ML080720490

Feb Exam 05000327-08-301, 05000328-08-301 Final Simulator Scenarios

ML080720490
Person / Time
Site:	Sequoyah
Issue date:	02/29/2008
From:	- No Known Affiliation
To:	Office of Nuclear Reactor Regulation, NRC/RGN-II
References
ER-08-301
Download: ML080720490 (341)

Text

{{#Wiki_filter:Final Submittal (Blue Paper) FINAL SIMULATOR SCENARIOS c§E4)uoy/lH cXc;o8-~C>/

I Appendix 0 Scenario Outline Form ES-D-1 I Facility: Sequoyah Scenario No.: 1 Op Test No.: NRC Examiners: Operators: Initial Conditions: 100% Power BOL Turbine Driven Auxiliary Feed water Pump OOS for Maintenance Turnover: Reduce Power To 93% for turbine valve testing. Target CTs: Initiate Feed and Bleed Per FR-H.1 Including manual start of SI Pump 1B-B prior to 10% Wide Range S/G level. Establish Feedwater flow from Condensate or AFW prior to exiting FR-H.1. Event Malf. No. Event Type* Event Description No. 1 N/A R-ATC Reduce Power from 100% N-SRO/BOP 2 NI07A TS-SRO NIS Power Range instrument Channel I fails high and requires I-SRO/ATC taking rods to manual due to inadvertent insertion. Tech Spec Evaluation. 3 CV01B TS-SRO Charging Pump 1B Trip Requires placing Standby pump in service and restoring letdown. Tech Spec Evaluation. C-ATC 4 RX26A TS-SRO Steam Generator #1 Pressure Channel fails low requiring manual control of loop 1 S/G Level Control valve. Tech Spec Evaluation. I-SRO/BOP 5 CN09 C-SRO/BOP Condenser Vacuum leak. 6 FW11A M-AII MFP A Trip From Spurious Low Vacuum results in plant runback. ZDISIC46 MFP Turb B Speed Controller (SIC-46-20B) - Speed Demand 20B Output Fails to 0% 3 Minutes after MFP A Trip requiring Reactor Trip if Rx Trip not already initiated during runback. 7 FW21B C-SRO/BOP AFW Pump 1B-B Airbound may eventually be restored by venting Pump casing. 8 ED06A C-SRO/BOP 1A Shutdown board Differential Fault 5 min after Rx Trip results in loss of 2nd Charging Pump, loss of last AFW pump 1A-A, and manual shutdown of DIG 1A-A due to a loss of cooling water. Initiates loss of all Feedwater flow to S/Gs and ultimately RCS Feed and Bleed due to loss of secondary Heat Sink with both Charging Pumps unavailable. 9 SI13A C-SRO/ATC Safety Injection pump 1B-B Auto Start failure requiring manual start to provide injection flow for RCS Feed and Bleed.

       *   (N)ormal,    (R)eactivity,  (I)nstrument,     (C)omponent,      (M)ajor Appendix 0                                                                             NUREG 1021 Revision 9

I Appendix 0 Scenario Outline Form ES-D-1 I Scenario 1 Summary The Crew will assume shift at 100% power with direction to reduce power to -93% for Main Turbine Valve testing. The Turbine Driven Auxiliary Feedwater pump (TDAFW) out of service for maintenance and will not be returned to service during the scenario. Following the power reduction, NIS power range channel I will fail high resulting in rod insertion and manual control to stop the insertion. The SRO will enter AOP-1.01 and direct actions to defeat the failed channel and return rod control to automatic. The SRO will also evaluate and enter applicable Technical Specifications. After the NIS Channel failure had been addressed, Charging Pump 1B will trip requiring placing the standby pump in service and restoring letdown. The SRO will evaluate and enter applicable Technical Specifications and Technical Requirements. After letdown is restored, Steam Generator #1 Pressure Transmitter will fail low resulting in the associated steam flow channel failing low due to density compensation input requiring manual control of Loop 1 feedwater control valve. SRO will direct performance of AOP-S.01 (Optional) and AOP-1.06 to select unaffected steam flow channel for control and returning feedwater control valve to Auto. Technical specifications may also be addressed for the failed pressure channel. A small condenser vacuum leak will occur that requires performance of AOP-S.02 but is not large enough to require Reactor and Turbine Trip. After condenser vacuum leak is adequately addressed, Main Feedwater Pump A will trip due to spurious low vacuum trip resulting in plant runback. Crew may elect to conservatively trip during runback since TDAAFW is not available and 1B-B MD AFW Pump is airbound (See below). ( Three minutes after MFP A trip, MFP B speed controller will fail to zero resulting in loss of all Main feedwater flow. Reactor trip will be required due to loss of Steam Generator level if not already initiated during runback and crew will enter Emergency procedure E-O and transition to ES-0.1. When AFW pump 1B-B starts due to Main Feedwater pump A trip, it will be airbound. Crew may eventually initiate venting of the pump casing and the pump may be restored following venting. Several minutes (-5) after the Rx Trip, a differential fault will occur on 6.9 Kv Shutdown 1A-A resulting in loss of the last Charging pump and the last Motor driven Auxiliary Feedwater pump 1A-A resulting in transition to FR-H.1 for loss of secondary heatsink. Scenario Failure/Event timing should ensure all S/G levels are less than 10% at this time or close enough to ensure timely entry into FR-H.1. After entering FR-H.1 the crew will initiate manual Sl and RCS feed and bleed since there are no charging pumps available. Upon initiating SI for Feed and Bleed, the crew will be required to manually start the 1B Safety Injection pump that failed to auto start as the source of RCS Feed. The Crew will continue in FR-H.1 to restore feedwater flow by either venting the airbound AFW pump or establishing condensate flow to at least one S/G. The scenario may be terminated after feedwater flow is established to at least one Steam Generator. Appendix 0 NUREG 1021 Revision 9

Page 1 of 3 NRC08A Rev 0 CONSOLE OPERATOR INSTRUCTIONS Sim. Setup ResetIC-~ Initialize simulator at ~% RTP BOL. Perform switch check. Allow the simulator to run for at least 3 minutes before loading SCEN file or starting the Place Mode_1_placard on panels. exercise. This will initialize ICS. Load SCENS: NRC08A Place..A. Train Week sign on the simulator. Place simulator momentarily in RUN, Place OOS equipment in required Ensure 1B-B Charging Pump is in operation. position with tags, Clear alarms and Return to FREEZE. These remote IMF FW07C f:1 TDAFW PUMP IS INOPERABLE. functions are active lOR ZLOHS151A_GREEN f:O when the SCENS file lOR ZLOHS117A_GREEN f:O Close FCV-1-17 & 18 & place Hold Notice on HS-is loaded. lOR ZLOHS118A_GREEN f:O 1-17&18 and FCV-1-51. lOR ZLOHS3136AA_GREEN1 f:O Also place Hold order on TDAFW Pump ERCW lOR ZLOHS3136AA_GREEN2 f:O supply valves. lOR ZLOHS3136AA_RED1 f:O lOR ZLOHS3136AA_RED2 f:O Place Protected Equipment tags on MD AFW lOR ZDIHS3136AA f:O pumps. ( lOR ZLOHS3179AA_GREEN1 f:O lOR ZLOHS3179AA_GREEN2 f:O lOR ZLOHS3179AA_RED1 f:O lOR ZLOHS3179AA_RED2 f:O lOR ZDIHS3179AA f:O Event #1: Decrease -100% DECREASE POWER TO 93% FOR Power as determined TURBINE VALVE TESTING. by NRC Examiner. Event #2: When IMF NI07A f:120 k:1 NIS POWER RANGE CHANNEL 1 (N41) OUTPUT Power Decrease SIGNAL FAILURE HIGH. complete as determined by NRC Acknowledge request to Reactor Engineering to Examiner, Insert this perform O-S/-NUC-OOO-011.0, Moveable Detector Malfuinction using Determination of Quadrant Power Tilt. Key 1 When IMs or MSS contacted to Remove failed power range channel from service per AOP Appendix, inform the crew that the IMs will report to the MCR in - 45 minutes. Event #3: When IMF CV01 B f:1 k:2 CHARGING PUMP B TRIP Determined by NRC Examiner, insert this When the Support SROIAUO are dispatched to Malfunction using investigate, wait - 5 min. and report that the relay

   .<ey 2.                                                         target is instantaneous overcurrent and the motor smells hot.

I

Page 2 of 3 NRC08A Rev 0 CONSOLE OPERATOR INSTRUCTIONS Event #4: When IMF RX26A f:O k:3 STM GEN #1 PRES TRANSMITTER FAILURE, Determined by NRC CHNL I PT-1-2A FAILS LOW Examiner, insert this Malfunction using When MSS or IMs contacted, then inform the Key 3. crew that IMs will be up in the MeR within 45 minutes. Event #5: When IMF CN09 f:O.15 k:4 LOSS OF CONDENSER VACUUM - SMALL LEAK Determined by NRC Examiner, insert this IF personnel are dispatched to look for the Malfunction using vacuum leak wait -5 min THEN report a noise in Key 4. the Turbine Building. near A and B main condenser north side on el 685. Event #6: When IMF FW11A f:1 k:5 MFP A TRIP FROM SPURIOUS LOW VACUUM Determined by NRC SIGNAL Examiner, insert these Malfunctions If dispatched to check pump locally, wait - 5 min using and report no obvious problem locally. KeyS. Time Delayed 3 min lOR ZDISIC4620B f:2 d:180 k:5 MFP TURB B SPEED CONTROLLER (SIC-46-20B) - ( ifter MFP A trip SPEED DEMAND OUTPUT FAILS TO 0%. (key-5) Event # 7: This Malf IMF FW22B f:1 AFW PUMP 1B-B AIRBOUND is active when the SCENS file is loaded. When personnel are dispatched to check pump, wait ~ 5 minutes and report: (IF RUNNING) that 1B-B MDAFW pump casing is hot and pump does not sound normal. (IF NOT RUNNING) that 1B-B MDAFW pump casing is hot. Event #8: Event IMF ED06A f:1 d:300 e:1 DIFFERENTIAL FAULT ON 6.9KV SD BD 1A-A Trigger 5 min after Reactor Trip. If dispatched, wait - 4 minutes and report a board differential relay operation. You cannot determine the cause but will continue to investigate. Event #9: This Malf is IMF SI13B f:1 SI PUMP A AUTO START FAILURE (ALL SIGNALS) active when the - PUMP WILL MANUALLY START SCENS file is loaded

Page 3 of 3 NRC08A Rev 0 CONSOLE OPERATOR INSTRUCTIONS If Dispatched to Vent DMF FW22B RESTORES AFW PUMP 1B-B AIRBOUND TO 1B-B AFW Pump, SIMULATE VENTING COMPLETE. DELETE malfunction only AFTER RCS If directed to Vent and Restore AFW pump 18-8, feed and bleed is stall until after ReS feed and bleed has started or as commenced per FR-H.1, ensure malfunction has Determined by NRC been deleted. and report that venting is complete. Examiner. If Dispatched to IRF CNR06 f:1 k:6 1-FU2-6-21D & 147D DISABLE INTERMEDIATE perform EA-2-2 HEATER ISOLATION Appendix A Part 1 to remove fuses to If dispatched to pull fuses, ensure remote disable intermediate function is entered and wait - 5 min to report heater string isolation fuses removed. insert Remote functions using Key 6 If Dispatched to IRF RPR11 f:1 k:7 BLOCK AUTO SI ON HIGH CONTAINMENT perform EA-99-1 to PRESSURE (EA-99-1) Block Auto SI signals, ( nsert Remote If dispatched as MIG to perform EA-99-1, wait-function using 10 minutes, enter remote function and report Key 7 complete. If Requested to IRF EDR66A f:1 k:8 120 VAC INSTRUMENT POWER RACK A Transfer 1-M7 TRANSFER SWITCH Instrument Rack A to Alternate, Use KEY-8 NOTE: Evaluator will need to intercept personnel dispatched to M-7 back panel to Operate Transfer switch and then request Console operator to enter KEY-B.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # Page 1 of 45

                                                               -----                             """;';;"'-..,1

( Event

Description:

Reduce Power For Turbine Valve Testing Time II Position II Applicant's Actions or Behavior Booth Instructor: No action required for Event 1 Indications available: None Applicable Direct a load reduction in accordance with 0-GO-5 Normal SRO Power Operations, Section 5.3, and 0-SO-62-7 Boron Concentration Control, Section 6.4. Evaluator Note: Following Steps are from 0-SO-62-7 Boron Concentration Control, Section 6.4 CAUTION: Returning the Boric Acid Blender to service after unplugging, cleaning, or maintenance on Boric Acid System could introduce debris, sludge, air or solidified boron into CCP suction resulting in pump damage. Extreme care must be exercised to properly flush the Boric Acid piping following an outage. NOTE: If a large amount of boration is required (plant shutdown), pzr heaters should be energized to cause spray operation for equalizing boron concentration in RCS and pressurizer. ENSURE makeup system aligned for AUTO operation RO in accordance with Section 5.1. NOTE Steps 2 and 3 are NIA for minor power changes OR if immediate boration is required to maintain shutdown margin, to maintain rods above the insertion limit, during an emergency shutdown (AOP-C.03), during recovery of a dropped/misaligned rod (AOP-C.01), or at Chemistry recommendation in mode 3, 4, 5 or 6. RECORD the quantity of boric acid required to achieve desired boron concentration using Appendix D. RO gals PERFORM Appendix I Independent Verification of Calculation for Amount of Boric Acid or Primary Water. (N/A if App. D was performed by SRO to verify data Crew from Rx Engineering)

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # Page 2 of _4.;.;;.5~ Event

Description:

Reduce Power For Turbine Valve Testing Tim Position II Applicant's Actions or Behavior DETERMINE available boric acid volume in in-service BAT. gals RO PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the STOP position. RO PLACE [HS-62-140B], CVCS Makeup Selector Switch to the BORATE position. RO ADJUST [FC-62-139], Boric Acid Flow Controller to the desired flow rate. RO SET [FQ-62-139], Batch Integrator to the desired quantity. RO PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the START position. RO ( ENSURE Boric Acid Pump aligned to blender in FAST speed by right red light LIT on [HS-62-230A] OR [HS-62-232A]. RO NOTE Flow oscillations and/or erratic controller response may require manual operation of Boric Acid Flow Controller [FC-62-139] until stable conditions exist. VERIFY Boric Acid Flow established. RO NOTE It may take approximately 15 minutes before any changes to reactivity are indicated on nuclear instrumentation or RCS temperature indication. IF reactor is critical, THEN MONITOR nuclear instrumentation and reactor coolant temperature to ensure proper response RO from boration. NOTE BAT operability limits are prescribed by TRM 3.1.2.6 (Modes 1-3) or 3.1.2.5 (Modes 4-6).

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # Page 3 of 45

                                                             ......;...----                    ~~I Event

Description:

Reduce Power For Turbine Valve Testing Time Position Applicant's Actions or Behavior IF Volume' Control Tank level increases to 63 percent, THEN ENSURE [LCV-62-118], Volume Control Tank Divert RO Valve OPENS to divert excess water to the Holdup Tank. NOTE Sample may be obtained at normal RCS sample intervals provided the unit is at power and the unit response following the boration is as expected. WHEN boration is complete, THEN

• PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the STOP position.
• CHECK no primary water flow on either [FI-62-142A]

OR [FQ-62-142].

• ENSURE [FC-62-142], Primary Water to Blender Flow
• Controller is in AUTO position and the potentiometer (dial indicator) is set at 35%.
• ADJUST [FC-62-139], Boric Acid Flow Controller to the RO desired blend solution in accordance with TI-44 Boron Tables.
• ENSURE [FCV-62-128] is CLOSED.
• PLACE [HS-62-140B], CVCS Makeup Selector Switch to the AUTO position.
• PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the START position.
• IF RCS boron sample required, THEN NOTIFY Chem Lab to obtain RCS boron sample.

NOTE Boration is done in batches until the total boron and/or power change is completed. REPEAT this section as required to complete total boron RO change. WHEN total boration is complete, THEN:

• REALIGN the blender controls for AUTO makeup to the RO CVCS in accordance with Section 5.1.
• NOTIFY Chem Lab to obtain RCS boron sample.

IF in modes 1, 2, or 3, THEN ENSURE requirements of TRM US 3.1.2.6 are met.

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # ......;.. Page 4 of 45 Event

Description:

Reduce Power For Turbine Valve Testing Time II Position II Applicant's Actions or Behavior Evaluator Note: Following Steps are from 0-GO-5, Normal Power Operation, Section 5.3 Beginning at Notes prior to step 7. NOTES

1) Guidance on restoration of EHC Controls after a BOP runback is contained in Appendix B, Turbine Runback Restoration.

2) For core operating recommendations for situations such as end of core life coast down or unusual power maneuvers, contact Reactor Engineering for guidance.

3) It is recommended that AFD be controlled within the target band.

4) The following general approach should be used during power reduction:

(a) borate RCS to reduce RCS TAVG within limits ofTREF, (b) reduce turbine load to match TREF with TAVG (c) periodically take rod control to MANUAL from AUTO and insert the bank to move AFD near the target value, (d) return rod control to AUTO when not using the bank to control AFD, and (e) repeat the above as necessary to accomplish the load change.

5) Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized during performance.

INITIATE a load reduction. BOP MONITOR turbine load decreasing. BOP CAUTION Do NOT exceed a load change rate of plus or minus 5%/minute or a step change of 10% NOTE TAVG is programmed from 578.2°F at 100% power to 54rF at zero power at a rate of 0.312°F per % power. MONITOR the following during the load reduction: TAVG following TREF program. All RPls, group step counters for rod insertion limits and Crew inoperable rods or rod misalignment, Loop ~ T, and NIS for correct power distribution and quadrant power tilts. Core AFD within -5% control band around the power level dependent target value.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # Event # .....;.. Page 5 of 45 Event

Description:

Reduce Power For Turbine Valve Testing Time Position II Applicant's Actions or Behavior NOTE Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-047-2000 (M-2). Valve position limit approximately 10% above the current BOP governor control indication as turbine load is changed. Lead Examiner may direct initiation of the next event at his discretion (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 2 Event

Description:

NIS Power range Channel I (N41) Fails High Time Position Applicant's Actions or Behavior Booth Instructor: When directed, initiate Event 2 Indications available: Control Rods Inserting M-4 Indicator Full Scale 1-AR-M4-B. D31PRS NIS POWER RANGE OVERPOWER ROD WITHDRAWAL STOP 1-AR-M4-B. E3 NC-46B NIS POWER RANGE CHANNEL DEVIATION 1-AR-M6-A. B1 NC-41U1NC-41-K NIS POWER RANGE HIGH NEUTRON FLUX RATE 1-AR-M6-A. 01 NC-41R NIS POWER RANGE HIGH SETPOINT HIGH FLUX LEVEL Recognizes, announces unexpected Control Rods insertion RO and takes Immediate action to place rod control in manual. ( Refer to alarm response procedures. Crew Determine NIS Instrument Failure has occurred and direct us entry to AOP-1.01 , Nuclear Instrument Malfunction, section 2.3 PLACE rod control in MAN. RO EVALUATE the following Tech Specs for applicability:

• 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation (Action 2 Applies)

SRO

• 3.3.3.5, Remote Shutdown Instrumentation (N/A)
• 3.3.3.7, Accident Monitoring Instrumentation (N/A)
• SR 4.2.4.2, QPTR with one PR Channel Inoperable (Surveillance requirement Applies)

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 2 Event

Description:

NIS Power range Channel I (N41) Fails High Time II Position II Applicant's Actions or Behavior PLACE following switches located on Detector Current Comparator drawer [M-13, N50] in position corresponding to failed Power Range Channel (N41):

• Upper Section RO
• Lower Section
• Appropriate Rod Stop Bypass switch
• Appropriate Power Mismatch Bypass switch DEFEAT failed Power Range channel USING Comparator Channel Defeat switch:

RO

• Comparator and Rate Drawer

[M-13, N37] RESTORE Tavg within 1.5°F of Tref USING one of the following: (

• manual rod control OR Crew
• RCS boration/dilution OR
• turbine load reduction ENSURE OPERABLE Power Range channel selected to the following:
• Nuclear Power Recorder

[M-4, NR-45] RO

• Nuclear Power Recorder - (.6.1)

[M-4, NR-45]

• RCS Temp .6.T recorder - (green pen)

[M-5, XS-68-2B] RETURN rod control to AUTO if desired. RO CHECK reactor power greater than 75%. RO

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # Event # 2 of 45 Event

Description:

NIS Power range Channel I (N41) Fails High Time I Position II Applicant's Actions or Behavior NOTIFY Reactor Engineering to PERFORM O-SI-NUC-OOO-011.0, Moveable Crew Detector Determination of Quadrant Power Tilt Ratio. NOTIFY 1M to remove failed power range channel from service USING appropriate Appendix: POWER RANGE PROT APPENDIX CHANNEL CH SRO N-41  ! A N-42 II B N-43 III C N~44 IV D (N41 Requires Appendix A) GO TO appropriate plant procedure. SRO When technical specifications have been identified or at discretion of the Lead Examiner, proceed to the next event

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 3 Event

Description:

Charging Pump 1B Trip Time Position Applicant's Actions or Behavior Booth Instructor: When directed, initiate event 3 Indications available: Motor trip out Alarm, Panel M-1 Motor trip out Buzzer White Disagreement light on 1B CCP Handswitch 1-AR-M6-C, 0-3, FS-62-93A1B CHARGING LINE FLOW ABNORMAL Refer to alarm response procedures Crew Perform Alarm Response procedure for Charging line flow Abnormal to place standby Charging Pump in service and RO restore letdown. CHECK charging line flow on [1-FI-62-93A]. RO Evaluator Note: Steps 2 through 4 of ARP are Not applicable Step 5c follows below. ( Note If sufficient time exists to obtain a local inspection of the Standby pump, then have an AUO conduct inspection prior to starting pump. IF CCP tripped or failed, THEN PERFORM the following:

1. IF Thermal Barrier flow is present, THEN A. VERIFY 1-LCV-62-132 and -133 OPEN and VCT level>

8% OR RO 1-LCV-62-135 AND/OR 1-LCV-62-136 OPEN. B. ANNOUNCE pump start over PA AND START the standby CCP and check for proper operation. (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 3 Event

Description:

Charging Pump 1B Trip Time II Position I Applicant's Actions or Behavior Caution Starting the standby CCP with RCP seal temperature greater than 230°F could lead to seal damage.

2. IF thermal barrier flow is NOT present or is lost after pump trip, THEN A. ENSURE suction path and VCT Level are normal.

B. VERIFY all RCP Seals less than 230°F. RO C. ANNOUNCE pump start over PA AND START the standby CCP and check for proper operation. (Step Should Be N/A)

3. REESTABLISH charging and letdown in accordance with 1-RO SO-62-1, Chemical & Volume Control System.

( Evaluator Note: Following steps are from 1-S0-62-1 Note This Instruction is to be used if letdown has been taken out of service or has isolated, charging still remains in service and CVCS demin status is unchanged. Note Following Instruction closely may prevent opening letdown relief valve. ENSURE following orifice isolation valves are CLOSED:

• 1-FCV-62-72 RO
• 1-FCV-62-73
• 1-FCV-62-74 PLACE [1-HIC-62-78] in MANUAL, AND OPEN [1-TCV RO 192] to -50%.

ENSURE following letdown isolation valves are OPEN: RO

• 1-FCV-62-69
• 1-FCV-62-70
• 1-FCV-62-77

(

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 3 of 45 Event

Description:

Charging Pump 1B Trip Time Position Applicant's Actions or Behavior Caution Flashing in letdown line may occur if 1-PCV-62-81 is opened excessively. PLACE [1-HIC-62-81A] in MANUAL, AND ADJUST [1-PCV-RO 62-81] to 50-60% OPEN (40-50% output). Caution Step [6] needs to be performed immediately after step [5] is completed to prevent flashing in letdown line. OPEN one of the letdown orifice isolation valves (N/A one(s) not used): RO

• 1-FCV-62-72
• 1-FCV-62-73
• 1-FCV-62-74 Note Normal letdown pressure is 325 psig at operating temperature.

( ADJUST [1-HIC-62-81A] to obtain desired letdown pressure as RO indicated on [1-PI-62-81]. RO PLACE [1-HIC-62-81A] in AUTO. Note Normal letdown temperature is -100°F. ADJUST [1-HIC-62-78A] to obtain desired letdown RO temperature, as indicated on [1-TI-62-78]. PLACE [1-HIC-62-78A] in AUTO. RO Note Letdown temperature may swing due to repeated actuation of TIS-62-79B/A on high temperature causing TCV-70-192 to fully open.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 3 of 45 Event

Description:

Charging Pump 1B Trip Time II Position I Applicant's Actions or Behavior IF necessary to stabilize letdown temperature due to oscillations in CCS flow, THEN PERFORM following to gain control of CCS flow through letdown heat exchanger: Open the following breaker:

• Vital Instrument Power Bd 1-111 1-BKRA-250-NG/15-F RO WHEN letdown heat exchanger outlet temperature is stabilized at approximately 100°F, THEN CLOSE following breaker:
• Vital Instrument Power Bd 1-111 1-BKRA-250-NG/15-F (Step Should Be N/A)

Note 1-TCV-62-79 (letdown temperature divert valve) should be in bypass position if the temperature reaches 140°F. IF Mix Bed HI Temperature Bypass valve [1-HS-62-79A] auto bypasses DI on high temperature, THEN ENSURE letdown temperature returns to NORMAL AND RO PLACE demin in service using [1-HS-62-79A]. (Step Should Be N/A) IF PZR level is on program and auto operation is desired, THEN [a] IF [1-HIC-62-93A] deviation meter is off scale high or off scale low THEN PLACE [1-L1C-62-339] in MANUAL AND RO ADJUST output until [1-HIC-62-93A] deviation meter is approximately mid-scale. [b] PLACE [1-L1C-62-339] in AUTO. [e] PLACE [1-HIC-62-93A] in AUTO.

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 3 Event

Description:

Charging Pump 1B Trip Time I Position II Applicant's Actions or Behavior PERFORM Independent Verification for following valve(s) that were OPENED: (N/A one(s) not used). VALVE NO. DESCRIPTION IV INITIALS

                            'I-FCV-132-69           Letdown Isolation RO/BOP            '1-FCV-62-70            Letdown lsotation
                            '1 -FC'V-62-11      letdown Flow Isolation 1-FCV-62-72          letdown Orifice        tsos.

rrcv-62-73 letdo\,vi1 Orifice 11501.

                            'l-FCV-62-14          letdown Orifice l:sot.

Evaluator Note: The following Tech Spec evaluation is not specifically directed by the ARP orSO performed. Evaluate Tech Specs and Technical Requirements Manual for Charging Pump trip.

• Tech Spec LCO 3.5.2 - ECCS Subsystems (72 Hour Action SRO Applies)
• TRM 3.1.2.4 - Charging Pumps - Operating (72 Hour Action applies)

When technical specifications and Tech Requirements have been identified, standby charging pump has been placed in service, and letdown restored, or at Lead Examiner's discretion, proceed to the next event.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 4 Event

Description:

Steam Generator #1 Steam Pressure channel fails low (PT-1-2A) Time II Position I Applicant's Actions or Behavior Booth Instructor: When directed, initiate Event 3 Indications available:

• Loop 2 Feedwater Flow Decreasing
• 1-AR-M5-A-A7, STEAM GEN FEEDWATER FLOW HIGH
• 1-AR-M6-B, A2, LOW STEAM LINE PRESSURE LOOP 1
• 1-AR-M6-B, A3, HIGH NEGATIVE RATE STEAM LINE PRESSURE LOOP 1 Refer to alarm response procedures Crew Direct entry to AOP-S.01, Loss Of Normal Feedwater, Sect 2.1 SRO Steps 1-4 If SRO goes directly to AOP-1.06, then go to next page.

RESTORE steam generator level(s) to program: ( BOP " a. PLACE affected level controller(s) in MANUAL: BOP

• FIC-3-35A, S/G-1

b. CONTROL feedwater flow on affected S/G(s) USING main feedwater regulating valve controller(s) to restore level to BOP program.

2. CHECK Steam Flow and Feed Flow BOP Channels NORMAL. [M-4]

RNO: TRANSFER associated Steam Flow selector switch to alternate channel: BOP LOOP TRANSFER SWITCH FLOW INDICATOR S/G 1 XS-1-3D (FI-1-3A) FI-1-3B

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 4 of 45 Event

Description:

Steam Generator #1 Steam Pressure channel fails low (PT-1-2A) Time Position Applicant's Actions or Behavior Caution: Feed Flow transients may impact core thermal power.

3. MAINTAIN steam generator level(s) on program.

BOP

4. CHECK S/G pressure instruments NORMAL.

BOP GO TO AOP-1.06, Steam Generator Instrument Malfunction. SRO Evaluator Note: SRO may directly enter AOp*1.06 at next step. Direct entry to AOP-1.06, Steam Generator Instrument ( SRO Malfunction, section 2.1 NOTES: Channels I and II compensate their respective steam flow signals which input to the STEAM/FEEDWATER FLOW MISMATCH alarms and S/G Water Level Control. Channels III and IV input to the STEAM GENERATOR LOOPS PRESS LOW alarm. VERIFY unaffected steam flow channel SELECTED:

• S/G-1 , XS-1-3D BOP PERFORM the following:
• PLACE affected level controller(s) in MANUAL:

0 FIC-3-35A, S/G 1 MATCH steam flow and feedwater flow on affected S/G USING main feedwater regulating valve controller(s). BOP

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 4 Event

Description:

Steam Generator #1 Steam Pressure channel fails low (PT-1-2A) Time II Position II Applicant's Actions or Behavior TRANSFER associated Steam Flow selector switch to alternate channel: BOP LOOP TRANSFER SWITCH FLOW INDICATOR S/G 1 XS-1-3D (FI-1-3A) FI-1-3B MAINTAIN steam generator level(s) on program. BOP PLACE main feedwater regulating valve(s) in AUTO. BOP EVALUATE the following Tech Specs for applicability:

• 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation
• 3.3.2.1 (3.3.2), Engineered Safety Feature Actuation System Instrumentation. (Action 17 Applies)

SRO

• 3.3.3.5, Remote Shutdown Instrumentation
• 3.3.3.7, Accident Monitoring Instrumentation.

( (Action 1 Applies) NOTE 1: Megawatt thermal indication on ICS (U1118 and U2118) may be impacted by this failure. NOTE 2: If performing AOP in conjunction with AOP-1.11 for an Eagle LCP failure, then actions to hard trip bistables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours UNLESS affected loop is restored to operable status by resetting Eagle rack. NOTIFY 1M to remove failed S/G pressure instrument from service USING appropriate Appendix: SRO LOOP INSTRUMENT NUMBER PROT CH APPENDIX 1 P-1-2A (P-514) I A GO TO appropriate plant procedure. SRO When Technical Specifications have been addressed, Lead Examiner may cue the next event

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 5 of 45 Event

Description:

Condenser Vacuum Leak Time Position Applicant's Actions or Behavior Booth Instructor: When directed, initiate Event 5 Indications available:

• O-M-12A, C-2, 1-RA-90-119B COND VAC PMP LO RNG AIR EXH MaN INSTR MALFUNC
• 1-AR-M2-C, C6, CONDENSER VACUUM LOW
• Condenser Vacuum degrading (Monitored on recorder or ICS), Air in leakage increasing Refer to alarm response procedure Crew Evaluator Note: Crew may recognize vacuum leak early and enter abnormal procedure AOP-S.02, Loss Of Condenser Vacuum, prior to alarm. If AOP Entered

( Directly go to Next page at NOTE. VERIFY alarm via [1-P/TR-2-2] recorder. BOP VERIFY required number of CCW pumps are in service. BOP CHECK condenser vacuum exhaust on ICS using either:

a. 1F2700A if 1-FCV-2-255 is closed BOP

b. 1F2263A if 1-FCV-2-255 is open.

IF condenser vacuum exhaust flow> 45 CFM, THEN ENSURE 1-FCV-2-255 OPEN. BOP IF alarm is valid, THEN GO TO AOP-S.02, Loss of Condenser Vacuum. SRO NOTE: Use of the highest reading operable condenser pressure instrument is conservative and recommended by engineering. (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 5 of 45 ( Event

Description:

Condenser Vacuum Leak Time Position Applicant's Actions or Behavior MONITOR condenser pressure for turbine trip criteria. BOP

• CHECK turbine load greater than or equal to 30%.

(MT Low Condenser Vacuum Trip @ 3.9 psia increasing) CHECK condenser pressure less than or equal to 2.7 psia. BOP (1-AR-M2-C, C-G, CONDENSER VACUUM LOW @ 2.7 psia increasing.) ENSURE condenser vacuum pumps RUNNING. BOP (Operator starts 1B Condenser Vacuum Pump) ENSURE condenser vacuum breaker CLOSED. BOP CHECK required CCW Pumps RUNNING [M-15]. BOP NOTE: ( ICS points F2700A and F2263A will alarm if Condenser Vacuum Exhaust Flow is ~ 45 cfm. DETERMINE volume of condenser inleakage USING the following plant computer points: BOP

• F2700A
• F2263A
• F2260A

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # Event # 5 Page 19 of 45 Event

Description:

Condenser Vacuum Leak Time Position Applicant's Actions or Behavior VERIFY inleakage value is < 45 cfm as indicated by both F2700A and F2263A. RNO: PERFORM the following: BOP

• ENSURE FCV-2-255, Condenser Vacuum Exhaust Bypass, is OPEN.
• IF greater than 5% RTP, THEN NOTIFY Chem Lab to reevaluate Vent Flow Rate Monitor setpoint in accordance with 0-SI-CEM-030-415.0.

DISPATCH an operator to PERFORM the following:

a. CHEC'K loop seal on vacuum breaker [Turbine Bldg, 706' elev].

( b. CHECK the following components: Crew

• Main Turbine rupture discs intact
• Condenser shell intact
• Main Feedwater Pump rupture discs intact
• Main Turbine exhaust hoods

c. VERIFY Main Steam Dump Drain Tank level control operating properly.

ENSURE control rods controlling in AUTO. RO CHECK condenser pressure STABLE or DROPPING. IF NOT: REDUCE turbine load to maintain condenser vacuum USING one of the following: BOP

• AOP-C.03, Rapid Shutdown or Load Reduction.

(preferred) OR

• Valve Position Limiter.

Power Change not required, On Lead Examiner's cue, proceed to the next event

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 6,7,8 Page 20 of 45 Event

Description:

Main Feedwater Pump A trip, MD AFW pump 1B-B Airbound, Main Feedwater Pump B Speed controller fails to 0%. Time Position Applicant's Actions or Behavior Booth Instructor: When directed, initiate Event 6 (Events 7, and 8 previously activated or automatically initiated) Indications of Main Feed Water Pump A Trip:

• Main feedwater Pump tripped Alarms
• Decreasing Feedwater flow to all Steam generators.
• Turbine and Reactor Runback Indications of MDAFW Pump 1B-B airbound:
• Pump running with proper valve alignment and no indicated AFW flow to loops 3 and 4.
• Low discharge pressure and pump amps.

Indications of Feedwater Pump B Speed control Fails to 0%.

• Main Feedwater Flow rapidly decreasing
• Main feedwater pump B speed rapidly decreasing

( Announce MFP trip and Monitor Turbine/Reactor runback, S/G Crew levels and Running Main Feed water pump response. Evaluator Note: Crew may only complete a small portion of AOP-S.01, if any, prior to second MFP Speed Control failure (3 min after MFP A trip) resulting in reactor trip. Also, crew may elect to trip the reactor as a conservative action during runback since TDAFW pump is not available and if they note the condenser vacuum spike during runback due to main steam entering from steam dump. If Rx Tripped crew will not enter AOP-S.01. SRO Direct Entry into AOP-S.01 , section 2.3. VERIFY turbine runback BOP to less than 72 % load (-880 Mwe).

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 6,7,8 of 45 Event

Description:

Main Feedwater Pump A trip, MD AFW pump 1B-B Airbound, Main Feedwater Pump B Speed controller fails to 0%. Time Position Applicant's Actions or Behavior VERIFY control rods inserting automatically to match T-avg and T-ref. RO ENSURE running main feedwater pump FULLY LOADED: Speed controller output at maximum. BOP [M-3, SIC-46-20A or SIC-46-20B] Evaluator Note: Crew should identify Airbound AFW Pump prior to or during performance of the following step. When identified, crew may stop the pump or dispatch personnel to check the pump locally prior to stopping it. Following field report on pump status, crew should also initiate venting of the pump casing. ENSURE AFW pumps started: ( a. MDAFW Pumps RUNNING. [M-4]

b. TDAFW Pump RUNNING. [M-3]

BOP c. TDAFW Pump LCVs OPEN. [M-3]

d. MDAFW Pump recirculation valves CLOSED: [M-4]

• FCV-3-400
• FCV-3-401 Evaluator Note: Second Main Feedwater Pump speed control failure will likely occur prior to or around this step.

Recognize main feedwater flow decreasing and attempt RO manual speed control Direct /Ensure Reactor trip based on decreasing S/G levels. SRO Reactor trip terminates this series of events.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # Event # 9 & 10 Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time II Position I Applicant's Actions or Behavior Booth Instructor: Remaining Events Automatically initiated. Indications available: 1A shutdown board differential Fault (5 minutes after Rx Trip)

• Loss of Train A Equipment including:

o Last Aux Feedwater Pump 1A. o Last Charging Pump 1A.

• Emergency DIG Start (Cooling water not available)
• Multiple alarms 1B safety Injection Pump auto start failure (When 51 actuated in FR-H.1)
• Green Light on Handswitch
• No Pump flow or amps Directs transition to E-O, Reactor Trip or Safety Injection SRO VERIFY reactor TRIPPED:
• Reactor trip breakers OPEN
• Reactor trip bypass breakers DISCONNECTED or OPEN RO
• Neutron flux DROPPING
• Rod bottom lights LIT
• Rod position indicators less than or equal to 12 steps.

VERI FY turbine TRI PPED: BOP

• Turbine stop valves CLOSED.

VERIFY at least one train of shutdown boards ENERGIZED. BOP EVALUATOR Note: 51 not required at this point crew will transition to ES-O.1 in the next step and continue until FR-H.1 is required following SO Board Differential ( fault. The exact Transition is crew dependent therefore steps may be included that are not performed in ES-O.1.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 ( Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time I Position II Applicant's Actions or Behavior DETERMINE if SI actuated:

• ECCS pumps RUNNING.
• Any SI alarm LIT [M-4D]

(RNO) DETERMINE if SI Required:

a. IF any of the following conditions exist:

• S/G Pressure less than 600 psig OR RO
• RCS pressure less than 1870 psig, OR
• Containment pressure greater than 1.5 psig THEN ACTUATE SI (NOT~SINOTREQWRE~

b. IF SI not required THEN PERFORM the following:

(

• MONITOR Status Trees GO TO ES-0.1, Reactor Trip Response EVALUATOR Note: During performance of ES-0.1, at some point Shutdown board 1A will be lost. Crew should note that the 1A DIG has no cooling water and emergency stop it. If not addressed by crew early, if will be addressed in AOP-P.05 as discussed below.

Crew may designate one of the ROs (most likely the BOP) to perform AOP-P .05 for Loss of Shutdown Board when it occurs. Details of AOP-P .05 are at the end of this event guide just prior to event guide for ES-0.5. Enter and direct ES-0.1, Reactor Trip Response SRO MONITOR SI NOT actuated: RO

• SI ACTUATED permissive DARK [M-4A, D4]

VERIFY generator breakers OPEN. BOP (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # ( Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time II Position II Applicant's Actions or Behavior MONITOR RCS temperatures: IF any RCP running, THEN RO CHECK T-avg stable at or trending to between 54rF and 552°F. (RNa Next Page If Required) (RNa If Required) IF temperature less than 547~F and dropping. THEN PERFORM the following:

a. ENSURE steam durnps and atmospheric reliefs CLOSeO.

b. ENSURE S/G blQwdowniSolation

( valves CLOSeO.

c. IF cooldown contin,ues, THEN PERFORM thefolowlng:

1) CONTROL total feed flow USING; &\..3-8, Manual Cmtro1 of BOP AFWFlow.

2) MAINTAIN total feed flow greater than 440 gpm UNTIL narrow range level greaterthan 10%

in at IHst one SlG,

3) DEPR.ESS RESET on MSR control panel"

4) IF any MSR temp contrOl valve fails to dose.

THEN ISOLATE HP steam to MSRs.

d. IF cooktovJn still continues, THEN

{ CLOSE MSIVs and bypass valves.

\

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 ( Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time II Position I Applicant's Actions or Behavior MON,rORfeedwater status:

a. T~a\fg Ie:ssthan650°F,

b. MFWreglJlatlng valves CLOSED.

c, MFW Tegwlating bypass valve controller outputs ZERO. BOP d, MFW isolatio'!'l valves CLOSED. e, MFW pumps TRIPPED. f, MFW ftow ZERO.

g. Tofm feed now to S/Gs greater than 440 gpm.

( CHECK if emergency boratJon is required:

a. VERIFY all control rods fully inserted:

                                           .. Rod bottom lights LIT

• Rod position indicators lessthan or equaJ to 12 steps.

b. MONITOR RGS temperature:

RO

• T~avg greater than 5400F if any Rep runnl\ng OR
• T",cojd greater than ~F If all Reps stopped.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 ( Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time II Position II Applicant's Actions or Behavior ANNOUNCE reactor trip BOP USING PA system., MONITOR pressurIzer level control:

a. CHECK pressurizer level greaterthan 17%,

RO b. VERIFY charging IN SERVICE,

c. VERIFY letdown IN SERVICE,

d. CHECK pressunzerl&vel trending to 25%

(normal range 20% to 30%). MONITOR pressurizer pressure control: a, PRiissurizer pressure ( gfeaterfhan 1870 psig. RO

b. Pressurizer pressure stable at or trending to 2235 psig (normal range 2210 psig to 2260 psig).

MAINTA&N SlG narrow range levels: BOP a. Greater than 10%. VERIFY AC busses ENERGIZED BOP from start busses. CAUTION Annlng steam dumps in pressure mode with demand signal presen.t could result in rapid R.CS cooldown.

I Appendix 0 Required Operator Actions Form ES-0-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 Page 27 of 45

                                                                                                        ---';'----ii Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time II Position II Applicant's Actions or Behavior DETERMJNE if steam dump to condenser available: a, CHECK condenser AVAILABLE:

• c-s CONDENSER INTERLOCK permlulve UT [M-4A. E6]

                                          ,. At leastone IntactSlG MSIV OPEN,

b. PLACE strtam dumps in STEAM PRESS mode:

BOP

1) PLACE steam dumps in OFF.

                                          .2) ENSURE steam dumps in steam pressure mode.

3) ENSURE zero output(demand).

4) PLACE steam dumps In ON,

5) ADJUST steam dump controller setpoint to 84% (1005 psig) in AUTO, Evaluator Note: It is assumed that transition to FR-H.1 will occur prior to or at this step. Transition should be based on Red Status tree path when the last AFW pump is lost due to the loss of the shutdown board.

Enter and direct actions of FR-H.1, loss of Secondary Heat SRO Sink. CAUTION Feeding an Intact or Ruptured S/G is preferred to feeding a Faulted SIG. Thermal stresses from feeding a Faulted SIG could rupture tubes, resulting i'n a Fautted-AND-Ruptured S/G. (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, Sl Pump 1B auto start failure. Time Position Applicant's Actions or Behavior DETERMlNE procedure appIkability:

a. CHECK the following:

• Total feed flawless than 440 gpm due to operator action BOP directed by another procedure.

AND

• Total feed flow capabiliity of greater than 440 gpm AVAilABLE.

MONITOR RWST ~evel ( RO greater than 27%. CHECK if secondary heat sink. required:

8. RGS pressure greater than any BOP non-Faulted SIG pressure.

D. RCS temperature greater than 3.50Q F . MON'ITOR at least one CCP available. (RNO Required since Last CCP was lost with the SD Board RO Differential Fault.) (RNO) RO STOP ail RCPs. Evaluator note: This should be done prior to openinq PORV's (RNO) SRO GO TO Caution prior to Step 1EL

I Appendix D Required Operator Actions Form E8-D-2 I Op Test No.: NRC Scenario # Event # 9 & 10 ( Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time Position Applicant's Actions or Behavior CAUTION Any delay in completing Steps 16 through 19 could result in fuel damage. ACTUATESL RO Evaluator Note: Crew should identify and start 51 Pump 1B that failed to auto start from 51 signal prior to or during this step. CRITICAL VERIFY RCSfeed path: Task 1 - Part 1 R CHECK ECGS pump status:

• At least one GGP RO R.UNNING OR

                                           .,   At least one SI pump RUNNING.

Critical Task "Prior to 10% Wide Range S/G level" (RNO required if 81 Pump not previously started) START pumps. IF NO GCP or SI pump can be started, RO THEN PERFORM the following: (Rest of step N/A 81 pump should be started) (

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 Page 30 of 45 ( Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time Position Applicant's Actions or Behavior VERIFY EGGS valve alignment for ftJl1mng pumps:

1) CCP suction ali!gned to RWST:

• LCV-62-'135 or LCV 136 OPEN
• LC\I-62-132 Of LCV-62-133 CLOSED

2) CCPIT valves OPEN:

• FC\I-63-25 or FGV-63-2B RO
• FCV-63--39 or FGV-63-40 3} Sl Pump suction valves OPEN:
• FCV-63-5

(

• FCV-63-47 (Train A)
• FCV-63-48 {Train B}

4) SI Pump injection valves OPEN:

• FCV-63-22
• FCV-63--152 (Train A)
• FCV-63-153 (Train B)

CRITICAL ESTABLISH RCS bleed path: Task 1 - Part 2 a. CHECK power to pressurizer POHV block valves AVAILABLE

b. CHECK pressurizer PORV block RO valves OPEN.

c. OPEN both pressurizer PORVs.

(Power will be available to only one block valve but it should be open) Critical Task "Prior to 10% Wide Ranae S/G level"

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 of 45 ( Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time Position Applicant's Actions or Behavior CHECK Res bleed path ADEQUATE:

• Both Pressurizer PORVs OPEN RO
• Both Pressurizer PORV block valves OPEN.

Evaluator Note: SRO should direct ROs to perform substeps of the following step. PERFORM the following WHILE continuing with this procedure:

a. E-O, Reactor Trip or Safety Injection, SRO Steps 1 through 4.

b. ES-O.5, Equipment Verifications.

( (ES-O.5 Included at the end of the Event Guides) MAINTAIN RCS heat removal: RO- ECGS flow

• Pressurizer PORVs OPEN.

RESET SI signaL RO RESET Phase A and Phase R RO MONnOR control air to containl'Ilient (Pane! oK and 6L]

• 1-FCV-32-80 (2-FCV~32-81)

Train A essential air OPEN RO

                                    -    1-FCV-32-102 (2-FCV-32-103)

Train 8 essenaat aif OPEN FCV-:32-110 (2-FGV-32-111) Non-essential air OPEN

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # Event # 9 & 10 Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time Position Applicant's Actions or Behavior MONITOR if containment spray required:

a. CHECK the following:

• Phase B ACTUATED OR
• Conulinment pressure greater than 2.13 psig.

(If NO, proceed to step to check RHR status) (If YES, Continue)

b. ENSURE containment spray INITIATED:

RO ( 1J Containment spray p!umps RUNNING.

2) Containment spray header isolation valves FCY-72-39 and FC\I-72-2 OPEN.

3) Containment spray rea:rculation valves to RWST FGV-72-34 and FCY-72-13 CLOSED.

4} Containment spray header fto\"\I' greater than 4750 gpm per train.

c. WHEN to minutes have elapsed THEN BOP VERIFY containment eur return fans RUNNING.

(

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 of 45 Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, Sl Pump 1B auto start failure. Time Position Applicant's Actions or Behavior CAUTION Operation of RHR pumps for greater than 100 minutes with miniflow valves open and NO CCS flow to RHR heat exchangers could result in pump damage. CHECK RHR status: RO a. CHECK RHR pumps RUNNING BOP D. CHECK ccs ALIGNED to RHR heat exchangers. MONITOR if containment spray should be stopped:

d. CHECK any containment spray pump RUNNING_

D_ CHECK containment pressure less than 2.0 psig. ( (If NO, Proceed to Monitor Containment Vacuum Control) (If YES, Continue) RO C. CHECK containment spray suction aligned to RWST

d. RESET containment spray.

e. STOP containment spray pumps and PLACE m A-AUTO.

f. CLOSE containment spray discharge valves:

• FCV-72-39, Train A
• FCV-72-2, Train R

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time II Position II Applicant's Actions or Behavior MONITOR if containment vacuum control should be returned to normal:

a. CHECK containment pressure less than -1 .0 psj'g..

RO b. VERIFY conta:inment vacuum relief isolation valves OPEN: [paneI6K]

• FCV-30-46 OPEN
• FCV-30-47 OPEN
• FCV-30-48 OPEN_

CRITICAL ATIEMPT to establish AFW flow to Task 2- at least one SIG in the following order of ( Option 1 pliority-- Intact, Ruptured, Faulted:

a. CHECK SIG blowdown isolanon valves CLOSED_

b. CHECK control room indications for BOP cause of APiV failure:

• CST level
• AFW pump power supply
• AFW valve alignment (Step Continued next page)

Critical Task:"Prior to exiting FR-H.1". Evaluator Note: If not previously performed crew may initiate venting of AFW pump at this point.

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time II Position II Aoolicant's Actions or Behavior

c. ESTABLISH MD APW pump flow:

1) ENSURE MD AFWpumps RUNNING.

2} ENSURE AFVV level contmj valves OPEN. BOP

3) ENSURE MD AFW recirculation valves FCV-3-400 and FG\l-3-401 CLOSED.

O. ESTABUSH TO AFW pump flow: (TDAFW Flow not available due to tacout)

e. MONITOR AFVVflow available to at least one SlG.

( BOP (If Yes, Proceed to step to control Control Feed Flow) (If NO. Continue) Evaluator Note: If AFW flow established by venting AFW pump, crew will go to the last step in this event guide to Control Feed Flow to S/G. Steps beginning on the next page will not be required.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 of 45 Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time II Position I Applicant's Actions or Behavior NOTE Containment pressure greater tnant.S psig will prevent opening RN isolation valves until 51 signal is blocked using EA-9!J*i, Blocking Auto Sl Signals. CRITICAL A.TTEMPT to establish feed flow TasK 2- from condensate system: Option 2 a. NOTIFY MliG to perform EA-99-'l, Blocking Auto SI signals.

b. CHECK condensate system IN SERVICE:

BOP

• Hotwell pumps
• Condensate booster pumps c.BlOCK S~ signals:
• Low pressurizer pressure SI

(

• Low stearruine pressure SI.

Critical Task:Prior to exiting FR-H. 1".

d. CHECK the following indications:

• PRESSURIZER SI TRAINS A & B BLOCKED permissive UT

[M-4A, 84] BOP

• STEAr",1l1NE PRESS ISOllSI BLOCK RATE ISOL ENABLE permissive LIT [M-4A, A4].

RO e. CHECK Containment pressure less than 1.5 psig. BOP (If NO, Skip next step until auto SI signals Blocked) (

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time Position Applicant's Actions or Behavior

f. CHECK FV'V isolation valves OPEN.

(RNO if Required) PERFORM the foUowing:

                                    'l} ENSURE MFW reg valve controllers in MANUAL and output ZERO.

2) ENSURE MFW bypass reg va~ve controllers In MANUAL and output BOP/RO ZERO.

3) RESET SI signal.

4) CYCLE reador trip breakers.

5) RESET F'V'-/lsolation.

6) OPEN FWisolation valves for intact S/Gs.

g. AUGN condensate flow path to S/Gs USING EA-2-2, Establishing BOP Secondary Heat Sink Using Main Feedwaier or Condensate System.

h. CHECK Condensate flowpath established:

                                         .. At least one Feedwater Isolation BOP Valve OPEN
                                         .. Condensate flowpath to SiG aligned.

(

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 1 Event # 9 & 10 of 45 Event

Description:

Loss of Heat Sink Feed/Bleed - 1A shutdown Board differential Fault, SI Pump 1B auto start failure. Time II Position II Applicant's Actions or Behavior L DEPRESSURIZE one SIG USING SIG atmospheric relief val've UNTil condensate flow established:

1) ENSURE ail MS'(Vand MSIV bypass valves CLOSED.

BOP

2) DUMP steam from one Intact SIG at maximum rate USING SfG atmospheric relief valve.

J. CONTINUE depressurization UNTil condensate flow' established.

k. WHEN condensate fi,ow established, THEN PERFORM the following:

BOP 1:) STOP SIG depressurization.

2) CONTROL pressure III selected S/G as necessary to maintain condensate flow.

CONTROL feed flow to SfG:

a. CHECK Core Exit TCs STABLE or DROPPING.

b. CHECK wide range level BOP on selected SfG greater than 10iC!,~ [30% ADY]

c. CONTROL S/G feed flow as necessary to restore narrow range level 111 selected SfG between 10% [25% ADV] and 50%~.

Scenario may be terminated when crew has established feedwater flow from either AFW or Condensate.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Event # AOP-P.05 Page 39 of 45 1 ( Event

Description:

Equipment Verifications I Time II Position II Applicant's Actions or Behavior I AOP-P.05 Actions Evaluator Note: Operator may discontinue early to assist with loss of heat sink BOP Enter and perform AOP-P.05 Section 2. 1 Reader-Doer. NOTE: Indicating lights for the turbin:e throttle, governor, intercept & reheat-stop valves are de-energized. MONITOR 1B-B 6900V Shutdown Board BOP ENERGIZED. CAUTION 1:: Restoring seal cooling to an overheated Rep seal could result in ( RCP seal damage or steam vo-iding in CCS.. CAUTION 2: Operati:on of Reps for greater than 2 minutes without CCS cooling to oil coolers will result in bearing temperatures greater than 200°F. CHECK RCP sea! cooling available:

                                       ,. seal injection flow BOP OR

• therrna! barrier coo~ing flow CAUTION: CCP and SI Pumps may experience bearing failure 10 minutes after loss of ERCW cool:ing.

ENSURE tHO Train A ERCW Pumps IN SERVICE: BOP

• K-A ERGW Pump

                                      .. R-A ERCW Pump

( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # AOP-P.05 Page 40 of 45 Event

Description:

Equipment Verifications I Time II Position II Applicant's Actions or Behavior I ENSURE Diesel Generators RUNNING and ERC\tV ALIGNED to all DIGs. BOP (RNO if not previously performed) EMERGENCY STOP any DIG with NO ERCW cooling available. ENSURE 18-B CCS Pump BOP supplying Train A ccs. MONITOR REACTOR COOlANT PUMPS BOP MOTOR THRUST BEARING TEMP HIGH alarm DARK [1i-M-SB, E-3l CHECK ERCW supply header pressure NORMAL: BOP

• 1(2}-PI-67-493, between BO psig and 120 pSJ:g CHECK dlarging IN SERVICE:

BOP

a. CHECK 18-B CCP RUNNING.

If Reactor is critical, THEN BOP EVALUATE CLOSING TDAF\fV LCV'S to prevent ReS cooldQwn BOP CHECK letdown IN SERVICE. PERFORM Appendix AA, Potential Tech BOP Spec Impacts.. (May be performed later) NOTE 1 1-M-l Instrument Rack A is normally powered from 4BOV Shutdown Bd 1A1-A. Power loss results in loss of varrous rad monitors, boric add flow indication, and other MeR indications and controls. NOTE 2: Restoration of power to Instrument Rack A may cause leV-&-1 06B to open, resulting In condensate system fjow changes. Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # AOP-P.05 Page 41 of 45 ( Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior RESTORE power to 1-Mq Instrument Rack A by pla£ing Instrument Rack A Transfer Svvitch to ALTERNATE position. [1-~tJ1-7, middle switch] Evaluator Note: remainder of procedure will most likely not be complete due to Loss of Heat sink and is therefore not included .. ( ( Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 42 of 45 ( Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior ES-O.5 Actions CHECK ERCW system operation: BOP

• VERIFY at least four ERCW pumps RUNNING.
• VERIFY DIG ERCW supply valves OPEN.

VERIFY CCS pumps RUNNING:

• Pump 1A-A (2A-A)

BOP

• Pump 1B-B (2B-B)
• Pump C-S.

VERIFY EGTS fans RUNNING. BOP VERIFY generator breakers OPEN. ( BOP VERIFY AFW pumps RUNNING: BOP

• MD AFW pumps
• TD AFW pump.

Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 43 of 45 Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control S/G levels, to establish flow due to failure, or to isolate a faulted S/G. CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

b. VERIFY TD AFW LCVs OPEN.

BOP

c. VERIFY MD AFW pump recirculation valves FCV-3-400 and FCV-3-401 CLOSED.

VERIFY MFW Isolation:

• MFW pumps TRIPPED
• MFW regulating valves CLOSED BOP
• MFW regulating bypass valve controller outputs ZERO
• MFW isolation valves CLOSED

(

• MFW flow ZERO.

MONITOR ECCS operation: VERIFY ECCS pumps RUNNING: BOP

• CCPs
• RHR pumps
• SI pumps Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 44 of 45 Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior VERIFY CCP flow through CCPIT.

• CHECK RCS pressure less than 1500 psig.

BOP

• VERIFY SI pump flow.
• CHECK RCS pressure less than 300 psig.
• VERIFY RHR pump flow.

VERIFY ESF systems ALIGNED:

• Phase A ACTUATED:

0 CONTAINMENT ISOLATION PHASE A TRAIN A alarm LIT [M-6C, B5]. 0 CONTAINMENT ISOLATION PHASE A TRAIN B alarm LIT [M-6C, B6].

• Containment Ventilation Isolation ACTUATED:

0 CONTAINMENT VENTILATION ISOLATION TRAIN A alarm LIT [M-6C, C5]. ( 0 CONTAI NMENT VENTI LATION ISOLATION TRAIN B alarm LIT [M-6C, C6]. BOP

• Status monitor panels:

0 6C DARK 0 6D DARK 0 6E LIT OUTSIDE outlined area 0 6H DARK 0 6J LIT.

• Train A status panel 6K:

0 CNTMT VENT GREEN 0 PHASE A GREEN

• Train B status panel 6L:

0 CNTMT VENT GREEN 0 PHASE A GREEN Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 45 of 45 Event

Description:

Equipment Verifications Time It Position II Applicant's Actions or Behavior MONITOR containment spray NOT required:

• Phase B NOT ACTUATED AND BOP
• Containment pressure less than 2.81 psig
• Ensure Containment Spray is actuated VERIFY pocket sump pumps STOPPED: [M-15, upper left corner]
• HS-77-410, Rx Bldg Aux Floor and Equipment Drain BOP Sump pump A
• HS-77-411, Rx Bldg Aux Floor and Equipment Drain Sump pump B.

DISPATCH personnel to perform EA-0-1, Equipment Checks Following ESF Actuation. BOP ( Appendix D NUREG 1021 Revision 9

SHIFT TURNOVER CHECKLIST Page 1 of 3 Today D SM D US/MCR Unit 1 D UO Unit 1 Off-going - Name D AUO Station SQN D STA (STA Function) AUO Comp Actions On-coming - Name Part 1 - Completed by Off-going Shift/Reviewed by On-coming Shift: Abnormal Eauioment Lineuo/Conditions: tI'Jf,JEfJ ~~f}J;(EII~1£ 1I~~tI'~o~~~ '~~;&-~~~f1~ , TrainA Week

• All Equipment normal

(

• TDAFW pump was tagged 2 hours ago for repair to the T&T valve. The packing was blowing excessively. Expected Return to service is 8 hours. (WO 07-080025-000 Total 0.03 gpm I Identified 0.02gpm I Unidentified 0.01 gpm. (Today 0600)

SHIFT TURNOVER CHECKLIST Page 2 of 3 Today SI/Test in Progress/Planned: (Including Need for New Brief) Daily and Shiftly Sis per work schedule Major Activities/Procedures in Progress/Planned:

• Reduce to <93% turbine power for Turbine Valve Testing. Initiate boration and rod insertion per Rx Engineering Spreadsheet. Spreadsheet has been verified by the SRO/STA. 0-SO-62-7 Appendix E and D have been performed.

Radiological Changes in Plant During Shift: None TS LCO 3.7.1.2.a: TDAFW pump was tagged 2 hours ago for repair to the T& T valve. The packing was blowing excessively. Expected Return to service is 8 hours. TS 3.3.3. 7.18b action 1; Accident Monitoring Instrumentation, ERCW to AFW Valve Position, Turbine Driven Pump. Part 2 - Performed by on-coming shift o Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's) ( o Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shift Turnover: o Standing Orders 0 LCO(s) in Actions (N/A for AUOs) o Immediate Required Reading 0 TACF (N/A for AUO's) Part 3 - Performed by both off-going and on-coming shift o Walkdown of MCR Control Boards (N/A for AUO's) Relief Time: Relief Date: today TVA 40741 [03-2001] OPDP-1-1 [03-14-2001 (

SHIFT TURNOVER CHECKLIST Page 3 of 3 Today Disabled Annunciators PANEL WINDOW ANNUNCIATOR WO I PER Number Equipment Off-Normal (Pink Tags) UNID And Noun Name Panel Problem Description WO I PER Number MCRWO List ID And Noun Name Panel Problem Description WOlPER Number ( (

UNIT ONE REACTIVITY BRIEF Date: Today Time: Now ( RCS Boron: 1093 ppm Today I BA Controller Setpoint: 27%

• I RCS B-10 Depletion: 2 ppm Operable BAT: A I BAT A Boron: 6850 ppm I BAT C Boron: 6850 ppm I RWST Boron: 2601 ppm Nominal Gallons per rod step from 219: 7 gallons of acid, 36 gallons of water
• Verify boric acid flow controller IS set at Adjusted SA Controller Setting law 0-SO-62-7 section 5.1 Gallons of acid: 26 Gallons of water: 138 Rod Steps: 4 Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 198 Steps on bank D 101 gallons 30% 174 Steps on bank D 295 gallons 50% 152 Steps on bank D 485 gallons

    ** These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until one week from now.

Number of dilutions: 0*** Number of borations: a Rod steps in: a Gallons per dilution: a Gallons per boration: a Rod steps out: a Total amount diluted: a Total amount borated: a Net change: a IN/Out Number of dilutions: a Number of borations: a Rod steps in: a Gallons per dilution: a Gallons per boration: a Rod steps out: a Total expected dilution: a Total expected boration: a Net change: a In/Out Remarks: Rx Power - 100% MWD/MTU - 1000 Xenon & Samarium at Equilibrium

                   ***The boron letdown curve is flat for the next 25 EFPD.

Next Unit 1 Flux Map is scheduled - three weeks from now Unit Supervisor: Name/Date

Operations Chemistry Information Sample Point Units Boron Date / Time Goal Limit U1 RCS ppm 1093 Today / Now Variable Variable U2 RCS ppm 816 Today / Now Variable Variable U1 RWST ppm 2601 Today / Now 2550 - 2650 2500 - 2700 U2 RWST ppm 2569 Today / Now 2550 - 2650 2500 - 2700 BAT A ppm 6850 Today / Now Variable Variable BATB ppm 6850 Today / Now Variable Variable BATC ppm 6850 Today / Now Variable Variable U1 CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 U1 CLA #2 ppm 2575 Today / Now 2470-2630 2400-2700 U1 CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700 U1 CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA#1 ppm 2531 Today / Now 2470-2630 2400-2700 U2 CLA#2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA#3 ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA#4 ppm 2526 Today / Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today / Now ~2050 ~2000 ( 2.18-2.48 2.33 Indicator Units U1 Date / Time U2 Date/Time SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now SI 137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent cpm 380 Today / Now 68 Today / Now 30 gpd leak equivalent cpm 1980 Today / Now 83 Today / Now 50 gpd leak equivalent cpm 3250 Today / Now 206 Today / Now 75 gpd leak equivalent cpm 4850 Today / Now 455 Today / Now 150 gpd leak equivalent cpm 9750 Today / Now 870 Today / Now CVE Air Inleakage cfm 10 Today / Now 12.5 Today / Now Bkgd on 99/119 cfm 50 Today / Now 40 Today / Now (

unit 1 DELTA REACTOR POWER ASSUMED INSERTED EXPECTED DELTA RHO BORON DELTA RECOMMEND RECOMMEND IODINE TIME POWER DEFECT ROD HT WORTH XENON BORON CONC PPM DILUTION BORATION CONC (hrs) (% ) (pcm) (steps) (pcm) (pcm) (pcm) (ppm) (ppm) (gal) (gal) (% eq) 0.0 100.0 1732.0 216.0 -24.5 -2728.0 1093.0 100.0 1.0 93.0 1608.0 204.0 -83.7 -2742.5 -50.4 1100.8 7.8 a 87 99.7 2.0 93.0 1604.5 204.0 -83.7 -2764.3 18.4 1098.0 -2.9 168 a 99.0 3.0 100.0 1729.6 216.0 -24.5 -2762.9 64.4 1087.9 -10.0 594 a 98.8 4.0 100.0 1734.4 216.0 -24.5 -2747.7 -10.4 1089.6 1.6 a 18 98.9 5.0 100.0 1733.7 216.0 -24.5 -2736.8 -11.7 1091. 4 1.8 a 20 99.0 6.0 100.0 1732.8 216.0 -24.5 -2729.0 -8.6 1092.7 1.3 a 15 99.1 7.0 100.0 1732.2 216.0 -24.5 -2723.7 -6.0 1093.7 0.9 a 10 99.2 8.0 100.0 1731.7 216.0 -24.5 -2720.1 -4.1 1094.3 0.6 a 7 99.3 9.0 100.0 1731.4 216.0 -24.5 -2717.8 -2.6 1094.7 0.4 a 4 99.3 10.0 100.0 1731.2 216.0 -24.5 -2716.4 -1. 5 1094.9 0.2 a 3 99.4

11. 0 100.0 1731.1 216.0 -24.5 -2715.7 -0.8 1095.1 0.1 a 1 99.5 12.0 100.0 1731.0 216.0 -24.5 -2715.6 -0.2 1095.1 0.0 a a 99.5 13.0 100.0 1731.0 216.0 -24.5 -2715.7 0.1 1095.1 0.0 1 a 99.6 14.0 100.0 1731.0 216.0 -24.5 -2716.1 0.4 1095.0 -0.1 4 a 99.6 15.0 100.0 1731.1 216.0 -24.5 -2716.7 0.6 1094.9 -0.1 5 a 99.6 16.0 100.0 1731.1 216.0 -24.5 -2717.3 0.7 1094.8 -0.1 6 a 99.7 17.0 100.0 1731.2 216.0 -24.5 -2718.0 0.7 1094.7 -0.1 7 a 99.7 18.0 100.0 1731.2 216.0 -24.5 -2718.7 0.8 1094.6 -0.1 7 a 99.7 19.0 100.0 1731.3 216.0 -24.5 -2719.4 0.8 1094.5 -0.1 7 a 99.8 20.0 100.0 1731.3 216.0 -24.5 -2720.1 0.7 1094.3 -0.1 7 a 99.8

21. 0 100.0 1731. 4 216.0 -24.5 -2720.7 0.7 1094.2 -0.1 6 a 99.8 22.0 100.0 1731.4 216.0 -24.5 -2721.4 0.7 1094.1 -0.1 6 a 99.8 23.0 100.0 1731.5 216.0 -24.5 -2721.9 0.6 1094.0 -0.1 6 a 99.8 24.0 100.0 1731.5 216.0 -24.5 -2722.5 0.6 1093.9 -0.1 5 a 99.9 25.0 100.0 1731. 6 216.0 -24.5 -2723.0 0.5 1093.8 -0.1 5 a 99.9 26.0 100.0 1731.6 216.0 -24.5 -2723.4 0.5 1093.8 -0.1 5 a 99.9 27.0 100.0 1731.6 216.0 -24.5 -2723.9 0.5 1093.7 -0.1 4 a 99.9 28.0 100.0 1731.7 216.0 -24.5 -2724.2 0.4 1093.6 -0.1 4 a 99.9 29.0 100.0 1731.7 216.0 -24.5 -2724.6 0.4 1093.6 -0.1 4 a 99.9 30.0 100.0 1731.7 216.0 -24.5 -2724.9 0.4 1093.5 -0.1 3 a 99.9

31. 0 100.0 1731. 8 216.0 -24.5 -2725.2 0.3 1093.5 0.0 3 a 99.9 32.0 100.0 1731.8 216.0 -24.5 -2725.5 0.3 1093.4 0.0 3 a 99.9 33.0 100.0 1731.8 216.0 -24.5 -2725.7 0.3 1093.4 0.0 2 a 99.9

        .-                                            ............."c.,                                      f .... -......,

Unit 1 34.0 100.0 1731.8 216.0 -24.5 -2725.9 0.2 1093.3 0.0 2 0 99.9 35.0 100.0 1731.9 216.0 -24.5 -2726.1 0.2 1093.3 0.0 2 0 100.0 36.0 100.0 1731.9 216.0 -24.5 -2726.3 0.2 1093.3 0.0 2 0 100.0 37.0 100.0 1731.9 216.0 -24.5 -2726.5 0.2 1093.3 0.0 2 0 100.0 38.0 100.0 1731.9 216.0 -24.5 -2726.6 0.2 1093.2 0.0 1 0 100.0 39.0 100.0 1731.9 216.0 -24.5 -2726.8 0.1 1093.2 0.0 1 0 100.0 40.0 100.0 1731.9 216.0 -24.5 -2726.9 0.1 1093.2 0.0 1 0 100.0

41. 0 100.0 1731.9 216.0 -24.5 -2727.0 0.1 1093.2 0.0 1 0 100.0 42.0 100.0 1731.9 216.0 -24.5 -2727.1 .0.1 1093.2 0.0 1 0 100.0 43.0 100.0 1731.9 216.0 -24.5 -2727.2 0.1 1093.1 0.0 1 0 100.0 44.0 100.0 1732.0 216.0 -24.5 -2727.3 0.1 1093.1 0.0 1 0 100.0 45.0 100.0 1732.0 216.0 -24.5 -2727.3 0.1 1093.1 0.0 1 0 100.0 46.0 100.0 1732.0 216.0 -24.5 -2727.4 0.1 1093.1 0.0 1 0 100.0 47.0 100.0 1732.0 216.0 -24.5 -2727.5 0.1 1093.1 0.0 1 0 100.0 48.0 100.0 1732.0 216.0 -24.5 -2727.5 0.1 1093.1 0.0 1 0 100.0 49.0 100.0 1732.0 216.0 -24.5 -2727.6 0.1 1093.1 0.0 0 0 100.0 50.0 100.0 1732.0 2 6.0 -24.5 -2727.6 0.0 1093.1 0.0 0 0 100.0

51. 0 100.0 1732.0 216.0 -24.5 -2727.6 0.0 1093.1 0.0 0 0 100.0 52.0 100.0 1732.0 216.0 -24.5 -2727.7 0.0 1093.1 0.0 0 0 100.0 53.0 100.0 1732.0 216.0 -24.5 -2727.7 0.0 1093.0 0.0 0 0 100.0 54.0 100.0 1732.0 216.0 -24.5 -2727.7 0.0 1093.0 0.0 0 0 100.0 55.0 100.0 1732.0 216.0 -24.5 -2727.8 0.0 1093.0 0.0 0 0 100.0 56.0 100.0 1732.0 216.0 -24.5 -2727.8 0.0 1093.0 0.0 0 0 100.0 57.0 100.0 1732.0 216.0 -24.5 -2727.8 0.0 1093.0 0.0 0 0 100.0 58.0 100.0 1732.0 216.0 -24.5 -2727.8 0.0 1093.0 0.0 0 0 100.0 59.0 100.0 1732.0 216.0 -24.5 -2727.8 0.0 1093.0 0.0 0 0 100.0 60.0 100.0 1732.0 216.0 -24.5 -2727.9 0.0 1093.0 0.0 0 0 100.0 Total 884 166

~MWD/MTU Hold Tavg = Tref +/- 1. SF Small hourly boration/dilution 6820 BAT ppm volumes may be accumulated for larger single additions Reason for Downpower Unit 1 TV test Date RxENG Name Beeper 70808 Comments

SQN 0-SO-62-7 1,2 BORON CONCENTRATION CONTROL Rev. 46 Page 161 of 199 APPENDIX 0 Page 1 of 1 CALCULATION FOR AMOUNT OF BORIC ACID OR PRIMARY WATER (TI-44) NOTE 1 One calculation is required for each major change. NOTE 2 Boric acid amounts to achieve required RCS boron concentration may be significantly higher than calculated amounts if CVCS demin resins are removing boron. Amount of boron removal by mixed bed resins will depend on RCS boron, resin age, whether demin bed was previously borated, and letdown temperature. Chemistry should be consulted if required to evaluate resin bed removal. [1] IF REACTF not used, THEN CALCULATE amount of primary water or boric acid required using TI-44. AMOUNT PRIMARY RCS BORON PPM CHANGE WATER OR BORIC ACID I () q 3 ppm Current (I 7 ~ Et/r4f~ TOTAL GAL(s) NOTE REACTF data sheets are to be signed by the preparer and reviewer. [2] IF REACTF used attach printout to procedure. o NOTE IV is not required if appendix is performed by an SRO to verify data provided by Rx. Eng. [3] ENSURE independently verified by an SRO in accordance with Appendix I. Initials END OF TEXT

NRC08A Borate.txt 0 [REACTF - VERS SQ2.1] BORATION / DILUTION CALCULATION SEQUOYAH UNIT 1 CYCLE 15 RCS AVG TEMP 578.2 DEG F RCS PRESSURE 2235.0 PSIG PZR LEVEL 60.0 % MAKEUP WTR CONC .0 PPM BORIC ACID CONC 6850.0 PPM INITIAL CONC FINAL BORIC ACID MAKEUP WTR BORON CONC CHANGE BORON CONC ADDITION ADDITION (PPM) (PPM) (PPM) (GAL) (GAL) 1093.0 6.8 1099.8 74.9 .0 0 ( page 1

SQN BORON CONCENTRATION CONTROL 0-SO-62-7 1,2 Rev. 46 Page 162 of 199 APPENDIX E Page 1 of 18 REACTIVITY BALANCE CALCULATION NOTE 1 One calculation is required for each major change. Calculation is an approximation of required Boron change. Eyeball interpolation of graphs is expected. NOTE 2 Dilution or Boration value for power change from P1 % to P2 % power in time period T with rods moving from step position R1 to R2. (Subscript convention: 1 = current point, 2 = target point) [1] ENTER the following data: DATA REQUIRED DATA Where To Get Current RCS Boron loCf3 ppm Chem Lab or Estimate using Appendix 0 Core Burnup 1t200 MWO/MTU ICS U0981 Current Reactor power I t:J 0  % NIS or ICS Final Reactor power 93  % As required for plant conditions Total Reactor Power change 7 11% 11 Current and final Reactor power Rate of Reactor power change 7  %/hr As required for plant conditions Number of hours to change power / hr(s) As required for plant conditions ICS or MCR Board Current Rod Position Zit::, steps Estimate number of rod steps required to Final Rod Position 201./ steps control 111 and rod withdrawal requirements for power change.

SQN BORON CONCENTRATION CONTROL 0-80-62-7 1,2 Rev. 46 Page 163 of 199 APPENDIX E Page 2 of 18 CAUTION Follow sign conventions explicitly. (See Example Power Increase and Power decrease.) [2] CALCULATE change in boron concentration by performing the following: Parameter Where To Get Calculation Value Attached Power Defect Curves: (negative [a] ~p POWER DEFECT Unit 1: Figure 1, 2, or 3

                                                                                     /b7S"            pcm  PD1 - 1~7D            pcm PD2 =         /05       pcm   for power (current)                                             L'1p  POWER DEFECT    increase)

Unit 2: Figure 8, 9, or 10. Xenon., From ICS* or REACTF (either current NOTE: Xenon reactivity must be negative (negative conditions or projection to initial condition). for rise in [b] ~p XENON Xenon-, From ICS* or REACTF Xenon (projection overtime period T).

                                                                                   -Z74 V            pcm XE2 - (-Zl2.t3) pcm         XE1 =                   pcm cone)

(current) L'1p XENON

                           *(ICS Xenon values must add negative sign).

[c] ~p RODS Attached Rod Worth Curves: Unit 1: Figure 4, 5, or 6

                                                                                   -7S-          pcm    Rods, - (- z,   s-)    pcm Rods,  =     -50         pcm (negative for rod (current)                                    insertion)

Unit 2: Figure 11, 12, or 13. L'1p RODS [d] ~p POWER DEFECT + XENON + RODS (CHANGE IN REACTIW DUE TO POWER DEFECT, XENON, AND RODS) '-13 pcm [a] pcm L'1p POWER DEFECT + [b] pcm L'ip XENON + [c] pcm L'ip RODS = [e] ~p BORON (CHANGE IN BORON REACTIVITY) -Y3 pcm

                                                                                            ~p L'1p BORON

( [d] pcm POWER DEFECT + XENON + RODS) X (-1) = [f] Apprn BORON (CHANGE IN BORON CONCENTRATION) (negative for dilution, ( [e] pcni L'1p BORON) -:- (  :' 1'- pcm/ppm Boron Worth) = 6.8 ppm positive for boration) from Fig. 7 (U-1) or Fig. 14 (U-2) [3] ENSURE independently verified by SRO in accordance with Appendix J. (N/A if performed by an 8RO to verify data provided by Rx. Eng)

Sequoyah Nuclear Plant ( Unit 1 & 2 General Operating Instructions O-GO-5 NORMAL POWER OPERATION Revision 0052 Quality Related Level of Use: Continuous Use ( Effective Date: 10-27-2007 Responsible Organization: OPS, Operations Prepared By: Judy R. Varner Approved By: W. T. Leary Current Revision Description Revised to remove references to DCN 22190 which was not implemented U1C15. PERFORMANCE OF THIS PROCEDURE COULD IMPACT REACTIVITY.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 2 of 93 Table of Contents

1.0 INTRODUCTION

...........................*.............................................................................. 3 1.1    Purpose                                                                                                                 3 1.2    Scope                                                                                                                   3

2.0 REFERENCES

4 2.1 Performance References 4 2.2 Developmental References 5 3.0 PRECAUTIONS AND LIMITATIONS 6 3.1 Precautions 6 3.2 Limitations 11 4.0 PREREQUiSiTES 14 5.0 INSTRUCTIONS 16 5.1 Power Ascension From 30% to 100% 17 ( 5.2 At Power Conditions 58 5.3 Power Reduction From 100% to 30% 64 5.4 Power Coastdown at End of Life 77 5.5 LOAD FOLLOW OPERATIONS 82 6.0 RECORDS 86 Appendix A: DELETED 87 Appendix B: TURBINE RUNBACK RESTORATION 88 Appendix C: ISOLATION OF MSR STARTUP VENTS 90 Appendix D: RECOMMENDED POWER VALUES BASED ON CONDENSATED PRESSURE 91 Source Notes 92 ATTACHMENTS Attachment 1: NORMAL POWER OPERATION

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 3 of 93

1.0 INTRODUCTION

1.1 Purpose This General Operating (GO) Instruction provides guidance for power ascension from approximately 30 to 100% power, at power conditions, power reduction from 100 to 30% power, Power Coastdown at End of Life operations, and Load Follow operations. This instruction provides additional guidance for turbine control restoration following a turbine runback. 1.2 Scope This GO contains the following sections: 5.1 Power Ascension From 30% Power to 100% 5.2 At Power Conditions 5.3 Power Reduction From 100% to 30% ( 5.4 Power Coastdown at End of Life 5.5 Load Follow Operations

SQN NORMAL POWER OPERAlION 0-GO-5 Unit 1 & 2 Rev. 0052 ( Page 4 of 93

2.0 REFERENCES

2.1 Performance References A. 1,2-S0-5-1, Feedwater Heaters and Moisture Separator Reheaters B. 1,2-S0-5-2, NO.3 Heater Drain Tank and Pumps C. 1,2-S0-5-3, NO.7 Heater Drain Tank and Pumps D. 1,2-S0-2/3-1, Condensate and Feedwater System E. 1,2-S0-2-9, Condenser Vacuum and Turbine Steam Seal Systems Operation F. 0-SO-12-1, Auxiliary Boiler System G. 0-SO-35-4, Monitoring Generator Parameters H. 0-SO-58-1. Main Generator Bus Duct Cooling System I. 0-SI-NUC-000-038.0, Shutdown Margin (' J. 0-SO~62-7, Boron Concentration Control \ K. 1,2-S0-62-9, CVCS Purification System L. 0-SO-68-3, Pressurizer Spray and Heater Pressure Control System M. 0-SO-85-1, Control Rod Drive System N. 0-PI-OPS-000-666.0, River Temperature Limits Specified by NPDES permit O. 0-SI-OPS-092-078.0, Power Range Neutron Flux Channel Calibration By Heat Balance Comparison P. 0-SI-CEM-000-050.0, 72-Hour Chemistry Requirements Q. 0-SI-CEM-030-407.2, Radioactive Gaseous Waste Effluent Particulate and Iodine Dose Rates from Shield and Auxiliary Building Exhausts (Weekly/Special) and Condenser Vacuum Exhausts (Special) R. 0-SI-CEM-030-415.0, Gaseous Effluent Requirements (Gross Alpha, Noble Gas and Tritium S. 0-SI-OPS-000-001.0, Initial Startup System Parameter Log T. TI-40, Determination of Preconditioned Reactor Power

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 5 of 93 2.2 Developmental References A. Memorandum from System Engineering concerning MSR operation - RIMS S57 880322999 B. Memo from Reactor Engineering - RIMS S57 941219 934 C. S57-880322-999 and S57-880808-851 D. W Letter GP89-076 (RIMS No. S53 890427 984) E. W Letter GP 89-155 (RIMS S57 891026972) F. W Letter GP 86-02(B44 861112 002) G. SSP-2.3, Administration of Site Procedures H. TVA-NQA-PLN89-A I. GOI-10, Reactivity Control at End of Cycle Life (Trojan Nuclear Plant) J. FSAR, Section 13.5 ( K. Memo from Reactor Engineering - August 6, 1996 (G Bair)

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 6 of 93 3.0 PRECAUTIONS AND LIMITATIONS 3.1 Precautions A. To ensure that NIS Reactor Power level indications remain within 2% of true power during power level changes, a check should be performed about every 20% power level change, when greater than 15% power, by comparing calorimetric power to each NIS Power Range drawer. The 20% power level check does not preclude the operating crews from making necessary changes in response to changing plant conditions. B. TRM 3.3.3.15 requires LEFM core thermal power (U2118) to be used to perform 0-SI-OPS-092-078.0 above 15% reactor power. LEFM indication is available if the following conditions are met:

• LEFM status NORMAL on ICS Calorimetric Data screen.
• LEFM core thermal power (ICS point U2118) shows good (green) data.
• LEFM MFW header temp (ICS point T8502MA) greater than or equal to 250°F.

( If LEFM indication is NOT available above 15% reactor power, then TR 3.3.3.15 action must be entered. C. The following should be used to determine the most accurate reactor power indication for comparison with NIS:

• When reactor power is greater than 15%, use LEFM calorimetric power indication (U2118).
• If LEFM is NOT available, then use average loop ~T (U0485 or M-5 indicators) up to 40%. Above 40%, use computer point U1118.

D. The turbine should be operated in "IMP OUT" control during normal unit operation. "IMP IN" operation results in system swings and should only be used during the performance of valve tests. (W Ltr GP 89-155; RIMS S57 891026 972) E. Pressurizer heaters and sprays may be operated as required to maintain pressurizer and RCS boron concentration within 50 ppm. If loop boron concentration is changed by 20 ppm or greater, use the pressurizer backup heaters to initiate automatic spray.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 7 of 93 3.1 Precautions (continued) F. Condensate 01 polishing operations during power ascension are controlled by staying within system parameters and by recommendations from the Chemistry Section. G. The valve position limiter should be periodically positioned approximately 10% above the current governor control indications (keeps governor valves off of the limiter) as turbine load is changed. This prevents inadvertent load increases by limiting governor valve opening and allows a faster response of the runback feature which ensures main feedwater system will supply the required amount of flow. H. Any off-frequency turbine operation is to be reported to Engineering for record keeping. The report will include duration and magnitude of off-frequency operation. I. Operation at off-frequencies is to be avoided in order to prevent the probable occurrence of turbine blade resonance. Prolonged periods of operation at certain off-design frequencies could cause excessive vibratory stresses which could eventually generate fatigue cracking in the blades. Off-frequency operation is permitted to the degree and time limit specified on the chart ( "Off-Frequency Turbine Operation", Figure A.26 of TI-28. J. The potential exists for condensation formation in steam extraction lines when feed water heaters are isolated. K. Initial Startup After Refueling - After refueling operations, the NIS indications may be inaccurate until calibration at higher power levels. The NIS calibration procedures will adjust the PRM trip setpoints to ensure that the excore detectors do not contribute to an overpower condition at the following RTP hold points. Reactor Engineering and/or Systems Engineering will determine procedure performance. [C.3]

1. At < 50% RTP a flux map and single point alignment, a hot channel factor determination, an axial imbalance comparison, and aPR NIS calibration will be performed. The PR high range trip setpoint will then be increased to its normal value of 109%.

2. At < 75% RTP, calorimetric calculations and RCS flow verification may be performed, EAGLE-21 updated prior to increasing power, a flux map, a hot channel factor determination, an axial imbalance comparison may be required if not performed at < 50%, a detector calibration (if ~ AFO ~ 3%),

and a PR NIS calibration may be performed.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 8 of 93 3.1 Precautions (continued)

3. If not performed at 75% hold point, an axial imbalance comparison and a detector calibration (if ~ AFD ~ 3%) should be performed at -100% RTP.

Engineering will determine if PR NIS calibration must be performed. Calorimetric calculations, RCS flow verification, a hot channel factor determination, and a reactivity balance will be performed and EAGLE-21 updated. Reactor Engineering will notify Operations that normal full power operations may proceed.

4. Preconditioned Power Levels and Maximum Allowable Rates of Power Increase are specified in TI-40, Determination of Preconditioned Reactor Power.

5. During initial startups, based on Westinghouse recommendations, a lower power ramp rate limit has been implemented for power levels above the intermediate power threshold. The Intermediate Power Threshold is unit/cycle dependent and is determined by the Vendor. Refer to TI-40.

6. ICS will automatically monitor pre-conditioned power level as follows:

a. Point U1127 is reactor power in percent of RTP based on either

( secondary calorimetric or RCS ~T depending on power level.

b. Point U01 03 is a 20 minute rolling average of reactor power rate-of-change fitted over a 20 minute period. U0103 is a leading indicator of%/hour power ramp rate and can be used in deciding to speed up or slow down the ramp rate.

                     ~. Point U01 04 is a 1 hour rolling average of reactor power rate-of-change fitted over a 1 hour period. U0104 is used in demonstrating compliance with fuel pre-conditioning power ramp rate limits.

d. Point K0058 is the currently qualified (or pre-conditioned) power level.

e. These points can all be monitored with the ICS group display 1140.

Appendix A may be used if the ICS is unavailable. L. TI-40 power increase limits that are exceeded, in anyone hour, are evaluated in accordance with SPP-3.1.

SQN NORMAL POWER OPERATION 0-GO-5 f Unit 1 & 2 Rev. 0052

\.                                                                    Page 9 of 93 3.1     Precautions (continued)

M. Power Coastdown At End Of Life:

1. Reactor power changes should be limited to less than or equal to 1%

per hour to avoid causing xenon peaking which could force a plant shutdown.

2. Do not perform unnecessary unit power maneuvers or testing (e.g., turbine valve testing). Such testing could result in an uncontrollable Xenon oscillation.

3. Nonessential work on systems which could cause a plant upset should be deferred.

4. Secondary Plant runbacks such as Main Feed Pump Turbine trip or

                       #3 Heater Drain Tank runback will require a unit shutdown if Reactor power is not promptly returned to pre-transient level due to the resulting severe Xenon transient. If a system power alert is in effect, and electrical generation is critical, unit load should be reduced as necessary keeping TAVG on program. Contact Reactor Engineering for an evaluation and guidance concerning unit shutdown or reduction of load.

(,

5. Management should be consulted to evaluate the feasibility of a unit restart if a reactor trip occurs with RCS equilibrium boron concentration less than 50 ppm. If the reactor is to be restarted, the power level shall be limited to nominal pre-trip power level.

N. Axial Flux Difference Management: When the reactor is operating at a steady power or during normal load changes, maintain L'11 within the operating limits of the Core Operating Limits Report (COLR). It is recommended that the core axial flux difference (AFD) be maintained within +/- 5% of the target band at all times, excluding the performance of 0-PI-NUC-092-036.0, "Incore - Excore Calibration," and End of life power coast downs. Operating time outside the band, which is given in TI-28 Attachments 1 and 2, should be minimized. Reactor Engineering should be contacted if time out of the +/- 5% target band exceeds approximately 30 minutes. O. The position of control bank 0 should normally be ~ 215 steps when power level is steady state at or above 85% RTP. At steady state power levels below 85%, control bank 0 should normally be ~ 165 steps. If rod position is more than 2 steps below this guidance for long term, then impact may occur to safety analysis assumptions. ( P. During heatup and cooldown transients, RCS density changes will cause changes in NIS indicated power. At constant reactor power, a 1°F change in T AVG may cause as much as a 1% (or more) change in indicated NIS power.

SON NORMAL POWER OPERAliON 0-GO-5 Unit 1 & 2 Rev. 0052 Page 10 of 93 3.1 Precautions (continued) Q. Operation of main generator without automatic voltage control could impact grid voltage requirements. The South East Area Load Dispatcher (SELD) should be notified immediately if generator is in service without automatic voltage regulator. Also, refer to Section E of GOI 6 for MVAR limits. R. Main Generator operation without Automatic Voltage control requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to Operations Duty Specialist (ODS) within twenty four (24) hours. S. Main Generator operation outside of the Voltage Schedule in GOI-6 requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to South East Area Load Dispatcher (SELD) within one (1) hour.

1. The following limitations are applicable to Unit Two ONLY.

1. In winter months #7 HDTP capacity is not adequate to pump #6 Heater drains when all Condensate Demineralizer pumps are in service. Current

(' practice is to run two Cond 01 Pumps and / or throttle the condensate system to reduce backpressure. The preferred method is to throttle condensate pressure instead of running only two Condensate Demineralizer booster pumps at full power due to pump runout concerns.

2. Siemens-Westinghouse analysis has determined that the maximum unit power with one MFP operation is 65% under worst case conditions. The plant could operate higher if plant conditions permit.

3. MFP flow from the lead MFP should not exceed 53.7% of the total flow.

Flow rates above this would result in HP steam flow tot he lead MFP1. Computer points 1(2)U0504 and U0505 can be used to monitor.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 11 of 93 3.2 Limitations A. When the axial flux difference monitor alarm is inoperable, the AFD must be logged every hour by performing 0-SI-NUC-000-044.0. (SR 4.2.1.1.a.2 & 4.2.1.1.b) B. When both the plant computer and NIS QPTR alarm systems are inoperable, the QPTR must be calculated every 12 hours by performing 0-SI.,NUC-000-133.0. (SR 4.2.4.1.b) C. Do not exceed a load change rate of plus or minus 5% per minute or a step change of1 0%. D. River water temperatures shall be maintained within the limitations of the NPDES permit as specified in 0-PI-OPS-000-666.0. NOTE Westinghouse should be contacted if the turbine is operated outside of its operating limits as stated below. ( E. To prevent high vibratory stresses and fatigue damage to the last stage turbine blading, do not operate the turbine outside of limits listed below: [W Ur GP86-02 (844 861112 002)]

1. At loads less than or equal to 30% (350 MW), the maximum permissible backpressure is 1.72 psia. (3.5" Hg)

2. At loads greater than 30%, the maximum permissible backpressure is 2.7 psia (5.5" Hg) with a 5 minute limitation before tripping the turbine.

F. Do not allow the generator to become underexcited. G. In the event of a change in the rated thermal power level exceeding 15% in one hour, notify Chemistry to initiate the conditional portions of 0-SI-CEM-000-050.0, 0-SI-CEM-030-407.2 and 0-SI-CEM-000-415.0 due to the thermal power change.

SQN NORMAL POWER OPERATION 0-GO-5 ( Unit 1 & 2 Rev. 0052 Page 12 of 93 3.2 Limitations (continued) H. The following Main Turbine vibration limitations and actions should be adhered to:

1. Vibration levels which exceed 7 mils (alarm setpoint) should be verified by Predictive Maintenance Group.

2. Vibration levels greater than 7 mils and less than 14 mils should be continuously monitored by Predictive Maintenance Group.

3. IF vibration level is greater than or equal to 14 mils, THEN TRIP the turbine.

I. Westinghouse recommends that if any throttle valve is held closed for more than 10 minutes, then it should be re-tested immediately upon reopening in accordance with 1,2-PI-OPS-047-002.0. J. The generator may be operated without a bus duct cooler up to approximately 729 MW turbine load. K. To ensure sufficient voltage for a safe shutdown after loss of both units, voltage ( and reactive power should be maintained within the limits of GOI-6. L. With LEFM calorimetric power indication available, full power operation is defined as approximately 3455 MWT not to exceed 3455.0 MWT averaged over a 8-hour period. [C.1] If LEFM is available, power shall be monitored using plant computer point U2118 Instantaneous Value. DO NOT allow average thermal power to exceed 3455 MW thermal for two consecutive hours. M. The following restrictions apply if LEFM calorimetric power indication (U2118) is unavailable:

1. Applicable action of TRM 3.3.3.15 must be entered.

2. AFD limits in COLR and TI-28 must be made more restrictive by 1%.

3. Rod insertion limits in COLR must be raised by 3 steps.

4. If reactor power is greater than 40%, power should be monitored using U1118. If U1118 is also unavailable, use the highest reading NIS channel.

5. If reactor power is less than 40%, use the RCS average ~T as the preferred method for determining power level.

N. IF equilibrium conditions are achieved, after exceeding by 10% or more of rated thermal power the thermal power at which the heat flux hot channel factor was last determined, THEN conditional performance of 0-SI-NUC-000-126.0, Hot Channel Factor Determination is required.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 13 of 93 3.2 Limitations (continued) O. At low power levels, the LP Heaters may be unbalanced in extraction steam supply use and heat pickup across the condensate side of the heater string. This condition should correct itself as the unit approaches 45-50% Turbine Power. (Ref: PER 99-003789-000) P. With one LP heater string out of service (isolated), power is limited to 86%

             . (Unit 1) or 90% (Unit 2). This is based on LP turbine blading limitations. (Ref:

DeN E21203A). (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 14 of 93 STARTUP No. _ Unit - - Date - - - - 4.0 PREREQUISITES NOTES

1) Throughout this Instruction where an IFITHEN statement exists, the step should be N/A'd if the condition does not exist.

2) Prerequisites may be completed in any order.

[1] ENSURE Instruction to be used is a copy of effective version. [2] TAVG is being maintained within 1.5°F of T REF. 0 [3] SG level controls are being maintained in AUTO (N/A if auto control NOT available). 0 [4] Control rods are being maintained within the operating band of Core Operating Limits Report (COLR) (N/A if shutting down due to dropped or misaligned rod). 0 ( [5] Steam dump control system is in the TAVG mode (N/A if Tavg Mode NOT available). 0 [6] The EHC system should bein OPER AUTO (pushbutton lit). 0 [7] Generator pressurized with hydrogen according to capability curve. (TI-28, Fig. A14) 0 NOTE During start up after a cold shutdown the Condensate 01 normally will be aligned for full flow polishing until the MSRs are in service. [8] ENSURE Condensate 01 polishing operation in accordance with RCL recommendations.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 15 of 93 STARTUP No._....,.....-__ Unit Date _ 4.0 PREREQUISITES (continued) [9] ENSURE each performer documents their name and initials: Print Name Initials (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 64 of 93 STARTUP No, _ Unit _ _ Date - - - - 5.3 Power Reduction From 100% to 30% NOTES

1) This section may be used to reduce power to -30% during plant shutdown OR a portion of this section may be performed to reduce power as required by plant conditions. Steps which are not required for partial load reduction may be marked N/A with SM concurrence as specified by SPP-2.2.

2) Appendix 0 provides guidance on recommended power values to maintain condensate pressure if secondary plant equipment must be removed from service for maintenance.

3) Steps 5.3[2] through 5.3[6] may be performed out of sequence.

[1 ] ENSURE Section 4.0, Prerequisites complete. [2] REVIEW of Precautions and Limitations Section 3.0 has been completed. 0 ( [3] NOTIFY RADCON of impending load reduction. 0 [4] NOTIFY CON 01 operators of load reduction and to remove beds as needed. 0 [5] NOTIFY Load Dispatcher of impending load reduction. 0 NOTE Lowering load on the Main Generator will cause VARs to trend in the positive direction (toward outgoing). This will require lowering generator voltage. Refer to GOI-6 Section E for MVAR limits for generator stability. [6] PERFORM the following as required: [6.1] IF Automatic Voltage Control is in service, THEN ADJUST Main Generator VARs USING [HS-57-221 Exciter Voltage Auto Adjuster as necessary during power escalation. [6.2] IF Automatic Voltage Control is NOT in service, THEN ADJUST Main Generator VARs USING [HS-57-231 Exciter Voltage Base Adjuster as necessary during power escalation.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 65 of 93 STARTUP No., _ Unit _ _ Date _ 5.3 Power Reduction From 100% to 30% (continued) NOTES

1) Guidance on restoration of EHC Controls after a BOP runback is contained in Appendix B, Turbine Runback Restoration. [C.4]

2) For core operating recommendations for situations such as end of core life coast down or unusual power maneuvers, contact Reactor Engineering for guidance. [C.5]

3) It is recommended that AFD be controlled within the target band.

4) The following general approach should be used during power reduction:

(a) borate RCS to reduce RCS TAVG within limits of T REF, (b) reduce turbine load to match T REF with TAVG (c) periodically take rod control to MANUAL from AUTO and insert the bank to move AFD near the target value, (d) return rod control to AUTO when not using the bank to control AFD, and (e) repeat the above as necessary to accomplish the load change. ( 5) Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized during performance. [7] INITIATE a load reduction. D

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 66 of 93 STARTUP No. Unit _ _ Date _ 5.3 Power Reduction From 100% to 30% (continued) [8] MONITOR turbine load decreasing. o CAUTION Do NOT exceed a load change rate of plus or minus 5%/minute or a step change of 10%. NOTE TAVG is programmed from 578.2°F at 100% power to 54JOF at zero power at a rate of 0.312°F per % power. [9] MONITOR the following during the load reduction: [9.1] TAVG following TREF program. o [9.2] All RPls, group step counters for rod insertion limits and ( inoperable rods or rod misalignment, Loop ~T, and NIS for correct power distribution and quadrant power tilts. D [9.3] Core AFD within +/- 5% control band around the power level dependent target value. D NOTE Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-047-2000 (M-2). [9.4] Valve position limit approximately 10% above the current governor control indication as turbine load is changed. D [10] IF AFD remains outside the AFD target band for approximately 30 min or more, THEN CONTACT Reactor Engineering as to why and when the AFD might be returned to the target band. D

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 67 of 93 STARTUP No. _ Unit _ _ Date _ 5.3 Power Reduction From 100% to 30% (continued) NOTES

1) Shutdown of the condensate demineralizer booster pumps should be based on header pressure, the ability of the drain tank pumps to pump forward, or System Engineering evaluation.

2) The following step may be marked N/A if reducing power as specified by AOP-S.04, Condensate and Heater Drains Malfunction, or as specified by Appendix D. In this case, all available condensate and heater drain pumps should remain in service to maintain adequate condensate pressure.

[11] WHEN reactor power is approximately 85 to 90%, THEN PERFORM the following: [11.1] IF three condensate demineralizer booster pumps are in service, THEN EVALUATE removing one (1) condensate demineralizer booster pump in accordance with 1,2-S0-2/3-1. [11.2] IF two condensate demineralizer booster pumps are in service, THEN EVALUATE removing both condensate demineralizer booster pumps in accordance with 1,2-S0-2/3-1. [11.3] STOP one (1) condensate booster pump in accordance with 1,2-S0-2/3-1.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 68 of 93 STARTUP No. Unit Date _ 5.3 Power Reduction From 100% to 30% (continued) NOTE 0-SI-OPS-092-078.0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance. [12] PERFORM the following at approximately 80% reactor power: [12.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 = - - -% D 34.55 [12.2] IF LEFM indication is NOT available, THEN CALCULATE reactor power: ( Calorimetric power= U1118 = D 34.11 [12.3] VERIFY that all NIS Power Range A channel drawers are within +/- 2% of the calculated calorimetric power. N-41 (XI-92-5005B) YESD NOD N-42 (XI-92-5006B) YESD NOD N-43 (XI-92-5007B) YESD NOD N-44 (XI-92-5008B) YESD NOD [12.4] IF any of the above steps are checked NO, THEN PERFORM 0-SI-OPS-092-078.0.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 69 of 93 STARTUP No. Unit _ _ Date _ 5.3 Power Reduction From 100% to 30% (continued) NOTE Turbine Impulse pressure relay lights are located on L-262.Relay lights are dark when relays are NOT armed. Relay NO.4 is a spare. [13] WHEN turbine load less than 71% (Unit 1) 72% (Unit 2), THEN PERFORM one of the following (N/A substep not performed): [13.1] VERIFY Turbine Runback circuits are NOT armed by performing the following: A. ENSURE [PIS-47-13RLY1]~ (Turbine runback from MFP loss) is NOT LIT.

8. ENSURE [PIS-47-13RLY2L (Turbine runback from

( NO.3 HOT) is NOT LIT. C. ENSURE [PIS-47-13RLY3]~ (Closure of LCV-6-1 068 from Loss of any #3 HOTP) is NOT LIT. [13.2] VERIFY Turbine Runback circuits are NOT armed by performing the following: A. ENSURE [FU2-47-13AL (Turbine runback from MFP loss) REMOVED (Aux Inst Rm. R71).

8. ENSURE [FU2-500-R071 K3]~ (Turbine runback from NO.3 HOT) REMOVED (Aux Inst Rm R-75).

C. ENSURE jumper between P18-1 and P18-2 in Pnl 262, (Closure of LCV-6-1068 from Loss of any

                             #3 HDTP) REMOVED.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 &2 Rev. 0052 Page 70 of 93 STARTUP No., _ Unit _ _ Date _ 5.3 Power Reduction From 100% to 30% (continued) CAUTION Valves LCV-6-1 06A and 1068 shall be verified to be controlling properly during unit load reduction. NOTES

1) One MFWP is normally removed from service at 45% turbine load but, if necessary, may be removed from service at power level less than 55% (Unit 1) or 65% (Unit 2) if approved by the Operations Superintendent.

2) If holding at a power level less than 60% the condensate demineralizer booster pumps may be left running.

3) Shutdown of the condensate demineralizer booster pumps and

       #3 heater drain pumps should be based upon header pressure and ability of the drain tank pumps to pump forward.

( [14] WHEN between 55 to 70% turbine load, THEN PERFORM the following: [14.1] SIMULTANEOUSLY STOP both operating condensate demineralizer booster pumps in accordance with 1,2-S0-2/3-1 (N/A if NOT in service). [14.2] VERIFY #3 HOT runback NOT armed by ensuring either (N/A method NOT used) Step 5.3[13.1]8 completed OR Step 5.3[13.2]8 completed.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 71 of 93 STARTUP No. _ Unit _ _ Date _ 5.3 Power Reduction From 100% to 30% (continued) [14.3] STOP one of the three #3 heater drain tank pumps in accordance with 1,2-80-5-2. [14.4] DISPATCH an AUO to perform one of the following to align steam seals to the unit: A. IF Auxiliary Stearn Header is available and other unit is greater than 55% load, THEN ALIGN opposite units #3 Extraction to supply steam seals in accordance with 0-80-12-1. D B. IF the #3 Extraction on the opposite unit is NOT available THEN PLACE the Auxiliary Boiler in service in accordance with 0-80-12-1, OR ( ENSURE steam seals are being supplied from the unit's main steam supply. D NOTE 0-81-0P8-092-078.0 may be performed at discretion of Operator if one or more PRMs is indicating close to the +/- 2% tolerance. [15] PERFORM the following at approximately 60% reactor power: [15.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 = - - -% D 34.55 [15.2] IF LEFM indication is NOT available, THEN CALCULATE reactor power: Calorimetric power= U1118 = - - -% D 34.11

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 72 of 93 STARTUP No. Unit - - Date _ 5.3 Power Reduction From 100% to 30% (continued) [15.3] VERIFY that all NIS Power Range A channel drawers are within +/- 2% of the calculated calorimetric power. N-41 (XI-92-5005B) YESD NOD N-42 (XI-92-5006B) YESD NOD N-43 (XI-92-5007B) YESD NOD N-44 (XI-92-5008B) YES D NOD [15.4] IF any of the above steps are checked NO, THEN PERFORM O-SI-OPS-092-078.0. (

saN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 73 of 93 STARTUP No. Unit _ _ Date _ 5.3 Power Reduction From 100% to 30% (continued) NOTE Steps 5.3[16] through 5.3[18] may be performed out of sequence. [16] WHEN between 40% and 65% turbine load, THEN STOP one of the two #7 heater drain tank pumps in accordance with 1,2-S0-5-3. [17] WHEN reactor power is approximately 50%, THEN VERIFY annunciator XA-55-4A, window E-4: P-9 LOW POWER TURB TRIP-REAC TRIP BLOCK is LIT. ( o [18] WHEN approximately 45% turbine load, THEN PERFORM the following: [18.1] IF operating with two main feedwater pumps in service, THEN SHUTDOWN one main feedwater pump in accordance with 1,2-S0-2/3-1. [18.2] STOP the second #7 heater drain tank pump in accordance with 1,2-S0-5-3. (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 74 of 93 STARTUP No. _ Unit _ _ Date - - - 5.3 Power Reduction From 100% to 30% (continued) NOTE 0-SI-OPS-092-078.0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance. [19] PERFORM the following at approximately 40% reactor power: [19.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 = - - -% D 34.55 [19.2] IF LEFM indication is NOT available, THEN ( CALCULATE reactor power: Calorimetric power= U1118 = - - -% D 34.11 [19.3] VERIFY that all NIS Power Range A channel drawers are within +/- 2% of the calculated calorimetric power. N-41 (XI-92-5005B) YES D NOD N-42 (XI-92-5006B) YES D NOD N-43 (XI-92-'5007B) YES D NOD N-44 (XI-92-5008B) YES D NOD [19.4] IF any of the above steps are checked NO, THEN PERFORM 0-SI-OPS-092-078.0.

SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 75 of93 STARTUP No. Unit _ _ Date - - - 5.3 Power Reduction From 100% to 30% (continued) NOTE AMSAC is blocked when less than 40% turbine load for greater than 360 seconds (time delay). [20] WHEN less than 40% turbine load, THEN VERIFY annunciator XA-55-4A, window E-7: C-20 AMSAC ARMED is DARK. o [21] WHEN approximately 35% reactor power, THEN ( VERIFY annunciator XA-55-4A, window C-5: P-8 LOW POWER LOW FLOW TRIP BLOCK is LIT. o [22] WHEN approximately 30% turbine load, THEN [22.1] STOP the two operating #3 heater drain pumps in accordance with 1,2-S0-5-2. [22.2] STOP one of the two operating condensate booster pumps in accordance with 1,2-S0-2/3-1. [22.3] STOP one of the three operating hotwell pumps in accordance with 1,2-S0-2/3-1.

SQN NORMAL POWER OPERATION O-GO-5 Unit 1 & 2 Rev. 0052 Page 76 of 93 STARTUP No. Unit _ _ Date _ 5.3 Power Reduction From 100% to 30% (continued) [23] STABILIZE the plant at approximately 30% reactor power with reliable steam flow/feed flow indications. D [24] IF further load reduction is required,THEN GO TO 0-GO-6, Power Reduction from 30% Reactor Power To Hot Standby. [25] IF main turbine shutdown is desired while holding reactor power at approximately 30%, THEN GO TO 0-GO-11, Turbine Shutdown Without Reactor Shutdown. [26] IF reactor shutdown and turbine shutdown is required THEN GO TO 0-GO-6, Power Reduction from 30% Reactor Power To Hot Standby. ( [27] IF unit is to return to 100% power operation, THEN GO TO Section 5.0 of this instruction. END OF TEXT

I Appendix 0 Scenario Outline Form ES-D-1 I Facility: Sequoyah Scenario No.: 2 Op Test No.: NRC Examiners: Operators: Initial Conditions: 100% Power BOL Turbine Driven Auxiliary Feedwater Pump OOS for maintenance. Turnover: Maintain Current Plant conditions. Target CTs: Isolate Steam flow and Feedwater flow to ruptured S/G prior to initiation of RCS Cooldown to target temperature. Cooldown RCS to less than or equal to target temperature prior to RCS depressurization. Depressurize RCS to meet E-3 depressurization criteria prior to S/G overfill (100% S/G dome level from simulator computer variable). Event Malf. No. Event Type* Event Description No. 1 ED16A TS-SRO 125 DC Vital Battery Charger I failure. Tech Spec evaluation. Crew initiates placing Spare Charger in Service to Vital Battery. ( 2 RW01E TS-SRO ERCW pump N-B trips. Requires placing standby pump in service and AOP M.01performance. Tech Spec Evaluation. C-SRO/BOP 3 RX11B I-All Impulse pressure transmitter PT-1-73 fails low resulting in rod insertion and manual rod control. SRO will direct AOP-1.08 to remove from service and transfer steam dump system to pressure control. 4 TH05A TS-SRO Steam generator #1 tube leak of approximately 15 gpm requiring rapid plant shutdown. Tech Spec Evaluation. C-AII 5 N/A R-ATC Perform rapid plant shutdown using AOP-C.03. Manual Rod control will be required. N-SRO/BOP 6 ZDIHS621 C-SRO/ATC Emergency boration valve (FCV-62-138) will not open from 38A control room handswitch. Normal boration required for shutdown. 7 TH05A M-AII Steam generator tube leak increases to tube rupture (-400 gpm) requiring Rx Trip and Safety injection. 8 FW09A C-BOP Motor Driven Auxiliary Feeedwater pump 1A-A fails to Auto start requiring manual start. 9 RC06A C-SRO/ATC Pressurizer Spray valve fails full open during RCS depressurization in E-3. Stopping RCPs (at least #1 & #2) to terminate depressurization required.

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

( Appendix 0 NUREG 1021 Revision 9

I Appendix 0 Scenario Outline Form ES-D-1 I Scenario 2 Summary Shortly after assuming shift, 125 Volt DC Vital Battery Charger I will fail. Crew will diagnose the failure and initiate Vital battery I transfer to the spare charger. SRO will evaluate and enter applicable Technical Specifications. After addressing the charger failure, Essential Raw Cooling Water pump N-B will trip. Crew will start the standby pump and perform the AOP which will require realigning the Standby pump for Emergency start also. SRO will evaluate Technical Specifications, LOC is applicable until selector switch for auto start is aligned to the operable pump then it may be exited I. After the ERCW pump AOP is complete Turbine Impulse Transmitter PT-1-73 will fail low. This will result in inadvertent rod insertion which will require placing rod control in manual for the remainder of the scenario. This failure will also require transferring steam dump control system to steam pressure mode. S/G level program and Tavg reference program (Tref) will be also be affected. SRO may again evaluate Technical Specifications; however, LCO entry will not be required since the low failure does not affect the associated interlock in such a way as to prevent the associated reactor protection system functions from operating. After this AOP has been addressed, a steam generator tube leak of approximately 15 gpm will occur in Steam Generator #1. Since this leak is within the capacity of the normal charging system, the associated AOP will require initiation of a rapid shutdown. RCS leakage Tech Spec. is applicable. When starting the rapid shutdown, the emergency boration valve will not open from the control room handswitch requiring performance of the altenate path to initiate boration using normal boration. Rod control during the shutdown will be manual. After the rapid shutdown has resulted in a sufficient power reduction, the steam generator Tube leak will propagate to a significant rupture of approximately 400 gpm. This leak size will require initiation of a Reactor Trip and Safety Injection. Motor Driven Auxiliary Feedwater Pump 1A-A will fail to auto start from ( the SI signal and will require manual start. The crew will progress through E-O and transition to E-3 where they will cooldown to target RCS temperature and depressurize the RCS. During depressurization a Pressurizer spray valve will fail open requiring stopping of at least RCPs 1 and 2 to stop the depressurization. The scenario may be terminated when crew has completed RCS depressurization in E-3. Appendix 0 NUREG 1021 Revision 9

Page 1 of 3 NRC08B Rev 0 CONSOLE OPERATOR INSTRUCTIONS Sim. Setup ResetIC-~ Initialize simulator at 100 % RTP BOL. Perform switch check. Allow the simulator to run for at least 3 minutes Place Mode_1_placard on panels. before loading SCEN file or starting the exercise. This will initialize ICS. Place-A-Train Week sign on the simulator. Load SCENS: NRC08B Place simulator momentarily in RUN, Place OOS equipment in required position with tags, Clear alarms and Return to FREEZE. These remote IMF FW07C f:1 TDAFW PUMP IS INOPERABLE. functions are active lOR ZLOHS151A_GREEN f:O when the SCENS file lOR ZLOHS 117A GREEN f:O Close FCV-1-17 & 18 & place Hold Notice on HS-is loaded. lOR ZLOHS118A GREEN f:O 1-17&18 and FCV-1-51. lOR ZLOHS3136AA GREEN1 f:O Also place Hold order on TDAFW Pump ERCW lOR ZLOHS3136AA_GREEN2 f:O supply valves. lOR ZLOHS3136AA_RED1 f:O lOR ZLOHS3136AA_RED2 f:O Place Protected Equipment tags on MD AFW lOR ZDIHS3136AA f:O Pumps. ( lOR ZLOHS3179AA GREEN1 f:O lOR ZLOHS3179AA GREEN2 f:O lOR ZLOHS3179AA RED1 f:O lOR ZLOHS3179AA_RED2 f:O lOR ZDIHS3179AA f:O Event #1: When IMF ED16A F:1 K:1 125 DC Vital Battery Charger I failure. Determined by NRC Examiner Examiner, After dispatched, wait I::t 2 minutes then report that insert this Malfunction the battery charger was smoking badly but no flames, using and that you have opened the AC input and DC Key 1. output breakers. Role playas Fire OPS as needed. If requested to place IRF EDR65A F:1 k:2 Place Spare Charger 1-S on Vital battery Bd I. spare charger 1-S on Vital Battery Bd I When dispatched, wait -20 min to insert the insert remote function remote function and then report the transfer using complete. KEY-2.

Page 2 of 3 NRC08B Rev 0 CONSOLE OPERATOR INSTRUCTIONS Event #2: When IMF RW01E F:1 K:3 ERCW pump N-B trips on overcurrent. Determined by NRC Examiner, insert this When dispatched to check the breaker, wait RI 3 Malfunction using minutes then report that there is an instantaneous Key 3. overcurrent relay on the pump breaker. When dispatched to check Motor wait -5 min and report smell of overheated insulation. Role playas AUO to close tripped pump discharge valve as needed, no console actions are needed. Event #3: When IMF RX11B f:O k:4 IMPULSE PRESSURE TRANSMITTER 1-PT-1-73 Determined by NRC FAILS LOW Examiner, insert this Malfunction using When IMs or MSS contacted to trip bistables, Key 4. inform the crew that the IMs will report to the MCR in - 45 minutes. Event #4: When IMF TH05A f:O.3 k:5 STEAM GENERATOR TUBE FAILURE SG #1 Determined by NRC APPROXIMATEL Y 15 GPM REQUIRING RAPID Examiner, insert this PLANT SHUTDOWN. Malfunction using ( (ey 5. When Chem Lab contacted for RM-90-119 limit, inform the crew of the limit on the Ops chemistry information report (turnover information). Report that other Chemistry actions will take -45 minutes to complete. When RADCON/Chem Lab are requested to survey/sample S/Gs, wait -10 min then report as RADCON that #1 S/G has slightly higher background than the others. Wait 45 minutes and report as Chem Lab that ruptured S/G is #1 S/G. Event #5: As Directed Initiate rapid plant shutdown using AOP-C.03. by S/G tube leak AOP. Event #6: This lOR ZDIHS62138A f:O EMERGENCY BORATION FLOW CONTROL Override is active VALVE (FCV-62-138) WILL NOT OPEN FROM when the SCENS file HANDSWITCH. is loaded If Dispatched to check locally wait- 3 min and report valve closed but you cannot determine why it won't open. If requested to operate the valve locally, report that it will not open locally either.

Page 3 of 3 NRC08B Rev 0 CONSOLE OPERATOR INSTRUCTIONS Event #7: When MMF TH05A f:8.6 r:300 LOOP 1 S/G TUBE LEAK INCREASING TO Power has been RUPTURE (-400 GPM) OVER 5 MIN. REQUIRING adequately RX TRIP AND SAFETY INJECTION. Decreased as Determined by NRC Examiner, Modify this Malfunction. Event #8: This IMF FW09A f:1 DEFEAT AUTO START OF MDAFWP 1A-A - PUMP Override is active CAN BEMANUALLY START when the SCENS file is loaded Event #9: When IMF RC06A f:100 k:6 PRZ SPRAY VALVE PCV-68-340B FAILS FULL Crew begins RCS OPEN (LOOP 2) Depressurization in E-3, insert this Malfunction using Key 6. (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # .....;.. Page 1 of .....;3;..;..7~1 Event

Description:

125 Volt DC Vital Battery Charger I Time II Position II Applicant's Actions or Behavior Console Operator: When directed, initiate Event 1 Indications Available: 1-AR-M1-C, A4, 125 DC VITAL CHGR I FAILURE OR VITAL BAT I DISCHARGE Upscale Deflection of of EI-57-92 on M-2. Refer to alarm response procedure 1-AR-M1-C window A4 BOP SELECT channell on [1-XS-57-96] 125V Vital Battery voltage, BOP AND CHECK battery bd voltage. IF failure of 125V DC Vital Battery Bd, THEN GO TO AOP-P.02, Loss of 125V DC Vital Battery Board. CREW ( (Step is N/A Board Voltaqe Normal) NOTE Downscale (zero or below) deflection of EI-57-92 indicates current flow from normal power supply (charger). Upscale (greater than zero) deflection of EI-57-92 indicates current flow from the battery. CHECK [1-EI-57-92] Vital Battery Bd I amps. BOP (Ampmeter shows upscale deflection indicating battery discharge) DISPATCH personnel to INSPECT AND CHECK for local alarms on the 125V DC Vital Charger I and 125V DC Vital BOP Battery bd I. Next 5 Steps of Annunciator Response Procedure are NA for BOP this failure.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # Page 2 of 37

                                                                 -.;...----                       ~--\I Event

Description:

125 Volt DC Vital Battery Charger I Time Position Applicant's Actions or Behavior IF charger failure, THEN EVALUATE need to place spare charger in service in accordance with 0-SO-250-1, 125 Volt de Vital Battery Board CREW (Crew should initiate placing spare charger in service to Vital Batt Bd I. Crew could also decide to place the s" Battery in service.) EVALUATE EPIP-1 Emergency Plan Classification Matrix. CREW (Crew should notify Shift Manager to evaluate REP) EVALUATE TS LCOs 3.8.2.3. (2 Hr Action b. Applies) SRO When Technical Specifications have been identified or at discretion of the Lead Examiner, proceed to the next event. (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 2 Event

Description:

ERCW Pump N-B Trips Time II Position II Applicant's Actions or Behavior Console Operator: When directed, initiate event 2 Indications available:

• Motor Trip out Buzzer and White Light on Pump Handswitch .
• Low ERCW Header Pressure Alarm Respond Backpanel Alarm, Place Failed Pump switch in Pull to BOP Lock, and Perform Annunciator Response Procedure.

Enter and Direct performance of AOP-M.01 , Section 2.1 SRO ERCW Pump Failure. IDENTIFY and LOCK OUT failed ERCW pump. BOP START additional ERCW pumps as required to maintain supply header pressure between 78 psig and 124 psig. BOP (Pressure should be in the band (-82 psig) however, Crew may start standby pump to provide additional margin since 4 pumps were initially running) CHECK two Train A ERCW Pumps AVAILABLE.

a. Supply header pressures [between 78 psig and 124 psig]:

• 1-PI-67-493A
• 2-PI-67-493A BOP

b. Supply header flows [expected value]:

• 1-FI-67-61 (-2700 gpm acceptable)
• 2-FI-67-61 (-13,500 gpm acceptable)

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 2 Event

Description:

ERCW Pump N-B Trips Time Position II Applicant's Actions or Behavior CHECK 1Band 2B ERCW supply header pressures and flows NORMAL:

a. Supply header pressures [between 78 psig and 124 psig]:

• 1-PI-67-488A BOP
• 2-PI-67-488A

b. Supply header flows [expected value]:

• 1-FI-67-62 (-1500 gpm acceptable)
• 2-FI-67-62 (-11,500 gpm acceptable DISPATCH personnel to INSPECT failed pump(s) and determine cause for failure.

Crew NOTIFY STA to evaluate Tech Spec LCO 3.7.4, ERCW ( System. SRO (SRO should evaluate Tech Specs - LCO Applies until selector switch is repositioned to operable pump. This may result in LCO entry and exit) CHECK ERCW pump loading amps NORMAL. RO TRANSFER emergency power selector switch away from failed pump. RO EVALUATE need to close and place clearance on manual discharge valve Crew for failed pump. GO TO appropriate plant procedure. SRO When Technical Specifications have been identified or at discretion of the Lead Examiner, proceed to the next event.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 3 ( Event

Description:

Impulse Pressure Transmitter PT-1-73 fails low Time II Position II Applicant's Actions or Behavior Console Operator: When directed, initiate event 3 Indications available:

• Control Rod insertion
• 1-AR-MS-A, CG, TAVG/TREF DEVIATION
• 1-AR-MS-A, B7, STEAM GEN LVL HIGH-LOW DEVIATION Refer to alarm response procedures Crew Direct entry to AOP-1.08, Turbine Impulse Pressure SRO Instrument Malfunction OR MAY enter to AOP-C.01, Sect 2.1, Continuous rod bank movement:

(

1. CHECK rod control:

a. ENSURE rod control in MAN. (YES)

b. CHECK rod motion STOPPED. (YES)

SRO 2. CHECK for steam line or feedwater line break: (NO)

3. CHECK for instrumentation malfunction:

a. CHECK nuclear instrumentation OPERABLE. (YES)

b. CHECK RCS RTDs OPERABLE. (YES)

c. CHECK turbine impulse pressure channels OPERABLE. (NO)

Transitions to AOP-1.08 from 3.c

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 3 ( Event

Description:

Impulse Pressure Transmitter PT-1-73 fails low Time II Position II Applicant's Actions or Behavior NOTE: Loss of Instrument Power to Steam Generator level setpoint program input will drive the setpoint below 33% Steam Generator level. CHECK PI-1-73 indicates normal. (RNO Steps)

• PLACE rods in MAN.
• EVALUATE placing Main Reg Valves in MAN to maintain SG level on program.

Operators may elect to leave FW Reg valves in auto, S/G will control at a lower level.

• PLACE Steam Dumps in Steam Pressure Mode USING 0-SO-1-2, Steam Dump System.

[1] PLACE [HS-1-103A] Steam Dump A FSV and [HS-1-103B] Steam Dump B FSV handswitches ( to OFF. RO/BOP [2] PLACE [HS-1-103D] Steam Dump Mode selector to STEAM PRESS. [3] VERIFY [XI-1-103A1B] Steam Dumps Armed white light is LIT. [4] IF [PIC-1-33] Steam Dump Controller in MANUAL, THEN ENSURE demand is Zero on controller. [5] IF [PIC-1-33] Steam Dump controller in AUTO, THEN ADJUST setpoint to obtain zero output (demand). [6] PLACE [HS-1-103A] Steam Dump A FSVand [HS-1-103B] Steam Dump B FSV handswitches to ON. [7] ADJUST [PIC-1-33] Steam Dump controller to maintain desired steam pressure.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 3 Event

Description:

Impulse Pressure Transmitter PT-1-73 fails low Time II Position II Applicant's Actions or Behavior

• DETERMINE Program T-avg for current reactor power USING TI-28 Figure A.9 or ICS (NSSS I BOP, Program Reactor Average Temperature).
• WHEN plant stable, THEN RESTORE T-avg to within 3 degrees of program:

RO/BOP

• POSITION control rods.

OR

• ADJUST turbine load.

OR

• ADJUST RCS boron concentration CHECK PI-1-72 indicates normal.

BOP NOTE: If performing AOP in conjunction with AOP-1.11 for an Eagle LCP failure, then actions to ( hard trip bistables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours UNLESS affected loop is restored to operable status by resetting Eagle rack. IF PI-1-72 or PI-1-73 has failed, THEN NOTIFY 1M to remove failed channel from service USING Appendix A, P-1-72 (P-CREW 506) OR Appendix B, P-1-73 (P-505) EVALUATE the following Tech Specs for applicability:

• 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation -

SRO (ACTION B.b applies, affected channels are operable) When Technical Specifications have been determined, the Lead Examiner may cue the next event

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Event # 4 Page 8 of 37 Event

Description:

S/G #1 Tube Leak Time II Position II Applicant's Actions or Behavior Console Operator: When directed, initiate Event 4 Indications available: 0-AR-M12-A, C1, CNDS VAC PMP LO RNG AIR EXH MON HIGH RAD 0-AR-M12-A, B5, STM GEN BLDN L1Q SAMP MON HI RAD (-10-12 min delay) Refer to alarm response procedure, Condenser Vacuum Crew Exhaust Hi Rad. CHECK 1-RM-90-119 rate meter and 1-RR-90-119 on 0-M-12 for indication of increased radiation. BOP NOTE ( Alarm validity may be determined based on absence of instrument malfunction alarm, indicated response of the rad monitor, and, if possible, other indications such as blowdown monitor (recognizing the difference in response time due to blowdown transport time). IF alarm is valid, THEN NOTIFY RCL to perform 1-CEM-068-137.5 Primary to Secondary Leakage via Steam Generators. BOP IF alarm is valid, THEN GO TO AOP-R.01, Steam Generator Tube Leak. BOP Direct entry to AOP-R.01, Steam Generator Tube Leak SRO EVALUATE the following Tech Specs SRO for applicability: Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Event # 4 Page 9 of 37 Event

Description:

S/G #1 Tube Leak Time II Position II Applicant's Actions or Behavior Evaluator Note: SRO may refer to Operations Chemistry Information Sheet in turnover package.

• 3.4.6.2, Operational Leakage. Enters action b.
• 3.7.1.2, Auxiliary Feedwater System
• 3.7.1.3, Condensate Storage Tank SRO
• 3.7.1.4, Secondary Coolant Activity (May Address TS Later, as required)
• 3.2.5, DNB Tech Spec: Pzr heater operation to control/restore to within limits.

EVALUATE EPIP-1, Emergency Plan Classification Matrix or notifies the SM. SRO NO Classification: RCS Identified leakage (Primary to Secondary leakage) is less than 25 gpm. ( High Secondary Radiation AND Pressurizer level dropping OR Charging flow rising with stable SRO Pressurizer level

• Go to section 2.1 NOTE:

This section should be used if tube leakage has an observable effect upon charging flow and/or Pressurizer level OR if directed by Section 2.2 due to leak rate exceeding 75 gallons per day (not due to temporary spike). CONTROL charging flow USING FCV-62-89 and FCV-62-93 as necessary to maintain pzr level on program. RO MONITOR Pressurizer level STABLE or RISING. RO Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Event # 4 Page 10 of 37 Event

Description:

S/G #1 Tube Leak Time II Position II Applicant's Actions or Behavior (RNO - May be performed later when leak increases) PERFORM the following:

• START additional CCP as necessary.
• IF pressurizer level continues to drop, THEN ENSURE letdown isolated:
• FCV-62-72 CLOSED RO/SRO
• FCV-62-73 CLOSED
• FCV-62-74 CLOSED IF loss of Pressurizer level is imminent, THEN PERFORM the following:
• TRIP the reactor.
• INITIATE Safety Injection.
• GO TO E-O, Reactor Trip or Safety Injection.

( MAINTAIN VCT level greater than 13% using automatic or manual makeup. RO INITIATE rapid shutdown by performing the following:

• ANNOUNCE S/G tube leak on PA system.
• PERFORM rapid shutdown USING AOP-C.03 WHILE continuing in this section.

Crew

• ENSURE power reduced to less than 50% within one hour.
• ENSURE unit in Mode 3 within the following 2 hours.

(SRO May handoff AOP-R.01 top BOP to perform reader Doer while directing rapid shutdown) ( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 ( Op Test No.: NRC Scenario # 2 Event # 4 Page 11 of 37 Event

Description:

S/G #1 Tube Leak I Time II Position II Applicant's Actions or Behavior Evaluator Note: The following steps from AOP-R.01 should continue in parallel with plant rapid shutdown using AOP-C.03 directed by SRO. Refer to the next event guide for rapid shutdown. NOTIFY RADCON to monitor Turbine Building and site environment: BOP

• Steam lines
• S/G blowdown NOTIFY Chem Lab to perform the following:

a. EVALUATE Primary to Secondary Leakage USING 1(2)-

SI-CEM-068-137.5:

• Method 1, Rapid Identification of Leaking Steam Generators (S/Gs) [Identifies S/G via blowdown sampling

(

• Method 3, Condenser Vacuum Exhaust (CVE)

Sampling for Determination of Primary-to-Secondary BOP (PIS) Leakage. [provides leak rate by comparison of RCS activity and CVE. Steady State conditions increase accuracy]

b. DETERMINE noble gas release rate, and particulate &

iodine dose rates for condenser vacuum exhaust USING 0-SI-CEM-030-415.0 and 0-SI-CEM-030-407.2.

c. ALIGN steam generator sample drain lines to FDCT USING 0-TI-CEM-000-016.4.

BYPASS condensate 01. BOP NOTE Closure of FCV-15-44 or FCV-15-43 will isolate blowdown flow to RM-90-120/121. Steam Generator Blowdown must be re-aligned to Con 01 using 1(2)-SO-15-1 to re-establish flow to rad monitors. Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Event # 4 Page 12 of 37 Event

Description:

S/G #1 Tube Leak Time Position Applicant's Actions or Behavior TERMINATE Steam Generator Slowdown to Cooling Tower Slowdown:

a. ENSURE FCV-15-44 S/G blowdown to Cooling Tower SOP Slowdown CLOSED.

b. ENSURE S/G blowdown ALIGNED to Con 01 USING 1(2)-

SO-15-1. NOTE Condenser Vacuum Exhaust and S/G blowdown Radiation Monitors should be monitored at approximately 15 minute intervals for indications of rising leak rate. Appendix A performance is not required. MONITOR indications of leaking steam generator: ( a. IDENTIFY leaking S/G(s) USING any of the following:

• Unexpected rise in any S/G narrow range level.
• S/G sample results.

SOP

• RADCON survey of main steamlines and S/G blowdown lines.
• High radiation on any main steamline radiation monitor.

b. MONITOR Condenser Vacuum Exhaust and S/G Slowdown Radiation Monitors for rise in leak rate.

CAUTION Closing TO AFW pump steam supply from SIG #1 will impact AFW operability. Refer to LCO 3.7.1.2. Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 13 of 37 Event

Description:

S/G #1 Tube Leak Time II Position II Applicant's Actions or Behavior WHEN leaking S/G IDENTIFIED, THEN PERFORM the following:

a. ADJUST leaking S/G atmospheric relief controller to 87%

in AUTO. (1040 psig)

b. ENSURE blowdown valves on leaking S/G CLOSED.

BOP c. CLOSE TD AFW pump steam supply from leaking S/G

• FCV-1-15 (S/G #1)

Or

• FCV-1-16 (S/G #4).

d. ENSURE TD AFW pump steam supply from intact S/G OPEN MINIMIZE Spread of contamination.

(

a. PERFORM EA-0-3, Minimizing Secondary Plant BOP Contamination.

b. EVALUATE Appendix C, Contingency Plan for Control and Processing of Large Volumes of Contaminated Water NOTE Steps prior to Step 21 may be performed in parallel with ES-0.1.

CHECK reactor SHUTDOWN. DO NOT CONTINUE this section UNTIL reactor shut down. Section will be terminated when Reactor Trip and SI have been actuated. Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5&6 Page 14 of 37 Event

Description:

Rapid Shutdown, Emergency Boration Valve Failure Time II Position II Applicant's Actions or Behavior Console Operator: No action required for event 5 or 6. Indications Available:

• Rapid Shutdown: N/A
• Emergency Boration Valve continues to indicate closed with 0 flow when taken to the open position.

Enter and Direct performance of AOP-C.03, Rapid Shutdown or SRO Load Reduction. ENSURE crew has been briefed on reactivity management expectations USING Appendix E. SRO NOTIFY following personnel of rapid shutdown or load ( reduction:

• Load Coordinator Crew
• Chemistry
• RADCON
• Plant Management MONITOR reactor/turbine trip NOT required USING Appendix A, Reactor and Turbine Trip Criteria.

BOP/RO CHECK VALVE POSITION LIMIT light DARK on EHC panel. [M-2] BOP/RO NOTE: BAT is preferred boration source. Boration volume and flowrates in the following step are recommendations and may be adjusted as necessary. ( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 ( Op Test No.: NRC Scenario # 2 Event # 5&6 Page 15 of 37 Event

Description:

Rapid Shutdown, Emergency Boration Valve Failure Time Position Applicant's Actions or Behavior IF borating from BAT, THEN PERFORM the following:

a. DETERMINE recommended boration volume:

                                    *    -800 gal to reduce power from 100% to 20%

RO/SRO OR

• 10 gal for each 1% power reduction

b. DETERMINE recommended boration flowrate and volume from table below:

TURBINE LOAD BORATION REDUCTION RATE (%Jmin) fLOWRATE { 1% ~15gpm SRO 2% -3:0gpm 3% ~45gpm 4% ~10gpm (SRO discretion may be used to determine reduction rate)

c. PLACE boric acid transfer pump aligned to blender in FAST speed.

RO ADJUST FCV-62-138 to establish desired flow rate. (Valve will not open, RNO required -Appendix D next page) RO INITIATE normal boration USING Appendix D. Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario #

                                           --2      Event #      5&6              Page 16     of   37 Event

Description:

Rapid Shutdown, Emergency Boration Valve Failure Time II Position II Applicant's Actions or Behavior APPENDIX D - NORMAL BORATION PLACE [HS-62-140A] Makeup Control to STOP position. PLACE [HS-62-140B] Makeup mode selector switch in BORATE position. NOTE Boric Acid controller setting is twice the desired flow rate. Maximum Boric Acid flow is -45 gpm. ADJUST [FC-62-139] BA flow controller setpoint for desired flow rate. ADJUST [FQ-62-139] BA integrator (batch counter) to desired boric acid volume. PLACE [HS-62-140A] Makeup Control Switch mode selector switch to START. IF desired boric acid flow rate NOT obtained, THEN ADJUST one or ( both of the following as necessary:

                                    * [FC-62-139] BA flow controller RO

• recirculation valve for BAT aligned to blender.

ENSURE desired boric acid flow indicated on FI-62-139. WHEN required boric acid volume has been added, THEN PERFORM the following:

a. PLACE [HS-62-140A], Makeup Control to STOP position

b. ENSURE [FC-62-142], Primary Water to Blender Flow Controller in AUTO with dial indicator set at 35%.

c. ADJUST [FC-62-139], Boric Acid Flow Controller to desired blend solution USING TI-44 Boron Tables.

d. PLACE [HS-62-140B], Makeup Mode Selector

e. Switch in AUTO position.

f. PLACE [HS-62-140A], Makeup Control to START.

Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5&6 Page 17 of 37 Event

Description:

Rapid Shutdown, Emergency Boration Valve Failure Time II Position II Applicant's Actions or Behavior CONTROL boration flow as required to inject desired boric acid RO volume. INITIATE load reduction as follows:

a. ADJUST load rate to desired value:

• between 1% and 4% per minute if borating via FCV-62-138 OR
• between 1% and 3% per minute if borating via normal boration (App. DJ

b. ADJUST setter for desired power level:

DESI'RED RECOMMENDED RX POWER LEVEL SETTER VALUE ( 90% 70 SRO/RO 80% 60 70~/o 50 60 0/0 40 50% 3.5 40~1Q 30 30% 25 20% or less 15 INITIATE turbine load reduction by depressing GO pushbutton. BOP CONTROL turbine load reduction as necessary to reduce power to desired level. BOP ( Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 18 37 Op Test No.: NRC Scenario # Event # 5&6 Page

                                                                                       -  - of Event

Description:

Rapid Shutdown, Emergency Boration Valve Failure Time 11 Position II Applicant's Actions or Behavior MONITOR T-avg/T-ref mismatch:

a. CHECK T-ref indication AVAILABLE.

ROIBOP (Tref Indication is not available due to PT-1-73 failure) - RNO Required - Next Step) PERFORM the following:

1) MONITOR Program T-avg for current reactor power USING TI-28 Figure A.9 or ICS (NSSS I BOP, Program Reactor Average Temperature).

2) USE program T-avg in place of T-ref.

3) MAINTAIN T-avg within 3°F of program T-avg USING manual rod control.

ROIBOP (

4) ADJUST turbine load rate as necessary.

5) IF mismatch between T-avg and program value CANNOT be maintained less than 5°F, THEN TRIP the reactor and GO TO E-O, Reactor Trip or Safety Injection.

STOP secondary plant equipment USING Appendix B, Secondary Plant Equipment. BOP MONITOR control rods above low-low insertion limit USING ICS or COLR. RO Evaluator Note: Additional AOP-C.03 Steps not included as required power change should be complete at or around this step. When desired, the Lead Examiner may cue the next event. Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, &9 Event

Description:

    #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time A licant's Actions or Behavior Console Operator: Increase SGTR to 8.6 severity (400 gpm) with 300 second ramp. Fail Pressurizer loop 2 spray valve full open after it has been fully opened for RCS depressurization in E-3. Indications Available: Steam Generator tube Rupture:

• Pressurizer pressure decreasing
• Pressurizer level decreasing and charging flow increasing
• Loop 1 Main Steam Line Rad Monitor Increasing AFW Pump 1A auto Start Failure:
• Pump Not running with 51 Signal present Pressurizer Spray valve failed open:

(

• Red Control panel light lit with 0 controller demand
• Pressurizer Pressure Stable or slightly decreasing Direct Manual Reactor trip and Safety Injection based on loss of pressurizer level imminent from AOP-R.01 Step 1 RNO.

As time allows, may also perform the following as directed by SRO same RNO:

• start additionsl CCP
• isolate letdown Manually Trip Reactor and initiate SI.

RO Enter and Direct performance of E-O, Reactor Trip Or Safety SRO Injection. ( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 20 of 37 ( Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position II Applicant's Actions or Behavior NOTE 1: Steps 1 through 4 are immediate action steps. NOTE 2: This procedure has a foldout page. Evaluator Note: AFW Pump 1A auto start failure should be identified and pump started during performance of prudent operator actions immediately following performance of Immediate Operator Actions. VERIFY reador TRIPPED:

• Reactor trip break&ts OPEN

                                   .. Reactor trip bypass breakers DISCONNECTED or OPEN

( RO

• Rod bottom lights LIT

                                   .. Rod position indicators less than or equal to 12 steps.
                                   .. Neutron ftux DROPPING VERIFY turbine TRIPPED:

BOP

                                   .. Turbine stop valves CLOSED.

VERIFYat leastone train of shutdown BOP boards ENERGIZED, DETERMINE ifSlaciuated: RO .. ECCS pumps RUNNING,

                                 .. Any 81 alarm LIT [M,.,4DJ, Appendix 0                                                                  NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 21 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

I Time I Position I Applicant's Actions or Behavior Evaluator Note: If not previously Identified, AFW Pump 1A auto start failure should be identified during performance ES-0.5. When Identified, the pump should be immediately started. PERFORM E~O.5! Equipment Verifications VVtU LE continuing in this BOP procedure, (ES-0.5 At end of Scenario) DETERMINE if secondary heat sink available: a, CHECK total AFW flOvv gt'estertlan 440 gpm.

b. CH,ECK narrow range lev~

BOP greaterthan 10% [25% ADV] in at least one S/G. C. CONTROl feed flow to maIntain narrow r.ange level between 10% [25% ADV] and 50% in intact Of ruptured 8/Gs. CHECK if main steam lines should be isolated:

a. CHECK if any of the following conditions have occurr&d;

• Any SlG pressure less than 600 psig.

BOP/RO OR

• Any SiG pressure dropping UNCONTROLLED.

OR Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 22 of 37 ( Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position II Applicant's Actions or Behavior CHECK RCP trip criteria:

a. CHECK the following:

• RCS preS$ure RO less than 1250 psig AND
• At least ona COP OR 81 pump RUNNING.

MONnOR RCS temperatures:

                                  -IF any Rep running, RO                  THEN CHECK T..avg stable at Of trending

( to betwaen 547 tiF and 552~F. (If No Perform RNO) (RNO) IF tem perature less than 547°F and dropping, THEN PeRfORM the following:

a. ENSURE steam dumps and atmospheric relIefS Cl.OSED.

RO/SOP

b. IF cooldown continues t THEN CONTROL total med flow USING EA~3-8. Manual Control ofAFWFlow, (AFW Flow to Ruptured SIG #1 may be isolated during performance of EA-3-B. Level should be >10%)

Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 23 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, przr spray Valve fails open.

Time I Position II Applicant's Actions or Behavior CHECK prElssuriz.er PORVs, safeties, and spray valves: a, Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED, RO e, Normal sprayvalves CLOSED, d, Powerto at least one block vaive AVA1LABLE.,

e. At. ~a.st one block valve OPEN.

DETERMINE if SlG secondary pressure boundaries are INTACT:

• CHECK atl SIG pressures BOP CONTROLLED or RISING.

(

• CHeCK all S/G pressures greaterthan 140 psi;,

DETERMINE if BIG tubes 'are INTACT:

a. CH.ECK the following:

• all SIG narrow range levels CONTROLLED or DROPPING BOP

                                      .seoondary radiation NORMAL USING AppendiX A,$eeondary RadMonitors.. {App. A is also contained in ES-O.5).

(Crew will Transition to £-3 at this Step) Enter and direct performance of E-3 Steam Generator Tube SRO rupture. MONITORat leut one Rep RUNNING, RO Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 24 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position II Applicant's Actions or Behavior MONITOR Rep trip criteria:

a. CHECKthe following:

• ReS pressureless than 1250 psig RO AND IF At least one CCP OR SI pump RUNNING.

MONITOR indications of Ruptured SlG(s):

a. IDENTIFY Ruptured SJG(s) as indicated by any of the follOWing:

• Unexpected rise in any SJG

( narrow range level. OR

                                     .. High radiation from any SIG BOP sample.

OR

• MCCON survey Qf main steam fines and SIG ~ Unes.

                                      .. High radiation 00 anymain steamlfne radiation monitor.

( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 25 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position II Aoolicant's Actions or Behavior CAUTION Isolating both steam supplieltothe TO AFW pump when it is the only scums of feed now wUI result in loss Ofsecondary heat sink. Critical ISOLATE flOw from Ruptured SlG(s}: Task 1 - Part 1 a, ADJUST Ruptured SIG(5) atmospheric relief controller setpoint to 87% in AUTO. (1040 psig) b.CHECK Ruptured SlG(s) almo$'pheric relief hand switch in P..AUTO andvalve(s) CLOSeD.

c. CLOSE TO AFW pump steam suPPly from Ruptured SlG FCV~1 ..15 (81<3#1) or BOP FCV-1..16 {OO #4},

(Realigning TDAFW to S/G #4 not required since TDAFW pump is Tagged out of service)

d. VERIFY Ruptured SlG(s) blowdawn isolation valves CLOSED.

e. CLOSE RU,pWred SIG{s) MSIV and MSIVbypass valve. .

(Crew will close Loop #1 MSIV) Critical Task: Prior to Initiation of RCS Cooldown to Target Temperature. CAUTION Feeding a SlG that Is Faulted and Ruptured increases the potential for an uncontroiledRCS cooldown and SlG overfill. This option sbould NOT be considered UNlESS needed forRCS cooldovm. ( Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 26 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position II Applicant's Actions or Behavior I I Critical MONITOR Ruptured S/O(.s) l&Vel: Task 1 - Part 2 CI. CHECK narrow range Jevel greaterthan 1'0% (25% ADV].

b. WHEN ruptured SlG lwei is greater than 10% 125% A.DV],

THEN

                                      'PERFORM the following:

BOP

1) STOP feed flew to ruptured $/G.

2:) ENSURE Tutb&na Driven AFW Lev for ruptured SlG In CLOSE PULL TO LOCK. (Crew will isolate or verify isolated AFW to Loop 1 S/G) Critical Task: Prior to Initiation of RCS Cooldown to Target Temperature. VER1FY Ruptured SlG ISOLATED from IntactSlG(s):

a. CHECK either of tha following conditions SATISFIED:

• Ruptured SlG MSiVsand MSIVbypass valves CLOSED OR BOP
• MSlV{s) and MSIV bypass valve(s)

CLOSED on Intact 8/G(s) to be used for ReS cooldown.

b. CHECK SIG #1 or SlG #4 ruptured.

c. CHECKTOA.FW pump steam supply fromruptured SIS ISOlATED:

• FCV-1-15 (SlG#1) or FCV~1*16 (SIG#4) CLOSeD

( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: Scenario # Event # NRC 7,8, & 9 Page 27 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position II Applicant's Actions or Behavior CHECK Ruptured SIG pressure BOP greater than 550 p$ig UJnit t) or 425 pslg (YOU)* Determine Target Temperature using table on next page. SRO ( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 28 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time Position II Applicant's Actions or Behavior NOTE . BIOOklng loW steamline pressure Sl as soon as pressurizer pressure is lessthan 1960 psigwil prevent an inadvertent MSIV closure and keep the condenser available for stearn dump.

               . After the low stea,mline pressure SI signal is blocked, main steamiine isolation wm occur if the high steam pressure rate setpoint is exceeded.

• The 1250 ps,ig Rep mp criterion is NOT applj,cable after RCS cooldown is initiated in the fOiIONlng step.

INITIATE RCS cooldown:

8. DETER" INE target core exit TIC temperature, based on Ruptured SlG pressure:

Lowett Ruptured Target Core Exit ( SIG pressure {psig} TIC Temp (oF) 1 100 or greater 497 1050 1099- 492 1000 1049- 486 950 999~ 480 900 949- 473 S!30 -S99 467 600 <iii 849 460 750 799- 453 700 749- 445 650 -- 699 437 600 . 649 4,28 550 599- 41 9 500 """ 549 410 450 499- 399 425 -449 393 Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 29 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position I Applicant's Actions or Behavior

b. WHEN RCS prMisure less than 1960 pmg, THEN PERFORM the following:

BOP

1) BLOCK low steamline pressure 51,

2) CHECKSTEAMUNE: PR.ESS ISOUSI BLOCK RAT5. ISOL ENABLE: parmisstve UT,

[M-4A, A4)

e. DUMP steam to condenser from IntactSIG(s) at maximum achievabf'e rate:

1) CHECKcondenser available:

(

• e.g condenser interlock permissive UT. (M-4A,. EGl
• Intad: SlG MSIVs OPEN.

2) PLACE steam dumps in OFF,

3) ENSURE steam dumps in steam pressure mode BOP with demand tess tMn 25*%.

4) PLACE sk1am dumps in ON,

5) ADJUST steam dump demand to FULLY OPEN three cooldoYm valves.

G) WHEN T-avgis lea than 540cF, THEN BYPASS steam, dump interlock.

7) RAISE AFWflow to intact SlGs as necessary to supportcooIdown, Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 30 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position II Applicant's Actions or Behavior d, WHEN core exit TICs less than targettemperature determined in Substep B,a, THEN PERFORM the. fofJowing;

1) CLOSE sleam dumps or SlG atmospheric reliefs to stop cooIdown, BOP

2) REDUCE AFW flow as necessary to stop oooldown.

MAINTAIN total1eed flow greater than 440 gpm UNTIL laval greaterthan 10%[25% ADV] in at least one Intact GIG. (

3) MAINTAIN core exit T!Cs less th~ln target temperature USING steam dumpsor atmospheric reliefs.

MAINTAIN rntactSlG narrow range levels: BOP

a. Greater than 10% (25% ADV]

b. Between 200/0 [25% AOV) and 50%.

CAUTION Any time a pressurizer PORV opens t 'tIleN is a possibility that it ma.y stiCk open. MONITOR pressurizer PORVs andblock valves: RO a. Power to block valves AVAILABLE

b. Pressurizer PORVs CLOSED

e. At leas,t one blockvalveOPEN.

RO RESET SI signal. MONITOR. AC bussesenergimd BOP from startbusses. Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 ( Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 31 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position II Applicant's Actions or Behavior RO ENSURE Phase A and Phase B RESET. CHICK control air established to containment [Pa~1 6K and aLl

• 1~FCV-32..so (2-FCV,.32--81)

Train A essential air OpeN RO

• 1..FCV..s2-102 (2-FCV..32..103)

Train B essential air OPEN

• 1..FCV-32;.110 (2-FCV~32~ 111) non-ess$Otial air OPEN.

DETERMINE if RHR pumps should be stO~d:

a. CHECK RHR pump suction algned from RWSr.

(

b. CHECK RCSpressure RO greater than 300 psig.

e. STOP RHR pumps and PLA.CE in A-AUTO.

d. MONITOR RCS pressure greater than 300 psig.

Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 32 of 37 ( Event

Description:

     #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

I Time II Positi Applicant's Actions or Behavior Critical CHECK if ReS cooldown Task 2 should be slopped:

a. CHECK coree exitTICs le$$1ha1'l target temperature d~ined in SUbstep a,a, DO NOT CONTiNUEthis procedure UNTIL core exit TlOs less thantarget temperature.

b. CLOSE steam dumps or atmoSpheric reliefs to stop cooIdown.

BOP c. REDUCEAFW flow as necessary to stop cooldown. MAINTAIN totalfaed flow ( greater than 440 gpm UNTlllevel greaterthan 10% [25%AD\'] in at least one Intact. stG,

d. MAINTAIN core exit TICs less tha1'l target temperature USING steam dumps or atmospheric reliefs.

Critical Task: Prior to RCS Depressurization. CHECK Ruptured S/G(s) pressure BOP STABLE or R.ISING~ CHECK RCS subcooling based on core RO exit T<<>> girea!erthan eOG F. Console Operator Note: When loop 2 spray valve is completely open in next step, insert malfunction to fail Loop 2 spray valve full open (Key 6). Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 33 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

I Time I Position II Applicant's Actions or Behavior Critical DEPRESSURIZE ReSto minimize break Task 3 floW and to refill pressurizer. a, CHECK normal pressurizer spray AVA.ILABLE.

b. INlnATE maximum available pressurizer spray.

c.. CHECK depressuri2stiion rate ADEQUATE,

d. CONTINUE depressurization UNTIL any of the following conditions SATISFIED:

• Both of the folowing:

1) ReS pressure

( less than Ruptured SJG(s) pressure RO AND

2) Pressurizer level greaterthan 10% [20% ADV],

OR

                                        .?ressurizer level greater than 65%.

OR

• ReS subcooUng based on core exitTICs less than 4O"F.

e. CLOSe spray valve(s):

1) Normal spray valves.

(RNO since spray valve will not close - Next Page) Critical Task: Prior to S/G Overfill Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7,8, & 9 Page 34 of 37 Event

Description:

      #1 S/G Tube Rupture, AFW Pump 1A Auto start fail, Przr spray Valve fails open.

Time II Position II Applicant's Actions or Behavior (RNO)

1) STOP Reps #1 and 2.

RO IF ReS pressure continues todrop, THEN STOP additional Rep as necessary. Scenario may be terminated when crew has completed ReS cooldown and depressurization at lead examiner discretion. ( Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # ES-O.5 Page 35 of 37 Event

Description:

Equipment Verifications I Time II Position II Applicant's Actions or Behavior I ES-O.5 Actions CHECK ERCW system operation: BOP

• VERIFY at least four ERCW pumps RUNNING.
• VERIFY DIG ERCW supply valves OPEN.

VERIFY CCS pumps RUNNING:

• Pump 1A-A (2A-A)

BOP

• Pump 1B-B (2B-B)
• Pump C-S.

VERIFY EGTS fans RUNNING. BOP VERIFY generator breakers OPEN. ( BOP VERIFY AFW pumps RUNNING:

• MD AFW pumps BOP
• TD AFW pump.

(If Not previously identified and started, 1A-A MDAFW pump start failure should be identified during performance of this step and pump immediately started) Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # ES-O.5 Page 36 of 37 Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control S/G levels, to establish flow due to failure, or to isolate a faulted S/G. CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

b. VERIFY TO AFW LCVs OPEN.

BOP

c. VERIFY MD AFW pump recirculation valves FCV-3-400 and FCV-3-401 CLOSED.

VERIFY MFW Isolation:

• MFW pumps TRIPPED
• MFW regulating valves CLOSED BOP
• MFW regulating bypass valve controller outputs ZERO
• MFW isolation valves CLOSED

(

• MFW flow ZERO.

MONITOR ECCS operation: VERIFY ECCS pumps RUNNING: BOP

• CCPs
• RHR pumps
• SI pumps
• VERIFY CCP flow through CCPIT.
• CHECK RCS pressure less than 1500 psig.

BOP

• VERIFY SI pump flow.
• CHECK RCS pressure less than 300 psig.
• VERIFY RHR pump flow.

VERIFY ESF systems ALIGNED:

• Phase A ACTUATED:

BOP 0 CONTAINMENT ISOLATION PHASE A TRAIN A alarm LIT [M-6C, B5]. 0 CONTAINMENT ISOLATION PHASE A TRAIN B alarm LIT [M-6C, B6). Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # ES-O.5 Page 37 of 37 ( Event

Description:

Equipment Verifications Time II Position II Aoolicant's Actions or Behavior

• Containment Ventilation Isolation ACTUATED:

0 CONTAINMENT VENTILATION ISOLATION TRAIN A alarm LIT [M-6C, C5]. 0 CONTAINMENT VENTILATION ISOLATION TRAIN B alarm LIT [M-6C, C6].

• Status monitor panels:

0 6C DARK 0 60 DARK 0 6E LIT OUTSIDE outlined area 0 6H DARK 0 6J LIT.

• Train A status panel 6K:

0 CNTMT VENT GREEN 0 PHASE A GREEN (

• Train B status panel 6L:

0 CNTMT VENT GREEN 0 PHASE A GREEN MONITOR containment spray NOT required:

• Phase B NOT ACTUATED AND BOP
• Containment pressure less than 2.81 psig
• Ensure Containment Spray is actuated VERIFY pocket sump pumps STOPPED: [M-15, upper left corner]
• HS-77-410, Rx Bldg Aux Floor and Equipment Drain BOP Sump pump A
• HS-77-411, Rx Bldg Aux Floor and Equipment Drain Sump pump B.

DISPATCH personnel to perform EA-0-1, Equipment Checks Following ESF Actuation. BOP ( Appendix 0 NUREG 1021 Revision 9

SHIFT TURNOVER CHECKLIST Page 1 of 3 Today 0 SM 0 US/MCR Unit 1 0 UO Unit 1 Off-going - Name 0 AUO Station SQN 0 STA (STA Function) AUO Comp Actions On-coming - Name Part 1 - Completed by Off-going Shift/Reviewed by On-coming Shift: Abnormal Eauioment Lineuo/Conditions:

                                       .~/1JVl ~~/fiJ/~Xfil/~1£iJi~~.~fTj~~fi)~~~~~-~~fi)~~                   s TrainA Week

• All Equipment normal
• TDAFW pump was tagged 2 hours ago for repair to the T&T valve. The packing was blowing excessively. Expected Return to service is 8 hours. (WO 07-080025-000 Total 0.03 gpm I Identified 0.02gpm I Unidentified 0.01 gpm. (Today 0600)

(

SHIFT TURNOVER CHECKLIST Page 2 of 3 Today 31ITest in Progress/Planned: (Including Need for New Brief) Daily and Shiftly Sis per work schedule Major Activities/Procedures in Progress/Planned: None Radiological Changes in Plant During Shift: None TS LCO 3.7.1.2.a: TDAFW pump was tagged 2 hours ago for repair to the T&T valve. The packing was blowing excessively. Expected Return to service is 8 hours. TS 3.3.3. 7.18b action 1; Accident Monitoring Instrumentation, ERCW to AFW Valve Position, Turbine Driven Pump. Part 2 - Performed by on-coming shift D Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's) D Review of Rounds Sheets/Abnormal Readings (AUO's only) ( Review the Following Programs for Changes Since Last Shift Turnover: D Standing Orders D LCO(s) in Actions (N/A for AUOs) D Immediate Required Reading D TACF (N/A for AUO's) Part 3 - Performed by both off-going and on-coming shift D Walkdown of MCR Control Boards (N/A for AUO's) Relief Time: Relief Date: today TVA 40741 [03-2001] OPDP-1-1 [03-14-2001

SHIFT TURNOVER CHECKLIST Page 3 of 3 Today Disabled Annunciators PANEL WINDOW ANNUNCIATOR WO I PER Number Equipment Off-Normal (Pink Tags) UNID And Noun Name Panel Problem Description WO I PER Number MCRWO List ID And Noun Name Panel Problem Description WOlPER Number (

UNIT ONE REACTIVITY BRIEF Date: Today Time: Now ( RCS Boron: 1093 ppm Today I BA Controller Setpoint: 27%

• I RCS B-10 Depletion: 2 ppm Operable BAT: A I BAT A Boron: 6850 ppm I BAT C Boron: 6850 ppm I RWST Boron: 2601 ppm Nominal Gallons per rod step from 219: 7 gallons of acid, 36 gallons of water
• Verify boric acid flow controller is set at Adjusted SA Controller Setting iaw 0-SO-62-7 section 5.1 Gallons of acid: 26 Gallons of water: 138 Rod Steps: 4 Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 198 Steps on bank D 101 gallons 30% 174 Steps on bank D 295 gallons 50% 152 Steps on bank D 485 gallons

     ** These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power

( operation only. Engineering data last updated one week ago. Data Valid until one week from now. Number of dilutions: 0*** Number of borations: a Rod steps in: a Gallons per dilution: a Gallons per boration: a Rod steps out: a Total amount diluted: a Total amount borated: a Net change: a IN/Out Number of dilutions: a Number of borations: a Rod steps in: a Gallons per dilution: a Gallons per boration: a Rod steps out: a Total expected dilution: a Total expected boration: a Net change: a In/Out Remarks: Rx Power - 100% MWD/MTU - 1000 Xenon & Samarium at Equilibrium

                    ***The boron letdown curve is flat for the next 25 EFPD.

Next Unit 1 Flux Map is scheduled - three weeks from now Unit Supervisor: _ Name/Date (

2.18-2.48 2.33 Indicator Units U1 Date / Time U2 Date/Time SI 50 S/G Leakage? Yes/No No Today 1 Now No Today 1 Now SI 137.5 eVE Leakrate gpd < 0.1 Today 1 Now < 0.1 Today 1 Now 5 gpd leak equivalent cpm 380 Today 1 Now 68 Today 1 Now 30 gpd leak equivalent cpm 1980 Today 1 Now 83 Today 1 Now 50 gpd leak equivalent cpm 3250 Today 1 Now 206 Today 1 Now 75 gpd leak equivalent cpm 4850 Today 1 Now 455 Today 1 Now 150 gpd leak equivalent cpm 9750 Today 1 Now 870 Today 1 Now eVE Air Inleakage cfm 10 Today 1 Now 12.5 Today 1 Now Bkgd on 99/119 cfm 50 Today 1 Now 40 Today 1 Now

I Appendix D Scenario Outline Form ES-D-1 I Facility: Sequoyah Scenario No.: 3 Op Test No.: NRC Examiners: Operators: Initial Conditions: -2% Reactor Power, A Main Feedwater Pump liS Turnover: Continue Plant Startup. Currently at O-GO-4 Section 5.2 Step 3. Target CTs: Establish at least one train of containment spray prior to completing FR-Z.1 Manually align one train of RHR for Containment Sump Recirculation and Establish ECCS flow prior to Degraded Core Cooling Conditions. Event Malf. No. Event Type* Event Description No. 1 N/A R-ATC Continue Power Increase from -2%. N-SRO/BOP 2 CN01B C-SRO/BOP Trip one of two running hotwell pumps. Standby pump should be ( started. 3 RX07A TS-SRO Controlling Pressurizer Pressure Channel Fails High. Przr spray I-SRO/ATC valves Open and require manual action to close. Tech spec Evaluation. 4 RX02A2 TS-SRO RTD COLD LEG 1 SENSOR 2 fails high. Requires manual action to defeat the channel. Tech Spec evaluation. I-SRO/ATC 5 TH01B C-AII Small RCS Leak -21 gpm in Loop 2 Hot leg. 6 TH01B M-AII RCS Leak increase to Break requires Rx trip and Safety Injection. N/A TH01B N/A Following Transition to E-1 RCS Break Increases to large break LOCA to expedite Containment Sump Swapover. 7 RP13C C-SRO/BOP Automatic Feedwater Isolation fails on both trains requiring manual isolation. 8 RP16K644A C-SRO/ATC Both containment spray discharge valves fail to Auto open on Hi-Hi Containment pressure signal requiring manual action to open. RP16K644B Train B Spray valve will not manually open ZDIHS722A 1B Containment Air Return fan Overcurrent trip on Start. CH08B 9 ZDIHS6372 C-SRO/ATC RHR suction valve FCV-63-72 from containment Sump will not A open. This requires stopping the RHR Pump on the affected train and aligning sump recirculation and ECCS injection on one train of RHR.

        *   (N)ormal,    (R)eactivity,  (I)nstru ment,   (C)omponent,     (M)ajor Appendix 0                                                                          NUREG 1021 Revision 9

I Appendix 0 Scenario Outline Form ES-D-1 I Scenario 3 Summary The crew will assume shift at approximately 2% reactor power with first Main feedwater pump in service and continue a power increase. During the power increase one of the two running hotwell pumps will trip requiring the crew to perform the associated AOP and place the third non-operating hotwell pump in service. The power increase should continue. Following an adequate power increase to demonstrate proficiency, the controlling pressurizer pressure channel will fail high resulting in pressurizer spray valves fully opening and requiring manual action to close them and stop the RCS depressurization. The SRO will direct performance of AOP to select another controlling channel and return spray control to automatic. SRO will evaluate and enter applicable Reactor Protection and ESFAS instrumentation Technical specifications. When pressurizer pressure instrument actions are complete, a cold leg RTD on loop 1 will fail high, this will cause the Tavg channel for loop 1 to be high and Delta T channel to be low. Tavg and Delta control inputs will be defeated by AOP performance and protection channel inputs will require Technical Specification entries. SRO will evaluate and enter applicable Technical specifications. A small unisolable RCS leak will occur of approximately 21gpm. Crew will attempt actions to isolate leak using AOP. Following determination that the leak is not isolated the Leak will be increased to a Large Break requiring Reactor Trip and Safety Injection. Following Transition to E-1, RCS break will be further increased to a large Break LOCA to expedite reaching RHR containment sump swapover. Following the Rx Trip and Safety Injection, Automatic Feedwater Isolation will fail requiring manual isolation. Upon reaching the Hi Hi containment pressure setpoint, containment spray pumps will start but their discharge valves will not open requiring manual action to initiate containment spray. Train A spray valve will open manually but B Train will not. 1B containment Air return fan will trip on Overcurrent when starting 10 minutes after Phase B. B train spray valve and 1B Air return fan failure ensure containment pressure ( remains high enough to require crew to perform FR-Z.1. The Crew will continue through the E procedures including FR-Z.1 contingency procedure for Hi containment pressure and eventually reach the setpoints for RHR suction to containments sump realignment. One of the containment sump supply valves fails to open automatically or manually and require the crew to stop the affected RHR pump and realign only one train of RHR suction to containment sump. If a setpoint for containment spray realignment to containment sump is reached, only one train of containment spray can be aligned to the containment sump, however, the discharge valve on that train will not open which results in no containment spray capability. The scenario may be terminated after ECCS is aligned for RHR sump recirculation using one train of RHR Appendix 0 NUREG 1021 Revision 9

o RWST  :

                                                                                                                                                             *L*.** **....*.,
                             .-           ---   ----     --   ---                      __    _-_   __      __    _-_   _-_ __ ._------_   ------ ..-------------_      _-"T LCVy'"        LCV  ~*.*** 11               LCV 62-132 ... LJ 62-135   LJ          ~ 62.136 62.133f LCV~               l  j ........ __ :
                                                                                                         ,               ~           :

FCV:

                                                                                                                                                                           ~-_ ..----- .....
                                .......~Charging                                                       ! '
                                                                                                                         ,4-::.       i
                                                                                                                                     ,,                            FCV I
                                                                                                         '                        ).;'~-

FCV 74*3 FCV --- ..------------ 63*7 , tf.r-.

                                                                                           ;!?:
                                                                                          ~~

U. RHR FCV 74-21 L.I../ Iu

__FCV*63-5

Page 1 of 2 NRC08C Rev 0 CONSOLE OPERATOR INSTRUCTIONS Sim. Setup Reset IC- _9_ Initialize simulator at -2% % RTP BOL. Perform switch check. Allow the simulator to run for at least 3 minutes Place Mode.-l....placard on panels. before loading SCEN file or starting the exercise. This will initialize ICS. Place....A-Train Week sign on the simulator. Load SCENS: NRC08C Ensure 1 Power Range and 1 Intermediate Range are selected for display on M-4 NIS Recorder NR-Place simulator momentarily in RUN, 45. Place OOS equipment in required position with tags, Clear alarms and Return to FREEZE. Event #1: Increase -2% POWER CONTINUE PLANT STARTUP. Power as determined by NRC Examiner. Event #2: When IMF CN01B f:1 k:1 HOTWELL PUMP B TRIP Power had been Increased -2% - 3% When the Support US/AUO are dispatched to or as determined by investigate, wait - 5 min. and report that the relay NRC Examiner, Insert target is instantaneous overcurrent and the this Malfuinction using motor smells hot. ( '(ey 1 Event #3: When IMF RX07A f:1 k:2 CONTROLLING PZR PRESSURE TRANSMITTER determined by NRC PT 68-340 FAILS HIGH Examiner, Insert this Malfuinction using When IMs or MSS contacted to trip bistables, Key 2 inform the crew that the IMs will report to the MCR in - 45 minutes. Event #4: When IMF RX02A2 f:630 k:3 RTD FAILURE COLD LEG 1 SENSOR 2 Determined by NRC Examiner, insert this When IMs or MSS contacted to trip bistables, Malfunction using inform the crew that the IMs will report to the Key 3. MCR in - 45 minutes. Event #5: When IMF TH01 B f:0.0025 k:4 LOOP 2 RCS HOT LEG LEAK -21 GPM. Determined by NRC Examiner, insert this Malfunction using Key 4. Event #6: When MMF TH01 B f:5 r:300 INCREASE LOOP 2 RCS HOT LEG LEAK TO Crew has evaluated BREAK OVER 5 MIN TO REQUIRE REACTOR TRIP whether leak is AND SAFETY INJECTION. isolated (Step 12 AOP-R.05), Modify this Malfunction at

   \lRC Lead Examiner I discretion.

Page 2 of 2 NRC08C Rev 0 CONSOLE OPERATOR INSTRUCTIONS Following Transition MMF TH01 B f:35 INCREASE LOOP 2 RCS HOT LEG BREAK TO to E-1, Modify Hot leg LARGE BREAK. Break size again to expedite sump swapover. Event #7: This IMF RP13C f:1 FAILURE OF THE AUTO FEEDWATER ISOLATION Malfunction is active SIGNAL - BOTH TRAINS. when the SCENS file is loaded. Event #8: These IMF RP16K644A f:1 1A-A CNTMT SPRAY VALVE, FCV-72-39, FAILS TO Malfunctions are AUTO OPEN ON HI HI CONTAINMENT PRESSURE active when the SIGNAL. WILL MANUALLY OPEN. SCENS file is loaded. IMF RP16K644B f:1 1B-B CNTMT SPRAY VALVE, FCV-72-2, FAILS TO AUTO OPEN ON HI HI CONTAINMENT PRESSURE SIGNAL. WILL MANUALLY OPEN. lOR ZDIHS722A f:O TRAIN B CONTAINMENT SPRAY VALVE WILL NOT OPEN MANUALLY. ( IMF CH08B f:1 AIR RETURN FAN 1B TRIP ON OVERCURRENT WHEN STARTED. (10 MINUTES AFTER PHASE B) If dispatched to check ARF breaker, wait -5 min and report overcurret trip. Event #9: This lOR ZDIHS6372A f:O TRAIN A RHR SUMP SWAPOVER VALVE FCV Malfunction is active 72 FAILS CLOSED. when the SCENS file is loaded. When Requested to IRF RHR14 f:1 k:5 RWST TO RHR PMP FLOW CNTL VLV POWER, place power on FCV- FCV-63-1. 63-1 insert this remote function using KeyS

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # Page 1 of 46

                                                             ---'----                         ------II Event

Description:

Power increase Time II Position I Applicant's Actions or Behavior Console Operator: No action required for event 1 Indications Available: None Applicable Direct load increase in accordance with 0-GO-4 Section 5.2, SRO Step 3. Reactor Power Ascension To Between 13% And 15% RTP. NOTES

1. Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements shall be adhered to for reactivity changes (l.e, reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized during performance.

2. Recommended dilution rate is 50 to 75 gallon batches every 12 to 15 minutes for a

( steady power increase. Rod movement should be limited to 1/2 step increments approximately every 1 1/2 minutes. Dilution and rod movement rates may be adjusted depending on SG level control stability.

3. Control Rod withdrawal and / or dilution requirements may be significantly impacted by the change in core reactivity due to changing Xenon concentration.

INITIATE a methodical and deliberate reactor power increase CREW by manual adjustment of the control banks or by diluting the RCS. WHEN reactor power is above 5%, THEN LOG Mode 1 entry in CREW the Unit Narrative LOQ. MAINTAIN the SG levels on program by periodically adjusting CRO the feedwater bypass reg controller level setpoints using Appendix Band C. Evaluator Note: The following Steps are from 0-SO-62-7 Boron Concentration Control, Section 6.2, Dilute

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # Page 2 of 46

                                                               -.;..----                           ....;.;;,....-~I Event

Description:

Power increase Time II Position II Applicant's Actions or Behavior CAUTION 1: When making an RCS dilution of L3000 gallons, it should be done in batches with an RCS boron concentration verification at the halfway point (e.g., 1500 gallons). Allow at least 15 minutes between batches. CAUTION 2; Returning the Boric Acid Blender to service after unplugging, cleaning, or maintenance on the Boric Acid System could introduce debris, sludge, air or chunks of solidified boron into the CCP suction resulting in pump damage. Extreme care must be exercised to properly flush the Boric Acid Blender system following an outage. NOTE 1: If an excessive amount of dilution is required (plant startup), the pressurizer heaters should be energized to cause pressurizer spray operation for equalizing boron concentration in RCS and pressurizer. NOTE 2: Dilute mode will be used anytime a long-term positive reactivity addition is desired. The operator should use the normal dilute mode whenever conditions permit. ENSURE unit is NOT in a Tech Spec or TRM action that ( RO prohibits positive reactivity additions. NOTE: HUT level increase of 1% is equal to 1380 gallons (TI-28 fig. C.21) ENSURE sufficIent capacity avaiiabl,e in the HUT selected to receive expecteeamounts of eves letdown: (N/A IT not used) RO HUT lEVEL INITl.ALS A  % B  % ENSURE makeup system is aligned for AUTO operation in RO accordance with Section 5.1. RECORD the quantity of dilution water required to achieve RO desired boron concentration using Appendix D. (N/A for minor power changes) NOTE Due to eyeball interpolation the verified calculation may slightly differ from the initial calculation. The following signoff indicates that any differences in the two results have been discussed and are close enough to be considered validated.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # Page 3 of 46

                                                                 .....;...----                    --';";'~I Event

Description:

Power increase Time II Position I Applicant's Actions or Behavior PERFORM Appendix I Independent Verification of Calculation for Amount of Boric Acid or Primary Water. (N/A if App. D was SRO performed by SRO to verify data from Rx Engineering) (Step not required provided in shift turnover package) PLACE [HS-62-140A], Boric Acid Supply to Blender Flow RO Control Switch to the STOP position. PLACE [HS-62-140B], CVCS Makeup Selector Switch to the RO DILUTE position. ENSURE [HS-62-140D], Boric Acid Valve to the Blender is RO CLOSED (Green light is LIT). RO SET [FQ-62-142], Batch Integrator for the desired quantity. NOTE: Primary Water Flow Controller [FC-62-142] receives its reference signal (70 gpm) from setpoint potentiometer (dial indicator) located on panel M-6. A setpoint of 35% corresponds to a 70 gpm primary water flow rate. ( ADJUST [FC-62-142], Primary Makeup Water Flow Controller RO for the desired flow rate. PLACE [HS-62-140A], Boric Acid Supply to Blender Flow RO Control Switch to the START position. NOTE: Flow oscillations and/or erratic controller response may require manual operation of Primary Water Flow Controller [FC-62-142] until stable conditions exist. VER~FY the following; RO [a) Inlet to top ofVCT [FCV-6:2-12SJ is OPEN. [b) Primary Water flow by IFMi2-14ZA) OR IFQ..:62-142l NOTE: Alternate dilution in small amounts is acceptable on a regular basis, provided no significant changes in seal water temperature or seal leakoff are indicated. Batches of 5 to 10 gallons may be added through FCV-62-144 on a frequency not to exceed once per 30 minutes. ICS points for NO.1 sealleakoffs and seal water temperatures on the RCPs should be monitored during and after dilution. (.,

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # Page 4 of 46

                                                              .....;...----                    '-;";'---11

( Event

Description:

Power increase Time Position Applicant's Actions or Behavior IF primary water addition to the bottom of the VeT [I=C\I-62-144] Is desired, THEN [a] CLOS:E [Fey-62-128}\iliittl [HS-62-128]. RO [b] OPEN [FCV-62-U4) with [HS-62-M41 [e] VERIFY Primary 'Water {IDev" by [H.62-142A] OR (FQ-62-142]. NOTE: It may take approximately 15 minutes before any changes to reactivity are indicated on nuclear instrumentation or RCS temperature indication. MONITOR nuclear instrumentation and reactor coolant RO temperature to ensure the proper response from dilution. IF [1I-62-129] , Volume Control Tank Level, increases to 63 RO percent, THEN ENSURE [LCV-62-118], Volume Control Tank Divert Valve OPENS to divert excess water to the Holdup Tanks. WHEN dIlution is complete, THEN [a] PLACE [HSc62-140A], Boric Acid to Blender Flow ( Control Switch to the STOP position. [b] IF [FC\L62-1441 was previously OPENED, THEN RO CLOSE [FCV-62-1441 with [HS-62-144). Ee] VERIFY no prima.ry waterflow' on either (H-62-142A] OR (FQ-62-14.2]. Ed] ENSURE [FCY~62-128) is CLOSED. Lead Examiner may direct initiation of the next event at his discretion. Steps on the next two pages are associated with performance of repetitive dilutions or may not be performed until all dilutions are complete.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # ~ Page 5 of 46 Event

Description:

Power increase Time II Position II Applicant's Actions or Behavior RO [17] IF power increase in progress and additional dilutions will be required,THEN use this table to re-perform steps [4] through [1 8]. STEP 1~' 2"~ 3'" [4] RECORD the quantity of dilution water required to achieve desired boron concentration usma Appendix D. ~ ~ ~ [5] PERFORM Appendix I, IV af Cakulation for amount afBA or PW.

                                                                                            ~ ~ ~
    '[6] PLACE [HS-62-140A), Boric Acid Supply to Blender Flow Control S~%'itch to the            f           i         f STOP position.                                                                     ~cv           1it f::i.l 1""C\I

[1] PLACE [HS..;62-1408], eves Makeup Selector Switch to the mLUTE position. 0 0 0 [8] ENSURE [HS-62-140D] Boric Acid Valve to Blender ;1S CLOSED (GreenEght LIT}. 0 0 0 [9] SET [FQ-62-1411, Batch Integrator for the desired quantity.  !  ! f i~ cv i~ CV 7'" Gil [10] ADJUST [fC-fil-141], Primar:'1 Makeup I"Vater Flow Controller for the desired i  ! I now ratR 7' cv 7f'"~v fa W [H] PLACE [H S-li2-140AJ, SA Supply to Blender Flow Control Switch to START. lto; j J f C'lJ' fl~ CV {~  :::tv [12] VERIFY the following: [a] Inlet to top ofVCT [FCV~62-1L8] !SOPEN. D 0 0 [b] Primary Waterflcrw by [R62-142A] or [FQ-62-142]. 0 0 0 ( f13] IF PV.J addition to top of VeT (FCV-6.l-118] 15 not warranted, but PW addition to the bottom oftlle VCT 'rFCV-62-144] is desired, THEN [a] CLOSE [FCV-62-1281'llith [I-1S-62-128] 0 0 0 [h] OPEN [FCV-62-144] with [HS-61-1441. 0 0 0 [c]VERIFY Primary Water ftow by [FI-62-141A] or [Hl-61-142l 0 0 0 [14] MONITOR nuclear instrumentation and reactor coolant temperature to ensure the praper reseense from dilution. D 0 0 [15} IF [U-62-1191 VCT level, increases to 63 percent, THEN ENSURE (lCV-62-118], VCT Divert Valve, OPENS to divert excess water to the HUTs. 0 D 0 [16] WHEN dilution is compJete, THEN  !  ! f [a] PLACE [HS-6L-140Al, Boric Acid to Blender How Control Switch to STOP 7:ev 7 cv T ,cv [h] IF IFCV~62-1441 was previOUSly OPENED, THEN CLOSE [FCV-62-144]

               '¢;,ith [HS-61-144].                                                             0            0          0

[e] VERliFY no primary waterfkrw 00 either [FI-61-142A) or [FQc61-142]. 0 0 0 [d] ENSURE [FCV-61-118] ,1S CLOSED. 0 0 0 [18] IF step [17] wilt be repeated, THEN PERFORM the following: [a] PLACE [HS-62 -14013], eves Makeup Selector SWitch to the AUTO posmon. [13] PLACE [HS-61-140A] , SA to Blender Flow Control SWitcb to START position. [e] ENSURE dilution is fiogged in Ufltt Narrative log.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # .....;... Page 6 of 46 Event

Description:

Power increase Time II Position II Applicant's Actions or Behavior REALIGN the blender controls for AUTO makeup to the RO CVCS in accordance with Section 5.1. RO ENSURE dilution(s) is logged in Unit Narrative Log. NOTE Sample may be obtained at normal RCS sample intervals provided the unit is at power and the unit response following the dilution is as expected. IF RCS boron sample is required, THEN NOTIFY Chem Lab to obtain RCS boron sample. (

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 2 Event

Description:

Trip one of two running hotwell pumps (B Pump) Time II Position Applicant's Actions or Behavior Console Operator: When directed, initiate event 2 Indications available: Motor Tripout alarm Panel M-1 White disagreement light on Hotwell Pump B handswitch. Place failed pump switch in STOP Position. Refer to BOP Annunciator Response Procedure. Enter and direct actions of AOP-S.04, section 2.4. SRO ENSURE two hotwell pumps RUNNING. BOP (Should Start Non-Operating Pump) ( MONITOR Steam generator levels returning to program. [M-4] BOP ENSURE the following conditions:

• Reactor power STABLE CREW
• Turbine load STABLE DISPATCH operator to investigate cause of Hotwell Pump trip.

BOP CAUTION: Reducing turbine load too rapidly could result in further drop in condensate pressure due to reduction in heater drain flow. Recommended load rate is 1% per minute if turbine load reduction is needed. NOTE: Severe MFW pump cavitation is likely if inlet pressure is less than 250 psig.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 2 of 46 Event

Description:

Trip one of two running hotwell pumps (B Pump) Time II Position II Applicant's Actions or Behavior MONITOR Feedwater pump inlet pressure greater than 320 psig. [M-3, PI-2-129] BOP CHECK reactor power greater than 75%. RO NOTE: With only two Hotwell pumps in service at 100% power, cavitation may occur and over time could lead to pump damage. Power reduction to 75% provides margin for additional failures. IF Hotwell Pump cannot be restored within 24 hours, THEN EVALUATE reactor power reduction to less than 75% at 1% per minute USING 0-80-5, Normal Power Operation. NOTIFY Maintenance to investigate and repair pump malfunction as necessary. GO TO appropriate plant procedure. ( Proceed to next event at lead examiners discretion.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 3 of 46 Event

Description:

Controlling Pressurizer Pressure channel Fails High Time Position Applicant's Actions or Behavior Console Operator: When directed, initiate event 3 Indications available: Pressurizer Hi Pressure, Alarm Panel (M-6a, C-S) Pressurizer Pressure above Setpoint ,Alarm Panel (M-SA, B-3) Both Pressurizer spray valves full open. Manually close both spray valves. RO (Immediate Action) SRO Enter and direct actions of AOP-1.04, Section 2.3. NOTE Step 1 is an IMMEDIATE ACTION. CHECK normal spray valves CLOSED. RO ( (RNO) IF RCS pressure is less than 2260 psig, THEN CLOSE affected spray valve(s) USING the following: PIC-68-340A, Master Pressure Controller. OR RO PZR Spray controllers PIC-68-340D (Loop 1) and/or PIC-68-340B (Loop 2). MONITOR pressurizer pressure stable or trending to desired pressure. RO CHECK PI-68-340A NORMAL. RO (RNO)

I Appendix 0 Required Operator Actions Form ES-0-2 I Op Test No.: NRC Scenario # 3 Event # 3 Event

Description:

Controlling Pressurizer Pressure channel Fails High Time II Position II Applicant's Actions or Behavior PERFORM the following:

a. ENSURE PRESS CONTROL SELECTOR switch XS 3400 in PT-68-334 & 323.

b. ENSURE LOOP TAVG T REC/SEL selector switch XS 2B in LOOP 2, 3, or 4.

RO

c. ENSURE PRESS REC CHANNEL SELECTOR XS 340B in PT-68-334, PT-68-323, or PT-68-322.

d. GO TO Caution prior to Step 8.

CAUTION: RCS pressure changes and changes in RCS boron concentration (due to differences between pzr and RCS boron) may cause small change in core reactivity. MONITOR reactor power:

a. CHECK reactor in Mode 1 or 2.

RO b. MONITOR core thermal power for unexpected changes. EVALUATE the following Tech Specs for applicability: (

• 3.2.5 ONB Parameters - (N/A unless RCS press decreased below 2205 psig)
• 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation-(Action 6 applies)

SRO

• 3.3.2.1 (3.3.2), ESF Actuation System Instrumentation -

(Action 17 applies)

• 3.3.3.5 Remote Shutdown Instrumentation - (N/A)
• 3.4.4 Pressurizer Heaters (may be applicable while heaters are unavailable due to instrument failure) - (N/A)

CHECK PZR PRESS and PZR SPRAY controllers in AUTO. RO (RNO) WHEN malfunction has been identified AND isolated or corrected, THEN PERFORM the following:

a. ENSURE Master Pzr Pressure Controller PIC-68-340A Output Percent Meter is less than 40%.

RO

b. ENSURE PZR PRESS Controller, PZR SPRAY controller, and PZR HTRS in AUTO.

NOTE: If performing AOP in conjunction with AOP-1.11 for an Eagle LCP failure, then actions to hard trip bistables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours UNLESS affected loop is

  . restored to operable status by resetting Eagle rack.

(

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 3 of 46 Event

Description:

Controlling Pressurizer Pressure channel Fails High Time II Position Applicant's Actions or Behavior REMOVE failed pressurizer pressure channel from service: SRO CHECK any pressurizer pressure channel INOPERABLE. RO CHECK OT~T setpoint on affected channel NORMAL. RO (RNO) GO TO Substep t t.d. IF any of the following conditions exists:

• transmitter signal failed (entire instrument loop affected including OT~ T pressure input)

OR SRO

• OT~T pressure input potentially affected or status CANNOT be determined, THEN PERFORM applicable appendix:

PZR PRESSURE CHANNEL APPENDIX

                                          ~NSTRUMENT

( P-68-340 (P-455) I A SRO P-68-334 (P-456) Iii B P-68-323 (P-457] nl C P-68-322 (P-458) IV o GO TO appropriate plant procedure. SRO If Tech Specs have been evaluated, Proceed to next event at lead examiners discretion. (

Appendix D Required Operator Actions Form ES-D-2 ( Op Test No.: NRC Scenario # 3 Event # 4 Page 12 of 46 Event

Description:

RTD failure Cold Leg Loop 1 Sensor #2 Fail High. Time II Position II Applicant's Actions or Behavior Console Operator: When directed, initiate Event 4 Indications available: Alarm "Narrow Range RTD failure Loop 1" (Panel XA-55 5A, D-6) Alarm "TS-68-2D Reac Cool Loops Overtemp 11T Trip Alert" (Panel XA-55 6A, A-2) Loop 1 Tavg indicating HI and Loop 1 11T Indicating Low (Panel M-5) RO Refer to Annunciator Response Procedure Enter and direct Actions of AOP-1.02 SRO PLACE rod control in MANUAL. RO (N/A Rods already in Manual at 2% Power) CAUTION: Control rods should NOT be manually withdrawn during a plant transient. RESTORE Tavg within 1.5°F of Tref USING one of the following:

• manual rod control OR SRO
• RCS boration/dilution OR
• turbine load reduction (Step is N/A since Tref not available with Turbine offline)

CHECK loop 1 temperature channel OPERABLE. RO (RNO) PERFORM the following:

a. PULL-TO-DEFEAT TAVG CHANNEL DEFEAT switch to LOOP 1

b. PULL-TO-DEFEAT ilT CHANNEL DEFEAT switch to LOOP 1 RO

c. PLACE LOOP TAVG ilT REC/SEL switch in LOOP 2,3, or 4

d. GO TO Step 7.

Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 4 Page 13 of 46 ( Event

Description:

RTD failure Cold Leg Loop 1 Sensor #2 Fail High. Time II Position II Applicant's Actions or Behavior EVALUATE the following Tech Specs for applicability:

• 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation -

(OTIi.TAction 6 already in effect, SIG Level Ii.TAction 10 also applies.) SRO

• 3.3.2.1 (3.3.2), Engineered Safety Feature Actuation System Instrumentation - (Action 37 for SIG Level AFW start applies).

NOTE: If performing AOP in conjunction with AOP-1.11 for an Eagle LCP failure, then actions to hard trip bistables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours UNLESS affected loop is restored to operable status by resetting Eagle rack. NOTIFY 1M to remove failed TAVG L\T instrument loop from RO service USING appropriate Appendix: ( ReS INSTRUMENT LOOP PROT APPENDIX LOOP CH NUMBER 1 T-68-2 'I: A (T-4*t114"12) 2 T-6H-25 a B (T-4211422) T-68~44 3 II!'I:! C (T-4311432) 4 T-6&-67 IV D (T-4411442) IF automatic rod control is available, THEN RESTORE rod control to AUTO. USING 0-SO-85-1. (Step Is N/A) GO TO appropriate plant procedure. When Tech Spec Evaluation is complete proceed to the next event at lead examiner's discretion. Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 14 of 46 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2) Time II Position II Applicant's Actions or Behavior Console Operator: When directed, initiate Event 5 Indications available: Containment Pressure Small Increase on M-6 Recorder PDIR-30-133 Containment Radiation monitors 106, and 112 increase Charging flow increase & VCT Level Decrease Alarm (1 st one after -12 min): Reactor Building AUX FL & EQ Drain Sump Hi When RCS Leak Identified enter and direct actions of AOP-SRO R.05. EVALUATE the following Tech SpeclTRM LCOs for applicability: (

• 3.2.5, DNB parameters
• 3.4.3.1, Safety and Relief Valves- Operating
• 3.4.3.2, Relief Valves-Operating
• 3.4.6.2, RCS Leakage SRO
• TRM 3.4.11, Reactor Coolant System Head Vents
• 3.4.12, Low Temperature Over Pressure Protection Systems
• 3.6.1.4, Containment Pressure
• 3.6.1.5, Containment Air Temperature (Tech Specs may be evaluated later at Lead Examiners discretion)

EVALUATE EPIP-1, Emergency Plan Classification Matrix. SRO (Direct SM to Evaluate REP) IF leak results in radiological hazard or safety hazard, THEN EVACUATE unnecessary personnel from affected areas. SRO DIAGNOSE the failure: SRO (Enter Section 2.1) CONTROL charging flow as necessary to maintain pressurizer level on program. RO ( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 15 of 46 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2) Time II Position I Applicant's Actions or Behavior MONITOR pressurizer level:

• greater than 10%

RO

• STABLE or RISING.

(May Return to perform RNO To Trip RX and Initiate SI later when Leak increases) NOTE: VCT level to volume conversion is approximately 20 gal / %. A change in indicated level of 0.5% in one minute equals the 10 gal/min EPIP-1 criteria. MAINTAIN VCT level greater than 13% USING automatic or manual makeup. RO MONITOR containment pressure STABLE or DROPPING. RO (RNO to Trip and SI may also apply later when leak increases) MONITOR ReS pressure STABLE or RISING. RO ( CHECK secondary side radiation NORMAL:

• S/G blowdown rad monitor BOP
• Condenser vacuum exhaust rad monitor
• Main steam line rad monitors.

CHECK leak inside containment:

• containment pressure RISING ABNORMALLY OR
• containment temperature or humidity abnormal CREW OR
• containment airborne activity abnormal (RM-90-106 or 112).

CHECK containment airborne activity RISING. (RM-90-106 or 112) BOP Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 ( Op Test No.: NRC Scenario # Event # 5 Page 16 of 46 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2) Time II Position II Applicant's Actions or Behavior NOTE: Containment purging and venting should NOT be resumed until Chemistry has evaluated off-site dose in a later step. ENSURE containment purging and venting STOPPED: BOP a. CHECK containment purging or venting in progress. DETERMINE leakage source: CREW a. CHECK leakage source UNKNOWN. D. ISOLATE I,etaown and charging:

1) CLOSE letdown orifice valves:

• FCV-82-72
• FCV-62-73

(

• FCV-62-74

2) CLOSE letdown isolation valves:

RO

• FCV-62-69
• FCV-62-70
• FCV-62-77

3) CLOSE FCV-62-90 and -9'1, Charging header isolation valves.

4) ENSURE FGV-62-B3, RHR Letdownlisolafj,on CLOSED.

( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Event # 5 Page 17 of 46 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2) Time II Position II Applicant's Actions or Behavior

c. CHECK pressunzer PORVs NORMAL RO

• Taj,ipipe temperature
• Acousbe monitors

d. CHECK pressunzer safety valves NORMAL RO

• Tailpipe temperature
• Acoustic monitors

e. CHECK PRT conditions NORMAL:

• level RO

(

• Pressure
• Temperature

f. NOTIFY Chemistry to ensure RO aU pnmary side sample valves CLOSED. [Hot Sample Room]

g. CHECK CCS parameters NORMAL

• CCS radiation monitors BOP NORMAL
• COS surge tank. level STABLE.

h. CHECK excess letdown heat exchanger NORMAL (if applicable):

BOP

• Temperature
• Pressure Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 18 of 46 Event

Description:

Small RCS Leak inside containment (Hot Leg Loop 2) Time II Position II Applicant's Actions or Behavior L CHECK TI-6B-398, Reador Vessel RO Head Vent Temperature NORMAL. [M-4] J. CHECK TI-68-21, reactor vessel RO flange leakoff temperature NORMAL [M-B] MONITOR auxiliary building radiation and BOP HElB recorders NORMAL

12. CHECK leak IDENTIHED and CREW ISOLATED.

After Crew has evaluated whether leak is isolated, (Step 12 of AOP-R.OS) the leak can be increased to require Reactor Trip and Safety Injection at Lead Examiners discretion. ( Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Scenario # Event # 6,7,8, & 9 19 46 Op Test No.: NRC Page of Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time Position Applicant's Actions or Behavior Console Operator: When directed, initiate Event Indications available: Large Break LOCA

• RCS Pressure and Pressurizer level decreasing
• Containment Pressure Increasing Auto Feedwater Isolation Failure (Manual isolation is available)
• Main Feedwater Pumps do not auto trip on 51
• Main Feedwater Isolation valves do not auto close on 51

( Containment Spray discharge valves fail to Auto Open (Valves will manually open)

• Spray pumps running due to Hi Hi containment pressure (2.81 Psi) with no spray flow indicated.
• Spray pump recirculation valves open A Train RHR sump suction valve FCV-63-72 fails closed (Will not manually open)
• Valve remains closed (green light lit) when auto sump swapover criteria is met and will not manually open.

Direct Manual Reactor Trip and Safety Injection based on one SRO of several monitor steps in AOP-R.05 for either Pressurizer level, Containment Pressure, Or RCS Pressure. RO Manually Trip the Reactor and Initiate SI. Enter and Direct performance of E-O, Reactor Trip Or Safety SRO Injection. ( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 20 of 46 ( Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. I Time II Position II Applicant's Actions or Behavior Evaluator Note: Immediately following performance of Immediate actions for Rx trip and 51, the Feedwater isolation failure may be identified and manually isolated. Also, a Hi Hi containment pressure condition may occur shortly after the trip and the containment Spray valve failures may be identified and corrected at this time. These actions may be performed as prudent actions prior to reaching the applicable procedure steps. ES-0.5, initiated at Step 5 of E-O, procedurally address each of these failures and will be performed by the BOP operator. NOTE 1: Steps 1 through 4 are immediate action steps. NOTE 2: This procedure has a foldout page. ( VERIFY reactor TRIPPEO;

• Reader trip breakers OPEN

                                   .. Reaetor trip bypass breakers DISCONNECTEO or OPEN RO

• Rod bottom lights LIT

                                   .. Rod position indicators less than or equal to 12 steps.
                                   .. NeutrOfl flux DROPPING VERiFYturbine TRIPPED; BOP

• Turbi,,& stop valves CLOSED.

VERIFY at feast one train of Shutdown BOP boards ENE.RGIZED, Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 21 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior DETERMIN'E if SI actuated: RO .. ECCS pumps RUNNING.

• Any 81 alarm LIT [M..4D],

PERFORM ES-C15} Equipment Verifications\t\IHl LE continuing in this BOP procedure. (ES-0.5 At end of Scenario) DETERMINE if $8eOndary heatsink available:

a. CHECKtotal AFW flOYI greater than 440 gpm...

( b. CHECK narrow range level RO greater than 10% [25% ADV] in afleast one S/G.

c. CONTROL feed flow to maintain narrowrange leV'fM between 10% [25% ADV] and 50%

in intact or ruptured 51Ga. CHECK if main steam lines should be iso1Jated:

a. CHECKFfany of the following conditions have occurred;

• Any SlG pressure less than 600 p.sig, RO OR
• Any SlG pressure dropping UNCONTRQU..ED.

OR

• Phase B actuation,

( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 22 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior

b. ENSURE MSIVs and MSIV bypass RO valves CLOSED,

c. ENSURE applicable Foldout Page SRO actmJ'lS COMPLETED.

Evaluator Note: Reps will probably be stopped prior to the next step due to Phase B actuation. (E-O Foldout page action) CHECK RCP trip criteria:

a. CHECK the fOllowing:

• ReS pressure Jessthan 1250 psig RO

{ AND Wi At least one: CCPOR St pump

                                            **RUNNING.

b. STOP Reps.

MONITOR Res temperatures:

• IF RCPs stopped, THEN RO/BOP CHECK T-eold stable at or trending to betINeM 547°F and 552 QF.

(If No Perform RNO) Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 23 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time Position Applicant's Actions or Behavior (RNO) IF temperature Jes$ than 547°F anddropping, THEN PERFORM the following: RO/BOP a, ENSURE steam dumps and atmospheric reHefs CLOSED, D. IF oooidown continues, THEN CONTR.OL total feed flow USING EA~. Manual Control of AfW FIO\V. CHECK pressurizer PORVs, safeties, and spray valves:

a. Pressurizer PORVs CLOSED.

b, Pressurizer safety valves CLOSED, RO e, Normal spray valvas CLOSED.

d. Power t.oat least one blockvalve AVAU.ASlE.

e, At teastone block valve OPEN, DETERMINE. if gJG secondary pressure boundaries are INTACT:

                              .. CHECK all SlG pressures RO/BOP CONTROllED or RISING.

• CHECKaU SiG pressures greaterthan 140 p$ig.

Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 24 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior DETERMINE if S/G *Wbes 'are INTACT:

a. CHECKthe following:

II all SIG natfOW range levels CONTROLLED 0*1' DROPPING II sacondary radiation NORMAL RO/BOP USING Appendix A,Secondary RadMonitors, (App, A is also contained \n E$..O",5).

b. CHECKAppendix A COMPLETED.

(RNO) b, 00 NOT CONTINUE this procedure ( UNTiL App, A has been completed or attempted. DETERMINE if ReS is INTACT:

a. CHECK the folfowing;

• Containment pressure NORMAL

                                     .. Containment sum p ievet NORMAL
                                     .. LOVVER, CQMPT TEMP HIGH RO alarm DARK {M-5C,81]

(RNO) PERFORM the following:

1) MONITOR status trees.

2) GO TO E-1! Loss of Reactoror Secondary Coolant

( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 ( Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 25 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior Ensure Status Trees are monitored (STA will perform if SRO available at this time) and Transition to E-1 Evaluator Note: Orange Paths may already be present at this point to perform FR-P.1 and/or FR-Z.1 When verified, SRO will leave E-1 after performing only a few steps. SRO Enter and direct actions of E-1 NOTE This procedure has a foldout page. CHECK Rep trip criteria:

a. CHECK the following:

• At least one CCP OR SI pump R.UNNING

( RO AND

• R.CS pressure less than 1250 pStg.

b. STOP RCPs.

(Step Previously performed) MONITOR if hydrogen i;gniters and recornbiners should be turned on:

a. CHECK containment conditions NOT normal:

• containment pressure high OR
• containment sump level high.

b. DISPATCH personnel tocpen Ice condenser AHU breakers USING EA-201-1, 480 V Board Room Breaker Alignments.

( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Event # 6,7,8, & 9 Page 26 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior

c. CHECK hydrogen concentration measurement AVAILABLE:

• Hydrogen analyzers have been in ANALYZE for at least 5 minutes.

(RNO) PERFORM the following:

                                "1) DISPATCH operator to place hydrogen analyzers In service USING Appendix lD (also contained In ES-O.5}.

2} WHEN hydrogen analyzers have been In ANALYZE for at least 5 minutes, THEN PERFORM substeps 2.d

                                    ""'r~ ,~b.? f Enter and Direct actions of FR-P.1, Pressurized thermal Shock if orange path present.

SRO (If FR-P.1 not required at this point continue on next page with FR-Z.1) MONITOR RW8T level RO greater than 27%. BOP MONITOR CST level grea.ter tha.n 5'%, Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 6,7,8, & 9 NRC Scenario # Event # Page 27 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior CHECK ReS pressure greater than 300 psig. (RNO) IF any of the folbwfng conditions exist:

• RHR injection flow greater than 1000gpn1 RO OR

                                  .. bothRHR pumps STOPPED ANDsumpraciro capability has been lost THEN RETUR.N TO procedure and step

( in effect. Transition to and Direct action of FR-Z.1 SRO Evaluator Note: At some point during the performance of FR-Z.1, RHR Auto Containment Sump swapover criteria may be met. At this point, crew will leave FR-Z.1 and enter ES-1.3. ES-1.3 will direct Resume FRP implementation to return to and complete FR-Z.1. All of FR-Z.1 is contained next in this event guide. ES-1.3 begins immediately following FR-Z.1. NOTE If this procedure has been entered for an orange path and performance of ECA-1.1 (Loss of RHR Sump Recirculation) is required, FR-Z.1 may be performed concurrently with ECA-1.1. MONITOR RWST level greater than 27%. RO Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 28 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. I Time I Position II Applicant's Actions or Behavior I VERIFY Phase B valves CLOSED. RO

• Panel 6K PHASE B GREEN
• Panel6L PHASE B GREEN ENSURE RCPs STOPPED.

RO (RCPs will be off due E-O foldout page actions) DETERMINE if this procedure should be exited:

a. CHECK for faulted S/G:

RO

• Any S/G pressure DROPPING in an

( uncontrolled manner OR

• Any S/G pressure less than 140 psig.

( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Scenario # 6,7,8, & 9 29 46 Op Test No.: NRC Event # Page of Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior I VERIFY containment spray operation:

a. CHECK RHR sump redrculation capabi;!ity AVAILABLE

b. VERIFY containment spray pumps RUNNiiNG.

c. CHECK RWST level' greater than 27%.

d. VERIFY containment spray suctio ALIGNED to RWST:

• FC\I-72-22 OPEN
• FC\I-72-21 OPEN_

( RO e. VERIFY containment spray discharge Critical valves OPEN: Task

• FCY-12-39
• FCY-12-2.

(Evaluator Note: FCV-72-2 will not manually open)

f. VERI:FY containment spray reese valves CLOSED:

• FGV-72-34
• FCY-12-13.

g. VERIFY containment spray flow greater than 4150 gpm on each train.

Critical Task "Prior to completing FR-Z.1" Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 30 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior II MONITOR containment air return fans:

• WHEN at least 10 minutes have ellapsed from Phase B, BOP THEN ENSURE containment aIr return fans RUNN~NG (Evaluator Note: B Train Air return Fan Trips on overcurrent when it starts)

VERIFY containment ventilation dampers CLOSED: RO

• Panel 6K CNTMT VENT GREEN

                                   .. Panel 6L CNTMT VENT GREEN..

( VERIFY Phase A vaJves CLOSED: RO

• Panel' 6K PHASE A GREEN

                                  .. Panel 6L PHASE A GREEN.

VERIFY MSIVs and lMSIV bypass valves BOP CLOSED. DETERMllNE if any SIGlntad:

a. CHECK at least one SiG pressure:

BOP* CONTROLLED or RIS1NG AND

                                       .. Greater than 140 pslg.

( Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 31 46 Op Test No.: NRC Scenario # Event # 6,7,8, & 9 Page of Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior CAUTION Isolating al,1 SIGs will result in a loss of secondary heat sink. DETERMINE if any SiG Faulted: 6:- CHECK S/G pressures:

• Any S/G pressure DROPPING BOP In an uncontroll,ed manner OR
• Any S/G pressure less than 140 pSig.

MONITOR if hydrogen ,igniters and recombjners should 'be turned on: ( a. DISPATCH personnel to open ice condenser AHU breakers USING EA-201-1 , 480 V Board Room Breaker Alignrnents. BOP

b. CHECK hydrogen concentration measurement A'VAllABLE:

• Hydrogen analyzers have been In ANALYZE for at least k;.). minutes.

Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Scenario # Op Test No.: NRC Event # 6,7,8, & 9 Page 32 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior (RNO May be previously performed)

b. PERfORM the following:

1) DISPATCH operator to place hydrogen analyzers in service USING Appendix D. (also BOP contained lin ES-R5)

2) WHEN hydrogen analltzers have been m ANALYZE for at least 5 minutes, THEN PERFORM sebsteps 12.c through 12.e.

MONITOR if RHR spray should be placed RO ( In service: MONITOR if containment spray should be stopped:

a. CHECK any containment spray pump RUNNING.

b. CHECK containment pressure less than 2.0 pSig.

c. CHECK containment spray suction aligned to RWST.

RO

d. RESeT Containment Spray.

e. STOP containment spray pumps and PLACE In A-AUTO.

f. CLOSE containment spray discharge valves:

• FCV-12-39, Train A
• FCV.. 72...2, Train B.

RETURN TO procedure and step SRO In effect Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 33 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. II Time Position Applicant's Actions or Behavior Evaluator Note: As previously discussed, ES-1.3 may be entered prior to completion of FR-Z.1 Enter and direct actions of ES-1.3 when Sump Swapover SRO criteria is met (RWST Level less than 27%). CAUTION Transfer to sump reci:n:ulati'on may cause high radiation in AUK Building. SRO SUSPEND FRP implementation. MONITOR RHR automatic switdlOver:

a. CHECK containment sump level greater than 1, 1~tQ.

( b. CHECK containment sump valves FCV-63-72 and FCV-'o3-73 OPEN. (RNO FCV-63-72 Failed to open) IF any sump valve IS CLOSED, THEN AlTEMPT to open affected sump valve from fvlCR RO (Valve will not open)

c. CHECK RHR suction valves FCV-74-3 and FC\f-74-21 CLOSING.

(RNO FCV-74-3 will not be closing since FCV-63-72 will not open, however valve should not be closed based on RNO) IF sump valve 00 affected train is cpeninq, THEN AlTEMPT to dose RHR sudion valve from MeR ( Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 34 of 46 ( Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. I Time II Position II Applicant's Actions or Behavior DETERMINE if contaimnent spray should be stopped:

a. CHECK any containment spray pump RUNNING.

b. CHECK containment pressure greater than or equal to 201) pSlg.

(RNO if less than 2.0 psig) STOP containment spray pumps as follows:

1) RES:ET containment spray signal.

2) STOP containment spray pumps RO and PLACE m A-AUTO.

( 3) CLOSE cntmt spray discharge valves FCV-72-39 and FGV-72-2. GO TO Step 4. (If RNO Not required, i.e. greater than 2.0 psi)

c. CHECK BOTH cntmt spray pumps RUNNING.

d. STOP one cntrm spray pump and PLACE In PUll-TO-LOCK.

                                    . MONITOR one cntmt spray pump RUNNING and delivering flow.

Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 35 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior MONITOR RWST supply to ECGS pumps:

• R\t'VST t Vt LO-LO alarm DARK (r...1-6E, E4].
• RWST level greater than 8%.

(RNO if Required at some point) RO WHEN RWST level is less than or equal to H%, THEN PULL TO LOCK any pumps taking suction from RWST:

a. Containment spray pumps.

(

b. SI pumps.

c. CCPs.

RO MONITOR RHR pumps RUNNING. NOTE Step 6 should be handed off to a Unit Operator.

6. PE:RfORM the foH:owing:

a, DiSPATCH personnel to restore power to FCV~63-'1 USING EA-201-1, 480 V Board Room Breaker Alignments. BOP b. OPEN RHR heat exchanger outlet valves FCY-I0-156 and FCV-70-t53.

c. VERIfY cos flow FI-70-159A and FI-I0-165A greater than 5050 gpm.

d. MONITOR ecs temperature and surge tank level.

( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 36 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed . Position Applicant's Actions or Behavior VERIFY RHR automatic switchover:

a. VERIFY containment sump valves FCV-63-72 and FCV-63-73 OPEN.

(RNO) IF any containment sump valive(s) RO CANNOT be opened, THEN PULL TO LOCK RHR pump on affected train(s). (A Train RHR Pump should be stopped) (RNO continued next page) IF Train A containment sump valve ( FCV-63-72 CANNOT be opened, THEN PERFORM the following:

1) CLOSE FCV-74-3 Train A RHR suction valve to satisfy interlock.

RO

2) WHEN FCV-14-3 !S CLOSED, THEN ATIEMPT to OPEN FCV-63-12.

(Continue AER for step 6)

b. ENSURE RWST to RHR sudion valves FCV-14-3 and FCV-74-21 CLOSED.

CAunON 51 pum,p operation with miniflow j'solatedand ReS pressu.re above shutoff head wHI result in 51 pump damage. NOTE The following continuous acton applies even after this procedure IS exited. MONITOR RCS pressure RO less than 1-500 PSJ9* ( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 37 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior I CLOSE SI pump miniflow to R\"'JST valves: RO

• FCV-63-3 (Step 9)
• FCV-63-4
• FCV 175 CLOSE RI-IR crosstie valves:

RO

• FCV-14-33 (Step 10)
• FGV-14-35..

OPEN CCP and SI pump suction valves fromRHR: RO (Step 11)- FCV~63-7 (

                                   -    FC\!-63-6.

AUGN RHR discharge to CCP and SI pump suction:

3. OPEN RHR discharge to CCP suction FCV-63-8.

(RNO since FCV-63-8 will not open due to interlock with FCV-RO 63-72 Sump valve that will not open) (Step 12) ENSURE operation of Train E RHR:

• Train B RHR pump RUNNING
• FCV-63-11 OPEN.

D. OPEN RHR discharge to SI pump suction FCV-63-11 Critical VERIfY Steps 9 through 12 Task SRO/RO COMPLETED. Critical Task "Prior to degraded Core Coolino conditions" Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 38 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. 1 Time II Position I Applicant's Actions or Behavior Evaluator Note: ECCS Alignment to containment sump is complete at this point. Lead Examiner may evaluate terminating scenario if critical tasks have been addressed and sufficient actions from contingency procedure FR-Z.1 have also been completed. CHECK EGCS pump status:

3. MONITOR BOTH RHR pumps RUNNING.

(RNO since only B RHR Pump is running) PERFORM the following:

1) ENSURE the foltowing:

• one CGPRUNNING (same train as running RHR

( pump preferred) RO

• other CCP In PUll TO LOCK (RNO 2) is N/A)

3) IF RCS press IS less than 150G pSl9, THEN ENSURE the following:

• one 51 pump RUNNING (same train as running RHR pump preferred)
• other SI pump ln PUll TO lOCK CAUTION Momentary loss of shutdown power whUe aligned for sump reckculation could result in CCP damage since the bl,ackout sequencer will start the CCPs but will NOT start the RHR pumps.

Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 39 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Applicant's Actions or Behavior MONITOR shutdown boards BOP continuously energized. RO RESET S~ signal. ALIGN ElRCW System BOP USING EA '1, ERC\N Operation. ISOLATE CCP suction from RWST:

a. CLOSE RWST suction valves LCV-62-135 and LC"l-62-136 WHILE monitoring CCPIT flow.

b. PLACE RWST suction valve bandswitches In A-AUTO (pushed in):

• HS-62-135

( RO

• HS-52-i3S

c. ENSURE at least one VCT outlet valve CLOSED:

• LCV-62-132 OR
• LCV-62-133.

ISOLATE RHR suction from RWST:

a. CHECK power RESTORED to FCV-63-1

b. CLOSE FCV-53-1 WHILE monitori:ng :RHR flow.

ISOLATE SI pump suction from RWST: RO

• CLOSE FCV-133-5 WI-ULE monitoring SI pump flow.

( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 NRC Event # 40 46 Op Test No.: Scenario # 6,7,8, & 9 Page of ( Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. Time II Position II Aoolicant's Actions or Behavior ALIGN containment spray suction to containment sump: a, CHECK any of the following conditions met

• RWST level less than orequal to 8%

OR RO

• containment sump level greater than or equal to 56%.

0_ ENSURE containment spray pumps in PUlL-TO-lOCK

c. CHECK FCV-63-72 Train A

( containment sump valve OPEN. (RNO FCV-63-72 failed closed) GO TO Suostep 21 J. (Step Continued next page) L CHECK FC\L63-73 Train B containment sump valve OPEN. J. CLOSE FCV-72-21, Train B cntmt spray suction from RWST Ie OPEN FCV-72-20 Train B cntmt spray suction from containment sump. L CHECK containment pressure greater than 2.0 pstg. (RNO if pressure less than 2.0 psi) (Step Continued next paqe) Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6,7,8, & 9 Page 41 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. I Time II Position II Applicant's Actions or Behavior PERfORM the followtng:

1) RESET Train B Containment Spray signal.

2) WHEN containment sump ievel IS greater than -1 B'% [22% ADY],

THEN PLACE Train B containment spray pump In A-AUTO.

3) ENSURE FCV-72-2 Train B cntmt spray iso! valve CLOSED.

(Continue step if pressure greater than 2.0 psi) rn. CHECK containment sump level ( greater than 1H~O [22% ADY]. (Continue step next page) fl. ESTABLISH Train B Cntmt Spray:

1) CHECK Train B containment spray pump suction aligned to containment sump.

2) START Cntmt spray pump B-EL

3) ENSURE FCV'-72-2 Train B Cntmt Spray isol valve OPEN.

RO

o. ENSURE reorc valves CLOSED for running Containment Spray pump(s}:

• FCV-72-34 Train A
• FGV-72-13 Train B.

p. CHECK containment spray flow greater than 4750 gpm

( on each train In service. Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Scenario # Op Test No.: NRC Event # 6,7,8, & 9 Page 42 of 46 Event

Description:

Large Break LOCA, Auto FW Isol failure, Cntmt Spray Vlvs Auto open fail, A Train RHR sump suction vlv fails closed. I Time II Position II Applicant's Actions or Behavior I MONITOR if RHR spray should be placed in service: RESUME FRP implementation. Evaluator Note: Crew may return to FR-Z.1 at this point if not completed earlier. Scenario may be terminated at lead examiner discretion when critical tasks have been addressed and sufficient actions in FR-Z.1 and ES-1.3 have been completed. ( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # ES-O.5 Page 43 of 46 Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior ES-O.5 Actions CHECK ERCW system operation: BOP

• VERIFY at least four ERCW pumps RUNNING.
• VERIFY DIG ERCW supply valves OPEN. I VERIFY CCS pumps RUNNING:
• Pump 1A-A (2A-A)

BOP

• Pump 1B-B (2B-B)
• Pump C-S.

VERIFY EGTS fans RUNNING. BOP VERIFY generator breakers OPEN. ( BOP VERIFY AFW pumps RUNNING: BOP

• MD AFW pumps
• TD AFW pump.

( Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario #

                                            --3     Event #       ES-O.5           Page 44   of 46 Event

Description:

Equipment Verifications Time II Position [ Applicant's Actions or Behavior I NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control S/G levels, to establish flow due to failure, or to isolate a faulted S/G. CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

b. VERIFY TO AFW LCVs OPEN.

BOP

c. VERIFY MD AFW pump recirculation valves FCV-3-400 and FCV-3-401 CLOSED.

VERIFY MFW Isolation:

• MFW pumps TRIPPED
• MFW regulating valves CLOSED
• MFW regulating bypass valve controller outputs ZERO BOP
• MFW isolation valves CLOSED

(

• MFW flow ZERO.

(Evaluator Note: If not previously completed Auto Feedwater Isolation Failure should be addressed at this point.) MONITOR ECCS operation: VERIFY ECCS pumps RUNNING: BOP

• CCPs
• RHR pumps
• SI pumps

( Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Scenario # Event # Page 45 of 46 Op Test No.: NRC 3 ES-O.5 Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior VERIFY CCP flow through CCPIT.

• CHECK RCS pressure less than 1500 psig.

BOP

• VERIFY SI pump flow.
• CHECK RCS pressure less than 300 psig.
• VERIFY RHR pump flow.

VERIFY ESF systems ALIGNED:

• Phase A ACTUATED:

0 CONTAINMENT ISOLATION PHASE A TRAIN A alarm LIT [M-6C, B5]. 0 CONTAINMENT ISOLATION PHASE A TRAIN B alarm LIT [M-6C, B6].

• Containment Ventilation Isolation ACTUATED:

0 CONTAINMENT VENTILATION ISOLATION TRAIN A alarm LIT [M-6C, C5]. ( 0 CONTAINMENT VENTILATION ISOLATION TRAIN B alarm LIT [M-6C, C6]. BOP

• Status monitor panels:

0 6C DARK 0 60 DARK 0 6E LIT OUTSIDE outlined area 0 6H DARK 0 6J LIT.

• Train A status panel 6K:

0 CNTMT VENT GREEN 0 PHASE A GREEN

• Train B status panel 6L:

0 CNTMT VENT GREEN 0 PHASE A GREEN ( Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Event # ES-O.5 Page 46 of 46 Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior MONITOR containment spray NOT required:

• Phase B NOT ACTUATED AND
• Containment pressure less than 2.81 psig BOP
• Ensure Containment Spray is actuated (Evaluator Note: If not previously addressed Containment Spray discharge valve auto open failures should be addressed at this point, only A Train valve can be manually opened)

VERIFY pocket sump pumps STOPPED: [M-15, upper left corner]

• HS-77-410, Rx Bldg Aux Floor and Equipment Drain BOP Sump pump A
• HS-77-411, Rx Bldg Aux Floor and Equipment Drain Sump pump B.

( DISPATCH personnel to perform EA-0-1, Equipment Checks Following ESF Actuation. BOP Appendix 0 NUREG 1021 Revision 9

SHIFT TURNOVER CHECKLIST Page 1 of 3 Today / { 0 SM 0 US/MCR Unit 1 0 UO Unit 1 Off-going - Name 0 AUO Station SQN 0 STA (STA Function) AUO Camp Actions On-coming - Name Part 1 - Completed by Off-gOing Shift/Reviewed by On-coming Shift: Abnormal Eauipment Lineun/Conditions:

                                       ;pjJiJU/JJ ~/tli!J;ffJ~tl1+/-     ~tltllV1~'l/o9,(j~ ~~93-~i4(f}92 TrainA Week
                      ~
                                              'fllt!J~1BIf!§JJJ$1Bt!JllJ..lfjlf!§J~ ~'l'l'l1~ ~93-~1Ql

• All Equipment normal

(

• All equipment normal Total 0.03 gpm I Identified 0.02gpm I Unidentified 0.01 gpm. (Today 0600)

(

SHIFT TURNOVER CHECKLIST Page 2 of 3 Today 31/Test in Progress/Planned: (Including Need for New Brief) 0-SI-SXX-068-127.0 in progress. Major Activities/Procedures in Progress/Planned: Plant Startup in progress. Currently in 0-GO-4 Section 5.2, Step 3 at -2% power. Continue plant startup per Rx Engineering Spreadsheet. Spreadsheet has been verified by the SRO/STA. 0-SO-62-7 Appendix D and E have been completed. Pre-conditioned Power level is 100%. Turbine roll in parallel with power increase is not desired. Radiological Changes in Plant During Shift: Reactor power increase will increase dose rates inside containment and various locations in the Aux. Bldg. See applicable Rad Con RWPs for details and entry requirements. Part 2 - Performed by on-coming shift D Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's) D Review of Rounds Sheets/Abnormal Readings (AUO's only) ( Review the Following Programs for Changes Since Last Shift Turnover: D Standing Orders D LCO(s) in Actions (N/A for AUOs) D Immediate Required Reading D TACF (N/A for AUO's) Part 3 - Performed by both off-going and on-coming shift D Walkdown of MCR Control Boards (N/A for AUO's) Relief Time: Relief Date: today TVA 40741 [03-2001] OPDP-1-1 [03-14-2001

SHIFT TURNOVER CHECKLIST Page 3 of 3 Today Disabled Annunciators ( PANEL WINDOW ANNUNCIATOR WO I PER Number Equipment Off-Normal (Pink Tags) UNID And Noun Name Panel Problem Description WO I PER Number MCRWO List 10 And Noun Name Panel Problem Description WOlPER Number ( (

UNIT ONE REACTIVITY BRIEF Date: Today Time: Now RCS Boron: 1703 ppm Today I BA Controller Setpoint: 47.5%

• I RCS B-10 Depletion: 2 ppm Operable BAT: A I BAT A Boron: 6850 ppm I BAT C Boron: 6850 ppm I RWST Boron: 2601 ppm Nominal Gallons per rod step from 219: N/A gallons of acid, N/A gallons of water
• Verify boric acid flow controller IS set at Adjusted SA Controller Setting law 0-SO-62-7 section 5.1 Gallons of acid: N/A Gallons of water: N/A Rod Steps: 4 Power reduction amount Estimated Final Rod Position Estimated boron addition 10% N/A Steps on bank 0 N/A gallons 30% N/A Steps on bank 0 N/A gallons 50% N/A Steps on bank 0 N/A gallons

    ** These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power

( operation only. Engineering data last updated one week ago. Data Valid until one week from now. Number of dilutions: *** Number of borations: a Rod steps in: a Gallons per dilution: a Gallons per boration: a Rod steps out: a Total amount diluted: a Total amount borated: a Net change: a IN/Out Number of dilutions: *** Number of borations: a Rod steps in: a Gallons per dilution: a Gallons per boration: a Rod steps out: a Total expected dilution: *** Total expected boration: a Net change: a In/Out Remarks: Rx Power - -2% MWO/MTU - 1000 Xenon & Samarium at Equilibrium

                   *** As Required by Reactor Engineering startup spreadsheet.

Next Unit 1 Flux Map is scheduled- N/A Unit Supervisor: Name/Date

Operations Chemistry Information ( Sample Point Units Boron Date / Time Goal Limit U1 RCS ppm 1703 Today / Now Variable Variable U2 RCS ppm 816 Today / Now Variable Variable U1 RWST ppm 2601 Today / Now 2550 - 2650 2500 - 2700 U2 RWST ppm 2569 Today / Now 2550 - 2650 2500 - 2700 BAT A ppm 6850 Today / Now Variable Variable BAT B ppm 6850 Today / Now Variable Variable BATC ppm 6850 Today / Now Variable Variable U1 CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 U1 CLA #2 ppm 2575 Today / Now 2470-2630 2400-2700 U1 CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700 U1 CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today / Now 2470-2630 2400-2700 U2 CLA#2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA#3 ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today / Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today / Now ~2050 ~2000 ( 2.18-2.48 2.33 Indicator Units U1 Date / Time U2 Date/Time SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now SI 137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent cpm 380 Today / Now 68 Today / Now 30 gpd leak equivalent cpm 1980 Today / Now 83 Today / Now 50 gpd leak equivalent cpm 3250 Today / Now 206 Today / Now 75 gpd leak equivalent cpm 4850 Today / Now 455 Today / Now 150 gpd leak equivalent cpm 9750 Today / Now 870 Today / Now CVE Air Inleakage cfm 10 Today / Now 12.5 Today / Now Bkgd on 99/119 cfm 50 Today / Now 40 Today / Now (

Unit 1 DELTA REACTOR POWER ASSUMED INSERTED EXPECTED DELTA RHO BORON DELTA RECOMMEND RECOMMEND IODINE TIME POWER DEFECT ROD HT WORTH XENON BORON CONC PPM DILUTION BORATION CONC (hrs) (%) (pcm) (steps) (pcm) (pcm) (pcm) (ppm) (ppm) (gal) (gal) (% eq) 0.0 2.0 35.6 173.0 -327.8 -118.3 1702.9 .9 1.0 14.0 240.3 195.0 -163.7 -125.9 48.1 1695.3 -7.6 290 0 2.5 2.0 26.0 427.1 200.0 -125.1 -143.6 166.0 1669.1 -26.2 1018 0 4.2 3.0 38.0 605.0 205.0 -89.7 -176.3 175.1 1641.5 -27.6 1091 0 7.0 4.0 50.0 779.2 210.0 -58.3 -226.7 193.2 1611.0 -30.5 1226 0 10.6 5.0 62.0 954.0 216.0 -27.9 -295.5 213.1 1577.4 -33.6 1378 0 15.1 6.0 74.0 1133.0 216.0 -26.9 -381.4 264.0 1535.9 -41.6 1747 0 20.3 7.0 86.0 1320.8 216.0 -25.9 -482.0 287.3 1490.7 -45.2 1951 0 26.2 8.0 98.0 1519.1 216.0 -24.7 -593.9 309.1 1442.1 -48.6 2170 0 32.7 9.0 100.0 1570.9 216.0 -24.5 -716.0 173.7 1414.9 -27.3 1241 0 39.2 10.0 100.0 1582.9 216.0 -24.5 -845.9 141.9 1392.6 -22.3 1029 0 45.2 11.0 100.0 1592.7 216.0 -24.5 -979.0 143.0 1370.2 -22.4 1054 0 50.6 12.0 100.0 1603.0 216.0 -24.5 -1111.2 142.4 1347.9 -22.3 1067 0 55.4 13.0 100.0 1613.2 216.0 -24.5 -1239.7 138.7 1326.2 -21.7 1056 0 59.8 14.0 100.0 1623.1 216.0 -24.5 -1362.8 132.9 1305.3 -20.8 1026 0 63.8 15.0 100.0 1632.6 216.0 -24.5 -1479.2 125.9 1285.6 -19.7 987 0 67.3 16.0 100.0 1641.6 216.0 -24.5 -1588.3 118.2 1267.2 -18.5 940 0 70.5 17.0 100.0 1650.1 216.0 -24.5 -1689.9 110.1 1250.0 -17.2 888 0 73.4 18.0 100.0 1657.9 216.0 -24.5 -1784.0 102.0 1234.0 -15.9 832 0 76.0 19.0 100.0 1665.2 216.0 -24.5 -1870.7 94.0 1219.4 -14.7 776 0 78.4 20.0 100.0 1672.0 216.0 -24.5 -1950.3 86.3 1205.9 -13.5 720 0 80.5

21. 0 100.0 1678.2 216.0 -24.5 -2023.2 79.1 1193.5 -12.3 666 0 82.4 22.0 100.0 1683.9 216.0 -24.5 -2089.7 72.3 1182.3 -11.3 615 0 84.2 23.0 100.0 1689.3 216.0 -24.5 -2150.4 66.1 1171.9 -10.3 566 0 85.7 24.0 100.0 1694.3 216.0 -24.5 -2205.6 60.1 1162.6 -9.4 520 0 87.1 25.0 100.0 1698.7 216.0 -24.5 -2255.7 54.6 1154.1 -8.5 475 0 88.4 26.0 100.0 1702.8 216.0 -24.5 -2301.2 49.6 1146.3 -7.7 434 0 89.5 27.0 100.0 1706.5 216.0 -24.5 -2342.5 44.9 1139.3 -7.0 396 0 90.6 28.0 100.0 1709.9 216.0 -24.5 -2379.8 40.7 1133.0 -6.3 361 0 91. 5 29.0 100.0 1712.9 216.0 -24.5 -2413.6 36.8 1127.2 -5.7 328 0 92.3 30.0 100.0 1715.6 216.0 -24.5 -2444.2 33.3 1122.0 -5.2 298 0 93.1 31.0 100.0 1718.1 216.0 -24.5 -2471.9 30.1 1117.4 -4.7 271 0 93.8 32.0 100.0 1720.4 216.0 -24.5 -2496.9 27.2 1113.1 -4.2 246 0 94.4 33.0 100.0 1722.4 216.0 -24.5 -2519.5 24.6 1109.3 -3.8 223 0 94.9

        ,-                                            <P'-"""

Unit 1 34.0 100.0 1724.2 216.0 -24.5 -2539.9 22.2 1105.8 -3.5 202 0 95.4 35.0 100.0 1725.9 216.0 -24.5 -2558.3 20.1 1102.7 -3.1 183 0 95.9 36.0 100.0 1727.4 216.0 -24.5 -2574.9 18.1 1099.9 -2.8 165 0 96.3 37.0 100.0 1728.7 216.0 -24.5 -2589.9 16.4 1097.3 -2.5 149 0 96.6 38.0 100.0 1730.0 216.0 -24.5 -2603.4 14.8 1095.0 -2.3 135 0 97.0 39.0 100.0 1731.0 216.0 -24.5 -2615.7 13.3 1093.0 -2.1 122 0 97.3 40.0 100.0 1732.0 216.0 -24.5 -2626.7 12.0 1091.1 -1. 9 110 0 97.5 41.0 100.0 1732.9 216.0 -24.5 -2636.6 10.8 1089.4 -1. 7 100 0 97.8 42.0 100.0 1733.7 216.0 -24.5 -2645.6 9.8 1087.9 -1. 5 90 0 98.0 43.0 100.0 1734.5 216.0 -24.5 -2653.7 8.8 1086.5 -1. 4 81 0 98.2 44.0 100.0 1735.1 216.0 -24.5 -2661.0 8.0 1085.3 -1.2 74 0 98.4 45.0 100.0 1735.7 216.0 -24.5 -2667.6 7.2 1084.1 -1.1 66 0 98.5 46.0 100.0 1736.3 216.0 -24.5 -2673.5 6.5 1083.1 -1. 0 60 0 98.7 47.0 100.0 1736.7 216.0 -24.5 -2678.9 5.8 1082.2 -0.9 54 0 98.8 48.0 100.0 1737.2 216.0 -24.5 -2683.7 5.3 1081. 4 -0.8 49 0 98.9 49.0 100.0 1737.6 216.0 -24.5 -2688.1 4.7 1080.7 -0.7 44 0 99.0 50.0 100.0 1737.9 216.0 -24.5 -2692.0 4.3 1080.0 -0.7 40 0 99.1

51. 0 100.0 1738.2 216.0 -24.5 -2695.5 3.9 1079.4 -0.6 36 0 99.2 52.0 100.0 1738.5 216.0 -24.5 -2698.7 3.5 1078.9 -0.5 32 0 99.3 53.0 100.0 1738.8 216.0 -24.5 -2701.6 3.1 1078.4 -0.5 29 0 99.4 54.0 100.0 1739.0 216.0 -24.5 -2704.2 2.8 1077.9 -0.4 26 0 99.4 55.0 100.0 1739.2 216.0 -24.5 -2706.5 2.6 1077.5 -0.4 24 0 99.5 56.0 100.0 1739.4 216.0 -24.5 -2708.6 2.3 1077.2 -0.4 21 0 99.5 57.0 100.0 1739.6 216.0 -24.5 -2710.5 2.1 1076.9 -0.3 19 0 99.6 58.0 100.0 1739.7 216.0 -24.5 -2712.3 1.9 1076.6 -0.3 17 0 99.6 59.0 100.0 1739.9 216.0 -24.5 -2713.8 1.7 1076.3 -0.3 16 0 99.7 60.0 100.0 1740.0 216.0 -24.5 -2715.2 1.5 1076.1 -0.2 14 0 99.7 Total 29846 0

~MWD/MTU Hold Tavg = Tref +/- 1. SF Small hourly boration/dilution 6820 BAT ppm volumes may be accumulated for larger single additions Reason for Power Increase Plant Startup Date RxENG Name Beeper 70808 Comments

SQN 0-SO-62-7 1,2 BORON CONCENTRATION CONTROL Rev. 46 Page 161 of 199 APPENDIX D Page 1 of 1 CALCULATION FOR AMOUNT OF BORIC ACID OR PRIMARY WATER (TI-44) NOTE 1 One calculation is required for each major change. NOTE 2 Boric acid amounts to achieve required RCS boron concentration may be significantly higher than calculated amounts if CVCS demin resins are removing boron. Amount of boron removal by mixed bed resins will depend on RCS boron, resin age, whether demin bed was previously borated, and letdown temperature. Chemistry should be consulted if required to evaluate resin bed removal. [1] IF REACTF not used, THEN CALCULATE amount of primary water or boric acid required using TI-44. AMOUNT PRIMARY RCS BORON PPM CHANGE WATER OR BORIC ACID ( /703 ppm Current Ib 67 -3G 1357 b/htle TOTAL GAL(s) NOTE REACTF data sheets are to be signed by the preparer and reviewer. [2] IF REACTF used attach printout to procedure. NOTE IV is not required if appendix is performed by an SRO to verify data provided by Rx. Eng. [3] ENSURE independently verified by an SRO in accordance with Appendix I. I//A-- lnitiats END OF TEXT

NRC08c Dilute.txt 0 [REACTF - VERS SQ2.1J BORATION / DILUTION CALCULATION SEQUOYAH UNIT 1 CYCLE 15 RCS AVG TEMP 547.0 DEG F RCS PRESSURE 2235.0 PSIG PZR LEVEL 24.7 % MAKEUP WTR CONC .0 PPM BORIC ACID CONC 6850.0 PPM INITIAL CONC FINAL BORIC ACID MAKEUP WTR BORON CONC CHANGE BORON CONC ADDITION ADDITION (PPM) (PPM) (PPM) (GAL) (GAL) 1703.0 -36.0 1667.0 .0 1357.7 0 ( { page 1

SQN BORON CONCENTRATION CONTROL 0-SO-62-7 1,2 Rev. 46 Page 162 of 199 APPENDIX E Page 1 of 18 REACTIVITY BALANCE CALCULATION NOTE 1 One calculation is required for each major change. Calculation is an approximation of required Boron change. Eyeball interpolation of graphs is expected. NOTE 2 Dilution or Boration value for power change from P1 % to P2 % power in time period T with rods moving from step position R1 to R2. (Subscript convention: 1 =current point, 2 =target point) [1] ENTER the following data: DATA REQUIRED DATA Where To Get Current RCS Boron J 703 ppm Chem Lab or Estimate using Appendix 0 Core Burnup IOOCJ MWO/MTU ICS U0981 Current Reactor power 2  % NIS or ICS Final Reactor power Zb  % As required for plant conditions Total Reactor Power change zLJ ~% ~ Current and final Reactor power Rate of Reactor power change /Z  %/hr As required for plant conditions Number of hours to change power 2 hr(s) As required for plant conditions ICS or MCR Board Current Rod Position /73 steps Estimate number of rod steps required to Final Rod Position 200 steps control ~I and rod withdrawal requirements for power change.

SQN BORON CONCENTRATION CONTROL 0-80-62-7 1,2 Rev. 46 Page 163 of 199 APPENDIX E Page 2 of 18 CAUTION Follow sign conventions explicitly. (See Example Power Increase and Power decrease.) [2] CALCULATE change in boron concentration by performing the following: Parameter Where To Get Calculation Value Attached Power Defect Curves: [a] flp POWER DEFECT go pcm PD 1 - t.;./ []- pcm PD 2 = -36~ pcm (negative for power Unit 1: Figure 1, 2, or 3 (current) 8.p POWER DEFECT increase) Unit 2: Figure 8, 9, or 10. Xenon-, From ICS* or REACTF (either current NOTE: Xenon reactivity must be negative (negative conditions or projection to initial condition). for rise in [b] flp XENON Xenon., From ICS* or REACTF -22..- Xenon (projection over time period T). -IC/D pcm XE2 -(-I! B) pcm XE 1 = pcm conc) (current) 8.p XENON

                          *(ICS Xenon values must add negative sign).

[C] flp RODS Attached Rod Worth Curves: Unit 1: Figure 4, 5, or 6

                                                                                ,...1 DO         pcm Rods 2    - (- Z(;U )pcm      Rods 1 = /60             pcm (negative for rod (current)                                  insertion)

Unit 2: Figure 11, 12, or 13. 8.p RODS [d] flp POWER DEFECT + XENON + RODS (CHANGE IN REACTIVY DUE TO POWER DEFECT, XENON, AND RODS) -227 pcm [a] pcm 8.p POWER DEFECT + [b] pcm ~p XENON + [c] pcm ~p RODS = [e] flp BORON (CHANGE IN BORON REACTIVITY) 2 2 7 pcm ( [d] pcm flp POWER DEFECT + XENON + RODS) X (-1) = 8.p BORON [f] Apprn BORON (CHANGE IN BORON CONCENTRATION) (negative for dilution, ( [e] pcm 8.p BORON) -:- ( - biZ 7 pcm/ppm Boron Worth) = ~3b ppm positive for boration) from Fig. 7 (U-1) or Fig. 14 (U-2) [3] ENSURE independently verified by SRO in accordance with Appendix J. (N/A if performed by an 8RO to verify data provided by Rx. Eng)

SON RCS AND PRESSURIZER TEMPERATURE AND PRESSURE LIMIT O-SI-SXX-068-127.0 Rev 11 1&2 Page 37 of 38 APPENDIX E Page 1 of 1 Unit._--.:.__ \ Sheetv- of ~ Date vA---' MINIMUM TEMPERATURE FOR CRITICALITY Acceptance Criteria Failure Actions: Action 1 - IF Acceptance Criteria is not Satisfied, THEN [a] NOTIFY SRO, [b] REFER talCO 3.1.1.4. D TAvg minus T Rof Deviation Alarm NOT Reset _ /'

                                                                                                                & TAvg less than 551°F                                                 [;II' Time (15 minute prior to Criticality tracking or 30 minute (TAv g minus TRof) Deviation Alarm NOT Reset intervals)

[4] [5] DYes DYes DYes DYes D Yes DYes DYes D No D No D No D No D No D No D No D No D No [6] DYes DYes D Yes DYes DYes DYes DYes DYes DYes Time: Time: Time: Time: Time: Time: Time: Time: Time: Date: Date: Date: Date: Date: Date:

                                                  ~ No .~ No Date:

D No D No D No D No D No D No D No Initials ~ ~ [1] RECORD reason for this performance. PERFORM the following sequence every 15 minutes to document prior to criticality temperature tracking or every 30 minutes until (t avg minus tref) deviation alarm is reset: [2] RECORD current time (24 hour clock). [5] VERIFY RCS TAvg is Acceptable by checkoff in row [5]. [3] RECORD instrument (Ref. Appendix F) selected for lowest RCS temperature (TAvg) tracking (*) AND [6] RECORD whether Criticality is achieved or whether (TAvg minus T Ref) RECORD current RCS temperature to nearest whole number. Deviation Alarm is Reset by checkoff in row [6] AND [4] RECORD instrument (Ref. Appendix F) selected for next lowest RCS (TAvg ) tracking (*) RECORD Date & Time when accomplished. AND RECORD current next lowest RCS temperature to nearest whole number. Use additional sheets as required. (*)-Additionallnstrument ID recording needs entering only when changed within test progress.

Sequoyah Nuclear Plant Unit 1 & 2 General Operating Instructions 0-GO-4 POWER ASCENSION FROM LESS THAN 5% REACTOR POWER TO 30% REACTOR POWER Revision 0055 Quality Related Level of Use: Continuous Use ( Effective Date: 09-13-2007 Responsible Organization: OPS, Operations Prepared By: Betsy Parson / W. T. Leary Approved By: K. A. Perkins Current Revision Description Added a note prior to Step 5.2[1] to remind performer of the potential impact of changing Xenon concentration of core reactivity (07000359). Made an editorial revision to update references to chemistry procedure (07000362). Clarified conditional to be applied in Appendix F Step 1.0[14] (07000147). Re-Iocated steps associated with Exciter Cooling, control of Seal Oil temperatures, Core Condition Monitor and Stator Cooling from Section 5.4 to Appendix F (07000359). Added informational note regarding the relationship between T AVG and Reactor Power prior to Step 5.1[7] (07000280). THIS PROCEDURE HAS THE POTENTIAL TO IMPACT REACTIVITY.

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 2 of 104 Table of Contents

1.0 INTRODUCTION

4 1.1 Purpose 4 1.2 Scope 4

2.0 REFERENCES

5 2.1 Performance References 5 2.2 Developmental References 7 3.0 PRECAUTIONS AND LIMITATIONS 8 3.1 Precautions 8 3.2 Limitations 11 4.0 PREREQUISITES 13 5.0 INSTRUCTIONS 14 5.1 Actions To Be Performed Prior To Increasing Reactor Power 14 5.2 Reactor Power Ascension To Between 13% And 15% RTP 17 5.3 Turbine Roll 22 5.4 Placing Main Generator In Service 46 5.5 Reactor Power Ascension to 30% RTP 65 6.0 RECORDS 77 Appendix A: MODE 2 TO MODE 1 REVIEW AND APPROVAL. 78 Appendix B: FIGURE 1 STEAM GENERATOR LEVEL SETPOINT VS REACTOR POWER 81 Appendix C: MAIN FEEDWATER REG AND REG BYPASS VALVE INSTRUCTIONS 82 Appendix D: Turbine RotorBalance 87 Appendix E: Preparations for Turbine Roll 89 Appendix F: Preparations for Generator Synch 94 Source Notes 102 (

SON POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 3 of 104 Table of Contents (continued) ATTACHMENTS Attachment 1: UNIT START UP FROM LESS THAN 5% REACTOR POWER TO 30% REACTOR POWER (

SQN POWER ASCENSION FROM LESS 0-GO-4 ( Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 4 of 104

1.0 INTRODUCTION

1.1 Purpose This General Operating (GO) Instruction provides necessary instructions to perform a unit startup from less than 5% Reactor Power with main feedwater reg bypass valves in AUTO to 30% Reactor Power with main feedwater reg valves in AUTO. 1.2 Scope A. This GO contains the following sections: 5.1 Actions To Be Performed Prior To Increasing Reactor Power 5.2 Reactor Power Ascension to Between 13% and 15% RTP 5.3 Turbine Roll 5.4 Placing Main Generator In Service 5.5 Reactor Power Ascension to 30% RTP ( (

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 5 of 104

2.0 REFERENCES

2.1 Performance References A. 0-PI-NUC-092-002.0, Incore Excore Detector Single Point Alignment B. 0-PI-NUC-092-081.0, Prestartup NIS Calibration Following Core Load C. 0-PI-NUC-092-082.0, Poststartup NIS Calibration Following Core Load D. 0-PI-OPS-047-760.1, Main Turbine Actual Overspeed (Annual and 18 Month Tests) E. 0-PI-SXX-000-022.0, Calorimetric Calculations F. 0-RT-NUC-000-001.0, Restart Test Program G. 0~SO-35-1, Generator Hydrogen Cooling System H. 0-SO-35-2, Stator Cooling Water System I. 0-SO-35-4, Monitoring Generator Parameters ( J. 0-SO-35-6, Generator Core Condition Monitor K. 0-SO-35-7, Hydrogen Dryer Operation L. 0-SO-27 -1, Condenser Circulating Water System M. 0-SI-NUC-092-079.0, Power Range Monitor Channel Calibration By Incore-Excore Axial Imbalance Comparison N. 0-SI-OPS-092-078.0, Power Range Nuclear Flux Channel Calibration by Heat Balance Comparison O. 1,2~PI-OPS-057 -002.0, Cycling of Unit PCBs Prior to Placing PCB in Service P. 1,2-S0-5-1, Feedwater Heaters and Moisture Separator Reheaters Q. 1,2-S0-5-2, NO.3 Heater Drain Tank and Pumps R. 1,2-S0-5-3, NO.7 Heater Drain Tank and Pumps S. 0-SO-1-2, Steam Dump System T. 0-SI-NUC-000-038.0, Shutdown Margin ( U. 1-PI-OPS-000-020.1, OATC MCR Duty Station Shift Relief and System Status Checklists Modes 1-4

SQN POWER ASCENSION FROM LESS 0-GO-4 ( Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 6 of 104 2.1 Performance References (continued) V. 1-PI-OPS-057-001.0, Functional Testing of Low Voltage Bus Cooling Pumps W. 2-PI-OPS-0-00-022.1, OATC MCR Duty Station Shift Relief and System Status Checklists Modes 1-4 X. 0-'GO-5, Normal Power Operation Y. 0-SO-24-1, Raw Cooling Water System Z. 1,2-S0-47-2, Electro-Hydraulic Control System AA. 0-SO-85-1, Control Rod Drive System BB. SSP-6.24, Maintenance Management System Configuration Control CC. Switchyard Letter 14, Visual Confirmation of Motor Operated Disconnects and Power Circuit Breaker Operation DO. Switchyard Letter 32, Delle-Alsthom Airblast Circuit Breakers ( EE. TI-28, Curve Book FF. TI-40, Determination of Reconditioned Reactor Power GG. 0-PI-OPS-000-666.0, River Temperature Limits Specified by NPDES permit HH. SI-53, Specific Iodine Isotopic Activity Concentration and/or DEI-131 Determination II. SI-407.2, Radioactive Gaseous Waste Effluent Particulate and Iodine Dose Rates from Shield and Auxiliary Building Exhausts (Weekly/Special) and Condenser Vacuum Exhausts (Special) JJ. 0-SI-CEM-030-415.0, Gaseous Effluent Requirements (Gross Alpha, Noble Gas and Tritium KK. 0-SO-57-1, Main Bank Transformer Cooling LL. 0-SO-58-1, Main Generator Bus Duct Cooling System

saN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 7 of 104 2.2 Developmental References A. FSAR Section 13.5 B. 0-GO-2-3, Plant Startup From Less Than 5% Reactor Power To 30% Reactor Power

c. W letter GP 89-155, RIMS S57 891026972 D. W letter 86-02/B44 861112 002 E. W FAR 5-S0-3771-075 Response

(

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 8 of 104 3.0 PRECAUTIONS AND LIMITATIONS 3.1 Precautions NOTE Adherence to Precautions and Limitations is referenced in SPP-2.2. A. Reactor Engineering should be contacted for guidance on core operating recommendations during unusual power maneuvers such as startup during end of core life. [C.11] B. TRM 3.3.3.15 requires LEFM core thermal power (U2118) to be used to perform 0-SI-OPS-092-078.0 above 15% reactor power. LEFM indication is available if the following conditions are met:

• LEFM status NORMAL on ICS Calorimetric Data screen
• LEFM core thermal power (ICS point U2118) shows good (green) data.

(

• LEFM MFW header temp (ICS point T8502MA) greater than 250°F.

If LEFM indication is NOT available above 15% reactor power, then TR 3.3.3.15 action must be entered. C. During startup, NIS power range indication may be reading significantly higher than true power until calibration adjustments are made. The following should be used to determine the most accurate indication for comparison with NIS:

• When reactor power is less than or equal to 15%, use average loop ~T (U0485).
• When reactor power is greater than 15%, use LEFM core thermal power indication (U2118). If LEFM is NOT available, then continue using average loop

               ~ T up to 40%. (U1118 will be used above 40% with LEFM unavailable).

D. The boron concentration in the pressurizer should be maintained within 50 ppm of the RCS by use of pressurizer heaters and spray. E. Pressurizer enclosure temperature should be maintained less than 150°F. Rapid changes in pressurizer enclosure temperature may result in pressurizer safety valve simmer. (

SON POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 9 of 104 3.1 Precautions (continued) F. The low pressure turbine steam inlet temperature should be limited to 400°F when unit load is less than 10%. When reducing load, the reheater control valves should be adjusted to limit reheater outlet temperature to a maximum of 400°F within approximately 15 minutes after reaching 10% load. G. 00 NOT pass steam through the turbine with the rotor at rest. The turbine should be on turning gear anytime the main steam lines are pressurized up to turbine stop valves. H. Change in load should be controlled in accordance with load changing curves of TI-28, Figures A.15 and A.16. I. The turbine should be operated in 'IMP OUT" control during normal unit operation. "IMP IN" operation results in system swings and should only be used during the performance of valve tests. (W letter GP 89-155, RIMS S57 901-26 972) J. The Predictive Maintenance Engineer (POM) should be contacted following a unit trip so that he may determine if local vibration monitoring of the ( Turbine-Generator, by the POM staff should be performed when the unit is restarted. Normally, monitoring is necessary following a refueling outage, a major maintenance outage on the turbine-generator, or after a plant trip which was due to a turbine initiated trip or a generator electrical initiated trip. Two hours lead time prior to the initial turbine roll is necessary to ensure that the POM staff is onsite to monitor the start-up. The Maintenance Shift Supervisor (MSS) has the telephone numbers and pager numbers for the Predictive Maintenance Engineer and the Supervisor for the POM staff.

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 10 of 104 3.1 Precautions (continued) K. Any off frequency turbine operation is to be reported to the Component Engineering Group Vibration Engineer for record keeping. The report will include duration and magnitude of off-frequency operation. L. Operation at off-frequencies is to be avoided in order to prevent the probable occurrence of turbine blade resonance. Prolonged periods of operation at certain off-design frequencies could cause excessive vibratory stresses which could eventually generate fatigue cracking in the blades. Off-frequency operation is permitted to the degree and time limit specified on the chart "Off-Frequency Turbine Operation", Figure A.26 of TI-28. M. The valve position limiter should be periodically positioned approximately 10% above governor control indications (keeps governor valves off of the limiter) as turbine load is increased. This prevents inadvertent load increases by limiting governor valve opening and allows a faster response of the runback feature which ensures main feedwater system will supply the required amount of flow. N. The position of control rod bank 0 should normally be ~ 215 steps when power level is steady state at or above 85% RTP. At steady state power levels below ( 85%, control bank 0 should normally be ~ 165 steps. If rod position is more than 2 steps below this guidance for long term, then an impact to safety analysis assumptions may occur. Long term will be defined/determined by Reactor Engineering and the Fuel Vendor. O. At low power levels, the LP Heaters may be unbalanced in extraction steam supply use and heat pickup across the condensate side of the heater string. This condition should correct itself as the unit approaches 45-50% Turbine Power. (REF. PER 99-003789-000) P. Operation of main generator without automatic voltage control could impact grid voltage requirements. The South East Area Load Dispatcher (SELD) should be notified immediately if generator is in service without automatic voltage regulator. Also, refer to Section E of GOI 6 for MVAR limits. Q. Main Generator operation without Automatic Voltage control requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to Operations Duty Specialist (ODS) within twenty four (24) hours. R. Main Generator operation outside of the Voltage Schedule in GOI-6 requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to South East Area Load Dispatcher (SELD) within one (1) hour. (

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 11 of 104 3.1 Precautions (continued) S. 0-PI-OPS-035-001.0 should be performed prior to turbine restart when recommended by engineering, following maintenance or plant activities in which the generator was depressurized during a forced outage, or after a refueling outage. 0-PI-OPS-035-001.0 provides verification and adjustment of the Seal Oil System normal and backup regulators. (REF PER-04-24237-000) 3.2 Limitations A. After refueling operations, the NIS indications may be inaccurate until calibration at higher power levels. The NIS calibration procedures will adjust the PRM trip setpoints to ensure that the excore detectors do not contribute to an overpower condition. Prior to startup, the PRM high range flux trip setpoint will be adjusted from 109 to 60%, with the rod stop (C-2) remaining at 103%. [C.2] B. Preconditioned Power Levels and Maximum Allowable Rates of Power Increase are specified in TI-40, Determination of Preconditioned Reactor Power. C. During initial startups, based on Westinghouse recommendations, a lower ( power ramp rate limit has been implemented for power levels above the intermediate power threshold. The Intermediate Power Threshold is unit/cycle dependent and is determined by the Vendor. Refer to TI-40. D. ICS will automatically monitor pre-conditioned power level as follows:

1. Point U1127 is reactor power in percent of RTP based on either secondary calorimetric or RCS 8 T depending on power level.

2. Point U01 03 is a 20 minute rolling average of reactor power rate-of-change fitted over a 20 minute period. U0103 is a leading indicator of %/hour power ramp rate and can be used in deciding to speed up or slow down the ramp rate.

3. Point U01 04 is a 1 hour rolling average of reactor power rate-of-change fitted over a 1 hour period. U0104 is used in demonstrating compliance With fuel pre-conditioning power ramp rate limits.

4. Point K0058 is the currently qualified (or pre-conditioned) power level.

5. These points can all be monitored with the ICS group display "TI40".

Appendix A may be used if the ICS is unavailable. E. Any TI-40 power increase limit that is exceeded in anyone hour is evaluated in ( accordance with SPP-3.1.

SON POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 12 of 104 3.2 Limitations (continued) F. In the event of a change in the rated thermal power level exceeding 15% in one hour, notify Chemistry to initiate the conditional portions of SI-407.2 0-SI-CEM-000-050.0 and 0-SI-CEM-030-415.0 due to the thermal power change. G. The main turbine shall be on turning gear at least one hour prior to rolling with steam. H. Westinghouse should be contacted if the turbine is operated outside of its operating limits. I. To prevent high vibratory stresses and fatigue damage to the last stage turbine blading, do NOT operate the turbine for even brief periods outside of limits listed below: [W Ltr GP 86-02 (B44 861112 002)]

1. At loads less than or equal to 30% (350 MW), the maximum permissible backpressure is 1.72 psia. (3.5" Hg). The ICS Computer alarm point UP5007 which will identify.the condition of condenser pressure> 1.72 psia in conjunction with MW being < 350.

( 2. At loads greater than 30%, the maximum permissible backpressure is 2.7 psia (5.5" Hg) with a 5 minute limitation before tripping the turbine. J. Generator voltage shall NOT exceed 24.8 kV. K. The main generator field shall NOT be energized at less than 90% rated speed. L. Do NOT allow the generator to become under-excited. (

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 13 of 104 STARTUP ~ Unit J Date~ 4.0 PREREQUISITES NOTE Throughout this Instruction where an IFITHEN statement exists, the step should be N/A'd if the condition does NOT exist. [1] ENSURE Instruction to be used is a copy of effective version. [2] ENSURE Precautions & Limitation of Section 3.0 have been reviewed. [3] ENSURE Reactor Power is between 1 and 4% with four main feedwater bypass reg valves in AUTO. (N/A if manual bypass reg valve operation is allowed by Plant Manager) ( [4] ENSURE each performer documents their name and initials: Print Name Initials

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 14 of 104 STARTUP .vv-- Unitl Date~ 5.0 INSTRUCTIONS 5.1 Actions To Be Performed Prior To Increasing Reactor Power [1] ENSURE Prerequisites complete. NOTE Steps 5.1 [2] through5.1 [12] can be performed out of sequence. [2] IF O-GO-4, Appendix A, Mode 2 to Mode 1 Review And Approval is NOT current for this startup, THEN INITIATE Appendix A, while continuing with this instruction. I [3] IF the Mode 3 to Mode 2 to Mode 1 surveillance checklists are NOT current for this startup for Mode 1 entry, THEN ( REQUEST Periodic Test Coordinator to issue the Mode 3 to Mode 2 to Mode 1 surveillance checklists to the applicable departments. Initials Time Date [4] ENSURE Reactor Power is between 1 and 4% with four main feedwater bypass reg valves in AUTO. (N/A if manual bypass reg valve operation is allowed by Plant Manager) NOTE During start up after a cold shutdown the Condensate 01 normally will be aligned for full flow polishing until the MSRs are in service. [5] ENSURE Condensate 01 polishing operation in accordance with RCL recommendations.

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 ( REACTOR POWER Page 15 of 104 STARTUP ~ Unit 1 0.....-_ Date~ 5.1 Actions To Be Performed Prior To Increasing Reactor Power (continued) CAUTION After refueling operation, NIS indications may be inaccurate until calibration at higher power levels has been performed. RTP shall NOT be allowed to exceed 4% prior to the verification of the proper (or conservative) IR andPR setpoints. [6] IF startup is following a refueling, THEN [6.1] MAINTAIN reactor power between 3 to 4%. [6.2] VERIFY trip and permissive setpoints are within limits in accordance with 0-PI-NUC-092-082.0. [C.2] Rx Engineering Date Time ( [6.3] ENSURE P-10 actuation setpoint is less than the IR trip power level setpoint. [C.2] Rx Engineering Date Time [6.4] ENSURE all applicable portions of 0-RT-NUC-000-001.0 are complete. Rx Engineering Date ime NOTE The relationship between T AVG and reactor power with Steam Dumps in Pressure Mode while maintaining Steam Pressure is 0.52deg. F / %. MAINTAIN T AVG stable with the steam dumps in the pressure

                                                                                        /

[7] mode or with the SG atmospheric relief valves set at 84% or 1005 psig. [8] ENSURE 0-SI-NUC-000-038.0 shutdown margin calculation is complete (N/A if NOT required).

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 16 of 104 STARTUP ~ Unit ----l-'_ Date~ 5.1 Actions To Be Performed Prior To Increasing Reactor Power (continued) [9] ENSURE containment air temperatures are within limits in accordance with 1,2-SI-OPS-000-003.D, App. B. (TS 3.6.1.5) [10] INITIATE Appendix E , Preparations for Turbine Roll. [11] INITIATE Appendix F, Preparations for Generator Synch. [12] REVIEW TI-40 to determine applicable Preconditioned Power Levels and Maximum Allowable Rates of Power Increase. [13] VERIFY all applicable action steps in Section 5.1 are complete or initiated. ( [14] ENSURE Appendix A, Mode 2 to Mode 1 Review and Approval completed to verify all restraints to Mode 1 entry have been resolved and approvals for mode change granted.

                                                                            \~   vV'-

SM Signature Date Time END OF TEXT

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN S% REACTOR POWER TO 30% Rev.OOSS REACTOR POWER Page 17 of 104 STARTUP vv"- UnitL Date ~ S.2 Reactor Power Ascension To Between 13% And 1S% RTP NOTE The steam generator level operator is in control of unit startup until the main feedwater reg valves are in AUTO. [C.S] [1] REVIEW plant parameters and indications, AND VERIFY stability prior to reactor power escalation. NOTES

1) Adjusting blowdown flow will provide an additional method of controlling SG water inventory. (Close blowdown isolation valves only if level cannot be maintained)

2) Prior to increasing reactor power above 5%, SG blowdown should be in service.

3) Maximum blowdown rate is less than or equal to 270 gpm. Each steam generator

( flow, up to 60 gpm is indicated on panel L-357 located in the A.B. Supply Fan Rm. Minimum blowdown rate equals 5 gpm for each steam generator. Final blowdown rate should be determined by chemical analysis.

4) Computer points require a prefix 0, 1, or 2 be placed in front of the point number; for example,1F2261A.

[2] IF SG blowdown is in service, THEN ADJUST FIC-15-43 as desired. (plant computer pt. F2261A)

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN S% REACTOR POWER TO 30% Rev.OOSS REACTOR POWER Page 18 of 104 STARTUP _ Unit _ _ Date _ 5.2 Reactor Power Ascension To Between 13% And 1S% RTP (continued) NOTES

1) Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized during performance.

2) Recommended dilution rate is 50 to 75 gallon batches every 12 to 15 minutes for a steady power increase. Rod movement should be limited to 1/2 step increments approximately every 1 1/2 minutes. Dilution and rod movement rates may be adjusted depending on SG level control stability.

3) Control Rod withdrawal and / or dilution requirements may be significantly impacted by the change in core reactivity due to changing Xenon concentration.

[3] INITIATE a methodical and deliberate reactor power increase ( by manual adjustment of the control banks or by diluting the RCS. D MODE 1 [4] WHEN reactor power is above 5%, THEN LOG Mode 1 entry in the Unit Narrative Log. D [5] MAINTAIN the SG levels on program by periodically adjusting thefeedwater bypass reg controller level setpoints using Appendix Band C. D [6] IF Turbine roll in parallel with power increase is desired, THEN PERFORM Section 5.3 in parallel with the remainder of this section.

SON POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 19 of 104 STARTUP _ Unit _ _ Date - - - 5.2 Reactor Power Ascension To Between 13% And 15% RTP (continued) [7] IF the intermediate range rod stop setpoint is reached before P-10 energizes, THEN [7.1] STOP the power escalation. o [7.2] CONTACT Reactor Engineering to evaluate power range calibration. [C.3] Initials Time Date [8] WHEN reactor power is greater than or equal to 10% on at least 2 out of 4 PRMs, THEN [C.1] [C.3] [8.1] VERIFY annunciator XA-55-4A, window 0-5: P-10 NUCLEAR ( ATPOWER is LIT. PERMISSIVE o [8.2] VERIFY annunciator XA-55-4A, window B-5: P-7 LOW POWER TRIP BLOCK is DARK. o [8.3] COMPARE the highest reading PRM with the highest reading loop L\T indication to be within 5% of each other. [C.1] [C.3] o [8.4] IF the above conditional response is NOT attained, THEN A. STOP the power increase. o B. NOTIFY the SRO. Initials Time Date

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 20 of 104 STARTUP _ Unit Date _ 5.2 Reactor Power Ascension To Between 13% And 15% RTP (continued) NOTE The following step will block both IR (25%) and PR (25%) low power reactor trips. [9] BLOCK the IR HI FLUX reactor trip and PR LO Range HI FLUX reactor trip by performing the following: [9.1] PLACE IRM TRIP BLOCK P-10 [HS-92-50031 AND [HS-92-50041 to BLOCK. o [9.2] VERIFY annunciator XA-55-4A, window C-2: INTERMED RANGE TRAINS A & B TRIP BLOCKED is LIT. o [9.3] RELEASE [HS-92-50031 AND [HS-92-50041. D [9.4] PLACE PRM LOW POWER TRIP BLOCK P-10 [HS-92-50051 AND [HS-92-50061 to BLOCK. o [9.5] VERIFY annunciator XA-55-4A, window 0-1: POWER RANGE LOW SETPOINT TRAINS A & B TRIP is LIT. BLOCKED D [9.6] RELEASE [HS-92-50051 AND [HS-92-50061. D

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 21 of 104 STARTUP _ Unit _ _ Date _ 5.2 Reactor Power Ascension To Between 13% And 15% RTP (continued) [10] WHEN reactor power is between 13 and 15%, THEN [10.1] STOP power increase. o [10.2] STABILIZE the plant. o [11] IF rolling of second MFWP on recirc without pumping forward for testing or maintenance is desired, THEN PLACE second MFPT in service by performing the following: [11.1] RECORD which MFPT is to be tested. _ _ _ _MFPT [11.2] PLACE second MFPT in service in accordance with 1-SO-2/3-1 Sect. 8.12 or 2-S0-2/3-1 , ( Sect. 8.4.3. o [12] IF unit shutdown is required, THEN GO TO 0-GO-6, Power Reduction From 30% Reactor Power To Hot Standby. [13] ENSURE steps 5.2[1] through 5.2[11] of this section complete. (applicable steps) NOTE If Section 5.3 has already been initiated, then performance should continue at the step in effect. [14] IF rolling the turbine, THEN GO TO Section 5.3. END OF TEXT

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 ( REACTOR POWER Page 81 of 104 Appendix B (Page 1 of 1) FIGURE 1 STEAM GENERATOR LEVEL SETPOINT VS REACTOR POWER NOTE This figure does NOT represent the automatic S/G level program. The operating band provides a guide for Operators during Unit start-up and is intended to enhance S/G level control during transition from AFW level control to Bypass Reg valve control to Main Reg Valve control.

                 ,-,~-    -,-- ------                                         ----------~-~~----------
                    \
                      'I
                       \                                                     ..L
                                                                                                 \
                                                                                                   \

T -r

                                                                               \
                                                                                                     \
                           \
                             \,

( , T

                                                                                                         \
                                 \
                                   ,                                                                       I.
                                 \"                                                                       \""
                                    \
                                     \
                                       \                                             \                        I
                                                                                                                ~
                                                                                 ~\
                                     ..."...                                                                   T I

I. I. \

                                                                                                                     -r"'

l \ i: \'

                                                  \

o 1

                                                                                                                           \
                                                     ..\                      1t~

irle: \ '""""\\

                                                         \
                                                           \
                                                             \
                                                              \
                                                                              ~  ct        \

I.

                                                                                                                               -+-

1

                                                                                                                                     \
                                                                                                                                       \
                                                            -t-                                                                     .......                 .~
                                                                                           \
                                                                \                                                                        \
                                                                  \
                                                                    \
                                                                  ....\--

I.

                                                                      \                                                                         t
                                                                        \                                                                         \,.     ~

l-

                                                                                                                                                    \.
                                                                          '.                 I \
                                                                                                                          '<I
                                                                                                                          "',                       r',

I I N

                                                                                                                                                            ~

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 82 of 104 Appendix C (Page 1 of 5) MAIN FEEDWATER REG AND REG BYPASS VALVE INSTRUCTIONS 1.0 REG BYPASS CONTROLLER LEVEL SETPOINT ADJUSTMENTS CAUTION It is VERY important that adjustments to reg valves are made SLOWLY with the operator observing indicators to verify the desired results. This point cannot be over stressed as it is a key point to a successful startup. NOTES

1) The SG reg bypass controller should be adjusted on only ONE SG at a time. [C.5]

2) The reg bypass controller should be in MANUAL prior to adjusting setpoint value to prevent controller gain input change.

( [1 ] WHEN reg bypass controller level setpoint requires adjustment, THEN PERFORM the following steps on one reg bypass valve at a time: [C.5] (N/A valves NOT adjusted) [1.1] REFER TO Appendix B for allowable setpoint. SG-1 SG-2 SG-3 SG-4 0 0 0 0 [1.2] PLACE reg bypass controller in MANUAL. SG-1 SG-2 SG-3 SG-4 0 0 0 0 NOTE Allow sufficient time for the reg bypass to respond. [1.3] STABILIZE SG level at a desired level. SG-1 SG-2 SG-3 SG-4 0 0 0 0 [1.4] ADJUST controller setpoint in small increments while I monitoring SG level. \ SG-1 SG-2 SG-3 SG-4 0 0 0 0

SON POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 83 of 104 Appendix C (Page 2 of 5) STARTUP Unit Date - - - 1.0 REG BYPASS CONTROLLER LEVEL SETPOINT ADJUSTMENTS (continued) [1.5] PLACE reg bypass controller in AUTO. SG-1 SG-2 SG-3 SG-4 o 0 o o [1.6] ALLOW the plant to stabilize before adjusting another valve setpoint. SG-1 SG-2 SG-3 SG-4 o 0 o o 2.0 DAMPENING SG LEVEL OSCILLATIONS WITH FEEDWATER REG BYPASS VALVES IN SERVICE NOTES (

1) Perform adjustments to one SG at a time. Allow Plant Parameters to Stabilize between valve adjustments. [C.5]

2) The wide range level recorders may respond to a change in level before the narrow range indicators. [C.5]

3) Indicated flowrate on the feed flow indicators may NOT reflect an accurate value of flow. The flow indication is to be used as a reference value only. [C.5]

4) The following step may be performed any time SG level oscillates outside the SG level setpoint operating band of +/-5 percent.

[1] IF required to dampen SG level oscillations at any time during SG level control with the reg bypass controllers in AUTO, THEN PERFORM the following: [C.5] [1.1] PLACE the reg bypass controller in MANUAL. o [1.2] CHANGE valve demand position LESS THAN 10 percent in the opposite direction of valve travel. o [1.3] PLACE the reg bypass controller in AUTO. o

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 84 of 104 Appendix C (Page 3 of 5) STARTUP Unit Date _ 3.0 POSITIONING MAIN FEEDWATER MAIN REG VALVES OFF SEAT DURING UNIT STARTUP NOTES

1) After a main reg is adjusted DO NOT increase reactor power or open main reg further until plant stabilizes and SG level returns to program. ALLOWING PLANT PARAMETERS TO STABILIZE BETWEEN REG VALVE ADJUSTMENTS IS THE KEY TO SMOOTH POWER ASCENSION.

2) Anticipate level shrink when the main reg comes off its seat. [C.5]

3) Use main feedwater flow indication to determine when main reg valves come off seat.

[1 ] PERFORM the following steps to position main reg valves off seat: ( [1.1] REVIEW plant parameters and indications prior to initial opening. SG-1 SG-2 SG-3 SG-4 0 0 0 0 [1.2] OPEN the main feedwater reg valve in small increments while maintaining the reg bypass valve between 25 and 60 percent open. SG-1 SG-2 SG*3 SG-4 0 0 0 0 [1.3] ENSURE reg bypass valve starts closing when main reg valve is opened. SG-1 SG-2 SG*3 SG-4 0 0 0 0 [1.4] ENSURE SG level returns to reg bypass controller setpoint when main reg valve is adjusted. SG-1 SG-2 SG-3 SG*4 0 0 0 0 [1.5] ENSURE SG level and MFW system stabilizes before performing subsequent valve adjustments. SG-1 SG-2 SG-3 SG-4 0 0 0 0

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 85 of 104 Appendix C (Page 4 of 5) STARTUP Unit - - Date --- 4.0 PLACING FEEDWATER MAIN REG VALVES IN AUTOMATIC CAUTIONS

1) DO NOT place a main reg valve in AUTO without sufficient flow being indicated on the controlling steam/feed flow indicators.

2) Both MFW reg and reg bypass controllers should NOT be left in AUTO simultaneously for an extended period. [C.5].

[1] WHEN desired to place main feedwater reg valves in AUTO, THEN PERFORM the following: [1.1] ADJUST SG level to SG program level setpoint, and ADJUST the main reg valve to obtain near zero ( deviation (between -5 percent and +5 percent) while matching steam and feed flows. SG-1 SG-2 SG-3 SG-4 o 0 o o [1.2] WHEN controller deviation is near zero, THEN PLACE the main reg valve in AUTO. SG-1 SG-2 SG-3 SG-4 o 0 o o [1.3] VERIFY the main reg valve is controlling SG level. SG-1 SG-2 SG-3 SG-4 o 0 o o

SQN POWER ASCENSION FROM LESS 0-GO-4 Unit 1 & 2 THAN 5% REACTOR POWER TO 30% Rev. 0055 REACTOR POWER Page 86 of 104 Appendix C (Page 5 of 5) STARTUP Unit Date - - - 4.0 PLACING FEEDWATER MAIN REG VALVES IN AUTOMATIC (continued) [1.4] PLACE the associated reg bypass valve in MANUAL. SG-1 SG-2 SG-3 SG-4 o 0 0 o [1.5] CLOSE the reg bypass valve in small increments, AND ENSURE the main reg valve responds to control SG level. SG-1 SG-2 SG-3 SG-4 o 0 o o [1.6] WHEN main reg valve is controlling SG level, THEN ( PROCEED TO another SG loop. SG-1 SG-2 SG-3 SG-4 o 0 o o

I Appendix D Scenario Outline Form ES-D-1 I Facility: Sequoyah Scenario No.: 4 Op Test No.: NRC Examiners: Operators: nd Initial Conditions: -41 % Power BOL Ready to Increase Power and Roll 2 Main Feedwater Pump. Turbine Driven Auxiliary Feedwater Pump OOS for maintenance Turnover: Continue plant startup. Currently at O-GO-5 Section 5.1, Step 23. Target CTs: Insert Negative reactivity using rods or boration prior to completion of FR-S.1 Step 4. Close MSIVs and Stop/Isolate AFW flow to Faulted S/G prior to transition out of E-2 but prior to orange path FR-P.1 being reached. Event Malf. No. Event Event No. Type* Description nd 1 N/A R-ATC -41 % Continue Power increase to Roll 2 MFP N-SRO/BOP ( 2 RX06A TS-SRO Controlling Pressurizer level transmitter fails low LT 68-339. Results in letdown isolation which requires restoration. Tech Spec I-SRO/ATC Evaluation. 3 RX16D TS-SRO Steam Generator # 4 narrow range level transmitter fails low. Tech Spec Evaluation. I-SRO 4 RX24 I-SRO/BOP Feed Water Header Pressure Transmitter PT-3-1 Fails Low. MFP Speed will increase requiring manual control. 5 MS06C C-SRO Small Steam Leak Outside Containment Upstream Of MSIV On Loop 3. (Non-Isolable) 6 MS06C M-AII Steam leak increases to large break requiring Reactor Trip and Safety Injection. 7 RP01C C-AII Both Reactor trip Breakers fail to trip automatically or manually resulting in ATWS. 8 RD09 C-SRO/ATC Rods Fail to move in auto but will move manually 5 seconds after turbine trip. 9 FW04C C-SRO/BOP Motor Driven AFW Level Control Valve To Loop 3 S/G (Faulted) Fails Full Open. Requires Stopping AFW Pump Or Local Isolation To Stop Feedwater To Faulted S/G.

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

( Appendix D NUREG 1021 Revision 9

I Appendix D Scenario Outline Form ES-D-1 I Scenario 4 Summary Crew will assume shift at approximately at -41 % reactor power with direction to continue plant startup. Crew will continue power increase and roll second Main Feedwater Pump (MFP). When the Main feedwater pump has been rolled, and adequate power change has been performed to demonstrate proficiency, the controlling pressurizer level channel will fail low. This will result in letdown isolation, channel defeat, and restoration of letdown as directed by the AOP. SRO will evaluate and enter applicable Technical Specifications. Following restoration of letdown, a Steam Generator #4 narrow range level transmitter will fail low. No plant transient will result due to the median selector circuit. SRO will direct AOP and evaluate and enter applicable Technical Specifications. Feedwater header pressure transmitter PT-3-1 will fail low resulting in MFP speed increasing to attempt to restore steam header to feedwater differential pressure to program. This will require manual control of MFP speed. AOP will be performed; however, MFP speed will have to remain in manual. When plant is stable a small unisolable steam leak will occur on loop 3 Steam generator outside containment upstream of the Main Steam Isolation Valve. Crew will perform actions of the AOP to stabilize the plant and monitor key parameters for Reactor trip. When the small steam leak has been addressed, the steam leak will be increased to a significant break requiring Reactor Trip and Safety injection. When manual reactor trip is actuated, both reactor trip breakers will fail to open automatically and manually resulting in an ATWS and entry ( into contingency procedure FR-S.1. During response to the ATWS, control rods will initially insert in automatic but stop after -5 seconds requiring manual rod insertion. When the Reactor is shutdown and Safety injection has occurred, the auxiliary feedwater supply valve to the faulted S/G will fail full open requiring that the associated AFW pump be stopped to stop feed flow to the faulted S/G. Local isolation of the failed AFW valve may also initiated. The scenario may be terminated when crew transitions out of emergency procedure E-2. Appendix D NUREG 1021 Revision 9

Page 1 of 2 NRC08D Rev 0 CONSOLE OPERATOR INSTRUCTIONS Sim. Setup Reset IC- --1H- Initialize simulator at -41 % % RTP BOL. Perform switch check. Allow the simulator to run for at least 3 minutes Place Mode_1_placard on panels. before loading SCEN file or starting the exercise. This will initialize ICS. Place-A-Train Week sign on the simulator. Load SCENS: NRC08D Set Ranges on Tave/Tref Recorder on 1-M-6 to +/- 3 degrees for current conditions Place simulator momentarily in RUN, (System Menu/Strip Chart Assign ... Tab through to Place OOS equipment in required fix) position with tags, Clear alarms and Return to FREEZE. These remote IMF FW07C f:1. TDAFW PUMP IS INOPERABLE. functions are active lOR ZLOHS151A_GREEN f:O when the SCENS file lOR ZLOHS117A_GREEN f:O Close FCV-1-17 & 18 & place Hold Notice on HS-is loaded. lOR ZLOHS118A_GREEN f:O 1-17&18 and FCV-1-51. lOR ZLOHS3136AA_GREEN1 f:O Also place Hold order on TDAFW Pump ERCW lOR ZLOHS3136AA_GREEN2 f:O supply valves. lOR ZLOHS3136AA_RED1 f:O lOR ZLOHS3136AA_RED2 f:O Place Protected Equipment Tags on MD AFW lOR ZDIHS3136AA f:O Pumps. ( lOR ZLOHS3179AA_GREEN1 f:O lOR ZLOHS3179AA_GREEN2 f:O lOR ZLOHS3179AA_RED1 f:O lOR ZLOHS3179AA_RED2 f:O lOR ZDIHS3179AA f:O Event #1: Increase Use Remote Functions FWR10A and -41% POWER, READY TO INCREASE POWER Power as determined FWR10B to adjust feedpump speed. AND START 2ND MAIN FEEDWATER PUMP, by NRC Examiner. FWR10A=3360 over 30 sec period and CONTINUE PLANT STARTUP. FWR10B=3300. OR adjust as necessary as requested by crew. Event #2: When IMF RX06A f:1 k:1 CONTROLLING PZR LEVEL TRANSMITTER FAILS Power Increase LOW CHNL LT 68-339 complete as determined by NRC When IMs or MSS contacted to trip bistables, Examiner, Insert this inform the crew that the IMs will report to the Malfuinction using MCR in - 45 minutes. Key 1 Event #3: When IMF RX15D f:O k:2 STM GEN LEVEL TRANSMITTER FAIL, CNTRL Determined by NRC CHNLS SG #4 LT 3-106. Exam iner, insert this Malfunction using When IMs or MSS contacted to trip bistables, Key 2. inform the crew that the IMs will report to the ( MCR in - 45 minutes.

\ ,

Page 2 of 2 NRC08D Rev 0 CONSOLE OPERATOR INSTRUCTIONS Event #4: When IMF RX24 f:1 k:3 FEED WATER HEADER PRESSURE Determined by NRC TRANSMITTER FAILS LOW; PT-3-1. Examiner, insert this Malfunction using If dispatched to check instrument locally, wait -5 Key 3. min and report no obvious problem locally. Event #5: When IMF MS06C f:25 k:4 MAIN STEAM LINE LEAK OUTSIDE Determined by NRC CONTAINMENT - LP3 UPSTREAM OF MSIV. Examiner, insert this Malfunction using If Dispatched to look for steam or feedwater leaks Key 4. wait -amtn and report steam coming from the East Valve vault room. Event #6: When MMF MS06C f:75 r:300 INCREASE STEAM LEAK TO RUPTURE OVER 5 Determined by NRC MIN REQUIRING RX TRIP AND SAFETY Examiner, Modify this INJECTION. Malfunction. If Dispatched to look for steam or feedwater leaks Note: If Crew Elects wait -3min and report steam coming from the to manually trip for East Valve vault room. small steam leak, modify when manual If dispatched previously, report leak much worse ( rip attempted. when asked. Event #7: These IMF RP01C f:1 BOTH REACTOR TRIP BREAKERS FAIL TO OPEN Malfunctions are ON MANUAL OR AUTO TRIP SIGNALS. ATWS active when the CONDITION ESTABLISHED. SCENS file is loaded. When dispatched to IRF RPR05A f:1 d:180 k:5 OPENS BOTH REACTOR TRIP BREAKER Open Rx Trip IRF RPR05B f:1 d:183 k:5 LOCALLY 3 SEC APART AFTER 3 MIN DELAY. Breakers locally insert these remote functions immediately using KeyS Event #8: Event IMF RD09 f:1 e:7 d:10 RODS FAIL TO MOVE IN AUTO 10 SECONDS Trigger 10 seconds AFTER TURBINE TRIP. after Turbine Trip. Event #9: Event IMF FW04C f:1 e:2 MDAFW TO #3 S/G LCV-3-148 FAILS FULL OPEN. trigger, inserted at time of SI. When dispatched to check valve locally, wait -3 to 5 minutes, and inform crew that the valve is full open but not sure what the problem is. If Requested to close IRF FWR05 f:O k:6 POSITION MDAFW ISOLATION VLV-3-826 LP 3 nan isol vlv for loop 3 (Isolates Main and Bypass valves) I MDAFW LeV use When Dispatched wait - 5 min and report closed. Key 6

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # Page 1 of 35

                                                                 .....;...----                    .....;;.;;.~l nd Event

Description:

Power increase and 2 MFPT Roll Time II Position II Applicant's Actions or Behavior Console Operator: No action required for event 1 Indications Available: None Applicable Direct load increase from -41 % power in accordance with 0-GO-5, SRO Normal Power Operation, beginning in Section 5.1, at Step 23. NOTE With verbal approval from the Operations Superintendent, placing the second main feed pump in service may be deferred until power is approximately 55% (Unit 1) or 65% (Unit 2). Logic prevents opening the standby MFPT condenser isolation valves if the pump is NOT reset prior to exceeding 9 million Ibs/hr flow on the running pump. ( WHEN approximately 40 to 45% turbine load, THEN SRO PLACE second MFPT in service by performing the followinq: IF the Operations Superintendent has approved one MFP operation duri,ng, tile power ascension, THEN A. 1.RECORO which MFPT is in service. SRO MFPT B. MONITOR loading of the rvlFP in service as load is increased. (Step is N/A Second MFPT is to be placed in Service) WHEN second MFPT is to be placed iin service, THEN SRO/BO P PLACE second MFPT in service in accordance with 1..2-50-2/3-1 . Evaluator Note: The following steps are from 1-S0-2/3-1 Section 5.16.4 beginning at step 15. The preceding steps of the SO were previously performed and snapped into the Scenario Initial Conditions. (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # Page 2 of 35

                                                                --'-----                         ---II

( Event

Description:

Power increase and 2 nd MFPT Roll Time Position II Applicant's Actions or Behavior OPEN Governor Valve by PERFORMING one of the following:

• IF MCR operation of Governor Valve Positioner is available, THEN
• PLACE the applicable Governor Valve Positioner to the BOP RAISE position to open the steam chest valves and accelerate the MFPT:

MFPT HAN DSWITCH POSITION B GV Positioner 1-HS-46-40A OPEN CAUTION DO NOT increase second MFPT speed faster than the master speed control can maintain program dip. NOTE As the second MFPT is loaded, the first MFPT should back down in load. ( SLOWLY LOAD the second MFPT to raise MFPT speed until demand on MFPT speed controller matches the demand output BOP of the first MFPT. ENSURE MFP Injection Water Intermediate Leakoff Pressure for BOTH MFPs is at least 250 psig.

                                       *   [1-PI-54-2], 1A MFP AND
                                       *   [1-PI-54-6], 1B MFP BOP ENSURE MFP Injection Water Differential Pressure for pump started is equal to or greater than 25 psid.
                                       * [1-PDI-54-1], 1A MFP OR
                                       * [1-PDI-54-5], 1B MFP WHEN the output meter for the SIC for the second MFPT matches the output meter on the Master Controller, THEN BOP         PLACE the second MFPT SIC in AUTO.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # .....;.. Page 3 of ....;3;.;;.5---11 nd Event

Description:

Power increase and 2 MFPT Roll Time II Position I Applicant's Actions or Behavior CLOSE the second MFPT drain valves 1B Drain Valves 1-HS-BOP 46-41 CLOSED CAUTION 1 MFP Recirc valves controllers should NOT be operated in AUTOMATIC due to the potential for isolating all three intermediate heater strings and resulting MFP damage. CAUTION 2 Operation of MFP RECIRC valve should be performed slowly due to affect on MFP DP program. ENSURE [1-FCV-3-70] or [1-FCV-3-84] MFP Recirc valve is BOP CLOSED and in MANUAL. CAUTION Failure to readjust the minimum speed on the second MFWP could result in the second MFWP being unable to supply adequate feed flow in the event the first MFWP trips. NOTE The following step may be performed in parallel with power increase but should be completed prior to exceeding 55% power. WHEN MFWP speed controllers [1-SIC-46-20A] and [1-SIC-46-20B] are in AUTO, THEN PERFORM the following to adjust the minimum speed on the second MFWP:

• VERIFY both MFWP speed controller bias settings at 50% .
• NOTIFY MIG to slowly adjust the hand speed changer on the second MFWP so that the MFWP speeds are equal.

Continue directing power increase in accordance with 0-GO-5. Using Dilution, Rod WID and Turbine load increase to maintain SRO Tavg on program and AFD. Evaluator Note: The following Steps are from 0-SO-62-7 Boron Concentration Control, Section 6.2, Dilute CAUTION 1: When making an RCS dilution of 2..3000 gallons, it should be done in batches with an RCS boron concentration verification at the halfway point (e.g., 1500 gallons). Allow at least 15 minutes between batches.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # Page 4 of 35

                                                              -----                               "';';~"'I Event

Description:

Power increase and 2nd MFPT Roll Time I Position II Applicant's Actions or Behavior CAUTION 2; Returning the Boric Acid Blender to service after unplugging, cleaning, or maintenance on the Boric Acid System could introduce debris, sludge, air or chunks of solidified boron into the CCP suction resulting in pump damage. Extreme care must be exercised to properly flush the Boric Acid Blender system following an outage. NOTE 1: If an excessive amount of dilution is required (plant startup), the pressurizer heaters should be energized to cause pressurizer spray operation for equalizing boron concentration in RCS and pressurizer. NOTE 2: Dilute mode will be used anytime a long-term positive reactivity addition is desired. The operator should use the normal dilute mode whenever conditions permit. ENSURE unit is NOT in a Tech Spec or TRM action that RO prohibits positive reactivity additions. NOTE: HUT level increase of 1% is equal to 1380 gallons (TI-28 fig. C.21) ENSURE sufficient capacfty avai:lable in the HUT selected to receive expected amounts of cvcs ietoown: (NfA jf not used) RO HUT LEVEL INITriALS A  % B  % ENSURE makeup system is aligned for AUTO operation in RO accordance with Section 5.1. RECORD the quantity of dilution water required to achieve RO desired boron concentration using Appendix D. (N/A for minor power changes) NOTE Due to eyeball interpolation the verified calculation may slightly differ from the initial calculation. The following signoff indicates that any differences in the two results have been discussed and are close enough to be considered validated. PERFORM Appendix I Independent Verification of Calculation for Amount of Boric Acid or Primary Water. (N/A if App. D was SRO performed by SRO to verify data from Rx Engineering) (Step not required provided in shift turnover package) PLACE [HS-62-140A], Boric Acid Supply to Blender Flow RO Control Switch to the STOP position.

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # Page 5 of 35

                                                                 -----                             """;";'--11 Event

Description:

Power increase and 2nd MFPT Roll Time II Position I Applicant's Actions or Behavior PLACE [HS-62-140B], CVCS Makeup Selector Switch to the RO DILUTE position. ENSURE [HS-62-140D], Boric Acid Valve to the Blender is RO CLOSED (Green light is LIT). RO SET [FQ-62-142], Batch Integrator for the desired quantity. NOTE: Primary Water Flow Controller [FC-62-142] receives its reference signal (70 gpm) from setpoint potentiometer (dial indicator) located on panel M-6. A setpoint of 35% corresponds to a 70 gpm primary water flow rate. ADJUST [FC-62-142], Primary Makeup Water Flow Controller RO for the desired flow rate. PLACE [HS-62-140A], Boric Acid Supply to Blender Flow RO Control Switch to the START position. NOTE: Flow oscillations and/or erratic controller response may require manual operation of Primary Water Flow Controller [FC-62-142] until stable conditions exist. VERIFY the following; ( RO [a) Inlet to top of VCT [FC'J-62-128) is OPEN. [b] Primary Water flow by (FUi2-142A] OR (FO-'62-142l NOTE: Alternate dilution in small amounts is acceptable on a regular basis, provided no significant changes in seal water temperature or seal leakoff are indicated. Batches of 5 to 10 gallons may be added through FCV-62-144 on a frequency not to exceed once per 30 minutes. ICS points for No. 1 seal leakoffs and seal water temperatures on the RCPs should be monitored durinq and after dilution. U: primary water addition to tne bottom of the VeT n::cv-62-144] is desired, THEN [a] CLOSE [FOJ-62-128] with [HS-62-1231 RO [b] OPEN [FC\l~62-144] with [HS-62-1441. [el VER1FY Primary Water flow by (FI.",62-'142A] OR (FO-62-142]. NOTE: It may take approximately 15 minutes before any changes to reactivity are indicated on nuclear instrumentation or RCS temperature indication. MONITOR nuclear instrumentation and reactor coolant RO temperature to ensure the proper response from dilution.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # .-;... Page 6 of 35 nd Event

Description:

Power increase and 2 MFPT Roll Time Position Applicant's Actions or Behavior IF [L1-62-129] , Volume Control Tank Level, increases to 63 RO percent, THEN ENSURE [LCV-62-118], Volume Control Tank Divert Valve OPENS to divert excess water to the Holdup Tanks. WHEN dilldion is complete, THEN (a] PLACE [HSc62-140A), Boric Acid to Blender Flow Control Switch to the STOP posnioo. [b] IF [FCV-62-144) was previously OPENED, THEN RO Cl.OSE (FeV-62-144] with [HS-62-144). [e] VER.IFY no primary water flow on either (FI-62-142AJ OR (FQ-62-142]. Ed] ENSURE [FCV-6.2-128] is CLOSED. Lead Examiner may direct initiation of the next event at his discretion. Steps on the next two pages are associated with performance of repetitive dilutions or may not be performed until all dilutions are complete. ( RO [17] IF power increase in progress and additional dilutions will be required,THEN use this table to re-perform steps [4] through [18]. (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # -.;.. Page 7 of 35 nd Event

Description:

Power increase and 2 MFPT Roll Position A licant's Actions or Behavior STEP 1'" 2"Y J'" [4] RECORD the quantit]' of dilution water required to achieve desired boron concentration using Appu,mdix D. [5] PERfORM Appendix l, IV of Calculation for amount of SA or PV!'

    '[0] PLACE fHS-6:l-140Al Boric Acid Supp'ly to Blender Flow Control Switch to the STOP position.
    '[1] PLACE [HS~62-14{jB}, eves Makeup Selector Switch to the DILUTE positiofL              0        0          0

[3] ENSURE fHS-62-140Dj Boric Acid Valve to Blender is CLOSED (Green light lIT}. 0 0 D [9] SET fFQ-62-1421, Batch integrator for the desired quantity. f J  ! l~ CV 1~ CV fa. C¥ [10] ADJUST [fC-62-142], Primary Makeup tater flow Controller for the desired f J  ! flow rate. 7cv 7*-;:; re;- [11] PLACE [HS-62-140A), 5A Suppl'y to mender flow Control Switch to START. f  !  ! 1~ rM 1~ c't' t-- -cv [12] VERIFY the foHowing: [a] InIet to top of VCT [FCV-62-128] is OPEN. 0 0 D [b] Primary V'later flmv by [fI-6Z-142A] or [FQ-62-1421 0 0 D [13] IF PV'V' addition to top afVCT [FCV-62-128J. is not warranted, but PW addition to the bottom of the \lCT [FCV-62-1441is desired, THEN [a) CLOSE [FC\}-62-128]with [HS-62-128] DOD ( [b) OPEN [FCV-62-144] with [HS-62-144]. DOD [e] VERIFY Primary l/<iater now by [FI-62-142A J or [FQ-62-1i421 DOD [14] MONnOR nuclear instrumentation and reactor coolant temperature to ensure the proper response from dilution, DOD [15] IF ILI-6l-US], VCTleveI, increases to 63 percent, THEN ENSURE rLCV~62-118], VCT Divert Valve, OPENS [.0 divert excess water to the HUTs. DOD

    '[16] WHEN dilution is complete, THEN

[a] PLACE fHS-62-140Al. Boric Acid to Stender flow Control S'N/teh ta STOP [b) IF [FCVc62-144] was previously OPENED, THEN CLOSE [FO/-62-144]

                'tlith [HS-62-144].                                                             DOD

[e] VERIFY no primary vilater flow on either IF/ c62-14M] or [FQc02-142]. DOD [d) ENSURE ifCV-62-128] is CLOSED. DOD [18]IF step [17] wilf: be repeated, THEN P:ERfORM the foHmvil1g: [a] PLACE [HS-62-140Bl, eves Makeup Selector SWitch to lheAUTO posmon. [13] PLACE [HS-62-140Al, SA to Blender Flow Control Switch to START position. [el .ENSURE dilution is logged in Hnit Narrative Log. REALIGN the blender controls for AUTO makeup to the RO eves in accordance with Section 5.1 RO ENSURE dilution(s) is ioqced in Unit Narrative Log.

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # -.;.. Page 8 of 35 ( Event

Description:

Power increase and 2 nd MFPT Roll Time II Position II Applicant's Actions or Behavior NOTE Sample may be obtained at normal RCS sample intervals provided the unit is at power and the unit response following the dilution is as expected. IF RCS boron sample is required, THEN NOTIFY Chem Lab to obtain RCS boron sample. ( (

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 2 Event

Description:

Controlling Pressurizer Level Channel Fails Low Time II Position II Applicant's Actions or Behavior Booth Instructor: When directed, initiate event 2 Indications available: 1-AR-M5-A, C3, PRESSURIZER LEVEL HIGH-LOW 1-AR-M5-A, E3, PRZR LVL LOW HEATER OFF & LETDOWN SECURED 0-AR-M27B-B, A5, LETDOWN HX OUTLET FLOWITEMP ABNORMAL Refer to alarm response procedures Crew Direct entry to AOP-1.04, Pressurizer Instrument Malfunction, US section 2.2 NOTE: Appendixes "I" is a layout of PZR level control provided for operator reference. ( CHECK L1-68-339 indicates NORMAL. (NO) PERFORM the following: RO

• ENSURE LEVEL CONTROL CHANNEL SELECTOR switch XS-68-339E in LT-68-335 & 320.
• ENSURE LEVEL REC CHANNEL SELECTOR switch XS-68-339B in LT-68-320 or LT-68-335.

CHECK letdown IN SERVICE. (NO) RO

• RESTORE letdown USING EA-62-5, Establishing Normal Charging and Letdown.

Evaluator Note: The following steps are from EA-62-5 performed by the RO to reestablish Letdown. SRO may continue in AOP-I04 with Tech Spec Evaluation etc .. NOTE EA-62-3, Establishing Excess Letdown, may be utilized if Normal Letdown cannot be established.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 2 Event

Description:

Controlling Pressurizer Level Channel Fails Low Time II Position I Applicant's Actions or Behavior IF charging flow NOT established, THEN PERFORM Section 4.2. (Charging flow is established) RO VERIFY pressurizer level greater than 17%. RO ENSURE letdown orifice isolation valves CLOSED:

• FCV-62-72 RO
• FCV-62-73
• FCV-62-74 OPEN letdown isolation valves:
• FCV-62-69 RO
• FCV-62-70
• FCV-62-77

( NOTE Placing cooling water on the Letdown Heat Exchanger prior to restoring letdown flow should prevent TIS-62-79B/A from actuating and fully opening TCV-70-192. PLACE [HIC-62-78] in MANUAL, AND OPEN [TCV-70-192] to

                                 - 50%.

RO PLACE letdown pressure controller [PCV-62-81] in MANUAL and ADJUST output between 40 and 50%, (50%-60% open). RO ADJUST charging flow as necessary to prevent flashing in the letdown line. RO OPEN letdown orifice isolation valves as needed:

• FCV-62-72 RO
• FCV-62-73
• FCV-62-74

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 2 of 35 Event

Description:

Controlling Pressurizer Level Channel Fails Low Time II Position II Applicant's Actions or Behavior NOTE Normal letdown pressure is 325 psig at normal operating temperature. ADJUST letdown pressure controller [PCV-62-81] output RO to obtain desired pressure. ADJUST letdown pressure controller [PCV-62-81] setpoint RO to match existing pressure. PLACE letdown pressure controller [PCV-62-81] in AUTO. RO NOTE Normal letdown temperature is -100°F. ADJUST [HIC-62-78A] to obtain desired letdown temperature, RO as indicated on [T1-62-78]. PLACE [HIC-62-78A] in AUTO. RO NOTE Letdown temperature may swing due to repeated actuation of TIS-62-79B/A, which causes letdown temperature control valve TCV-70-192 to fully open. IF necessary to stabilize letdown temperature, THEN PERFORM the following:

• PLACE [HIC-62-78A] in MANUAL and ADJUST RO controller output in OPEN direction.
• WHEN letdown heat exchanger outlet temperature is stabilized at approximately 100°F, THEN PLACE [HIC-62-78A] in AUTO.

ENSURE high temperature divert valve [HS-62-79A] in DEMIN RO position. ADJUST charging and letdown as necessary to maintain RCP RO seal injection flow and pressurizer level.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 2 of 35 Event

Description:

Controlling Pressurizer Level Channel Fails Low Time Position Applicant's Actions or Behavior EVALUATE the following Tech Specs for applicability:

• 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation.

Enters action 6. US

• 3.3.3.5 Remote Shutdown Instrumentation
• 3.3.3.7 Accident Monitoring Instrumentation. Enters action 2.
• 3.4.4 Pressurizer. For Heaters, momentary entry for action (a) due to cutoff.

ENSURE pressurizer heaters restored to service. RO CAUTION: RCS pressure changes and changes in RCS boron concentration (due to differences between pzr and RCS boron) may impact core reactivity. MONITOR reactor power:

a. CHECK reactor in Mode 1 or 2.

( RO

b. MONITOR core thermal power for unexpected changes.

NOTE: If performing AOP in conjunction with AOP-1.11 for an Eagle LCP failure, then actions to hard trip bistables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours UNLESS affected loop is restored to operable status by resetting Eagle rack. NOTIFY 1M to remove failed pressurizer level channel from service USING appropriate Appendix:

• L-68-339 Appendix I When Letdown is restored and Technical Specifications are addressed, the Lead Examiner may cue the next event

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 3 of 35 Event

Description:

Steam Generator #3 NR Level Transmitter fails low Time " Position II Applicant's Actions or Behavior Console Operator: When directed, initiate event 3 Indications available: S/G Level instrument LT-3-106 indicates downscale Alarm: XA-55-6B, 0-4 "LS-3-106B STEAM GENERATOR LOOP 4 LOW LOW WATER LEVEL" Alarm: XA-55-3C, 0-2 "EAMITTO SG LOOP 4 LO LO LEVEL" Refer to Annunciator Response. Diagnose failure. CREW (Evaluator Note: No Plant transient occurs due to median selection circuit). Enter and direct actions of AOP-1.06, Section 2.2. SRO EVALUATE the following Tech Specs for applicability:

• 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation
• Action 9 Applies for S/G Water Level Low Low Trip)
• 3.3.2.1 (3.3.2), Engineered Safety Feature Actuation System Instrumentation
• Action 17 Applies for Turbine Trip and FW Isolation from S/G water Level High High.

SRO

• Action 36 applies for S/G water level low low AFW start
• Action 22 c applies for P-14 Interlock, no additional actions required.
• 3.3.3.5, Remote Shutdown Instrumentation - N/A
• 3.3.3.7, Accident Monitoring Instrumentation - NA

I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 3 Page 14 of 35 Event

Description:

Steam Generator #3 NR Level Transmitter fails low Time I Position II Applicant's Actions or Behavior NOTE: If performing AOP in conjunction with AOP-1.11 for an Eagle LCP failure, then actions to hard trip bistables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours UNLESS affected loop is restored to operable status by resetting Eagle rack. NOTIFY 1M to remove failed S/G level instrument from service USING appropriate Appendix: L-3-1 06 - Appendix V When Technical Specifications are addressed, the Lead Examiner may cue the next event

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 4 Page 15 of 35 Event

Description:

FW Hdr Press Transmitter Fails low (PT-3-1) Time II Position II Applicant's Actions or Behavior Console Operator: When directed, initiate Event 4 Indications available: MFW Pump speed increases increasing FW flow to all SIG Hotwell level decreases due to increased FW demand Alarm: XA-55-3C, C-1 "PS-3-4 NO 1 FW HTR PRESSURE HI" Rods may step out due to this failure. Evaluator Note: For this event, crew may respond per the Annunciator Response Procedure or AOP-S.01 Section 2.2. Both are not required. The ARP is outlined first then the AOP. ( Take Manual Control of MFP Master Speed control and reduce BOP Feedwater pressure and Flow. Crew Refer to annunciator Response procedure. [1J DISPATCH operator to #1 feedwater heaters to verify the following valves open:

a. 1-PSY-3-4 1:1'- 1-PSY-3-14 c.1-PSV 24 BOP [2] REDUCE feedwater pressure to ~11 00 psrc9.

[3J WHEN pressure reduces to - 1100 psig, THEN VERIFY the above mentioned PS\t's dosed. [4] IF alarm still illuminated or by SRO decision, THEN GO TO AOP-SJ)1 , Loss of Normal Feedwater. SRO Implement AOP-S.01 Section 2.2. (Optional) Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 4 Page 16 of 35 Event

Description:

FW Hdr Press Transmitter Fails low (PT-3-1) Time II Position II Applicant's Actions or Behavior NOTE: Step 1 is an IMMEDIATE AGTION_ RESTORE feedwater pressure:

a. PLACE affected MFP speed controller(s} ill MANUAl:

• MfPT 1A{2A) & 1B(28)

Speed Control OR BOP

• MfPT 1A(2A) Speed Controller OR

(

• MFPT 18(2B) Speed Controller

b. ADJUST speed on affected MFP(s) to restore feedwater pressure to normal

(-1040 psig at fu~1 pov,fer). DETERMINE if MfP trip IS needed:

a. CHECK BOTH MFWPs in service.

b. IF ~..1FW pump trip is needed due to loss of speed control, BOP THEN PERFORM the following:

1) TRIP affectedMFP.

2} GO TO applkabJe section: (Step Should be N/A) Feed flow transients may impact core thermall power. Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Event # 4 Page 17

                                                                               --   of 35 Event

Description:

FW Hdr Press Transmitter Fails low (PT-3-1) Time I Position II Applicant's Actions or Behavior MAINTAIN steam ,generator leveI(s) BOP on proqsam. NOTE: Appendix C may be used to determine program feedwater DIP for current power. MAINTAIN MFP dIscharge pressure BOP on program USING res or ava;llable control board indicaticns. CREW INITIATE repairs on failed equipment When Plant is stable with MFP speed control in manual, Lead Examiner may cue the next event at his discretion. Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 5 Page 18 of 35 Event

Description:

Small Steam Leak Outside containment on loop 3 I Time II Position I Applicant's Actions or Behavior Booth Instructor: When directed, initiate Event 5 Indications available: NIS Power Increasing Condenser Hotwell level decrease Diagnose Secondary leak outside containment based on NIS Crew power increase, containment conditions normal, Hotweillevel decreasinq Enter and direct actions of AOP-S.05, Steam Line or SRO Feedwater Line BreaK/Leak. MONITOR actions necessary to protect personnel:

• IF immediate isolation of steamlfeedwater lines is needed to protect personnel, THEN PERFORM the following:

SRO a) TRIP the reactor. b) WHEN reactor is tripped, THEN CLOSE MSIVs and FEED REG VALVES. e) GO TO E-{l, Reactor Trip or Safpfu IntpctiorL Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 5 Page 19 of 35 Event

Description:

Small Steam Leak Outside containment on loop 3 I Time II Position I Applicant's Actions or Behavior MONITOR reactor power STABLE or CONTROLLED. (RNa May Be performed later when leak increases to break) PERfORM the following: RO a. TRIP' the reactor. D. WHEN readoris tripped, THEN CLOSE MSiVs.

c. GO TO E-O, ReadorTrip or Safety

                                      ~njedion.

RO MONITOR reactor power less than 100% BOP MONITOR steam generator levels STABLE on program. RO MONITOR T-avg/T-ref deviation less than 5°F. ( EVALUATE EPIP-1 , Emergency Plan Initiating Conditions SRO Matrix. (Notify Shift Manaqer to Evaluate REP) MONITOR nomel'l level STABLE BOP

• VERIfY LCV-2-9 maintaining hotwell level In AUTO.

(RNa Maybe required) Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 5 Page 20 of 35 Event

Description:

Small Steam Leak Outside containment on loop 3 I Time II Position II Applicant's Actions or Behavior INITIATE makeup to homel:1 att 00% [M-2l

a. PLACE UC-2-9, Auto Makeup, in MANUAL D. OPEN lCV-2-9 USING UC-2-9, Auto Makeup, to fm notwell.

c. If loss of nomeii level IS imminent, THEN PERfORM the following:

1 TRIP the reactor.

2. WHEN reactor IS tripped, THEN CLOSE fv1SIVs.

3. GO TO E-O, Reactor Trip or

( Safety Injection. NOTE Tech Spec lCO 3J'i 1.4 action is applicable if containment pressure exceeds 0.3 pSlig. RO MONITOR containment pressure STABLE. CHECK the fonowing containment parameters NORMAL: BOP/RO

• Contaiinment temperature
• Containment humidity Lead Examiner may initiate next event to increase leak to a large break at or before this point when crew has determined there is a secondary leak outside containment.

Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Scenario # Event # ( Op Test No.: NRC 6,7,8,&9 Page 21 of 35 Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. Time II Position II Applicant's Actions or Behavior Booth Instructor: When directed, initiate Event 6 Indications available: Steam Leak Increases to Large Break:

• NIS Power Increasing
• Hotwell Level decreasing ATWS:
• Reactor Trip breakers still closed after attempting to open with both Rx Trip switches.

Rods Fail to Move in auto:

• Rods stop moving 5 seconds following turbine trip.

( Motor Driven AFW Pump Level control valve to Loop 3 fails open:

• Red position indicating light remains on when attempting to manually close
• Continued Flow to Faulted S/G when attempting to manually isolate.

Direct manual Rx Trip and MSIV closure based on AOP-S.05 SRO criteria. (Rx Power not stable or Loss of Hotwell Level Imminent) RO Identify ATWS after attempting both Rx trip Switches. US Direct entry to FR-S.1, Nuclear Power Generation/ATWS CAUTION: RCPs should NOT be tripped with reactor power greater than 5%. NOTE: Steps 1 and 2 are immediate action steps. Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6,7,8,&9 Page 22 of 35 Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. I Time II Position I Applicant's Actions or Behavior I Evaluator Note: Crew may close MSIV's and attempt to isolate AFW to faulted S/.G WHEN REACTOR IS TRIPPED during performance of FR-S.1. When attempting to isolate AFW, level control valve will not close and crew may elect to stop 1B AFW Pump at that time. VERIFY reactor TRIPPED: CRITICAL TASK

• Reactor trip breakers OPEN
• Reactor trip bypass breakers OPEN or DISCONNECTED
• Neutron flux DROPPING
• Rod bottom lights LIT
• Rod position indicators less than or equal to 12 steps.

(RNO required) ( RO TRIP reactor. IF reactor trip breakers will NOT open, THEN MAINTAIN auto or manual rod insertion at max achievable rate UNTIL rods are at bottom (Should identify rod failing to insert automatically 10 sec after turbine Trip initiates rod insertion and begin manually inserting rods) Critical Task "Prior to completion of FR-S.1 step 4" VERIFY turbine TRIPPED: BOP

• ALL turbine stop valves CLOSED Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6,7,8,&9 Page 23 of 35 ( Event

Description:

Steam leak increases to large break, AlWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. Time II Position II Applicant's Actions or Behavior CHECK AFW System operation: MD AFW pumps RUNNING TD AFW pump RUNNING as necessary. (Not Running Tagged OOS in initial conditions) BOP MD AFW LCVs in AUTO. TD AFW LCVs OPEN. MD AFW pump recirculation valves FCV-3-400 and FCV-3-401 CLOSED. EMERGENCY BORATE RCS by performing the following: CRITICAL TASK

a. ENSURE at least one CCP RUNNING.

( b. INITIATE Emergency Boration USING EA-68-4.

• PLACE boric acid transfer pumps in fast speed.
• ADJUST emergency borate valve [FCV-62-138] to obtain boric acid flow between 35 gpm and 150 gpm on

[FI-62-137A].

• MONITOR emergency boration flow:

a. CHECK emergency boration flow established on [FI-BOP 62-137A].

b. IF boric acid flow less than 35 gpm, THEN (N/A)

c. VERIFY charging flow path established:

• FCV-62-90 OPEN
• FCV-62-91 OPEN
• FCV-62-86 or FCV-62-85 OPEN.

d. CHECK pressurizer pressure less than 2335 psig.

Critical Task "Prior to completion of FR-S.1 step 4" Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6,7,8,&9 Page 24 of 35 ( Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. Time II Position II Applicant's Actions or Behavior VERIFY Containment Purge isolated: VERIFY containment purge and vent dampers (System 30) Crew CLOSED. [Panel 6K and 6L] MONITOR SI NOT actuated:

• S.1. ACTUATED permissive DARK [M-4A, D4].

(RNa required If SI occurs during performance of FR-S.1 ) IF SI actuated, THEN Crew PERFORM the following WHILE continuing with this procedure:

a. E~O, Reactor Trip or Safety Injection,

( Steps 1 through 4. Reactor TRIPPED. (RNa) PERFORM the following:

• DISPATCH personnel to locally open reactor trip Crew breakers and MG set output breakers [MG Set Room, Aux Bldg el. 759].
• DISPATCH personnel to locally open breakers to MG sets [480V Unit Boards A and B].

(Evaluator Note: Crew will likely have dispatched personnel prior to reaching this step) Turbine TRIPPED: BOP

• ALL turbine stop valves CLOSED.

Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6,7,8,&9 Page 25 of 35 Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. Time I Position II Applicant's Actions or Behavior I MONITOR reactor subcritical: RO

• Power range channels less than 5%.
• Intermediate range SUR NEGATIVE.

SRO GO TO Step 19.

19. ENSURE status tree monitoring initiated.

SRO MONITOR boration termination criteria:

• NOTIFY Chern Lab to sample RCS boron concentration.

RO

• CHECK for all of the following:

0 all control rods FULLY INSERTED 0 RCS temperature greater than 540°F 0 no RCS dilution has occurred. WHEN emergency boration is no longer needed, THEN STOP RO/US emergency boration USING EA-68-4, Emergency Boration. SRO RETURN TO procedure and step in effect. Directs transition to E-O, Reactor Trip or Safety Injection SRO VERIFY reactor TRIPPED:

• Reactor trip breakers OPEN
• Reactor trip bypass breakers DISCONNECTED or OPEN RO
• Neutron flux DROPPING
• Rod bottom lights LIT
• Rod position indicators less than or equal to 12 steps.

( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6,7,8,&9 Page 26 of 35 Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. Time II Position II Applicant's Actions or Behavior VERIFY turbine TRIPPED: BOP

• Turbine stop valves CLOSED.

VERIFY at least one train of shutdown boards ENERGIZED. BOP DETERMINE if SI actuated:

• ECCS pumps RUNNING.

RO

• Any SI alarm LIT [M-4D]

(May manually actuate 51 if not already actuated. Auto 51 will likely occur when MSIV's are closed after Rx Trip in FR-S.1 and faulted S/G continues to depressurize) PERFORM ES-0.5, Equipment Verifications WHILE continuing ( BOP in this procedure. (At end of scenario) DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpm.

b. CHECK narrow range level greater than 10% [25 ADV]

RO in at least one S/G.

c. CONTROL feed flow to maintain narrow range level between 10% [25% ADV] and 50% in all S/Gs.

( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: Scenario # Event # 6,7,8,&9 27 NRC Page of 35 Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. I Time I Position II Applicant's Actions or Behavior I CHECK if main steam lines should be isolated:

a. CHECK if any of the following conditions have occurred:

• Any S/G pressure less than 600 psig AND STEAMLINE PRESS ISOL SI BLOCK RATE ISOL ENABLE permissive DARK [M-4A, A4]

OR

• Any S/G pressure dropping UNCONTROLLED.

OR RO

• Phase B actuation

( b. ENSURE MSIVs and MSIV bypass valves CLOSED. (May have already closed MSIVs)

c. ENSURE applicabJe Foldout Page actions COMPLETED.

(Includes AFW isolation to faulted S/G if not previously performed) NOTE: Loss of seal injection flow could adversely affect RCP seals. CHECK RCP trip criteria:

a. CHECK the following:

• RCS pressure less than 1250 psig. (NO)

RO AND

• At least one CCP OR SI pump RUNNING

( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6,7,8,&9 Page 28 of 35 Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. Time II Position II Applicant's Actions or Behavior MONITOR RCS temperatures:

• IF any RCP running, THEN CHECK T-avg stable at or trending between 547 degrees F RO and 552 degrees F.

(RNO) IF temperature less than 547°1=' and dropping, THEN PERFORM the following: BOP 3, ENSURE steam dumps and atmospheric raners CLOSED. ( b. IF eooldown continues, THEN CONTROL toml feed flow USING E:A~3-8, Manual Control of AFW FIOVII, CHECK pressurizer PORV's, safeties, and spray valves:

a. Pressurizer PORV's CLOSED.

b. Pressurizer safety valves CLOSED.

RO c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6,7,8,&9 Page 29 of 35 Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. Time II Position II Applicant's Actions or Behavior CHECK S/G secondary pressure boundaries INTACT:

• All S/G pressures CONTROLLED or RISING (NO)
• All S/G pressures greater than 140 psig.

(RNO) RO/SRO PERFORM the foliOViiing: a.. MONITORstalus trees.

b. GO TO E Faulted Steam m2.

Generator Isolation. Ensure Status Trees monitoring and Direct entry to E-2, Faulted SG Isolation. SRO (Status Tree monitoring should already be implemented ( due to previous transition to FR-S.1) CAUTION UnisoiaUng a faulted SlG or secondary break should NOT be considered UNLESS needed for ReS cooldown. CHECK MSIVs and MSIV bypass valves CLOSED. RO/BOP (MSIV's should already be closed shortly after Rx Trip in FR-S.1 or in E-O per foldout page) CHECK ANY S/G secondary pressure boundary INTACT: RO/BOP

• Any S/G pressure controlled or rising .

( Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: Scenario # Event # 6,7,8,&9 Page 30 of 35 NRC Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted SfG fails open. Time II Position II Applicant's Actions or Behavior IDENTIFY Faulted S/G(s): CHECK S/G pressures:

• Any S/G pressure DROPPING BOP in an uncontrolled manner.

OR

• Any S/G pressure less than 140 psig.

Caution: Secondary heat sink requires at least one S/G available. Caution: Isolating both steam supplies to the TD AFW pump when it is the only source of feed flow will result in loss of secondary heat sink. Evaluator Note: AFW may have previously been isolated per E-O fold-out page. If not previously performed, 1B AFW pump will be stopped until local isolation of loop 3 AFW LCV is performed since it failed open) ISOLATE Faulted S/G(s): CRITICAL TASK

• ISOLATE MFW.

Evaluator information Loop 3 Valves: Main Feed Reg Valve 3-90 Main Feed Reg Bypass Valve 3-90 FW Isolation Valve 3-87A

• ISOLATE AFW.

Evaluator information Loop 3 Valves: MD AFW Main 3-148 MD AFW Bypass 3-148a TDAFW3-172 (RNO) ROIBOP

• CLOSE valves manually of locally
• CLOSE TD AFW pump steam supply from faulted S/G o FCV-1-15 (S/G 1) or FCV-1-16 (S/G 4).
• VERIFY S/G blowdown valves CLOSED.
• VERIFY atmospheric relief CLOSED.

Critical Task "prior to transition out of E-2" Appendix D NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6,7,8,&9 Page 31 of 35 ( Event

Description:

Steam leak increases to large break, ATWS occurs, Rods fail to move in auto (5 sec delay) and MDAFW pump Lvi Control Vlv to faulted S/G fails open. Time II Position II Applicant's Actions or Behavior CHECK CST level greater than 5%. ROIBOP VERIFY secondary radiation NORMAL:

a. CHECK secondary radiation NORMAL USING Appendix A, Secondary Rad Monitors.

BOP (Ap~:L A also contained In ES-O.5) O. NOTIFY Ohern lab to take SlG adivity samples. CHECK SI termination criteria:

a. RCS suocoo.ling based all. core exit T!Cs 9reater than 40'"'F.

b. Secondary heat sink:

(

• Narrow range level in at feast one intact S!G greater than 10% [25~iO ADV]

Crew OR

• Total feed flow to Intact SIGs greater than 440 gpm.

c. ReS pressure stable or rising.

d. Pressurizer level greater than 10%, [20~!o ADVj.

                                  . GO TO ES-1.1, Sf Termination.

Scenario may be terminated when crew transitions to ES-1.1, 51 Termination Appendix D NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # ES-O.5 Page 32 of 35 Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior ES-O.5 Actions CHECK ERCW system operation: BOP

• VERIFY at least four ERCW pumps RUNNING.
• VERIFY DIG ERCW supply valves OPEN.

VERIFY CCS pumps RUNNING:

• Pump 1A-A (2A-A)

BOP

• Pump 1B-B (2B-B)
• Pump C-S.

VERIFY EGTS fans RUNNING. BOP VERIFY generator breakers OPEN. ( BOP VERIFY AFW pumps RUNNING: BOP

• MD AFW pumps
• TO AFW pump.

Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 ( Op Test No.: NRC Scenario # 4 Event # ES-O.5 Page 33 of 35 Event

Description:

Equipment Verifications Time II Position I Applicant's Actions or Behavior NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control S/G levels, to establish flow due to failure, or to isolate a faulted S/G. CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

b. VERIFY TO AFW LCVs OPEN.

BOP

c. VERIFY MD AFW pump recirculation valves FCV-3-400 and FCV-3-401 CLOSED.

VERIFY MFW Isolation:

• MFW pumps TRIPPED
• MFW regulating valves CLOSED BOP
• MFW regulating bypass valve controller outputs ZERO
• MFW isolation valves CLOSED

(

• MFW flow ZERO.

MONITOR ECCS operation: VERIFY ECCS pumps RUNNING: BOP

• CCPs
• RHR pumps
• SI pumps Appendix 0 NUREG 1021 Revision 9

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # ES-O.5 Page 34 of 35 Event

Description:

Equipment Verifications Time II Position II Applicant's Actions or Behavior VERIFY CCP flow through CCPIT.

• CHECK RCS pressure less than 1500 psig.

BOP

• VERIFY SI pump flow.
• CHECK RCS pressure less than 300 psig.
• VERIFY RHR pump flow.

VERIFY ESF systems ALIGNED:

• Phase A ACTUATED:

0 CONTAINMENT ISOLATION PHASE A TRAIN A alarm LIT [M-6C, B5]. 0 CONTAINMENT ISOLATION PHASE A TRAIN B alarm LIT [M-6C, B6].

• Containment Ventilation Isolation ACTUATED:

0 CONTAINMENT VENTILATION ISOLATION TRAIN A alarm LIT [M-6C, C5]. ( 0 CONTAINMENT VENTILATION ISOLATION TRAIN B alarm LIT [M-6C, C6]. BOP

• Status monitor panels:

0 6C DARK 0 60 DARK 0 6E LIT OUTSIDE outlined area 0 6H DARK 0 6J LIT.

• Train A status panel 6K:

0 CNTMT VENT GREEN 0 PHASE A GREEN

• Train B status panel 6L:

0 CNTMT VENT GREEN 0 PHASE A GREEN MONITOR containment spray NOT required:

• Phase B NOT ACTUATED AND BOP
• Containment pressure less than 2.81 psig

(

• Ensure Containment Spray is actuated Appendix 0 NUREG 1021 Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario #

                                             -4
                                                 -  Event #      ES-O.5           Page 35    of 35 Event

Description:

Equipment Verifications I Time II Position II Applicant's Actions or Behavior I VERIFY pocket sump pumps STOPPED: [M-15, upper left corner]

• HS-77-410, Rx Bldg Aux Floor and Equipment Drain BOP Sump pump A
• HS-77-411, Rx Bldg Aux Floor and Equipment Drain Sump pump B.

DISPATCH personnel to perform EA-0-1, Equipment Checks Following ESF Actuation. BOP ( Appendix D NUREG 1021 Revision 9

SHIFT TURNOVER CHECKLIST Page 1 of 3 Today r8J SM r8J US/MCR Unit 1 r8J UO Unit 1 Off-going - Name 0 AUO Station SON r8J STA (STA Function) AUO Camp Actions On-coming - Name Part 1 - Completed by Off-going Shift/Reviewed by On-coming Shift: Abnormal Eauioment Lineuo/Conditions: tMfJl'IIJ ~~'llJ7Jf~(i1J!j ~~~tMu't6~'{JJ ~itl!5-i~'{J~J TrainA Week All equipment normal

• TDAFW pump was tagged 2 hours ago for repair to the T&T valve. The packing was blowing excessively. Expected Return to service is 8 hours. uWO 07-080025-000 Total: 0.04 gpm; Identified: 0.02 gpm; Unidentified: 0.02 gpm (today)

SHIFT TURNOVER CHECKLIST Page 2 of 3 Today SIITest in Progress/Planned: (Including Need for New Brief) As Needed for Startup. Major Activities/Procedures in Progress/Planned: Plant Startup held at -41 % awaiting availability of MFP B for past 72hrs. Currently in 0-GO-5 Section 5.1, Step

23. Continue plant startup per Rx Engineering Spreadsheet. Spreadsheet has been verified by the SRO/STA.

1-S0-62-7 Appendix D and E have been completed. Pre-conditioned Power level is 100%. 1-S0-2/3-1 Section 5.16.4 Startup of Second MFPT is in progress and complete through step 14. AUO, MIG, and PDM, support are present at the B MFPT as needed. Radiological Changes in Plant During Shift: Reactor power increase will increase dose rates inside containment and various locations in the Aux. Bldg. See applicable Rad Con RWPs for details and entry requirements. TS LCO 3.7.1.2.a: TDAFW pump was tagged 2 hours ago for repair to the T&T valve. The packing was blowing excessively. Expected Return to service is 8 hours. TS 3.3.3. 7.18b action 1; Accident Monitoring Instrumentation, ERCW to AFW Valve Position, Turbine Driven Pump. ( :lart 2 - Performed by on-coming shift o Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's) o Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shift Turnover: o Standing Orders 0 LCO(s) in Actions (N/A for AUOs) o Immediate Required Reading 0 TACF (N/A for AUO's) Part 3 - Performed by both off-going and on-coming shift o Walkdown of MCR Control Boards (N/A for AUO's) Relief Time: Relief Date: today TVA 40741 [03-2001] OPDP-1-1 [03-14-2001

SHIFT TURNOVER CHECKLIST Page 3 of 3 Today Disabled Annunciators PANEL WINDOW ANNUNCIATOR WO I PER Number Equipment Off-Normal (Pink Tags) UNID And Noun Name Panel Problem Description WO I PER Number MCRWO List ID And Noun Name Panel Problem Description WOlPER Number (

UNIT ONE REACTIVITY BRIEF Date: Today Time: Now RCS Boron: 1346 ppm Today I BA Controller Setpoint: 34 %

• I RCS B-10 Depletion: 2 ppm Operable BAT: A I BAT A Boron: 6850ppm I BAT C Boron: 6850ppm I RWST Boron: 2601 ppm Nominal Gallons per rod step from 180: 17 gallons of acid, 75 gallons of water
• Verify boric acid flow controller is set at Adjusted BA Controller Setting iaw 0-SO-62-7 section 5.1 Gallons of acid: 22 Gallons of water: 94 Rod Steps: 1 Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 168 Steps on bank D 91 gallons 30% 139 Steps on bank D 294 gallons 50% n/a n/a

    ** These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power

( operation only. Engineering data last updated one week ago. Data Valid until three weeks from now. Number of dilutions: 0 Number of borations: Rod steps in: Gallons per dilution: 0 Gallons per boration: Rod steps out: Total amount diluted: 0 Total amount borated: Net change: IN/Out Number of dilutions: *** Number of borations: Rod steps in: Gallons per dilution: 0 Gallons per boration: Rod steps out: Total expected dilution: *** Total expected boration: Net change: In/Out Remarks: Rx Power - 41% MWD/MTU - 1000 Xenon & Samarium at Equilibrium

                   *** As Required by Reactor Engineering startup spreadsheet.

Next Unit 1 Flux Map is scheduled- N/A Unit Supervisor: Name/Date

Operations Chemistry Information Sample Point Units Boron Date / Time Goal Limit U1 RCS ppm 1346 Today / Now Variable Variable U2 RCS ppm 816 Today / Now Variable Variable U1 RWST ppm 2601 Today / Now 2550 - 2650 2500 - 2700 U2 RWST ppm 2569 Today / Now 2550 - 2650 2500 - 2700 BAT A ppm 6850 Today / Now Variable Variable BAT B ppm 6850 Today / Now Variable Variable BATC ppm 6850 Today / Now Variable Variable U1 CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 U1 CLA #2 ppm 2575 Today / Now 2470-2630 2400-2700 U1 CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700 U1 CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today / Now 2470-2630 2400-2700 U2 CLA#2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA#3 ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA#4 ppm 2526 Today / Now 2470-2630 2400-2700 ( Spent Fuel Pool ppm 2547 Today / Now ~2050 ~2000 2.18-2.48 2.33 Indicator Units U1 Date / Time U2 Date/Time SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now SI 137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent cpm 229 Today / Now 68 Today / Now 15 gpd (30 min increase) cpm 567 Today / Now 83 Today / Now 30 gpd leak equivalent cpm 1174 Today / Now 206 Today / Now 75 gpd leak equivalent cpm 2875 Today / Now 455 Today / Now 150 gpd leak equivalent cpm 5710 Today / Now 870 Today / Now CVE Air Inleakage cfm 10 Today / Now 12.5 Today / Now Bkgd on 99/119 cfm 40 Today / Now 40 Today / Now

Unit 1 DELTA REACTOR POWER ASSUMED INSERTED EXPECTED DELTA RHO BORON DELTA RECOMMEND RECOMMEND IODINE TIME POWER DEFECT ROD HT WORTH XENON BORON CONC PPM DILUTION BORATION CONC (hrs) (%) (pcm) (steps) (pcm) (pcm) (pcm) (ppm) (ppm) (gal) (gal) (% eq) 0.0 41.0 698.8 180.0 -290.1 -2020.0 1346.0 41.4 1.0 50.0 836.5 190.0 -206.3 -1998.9 32.8 1340.9 -5.1 247 0 41. 8 2.0 60.0 990.0 200.0 -127.4 -1957.5 33.2 1335.7 -5.2 251 0 43.1 3.0 70.0 1144.5 210.0 -60.0 -1904.6 34.1 1330.3 -5.3 259 0 45.3 4.0 80.0 1301. 6 216.0 -27.9 -1849.0 69.4 1319.5 -10.9 530 0 48.2 5.0 90.0 1464.2 216.0 -26.2 -1797.5 109.5 1302.3 -17.1 847 0 51. 8 6.0 100.0 1634.0 216.0 -24.5 -1755.1 125.6 1282.7 -19.7 987 0 56.1 7.0 100.0 1643.0 216.0 -24.5 -1736.3 -9.8 1284.2 1.5 0 17 60.4 8.0 100.0 1642.3 216.0 -24.5 -1746.2 9.2 1282.8 -1.4 72 0 64.3 9.0 100.0 1642.9 216.0 -24.5 -1775.7 30.1 1278.1 -4.7 238 0 67.8 10.0 100.0 1645.1 216.0 -24.5 -1818.0 44.5 1271.1 -7.0 353 0 71. 0

11. 0 100.0 1648.3 216.0 -24.5 -1868.2 53.4 1262.8 -8.3 426 0 73.8 12.0 100.0 1652.1 216.0 -24.5 -1922.7 58.3 1253.6 -9.1 469 0 76.4 13.0 100.0 1656.3 216.0 -24.5 -1978.9 60.3 1244.2 -9.4 489 0 78.7 14.0 100.0 1660.6 216.0 -24.5 -2034.9 60.4 1234.8 -9.4 492 0 80.8 15.0 100.0 1664.9 216.0 -24.5 -2089.6 59.0 1225.6 -9.2 485 0 82.7 16.0 100.0 1669.1 216.0 -24.5 -2142.0 56.7 1216.7 -8.8 469 0 84.4 17.0 100.0 1673.2 216.0 -24.5 -2191.7 53.8 1208.3 -8.4 448 0 85.9 18.0 100.0 1677.0 216.0 -24.5 -2238.4 50.5 1200.4 -7.9 423 0 87.3 19.0 100.0 1680.6 216.0 -24.5 -2281.9 47.1 1193.1 -7.4 3'97 0 88.6 20.0 100.0 1684.1 216.0 -24.5 -2322.2 43.8 1186.3 -6.8 371 0 89.7

21. 0 100.0 1687.4 216.0 -24.5 -2359.4 40.5 1179.9 -6.3 345 0 90.7 22.0 100.0 1690.4 216.0 -24.5 -2393.6 37.2 1174.1 -5.8 318 0 91. 6 23.0 100.0 1693.2 216.0 -24.5 -2424.9 34.1 1168.8 -5.3 293 0 92.4 24.0 100.0 1695.8 216.0 -24.5 -2453.5 31.1 1164.0 -4.9 269 0 93.2 25.0 100.0 1698.1 216.0 -24.5 -2479.5 28.4 1159.5 -4.4 246 0 93.9 26.0 100.0 1700.2 216.0 -24.5 -2503.3 25.8 1155.5 -4.0 225 0 94.5 27.0 100.0 1702.1 216.0 -24.5 -2524.8 23.5 1151.9 -3.7 205 0 95.0 28.0 100.0 1703.9 216.0 -24.5 -2544.4 21.3 1148.5 -3.3 186 0 95.5 29.0 100.0 1705.5 216.0 -24.5 -2562.1 19.3 1145.5 -3.0 169 0 95.9 30.0 100.0 1706.9 216.0 -24.5 -2578.2 17.5 1142.8 -2.7 154 0 96.3

31. 0 100.0 1708.2 216.0 -24.5 -2592.7 15.9 1140.3 -2.5 140 0 96.7 32.0 100.0 1709.4 216.0 -24.5 -2605.9 14.3 1138.1 -2.2 127 0 97.0 33.0 100.0 1710.5 216.0 -24.5 -2617.8 13.0 1136.1 -2.0 115 0 97.3

Unit 1 34.0 100.0 1 711. 4 216.0 -24.5 -2628.5 11. 7 1134.2 -1. 8 104 0 97.6 35.0 00.0 1712.3 216.0 -24.5 -2638.2 10.6 1132.6 -1. 7 94 0 97.8 36.0 100.0 1713.1 16.0 -24.5 -2647.0 9.6 1131.1 -1. 5 85 0 98.0 37.0 100.0 1713.8 216.0 -24.5 -2654.9 8.6 1129.8 -1. 3 77 0 98.2 38.0 100.0 1714.4 216.0 -24.5 -2662.1 7.8 1128.5 -1.2 69 0 98.4 39.0 100.0 1715.0 216.0 -24.5 -2668.6 7.0 1127.4 -1.1 63 0 98.6 40.0 100.0 1715.5 216.0 -24.5 -2674.4 6.4 1126.5 -1. 0 57 0 98.7

41. 0 100.0 1716.0 216.0 -24.5 -2679.6 5.7 1125.6 -0.9 51 0 98.8 42.0 100.0 1716.4 216.0 -24.5 -2684.4 5.2 1124.8 -0.8 46 0 98.9 43.0 100.0 1716.8 216.0 -24.5 -2688.7 4.7 1124.0 -0.7 42 0 99.0 44.0 100.0 1717.2 216.0 -24.5 -2692.5 4.2 1123.4 -0.7 38 0 99.1 45.0 100.0 1717.5 216.0 -24.5 -2696.0 3.8 1122.8 -0.6 34 0 99.2 46.0 100.0 1717.8 216.0 -24.5 -2699.2 3.4 1122.3 -0.5 31 0 99.3 47.0 100.0 1718.0 216.0 -24.5 -2702.0 3.1 1121.8 -0.5 28 0 99.4 48.0 100.0 1718.3 216.0 -24.5 -2704.5 2.8 1121.3 -0.4 25 0 99.4 49.0 100.0 1718.5 216.0 -24.5 -2706.9 2.5 1120.9 -0.4 22 0 99.5 50.0 100.0 1718.7 216.0 -24.5 -2708.9 2.3 1120.6 -0.4 20 0 99.5

51. 0 100.0 1718.8 216.0 -24.5 -2710.8 2.0 1120.3 -0.3 18 0 99.6 52.0 100.0 1719.0 216.0 -24.5 -2712.5 1.8 1120.0 -0.3 17 0 99.6 53.0 100.0 1719.1 216.0 -24.5 -2714.0 1.7 1119.7 -0.3 15 0 99.7 54 0 100.0 1719.2 16.0 -24.5 -2715.4 1.5 1119.5 -0.2 13 0 99.7 55.0 100.0 1719.3 216.0 -24.5 -2716.6 1.4 1119.3 -0.2 12 0 99.7 56.0 100.0 1719.4 216.0 -24.5 -2717.8 1.2 1119.1 -0.2 11 0 99.8 57.0 100.0 1719.5 216.0 -24.5 -2718.8 1.1 1118.9 -0.2 10 0 99.8 58.0 100.0 1719.6 216.0 -24.5 -2719.7 1.0 1118.8 -0.2 9 0 99.8 59.0 100.0 1719.7 216.0 -24.5 -2720.5 0.9 1118.6 -0.1 8 0 99.8 60.0 100.0 1719.8 216.0 -24.5 -2721.2 0.8 1118.5 -0.1 7 0 99.8 Total 12046 17

~MWD/MTU Hold Tavg = Tref +/- 1. SF Small hourly boration/dilution 6820 BAT ppm volumes may be accumulated for larger single additions Reason for Power Increase Plant Startup Date RxENG Name Beeper 70808 Comments

SON 0-SO-62-7 1,2 BORON CONCENTRATION CONTROL Rev. 46 Page 161 of 199 APPENDIX 0 Page 1 of 1 CALCULATION FOR AMOUNT OF BORIC ACID OR PRIMARY WATER (TI-44) NOTE 1 One calculation is required for each major change. NOTE 2 Boric acid amounts to achieve required RCS boron concentration may be significantly higher than calculated amounts if CVCS demin resins are removing boron. Amount of boron removal by mixed bed resins wi!! depend on RCS boron, resin age, whether demin bed was previously borated, and letdown temperature. Chemistry should be consulted if required to evaluate resin bed removal. [1] IF REACTF notused, THEN CALCULATE amount of primary water or boric acid required using TI-44. AMOUNT PRIMARY RCSBORON PPM CHANGE WA TER OR BORIC ACID ( /34 b ppm Current

                                              -II 5Z  t./ f); I v3-e.

TOTAL GAL(s) NOTE REACTF data sheets are to be signed by the preparer and reviewer. [2] IF REACTF used attach printout to procedure. NOTE IV is not required if appendix is performed by an SRO to verify data provided by Rx. Eng. [3] ENSURE independently verified by an SRO in accordance with Appendix I. Initials END OF TEXT

NRC08D Dilute.txt 0 [REACTF - VERS SQ2.1] BORATION / DILUTION CALCULATION SEQUOYAH UNIT 1 CYCLE 15 RCS AVG TEMP 560.0 DEG F RCS PRESSURE 2235.0 PSIG PZR LEVEL 39.4 % MAKEUP WTR CONC .0 PPM BORIC ACID CONC 6850.0 PPM INITIAL CONC FINAL BORIC ACID MAKEUP WTR BORON CONC CHANGE BORON CONC ADDITION ADDITION (PPM) (PPM) (PPM) (GAL) (GAL) 1346.0 -11.0 1335.0 .0 524.1 0 ( v page 1

SQN BORON CONCENTRATION CONTROL 0-SO-62-7 1,2 Rev. 46 Page 162 of 199 APPENDIX E Page 1 of 18 REACTIVITY BALANCE CALCULATION NOTE 1 One calculation is required for each major change. Calculation is an approximation of required Boron change. Eyeball interpolation of graphs is expected. NOTE 2 Dilution or Boration value for power change from P1 % to P2 % power in time period T with rods

                                                                                 =                =

moving from step position R 1 to R 2. (Subscript convention: 1 current point, 2 target point) [1] ENTER the following data: DATA REQUIRED DATA Where To Get Current RCS Boron / 3'LI b ppm Chem Lab or Estimate using Appendix 0 Core Burnup /0 0 0 MWO/MTU ICS U0981 Current Reactor power L;/  % NIS or ICS Final Reactor power b'D  % As required for plant conditions Total Reactor Power change /1 ~% ~ Current and final Reactor power Rate of Reactor power change /.5:  %/hr As required for plant conditions Number of hours to change power Z hr(s) As required for plant conditions ICS or MCR Board Current Rod Position /80 steps Estimate number of rod steps required to Final Rod Position 2 0 0 steps control ~I and rod withdrawal requirements for power change.

SQN BORON CONCENTRATION CONTROL 0-80-62-7 1,2 Rev. 46 Page 163 of 199 APPENDIX E Page 2 of 18 CAUTION Follow sign conventions explicitly. (See Example Rower Increase and Power decrease.) [2] CALCULATE change in boron concentration by performing the following: Parameter Where To Get Calculation Value Attached Power Defect Curves: (negative [a] f1p POWER DEFECT Unit 1: Figure 1, 2, or 3 680 pem PD 1 - 97V pem PD2 = -27D pem for power (current) tl.p POWER DEFECT increase) Unit 2: Figure 8, 9, or 10. Xenon-, From ICS* or REACTF (either current NOTE: Xenon reactivity must be negative (negative conditions or projection to initial condition). for rise in [b] f1p XENON Xenon-, From ICS* or REACTF (projection over time period T).

                                                                                   - J ctsD           pem XE z - (- ZOZo)pem            XE 1 =        70       pem Xenon conc)

(current) tl.p XENON

                           *(ICS Xenon values must add negative sign).

[C] f1p Attached Rod Worth Curves: _/30 Rods, -(-Z8n) Rods, = (negative RODS Unit 1: Figure 4, 5, or 6 pem pem IS-a pem for rod (current) insertion) Unit 2: Figure 11, 12, or 13. tl.p RODS [d] f1p POWER DEFECT + XENON + RODS (CHANGE IN REACTIVY DUE TO POWER DEFECT, XENON, AND RODS) -7° pem raj pem tl.p POWER DEFECT + [bJ pcm L\p XENON + [cJ pcm L\p RODS = [e] f1p BORON (CHANGE IN BORON REACTIVITY) 70 pem ( [dJ pem f1p POWER DEFECT + XENON + RODS) X (-1) = tl.p BORON [f] Apprn BORON (CHANGE IN BORON CONCENTRATION) (negative for dilution, ( [eJ pcm tl.p BORON) -:- ( - 6.3 pcm/ppm Boron Worth) = -tl ppm positive for boration) from Fig. 7 (U-1) orFig. 14 (U-2) [3] ENSURE independently verified by 8RO in accordance with Appendix J. (N/A if performed by an 8RO to verify data provided by Rx. Eng)

1-S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 47 ( 1 Page 118 of 268 Date ~ 5.16.4 Startup of Second MFPT NOTE Throughout this section, N/A the non selected MFPT handswitches and valves. [1] RECORD MFPT selected to be started second. B AND RECORD MFPT to be started speed. LIG [2] ENSURE applicable Preparation for Startup has been completed: MFPT PREPARATION FOR STARTUP INITIALS 1A Section 5.16.1 of this instruction /v j;t-1B Section 5.16.2 of this instruction ,./VI---- [3] ENSURE applicable MFPT outlet valve OPEN: ( DESCRIPTION VALVE NO. POSITION INITIALS FWP 1A Outlet Flow Control Valve 1-FCV-3-67 OPEN fi//f} FWP 1B Outlet Flow Control Valve 1-FCV-3-81 OPEN ~ [4] ENSURE MFPT Speed Controller for the MFPT to be started in MANUAL AND ADJUST Demand Setpoint to ZERO. (N/A for M FPT NOT started) SPEED SWITCH DEMAND MFPT CONTROLLER POSITION ..J SETPOINT ..J A.

                                                                   ,./

A 1-SIC-46-20A MAN I~[J ZERO ~n ./ B 1-SIC-46-20B MAN [9/ ZERO Y [5] DISPATCH personnel to determine if electric speed changer outlet pressure on 1-PI-46-5100 for A MFPT or 1-PI-46-5105 for B MFPT indicating between 18-22 psig.

1-S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 47 1 Page119 of 268 Date _ 5.16.4 Startup of Second MFPT (Continued) [6] IF electric speed changer outlet pressure is not correct, THEN NOTIFY IMs to evaluate EH speed change signal. [7] ENSURE MFPTs H-P and L-P steam isolation valves for the MFP being started are OPEN. [C.5] VALVE DESCRIPTION POSITION ./ 1-611 MFPT A HP ISOL OPEN ;Jt1r 1-603 MFPT ALP ISOL OPEN JJl$r 1-612 MFPT B HP ISOL OPEN [iY' 1-604 MFPT B LP ISOL OPEN vr CAUTION The MFP suction pressure should be monitored when operating the recirc valve on the idle pump. ( [8] PERFORM the following: [a] ENUSRE [1-HCV-3-70] CLOSED. [b] ENUSRE [1-HCV-3-84] CLOSED. [c] IF starting A MFP, THEN THROTTLE [1-FCV-3-70] MFP Recirc valve between 30%-50% OPEN USING [1-FIC-3-701 [d] IF starting B MFP, THEN THROTTLE [1-FCV-3-84] MFP Recirc valve between 30%-50% OPEN USING [1-FIC-3-841 l\'~ '-.~ [9] RESET the Standby MFPT. [10] ENSURE the following: MFPT DESCRIPTION VALVE POSITION A Condenser Inlet Isol valve FCV-2-205A OPEN Condenser Outlet Isol valve FCV-2-210A OPEN B Condenser Inlet Isol valve FCV-2-211A OPEN Condenser Outlet Isol valve FCV-2-216A OPEN

1-S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 47 1 Page 120 of 268 5.16.4 Startup of Second MFPT (Continued) Date vv:-:: NOTE Either stop valve handswitch will open both high pressure and low pressure stop valves for the applicable MFPT. [11] OPEN the Stop Valves for the MFPT to be started by placing either the HIP or LIP handswitch to the RAISE position: VALVE MFPT DESCRIPTION HANDSWITCH INITIALS POSITION 1A HIP Stop Valve 1-HS-46-15A OPEN JlJk:- LIP Stop Valve 1-HS-46-16A OPEN AJ/rr-18 HIP Stop Valve 1-HS-46-43A OPEN ~ LIP Stop Valve 1-HS-46-44A OPEN ~ [12] VERIFY the MFP turning gear motor has STOPPED. ( CAUTION Observe MFP speed, flow, discharge pressure during the MPFT startup to prevent an inadvertent FW swing ifthe MFPT minimum speed setpoint is excessively high. NOTE The feedwater pump speed controller will take control at the minimum speed setting and run the governor valve positioner out to its upper limit. Minimum speed on high pressure steam is 3100 to 3,300 rpm and 3650 to 3850 rpm on low pressure steam. This value may vary based on previous hand speed changer adjustment. [13] NOTIFY MIG to adjust the MFPT hand changer for the proper rpm as the second MFPT is accelerated.

SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 47 1 Page 121 of 268 Date~ 5.16.4 Startup of Second MFPT (Continued) NOTE 1 Vibration and thrust bearing wear should be monitored on local Bently Nevada panel and ICS (Secondary Mimics, MFP Bearing Data). Max allowable vibration (danger limit) is 5 mils above baseline; alert value is 3 mils above baseline. Thrust bearing wear trip setpoint is 10 mils above baseline (7 mils alert above baseline). NOTE 2 1A MFWP condenser vacuum may be monitored using 1-PI-2-331 A (TB el. 685), ICS computer point 1U2082, or by monitoring condenser drain temperature (ICS point 1T2360A). 1B MFWP condenser vacuum may be monitored using, 1-PI-2-331 B (TB el. 685), ICS computer point 1U2084, or by monitoring condenser drain temperature (ICS point 1T2361A). Drain temp s 160°F indicates vacuum of at least 20" Hg. MFWP trip setpoint of 12.2 psia corresponds to - 5 "Hg vacuum or drain temp of - 200°F. NOTE 3 Max allowable bearing temperature is 225°F. ( [14] MONITOR the following parameters during MFWP startup:

• Vibration and thrust bearing wear (at local panel)
• MFWP Condenser vacuum/drain temperature.
• Oil system and bearing temperatures.

[15] OPEN Governor Valve by PERFORMING one of the following: [a] IF MCR operation of Governor Valve Positioner is available, THEN PLACE the applicable Governor Valve Positioner to the RAISE position to open the steam chest valves and accelerate the MFPT" MFPT DESCRIPTION HANDSWITCH POSITION INITIALS A GV Positioner 1-HS-46-13A OPEN B GV Positioner 1-HS-46-40A OPEN

SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 47 1 Page 122 of 268 Date _ 5.16.4 Startup of Second MFPT (Continued) [b] IF MCR operation of Governor Valve Positioner is unavailable, THEN

1. ESTABLISH direct communications between the personnel operating the U1 MFP speed control locally and the U1 Main Control Room. 0

2. DIRECT MIG to slowly adjust U1 MFP Speed Control using local manual control of the MFP Governor Valve Positioner to throttle steam chest vales and control MFPT speed. 0 CAUTION DO NOT increase second MFPT speed faster than the master speed control can maintain program dIp.

NOTE As the second MFPT is loaded, the first MFPT should back down in load. ( [16] SLOWLY LOAD the second MFPT to raise MFPT speed until demand on MFPT speed controller matches the demand output of the first MFPT. o [17] ENSURE MFP Injection Water Intermediate Leakoff Pressure for BOTH MFPs is at least 250 psig. [a] [1-PI-54-2], 1A MFP AND [b] [1-PI-54-61 1B MFP [18] ENSURE MFP Injection Water Differential Pressure for pump started is equal to or greater than 25 psid. [a] [1-PDI-54-11 1A MFP OR [b] [1-PDI-54-51 1BMFP [19] WHEN the output meter for the SIC for the second MFPT matches the output meter on the Master Controller, THEN PLACE the second MFPT SIC in AUTO.

SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 47 1 Page 123 of 268 Date _ 5.16.4 Startup of Second MFPT (Continued) [20] CLOSE the second MFPT drain valves (N/A valves not closed): MFPT DESCRIPTION HANDSWITCH POSITION INITIALS 1A Drain Valves 1-HS-46-14 CLOSED 18 Drain Valves 1-HS-46-41 CLOSED CAUTION 1 MFP Recirc valves controllers should NOT be operated in AUTOMATIC due to the potential for isolating all three intermediate heater strings and resulting MFP damage. (

Reference:

PER 00-002540-000). CAUTION 2 Operation of MFP RECIRC valve should be performed slowly due to affect on MFP DP program. ( [21] ENSURE [1-FCV-3-70] or [1-FCV-3-84] MFP Recirc valve is CLOSED and in MANUAL. CAUTION Failure to readjust the minimum speed on the second MFWP could result in the second MFWP being unable to supply adequate feed flow in the event the first MFWP trips. NOTE The following step may be performed in parallel with power increase but should be completed prior to exceeding 55% power. [22] WHEN MFWP speed controllers [1-SIC-46-20A] and [1-SIC-46-20B] are in AUTO, THEN PERFORM the following to adjust the minimum speed on the second MFWP: [a] VERIFY both MFWP speed controller bias settings at 50%. o [b] NOTIFY MIG to slowly adjust the hand speed changer on the second MFWP so that the MFWP speeds are equal. o

1-80-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 47 1 Page 124 of 268 Date _ 5.16.4 Startup of Second MFPT ( continued) CAUTION 1 A bias adjustment in the upward direction (> 50%) should NOT be used unless evaluated by Systems Engineering since this could impact a MFPT's maximum speed and the ability to fully load in the event the other MFPT trips. CAUTION 2 Transferring a MFPT Controller from Manual to Auto with the bias not set to 50% will result in an instantaneous speed change of the MFPT. Transferring the Master MFPT Controller from Manual to Auto with bias not set to 50% will result in an instantaneous speed change of the MFPT. NOTE 1 The following step may be performed at any time when both MFPTs are inservice and in AUTO, ( NOTE 2 With both MFPTs in AUTO it may become necessary to adjust the MFPT speed control bias on one of the operating MFPTs to prevent MFPTs from fighting each other (oscillating). [23] IF an adjustment of the flow balance between the MFPTs is desired, THEN SLOWLY ADJUST one MFPT speed control bias in downward direction (0% to 50%) until desired flow balance is achieved. o End of Section 5.16.4

Sequoyah Nuclear Plant Unit 1 & 2 General Operating Instructions O-GO-5 NORMAL POWER OPERATION Revision 0052 Quality Related Level of Use: Continuous Use ( Effective Date: 10-27-2007 Responsible Organization: OPS, Operations Prepared By: Judy R. Varner Approved By: W. T. Leary Current Revision Description Revised to remove references to DCN 22190 which was not implemented U1C15. PERFORMANCE OF THIS PROCEDURE COULD IMPACT REACTIVITY.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 2 of 93 Table of Contents

1.0 INTRODUCTION

3 1.1 Purpose 3 1.2 Scope 3

2.0 REFERENCES

4 2.1 Performance References 4 2.2 Developmental References 5 3.0 PRECAUTIONS AND LIMITATIONS 6 3.1 Precautions 6 3.2 Limitations 11 4.0 PREREQUiSiTES 14 5.0 INSTRUCTIONS 16 5.1 Power Ascension From 30% to 100% 17 5.2 At Power Conditions 58 5.3 Power Reduction From 100% to 30% 64 5.4 Power Coastdown at End of Life 77 5.5 LOAD FOLLOW OPERATIONS 82 6.0 RECORDS 86 Appendix A: DELETED 87 Appendix B: TURBINE RUNBACK RESTORATION 88 Appendix C: ISOLATION OF MSR STARTUP VENTS 90 Appendix D: RECOMMENDED POWER VALUES BASED ON CONDENSATED PRESSURE 91 Source Notes 92 ATTACHMENTS Attachment 1: NORMAL POWER OPERATION

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 3 of 93

1.0 INTRODUCTION

1.1 Purpose This General Operating (GO) Instruction provides guidance for power ascension from approximately 30 to 100% power, at power conditions, power reduction from 100 to 30% power, Power Coastdown at End of Life operations, and Load Follow operations. This instruction provides additional guidance for turbine control restoration following a turbine runback. 1.2 Scope This GO contains the following sections: 5.1 Power Ascension From 30% Power to 100% 5.2 At Power Conditions 5.3 Power Reduction From 100% to 30% ( 5.4 Power Coastdown at End of Life 5.5 Load Follow Operations (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 4 of 93

2.0 REFERENCES

2.1 Performance References A. 1,2-80-5-1, Feedwater Heaters and Moisture Separator Reheaters B. 1,2-80-5-2, No.3 Heater Drain Tank and Pumps C. 1,2-80-5-3, No.7 Heater Drain Tank and Pumps D. 1,2-80-2/3-1, Condensate and Feedwater System E. 1,2-80-2-9, Condenser Vacuum and Turbine Steam Seal Systems Operation F. 0-80-12-1, Auxiliary Boiler System G. 0-80-35-4, Monitoring Generator Parameters H. 0-80-58-1. Main Generator Bus Duct Cooling System I. 0-81-NUC-000-038.0, Shutdown Margin ( J. 0-80-62-7, Boron Concentration Control K. 1,2-80-62-9, CVCS Purification System L. 0-80-68-3, Pressurizer Spray and Heater Pressure Control System M. 0-80-85-1, Control Rod Drive System N. 0-PI-OP8-000-666.0, River Temperature Limits Specified by NPDES permit O. 0-81-0P8-092-078.0, Power Range Neutron Flux Channel Calibration By Heat Balance Comparison P. 0-81-CEM-000-050.0, 72-Hour Chemistry Requirements Q. 0-81-CEM-030-407.2, Radioactive Gaseous Waste Effluent Particulate and Iodine Dose Rates from Shield and Auxiliary Building Exhausts (Weekly/Special) and Condenser Vacuum Exhausts (Special) R. 0-81-CEM-030-415.0, Gaseous Effluent Requirements (Gross Alpha, Noble Gas and Tritium

8. 0-81-0P8-000-001.0, Initial 8tartup 8ystem Parameter Log T. TI-40, Determination of Preconditioned Reactor Power

SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 5 of 93 2.2 Developmental References A. Memorandum from System Engineering concerning MSR operation - RIMS S57 880322999 B. Memo from Reactor Engineering - RIMS S57 941219 934 C. S57 -880322-999 and S57-880808-851 D. W Letter GP89-076 (RIMS No. S53 890427 984) E. W Letter GP 89-155 (RIMS S57 891026 972) F. W Letter GP 86-02(B44 861112 002) G. SSP-2:3, Administration of Site Procedures H. TVA-NQA-PLN89-A I. GOI-10, Reactivity Control at End of Cycle Life (Trojan Nuclear Plant) J. FSAR, Section 13.5 ( K. Memo from Reactor Engineering - August 6, 1996 (G Bair)

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 6 of 93 3.0 PRECAUTIONS AND LIMITATIONS 3.1 Precautions A. To ensure that NIS Reactor Power level indications remain within 2% of true power during power level changes, a check should be performed about every 20% power level change, when greater than 15% power, by comparing calorimetric power to each NIS Power Range drawer. The 20% power level check does not preclude the operating crews from making necessary changes in response to changing plant conditions. B. TRM 3.3.3.15 requires LEFM core thermal power (U2118) to be used to perform 0-SI-OPS-092-078.0 above 15% reactor power. LEFM indication is available if the following conditions are met:

• LEFM status NORMAL on ICS Calorimetric Data screen.
• LEFM core thermal power (ICS point U2118) shows good (green) data.
• LEFM MFW header temp (ICS point T8502MA) greater than or equal to 250°F.

( If LEFM indication is NOT available above 15% reactor power, then TR 3.3.3.15 action must be entered. C. The following should be used to determine the most accurate reactor power indication for comparison with NIS:

• When reactor power is greater than 15%, use LEFM calorimetric power indication (U2118).
• If LEFM is NOT available, then use average loop ~T (U0485 or M-5 indicators) up to 40%. Above 40%, use computer point U1118.

D. The turbine should be operated in "IMP OUT" control during normal unit operation. "IMP IN" operation results in system swings and should only be used during the performance of valve tests. (W Ltr GP 89-155; RIMS S57 891026 972) E. Pressurizer heaters and sprays may be operated as required to maintain pressurizer and RCS boron concentration within 50 ppm. If loop boron concentration is changed by 20 ppm or greater, use the pressurizer backup heaters to initiate automatic spray.

SQN NORMAL POWER OPERATION O-GO-5 Unit 1 & 2 Rev. 0052 Page 7 of 93 3.1 Precautions (continued) F. Condensate 01 polishing operations during power ascension are controlled by staying within system parameters and by recommendations from the Chemistry Section. G. The valve position limiter should be periodically positioned approximately 10% above the current governor control indications (keeps governor valves off of the limiter) as turbine load is changed. This prevents inadvertent load increases by limiting governor valve opening and allows a faster response of the runback feature which ensures main feedwater system will supply the required amount of flow. H. Any off-frequency turbine operation is to be reported to Engineering for record keeping. The report will include duration and magnitude of off-frequency operation. I. Operation at off-frequencies is to be avoided in order to prevent the probable occurrence of turbine blade resonance. Prolonged periods of operation at certain off-design frequencies could cause excessive vibratory stresses which could eventually generate fatigue cracking in the blades. Off-frequency ( operation is permitted to the degree and time limit specified on the chart "Off-Frequency Turbine Operation", Figure A.26 of TI-28. J. The potential exists for condensation formation in steam extraction lines when feedwater heaters are isolated. K. Initial Startup After Refueling - After refueling operations, the NIS indications may be inaccurate until calibration at higher power levels. The NIS calibration procedures will adjust the PRM trip setpoints to ensure that the excore detectors do not contribute to an overpower condition at the following RTP hold points. Reactor Engineering and/or Systems Engineering will determine procedure performance. [C.3]

1. At < 50% RTP a flux map and single point alignment, a hot channel factor determination, an axial imbalance comparison, and a PR NIS calibration will be performed. The PR high range trip setpoint will then be increased to its normal value of 109%.

2. At < 75% RTP, calorimetric calculations and RCS flow verification may be performed, EAGLE-21 updated prior to increasing power, a flux map, a hot channel factor determination, an axial imbalance comparison may be required if not performed at < 50%, a detector calibration (if ~ AFO ? 3%),

and a PR NIS calibration may be performed.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 8 of 93 3.1 Precautions (continued)

3. If not performed at 75% hold point, an axial imbalance comparison and a detector calibration (if ~ AFD ~ 3%) should be performed at - 100% RTP.

Engineering will determine if PR NIS calibration must be performed. Calorimetric calculations, RCS flow verification, a hot channel factor determination, and a reactivity balance will be performed and EAGLE-21 updated. Reactor Engineering will notify Operations that normal full power operations may proceed.

4. Preconditioned Power Levels and Maximum Allowable Rates of Power Increase are specified in TI-40, Determination of Preconditioned Reactor Power.

5. During initial startups, based on Westinghouse recommendations, a lower power ramp rate limit has been implemented for power levels above the intermediate power threshold. The Intermediate Power Threshold is unit/cycle dependent and is determined by the Vendor. Refer to TI-40.

6. \CS will automatically monitor pre-conditioned power level as follows:

( a. Point U1127 is reactor power in percent of RTP based on either secondary calorimetric or ReS ~ T depending on power level.

b. Point U01 03 is a 20 minute rolling average of reactor power rate-of-change fitted over a 20 minute period. U0103 is a leading indicator of %/hour power ramp rate and can be used in deciding to speed up or slow down the ramp rate.

c. Point U01 04 is a 1 hour rolling average of reactor power rate-of-change fitted over a 1 hour period. U0104 is used in demonstrating compliance with fuel pre-conditioning power ramp rate limits.

d. Point K0058 is the currently qualified (or pre-conditioned) power level.

e. These points can all be monitored with the ICS group display "TI40".

Appendix A may be used if the ICS is unavailable. L. TI-40 power increase limits that are exceeded, in anyone hour, are evaluated in accordance with SPP-3.1.

SQN NORMAL POWER OPERAliON O-GO-5 Unit 1 & 2 Rev. 0052 Page 9 of 93 3.1 Precautions (continued) M. Power Coastdown At End Of Life:

1. Reactor power changes should be limited to less than or equal to 1%

per hour to avoid causing xenon peaking which could force a plant shutdown.

2. Do not perform unnecessary unit power maneuvers or testing (e.g., turbine valve testing). Such testing could result in an uncontrollable Xenon oscillation.

3. Nonessential work on systems which could cause a plant upset should be deferred.

4. Secondary Plant runbacks such as Main Feed Pump Turbine trip or

                   #3 Heater Drain Tank runback will require a unit shutdown if Reactor power is not promptly returned to pre-transient level due to the resulting severe Xenon transient. If a system power alert is in effect, and electrical generation is critical, unit load should be reduced as necessary keeping TAVG on program. Contact Reactor Engineering for an evaluation and guidance concerning unit shutdown or reduction of load.

5. Management should be consulted to evaluate the feasibility of a unit restart if a reactor trip occurs with RCS equilibrium boron concentration less than 50 ppm. If the reactor is to be restarted, the power level shall be limited to nominal pre-trip power level.

N. Axial Flux Difference Management: When the reactor is operating at a steady power or during normal load changes, maintain ~I within the operating limits of the Core Operating Limits Report (COLR). It is recommended that the core axial flux difference (AFD) be maintained within +/- 5% of the target band at all times, excluding the performance of 0-PI-NUC-092-036.0, "Incore - Excore Calibration," and End of life power coast downs. Operating time outside the band, which is given in TI-28 Attachments 1 and 2, should be minimized. Reactor Engineering should be contacted if time outof the +/- 5% target band exceeds approximately 30 minutes. O. The position of control bank D should normally be ~ 215 steps when power level is steady state at or above 85% RTP. At steady state power levels below 85%, control bank D should normally be ~ 165 steps. If rod position is more than 2 steps below this guidance for long term, then impact may occur to safety analysis assumptions. P. During heatup and cooldown transients, RCS density changes will cause changes in NIS indicated power. At constant reactor power, a 1°F change in TAVG may cause as much as a 1% (or more) change in indicated NIS power.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 10 of 93 3.1 Precautions (continued) Q. Operation of main generator without automatic voltage control could impact grid voltage requirements. The South East Area Load Dispatcher (SELD) should be notified immediately if generator is in service without automatic voltage regulator. Also, refer to Section E of GOI 6 for MVAR limits. R. Main Generator operation without Automatic Voltage control requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to Operations Duty Specialist (ODS) within twenty four (24) hours. S. Main Generator operation outside of the Voltage Schedule in GOI-6 requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to South East Area Load Dispatcher (SELD) within one (1)hour.

1. The following limitations are applicable to Unit Two ONLY.

1. In winter months #7 HDTP capacity is not adequate to pump #6 Heater drains when all Condensate Demineralizer pumps are in service. Current

( practice is to run two Cond 01 Pumps and / or throttle the condensate system to reduce backpressure. The preferred method is to throttle condensate pressure instead of running only two Condensate Demineralizer booster pumps at full power due to pump runout concerns.

2. Siemens-Westinghouse analysis has determined that the maximum unit power with one MFP operation is 65% under worst case conditions. The plant could operate higher if plant conditions permit.

3. MFP flow from the lead MFP should not exceed 53.7% of the total flow.

Flow rates above this would result in HP steam flow tot he lead MFPT. Computer points 1(2)U0504 and U0505 can be used to monitor.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 11 of 93 3.2 Limitations A. When the axial flux difference monitor alarm is inoperable, the AFD must be logged every hour by performing 0-SI-NUC-000-044.0. (SR 4.2.1.1.a.2 & 4.2.1.1.b) B. When both the plant computer and NIS QPTR alarm systems are inoperable, the QPTR must be calculated every 12 hours by performing 0-SI-NUC-000-133.0. (SR 4.2.4.1.b) C. Do not exceed a load change rate of plus or minus 5% per minute or a step change of 10%. D. River water temperatures shall be maintained within the limitations of the NPDES permit as specified in 0-PI-OPS-000-666.0. NOTE Westinghouse should be contacted if the turbine is operated outside of its operating limits as stated below. ( E. To prevent high vibratory stresses and fatigue damage to the last stage turbine blading, do not operate the turbine outside of limits listed below: [W Ltr GP 86-02 (B44 861112 002)]

1. At loads less than or equal to 30% (350 MW), the maximum permissible backpressure is 1.72 psia. (3.5" Hg)

2. At loads greater than 30%, the maximum permissible backpressure is 2.7 psia (5.5" Hg) with a 5 minute limitation before tripping the turbine.

F. Do not allow the generator to become underexcited. G. In the event of a change in the rated thermal power level exceeding 15% in one hour, notify Chemistry to initiate the conditional portions of 0-SI-CEM-000-050.0, 0-SI-CEM-030-407.2 and 0-SI-CEM-000-415.0 due to the thermal power change.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Paae 12 of 93 3.2 Limitations (continued) H. The following Main Turbine vibration limitations and actions should be adhered to:

1. Vibration levels which exceed 7 mils (alarm setpoint) should be verified by Predictive Maintenance Group.

2. Vibration levels greater than 7 mils and less than 14 mils should be continuously monitored by Predictive Maintenance Group.

3. IF vibration level is greater than or equal to 14 mils, THEN TRIP the turbine.

I. Westinghouse recommends that if any throttle valve is held closed for more than 10 minutes, then it should be re-tested immediately upon reopening in accordance with 1,2-PI-OPS-047-002.0. J. The generator may be operated without a bus duct cooler up to approximately 729 MW turbine load. K. To ensure sufficient voltage for a safe shutdown after loss of both units, voltage ( and reactive power should be maintained within the limits of GOI-6. L. With LEFM calorimetric power indication available, full power operation is defined as approximately 3455 MWr not to exceed 3455.0 MWr averaged over a 8-hour period. [C.1] If LEFM is available, power shall be monitored using plant computer point U2118 Instantaneous Value. DO NOT allow average thermal power to exceed 3455 MW thermal for two consecutive hours. M. The following restrictions apply if LEFM calorimetric power indication (U2118) is unavailable:

1. Applicable action of TRM 3.3.3.15 must be entered.

2. AFD limits in COLR and TI-28 must be made more restrictive by 1%.

3. Rod insertion limits in COLR must be raised by 3 steps.

4. If reactor power is greater than 40%, power should be monitored using U1118. If U1118 is also unavailable, use the highest reading NIS channel.

5. If reactor power is less than 40%, use the RCS average bT as the preferred method for determining power level.

N. IF equilibrium conditions are achieved, after exceeding by 10% or more of rated ( thermal power the thermal power at which the heat flux hot channel factor was last determined, THEN conditional performance of 0-SI-NUC-000-126.0, Hot Channel Factor Determination is required.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 13 of 93 3.2 Limitations (continued) O. At low power levels, the LP Heaters may be unbalanced in extraction steam supply use and heat pickup across the condensate side of the heater string. This condition should correct itself as the unit approaches 45-50% Turbine Power. (Ref: PER 99-003789-000) P. With one LP heater string out of service (isolated), power is limited to 86% (Unit 1) or 90% (Unit 2). This is based on LP turbine blading limitations. (Ref: DeN E21203A). ( (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 14 of 93 STARTUP No. Vv- Unit \ DateVV--- 4.0 PREREQUISITES NOTES

1) Throughout this Instruction where an IFITHEN statement exists, the step should be N/A'd if the condition does not exist.

2) Prerequisites may be completed in any order.

[1] ENSURE Instruction to be used is a copy of effective version. [2] T AVG is being maintained within 1.5°F of T REF. [3] SG level controls are being maintained in AUTO (N/A if auto control NOT available). [4] Control rods are being maintained within the operating band of Core Operating Limits Report (COLR) (N/A if shutting down due to dropped or misaligned rod). ( [5] Steam dump control system is in the T AVG mode (N/A if Tavg Mode NOT available). [6] The EHC system should be in OPER AUTO (pushbutton lit). [7] Generator pressurized with hydrogen according to capability curve. (TI-28, Fig. A.14) NOTE During start up after a cold shutdown the Condensate 01 normally will be aligned for full flow polishing until the MSRs are in service. [8] ENSURE Condensate 01 polishing operation in accordance with RCL recommendations.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 15 of 93 STARTUP No. v--- Unit-:...I_ Date~ 4.0 PREREQUISITES (continued) [9] ENSURE each performer documents their name and initials: Print Name Initials

                 ~          V'----      v-....r--         V\,./'-"""'--

( (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 16 of 93 5.0 INSTRUCTIONS CAUTION Steps of this procedure must be performed sequentially, unless specifically stated otherwise. NOTES

1) RADCON should be notified during normal plant operations if power level increases or decreases are either stopped or started.

2) Guidance on restoration of EHC Controls after a BOP runback is contained in Appendix B, Turbine Runback Restoration. [C.4]

(

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 17 of 93 STARTUP No. ~ Unit--L- Date~ 5.1 Power Ascension From 30% to 100% NOTES

1) Main Generator operation without Automatic Voltage control requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to Operations Duty Specialist (ODS) within twenty four (24) hours.

2) Main Generator operation outside of the Voltage Schedule in GOI-6 requires that Narrative Log entries be made (time, date, reason & duration) and that notification be made to South East Area Load Dispatcher (SELD) within one (1) hour.

3) Operation of main generator without automatic voltage control could impact grid voltage requirements. The South East Area Load Dispatcher (SELD) should be notified immediately if generator is in service without automatic voltage regulator.

Also, refer to Section E of Gal 6 for MVAR limits.

4) Confirmation from Chemistry Section SHALL be obtained prior to exceeding 30%

reactor power. ( [1 ] ENSURE Section 4.0, Prerequisites complete. [2] VERIFY from Chemistry Section that SG and feedwater secondary chemistry is within acceptable limits.

                                               ~

Chemistry personnel contacted [3] IF this is a startup following refueling, THEN ENSURE applicable portions of 0-RT-NUC-000-001.0 are COMPLETE for operation above 35% power. Rx Engr. (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 18 of 93 STARTUP No . ../V- Unit _ _\ Date~ 5.1 Power Ascension From 30% to 100% (continued) NOTES

1) This step may be performed out of sequence as necessary to meet power level.

2) O-SI-OPS-092-078.0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance.

[4] PERFORM the following at approximately 35% reactor power: [4.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 ~ = ~/o 34.55 [4.2] IF LEFM indication is NOT available, THEN CALCULATE reactor power: Average value of RCS L1T (U0485)= v}}V  % [4.3] VERIFY all NIS Power Range channel drawers are within +/- 2% of the calculated reactor power: N-41 (XI-92-5005B) YES ~ NO D N-42 (XI-92-5006B) YES ~ NO D N-43 (XI-92-5007B) YES rn/~o D N-44 (XI-92-5008B) YES it' NO D [4.4] IF any of the above steps are checked NO, THEN PERFORM O-SI-OPS-092-078.0.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 19 of 93 STARTUP No. ~ Unit_\!....-_ Date~ 5.1 Power Ascension From 30% to 100% (continued) NOTES

1) With reactor engineering concurrence, power increase per steps 5.1[6] through 5.1[9]

may be performed in parallel with this step.

2) If startup is following refueling operations and secondary side chemistry is acceptable for power increase, then N/A Step 5.1 [5]. (Startup Reactivity Calibrations and Tests will be performed at << 45% Reactor Power if not performed at >> 30% Power).

[5] IF startup is following refueling activities and secondary chemistry hold is precluding power ascension, THEN ENSURE the following have been performed prior to exceeding 50% rated thermal power: (May be performed in any order) [5.1] 0-SI-NUC-000-126.0, Hot Channel Factor Determination. ( Rx Eng ate [5.2] 0-SI-NUC-092-079.0, Incore-Excore Axial Imbalance Comparison. Rx Eng [5.3] 0-PI-NUC-092-002.0, Detector Single Point Alignment. Rx Eng ate

SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 20 of 93 STARTUP No. ~ unitL Date ~ 5.1 Power Ascension From 30% to 100% (continued) [5.4] 0-PI-IXX-092-N45.0, PR NIS Calibration. MIG [5.5] PR High Flux Trip reset to 109%. [C.3]. MIG [5.6] Applicable portions of 0-RT-NUC-000-001.0 COMPLETE for operation above 50% power. Rx Eng [6] DETERMINE the following from TI-40 AND RECORD in narrative log AND below: ( [6.1] Reactor preconditioned power level. 10 () [6.2] Ramp rate restrictions. ~ NOTE N/A Substep 5.1[6.3] and 5.1 [6.4] if not initial startup after refueling outage. [6.3] Intermediate power threshold~~~ [6.4] Ramp Rate above the intermediate power threshold. [7] MONITOR TI-40 limits (using ICS trend features if available).

SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 ( Page 21 of 93 STARTUP No. ~ Unit~ Date ~ 5.1 Power Ascension From 30% to 100% (continued) NOTE Raising load on the Main Generator will cause VARs to trend in the negative direction (toward incoming). This will require raising generator voltage. Refer to GOI-6 Section E for MVAR limits for generator stability. Refer to precautions Q, R, and S. [8] PERFORM the following as required: [8.1] IF Automatic Voltage Control is in service, THEN ADJUST Main Generator VARs USING [HS-57 -221 Exciter Voltage Auto Adjuster as necessary during power escalation. [8.2] IF Automatic Voltage Control is NOT in service, THEN ( ADJUST Main Generator VARs USING [HS-57-231 Exciter Voltage Base Adjuster as necessary during power escalation. NOTES

1) Steps 5.1 [9] through 5.1[15] may be performed concurrently or out of sequence.

2) Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-047-2000 (M-2).

3) Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized during performance.

[9] INITIATE power increase to between 45 and 49% and MAINTAIN valve position limit approximately 10% above current governor control indication as turbine load is changed. (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 &2 Rev. 0052 Paae 22 of 93 STARTUP No. ~ unitL Date ~ 5.1 Power Ascension From 30% to 100% (continued) NOTE Control rods may be used along with dilution during reactor power increase to maintain AFD within the target control band. [10] IF diluting the RCS to increase TAVG, THEN CONTINUE dilution and increase turbine load to maintain T REF with TAVG.(0-SO-62-7) [11] PERFORM the following during power increase: NOTE TAVG will be programmed from 547°F at no load to 578.2°F at 100% load at a rate of 0.312°F per % power. ( [11.1] MONITOR TAVG following TREF on program. [11.2] MONITOR pressurizer level on program (25 to 60% as a function of TAVG). NOTE If LEFM is available, computer point U2118 should be used as true reactor power. If LEFM is NOT available, use U1118 when greater than or equal to 40% and the average value of RCS L1T when less than 40%. [11.3] MONITOR all RPls, group step counters for rod insertion limits and inoperable rods or rod misalignment, Loop L1T, and NIS for correct power distribution and quadrant power tilts. NOTE Generator MVARs may be reduced if the Generator Stator Ground Fault Relay indication approaches the alarm value of 50%. Refer to GOI-6 Section E for MVAR limits for generator stability. [11.4] MONITOR generator conditions in accordance with 0-50-35-4, Monitoring Generator Parameters. [C.6]

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 23 of 93 STARTUP No. Jv----. Unit \ Date~ 5.1 Power Ascension From 30% to 100% (continued) NOTE The turbine load increase should be stopped until the main feedwater reg valves are operating in the acceptable band. [11.5] ENSURE main feedwater reg valves are operating properly in auto (within +/- 5% from zero deviation is acceptable ). [11.6] IF main feedwater reg. valves are NOT maintaining within the 5% band, THEN NOTIFY Instrument Maintenance. CAUTION The potential exists for condensation formation in steam extraction lines when feedwater heaters are isolated. ( NOTE Instrument Maintenance support may be required if controller adjustments are needed. [11 .7] ENSURE Feedwater Heaters 5 and 6, MSR Drain Tank, and #7 Heater Drain Tank level controllers are adjusted to maintain levels within normal ranges.

SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 24 of 93 STARTUP No. \.IV'- Unit L Date ~ 5.1 Power Ascension From 30% to 100% (continued) [12] WHEN reactor power is approximately 35%, THEN VERIFY annunciator XA-55-4A, window C-5: P-8 LOW POWER LOW FLOW TRIP BLOCK is DARK. [13] IF unit is returning to service after a power reduction and the MSRs were removed from service, THEN PLACE MSR HP steam warming valves to OPEN position: MSR HANDSWITCH WARMING VALVE INITIALS A1 HS-1-142 FCV-1-142 VJr~ 1st I I CV ( 81 HS-1-144 FCV-1-144 1st CV C1 HS-1-146 FCV-1-146 1st CV A2 HS-1-136 FCV-1-136 1st CV 82 HS-1-138 FCV-1-138 1st CV

                                                                                  ~
                                                                                    ~

C2 HS-1-140 FCV-1-140 v 1st CV [14] ENSURE #3 and #7 heater drain tanks on recirc in accordance with 1,2-S0-5-2 and 1,2-S0-5-3. [15] ENSURE the remaining available pumps are aligned and ready for service in accordance with 1,2-S0-2/3-1: ( [15.1] Condensate booster pumps. [15.2] Hotwell pump.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 25 of 93 STARTUPNo.~ unitL Date~ 5.1 Power Ascension From 30% to 100% (continued) NOTES

1) When placing additional condensate pumps inservice, or HOT pumps in service, ensure that the main reg valves respond correctly and then stabilize in the acceptable band.

2) The following step may be performed out of sequence and may be marked N/A if it was previously performed in O-GOA.

[16] WHEN the condensate booster pump reaches approximately 140 amps, THEN START the following pumps in accordance with 1,2-S0-2/3-1: [16.1] Third HW pump (if available). [16.2] Second CBP. (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 26 of 93 STARTUP No. ~ Unit+ Date~ 5.1 Power Ascension From 30% to 100% (continued) CAUTION Valves 106A and 1068 shall be verified to be controlling properly after each #3 HOT pump start. NOTES

1) When placing additional condensate pumps or HOT pumps in service, ensure that the main reg valves respond correctly and then stabilize in the acceptable band.

2) With verbal approval from the Operations Superintendent, pumping forward of the #3 and #7 Heater Drain System may be deferred until turbine load is approximately 60%,

if system conditions warrant.

3) Steps 5.1[17] through 5.1[22] may be performed out of sequence.

( [17] DETERMINE if #3 and #7 heater drain tank pumps can be aligned to pump forward: [17; 1] WHEN confirmation obtained from Chemistry Section that #3 heater drain tank chemistry is within limits, THEN START pumping forward using two (2) #3 heater drain tank pumps using 1,2-S0-5-2. . [17.2] WHEN confirmation obtained from Chemistry Section that #7 heater drain tank chemistry is in limits, THEN START pumping forward using the #7 heater drain tank pumps using 1,2-S0-5-3. [18] IF turbine load increase continues without the #3 heater drain tank pumps pumping forward, THEN [18.1] MAINTAIN Condensate Booster Pump suction pressure greater than or equal to 75 psig (PI-2-77). ( [18.2] MAINTAIN Main Feedwater Pump suction pressure greater than 330 psig (PI-2-129).

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 27 of 93 STARTUP No. \f'J\...< Unit -l- Date~ 5.1 Power Ascension From 30% to 100% (continued) CAUTIONS

1) MSR heatup limits are restricted to 100°F per hour or 25°F in a 15-minute period (automatic mode) or 50°F in a 30-minute period (manual mode). (SECO limits, contract 85P62-836839)

2) On the LP turbine inlet, do NOT exceed an instantaneous change of 50°F or a rate of change of 125°F/Hr for turbine expansion considerations.

3) For a cold start, the HP bundle warming valves should be opened at least 15 minutes before bringing the MSR in service.

NOTE Placing MSRs in service before 35% turbine load can cause turbine rotor long condition. [19] WHEN:::: 35% turbine load, THEN ( [19.1] IF cold start (LP turbine inlet metal temperature less than 300°F), THEN DEPRESS the RESET pushbutton on the moisture separator reheater control panel. [19.2] CLOSE the following steam inlet leakoff isolation valves: MSR VALVE POSITION INITIALS 1-679 CLOSED ~ A-1

                                                                  ~

1-714 CLOSED 1-680 CLOSED

                        , B-1 1-715       CLOSED           ~

1-681 CLOSED ~ C-1 1-716 CLOSED .........-'\... CLOSED ~ 1-682 A-2 1-717 CLOSED ~ 1-683 CLOSED ---v-B-2 1-718 CLOSED ..../\,., 1-684 CLOSED ~ C-2 1-719 CLOSED ~

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 28 of 93 STARTUP No. \.../"-- Unit~ Date~ 5.1 Power Ascension From 30% to 100% (continued) NOTE Due to required interlocks on MSR valves the following valves listed in the table should be performed in sequential order. For example: Open FCV-1-241 and when full open, then open FCV-1-141. [19.3] ENSURE MSR HP steam supplies ALIGNED as follows: MSR EQUIPMENT HANDSWITCH POSITION -..j

                                                                                          /

MSR BYPASS ISOL HS-1-241A OPEN ~/ A1 MSR MAIN ISOL HS~1-141A OPEN ~ B1 MSR BYPASS ISOL HS-1-243A OPEN mI; MSR MAIN ISOL HS-1-143A OPEN cg/ MSR BYPASS ISOL HS-1-245A OPEN cY ( C1 MSR MAIN ISOL HS-1-145A OPEN rn/ A2 MSR BYPASS ISOL HS-1-235A OPEN w: t:(' MSR MAIN ISOL HS-1-135A OPEN B2 MSR BYPASS ISOL HS-1-237A OPEN 4V MSR MAIN ISOL HS-1-137A OPEN u:v MSR BYPASS ISOL HS-1-239A OPEN Q./ C2 MSR MAIN ISOL HS-1-139A OPEN ,0/ NOTES

1) Control valves ramp open for 120 minutes for turbine cold start.

2) MSR Control valves ramp open from the 400°F position to full open in one hour when Hot Start button was previously depressed during performance of 0-GO-4 or 0-GO-11.

[19.4] DEPRESS the RAMP pushbutton on the moisture separator reheater control panel to initiate steam flow to the reheater. (step continued on next page)

SQN NORMAL POWER OPERATION 0-GO-5 ( Unit 1 & 2 Rev. 0052 Page 29 of 93 STARTUP No. ~ Unit-L Date~ 5.1 Power Ascension From 30% to 100% (continued) [19.5] IF MSR controls will NOT function in RAMP mode, THEN PERFORM the following: A. DEPRESS MANUAL pushbutton on MSR control panel. B. ADJUST manual potentiometer to gradually open MSR TCVs over approx. 120 minutes WHILE continuing in this procedure. [19.6] OPEN all MSR OPERATING vents (6-3 thru 6-93) on panel XS-6-3. [19.7] CLOSE all MSR STARTUP vents (6-1 thru 6-91) on panel XS-6-1. [19.8] PERFORM Appendix C to locally isolate MSR startup vents. [19.9] ENSURE MSR HP steam warming valves are CLOSED: MSR EQUIPMENT HANDSWITCH POSITION ~ A1 MSR WARMING LINE HS-1-142 CLOSED B'" B1 MSR WARMING LINE HS-1-144 CLOSED ~ C1 MSR WARMING LINE HS-1-146 CLOSED ~ A2 MSR WARMING LINE HS-1-136 CLOSED ~ B2 MSR WARMING LINE HS-1-138 CLOSED c¥/ C2 MSR WARMING LINE HS-1-140 CLOSED ~ (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 STARTUP No. \~- Unit

                                                             ,     Rev. 0052 Page 30 of 93 Date~

5.1 Power Ascension From 30% to 100% (continued) [19.10] IF this power ascension is during the months of October 1 through March 31, THEN REFER to 0-PI-OPS-000-006.0 and consult System Engineer for position of MSR doghouses' vent dampers. [19.11] IF this power ascension is during the months of April 1 through September 30, THEN OPEN MSR doghouses' vent dampers. [20] IF pumping forward with #3 HOT, THEN ENSURE 1,2-LCV-6-1 06A and Bare maintaining #3 heater drain tank level. NOTE ( Benchboard instruments PI-5-87A for #7 heater and PI-5-84A for

  #6 heater may be used to determine heater shell side pressure.

[21] IF #7 heater drain tank (HOT) pressure is indicating an overpressure condition, THEN PERFORM 1,2-S0-5-3, Section 8.0, Infrequent Operation to prevent #7 HOT overpressurization.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 31 of 93 STARTUP No. \.../".A.-- unitl Date~ 5.1 PowerAscension From 30% to 100% (continued) [22] WHEN approximately 40% turbine load: [22.1] VERIFY annunciator XA-55-4A, window E-7: C-20 AMSAC ARMED is LIT. [22.2] CLOSE the drains on the operating main feedwater pump turbine (N/A other pump). MFPT DESCRIPTION HANDSWITCH POSITION INITI~ A DRAIN VALVES HS-46-14 CLOSED V B DRAIN VALVES HS-46-41 CLOSED ft/)~ (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 32 of 93 STARTUP No. _ Unit - - Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE With verbal approval from the Operations Superintendent, placing the second main feed pump in service may be deferred until power is approximately 55% (Unit 1) or 65% (Unit 2). Logic prevents opening the standby MFPT condenser isolation valves if the pump is NOT reset prior to exceeding 9 million Ibs/hr flow on the running pump. [23] WHEN approximately 40 to 45% turbine load, THEN PLACE second MFPT in service by performing the following: [23.1] IF the Operations Superintendent has approved one MFP operation during the power ascension, THEN A. 1.RECORD which MFPT is in service. _ _ _MFPT ( B. MONITOR loading of the MFP in service as load is increased. 0 [23.2] WHEN second MFPT is to be placed in service, THEN PLACE second MFPT in service in accordance with 1,2-S0-2/3-1. o (

SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 33 of 93 STARTUP No. _ Unit - - Date - - - 5.1 Power Ascension From 30% to 100% (continued) NOTE This step and individual substeps may be performed out of sequence. [24] PERFORM the following as system parameters permit: [24.1] VERIFY three (3) Hotwell pumps running (if available). D [24.2] VERIFY two (2) Condensate booster pumps running. D [24.3] VERIFY MFW pump(s)in service (only 1 required if approved by Operations Superintendent). D [24.4] VERIFY two (2) #3 heater drain tank pumps running. D [24.5] VERIFY one (1) #7 Heater Drain Tank pump in service. D ( [24.6] ENSURE one gland steam exhauster running and one stopped in AUTO position: EXHAUSTER HANDSWITCH (~) (~) A HS-47-209A AUTOD START D B HS-47-209B AUTOD START D [24.7] IF gland seal water is being supplied from opposite unit, THEN RESTORE normal gland seal water alignment (supplied from this unit) in accordance with 1,2-S0-37-1, Gland Seal Water System. D

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Paae 34 of 93 STARTUP No. _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE Steps 5.1[25] through 5.1 [30] may be performed out of sequence. [25] IF the second #7 heater drain tank pump has not been started, THEN START the second #7 heater drain tank pump in accordance with 1,2-S0-5-3. NOTE Hydrogen pressure should be maintained greater than or equal to 66 psig. [26] ENSURE generator hydrogen pressure is sufficient for ( anticipated load in accordance with TI-28, Figure A.14, Generator Capability Curve. [27] VERIFY river water temperature within the limitations of the NPDES permit as specified in 0-PI-OPS-000-666.0. D CAUTION After refueling operations, the NIS indications may be inaccurate until calibration at higher power levels. DO NOT increase power greater than 50% until Reactor Engineering has ensured that applicable portions of 0-RT-NUC-000-001.0 are complete. [28] IF applicable portions of 0-RT-NUC-000-001.0 are complete for power increase above 50% of rated thermal power, THEN N/A the following Step 5.1 [29]. (Reactor Engineering) (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 35 of 93 STARTUP No. _ Unit - - Date _ 5.1 Power Ascension From 30% to 100% (continued) [29] IF startup is following refueling activities, THEN ENSURE the following have been performed prior to exceeding 50% rated thermal power: (may be performed in any order) A. 0-SI-NUC-000-126.0, Hot Channel Factor Determination. Rx Eng Date B. 0-SI-NUC-092-079.0, Incore-Excore Axial Imbalance Comparison. Rx Eng Date ( C. 0-PI-NUC-092-002.0, Detector Single Point Alignment. Rx Eng Date D. 0-PI-IXX-092-N45.0, PR NIS Calibration .. MIG Date E. PR High Flux Trip reset to 109%. [C.3]. MIG Date F. Applicable portions of 0-RT-NUC-"000-001.0 COMPLETE for operation above 50% power. Rx Eng Date [30] WHEN reactor power is approximately 49%. THEN PERFORM the following: (in any order). (, [30.1] ENSURE indicated Axial Flux Difference is within the limits specified in the COLR (T8 3.2.1.1).

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 36 of 93 STARTUP No. _ Unit Date _ 5.1 Power Ascension From 30% to 100% (continued) [30.2] PERFORM a conditional 0-SI-NUC-000-044.0, Axial Flux Difference. NOTE QPTR alarms pertain to the plant computer and annunciator panel AR-M4-B, windows B-3, C-3, and 0-4. Alarms may sporadically occur at 1.5% when the setpoint is 2%. [30.3] PERFORM a conditional 0-SI-NUC-000-133.0, Quadrant Power Tilt Ratio. [30.4] IF QPTR exceeds 1.015, THEN CONTACT Reactor Engineering for evaluation. NOTE ( Ramp load rate increases shall be within the limits stated in TI-40. [31] RECORD the following fromTI-40: [31.1] Power ascension ramp rate from TI-40. _ o NOTE N/A substep 5.1 [31.2] and 5.1[31.3] if NOT initial startup after refueling outage. [31.2] Intermediate power threshold setpoint. _ o [31.3] Ramp Rate above the intermediate power threshold. o (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 37 of 93 STARTUP No, _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) [32] CONTINUE reactor power ascension to 74%. o NOTE Control rods may be used along with dilution during reactor power increase to maintain AFD within the target control band. [33] IF diluting the RCS to increase TAVG, THEN CONTINUE dilution and increase turbine load to maintain T REF with T AVG. (0-SO-62-7) 0 NOTE Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-047-2000 (M-2). ( [34] MONITOR the turbine load increasing and MAINTAIN valve position limit approximately 10% above current governor control indication as turbine load is changed. 0 NOTE Steps 5.1 [35] through 5.1[37] may be performed out of sequence. [35] WHEN greater than or equal to 50% reactor power, THEN [35.1] VERIFY annunciator XA-55-4A, window E-4: P-9 LOW POWER TU RB TRIP-REAC TRIP BLOCK is DARK. o

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 38 of 93 STARTUP No. _ Unit - - Date _ 5.1 Power Ascension From 30% to 100% (continued) [35.2] VERIFY annunciator XA-55-4B, window B-3: NIS POWER RANGE UPPER DETECTOR HI FLUX DEVN OR is DARK. AUTO DEFEAT o [35.3] VERIFY annunciator XA-55-4B, window C-3: NIS POWER RANGE LOWER DETECTOR HI FLUX DEVN OR is DARK. AUTO DEFEAT o ( [35.4] VERIFY annunciator XA-55-4B, window 0-4: COMPUTER ALARM ROD DEV & SEQ NIS PWR RANGE is DARK. TILTS o [36] ENSURE MFPTC vacuum normal (greater than 20 inches HG vacuum) using PI-2-331Aand PI-2-331B on Panel L-69. 0 NOTE During power operation above 50%, condenser air inleakage should be maintained less than 6 CFM. [37] IF condenser air inleakage exceeds 15 CFM, THEN INITIATE actions to identify the source of inleakage and NOTIFY Engineering and the Operations Superintendent or Plant Manager. {

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 39 of 93 STARTUP No. _ Unit - - Date --- 5.1 Power Ascension From 30% to 100% (continued) NOTES

1) Steps 5.1 [38] through 5.1[41] may be performed out of sequence.

2) O-SI-OPS-092-078.0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance.

[38] PERFORM the following at approximately 55% reactor power: [38.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 = - - -% 34.55 o [38.2] IF LEFM indication is NOT available, THEN CALCULATE reactor power: Calorimetric power= U1118 = - - -% 34.11 D [38.3] VERIFY that all operable NIS Power Range channel drawers are within +/- 2% of the calculated calorimetric power. N-41 (XI-92-5005B) YESD NOD N-42 (XI-92-5006B) YESD NOD N-43 (XI-92-5007B) YES D NOD N-44 (XI-92-5008B) YES D NOD [38.4] IF any of the above steps are checked NO, THEN PERFORM O-SI-OPS-092-078.0.

SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 40 of 93 STARTUP No. _ Unit _ _ Date ---- 5.1 Power Ascension From 30% to 100% (continued) NOTES

1) More restrictive turbine load limit for Unit 1 is based on ensuring adequate MFP suction pressure to allow pumping against higher S/G pressures following S/G replacement. (Ref: DCN E21203A).

2) Siemens Westinghouse analysis has determined that the maximum Unit Two unit power with 1 MFP operation is 65% under worst case conditions. Operation at higher power levels are dependent on current conditions. This would require System Engineering evaluation.(Ref: DCN D21732A).

[39] ENSURE second MFPT is in service PRIOR TO increasing turbine load above 55% (Unit 1) or 65% (Unit 2). [40] ENSURE at least one bus duct cooler is in service USING 0-80-58-1 PRIOR TO increasing load above 729 MWe. ( CAUTION

  #3 and #7 heater drains must be pumping forward prior to exceeding 60% turbine load. This load limit assumes that both MFW pumps are in service. If only one MFWP is running, turbine load must be further limited to maintain adequate MFWP suction pressure.

[41] ENSURE both #3 and #7 heater drain tank systems are pumping forward PRIOR TO increasing turbine load above 60%.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 41 of 93 STARTUP No. _ Unit - - Oate _ 5.1 Power Ascension From 30% to 100% (continued) CAUTIONS

1) Valves 106A and 1068 shall be verified to be operating properly after each #3 HOT pump start.

2) At approximately 79% turbine load with LCV-6-105A or 8 open and only two #3 HOT pumps are in service, the required NPSH for the MFP will be insufficient.

NOTES

1) When placing HOT pumps in service, ensure main feedwater pumps and main reg valves respond correctly and then stabilize in an acceptable band.

2) LCV-6-105A will come open at about 70% turbine load if condensate discharge pressure is high. Minimize duration at this load to reduce wear on the valve. As load is increased to 100% condensate pressure will gradually decrease allowing the #3 HOT pumps to pump forward and the condenser bypass valve(s) to close.

( 3) Steps 5.1 [42] through 5.1[45] may be performed in any order. [42] WHEN approximately 70% turbine load, THEN [42.1] PLACE the third #3 heater drain pump in service in accordance with 1,2-S0-5-2. [C.2] [42.2] ENSURE valves LCV-6-106A and LCV-6-106B are controlling #3 heater drain tank level properly.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 42 of 93 STARTUP No., _ Unit _ _ Oate _ 5.1 Power Ascension From 30% to 100% (continued) CAUTION Evaluate starting and stopping of Condensate Oemineralizer pumps using condensate pressure, MFP inlet pressure, condensate booster pump inlet pressure, and #3 and #7 HOT pump and bypass valve operation. The US/SRO may start or stop Condensate Oemineralizer pumps at his discretion, but if any of the following occurs the pumps must be started:

1) Condensate Booster Pump suction pressure is less than 125 psig,as indicated on [PI-2-771.

2) Main Feedwater Pump suction pressure less than 420 psig, as indicated on

[PI-2-1291.

3) Injection Water Pump discharge pressure is less than 265 psig, as indicated by an alarm on XA-55-3B window E-1.

NOTES (

1) Should #7 heater drain tank pump(s) amps swing or if system pressure needs to be increased by approximately 40 psig, then Cond 01 Booster pumps can be started; however, two of the three pumps must be started at the same time.

2) When placing condensate pumps in service, ensure main reg valves respond correctly and then stabilize in an acceptable band.

[43] EVALUATE starting two condensate demineralizer booster pumps in accordance with 1,2-S0-2/3-1 (This step can be N/A'd or signed-off at time when pumps are started). NOTE If starting up following refueling operations and reactivity calculations and tests were completed at >> 30% reactor power, then reactivity calculations and tests must be performed again at << 75% RTP. [44] IF all applicable portions of 0-RT-NUC-000-001.0 are complete for power increase above 75% of rated thermal power, THEN N/A the following Step 5.1[45]. (Reactor Engineering) (

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 43 of 93 STARTUP No. _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) CAUTION After refueling, NIS indications may be inaccurate until calibration at higher power levels. DO NOT increase power above 75% until applicable portions of O-RT-NUC-000-001.0 are complete. [45] IF startup is following refueling, THEN PERFORM the following prior to operation above 75% power: (may be performed in any order) [45.1] ENSURE the following have been performed (may be N/A'd by Reactor Eng. and Instrument Maint. if NOT required): A. O-SI-NUC-OOO-126.0, Hot Channel Factor Determination. ( Rx Eng Date B. O-SI.,.NUC-092-079.0, Incore-Excore Axial Imbalance Comparison. Rx Eng Date

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 44 of 93 STARTUP No. _ Unit - - Date _ 5.1 Power Ascension From 30% to 100% (continued) C. O-PI-NUC-092-036.0, Incore/Excore Detector Calibration (N/A if NOT required or if MFD < 3%). RxEng Da~ D. O-PI-NUC-092-002.0, Detector Single Point Alignment. RxEng Da~ E. O-PI-IXX-092-N45.0, PR NIS Calibration. Rx Eng Date [45.2] NOTIFY Systems Eng to perform O-PI-SXX-OOO-022.2 to ( check RCS Loop ~T Zeros. [C.7] o [45.3] ENSURE applicable portions of O-RT-NUC-OOO-001.0 are complete for operation above 75% RTP. Rx Engr.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 45 of 93 STARTUP No. ~ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTES

1) O-SI-OPS-092-078.0 may be performed at the discretion of the Operator if one or more PRMs is indicating close to the +/- 2% tolerance.

2) Steps 5.1[46] and 5.1[47] may be performed out of sequence.

[46] PERFORM the following at approximately 75% reactor power: [46.1] IF LEFM indication is available, THEN CALCULATE Calorimetric power: Calorimetric power= U2118 = - - -% D 34.55 ( [46.2] IF LEFM indication is NOT available, THEN CALCULATE reactor power: Calorimetric power= U1118 = - - -% D 34.11 [46.3] VERIFY that all NIS Power Range A channel drawers are within +/- 2% of the calculated calorimetric power. N-41 (XI-92-5005B) YESD NOD N-42 (XI-92-5006B) YESD NOD N-43 (XI-92-5007B) YESD NOD N-44 (XI-'92-5008B) YES D NOD [46.4] IF any of the above steps are checked NO, THEN PERFORM O-SI-OPS-092-078.0.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 46 of 93 STARTUP No. ~ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) CAUTIONS

1) LCV-6-105A and/or 1058 may be throttling open due to condensate system pressure being higher than #3 HDT pump discharge pressure.

2) Turbine run back will occur if #3 HDT pump flow to the condensate system drops below 5500 gpm (for greater than 10 seconds), condensate bypass valve LCV-6-105A or 1058 opens, and turbine load is above 81% (Unit 1) or 82%

(Unit 2). [47] PRIOR to increasing turbine load above 77%: ENSURE the following: [47.1] LCV-6-1 06A and -1068 are controlling properly. [47.2] LCV-6-105A and -1058 are CLOSED. ( NOTE Ramp load rate increases shall be within the limits of TI-40. [48] RECORD power ascension ramp rate from TI-40. _ o NOTES

1) Operation above 75% Load with only two Hotwell Pumps in service requires further evaluation.

2) Steps 5.1[49] through 5.1[52] may be performed out of sequence.

[49] CONTINUE the power ascension to 90% reactor power. o (

SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 47 of 93 STARTUP No. _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE Control rods may be used along with dilution during reactor power increase to maintain AFO within the target control band. [50] IF diluting the RCS to increase TAVG, THEN CONTINUE dilution and increase turbine load to maintain TREF with TAVG. (0-SO-62-7) D NOTE Guidance on restoration of EHC Controls after a BOP runback via the valve position limiter is contained in Appendix B, Turbine Runback Restoration. [C.4] ( [51] MONITOR the turbine load increasing and MAINTAIN valve position limit approximately 10% above the current governor control indication as turbine load is changed. D NOTE When the turbine impulse pressure relay number is illuminated on Panel L-262, the relay is closed and Runback circuit is armed. [52] WHEN greater than 77% Turbine Load, THEN VERIFY [PIS-47-13RLY1] light [fJ,'Turbine Runback From Loss of 1 MFP' is illuminated on Panel L-262. [53] WHEN greater than 82% Turbine Load, THEN VERIFY the following relay lights are illuminated on Panel L-262: [53.1] [PIS-47-13RLY2]J. Turbine Runback From #3HOT.[2] D [53.2] [PIS-47-13RLY 3]J. NPSH Protection VLV-6-106B closes on #3 HOT pump trip. [1J o

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 ( Paue 48 of 93 STARTUP No. _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTES

1) Reactor power can be increased greater than 90% as long as adequate MFP suction is maintained.

2) Steps 5.1 [54] through 5.1[58] may be performed out of sequence.

[54] WHEN approximately 85 to 90% reactor power OR when determined by Unit SRO (if power raised above 90%), THEN ENSURE third condensate booster pump in service in accordance with 1,2-S0-2/3-1. [C.2] NOTE ( A nominal CBP suction pressure of approximately 180 psig, as indicated on [PI-2-77], will alleviate bypassing to the condenser at full power. [55] IF condensate pressure is high resulting in #3 or #7 heater drain tank bypassing to the condenser, OR the normal level control valves are near full open, THEN [55.1] THROTTLE [14-550] to attain desired condensate pressure. [55.2] IF unable to throttle [14-550], THEN REFER to 1,2-S0-5-2, Section 8.0 to adjust condensate pressure. OR [55.3] EVALUATE removal of the condensate demineralizer booster pumps (N/A if NOT in service). o

SQN NORMAL POWER* OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 49 of 93 STARTUP No . _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE Two Cond 01 Booster pumps must be started at the same time. [56] EVALUATE starting available condensate demineralizer booster pump(s) to raise system pressure - 40 psig. Pump Started YES 0 NO 0 [57] WHEN reactor power is approximately 90%, THEN PERFORM the following: [57.1] ADJUST Power Range instrumentation in accordance with 0-SI-OPS-092-078.0. o ( [57.2] INITIATE performance of 1-PI-OPS-000-020.1 or 2-PI-OPS-000-022.1, Appendix B. o CAUTION The potential exists for condensation formation in steam extraction lines when feedwater heaters are isolated. [57.3] ENSURE the following level controllers are maintaining levels within normal ranges: A. Secondary plant heaters. B. MSR drain tanks. CAUTION DO NOT exceed an average of 3455.0 MWT during an a-hour period. rC.1] [58] MONITOR NIS, L\ T and calorimetries on plant computer (pt. U2118) while increasing reactor power. o

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 50 of 93 STARTUP No.-.-- _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTES

1) Feedwater venturi unfouling may impact U1118 indication. LEFM calorimetric power (U2118) is not affected by venturi unfouling.

2) If U1118 is being used to monitor reactor power due to LEFM unavailable, then Calorimetric Calculation should be performed prior to exceeding 97% reactor power.

3) Steps 5.1[59] through 5.1 [63] may be performed out of sequence.

[59] IF Unit is returning to full power after a turbine load reduction to less than 50% AND U1118is being used to monitor power, THEN PERFORM the followingpriorto exceeding 97% power: ( [59.1] NOTIFY Systems Engineering to perform 0-PI-SXX-000-022.2, Calorimetric Calculation, Section 8.1, if necessary. o [59.2] PERFORM applicable sections of 0-PI-SXX-000-022.2 to adjust Feedwater Flow Constant. (N/A if NOT required) BOP Eng

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 51 of 93 STARTUP No, _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE Ramp load rate increases shall be within the limits of TI-40. [60] RECORD the following fromTI-40: [60.1] Power ascension ramp rate from TI-40. _ o NOTE N/A substep 5.1[60.2] and 5.1[60.3] if not initial startup after refueling outage. [60.2] Intermediate power threshold setpoint _ o [60.3] Ramp Rate above the intermediate power ( threshold . _ o [61] CONTINUE power ascension to 100% RTP. o NOTE Control rods may be used along with dilution during reactor power increase to maintain AFD within the target control band. [62] IF diluting the RC8 to increase TAVG. THEN CONTINUE dilution and increase turbine load to maintain T REF with TAVG. (0-80-62-7) 0 NOTE Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-047-2000 (M-2). [63] MONITOR the turbine load increasing AND MAINTAIN valve position limit approximately 10% above the current governor control indication as turbine load is changed. 0

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Paqe 52 of 93 STARTUP No. _ Unit _ _ Date ---- 5.1 Power Ascension From 30% to 100% (continued) NOTE Steps 5.1 [64] through 5.1[66] may be performed out of sequence. [64] WHEN reactor power approaches 100%, THEN ADJUST governor valve position limiter - 2% above governor valve position. 0 CAUTION Governor valve position limit meter may NOT match the governor valve position meter; therefore, monitor the megawatt meter and valve position limit light continuously during the following step. NOTES ( 1) Operation with the VALVE POS LIMIT light LIT is acceptable if unsatisfactory load swings are experienced.

2) Actions effecting reactivity are directed in the following step. All appropriate verifications and peer checks shall be utilized during performance.

[65] IF unsatisfactory load swings are experienced as the unit approaches full power, THEN [65.1] WITH turbine load set for maximum of 100% power, SLOWLY and CAUTIOUSLY PULSE the governor VALVE POSITION LIMIT in LOWER direction while monitoring megawatts for a decrease and VALVE POS LIMIT light to ILLUMINATE. 0 [65.2] WHEN the limiter just reaches the governor valve position, THEN STOP limiter adjustment. o

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 ( Page 53 of 93 STARTUP No. _ Unit _ _ Date ---- 5.1 Power Ascension From 30% to 100% (continued) CAUTION Do not raise the limiter position unless the turbine control is positively controlling the turbine (limit light NOT LIT). NOTE Actions effecting reactivity are directed in the following step. All appropriate verifications and peer checks shall be utilized during performance. [66] PERFORM the following if the limiter prevents reactor operation at approximately 100%: [66.1] ADJUST SETTER/REFERENCE controls to reduce turbine loading until the VALVE POS LIMIT light is NOT LIT. 0 ( [66.2] INCREASE VALVE POSITION LIMIT to allow a load increase using the SETTER/REFERENCE controls, NOT to exceed 3455.00 MWT. o

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 54 of 93 STARTUP No.. _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTES

1) Full power operation is defined as 100% power operation at approximately 3455 MW T instantaneous value, U2118 not to exceed 3455.00 MW T average thermal power in an 8-hour period. [C.1]

2) Do not intentionally operate the reactor at greater than 100% power (e.g., if reactor power is less than 100% for any time period then operation at slightly greater than 100% to "make up" for "lost" power is not permissible). [C.1]

3) Computer point U2118 should be trended on a trend recorder in the unit horseshoe and monitored for increasing reactor power trends above 3455 MW T . Prompt action shall be taken to decrease reactor power whenever an increasing power trend is observed. [C.1]

4) Do not exceed an 8-hour average value (U2126) of 3455.00 MWT. Do not allow U2125 (one hour avg) to exceed 3455.00 MWT (100%) for more than one hour. [C.1]

5) Portions of step 5.1[68] may be performed in parallel with step5.1 [67] if required.

[67] WHEN the unit stabilizes at 100% reactor power, THEN PERFORM the following: (may be performed in any order) [67.1] ADJUST GovernorValve position, rod height, and/or RCS boron concentration as necessary to establish core thermal power at desired value and Auctioneered Hi T-avg approximately equal to Tvref. 0 [67.2] NOTIFY load coordinator that the power increase is complete. 0 [67.3] NOTIFY RADCON that power has stabilized at 100%. 0 (step continued on next page)

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Pace 55 of 93 STARTUP No, _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE Use of seal steam spillover bypass FCV-47-191 should be minimized to reduce the effect of unit trip on seal steam pressure. [67.4] IF Seal Steam spillover bypass [FCV-47-1911 is IN SERVICE, THEN THROTTLE Seal Steam spillover bypass to control [FCV-47-1911 as required to control seal steam pressure. o [67.5] IF river temperature is less than 45°F, THEN CONSULT Engineering to determine if third CCW pump should be removed from service. 0 ( [67.6] CONTACT vibration engineer in Predictive Maintenance Group to monitor MFWP vibration. o CAUTION A bias adjustment in the upward direction (> 50%) should NOT be used unless evaluated by Systems Engineering since this could impact a MFPT's maximum speed and the ability to fully load in the event the other MFPT trips. [67.7] IF feed pump vibration is above desired levels, THEN CONSULT with vibration engineer and system engineer to determine which feed pump to bias to reduce vibration. 0 [67.8] IF MFPT master controller output is NOT indicating 45% to 55% THEN CONSULT with MFPT controls system engineer to evaluate if adjustment is required per 1,2-S0-2/3-1. 0

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 56 of 93 STARTUP No.. _ Unit _ _ Date _ 5.1 Power Ascension From 30% to 100% (continued) [68] IF startup is following refueling activities, THEN ENSURE the following are performed at approximately 100% Rated Thermal Power: (may be performed in any order) [68.1] 0-PI-SXX-000-022.2, Calorimetric Calculation. Systems Eng. [68.2] 0-PI-SXX-000-022.1, Delta T and Tavg Update. [C.?] Systems Eng.. [68.3] 0-SI-NUC-000-126.0, Hot Channel Factor Determination.

SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0052 Page 57 of 93 STARTUP No. _ Unit - - Date _ 5.1 Power Ascension From 30% to 100% (continued) NOTE This step may be performed out of sequence if required. [69] IF Steam Generator WR level recorders were re-scaled to 80% - 90% in 0-GO-2, THEN NOTIFY MIG to re-scale LR-3-43A and LR-3-98A, Steam Generator Wide Range Level Recorders, to 0% - 100%. [70] IF unit shutdown to minimum load, THEN GO TO Section 5.3. [71] IF unit is to be maintained at normal power, THEN GO TO Section 5.2. END OF TEXT}}