thrust bearing temperature of less than 171°F.

_______ 5.1.9 Check temperature at 1-SW-TI-103A, CHG A LO OUT TEMP, is < 128°F.

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 9 of 17 5.1.10 Stop the previously running Charging Pump by placing the control switch in AUTO-AFTER-STOP for 1-CH-P-1B or AFTER STOP for 1-CH-P-1C.

Mark the remaining pump N/A: (Reference 2.4.2)

_______ _______

• 1-CH-P-1B IV

_______ _______

• 1-CH-P-1C (NORM)

IV

_______ _______

• 1-CH-P-1C (ALT)

IV

_______ 5.1.11 WHEN bearing temperatures have stabilized, THEN return the PCS Group Display to a normal interval.

Completed by: ___________________________________________ Date: _________

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 10 of 17 5.2 Transferring To 1-CH-P-1B CAUTION This procedure should only be used to transfer Charging Pumps when the pump to be placed in service is already operable. (Reference 2.4.1)

CAUTION The following Charging Pump motor starting limits must be observed:

• Motor cold two (2) consecutive starts

• Motor hot one (1) consecutive start

• Subsequent starts with motor running between starts 15 minutes apart

• Subsequent starts with motor idle between starts 60 minutes apart

_______ 5.2.1 Check Initial Conditions are satisfied.

_______ 5.2.2 Review Precautions and Limitations.

NOTE: If this procedure is being performed under emergency conditions the following step may be marked N/A.

NOTE: Thirty gallons of water will be flushed through the charging pump casing.

VCT level should be sufficiently high to accommodate an approximately 2 percent level decrease.

NOTE: It is not necessary to wait on sample results prior to continuing. Sample is for trending iron content.

5.2.3 Purge 1-CH-P-1B as follows: (Reference 2.4.8)

_______ a. Have Chemistry Department perform CH-11.250, Charging Pump Discharge: Sampling By Purging To Gas Stripper.

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 11 of 17

_______ b. Monitor VCT level for an approximately 2 percent level change.

c. IF VCT level does not decrease as expected, indicating that the sample line is plugged, THEN do the following:

_______ 1. Notify Chemistry Department to terminate sampling purge using CH-11.250, Charging Pump Discharge: Sampling By Purging To Gas Stripper.

_______ 2. Enter a Condition Report.

_______ 5.2.4 Place a PCS Group Display on a short interval to trend charging pump bearing temperatures.

_______ 5.2.5 Have the Unit SRO determine if the boron concentration in 1-CH-P-1B will SRO adversely affect Reactor Power. (Reference 2.4.5)

_______ 5.2.6 IF Reactor Power will be adversely affected, THEN take action to minimize SRO affect: (Reference 2.4.5)

• Adjust RCS boron to compensate.

• Adjust Reactor Power.

• Purge affected Charging Pump to Sample Sink using 1-MOP-8.02, 1-CH-P-1B, B Charging Pump.

_______ 5.2.7 Check the control switch for 1-CH-P-1B1, B Chg Pump Aux Oil Pump, is in AUTO and the pump is running.

_______ 5.2.8 Start 1-CH-P-1B.

NOTE: Regulating the temperature of the oil out of the oil cooler at less than 128°F will maintain a satisfactory thrust bearing temperature of less than 171°F.

_______ 5.2.9 Check temperature at 1-SW-TI-103B, CHG B LO OUT TEMP, is < 128°F.

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 12 of 17 5.2.10 Stop the previously running Charging Pump by placing the control switch in AUTO-AFTER-STOP for 1-CH-P-1A or AFTER STOP for 1-CH-P-1C.

Mark the remaining pump N/A: (Reference 2.4.2)

_______ _______

• 1-CH-P-1A IV

_______ _______

• 1-CH-P-1C (NORM)

IV

_______ _______

• 1-CH-P-1C (ALT)

IV

_______ 5.2.11 WHEN bearing temperatures have stabilized, THEN return the PCS Group Display to a normal interval.

Completed by: ___________________________________________ Date: _________

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 13 of 17 5.3 Transferring To 1-CH-P-1C CAUTION This procedure should only be used to transfer Charging Pumps when the pump to be placed in service is already operable, or for transferring power supplies for C Charging Pump when C Charging Pump is available for service.

CAUTION The following Charging Pump motor starting limits must be observed:

• Motor cold two (2) consecutive starts

• Motor hot one (1) consecutive start

• Subsequent starts with motor running between starts 15 minutes apart

• Subsequent starts with motor idle between starts 60 minutes apart

_______ 5.3.1 Check Initial Conditions are satisfied.

_______ 5.3.2 Review Precautions and Limitations.

NOTE: If this procedure is being performed under emergency conditions the following step may be marked N/A.

NOTE: Thirty gallons of water will be flushed through the charging pump casing.

VCT level should be sufficiently high to accommodate an approximately 2 percent level decrease.

NOTE: It is not necessary to wait on sample results prior to continuing. Sample is for trending iron content.

5.3.3 Purge 1-CH-P-1C as follows: (Reference 2.4.8)

_______ a. Have Chemistry Department perform CH-11.250, Charging Pump Discharge: Sampling By Purging To Gas Stripper.

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 14 of 17

_______ b. Monitor VCT level for an approximately 2 percent level change.

c. IF VCT level does not decrease as expected, indicating that the sample line is plugged, THEN do the following:

_______ 1. Notify Chemistry Department to terminate sampling purge using CH-11.250, Charging Pump Discharge: Sampling By Purging To Gas Stripper.

_______ 2. Enter a Condition Report.

_______ 5.3.4 Place a PCS Group Display on a short interval to trend charging pump bearing temperatures.

_______ 5.3.5 Have the Unit SRO determine if the boron concentration in 1-CH-P-1C will SRO adversely affect Reactor Power. (Reference 2.4.5)

_______ 5.3.6 IF Reactor Power will be adversely affected, THEN take action to minimize SRO affect: (Reference 2.4.5)

• Adjust RCS boron to compensate.

• Adjust Reactor Power.

• Purge affected Charging Pump to Sample Sink using 1-MOP-8.03, 1-CH-P-1C, C Charging Pump.

_______ 5.3.7 IF 1-CH-P-1C is NOT being supplied by the desired Bus, THEN transfer power supplies using Subsection 5.4.

_______ 5.3.8 Check the control switch for 1-CH-P-1C1, C Chg Pump Aux Oil Pump, is in AUTO and the pump is running.

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 15 of 17 5.3.9 Start 1-CH-P-1C using appropriate control switch for Bus supplying pump:

_______

• IF H Bus is supplying power, THEN C (NORM).

_______

• IF J Bus is supplying power, THEN C (ALT).

NOTE: Regulating the temperature of the oil out of the oil cooler at less than 128°F will maintain a satisfactory thrust bearing temperature of less than 171°F.

_______ 5.3.10 Check temperature at 1-SW-TI-103C, CHG C LO OUT TEMP, is < 128°F.

5.3.11 Stop the previously running Charging Pump by placing the control switch in AUTO-AFTER-STOP. Mark the remaining pump N/A: (Reference 2.4.2)

_______ _______

• 1-CH-P-1A IV

_______ _______

• 1-CH-P-1B IV

_______ 5.3.12 WHEN bearing temperatures have stabilized, THEN return the PCS Group Display to a normal interval.

Completed by: ___________________________________________ Date: _________

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 16 of 17 5.4 Transferring Power Supplies for 1-CH-P-1C CAUTION This procedure should only be used to transfer Charging Pumps when the pump to be placed in service is already operable, or for transferring power supplies for C Charging Pump when C Charging Pump is available for service.

_______ 5.4.1 Check Initial Conditions are satisfied.

_______ 5.4.2 Review Precautions and Limitations.

_______ 5.4.3 IF 1-CH-P-1C is operating, THEN transfer to 1-CH-P-1A using Subsection 5.1 OR to 1-CH-P-1B using Subsection 5.2.

5.4.4 Ensure both control switches for 1-CH-P-1C are in PULL-TO-LOCK:

_______

• 1-CH-P-1C (NORM)

_______

• 1-CH-P-1C (ALT) 5.4.5 Ensure both breakers for 1-CH-P-1C are racked out to DISCONNECT using 0-OP-26.9 or 0-GOP-26.9, 4160 Volt Breaker Operation:

_______ _______

• 1-EE-BKR-15H7 IV

_______ _______

• 1-EE-BKR-15J7 IV 5.4.6 Rack in the desired breaker for 1-CH-P-1C to CONN using 0-OP-26.9 or 0-GOP-26.9, 4160 Volt Breaker Operation:

_______ _______

• 1-EE-BKR-15H7 IV

_______ _______

• 1-EE-BKR-15J7 IV

DOMINION 1-OP-8.9 North Anna Power Station Revision 11 Page 17 of 17 5.4.7 Place the C Charging Pump control switch in the AFTER - STOP for the breaker racked to CONN. Mark the remaining switch N/A:

(Reference 2.4.2)

_______ _______

• 1-CH-P-1C (NORM)

IV

_______ _______

• 1-CH-P-1C (ALT)

IV Completed by: ___________________________________________ Date: _________

Appendix D Scenario Outline Form ES-D-1 Facility: North Anna Power Station Scenario No.: (2014) NRC-4 Op-Test No.: 1 Examiners: ___________________________ Operators: _____________________________

___________________________ _____________________________

___________________________ _____________________________

Initial Conditions: Unit at 100% power. MOL. 1-FW-P-2 returned to service last shift. 2-CC-P-1B was tagged out last shift for major maintenance and is not expected to be returned to service for several days.

Turnover: Maintain current plant conditions.

Event Malf. Event Event No. No. Type* Description 1 N (R) (S) Makeup to RWST 2 FW3202 I (B) (S) "B" SG Median SG level channel fails. Level control remains in TRM (S) manual.

3 RC29 C (R) (S) Master pressure controller fails high causing PORV and spray valves to open. All can be closed. (CT)

TS (S) 4 C (B) (S) Running BC pump trips and standby pump does not automatically start.

5 RC2401 C (All) "A" SGTL requiring 1-AP-24 entry 6 RC2401 R (R) (S) SGTL increases to >100 gpd requiring unit ramp N (B)

TRM (S) 6a C (R) (S) Control rods fail to move in automatic during load reduction (after initially moving) 7 RC1203 C (R) (S) Seal leak on "C" RCP requires pump shutdown and isolation after reactor trip (CT) 8 RC2401 M (All) SGTL increases to SGTR requiring SI (2 CTs) 9 MS0501 C (B) (S) "A" MSTV cannot be closed Event 9 happens during event 8 and is numbered only for use on subsequent forms.

The scenario can be terminated once safety injection has been terminated in 1-E-3.

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

DOMINION NORTH ANNA POWER STATION INITIAL LICENSED OPERATOR EXAMINATION SIMULATOR EXAMINATION GUIDE SCENARIO 2014 NRC4 2014 NRC 4 Page 2 Revision 1

SIMULATOR EXAMINATION GUIDE EVENT DESCRIPTION

1. Makeup to RWST

2. "B" SG Median SG level channel fails

3. Master pressure controller fails high causing PORV and spray valves to open. All can be closed. (CT)

4. Running BC pump trips and standby pump does not automatically start.

5. "A" SGTL 6/6a. SGTL increases to >100 gpd requiring unit ramp Control rods fail to insert automatically

7. Seal leak on "C" RCP requires reactor to be tripped, pump shutdown and isolation (CT)

8. SGTR (4 CTs)

9. "A" MSTV cannot be closed Scenario Recapitulation:

Malfunctions after EOP entry 2 (SGTR, "A" MSTV cannot be closed)

Total Malfunctions 8 (SG Median SG level channel failure, master pressure controller failure, trip of running bearing cooling pump with failure of standby pump to auto start, "A" SGTL, control rods fail to insert automatically, SGTR, seal leak on "C" RCP, "A" MSTV cannot be closed.)

Abnormal Events 5 (SG Median SG level channel failure, master pressure controller failure, trip of running bearing cooling pump with failure of standby pump to auto start, "A" SGTL, seal leak on "C" RCP)

Major Transients 1 (SGTR)

EOPs Entered 1 (E-3)

EOP Contingencies 0 Critical Tasks 4 SCENARIO DURATION 125 Minutes 2014 NRC 4 Page 3 Revision 1

SIMULATOR EXAMINATION SCENARIO

SUMMARY

SCENARIO 2014 NRC4 The scenario will start with Unit 1 at 100% power MOL. 1-FW-P-2 was returned to service last shift following governor valve work. Unit 2 is also at 100% power with Auxiliary Steam being supplied by Unit 2 extraction steam. 2-CC-P-1B was tagged out for major maintenance last shift and is not expected to be returned to service for several days. Shift orders are to use the Unit 1 blender to perform a makeup to the RWST of 500 gallons at 3000 ppm for boron concentration adjustment.

Once the crew assumes the watch, they will perform a makeup to the RWST. Once the makeup has been completed, the next event may occur. (NOTE: This event can be pre-briefed.)

At this time, "B" SG median level will fail. The crew will use the annunciator response for F-F2 to take manual control of "B" SG level and restore feedwater flow and level to normal. The US will refer to the TRM. Once SG level has been restored the next event can occur. Level control will remain in manual for the rest of the scenario.

Next, the PRZR master pressure controller will fail causing PORV, 1-RC-PCV-1455C, to open. The US will direct the crew to enter 1-AP-44, "Loss of RCS Pressure." The RO will manually close the open PORV and take manual control of the master pressure controller and close the spray valves.

Next, the running BC pump breaker will trip. The crew should identify annunciators associated with the loss of BC and the US should direct the crew to enter 1-AP-19, "Loss of Bearing Cooling Water." The crew will identify the failure of the standby BC pump to auto-start and manually start the pump. Once the crew has stabilized the plant, the next event will occur.

Now, a tube leak will occur on "A" SG. The first indication will be the N-16 radiation monitor for "A" SG indicating increased leakage. The US should direct the crew to enter 1-AP-5, "Unit 1 Radiation Monitoring System," and direct HP/Chemistry to obtain and analyze a "A" SG blowdown sample. Eventually, the main steamline header N-16 monitor indication will increase and Chemistry will inform the crew that they have indications of a tube leak on the "A" SG. Based on confirmed leakage, the US should direct the crew to enter 1-AP-24, "Steam Generator Tube Leak."

The US should refer to technical specifications and the TRM for primary to secondary leakage.

The steam generator tube leakage will increase to the point where a unit ramp is required per the TRM. The crew will commence a unit ramp using 1-AP-2.1, "Fast Load Reduction." Control rods will fail to insert automatically and the RO will have to maintain temperature and pressure manually during the ramp.

There will be a #1 seal failure on the "C" RCP. The crew will respond IAW 1-AP-33.1, "Reactor Coolant Pump Seal Failure." They will identify that the high seal leakage requires that the "C" RCP be secured. The crew will enter 1-E-0, "Reactor Trip or Safety Injection," trip the reactor, stop the "C" RCP, and close the seal leakoff valve. When the reactor coolant pump is secured the next event will happen automatically.

2014 NRC 4 Page 4 Revision 1

The steam generator tube leakage will increase to where a safety injection is required. The crew will continue in 1-E-0, eventually transitioning to 1-E-3, "SGTR." When the crew attempts to close the MSTV for the ruptured SG it will not close and the crew will have to close the associated NRV. The crew will cooldown and depressurize the RCS and then terminate safety injection. At this time the scenario will be terminated.

2014 NRC 4 Page 5 Revision 1

SCENARIO TURNOVER SHEET Read the following to the crew:

Purpose: This examination is intended to evaluate the crews performance of various tasks associated with the Initial License Operator Training Program. All activities should be completed in accordance with approved operations standards.

1. You are on a day shift during the week.

2. A rough log should be maintained to aid in making reports and to help during briefs.

3. Respond to what you see. In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated and the crew informed.

Unit Status:

Unit 1 is at 100% power. RCS boron is 988 ppm and core age is 9,000 MWD/MTU. Aux steam is on unit 2.

Unit 2 is at 100% power.

Equipment Status:

1-FW-P-2 was returned to service last shift. Maintenance rule window is green. 2-CC-P-1B was tagged out last shift for major maintenance. It is expected to be out for several more days. Protected train is 2H.

Shift Orders:

Makeup to the Unit 1 RWST using the unit 1 blender. Add 500 gallons of water at approximately 3000 ppm boron. Maintain current plant conditions.

2014 NRC 4 Page 6 Revision 1

EVENT 1: Given that a makeup to the RWST has been requested, the crew will use 1-OP-7.7, "Refueling Water Storage Tank System Operation" to adjust boron concentration.

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Blender functions as expected Crew informs HP of the RWST makeup and the anticipated volume addition.

RO directs an operator to close 1-CH-232 and open 1-CH-233.

RO records the as-found positions for 1-CH-FC-1113A, 1-CH-FC-1114A and 1-CH-HFC-1114.

RO turns the blender control switch to STOP.

RO closes 1-CH-FCV-1113A, 1-CH-FCV-1113B and 1-CH-FCV-1114B (IV required)

RO determines the required flow for desired concentration of the blend. (Given at turnover.)

RO adjusts integrators on blenders.

RO requests AB operator to open 1-CH-230.

Crew informs HP count room that makeup to the RWST will commence.

RO places blender mode selector switch in Manual.

RO places blender control switch in START.

RO ensures control switch for 1-CH-FCV-1113A in desired position.

RO adjusts 1-CH-FC-1113A and 1114A for desired flow.

Crew performs channel checks on RWST indications and verifies level channels agree within 3% and that levels are increasing.

NOTE: The crew may set up a blend at the current RCS boron concentration and perform a short blend to flush the blender. This is not required.

2014 NRC 4 Page 7 Revision 1

EVENT 1: Given that a makeup to the RWST has been requested, the crew will use 1-OP-7.7, "Refueling Water Storage Tank System Operation" to adjust boron concentration.

TIME EXPECTED ACTION INSTRUCTOR REMARKS RO places 1-CH-FCV-1113A in close and places blender control switch in STOP when desired volume has been added.

RO has operator close valves in AB (and has them IV'd).

RO places blender valves in automatic.

RO ensures blender controller is returned to the as-found settings.

RO uses 1-OP-8.3 to adjust blender controller settings, if desired.

RO returns the blender to AUTO using 1-OP-8.3, if required.

RO ensures the 1-CH-DCC-1113 integrator setpoint values are set correctly.

Crew notifies chemistry to sample the RWST.

NOTE: The next event can occur once Validation time: 35 minutes the RWST makeup has been completed, or as directed by the lead examiner.

2014 NRC 4 Page 8 Revision 1

EVENT 2: Given that the unit is at power and "B" SG median select level has failed, the crew will respond in accordance with the AR for annunciator F-F2.

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciator F-F2 illuminates

• "B" FRV modulates closed

• "B" SG level decreases BOP identifies annunciator F-F2, SG 1B LEVEL ERROR, is illuminated.

BOP identifies that "B" SG level is decreasing and "B" MFRV is closing.

US directs crew to obtain annunciator response for annunciator F-F2.

BOP takes manual control of "B" MFRV and adjusts FW flow to restore level to normal.

US or BOP determine a control band for "B" SG level.

US requests CR and I&C support for failure.

US refers to TR 3.3.11A and verifies that the "B" MFRV is in manual within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

NOTE: The next event can occur once Level control will remain in manual.

"B" SG level has been restored to Validation time: 6 minutes normal, or as directed by the lead examiner.

2014 NRC 4 Page 9 Revision 1

EVENT 3: Given the unit is at power and the PRZR pressure master controller fails high, the crew will respond in accordance with 1-AP-44, "Loss of Reactor Coolant System Pressure."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciators B-E6, C-D1, and later B-F7 illuminate

• Master pressure controller fails high

• 1-RC-PCV-1455C indicates open

• 1-RC-PCV-1455A and 1455B indicate open

• RCS pressure decreases Crew identifies annunciator B-E6, PRZR PRESS CONT HI OUTPUT.

US directs crew to enter 1-AP-44.

RO verifies PRZR PORVs closed. (NO)

CT1 Crew stops RCS pressure decrease. *Prior to receiving an automatic IOAs

• RO closes 1-RC-PCV-1455C. reactor trip on low pressure

• RO checks master pressure controller controlling properly. (NO)

• RO places master pressure controller to manual and adjusts to stabilize and restore pressure.

IOA RO verifies PRZR spray valves closed.

RO verifies all PRZR heaters energized.

RO verifies auxiliary spray valve closed.

Crew verifies PORV and safety valves closed.

RO verifies RCS pressure stable or increasing.

RO verifies RCS pressure normal and adjusts sprays or heaters, as required.

US refers to:

TS 3.4.1A - DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to restore pressure to within COLR limits (>2205 psig), if required.

TS 3.4.13 for primary leakage (while PORV open and unisolated).

Crew evaluates malfunction and submits work request.

2014 NRC 4 Page 10 Revision 1

EVENT 3: Given the unit is at power and the PRZR pressure master controller fails high, the crew will respond in accordance with 1-AP-44, "Loss of Reactor Coolant System Pressure."

TIME EXPECTED ACTION INSTRUCTOR REMARKS NOTE: The next event will occur once T.S Validation time: 14 minutes are discussed, or as directed by the lead examiner.

2014 NRC 4 Page 11 Revision 1

EVENT 4: Given that the unit is at power and the running BC pump has tripped with the standby failing to start, the crew will be expected to respond in accordance with 1-AP-19, "Loss of Bearing Cooling Water."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciators F-E4 and F-F4 are illuminated (possibly K-F5)

• "A" BC pump has amber light lit

• "B" BC pump does not auto start Crew identifies annunciators F-E4, BC WTR DISCH HDR LO PRESS, and F-F4, BC WTR PP 1A-1B AUTO TRIP SYS MISALIGNED, and informs US.

US directs the crew to enter 1-AP-19.

IOA BOP checks one bearing cooling pump running with normal amps. (NO)

IOA BOP starts "B" BC pump. RNO BOP checks BC pump evolutions in progress. (YES)

BOP places 1-BC-P-1A in PTL.

BOP verifies BC pump running with normal indications.

Crew verifies BC system operating normally in tower mode.

Crew verifies BC system operation is normal.

Crew dispatches operator to check BC pumps.

Crew checks main generator temperature alarms are not lit.

Crew dispatches operator to check bus duct This will take ~20 minutes temperatures locally.

Crew dispatches an operator to locally check equipment cooled by BC.

NOTE: The next event will occur after the NOTE: Check with booth to verify crew has started the standby BC pump that charging flow is recovering from and stabilized the plant, or as directed by earlier pressure transient before the lead examiner. initiating SGTL.

Validation time:8 minutes 2014 NRC 4 Page 12 Revision 1

EVENT 5: Given that the unit is at power and indications exist of a SG tube leak, the crew will be expected to respond in accordance with 1-AP-5, "Unit 1 Radiation Monitoring System," and 1-AP-24, "Steam Generator Tube Leak."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• 1-MS-RI-190, "A" SG N-16, is first in Alert

• Annunciator K-G6 illuminated

• Annunciator K-G6 reflashes

• 1-MS-RI-190 is in hi alarm

• 1-MS-RI-193, Main Steamline header N-16, indication increases to hi alarm

• 1-MS-RI-191 and 1-MS-RI-192 increase to Alert RO/BOP identifies annunciator K-G6, N-16 RAD DET.

Crew identifies an Alert alarm on 1-MS-RI-190, "A" SG main steamline N-16 radiation monitor.

US directs BOP to enter 1-AP-5.

NOTE: If crew requests HP to perform local radiation surveys on the MS lines, HP will inform the crew that contact readings on the "A" MS line show a slight increases since last surveys.

Crew monitors radiation on N-16 trend recorder and determines leakage is increasing.

Crew identifies increasing radiation on main steamline header N-16 radiation monitor.

US directs crew to initiate the 1-AP-5 attachment for monitoring primary to secondary leakage, and enters 1-AP-24.

Crew determines if a reactor trip is required. AP-24 (NO)

Crew refers to attachment 4 for required actions.

Crew notifies Chemistry to initiate increased monitoring and to initiate action level 1 actions.

Crew requests samples from Chemistry and HP.

Crew determines RCS leakrate, as time permits.

2014 NRC 4 Page 13 Revision 1

EVENT 5: Given that the unit is at power and indications exist of a SG tube leak, the crew will be expected to respond in accordance with 1-AP-5, "Unit 1 Radiation Monitoring System," and 1-AP-24, "Steam Generator Tube Leak."

TIME EXPECTED ACTION INSTRUCTOR REMARKS Crew reviews actions for high secondary coolant activity:

• Turn off Unit 1 and Common sump pumps (turbine building)

• Place caution tags to direct samples be taken before pumping sumps

• Determine is AS should be transferred to Unit 2 (already on Unit 2 second-points)

• Consult with HP prior to using hotwell high level divert.

Crew notifies STA to evaluate the steam AP-5 generator leak rate trend data.

Crew notifies HP SS and the OMOC of the abnormal status of the monitor reading.

Crew identifies the leaking generator as "A" and quantifies leakage using N-16.

Crew monitors leakage on trend recorder.

Crew verifies/initiates 1-AP-24 and attachment 13 of 1-AP-5.

Crew increases monitoring requirements by Attachment 13 trending leakrate.

Crew requests Air Ejector grab samples every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

US refers to TR 3.4.4.

NOTE: The next event can occur once the Validation time: 12 minutes crew has made appropriate notifications and requests, or as directed by the lead examiner.

2014 NRC 4 Page 14 Revision 1

EVENT 6: Given that the unit is at power and indications exist of a SG tube leak requiring a unit ramp, the crew will be expected to respond in accordance with 1-AP-24, "Steam Generator Tube Leak," and 1-AP-2.2, "Fast Load Reduction."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciator K-G6 reflashes

• 1-MS-RI-190 indication increases to 110 gpd

• Control rods stop moving in automatic RO/BOP identifies reflash of annunciator K-G6, N-16 RAD DET.

Crew identifies 1-MS-RI-190, "A" SG main steamline N-16 radiation monitor increasing to >100 gpd.

US reenters 1-AP-24 or reviews Note before step one requiring unit power to be reduced to 50% power within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and to Mode 3 conditions within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />.

US directs crew to enter 1-AP-2.2.

RO initiates RCS boration using either AP-2.2 attachment 5 or a standard ramp plan. Reactivity for RO/SRO 2014 NRC 4 Page 15 Revision 1

EVENT 6: Given that the unit is at power and indications exist of a SG tube leak requiring a unit ramp, the crew will be expected to respond in accordance with 1-AP-24, "Steam Generator Tube Leak," and 1-AP-2.2, "Fast Load Reduction."

TIME EXPECTED ACTION INSTRUCTOR REMARKS BOP reduces plant load at 5%/minute or less Normal for BOP as follows: Attachment 4 of 1-AP-2.2

• Verifies turbine in Operator Auto (NO)

• Verifies GV tracking meter is approximately zero

• Ensures turbine control reference and setter are matched

• Presses the OPER AUTO push button

• Verifies valve position limit light is OFF (NO)

• Removes turbine from limiter using attachment 4

• Places setter at the desired setpoint

• Sets ramp rate using thumbwheel

• Presses the GO pushbutton

• Presses HOLD pushbutton once limit light goes out

• Verifies the turbine is in IMP-IN (NO)

• Ensures reference and setter are matched

• Presses IMP-IN pushbutton

• Initiates load reduction using attachment 4

• Places setter at desired setpoint

• Sets ramp rate using thumbwheel

• Ensures the VPL is above the expected valve position

• Presses GO pushbutton.

RO verifies rods are in auto.

NOTE: RO will have to maintain RCS pressure manually due to previous failure. BOP will have to maintain "B" SG level.

RO energizes additional pressurizer heaters.

NOTE: After rods have initially stepped in auto, a failure will be put in that stops them from stepping in auto.

• RO verifies proper auto control rod insertion. (NO)

RO places control rods in manual and adjusts as required to maintain Tave within 5° of Tref.

2014 NRC 4 Page 16 Revision 1

EVENT 6: Given that the unit is at power and indications exist of a SG tube leak requiring a unit ramp, the crew will be expected to respond in accordance with 1-AP-24, "Steam Generator Tube Leak," and 1-AP-2.2, "Fast Load Reduction."

TIME EXPECTED ACTION INSTRUCTOR REMARKS RO monitors steam dumps for proper operation.

• RO maintains rod bank lo/lo-lo limit and AFD to keep within limits.

US makes required notifications to MOC and evaluates EPIPs and VPAP-2802, as required.

Crew verifies auxiliary steam is on Unit 2 extraction steam.

• BOP verifies HP TB gland steam pressure indicates between 1.5 and 15 psig.

Crew starts removing reheat steam system from service by slowly reducing the controller.

Crew stops LP heater drain pumps at ~85%

power.

US will review TR 3.4.4, as time permits. NOTE: This may need to be a follow-(The actions of TR 3.4.4 are directed by 1- up question. May have been done AP-24.) during response to event 5.

NOTE: The next event can occur once Validation time: 17 minutes enough of a ramp down has been observed. Includes manual rod insertion for RO.

2014 NRC 4 Page 17 Revision 1

EVENT 7: Given that the unit is at power and indications exist of an RCP seal leak , the crew will be expected to respond in accordance with 1-AP-33.1, "Reactor Coolant Pump Seal Failure," and 1-E-0, "Reactor Trip or Safety Injection."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• Annunciator C-G7 is lit

• "C" RCP Seal leakoff > 6 gpm RO identifies annunciator C-G7, "RCP 1A-B-C SEAL LEAK HI FLOW".

US directs crew to enter 1-AP-33.1.

Crew identifies "C" as the affected RCP.

RO checks if "C" #1 seal has a low delta P.

RO determines that "C" #1 seal leak-off flow is > 5.9 GPM.

RO checks that annunciator C-G7 is lit and valid based on other indications. (YES)

US directs crew to enter 1-E-0, while continuing with 1-AP-33.1.

IOA RO/BOP trip the reactor.

• RO checks reactor trip and bypass breakers are open

• RO checks rod bottom lights lit

• RO checks neutron flux decreasing IOA BOP verifies turbine trip:

• Manually trips turbine

• Verifies all turbine stop valves closed

• Resets reheaters

• Verifies MSR FCVs closed

• Verifies generator output breaker open.

IOA Crew verifies both emergency busses are engerzied.

IOA Crew verifies that safety injection has not occurred and is not required.

• No LHSI pumps running

• No SI first out annunciator lit

• No low pressurizer pressure

• No high containment pressure

• No steamline differential pressure

• No high steam flow with low-lo Tave or low steam pressure (NO) 2014 NRC 4 Page 18 Revision 1

EVENT 7: Given that the unit is at power and indications exist of an RCP seal leak , the crew will be expected to respond in accordance with 1-AP-33.1, "Reactor Coolant Pump Seal Failure," and 1-E-0, "Reactor Trip or Safety Injection."

TIME EXPECTED ACTION INSTRUCTOR REMARKS CT2 Crew isolates affected Reactor *Within 5 minutes of seal leakoff Coolant Pump seal leakoff exceeding alarm setpoint

• Crew verifies reactor is tripped.

• Crew trips "C" RCP.

• Crew verifies "C" loop flow indicates RCP has stopped.

• Crew closes 1-CH-HCV-1303C, #1 seal leakoff valve.

• Crew closes 1-RC-PCV-1455B.

NOTE: When "C" RCP is secured the SGTL size will increase to a SGTR after a delay. This is handled by the next event.

Crew initiates evaluation of RCP and seals Validation time: about 4 minutes.

and returns to 1-E-0.

2014 NRC 4 Page 19 Revision 1

EVENT 8: Given that unit is tripped and a SGTR has developed, the crew will be expected to respond in accordance with 1-E-0, "Reactor Trip and Safety Injection," and 1-E-3, "SGTR."

TIME EXPECTED ACTION INSTRUCTOR REMARKS SPD Verified: __________ (Initials)

• RCS pressure and level decrease unexpectedly

• "A" SG WR level increases unexpectedly fast

• "A" MSTV will not close RO identifies decrease in RCS pressure and level.

BOP identifies an unexpected increase in "A" WR SG level.

NOTE: Crew may initially enter 1-AP-16 and maximize charging/isolate letdown.

US directs crew to initiate Safety Injection.

RO/BOP initiate safety injection. 1-AP-24 is no longer applicable once SI is in service.

RO checks no CAPs 1-5 apply.

US initiates attachments 4(5), and 8. Attachment 4 initiates attachment 5. The BOP will likely be given the attachments. All are included in package.

NOTE: CAP of 1-E-0, and attachment 4 both contain direction to close and lock 1-CH-217, PG to U-1 blender.

Crew verifies SI flow.

HHSI cold leg SI flow indicated (YES)

RCS pressure < 225 psig (NO)

Crew verifies AFW flow.

AFW flow to all SGs indicated Total AFW flow > 340 gpm (or level in at least one SG > 11%)

2014 NRC 4 Page 20 Revision 1

EVENT 8: Given that unit is tripped and a SGTR has developed, the crew will be expected to respond in accordance with 1-E-0, "Reactor Trip and Safety Injection," and 1-E-3, "SGTR."

TIME EXPECTED ACTION INSTRUCTOR REMARKS

• RO checks RCS temperatures:

• Steam dumps controlling: Stable or trending to 547°F

• PORVs controlling: Stable or trending to 551°F.

• If temperature not under control:: Stop dumping steam. Adjust AFW flow to maintain >340 gpm until at least one SG

> 11% NR. If cooldown continues: close MSTVs. (or NRVs)

• If temperature is under control: Adust AFW flow to maintain > 340 GPM until at least one SG > 11% NR.

• RO checks PRZR PORVs and spray valves.

• PORVs closed

• Spray valves responding to control pressure at 2235 psig or demand at zero and closed

• At least one PORV block valve open.

RO checks RCP trip and charging pump recirc criteria.

RCS subcooling < 25°F (NO)

BOP checks SGs not faulted.

• All SG pressures > 80 psig and under control of operator. (YES)

BOP checks SGs tubes are not ruptured:

(NO):

Level in any SG increasing in an uncontrolled manner. (If yes, go to 1-E-3)

US directs transition to 1-E-3.

RO checks RCP trip and charging pump recirc criteria.

RCS subcooling < 25°F (NO)

BOP identifies ruptured SG as "A".

Unexpected increase in any SG NR level.

NOTE: Some steps may have been performed by attachment 8 of 1-E-0 or 1-AP-24.

2014 NRC 4 Page 21 Revision 1

EVENT 8: Given that unit is tripped and a SGTR has developed, the crew will be expected to respond in accordance with 1-E-0, "Reactor Trip and Safety Injection," and 1-E-3, "SGTR."

TIME EXPECTED ACTION INSTRUCTOR REMARKS CT3 Crew isolates flow to/from ruptured *Isolate before a transition to ECA-3.1 SG. occurs

• BOP adjusts ruptured SG PORV setpoint to 1050 PSIG.

• Check ruptured SG PORV closed.

• RO/BOP direct an operator to perform attachment to locally close 1-MS-18.

• Crew checks Decay Heat Release valve closed.

• Crew verifies ruptured SG Blowdown valves closed.

• Crew closes ruptured SG MSTV and Bypass valve. (NO)

• Crew closes "A" SG NRV.

• *Crew verifies ruptured SG level greater than 11%.

• Crew closes 1-FW-MOV-100D.

Crew initiates attachment for local turbine building operations.

• RO checks PRZR PORV and block valves:

• Power available to PORV block valves

• PORVs closed

• At least one PORV block valve open.

• BOP checks intact SG levels:

• NR level > 11%

• Control AFW flow to maintain NR level between 23 and 50%.

RO resets both trains of SI.

Crew manually aligns condenser air ejector discharge to containment.

• Crew removes air ejector RM instrument fuses

• Crew resets Phase A

• Crew puts AE divert to cont. SI reset switches to reset (SG panels)

• Crew verifies lineup of SV TVs

• Crew opens 1-AS-FCV-100A/B (BB2)

BOP verifies outside IA supplying containment.

2014 NRC 4 Page 22 Revision 1

EVENT 8: Given that unit is tripped and a SGTR has developed, the crew will be expected to respond in accordance with 1-E-0, "Reactor Trip and Safety Injection," and 1-E-3, "SGTR."

TIME EXPECTED ACTION INSTRUCTOR REMARKS BOP verifies flow isolated from ruptured SG:

• Procedure step 3 complete AND

• Attachment 8 step 3 complete OR

• 1-E-0 attachment 8 step 5 complete

• Ruptured SG pressure >350 psig.

Crew determines required core exit temperature based on SG pressure.

Crew verifies steam dumps available.

Crew places steam dumps in steam pressure mode:

• Put both steam dump interlock switches to OFF/RESET

• Put steam dump controller to MANUAL

• Put mode selector switch to STEAM PRESS

• Verify or reduce steam dump demand to zero

• Put both steam dump interlock switches to ON Crew initiates RCS cooldown.

• RO checks panel P-F3 lit. (NO)

• RO raises steam dump controller demand and dumps steam to condenser from intact SGs at maximum controllable rate

• RO holds both steam dump interlock switches in BYP INTK until panel P-F3 is lit

• RO verifies panel P-F4 is lit

• RO verifies panel P-G3 is lit (NO)

• Crew blocks hi stm flow SI signals

• Verify CETCs less than required temperature.

• RO stops RCS cooldown by closing steam dumps

• Maintain required RCS temperature <

required temperature.

BOP checks ruptured SG pressure stable or increasing.

RO checks RCS subcooling > 45°F.

2014 NRC 4 Page 23 Revision 1

EVENT 8: Given that unit is tripped and a SGTR has developed, the crew will be expected to respond in accordance with 1-E-0, "Reactor Trip and Safety Injection," and 1-E-3, "SGTR."

TIME EXPECTED ACTION INSTRUCTOR REMARKS

• Crew blocks low pressurizer pressure SI:

• Pressurizer pressure < 1950 psig

• Panel P-G4 LIT (NO)

• Place both low PRZR pressure SI block switches to block

• Verify Panel P-G4 LIT.

NOTE: The following is written assuming the ruptured SG level is off scale high. If not, pressurizer sprays will be used to depressurize instead of a PORV.

RO depressurizes RCS to minimize break flow and refill pressurizer.

• Places PRZR heaters in PTL

• Check ruptured SG NR level on scale (NO)

• Check a PRZR PORV is available (YES)

• Open one PRZR PORV until one of the following is met:

• PRZR level > 69% OR

• RCS subcooling < 25°F OR

• Both of the following:

RCS pressure < ruptured SG pressure AND PRZR level > 21%.

• Close PRZR PORV RO checks RCS pressure stable or increasing.

RO checks if SI can be terminated:

• Secondary heat sink: Total AFW flow to SGs >340 gpm available OR SG NR level in at least one intact SG > 11%

• RCS pressure stable or increasing

• RCS subcooling > 25°F

• PRZR level > 21%.

RO stops all but one charging pump and places in PTL.

2014 NRC 4 Page 24 Revision 1

EVENT 8: Given that unit is tripped and a SGTR has developed, the crew will be expected to respond in accordance with 1-E-0, "Reactor Trip and Safety Injection," and 1-E-3, "SGTR."

TIME EXPECTED ACTION INSTRUCTOR REMARKS CT4 Crew terminates safety injection: *Prior to water entering the steam

• Checks 1-SI-MOV-1860A/B closed header

• Opens 1-CH-MOV-1373 (CHP recirc)

• Opens charging pump recircs: 1-CH-MOV-1275A/B/C

• Closes BIT inlet isolation valves (1-SI-MOV-1867A/B)

• Closes BIT outlet isolation valves (1-SI-MOV-1867C/D)

• Verifies 1-SI-MOV-1836, 1-SI-MOV-1869A/B are closed.

NOTE: The scenario may be terminated after SI has been terminated, or as directed by the lead examiner.

2014 NRC 4 Page 25 Revision 1

REFERENCES PROCEDURE REV.

Operating Procedure 1-Op-7.7, "Refueling Water Storage Tank System Operation. 57 Abnormal Procedure 1-AP-44, "Loss of RCS Pressure." 19 Abnormal Procedure 1-AP-16, "Increasing Primary Plant Leakage." 29 Abnormal Procedure 1-AP-19, "Loss of Bearing Cooling Water." 19 Abnormal Procedure 1-AP-5, "Unit 1 Radiation Monitoring System." 37 Abnormal Procedure 1-AP-24, "Steam Generator Tube Leak". 22 Abnormal Procedure 1-AP-2.2, "Fast Load Reduction." 27 Abnormal Procedure 1-AP-33.1, Reactor Coolant Pump Seal Failure. 16 Emergency Operating Procedure 1-E-0, "Reactor Trip or Safety Injection." 46 Emergency Operating Procedure 1-E-3, "Steam Generator Tube Rupture." 28 Station Annunciator Response Procedures. N/A Administrative Procedure PI-AA-5000, "Human Performance." 8 INPO, Guideline for Teamwork and Diagnostic Skill Development: INPO 88-003. Jan. 1988 INPO, ACAD 07-002 Simulator Training Guidelines Jan. 2007 2014 NRC 4 Page 26 Revision 1

ATTACHMENT 1 SIMULATOR OPERATOR'S COMPUTER PROGRAM 2014 NRC 4 Page 27 Revision 1

SIMULATOR OPERATOR'S COMPUTER PROGRAM 2014 NRC 4 Initial conditions

1. Recall IC 371

2. Ensure Tave, Tref, PDTT level, and VCT level are selected on trend recorders.

3. 2H is the protected train.

4. Place red sticker on 2-CC-P-1B switch

5. Copies of AP-5 and AP-24 for booth.

6. Copy of 1-OP-7.7 for booth.

PRELOADS PRIOR TO SCENARIO START CONDITION MALFUNCTION/OVERRIDE/ETC.

Tagout of 2-CC-P-1B Verify 2-CC-P-1A is running Place 2-CC-P-1B in PTL Remote functions:

U2_CCP1B_RACKIN = RACKOUT U2_CC_28 = 0 Failure of standby bearing Remote function:

cooling pump to auto-start BCP_AUTO_DEFEAT = T Failure of "A" MSTV to Malfunction:

close MS0501 2014 NRC 4 Page 28 Revision 1

SCENARIO EVENTS EVENT 1 Makeup to RWST MALFUNCTIONS/OVERRIDES Open 1-CH-230 using trigger 1:

Remote function:

CH_230 = 100, Delay time = 5, Ramp = 30, trigger = 1 Close 1-CH-230 by returning remote function to 0 over 10 seconds.

The next event can occur once the makeup to the RWST is complete.

COMMUNICATIONS When sent to close 1-CH-232: wait 1 minute and then report that the valve is closed. (Step 5.1.5)

When sent to open 1-CH-233: wait 2-3 minutes and then report that the valve is open. (Step 5.1.7)

When sent to open 1-CH-230: use trigger 1 and wait 1-2 minutes and then report that the valve is open.

When called to close 1-CH-233 and 1-CH-230: close CH_230 (as directed above), wait 3-4 minutes and then report that the valves are closed and the procedure is on top of the gaitronics near the MCC in front of the blender.

When sent to verify 1-CH-233 and 1-CH-230, wait 3-4 minutes and report that the valves have been IV'd closed.

2014 NRC 4 Page 29 Revision 1

EVENT 2 "B" SG Median Select level failure MALFUNCTIONS/OVERRIDES Malfunction:

FW3202, Delay time = 5, Ramp = 5, Severity = 20, Trigger = 2 The next event can occur once "B" SG level has been restored to normal, or as directed by the lead examiner.

COMMUNICATIONS 2014 NRC 4 Page 30 Revision 1

EVENT 3 PRZR master pressure controller failure MALFUNCTIONS/OVERRIDES Malfunction:

RC29, Delay time = 5, Ramp = 5, Severity = 2, Trigger = 3 The next event will occur once T.S are discussed, or as directed by the lead examiner.

COMMUNICATIONS 2014 NRC 4 Page 31 Revision 1

EVENT 4 BC pump failure MALFUNCTIONS/OVERRIDES Remote function:

BCP1A_PROTECT = TRUE, Delay time = 5, Trigger = 4 The next event will occur after the crew has started the standby BC pump and stabilized the plant, or as directed by the lead examiner.

COMMUNICATIONS If sent to check pumps: Wait 2 minutes and report that 1-BC-P-1A looks OK, just no longer running. 1-BC-P-1B is running fine.

Note that the AP now places the tripped pump in PTL which means the discharge MOV is closed.

If sent to breaker for 1-BC-P-1A: Wait for 1 minute and report that 1-EP-BKR-15B8 has an overcurrent drop on it.

When sent to check local generator leads bus ducting temperatures, it would take about 20 minutes to get these. Report that all are <120°C.

When sent to look at BC loads: wait 10 minutes and then report back that all BC loads are operating normally.

2014 NRC 4 Page 32 Revision 1

EVENT 5 SGTL MALFUNCTIONS/OVERRIDES Malfunction:

RC2401, Delay time = 5, Ramp = 30, Severity = .0036 (55 gpd), Trigger = 5 (alarms in ~2 minutes)

The next event can occur once the crew has made appropriate notifications and requests, or as directed by the lead examiner.

COMMUNICATIONS HP surveys should take approximately 5 minutes. Chemistry samples should take approximately 30 minutes. HP will inform the crew that there is a slight increase in contact readings on the "A" MS line.

Communication from HP as per AP-24: Total activity - 4.61 x 10-5 ci/ml. Turbine building sumps must be sampled prior to pumping. (This would take at least 30 minutes.)

2014 NRC 4 Page 33 Revision 1

EVENT 6 SGTL worsens MALFUNCTIONS/OVERRIDES Set up trigger 6 on trigger screen as follows:

IMF RC2401 .007 60 Put in Trigger 20 during ramp once control rods have stepped automatically one time.

CNTRL_ROD_AUTO = OFF, Trigger = 20 The next event can occur once enough of a ramp down has been observed. Includes manual rod insertion for RO.

COMMUNICATIONS HP surveys should take approximately 5 minutes. Chemistry samples should take approximately 30 minutes. HP will inform the crew that there is a slight increase in contact readings on the "A" MS line.

Communication from HP as per AP-24: Total activity - 4.61 x 10-5 ci/ml. Turbine building sumps must be sampled prior to pumping. (This would take at least 30 minutes.)

2014 NRC 4 Page 34 Revision 1

EVENT 7 RCP seal leak MALFUNCTIONS/OVERRIDES Malfunction:

RC1203, Delay time = 5, Ramp = 5, Severity = 50, Trigger =7 The next event is on a trigger when the RCP is tripped.

COMMUNICATIONS 2014 NRC 4 Page 35 Revision 1

EVENT 8 SGTR MALFUNCTIONS/OVERRIDES Set up trigger 8 on trigger screen to initiate when "C" RCP is stopped.

.NOT. RCP1C_BKR = 0 (RC7)

IMF RC2401 (8 30) 60 60 Remote function:

MS_18 = 0, Delay time = 60, Ramp = 60, Trigger = 9 Note the "A" SG level is not in the steam line when the depressurization is stopped and again when SI is terminated.

_______ "A" SG level when depressurization stopped

_______ "A" SG level when SI is terminated The scenario may be terminated after SI has been terminated, or as directed by the lead examiner.

COMMUNICATIONS If directed to use attachment 8 of 1-E-0 or 1-E-3 to locally isolate "A" SG in MSVH: use trigger 9 to close MS-18.

If using 1-E-0 attachment: Report back that attachment 8 step 5 is complete. Ruptured generator is isolated and non-ruptured generators are available for cooldown.

Wait a few minutes and then report that attachment 8 of 1-E-0 is complete.

If using 1-E-3 attachment: Report back that attachment 8, step 3 is complete. Ruptured generator is isolated and non-ruptured generators are available for cooldown.

Wait a few minutes and then report that attachment 8 of 1-E-3 is complete.

2014 NRC 4 Page 36 Revision 1

ATTACHMENT 3 SCENARIO PERFORMANCE OBJECTIVES 2014 NRC 4 Page 37 Revision 1

EVENT 1 PERFORMANCE OBJECTIVES EVENT GOAL: Given that a makeup to the RWST has been requested, the crew will use 1-OP-7.7, "Refueling Water Storage Tank System Operation" to adjust boron concentration NORTH ANNA SPECIFIC TASKS:

None CRITICAL TASK:

N/A 2014 NRC 4 Page 38 Revision 1

EVENT 2 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power and "B" SG median select level has failed, the crew will respond in accordance with the AR for annunciator F-F2.

NORTH ANNA SPECIFIC TASKS:

None CRITICAL TASK:

N/A 2014 NRC 4 Page 39 Revision 1

EVENT 3 PERFORMANCE OBJECTIVES EVENT GOAL: Given the unit is at power and the PRZR pressure master controller fails high, the crew will respond in accordance with 1-AP-44, "Loss of Reactor Coolant System Pressure."

NORTH ANNA SPECIFIC TASKS:

R634 Respond to a loss of reactor coolant system pressure CRITICAL TASK:

See next page 2014 NRC 4 Page 40 Revision 1

CT Statement:

Crew stops RCS pressure decrease.

Safety Significance:

Failure to close the PORV and pressurizer spray valves under the postulated plant conditions constitutes "mis-operation or incorrect crew performance which leads to degradation of any barrier to fission product release." In this case, the RCS fission-product barrier can be restored to full integrity simply by closing the PORV block MOV) and the spray valves.

Therefore, failure to close the PORV block MOV and spray valves also represents a "demonstrated inability by the crew to take an action or combination of actions that would prevent a challenge to plant safety."

Cues:

Valid indication of pressure decreasing by the presence of various annunciators Indication of PORV open RCS pressure indication decreasing.

Performance Indicator:

RO manually closes PORV 1-RC-PCV-1455C RO manually closes pressurizer spray valves by using the master pressure controller Feedback:

RCS pressure decrease stopped.

WOG

Reference:

Based on Appendix B CT-10.

Conditions:

Prior to receiving an automatic reactor trip on low pressure.

2014 NRC 4 Page 41 Revision 1

EVENT 4 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power and the running BC pump has tripped with the standby failing to start, the crew will be expected to respond in accordance with 1-AP-19, "Loss of Bearing Cooling Water."

NORTH ANNA SPECIFIC TASKS:

R522 Stabilize the unit following a loss of Bearing Cooling Water CRITICAL TASK:

N/A 2014 NRC 4 Page 42 Revision 1

EVENT 5 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power and indications exist of a SG tube leak, the crew will be expected to respond in accordance with 1-AP-5, "Unit 1 Radiation Monitoring System," and 1-AP-24, "Steam Generator Tube Leak."

NORTH ANNA SPECIFIC TASKS:

None CRITICAL TASK:

N/A 2014 NRC 4 Page 43 Revision 1

EVENT 6 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power and indications exist of a SG tube leak requiring a unit ramp, the crew will be expected to respond in accordance with 1-AP-24, "Steam Generator Tube Leak," and 1-AP-2.2, "Fast Load Reduction."

NORTH ANNA SPECIFIC TASKS:

None CRITICAL TASK:

N/A 2014 NRC 4 Page 44 Revision 1

EVENT 7 PERFORMANCE OBJECTIVES EVENT GOAL: Given that the unit is at power and indications exist of an RCP seal leak , the crew will be expected to respond in accordance with 1-AP-33.1, "Reactor Coolant Pump Seal Failure," and 1-E-0, "Reactor Trip or Safety Injection."

NORTH ANNA SPECIFIC TASKS:

R185 Perform the immediate operator actions in response to a reactor trip or safety injection.

R533 Respond to a reactor coolant pump seal failure.

CRITICAL TASK:

See Next Page 2014 NRC 4 Page 45 Revision 1

CT Statement:

Crew isolates affected Reactor Coolant Pump seal leakoff.

Safety Significance:

"an indication of a failure of the #1 seal in any RCP with controlled seal leakoff requires prompt action to secure the leakoff path as soon as is practical and in no case longer than five minutes after seal leakoff exceeds the high flow alarm setpoint. Failure to isolate the affected RCP seal leakoff in a timely manner may subject the RCP shaft, lower radial bearing, and seals to high temperature conditions which could lead to premature failure of the remaining seals, failure of the lower radial bearing, and warping of the RCP shaft."

Cues:

Indication and annunciation of:

• Affected RCP #1 seal DP less than 200 psid OR

• Valid indication of #1 seal leakoff greater than alarm setpoint Performance Indicator:

• Crew verifies reactor tripped

• Crew stops affected RCP

• Crew closes affected RCP #1 seal leakoff valve (once loop flow indicates affected RCP is stopped)

Feedback:

Indication of:

• Reactor trip

• decreasing or zero flow for loop with affected RCP

• affected RCP seal leakoff valve closed.

WOG

Reference:

Westinghouse RCP vendor manual - addendum #3 Conditions:

Within 5 minutes of seal leakoff exceeding alarm setpoint.

2014 NRC 4 Page 46 Revision 1

EVENT 8 PERFORMANCE OBJECTIVES EVENT GOAL: Given that unit is tripped and a SGTR has developed, the crew will be expected to respond in accordance with 1-E-0, "Reactor Trip and Safety Injection," and 1-E-3, "SGTR."

NORTH ANNA SPECIFIC TASKS:

R187 Identify and isolate a ruptured steam generator.

R759 Cool down the Reactor Coolant System during the response to a steam generator tube rupture.

CRITICAL TASK:

See Following Pages 2014 NRC 4 Page 47 Revision 1

CT Statement:

Crew isolates flow to/from ruptured SG.

Safety Significance:

Failure to isolate the ruptured SG causes a loss of differential pressure between the ruptured SG and the intact SGs. Upon loss of differential pressure, the crew must transition to a contingency procedure that constitutes an incorrect performance that "...necessitates the crew taking compensating action which complicates the event mitigation strategy..."

Cues:

Indication and annunciation of:

Increasing SG water level and radiation A reactor trip A safety injection.

Performance Indicator:

BOP adjusts ruptured SG PORV setpoint at 1050 PSIG.

BOP checks ruptured SG PORV closed.

RO checks decay heat release valve closed.

BOP checks affected SG blowdown trip valves closed.

BOP closes "A" SG NRV RO/BOP directs an auxiliary operator to locally close affected SG Steam to the Terry Turbine.

BOP closes affected SG AFW valve Feedback:

Indication of:

Stable or increasing pressure in the ruptured SG.

Decreasing or zero feedwater flow rate to the ruptured SG.

WOG

Reference:

Appendix B CT-18 Conditions:

Isolate before a transition to ECA-3.1 occurs.

2014 NRC 4 Page 48 Revision 1

CT Statement:

Crew terminates SI.

Safety Significance:

Failure to terminate SI and control RCS pressure and makeup flow during a SGTR needlessly complicates the mitigation strategy. It also constitutes a "significant reduction of safety margin beyond that irreparably introduced by the scenario."

Cues:

Procedurally directed by E-3 Performance Indicator:

BOP isolates BIT.

Feedback:

Cold leg SI flow indicates zero.

WOG

Reference:

Appendix B CT-21 Conditions:

Prior to water entering the steam header.

2014 NRC 4 Page 49 Revision 1

ATTACHMENT 2 SIMULATOR PERFORMANCE DATASHEET

Scenario Performance Datasheet EVENT 1: Given that a makeup to the RWST has been requested, the crew will use 1-OP-7.7, "Refueling Water Storage Tank System Operation" to adjust boron concentration SPD Verified: __________ (Initials)

• Blender functions as expected EVENT 2: Given that the unit is at power and "B" SG median select level has failed, the crew will respond in accordance with the AR for annunciator F-F2.

SPD Verified: __________ (Initials)

• Annunciator F-F2 illuminates

• "B" FRV modulates closed

• "B" SG level decreases EVENT 3: Given the unit is at power and the PRZR pressure master controller fails high, the crew will respond in accordance with 1-AP-44, "Loss of Reactor Coolant System Pressure."

SPD Verified: __________ (Initials)

• Annunciators B-E6, C-D1, and later B-F7 illuminate

• Master pressure controller fails high

• 1-RC-PCV-1455C indicates open

• 1-RC-PCV-1455A and 1455B indicate open

• RCS pressure decreases EVENT 4: Given that the unit is at power and the running BC pump has tripped with the standby failing to start, the crew will be expected to respond in accordance with 1-AP-19, "Loss of Bearing Cooling Water."

SPD Verified: __________ (Initials)

• Annunciators F-E4 and F-F4 are illuminated (possibly K-F5)

• "A" BC pump has amber light lit

• "B" BC pump does not auto start EVENT 5: Given that the unit is at power and indications exist of a SG tube leak, the crew will be expected to respond in accordance with 1-AP-5, "Unit 1 Radiation Monitoring System," and 1-AP-24, "Steam Generator Tube Leak."

SPD Verified: __________ (Initials)

• 1-MS-RI-190, "A" SG N-16, is first in Alert

• Annunciator K-G6 illuminated

• Annunciator K-G6 reflashes

• 1-MS-RI-190 is in hi alarm

• 1-MS-RI-193, Main Steamline header N-16, indication increases to hi alarm 1-MS-RI-191 and 1-MS-RI-192 increase to Alert 2014 NRC 4 Date _________ Revision 0

Scenario Performance Datasheet EVENT 6: Given that the unit is at power and indications exist of a SG tube leak requiring a unit ramp, the crew will be expected to respond in accordance with 1-AP-24, "Steam Generator Tube Leak," and 1-AP-2.2, "Fast Load Reduction."

SPD Verified: __________ (Initials)

• Annunciator K-G6 reflashes

• 1-MS-RI-190 indication increases to 110 gpd

• Control rods stop moving in automatic EVENT 7: Given that the unit is at power and indications exist of an RCP seal leak , the crew will be expected to respond in accordance with 1-AP-33.1, "Reactor Coolant Pump Seal Failure," and 1-E-0, "Reactor Trip or Safety Injection."

SPD Verified: __________ (Initials)

• Annunciator C-G7 is lit

• "C" RCP Seal leakoff > 6 gpm EVENT 8: Given that unit is tripped and a SGTR has developed, the crew will be expected to respond in accordance with 1-E-0, "Reactor Trip and Safety Injection," and 1-E-3, "SGTR."

SPD Verified: __________ (Initials)

• RCS pressure and level decrease unexpectedly

• "A" SG WR level increases unexpectedly fast

• "A" MSTV will not close 2014 NRC 4 Date _________ Revision 0

SCENARIO TURNOVER SHEET Read the following to the crew:

Purpose: This examination is intended to evaluate the crews performance of various tasks associated with the Initial License Operator Training Program. All activities should be completed in accordance with approved operations standards.

1. You are on a day shift during the week.

2. A rough log should be maintained to aid in making reports and to help during briefs.

3. Respond to what you see. In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated and the crew informed.

Unit Status:

Unit 1 is at 100% power. RCS boron is 988 ppm and core age is 9,000 MWD/MTU. Aux steam is on unit 2.

Unit 2 is at 100% power.

Equipment Status:

1-FW-P-2 was returned to service last shift. Maintenance rule window is green. 2-CC-P-1B was tagged out last shift for major maintenance. It is expected to be out for several more days. Protected train is 2H.

Shift Orders:

Makeup to the RWST using the unit 1 blender. Add 500 gallons of water at approximately 3000 ppm boron. Maintain current plant conditions.

Prebrief The OATC (RO) has been designate to perform the RWST makeup.

At this time, please prebrief the RWST makeup.

BARS is not in service RP is NOT in service to the RWST BAST boron concentration is 14,043 ppm AB operator (Mike Brophy) has a copy of the OP and has been briefed.

An extra (Dave Huff) has been designated to be the AB IV'er and has been briefed.

• • • A Non-Controlled Document ***

Unit 1 OATC Protected This Sheet updated on: Today 2H Power: 100 GV Position 56  % BLOWDOWNS Boron: 988 ppm TURBINE REF: 95 1.0% on limiter CD: 2 GPM Dilutions: 1-3 50 gal 'A' BAST: 14,043 ppm SW: secured PG/°F Change: 190 Gls. IN PIPE: PG BC: Secured on U-1 BA/°F Change: 13.8 Gls. CATION BED: Secured S/G: Hi cap 60/60/60 BLEND RATIO: 13.2 to 1 Aux Stm Supply: U2 2nd PT Approximate 1-RC-PCV-1444J 54 % 1-RC-LCV-1459G 40 %

Outputs 1-CH-PCV-1145 77 % 1-CC-TCV-106 25 %

Limiting Actions: None Items Tagged: 2-CC-P-1B Items OOC:

Annunciators Lit 1-LOG-14:

Problems/OWA:

OD's OD-555: 1H EDG Mech Stop (Mushroom) Pushbutton may not work to stop 1H EDG OD-542: AFW Pipe Tunnel Missile Protection ODM's ODM-309: B&C RCP seals, < 0.8 seal leakoff (AR 1C-G8), PG < 90 °, RCS@175 ppm MISC Maintain VCT Pressure < 35 psig per Chemistry request 1-FW-P-2 returned to operable last shift. Previously tagged for work on governor valve.

Open Procedures:

PT's Days: PT's Nights:

Normal Nightlies

Reactivity Worksheet This calculation made on: Sunday June 1, 2014 14:22:34 Cycle Data file: N1C24 Cycle Data Updated: 9/25/2013 Core Burnup 9,000.0 MWD/MTU PG (blend)

RCS Cb 988 ppm 75 gpm BAST Cb 14,043 ppm 5.00 pot ITC -23.6 pcm/°F Boric Acid (blend)

PC -20.7 pcm/% 5.7 gpm Boron Coefficient -6.63 pcm/ppm 2.84 pot (ITEM 1) = ITC/Boron Coefficient = 3.56 ppm/°F (ITEM 2) = PC/Boron Coefficient = 3.12 ppm/%

PG needed to raise RCS temperature 1ºF*

50455.4

• ln (RCS CB/(RCS CB - ITEM 1)) 190 gallons of PG Boron needed to lower RCS temperature 1ºF 50455.4

• ln ((BAST CB - RCS CB) / (BAST CB - (RCS CB + ITEM 1)) 13.8 gallons of acid PG needed to raise Reactor Power 1%*

50455.4

• ln (RCS CB/(RCS CB - ITEM 2)) 166 gallons of PG Boron needed to lower Reactor Power 1%

50455.4

• ln ((BAST CB - RCS CB) / (BAST CB - (RCS CB + ITEM 2)) 12.1 gallons of acid BLEND RATIO CALCULATION (BAST CB - RCS CB) / RCS CB 13.2 to 1 ratio

• Denotes Calculations that have been corrected for B-10 RCS Makeup Table PG BA PG BA PG BA 120 gpm 9.1 gpm 80 gpm 6.1 gpm 40 gpm 3.0 gpm 8.00 pot 4.54 pot 5.33 pot 3.03 pot 2.67 pot 1.51 pot PG BA PG BA PG BA 110 gpm 8.3 gpm 70 gpm 5.3 gpm 30 gpm 2.3 gpm 7.33 pot 4.16 pot 4.67 pot 2.65 pot 2.00 pot 1.14 pot PG BA PG BA PG BA 100 gpm 7.6 gpm 60 gpm 4.5 gpm 20 gpm 1.5 gpm 6.67 pot 3.78 pot 4.00 pot 2.27 pot 1.33 pot 0.76 pot PG BA PG BA PG BA 90 gpm 6.8 gpm 50 gpm 3.8 gpm 10 gpm 0.8 gpm 6.00 pot 3.41 pot 3.33 pot 1.89 pot 0.67 pot 0.38 pot Prepared:________ Reviewed:________

Page 1 of 1 100% power reactivity sheet.xls

PROCEDURE NO:

1-OP-7.7 REVISION NO:

NORTH ANNA POWER STATION 57 PROCEDURE TYPE: UNIT NO:

OPERATING PROCEDURE 1 PROCEDURE TITLE:

REFUELING WATER STORAGE TANK SYSTEM OPERATION EOP AP LICS REVISION

SUMMARY

Incorporated EPAR P1 changing Step 5.1.2 to make specific to Unit 1 only.

Incorporated OP 13-0448 and CA273395, CR532638, Engineering Evaluate Feasibility to Perform Blended Flow Makeup to Unit 1 or Unit 2 RWST while Refueling Purification System is in Service to the Affected RWST.

• Added P&L 4.14, Step 5.1.2 Caution and Step 5.1.6 Note to applicably address: Engineering has determined blended makeup to the RWST may be performed with RP in service to the RWST. The Reverse Osmosis Unit for Silica Reduction (BARS) is secured before the makeup to prevent having two separate volume manipulations occurring simultaneously.

• Modified Step 5.1.2 to make conditional for Reverse Osmosis Unit for Silica Reduction (BARS) is in service on the Unit 1 RWST and Shutdown using 0-OP-16.9.

• Changed Step 5.1.6 to address if RP is in service on the Unit 1 RWST AND securing the RP system is desired

• Added Step 5.1.23 to address if RP was secured on the Unit 1 RWST in Step 5.1.6 AND return to service is desired.

• Added Step 5.1.24 to address if desired to place the Reverse Osmosis Unit for Silica Reduction in service on the Unit 1 RWST, then place the BARS in service using 0-OP-16.9.

PROBLEMS ENCOUNTERED: NO YES Note: If YES, note problems in remarks.

UNIT ONE REMARKS: ________________________________________________________________________________________________

_________________________________________________________________________________________________________

_________________________________________________________________________________________________________

_________________________________________________________________________________________________________

_________________________________________________________________________________________________________

______________________________________________________________________________ (Use back for additional remarks.)

SRO: DATE:

CONTINUOUS USE

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 2 of 36 TABLE OF CONTENTS Section Page 1.0 PURPOSE 3

2.0 REFERENCES

3 3.0 INITIAL CONDITIONS 7 4.0 PRECAUTIONS AND LIMITATIONS 7 5.0 INSTRUCTIONS 11 5.1 Makeup To The No. 1 RWST From The No. 1 Blender 11 5.2 Placing The RWST On The Chilled Water Coolers 19 5.3 Removing The RWST From The Chilled Water Coolers 24 5.4 Placing RWST Mechanical Refrigeration Unit In Service OR Swapping Units 26 5.5 Removing RWST Mechanical Refrigeration Unit From Service 29 5.6 Swapping RWST Recirc Pumps 31 ATTACHMENTS 1 Unit 1 RWST Operations Diagram 32 2 York Control Center Display Information 33

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 3 of 36 1.0 PURPOSE 1.1 To provide instructions for making up to the No. 1 RWST using the No. 1 blender.

1.2 To provide instructions for placing the RWST in service on the Chilled Water Coolers.

1.3 To provide instructions for removing the RWST from service on the Chilled Water Coolers.

1.4 To provide instructions for placing the RWST Mechanical Refrigeration Units in Service.

1.5 To provide instructions for removing the RWST Mechanical Refrigeration Units from Service.

1.6 To provide instructions for swapping the RWST Recirc Pumps.

The following synopsis is designed as an aid to understanding this procedure and is not intended to alter or take the place of the actual purpose, instructions, or text of the procedure itself.

IF the Unit is in Modes 3 - 6, THEN Tech Spec 3.1.8 and Tech Spec 3.9.2 as applicable, requires the PG isolation valve to the blender to be shut and locked, or four alternative valves to be shut and locked, except during the case of boron dilutions or makeup. Since an RWST makeup is not intended to affect the boron concentration of the RCS, a recent Tech Spec interpretation in the interest of reactivity management is that the four alternative valves are provided to allow for just such a makeup to the RWST, without affecting the RCS boron concentration.

2.0 REFERENCES

2.1 Source Documents 2.1.1 UFSAR, Section 6, Engineered Safety Features

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 4 of 36 2.1.2 Response Providing Information Regarding Implementation Details for the Phase 2 and 3 Mitigation Strategies dated February 12, 2007 (Serial No. 07-0004) (Reference 2.4.11) 2.1.3 Supplemental Response Providing Information Regarding Implementation Details for the Phase 2 and 3 Mitigation Strategies dated May 12, 2007 (Serial No. 07-0004B) (Reference 2.4.11) 2.2 Technical Specifications 2.2.1 Tech Spec 3.1.8 2.2.2 Tech Spec 3.3.3 2.2.3 Tech Spec 3.5.2 2.2.4 Tech Spec 3.5.3 2.2.5 Tech Spec 3.5.4 2.2.6 Tech Spec 3.9.2 2.2.7 TRM 3.1.1 2.2.8 TRM 3.1.2 2.2.9 TRM 3.10.1 2.3 Technical References 2.3.1 NCRODP-52, Safety Injection System 2.3.2 NCRODP-53, Quench Spray System 2.3.3 Operating Procedures:

• 0-OP-16.1, Spent Fuel Pit Cooling and Purification System

• 1-OP-51.2, Chilled Water System: Steam Chiller Operation

• 0-OP-51.5, Operation Of The Chilled Water Systems: Mechanical Chiller

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 5 of 36 2.3.4 This procedure is referenced by the following Emergency Procedures:

• 1-ECA-1.1, Loss of Emergency Coolant Recirculation

• 1-ECA-3.2, SGTR with Loss of Reactor Coolant-Saturated Recovery Desired 2.3.5 Flow Diagrams:

• 11715-FM-88A, Fuel Pit and Refueling Purification

• 11715-FM-91A, Quench and Recirc Spray

• 11715-FM-94A, Residual Heat Removal System

• 11715-FM-95B, Chemical and Volume Control System

• 11715-FM-96A, Safety Injection System

• 11715-FM-96B, Safety Injection System

• 12050-FM-95B, Chemical and Volume Control System 2.3.6 VPAP-2103N, Offsite Dose Calculation Manual (North Anna) 2.3.7 STD-GN-0008, Equipment Mark Numbers 2.3.8 Memo from James Breeden to Count Room Technicians dated 02-19-91, verified still applicable on 05-04-95 2.3.9 Fax Message from Michael Holtz, Joseph Oat Corporation, to Ed Wells, VEPCO, dated 07/09/97, Refueling Water Storage Tank Coolers (Rev 32) 2.3.10 DCP 03-160, Boric Acid and PG Water Flow to Blender Integrator Modification/NAPS/Unit 2 2.3.11 DCP 03-159, Boric Acid and PG Water Flow to Blender Integrator Modification / NAPS / Unit 1 2.3.12 Temporary Modification N1-2004-1749 2.3.13 DCP 04-116, Replacement of RWST Refrigeration Units / NAPS / Unit 1

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 6 of 36 2.3.14 VTM 59-Y058-00009, RWST Refrigeration Units, Air Cooled Liquid Chillers Hermetic Scroll, York 2.3.15 DCP 08-100, Modification of RWST Chiller Controls 2.3.16 DC NA-12-00019, Reverse Osmosis Unit for Silica Reduction 2.4 Commitment Documents 2.4.1 CTS Assignment 02-91-1800 Commitment 001, Technical Specification Change Number 244 2.4.2 CTS Assignment 02-90-18-11, Commitment 005, Technical Specification Change Number 114 2.4.3 Engineering Transmittal CE 96-014, Rev. 0, Mode 5 & 6 Compensatory Measures Recommended for Problem Reported in DR N-96-0278 (see Rev 29) 2.4.4 CTS Assignment 02-96-2169 Commitment 002, Compensatory Actions Required for Operation of the RP System During a Seismic Event (see Rev 30) 2.4.5 DR N-97-1608, Ops procedures for aligning Chilled Water to the RWST coolers do not contain maximum Chilled Water flow criteria 2.4.6 ET SE 99-044, Rev 0, Revision to the Compensatory Actions Required by CTS Assignment 02-96-2169 Commitment 002 for Operation of the Refueling Purification (RP) System During a Seismic Event, NAPS Units 1 and 2.

2.4.7 Plant Issue N-2003-0800, Grating Slipped from Hand and Hit Operator 2.4.8 Plant Issue N-2003-3417, Failure to Notify Health Physics Count Room prior to RWST Make-up 2.4.9 Plant Issue N-2006-1335-E1, To maintain normal flow through the RWST recirculation pumps with reduced RWST inventory, the low return flow path is opened when the low suction flow path is open

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 7 of 36 2.4.10 CA008653, Unit 2 Containment Refueling Cavity Clarity is Poor Following Placing Reactor Purification (RP) System in Operation on the Cavity 2.4.11 LA000528, Revise 0-AP-48, 1/2-FR-H.1 and 1/2-OP-7.7 as identified in ID#2 (The procedure fulfills the commitment to refill the RWST for long term makeup to the RCS.)

2.4.12 CA181833, CR397144, Procedures to Suspend Procedures Relating to NRC Question on RP System Alignment to the RWST 2.4.13 CA273395, CR532638, Engineering Evaluate Feasibility to Perform Blended Flow Makeup to Unit 1 or Unit 2 RWST while Refueling Purification System is in Service to the Affected RWST Init Verif 3.0 INITIAL CONDITIONS None 4.0 PRECAUTIONS AND LIMITATIONS 4.1 Comply with the following guidelines when marking steps N/A:

_______

• IF the conditional requirements of a step do not require the action to be performed, THEN mark the step N/A.

_______

• IF any other step is marked N/A, THEN have the SRO (or designee) approve the N/A and justify the N/A on the Procedure Cover Sheet.

_______ 4.2 VPAP-2103N: A minimum of one RWST level indicator shall be operable and must be Channel Checked at least daily during additions to tank.

_______ 4.3 Monitor RWST level to avoid tank overflow.

_______ 4.4 IF the Blender is needed for normal boric acid control for CVCS, THEN do NOT use the Blender for RWST makeup.

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 8 of 36

_______ 4.5 Prior to makeup to the RWST, HP should be notified so they can obtain an air sample at the RWST vent if required. (Cubic feet displaced = Number of gallons makeup x 0.13368) (Reference 2.3.8)

_______ 4.6 A large volume RWST makeup from the Blender will add a significant amount of heat to the RWST. To prevent RWST high temperature concerns when in Modes 1 - 4, makeups should be terminated prior to reaching 50°F at the RWST Tank Temp Top, 1-QS-TI-100A. Makeup to RWST at slower rates will result in slower heatup of the RWST.

_______ 4.7 Since portions of the RP system are not seismically qualified, the potential for loss of RWST or Reactor Cavity inventory exists from a seismic event. Therefore, making up to the No. 1 RWST using the No. 2 blender and making up to the No. 1 RWST using the Spent Fuel Pit is prohibited. (Reference 2.4.12)

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 9 of 36 4.8 The following Tech Specs apply:

_______

• Tech Spec 3.1.8, Primary Grade Water Flow Path Isolation Valves

_______

• Tech Spec 3.3.3, Post Accident Monitoring (PAM) Instrumentation

_______

• Tech Spec 3.5.2, ECCS Operating

_______

• Tech Spec 3.5.3, ECCS Shutdown

_______

• Tech Spec 3.5.4, Refueling Water Storage Tank (RWST)

_______

• Tech Spec 3.9.2, Primary Grade Water Flow Path Isolation Valves Mode 6

_______

• TRM 3.1.1, Boron Flow Paths Operating

_______

• TRM 3.1.2, Boron Flow Paths Shutdown

_______

• TRM 3.10.1, Liquid Holdup Tanks

_______ 4.9 Each RWST Cooler has a shell side design flowrate of 600 gpm. Chilled Water flow should NOT exceed this value. (Reference 2.4.5)

_______ 4.10 For 1-QS-MR-1A, Refueling Water Refrigeration Unit, and 1-QS-MR-1B, Refueling Water Refrigeration Unit, IF power has been OFF more than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, THEN the compressor heaters must be energized for a minimum of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to starting a compressor. This is to ensure that the oil is hot enough to drive the refrigerant out of solution.

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 10 of 36

_______ 4.11 It is desired to minimize the time 1-QS-40, RWST Low Header To Refuel Wtr Recirc Pps Isol Valve, is open in Modes 1-4 to minimize the possibility of losing RWST level through a break in the piping downstream of 1-QS-40. This piping was reclassified NSQ by DCP 04-116.

_______ 4.12 Information related to the York Control Center Display is available on Attachment 2, York Control Center Display Information.

_______ 4.13 If 1-QS-40, RWST Low Header To Refuel Wtr Recirc Pps Isol Valve, is opened, then 1-QS-60, RWST Coolers To RWST Low Header Isol Valve, should be opened.

This will prevent unnecessary wear to 1-QS-P-2A, Refueling Water Storage Tk Recirc Pump, and 1-QS-P-2B, Refueling Water Storage Tk Recirc Pump.

(Reference 2.4.9)

_______ 4.14 Engineering has determined blended makeup to the RWST may be performed with RP in service to the RWST. The Reverse Osmosis Unit for Silica Reduction (BARS) is secured before the makeup to prevent having two separate volume manipulations occurring simultaneously. (Reference 2.4.13)

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 11 of 36 5.0 INSTRUCTIONS 5.1 Makeup To The No. 1 RWST From The No. 1 Blender

_______ 5.1.1 Review Precautions and Limitations.

CAUTION The Reverse Osmosis Unit for Silica Reduction (BARS) is secured before the makeup to prevent having two separate volume manipulations occurring simultaneously. (Reference 2.4.13)

_______ 5.1.2 IF the Reverse Osmosis Unit for Silica Reduction (BARS) is in service on the Unit 1 RWST, THEN shutdown the BARS System in accordance with 0-OP-16.9, Operation of the Reverse Osmosis Unit for Silica Reduction.

_______ 5.1.3 Inform HP of makeup to the RWST and the anticipated volume addition.

(Reference 2.3.8)

_______ 5.1.4 Check the Blender will be needed only for the RWST makeup.

_______ 5.1.5 Close 1-CH-232, Spent Fuel Pit Boric Acid Makeup Isol Valve (by NRHX Cube).

NOTE: Engineering has determined blended makeup to the RWST may be performed with RP in service to the RWST. (Reference 2.4.13) 5.1.6 IF RP is in service on the Unit 1 RWST AND securing the RP system is desired, THEN do the following:

_______ a. Secure RP in accordance with the applicable procedure.

_______ _______ b. Ensure 1-RP-24, Refuel Purification Fltrs To Unit 1 RWST Isol Valve, IV located in the Unit 1 Penetration Area, is closed.

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 12 of 36

_______ 5.1.7 Open 1-CH-233, Boric Acid Blender To RWST High Hdr Isol Valve, located in the Unit 1 Penetration Area.

5.1.8 Have the OATC do the following:

_______ a. Record the As-Found Blender Controller settings below:

Auto / Manual Controller Controller Name (circle one) Output Pot Setting Boric Acid To 1-CH-FC-1113A Blender Flow Auto / Manual __________% ___________

Controller Primary Water To 1-CH-FC-1114A Blender Flow Auto / Manual __________% ___________

Controller Primary Water To Blender Flow 1-CH-HFC-1114 __________%

Controller (Half Station)

_______ b. Place the BLENDER CONTROL switch in STOP.

c. Close the following valves:

_______ _______

• 1-CH-FCV-1113A, BORIC ACID TO BLENDER VALVE IV

_______ _______

• 1-CH-FCV-1113B, BLENDER MAKEUP TO CHG PP SUCTION IV HDR

_______ _______

• 1-CH-FCV-1114B, BLENDER MAKEUP TO VCT IV

_______ d. Have a second qualified person independently verify that the valves in Substep 5.1.8.c are closed.

_______ e. Determine required flow for desired concentration of the blend using the latest boron sample of the BAST and RWST.

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 13 of 36 NOTE: Integrator operation for 1-CH-DCC-1113, Boric Acid and PG Digital Controller, is provided in the Attachment of 1-OP-8.3, Boron Concentration Control.

f. Adjust the integrator on 1-CH-DCC-1113, Boric Acid and PG Digital Controller, as follows:

• IF automatic integrator make-up termination is desired, THEN Set AND Enable [RUN] the following applicable integrator setpoint (SP) values to the required quantity to be added:

_______ ** Boric Acid

_______ ** PG Water

• IF automatic integrator make-up termination is NOT desired, THEN ensure the following applicable integrator setpoint (SP) values are Set AND Enabled [RUN] above the required quantity to be added:

_______ ** Boric Acid (maximum 3000)

_______ ** PG Water (maximum 30,000)

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 14 of 36 5.1.9 IF Unit 1 is in Modes 3 - 6, THEN do the following in accordance with Tech Spec 3.1.8 or Tech Spec 3.9.2 as applicable:

_______ a. Ensure chemical addition to Unit 1 RCS is not in progress.

b. Close and lock the following valves:

_______ _______ 1. 1-CH-220, PG to Charging Pump Suction (near chem mixing tk at IV blender)

_______ _______ 2. 1-CH-241, Manual Emergency Borate Valve (at blender)

IV

c. Close the following valves, and vent the regulators to fail the blender outlet valves closed:

_______ _______ 1. 1-IA-755, IA to 1-CH-FCV-1113B, Blender Outlet to Ch Pump IV Suction

_______ _______ 2. 1-IA-704, IA to 1-CH-FCV-1114B, Blender Outlet to Top of VCT IV

_______ d. Ensure Substeps 5.1.9.b and 5.1.9.c have been independently verified.

_______ e. Unlock AND open 1-CH-217, PG Supply To Boric Acid Blender Isolation Valve.

_______ 5.1.10 At the Unit 1 Blender, open 1-CH-230, Boric Acid Blender To RWST And Fuel Pit Isol Vv.

_______ 5.1.11 Notify the Health Physics Count Room that makeup to the RWST will commence. (Reference 2.3.8 and 2.4.8)

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 15 of 36 NOTE: The RWST should NOT be filled above the high level alarm (98.5 percent).

Total Gallons from low level to high level is approximately 8500 gallons.

NOTE: A large volume RWST makeup from the Blender will add a significant amount of heat to the RWST. To prevent RWST high temperature concerns when in Modes 1 - 4, makeups should be terminated prior to reaching 50 °F at the RWST Tank Temp Top, 1-QS-TI-100A. Makeup to RWST at slower rates will result in slower heatup of the RWST.

5.1.12 Have OATC start makeup to the RWST as follows:

_______ a. Place BLENDER MODE switch in MANUAL.

_______ b. Place BLENDER CONTROL switch in START.

_______ c. Place 1-CH-FCV-1113A, BORIC ACID TO BLENDER VALVE in AUTO, or operate in manual as desired.

5.1.13 Have OATC obtain the desired flow rates by adjusting the following controllers:

_______

• 1-CH-FC-1113A, BORIC ACID TO BLENDER FLOW CONTROLLER

_______

• 1-CH-FC-1114A, PRIMARY WATER TO BLENDER FLOW CONTROLLER

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 16 of 36 5.1.14 Perform CHANNEL CHECK on RWST level indicators as follows:

(Reference 2.3.6)

a. Record the levels for the following indicators:

_______

• 1-QS-LI-100A: ________%

_______

• 1-QS-LI-100B: ________%

_______

• 1-QS-LI-100C: ________%

_______

• 1-QS-LI-100D: ________%

_______ b. Check level channels agree within 3 percent.

_______ c. Check levels are increasing.

5.1.15 WHEN makeup to the RWST is complete, OR the makeup is stopped, THEN have OATC do the following:

_______ a. Place 1-CH-FCV-1113A, BORIC ACID TO BLENDER VALVE, in CLOSE.

_______ b. Place BLENDER CONTROL switch in STOP.

_______ c. IF continuing the RWST makeup is desired, THEN return to Step 5.1.12.

5.1.16 IF Unit 1 is in Modes 3 - 6, THEN do the following in accordance with Tech Spec 3.1.8 or Tech Spec 3.9.2 as applicable:

_______ _______ a. Close AND lock 1-CH-217, PG Supply To Boric Acid Blender Isolation IV Valve.

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 17 of 36

_______ b. Ensure Substep 5.1.16.a has been independently verified.

c. Open the following valves to restore IA to the blender outlet valves:

_______ _______ 1. 1-IA-755, IA to 1-CH-FCV-1113B, Blender Outlet to Ch Pump IV Suction

_______ _______ 2. 1-IA-704, IA to 1-CH-FCV-1114B, Blender Outlet to Top of VCT IV

d. Remove the locks from the following valves:

_______ _______ 1. 1-CH-220, PG to Charging Pump Suction (near chem mixing tk at IV blender)

_______ _______ 2. 1-CH-241, Manual Emergency Borate Valve (at blender)

IV 5.1.17 Do the following to prevent Blender flow from entering the Spent Fuel Pit or the RWST:

a. Close the following valves:

_______ _______

• 1-CH-233, Boric Acid Blender To RWST High Hdr Isol Valve (Unit 1 IV Pen Area)

_______ _______

• 1-CH-230, Boric Acid Blender To RWST And Fuel Pit Isol Vv (by IV Unit 1 Blender)

_______ b. Have a second qualified person independently verify that the valves in Substep 5.1.17.a are closed.

5.1.18 IF required, THEN have OATC place the following valves in AUTO:

_______ _______

• 1-CH-FCV-1113A, BORIC ACID TO BLENDER VALVE IV

_______ _______

• 1-CH-FCV-1113B, BLENDER MAKEUP TO CHG PP SUCTION HDR IV

_______ _______

• 1-CH-FCV-1114B, BLENDER MAKEUP TO VCT IV

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 18 of 36 5.1.19 Do the following to ensure proper Blender settings:

_______ _______ a. Ensure the Blender Controller is returned to the As-Found settings IV recorded in Step 5.1.8.a.

_______ b. IF desired, THEN perform an RCS make-up to adjust Blender Controller settings in accordance with 1-OP-8.3, Boron Concentration Control.

_______ 5.1.20 IF required, THEN have OATC return the Blender to AUTO in accordance with 1-OP-8.3, Boron Concentration Control.

NOTE: Integrator operation for 1-CH-DCC-1113, Boric Acid and PG Digital Controller, is provided in the Attachment of 1-OP-8.3, Boron Concentration Control.

5.1.21 Ensure the following 1-CH-DCC-1113, Boric Acid and PG Digital Controller, integrator setpoint (SP) values are Set sufficiently high AND Enabled [RUN] to prevent stopping non-automatic make-up operations:

_______

• Boric Acid (maximum 3000)

_______

• PG Water (maximum 30,000)

_______ 5.1.22 Notify Chemistry Department to sample the RWST.

_______ 5.1.23 IF RP was secured on the Unit 1 RWST in Step 5.1.6 AND return to service is desired, THEN return RP to service in accordance with the applicable procedure.

_______ 5.1.24 IF desired to place the Reverse Osmosis Unit for Silica Reduction in service on the Unit 1 RWST, THEN place the BARS in service using 0-OP-16.9, Operation of the Reverse Osmosis Unit for Silica Reduction.

Completed by: ___________________________________________ Date: _________

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 19 of 36 5.2 Placing The RWST On The Chilled Water Coolers NOTE: It is desired to minimize the time 1-QS-40, RWST Low Header To Refuel Wtr Recirc Pps Isol Valve, is open in Modes 1-4 to minimize the possibility of losing RWST level through a break in the piping downstream of 1-QS-40.

This piping was reclassified NSQ by DCP 04-116.

_______ 5.2.1 Review Precautions and Limitations.

5.2.2 Align Chilled Water to the desired Chilled Water Cooler as follows:

a. For 1-CD-E-2A, 2A Chilled Wtr Refueling Water Storage Tank Cooler, open the following valves:

_______

• 1-CD-27, 2A RWST Cooler Chilled Water Supply Isol Valve

_______

• 1-CD-35, 2A RWST Cooler Chilled Water Outlet Isol Valve

b. For 1-CD-E-2B, 2B Chilled Wtr Refueling Water Storage Tank Cooler, open the following valves:

_______

• 1-CD-30, 2B RWST Cooler Chilled Water Supply Isol Valve

_______

• 1-CD-40, 2B RWST Cooler Chilled Water Outlet Isol Valve

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 20 of 36 CAUTION The maximum design flowrate of each RWST Cooler is 600 gpm. (Reference 2.4.5) 5.2.3 Align the Chilled Water System to the coolers using one of the following:

_______

• 1-OP-51.2, Chilled Water System: Steam Chiller Operation

_______

• 0-OP-51.5, Operation Of The Chilled Water Systems: Mechanical Chiller

_______

• 2-OP-51.2, Chilled Water System: Steam Chiller Operation 5.2.4 Ensure that the proper flowpath is aligned to and from the RWST:

(Reference 2.4.9)

_______ a. Ensure that 1-QS-40, RWST Low Header To Refuel Wtr Recirc Pps Isol Valve, is Open.

_______ b. Ensure that 1-QS-60, RWST Coolers To RWST Low Header Isol Valve, is Open.

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 21 of 36 5.2.5 Align the RWST to the desired Chilled Water Cooler as follows:

a. For 1-CD-E-2A, 2A Chilled Wtr Refueling Water Storage Tank Cooler, open the following valves:

_______

• 1-QS-58, 2A RWST Cooler Outlet Header Isolation Valve

_______

• 1-QS-48, 2A RWST Cooler Inlet Header Isolation Valve

b. For 1-CD-E-2B, 2B Chilled Wtr Refueling Water Storage Tank Cooler, open the following valves:

_______

• 1-QS-59, 2B RWST Cooler Outlet Header Isolation Valve

_______

• 1-QS-47, 2B RWST Cooler Inlet Header Isolation Valve 5.2.6 Isolate both Mechanical Refrigeration units by closing the following valves:

_______ _______

• 1-QS-49, Refuel Wtr Refrigeration Unit 1A Inlet Hdr Isol Vv IV

_______ _______

• 1-QS-52, Refuel Wtr Refrigeration Unit 1A Out Hdr Isol Vv IV

_______ _______

• 1-QS-53, Refuel Wtr Refrigeration Unit 1B Inlet Hdr Isol Vv IV

_______ _______

• 1-QS-56, Refuel Wtr Refrigeration Unit 1B Out Hdr Isol Vv IV 5.2.7 IF 1-QS-P-2A, Refueling Water Storage Tk Recirc Pump, or 1-QS-P-2B, Refueling Water Storage Tk Recirc Pump, have NOT been ran since the RWST was drained for cavity fill, THEN vent the pump to be started as follows:

a. IF 1-QS-P-2A will be started, THEN do the following:

_______ 1. Open 1-QS-96, 2A Refuel Wtr Recirc Pump Disch Sample Isol Valve

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 22 of 36

_______ 2. Crack open 1-QS-119, 2A Refuel Wtr Recirc Pump Disch Sample Isol Valve, to vent pump.

_______ 3. WHEN a steady stream of water issues, THEN close 1-QS-119.

_______ 4. Close 1-QS-96.

5. Have a qualified person independently verify the following valves are closed:

_______

• 1-QS-96, 2A Refuel Wtr Recirc Pump Disch Sample Isol Valve IV

_______

• 1-QS-119, 2A Refuel Wtr Recirc Pump Disch Sample Isol Valve IV

b. IF 1-QS-P-2B will be started, THEN do the following:

_______ 1. Open 1-QS-97, 2B Refuel Wtr Recirc Pump Disch Sample Isol Valve

_______ 2. Crack open 1-QS-120, 2B Refuel Wtr Recirc Pump Disch Sample Isol Valve, to vent pump.

_______ 3. WHEN a steady stream of water issues, THEN close 1-QS-120.

_______ 4. Close 1-QS-97.

5. Have a qualified person independently verify the following valves are closed:

_______

• 1-QS-97, 2B Refuel Wtr Recirc Pump Disch Sample Isol Valve IV

_______

• 1-QS-120, 2B Refuel Wtr Recirc Pump Disch Sample Isol Valve IV

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 23 of 36 5.2.8 Place one of the following pumps in FAST:

_______

• 1-QS-P-2A, Refueling Water Storage Tk Recirc Pump

_______

• 1-QS-P-2B, Refueling Water Storage Tk Recirc Pump Completed by: ___________________________________________ Date: _________

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 24 of 36 5.3 Removing The RWST From The Chilled Water Coolers

_______ 5.3.1 Review Precautions and Limitations.

5.3.2 Stop the following pumps:

_______

• 1-QS-P-2A, Refueling Water Storage Tk Recirc Pump

_______

• 1-QS-P-2B, Refueling Water Storage Tk Recirc Pump 5.3.3 Isolate the RWST from the desired Chilled Water Heat Exchanger as follows:

a. For 1-CD-E-2A, 2A Chilled Wtr Refueling Water Storage Tank Cooler, close the following valves:

_______ _______

• 1-QS-58, 2A RWST Cooler Outlet Header Isolation Valve IV

_______ _______

• 1-QS-48, 2A RWST Cooler Inlet Header Isolation Valve IV

b. For 1-CD-E-2B, 2B Chilled Wtr Refueling Water Storage Tank Cooler, close the following valves:

_______ _______

• 1-QS-59, 2B RWST Cooler Outlet Header Isolation Valve IV

_______ _______

• 1-QS-47, 2B RWST Cooler Inlet Header Isolation Valve IV

_______ _______ 5.3.4 Close 1-QS-40, RWST Low Header To Refuel Wtr Recirc Pps Isol Valve.

IV

_______ _______ 5.3.5 Close 1-QS-60, RWST Coolers To RWST Low Header Isol Valve.

IV

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 25 of 36 5.3.6 IF required, THEN remove the Chilled Water System from the coolers using one of the following:

_______

• 1-OP-51.2, Chilled Water System: Steam Chiller Operation

_______

• 0-OP-51.5, Operation Of The Chilled Water Systems: Mechanical Chiller

_______

• 2-OP-51.2, Chilled Water System: Steam Chiller Operation 5.3.7 IF required to isolate the coolers, THEN close the following valves:

_______

• 1-CD-27, 2A RWST Cooler Chilled Water Supply Isol Valve

_______

• 1-CD-35, 2A RWST Cooler Chilled Water Outlet Isol Valve

_______

• 1-CD-30, 2B RWST Cooler Chilled Water Supply Isol Valve

_______

• 1-CD-40, 2B RWST Cooler Chilled Water Outlet Isol Valve Completed by: ___________________________________________ Date: _________

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 26 of 36 5.4 Placing RWST Mechanical Refrigeration Unit In Service OR Swapping Units

_______ 5.4.1 Review Precautions and Limitations.

5.4.2 IF a Refueling Water Refrigeration Unit is in service, THEN stop the unit in service by placing the toggle switch to OFF:

_______

• 1-QS-MR-1A, Refueling Water Refrigeration Unit

_______

• 1-QS-MR-1B, Refueling Water Refrigeration Unit CAUTION

• For 1-QS-MR-1A, Refueling Water Refrigeration Unit, and 1-QS-MR-1B, Refueling Water Refrigeration Unit, IF power to a refrigeration unit has been OFF more than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, THEN the compressor heaters must be energized for a minimum of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to starting a compressor. This is to ensure that the oil is hot enough to drive the refrigerant out of solution.

• Do NOT run both chillers at the same time. There is not sufficient recirc flow to run both chillers at once.

5.4.3 Place the desired Mechanical Refrigeration unit in service as follows. Mark steps for the unit NOT started N/A:

a. For 1-QS-MR-1A, Refueling Water Refrigeration Unit, do the following:

1. Open the following valves:

_______

• 1-QS-49, Refuel Wtr Refrigeration Unit 1A Inlet Hdr Isol Vv

_______

• 1-QS-52, Refuel Wtr Refrigeration Unit 1A Out Hdr Isol Vv

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 27 of 36

2. Ensure the following valves are closed:

_______ _______

• 1-QS-53, Refuel Wtr Refrigeration Unit 1B Inlet Hdr Isol Vv IV

_______ _______

• 1-QS-56, Refuel Wtr Refrigeration Unit 1B Out Hdr Isol Vv IV

b. For 1-QS-MR-1B, Refueling Water Refrigeration Unit, do the following:

1. Open the following valves:

_______

• 1-QS-53, Refuel Wtr Refrigeration Unit 1B Inlet Hdr Isol Vv

_______

• 1-QS-56, Refuel Wtr Refrigeration Unit 1B Out Hdr Isol Vv

2. Ensure the following valves are closed:

_______ _______

• 1-QS-49, Refuel Wtr Refrigeration Unit 1A Inlet Hdr Isol Vv IV

_______ _______

• 1-QS-52, Refuel Wtr Refrigeration Unit 1A Out Hdr Isol Vv IV NOTE: It is desired to minimize the time 1-QS-40, RWST Low Header To Refuel Wtr Recirc Pps Isol Valve, is open in Modes 1-4 to minimize the possibility of losing RWST level through a break in the piping downstream of 1-QS-40.

This piping was reclassified NSQ by DCP 04-116.

c. IF low suction to Recirc Pumps is required, THEN do the following:

_______ 1. Open 1-QS-40, RWST Low Header To Refuel Wtr Recirc Pps Isol Valve.

_______ 2. Close 1-QS-39, RWST Hi Header To Refuel Wtr Recirc Pps Isol Valve.

d. IF high suction to Recirc Pumps is required, THEN do the following:

_______ 1. Check adequate RWST level to support high suction.

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 28 of 36

_______ 2. Ensure 1-QS-39, RWST Hi Header To Refuel Wtr Recirc Pps Isol Valve is open.

_______ 3. Ensure 1-QS-40, RWST Low Header To Refuel Wtr Recirc Pps Isol Valve is closed.

NOTE: Refrigeration Unit discharge is always aligned to the upper portion of RWST.

_______ e. IF low suction to recirc pumps is required, THEN open 1-QS-60, RWST Coolers To RWST Low Header Isol Valve, to provide a low discharge path. (Reference 2.4.9)

_______ f. IF the low suction is placed in service, THEN enter a Mode 4 info action that the chillers are aligned to the low suction.

5.4.4 IF NOT already running, THEN start one of the following pumps in SLOW:

_______

• 1-QS-P-2A, Refueling Water Storage Tk Recirc Pump

_______

• 1-QS-P-2B, Refueling Water Storage Tk Recirc Pump 5.4.5 Start the desired Mechanical Refrigeration Unit by placing the toggle switch for the chiller to be started to ON:

_______

• 1-QS-MR-1A, Refueling Water Refrigeration Unit

_______

• 1-QS-MR-1B, Refueling Water Refrigeration Unit Completed by: ___________________________________________ Date: _________

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 29 of 36 5.5 Removing RWST Mechanical Refrigeration Unit From Service

_______ 5.5.1 Review Precautions and Limitations.

5.5.2 Secure the running Mechanical Refrigeration Unit by placing the toggle switch to OFF:

_______

• 1-QS-MR-1A, Refueling Water Refrigeration Unit

_______

• 1-QS-MR-1B, Refueling Water Refrigeration Unit 5.5.3 IF BOTH Mechanical Chillers will be removed from service AND pump will NOT have a flow path, THEN place the operating pump in OFF:

_______

• 1-QS-P-2A, Refueling Water Storage Tk Recirc Pump

_______

• 1-QS-P-2B, Refueling Water Storage Tk Recirc Pump 5.5.4 Isolate the applicable Mechanical Refrigeration unit as follows:

a. For 1-QS-MR-1A, Refueling Water Refrigeration Unit, close the following valves:

_______ _______

• 1-QS-49, Refuel Wtr Refrigeration Unit 1A Inlet Hdr Isol Vv IV

_______ _______

• 1-QS-52, Refuel Wtr Refrigeration Unit 1A Out Hdr Isol Vv IV

b. For 1-QS-MR-1B, Refueling Water Refrigeration Unit, close the following valves:

_______ _______

• 1-QS-53, Refuel Wtr Refrigeration Unit 1B Inlet Hdr Isol Vv IV

_______ _______

• 1-QS-56, Refuel Wtr Refrigeration Unit 1B Out Hdr Isol Vv IV

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 30 of 36

_______ _______ 5.5.5 IF low return to the RWST is not required, THEN ensure that 1-QS-60, IV RWST Coolers To RWST Low Header Isol Valve, is closed.

Completed by: ___________________________________________ Date: _________

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 31 of 36 5.6 Swapping RWST Recirc Pumps

_______ 5.6.1 Review Precautions and Limitations.

5.6.2 IF swapping to 1-QS-P-2A, Refueling Water Storage Tk Recirc Pump, THEN do the following:

_______ a. Circle As Found speed of 1-QS-P-2B: SLOW / FAST

_______ b. Place control switch for 1-QS-P-2A in speed of 1-QS-P-2B.

_______ c. Place control switch for 1-QS-P-2B in OFF.

5.6.3 IF swapping to 1-QS-P-2B, Refueling Water Storage Tk Recirc Pump, THEN do the following:

_______ a. Circle As Found speed of 1-QS-P-2A: SLOW / FAST

_______ b. Place control switch for 1-QS-P-2B in speed of 1-QS-P-2A.

_______ c. Place control switch for 1-QS-P-2A in OFF.

Completed by: ___________________________________________ Date: _________

ATTACHMENTS

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 32 of 36 (Page 1 of 1)

Attachment 1 Unit 1 RWST Operations Diagram 1-QS-61 1-QS-59 1-QS-58 1-QS-39 1-QS-TK-1 Refueling Water 1-QS-60 1-CD 1-CD Storage Tank

-E-2B -E-2A Coolers RWST 1-QS-40 1-QS-47 1-QS-48 Refueling Water Refrigeration Units 1-QS-46 1-QS-53 1-QS-56 1-QS-44 1-QS 1-QS -MR-1B

-P-2B 1-QS-43 1-QS-49 1-QS-52 1-QS 1-QS-41 -MR-1A 1-QS

-P-2A 1-RP-128 Refueling Water Recirculation Pumps To Spent Fuel Pool 1-RP-127 To #1 To #2 RWST Sample RWST 1-RP-81 1-RP-80 1-RP-24 1-RP-134 1-RP-79 1-RP-78 To #1 Cavity To #2 Cavity 1-CH-233 1-CH-232 2-CH-147 2-CH-148 From 1-RP-FL-1A From 1-CH-230 1-RP-FL-1B 2-CH-145 From #1 Blender From #2 Blender Graphics No: WT642C UNIT 1 RWST OPERATIONS

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 33 of 36 (Page 1 of 4)

Attachment 2 York Control Center Display Information NOTE: In addition to the listed displays, Printouts, History displays, and setpoint displays are also available but are not included here because of limited use to Operators. Data and History printout is obtained by hooking up printer supplied by vendor. See vendor manual for instructions if access to these functions are required.

Status Messages Display Message Meaning / Action STATUS Messages - Possible messages when STATUS button is pressed:

General Status Messages UNIT SWITCH OFF Unit switch on control panel is in OFF position. Unit will not run.

SHUTDOWN REMOTE CONTROLLED Should not appear at North Anna. We have no remote controls on this system.

SHUTDOWN DAILY SCHEDULE Should not appear at North Anna. We have system scheduled to run 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> a day, 7 SHUTDOWN days a week.

FLOW SWITCH / REM STOP Water flow switch is open, preventing chiller from running.

NO RUN PERM SYS 1 SYS SWITCH OFF System switch under OPTIONS is turned off. System will not be allowed to run until SYS 2 SYS SWITCH OFF switch is turned back on.

SYS 1 NO COOL LOAD Inlet water temperature below 40°F. Prevents system operation.

SYS 2 NO COOL LOAD SYS 1 COMPS RUN X Indicates the number of compressors running. X will be replaced by the actual number SYS 2 COMPS RUN X of compressors running.

SYS 1 AR TIMER XX S Shows amount of time left on the anti-recycle timer. Displayed when the system is SYS 2 AR TIMER XX S unable to start due to the anti-recycle timer being active.

SYS 1 DSCH LIMITING Discharge pressure limiting is in effect. Due to high load or pull down conditions.

SYS 2 DSCH LIMITING Stops one compressor. Allows restart when discharge pressure drops to 85% of unload pressure and 10 minutes have elapsed.

SYS 1 LOAD LIMIT XX% Load limiting is in effect. Should not appear at North Anna.

SYS 2 LOAD LIMIT XX%

MANUAL Daily Schedule is being ignored and system will start if controls and interlocks permit.

OVERRIDE Priority message that cannot be overridden by other messages. Only use for emergencies and servicing. Override automatically disables itself after 30 minutes.

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 34 of 36 (Page 2 of 4)

Attachment 2 York Control Center Display Information Status Messages Display Message Meaning / Action SYS 1 PUMPING DOWN A compressor is pumping the system down on shutdown. Compressor shuts off when SYS 2 PUMPING DOWN suction pressure decreases to suction pressure cutout setpoint, or 180 seconds, whichever comes first.

Fault Status Messages System Safeties - System shutdown if a safety threshhold is exceeded for 3 seconds. Auto reset. However, if 3 faults occur within 90 minutes, system is locked out on last fault and requires manual reset. the system switch (under OPTIONS key) must be turned off and then back on to clear the lockout fault.

SYS 1 HIGH DSCH PRES System will shutdown when the discharge pressure programmable cutout is exceeded SYS 2 HIGH DSCH PRES and will be allowed to restart when the discharge pressure falls 40 psig below the cutout.

SYS 1 LOW SUCT PRESS Stops the system if suction pressure falls to 23 psig and resets at 35 psig. Ignored for SYS 2 LOW SUCT PRESS first 30 seconds after system startup.

SYS 1 MP/HPCO INHIB Compressor shutdown to protect motor from overheating, protect compressor from SYS 2 MP/HPCO INHIB dangerously high discharge pressure, or protect compressor scroll from overheating.

The system will NOT be locked out.

SYS 1 MP/HPCO FAULT On the third MP/HPCO Inhibit fault, the MP/HPCO Fault will lockout the system for SYS 2 MP/HPCO FAULT 30 minutes.

SYS 1 HIGH MTR CURR Actual system voltage exceeds trip voltage for 5 seconds and system shuts down.

SYS 2 HIGH MTR CURR Clears when condition no longer present.

SYS 1 LOW SUPERHEAT Shuts down the compressor(s) to protect from liquid floodback due to low suction SYS 2 LOW SUPERHEAT superheat.

SYS 1 SENSOR FAILURE Prevents system from running when sensors measuring superheat are not functioning SYS 2 SENSOR FAILURE properly. Locks out system and prevents auto restarting.

Unit Safeties - Faults that cause all running compressor(s) to shutdown. Auto reset after condition is no longer present.

UNIT FAULT: Unit shutdown to protect chiller from operating in a low ambient condition. Restart can LOW AMBIENT TEMP occur when temperature rises 2°F above the cutoff.

UNIT FAULT: Unit shutdown to protect evaporator from freeze-up should water temperature fall LOW LIQUID TEMP below the freeze point. Restart can occur when temperature rises 2°F above the cutoff.

UNIT FAULT: Unit shutdown to ensure system is not operated at voltages where malfunction of the 115VAC UNDER VOLTAGE microprocessor could result in system damage. Restart allowed after power restored and anti-recycle timers have timed out.

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 35 of 36 (Page 3 of 4)

Attachment 2 York Control Center Display Information Status Messages Display Message Meaning / Action UNIT FAULT: Unit shutdown when voltage exceeds programmed trip voltage for 5 seconds when the HIGH MTR CURR CURRENT FEEDBACK ONE PER UNIT option is selected under the OPTIONS key.

Restart allowed after anti-recycle timer has timed out.

Unit Warning - Not a safety and will not be logged in history buffer. Unit will not auto-restart. Operator reset required.

! ! LOW BATTERY ! ! Can only occur at startup. If low battery is found, all values are reset to default. Replace CHECK PROG/SETP/OPTN battery and press PROGRAM key to reset. This sets anti-recycle timer to allow time to check setpoints and reprogram as necessary.

Display Operator Data Display Parameter OPER DATA KEY DISPLAYS - use UP and DOWN arrow keys to scroll through displays.

LCHLT = XX.X°F Chilled Water leaving and returning temperatures. Display Limit is 9.2 - 140°F RCHLT = XX.X°F AMBIENT AIR TEMP Ambient Air Temperature. Display Limit is 0.4- 131.2°F

= XX.X°f SYS X SP = XX.X PSIG Suction and discharge pressures. Suction Pressure Display Limit is 0 - 200 psig.

DP = XX.X PSIG Discharge Pressure Display Limit is 0 - 400 psig.

SYS X HOURS 1 = XXXXX Compressor accumulated runtimes.

2 = XXXXX SYS X STARTS 1 = XXXXX Number of starts for each compressor.

2 = XXXXX LOAD TIMER XX SEC Time in seconds until the unit can load or unload. Whether system loads or unloads is UNLOAD TIMER XX SEC determined by how far actual liquid temperature is from setpoint.

COOLING DEMAND Current step in capacity control scheme when in Return Water Control Mode.

X OF X STEPS TEMP ERROR XXX.X°F Temperature error and rate of change of Chilled Water when in Leaving Chilled Liquid TEMP RATE XXX.X°F/M Control mode.

EVAP PUMP IS OFF Evaporator pump and heater status. Evap Pump should be OFF since we do not have EVAP HEATER IS OFF our pump wired to the chiller unit.

ACTIVE REMOTE CTRL Type of Remote Control Active. Our units do not have remote control.

NONE

DOMINION 1-OP-7.7 North Anna Power Station Revision 57 Page 36 of 36 (Page 4 of 4)

Attachment 2 York Control Center Display Information Display Operator Data Display Parameter UNIT AMPS = XX.X Total chiller current and voltage, if CURRENT FEEDBACK is programmed as VOLTS = XX.X NONE.

SYS X COMP STATUS Indicates compressors running.

1 = XXX 2 = XXX SYS X RUN TIME Run time for the current system cycle. (NOT accumulated runtime.)

XX - XX - XX - XX D-H-M-S SYS X LLSV IS ON Status of liquid line solenoid and hot gas solenoid as called for by controller board.

HOT GAS SOL IS OFF SYS X FAN STAGE X Indicates what stage of condenser fan operation is active.

SYS X AMPS = XX.X System current and voltage, if CURRENT FEEDBACK is programmed.

VOLTS = XX.X