Text

July-August Exam 50-325, 324/2007301 Draft Simulator Scenarios (4 of 4)
	ML072960488
Person / Time
Site:	Brunswick
Issue date:	01/31/2007
From:	; - No Known Affiliation
To:	; Office of Nuclear Reactor Regulation
References
	50-324/07-301, 50-325/07-301 50-324/07-301, 50-325/07-301
	Download: ML072960488 (117)
	v • d • e

PROGRESS ENERGY CAROLINAS BRUNSWICK TRAINING SECTION 2007 NRC EXA BRUNSWICK JULY-AUG EXAM - 325,324/2007-301 DRAFT, SIMU~ATOR SCENARIO 4 OF 4 2007 NRC Examination Scenario #4

SCENARIO DESCRIPTION BRUNSWICK 2007 NRC Scenario #4 The plant is at approximately 4% power and a startup is in progress lAW GP-3. The SJAE must be placed in half load.

As control rods are withdrawn, IRM "C" will fail downscale The rator must recognize that the IRM is failed. When diagnosed, the SRO will cons (3.3.1-RPS) and declare IRM inoperable and direct the RO to bypass the Once the startup continues, Scram Accumulator 34- low pressure. The crew will dispatch an AO to investigate/charge th reference Tech Spec 3.1.5 and either declare control rod 34-1 ' are the control rod inoperable in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

A seismic event will occur. This wil of the EDG 3 and a high alarm trip of IRM F. A half scram wil be diagnosed by the crew. AOP-13 will be entered and the W Tech Specs (3.3.1),

a half scram must be i e to th P and it will be successful.

I&C will also be notif s IA A seismic aftersh A to trip on high alarm but RPS will fail and a manual sc I Task). Numerous control rods will fail to inse -E ust r the ATWS. Additionally, a leak will develo WCU will fal to isolate on the SLC initiation and power will b Attem U Ie ' ill be ongoing but will fail. The crew will enter OEOP-O ures and sump levels begin to rise in the Reactor Building.

When roo o areas of the Rx Building exceed max safe levels, Emergency D will be required (Critical Task).

After the ED, a fail III occur on either the RFPT StU level control valve or the 2FW-V120 (S/U level control bypass) to restore and control vessel level following emergency depressurization. The failure will occur on whatever method is first used by the operator to feed the vessel.

The scenario can be terminated once emergency depressurization occurs and reactor water level has recovered and is stable in the normal band 2007 NRC Examination Scenario #4 2

SIMULATOR SETUP Initial Conditions Ie 182 Rx Pwr 4°/b Core Age EOC EVENTS Event Trigger Trigger Description Number 1 NA NA Place both SJAE's in hqi1lf 2 1 Manual Increase Reactor Po 3 2 Manual 4 3 Manual 5 8 Manual 6 of an Emergency Diesel Generator, 4 Manual

fications, AOPs) 7 5 Manual U Unisolable Leak EOP, AOP) 8 NA NA 2007 NRC Examination Scenario #4 3

Interventions Summary Malfunctions Summary MalflD Mult Description Current Target Rmptime Actime Dactime Trig to Value Value N1015F IRM B FAILS HI TRUE TRUE N1014F IRM C FAILS DOWNSCALE FALSE TRUE N1024F IRM F FAILS HI FALSE 3 N1018F IRM A FAILS HI FALSE 4 Remf 10 Mult Rmptime Actime Trig ID EP_IAEOPJP1 ON 5 Actual Override Rmptime Actime Dactime Trig Value Value OFF ON 2 Annunciator Summary Window Description Tagname Override Type OVal AVaI Actime Dactime Trig 6-1 CRD ACCUM LO PRESS/HI LEVEL ZA761 ON ON OFF 2 6-4 SEISMIC EVENT ZUA2864 ON ON OFF 3 1-4 SOUTH RHR RM FLOOD LEVEL ZUA1214 ON ON OFF 6 HI-HI 2007 NRC Examination Scenario #4 4

Batch Files II_File-~I I Trigg~erD---:....-.escriptio_n----II Special Instructions Load scenario file 2007 NRC Scenario 4.scn 2007 NRC Examination Scenario #4 5

SHIFT BRIEFING Plant Status A plant startup is in progressp Reactor power is approximately 4 % p Equipment Out of Service IRM US" is bypassed and failed upscale Plan of the Day Continue plant startup in accordance with OGP-O Following shift turnover, place both SJAEs i Continue in GP-10 at Sequence A2X, st":"a Nuclear Engineer has been contacted and c rod withdrawal may be usedp 2007 NRC Examination Scenario #4 6

SCENARIO INFORMATION Examiner Notes Procedures Used in Scenarios:

EVENT 1

20P-30 EVENT 2

OGP-03 EVENT 3

Annunciator procedure

Technical Specifications EVENT 4

Annunciator Procedure

Technical Specifications Event 5

OAOP-13

A

2EOP- ram Procedure)

2EOP er Control)

OEOP-03-SC condary Containment Control Procedure)

OEOP-04-RRCP (Radiological Release Control Procedure)

EVENT 7

Feedwater Level Control "Hard Card"

2EOP-01-RVCP (Reactor Vessel Control Procedure) 2007 NRC Examination Scenario #4 7

Critical Tasks A seismic aftershock will then occur causing an IRM A upscale trip but RPS A will fail and a manual scram must be inserted (Critical Task). Numerous control rods will fail to insert and 2-EOP-01-LPC must entered for the ATWS. Additionally, a leak will develop in the RWCU system, RWCU will fail to isolate on the S C initiation and power will be lost to MCC 2XC.

Attempts to isolate the RWCU leak will be ongoing but . The crew will enter OEOP-03-SCCP as temperatures and sump levels be the Reactor Building.

When room flood levels in two areas of the Rx Sui .. safe levels, Emergency Depressurization will be required (C

2007 NRC Examination Scenario #4 8

EVENT 1 SHIFT TURNOVER, ALIGNING SJAE "A" AND "B" TO HALF LOAD The crew will align SJAE operation for both SJAE trains in-service in half load&

Malfunction required:

None Objectives:

sea Directs BOP to place "A" and "B" SJAEs in half I BOP Aligns 2A and 28 SJAE Trains for half load Success Path:

2A and 28 SJAE trains are aligned for half 10 Simulator Operator Activities:

WHEN requested, adjust 2-CO-FV4 sate Header pressure&

2007 NRC Examination Scenario #4 9

EVENT 1 SHIFT TURNOVER, ALIGNING SJAE "A" AND "8" TO HALF LOAD Required Operator Actions Normal Plant Operation - Aligning of SJAEs for half load operation SRO Direct BOP to align SJAEs for half load operati BOP Aligns SJAEs for half load operation APPLICANT'S ACTIONS OR BEHAVIOR:

2007 NRC Examination Scenario #4 10

EVENT 2 INCREASE REACTOR POWER The crew will align Malfunction required:

None Objectives:

sca Directs RO to increase reactor power with contra' RO Pulls control rods to increase reactor powe Success Path:

Rx power increasing, RO monitors reactor pa Simulator Operator Activities:

None 2007 NRC Examination Scenario #4 11

EVENT 2 INCREASE REACTOR POWER Required Operator Actions SRO

Directs increasing reactor power per GP-03 at step 5.1.5 RO

As directed, increases Rx power per GP-03. Mo .

level APPLICANT'S ACTIONS OR BEHAVIOR:

2007 NRC Examination Scenario #4 12

EVENT 3 IRM "C" FAILS DOWNSCALE The crew will raise reactor power and respond to a failure of IRM "C" to show any change to the power increase.

Malfunctions required:

IRM "C" will fail "downscale".

Objectives:

SCO s IRM "C" inoperable

ons. (3.3.1.1-During/following the assessm ace IRM "C" in bypass.

Contacts I&C for tro RO Durin for power ascension, IRM "C" is identified as failing do 'Iity and bypassing of it are accomplished. Part of the inope t there are adequate IRMs to meet minimum require .

EVENT 3 IRM "C" DOWNSCALE 2007 NRC Examination Scenario #4 13

Simulator Operator Activities:

WHEN control rod withdrawal is commenced and directed by lead examiner, activate TRIGGER 1

WHEN asked, as I&C, to assist in the investigation of th the request.

2007 NRC Examination Scenario #4 14

EVENT 3 IRM "C" DOWNSCALE Required Operator Actions Instrumentation Response - IRM "C" fails downscale SRO Directs actions to raise power per OGP-03.

Evaluates report of IRM "C" failure to resg power change and declares IRM "A" inoperable.

Contacts I&C to request support i Directs RO to bypass IRM "C RO Responds to the folio .

A-5 1-4, IRM DOW A-5 2-2, ROD OUT fiRM "e" to respond to the withdrawal of 2007 NRC Examination Scenario #4 15

EVENT 4 HCU ALARM The crew respond to an HCU accumulator alarm.

Malfunction required:

HCU 34-15 will receive an accumulator low gas pressure/hi water level alarm-actual cause will be a low gas pressure.

Objectives:

seQ Correctly evaluates the condition of the accum Iting in the associated control rod being, inoperable. T e Inop within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months RO Responds to annunciator 2-A-7 6-1,'

Success Path:

seQ obtains information regarding t luates the HCU as being inoperable due to low accumulator ga ~> ecifications).

WHEN cont tor, wait 3 minutes and report that the HCU al pressure, and that the pressure is 930 psig.

IWtator to recharge the HCU accumulator, 2007 NRC Examination Scenario #4 16

EVENT 4 HCU ALARM Required Operator Actions Normal Plant Operation - Assessing Technical Specifications due to a parameter outside establish bands (HCU accumulat larm due to low nitrogen pressure)

SRO Successfully evaluates that the low nitr resulting in an inoperability on the as TS 3.1.5.C.2 - Declare Affected RO Responds to annunciator APPLICANT'S ACTIO 2007 NRC Examination Scenario #4 17

EVENT 5 "8" SPE FAN TRIPS The crew will respond to a trip of the "8" SPE and will place the "A" SPE in service Malfunctions required:

28 Steam Packing Exhauster Trip.

Objectives:

seQ Diagnoses trip of 28 Steam Packing Exhau Directs placing the 2A Steam Packin ,

BOP Responds to annunciators:

2-UA-2 2-5 STEAM PACKI 2-UA-2 4-5, GLAND SEAL service per OP-26.1 ,Section xaminer, activate TRIGGER 8 WHEN asked ack 2007 NRC Examination Scenario #4 18

EVENT 5 "8" SPE FAN TRIPS Required Operator Actions seQ Diagnoses trip of 28 Steam Packing Exhauster.

Directs placing the 2A Steam Packing Exhauster per .1, Section 8.1.

BOP Responds to annunciators:

2-UA-2 2-5 STEAM PACKING EXHAUSTE 2-UA-2 4-5, GLAND SEAL VACUUM LO Diagnoses trip of 28 Steam Packing' As directed, places 2A Steam Packing E 8.16 2007 NRC Examination Scenario #4 19

EVENT 6 SEISMIC EVENT, IRM UPSCALE, SPURIOUS DIESEL GENERATOR START The crew will respond to a seismic event annunciator, IRM uF" failing upscale without causing a half scram signal on the uB" RPS channel, and a spurious start of Emergency Diesel Generator #3.

Malfunctions required:

The seismic event annunciator will alarm, IRM "F" will fail without a change in reactor power, the #3 Emergency Diesel Generator will.. spurious automatic start signal.

Objectives:

seQ Enters OAOP- 13.0 and contacts the ify the yalidity of the alarm.

Diagnoses the condition wi scram signal on the "B" RP 3 Emergency Diesel to the field to investigate for potential RO

':ual scram signal on the "B" RPS channel.

BOP and executes OAOP- 13.

When di res #3 Emergency Diesel Generator and places it in standby.

Success Path:

The crew will enter and execute OAOP-13, dispatch personnel to investigate for damage from the earthquake, insert a scram signal on the "B" RPS channel, and return

3 Emergency Diesel Generator to a standby condition.

2007 NRC Examination Scenario #4 20

Simulator Operator Activities:

WHEN directed by the lead examiner, activate TRIGGER 3 WHEN contacted as the National Earthquake Center, confirm that an earthquake has occurred with an epicenter at Charleston, SC. Also state that a magnitude has not yet been determined.

WHEN contacted as I&C to investigate the #3 Emergency Oi enerator, acknowledge the request, wait 3 minutes, and report to th 01 room that the diesel start was due a spurious relay trip and that investigatio , firmed that the diesel can be secured and returned to standby.

WHEN contacted as the auxiliary operators to damage, acknowledge the request.

2007 NRC Examination Scenario #4 21

EVENT 6 SEISMIC EVENT, IRM UPSCALE, SPURIOUS DIESEL GENERATOR START Required Operator Actions Abnormal Operating Procedures - Seismic Event SRO o Enters OAOP-13 and directs BOP to execut investigation of the seismic event o Diagnoses the report of the IRM "F" the RO to insert a manual scram signal on the "8" R support investigation of same. TS 3.3.1 RO When directed by the Channel BOP e OAOP-13 in response to the seismic ncy Diesel Generator and return it to a Ion 7.1 AP-2007 NRC Examination Scenario #4 22

EVENT 7 SEISMIC AFTERSHOCK, ATWS, RWCU UNISOLABLE LEAK The crew will respond to a failure to scram and an unisolable leak on the RWCU system located inside the Secondary Containment.

Malfunctions required:

RPS Channel "A" will fail to initiate a scram signal when "A" fails upscale, resulting in an ATWS condition. A leak will develop 0 WCU system in the Secondary Containment, and will not be able to be . e due to a failure of the 2-G31-F004 and a loss of power to the 2-G31-F Objectives:

SCO Enters 2EOP-01-LPC (Level Power Co the crew in response to the ATWS. Directs LEP-O Enters OEOP-03-SCCP (Se ontrol Procedure) and directs the actions of the crew based om RWCU.

Enters OAOP-05.

Containment.

RO "A" to cause a reactor scram signal to insert a scram on the RPS "A" channel.

card and places mode switch to shutdown.

BOP Recognizes a d reports a failure of RWCU to isolate and attempts to close the valves by operator action.

Recognizes and reports the failure of the 2-G31-F004 to close and the loss of power to the 2-G31-F001.

Observes and reports annunciators relating to Secondary Containment parameters, specifically relating to room flooding status for evaluation of Secondary Containment Control Procedure.

2007 NRC Examination Scenario #4 23

EVENT 7 SEISMIC AFTERSHOCK, ATWS, RWCU UNISOLABLE LEAK Success Path:

The crew will correctly diagnose the ATWS and the unisolable leak in the Secondary Containment and respond correctly according to 2EOP-01-LPC, OEOP-03-SCCP and OAOP-05.

Simulator Operator Activities:

WHEN directed by the lead examiner, activate T

WAIT 1 minute and report to the control ro the Reactor Building and everyone is lea

IF requested to defeat the Low Leve EP 10, wait 3 minutes and actuate TRIGGER

IF directed to attempt to re G31-F004, acknowledge the request, wait 1 minute, and hat the Reactor Building cannot be accessed due to th

WHEN requeste jumpers are in 2007 NRC Examination Scenario #4 24

EVENT 7 SEISMIC AFTERSHOCK, ATWS, RWCU UNISOLABLE LEAK Required Operator Actions:

SCQ Enters 2EOP-01-LPC (Level Power Control) and directs the actions of the crew in response to the ATWS. Directs LEP-02 Enters OEQP-03-SCCP (Secondary Containment Procedure) and directs the actions of the crew based on the unisolable I RWCU.

Enters OAOP-05.0 due to the unisolable Ie Containment.

RO BOP 2-G31-F004 to close and the loss of ciators relating to Secondary Containment lIy r g to room flooding status for evaluation of nt Control Procedure.

re of the RWCU isolation valves to close, attempts to close ual action, and reports the results to the SCQ.

Carries out actions necessary to control reactor level and pressure ads directed by the SCO.

2007 NRC Examination Scenario #4 25

EVENT 7 SEISMIC AFTERSHOCK, ATWS, RWCU UNISOLABLE LEAK APPLICANT'S ACTIONS OR BEHAVIOR:

2007 NRC Examination Scenario #4 26

EVENT 8 EMERGENCY DEPRESSURIZATION/START-UP LEVEL CONTROL VALVE FAILURE The crew will respond to a flooding condition in two areas of the Secondary Containment requiring Emergency Depressurization t followed by a failure of the Startup Level Control Valve in the "Closed" position or the failure to op of valve 2-FW-V120.

Either of these valves will permit makeup to the reactor vess the Condensate and Feedwater system. The first one attempted for use by the tor will fail Malfunctions required:

Flooding will occur in two areas of the S "th a primary system causing the flooding, requirin . Upon depressurization, the Startup Level . il closed.

Objectives:

SCQ

8ry Containment Control en two areas flood levels ergency Depressurize the reactor and BOP esto - .edwater flow, correctly diagnoses and reports Startup Level Control Valve OR the 2-FW-V120 has ethod that is available to feed the reactor.

Crew recognizes the ooding condition in the Secondary Containment requiring Emergency Depressurization, successfully depressurizes the reactor, recognizes the failure of the Startup Level Control Valve OR the 2-FW-V120 valve.

2007 NRC Examination Scenario #4 27

Simulator Operator Activities WHEN directed by the lead examiner, initiate TRIGGER 6

- - WHEN 7 ADS valves are opened, initiate TRIGGER 7 OR TRIGGER 9. MUST WATCH OPERATOR INO ER TO FAIL CORRECT VALVE 2007 NRC Examination Scenario #4 28

EVENT 8 EMERGENCY DEPRESSURIZATION/START-UP LEVEL CONTROL VALVE FAILURE Required Operator Actions sea Direct actions associated with OEOP-03-SCCP (Second" Containment Control Procedure) to Emergency Depressurize the reactor W 0 areas flood levels reach max safe.

Directs BOP to open 7 ADS valves to Emerge to control injection sources.

BOP When directed, opens 7 ADS Valve actor ressurize the reactor.

Upon restorati '

Valve OR t method to 2007 NRC Examination Scenario #4 29

Simulator Operator Activities:

WHEN directed by the lead examiner, place the simulator in DO NOT RESET THE SIMU ECEIPT OF CONCURRENCE TO "AD EXAMI 2007 NRC Examination Scenario #4 30

Transferring Off-Gas Train 2A(2B) from Full Load to Half Load R Reference Use 8w2.. 1 Initial Conditions

1. Off-Gas Train 2A(2B) is in operation at full load. D

2. AO is available to respond to valve or breaker problems D that could be encountered during the transfer.

8.2.2 Procedural Steps

1. DEPRESS OFFGAS TRAIN A(B) MASTER SWITCH, D OG-CS-4290(4330), HALF LOAD push button AND ENSURE the following valves close:

a. SJAE 2A(2B) SECOND STAGE B EJECTOR D STEAM INLET VALVE, SJE-V11(V13)

b. SJAE 2A(2B) SECOND STAGE B EJECTOR D OUTLET VALVE, HTOG-V1(V3)

c. SJAE 2A(2B) FIRST STAGE B EJECTOR STEAM D INLET VALVE, SJE-V4(V3)

d. SJAE 2A(2B) FIRST STAGE B EJECTOR OFF D GAS INLET VALVE, OG-V10(V12).

120P-30 Rev. 79 Page 56 of 1231

8.2.2 Procedural Steps NOTE: Off-Gas Train A(B) is now operating at half load.

2. CHECK SJAE OFF GAS RAD MONITORS A and B, D

D12-RM-K601A and D12-RM-K601B, AND NOTIFY E&RC to sample within four hours following a monitor reading increase of greater than or equal to 50% without an accompanying increase in thermal power in accordance with Technical Specification SR 3.7.5.1.

3. ENSURE there is no significant change in condenser D vacuum.

120P-30 Rev. 79 Page 57 of 1231

~ Progress Energy BRUNSWICK NUCLEAR PLANT c

Continuous Use PLANT OPERATING MANUAL VOLUME IV GENERAL PLANT OPERATING PROCEDURE UNIT o

OGP-03 UNIT STARTUP AND SYNCHRONIZA TION REVISION 59 IOGP-03 Rev. 59 Page 1 of 241

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE................................................................................................................ 3

2.0 REFERENCES

3 3.0 PRECAUTIONS AND LIMITATIONS 4 4.0 PREREQUISITES 5 5.0 PROCEDURAL STEPS 6 5.1 Transferring The Reactor Mode Switch To RUN u.... 5 5.2 Placing the Feedwater Heaters in Operation 10 5.3 Turbine Generator Startup and Synchronization .. 15 5.4 Preparation of Heater Drain System for Forward Pumping .. 17 5.5 Transferring Auxiliary Power From The SAT to the UAT......... 18 ATTACHMENTS 1 Verification of Reactor Power Level Using Alternate Indications 20 IOGP-03 Rev. 59 Page 2 of 241

1.0 PURPOSE This procedure provides the precautions, limitations and instructional guidance for increasing power from rated pressure to synchronization and loading of the turbine generator.

2.0 REFERENCES

2.1 Technical Specifications 2.2 FSAR 2.3 OAI-81, Water Chemistry Guidelines 2.4 OE&RC-0040, High Radiation Area Key Control 2.5 OGP-02, Approach to Criticality and Pressurization of the Reactor 2.6 OGP-10, Rod Sequence Checkoff Sheets 2.7 1(2)OP-01, Nuclear Boiler System 2.8 1(2)OP-07, Reactor Manual Control System Operating Procedure 2.9 1(2)OP-09, Neutron Monitoring System Operating Procedure 2.10 1(2)OP-26, Turbine System Operating Procedure 2.11 1(2)OP-27, Generator and Exciter System Operating Procedure 2.12 1(2)OP-29, Circulating Water System 2.13 1 (2)OP-3b~* Condenser Air Removal and Off Gas Recombiner System Operating Procedure 2.14 1(2)OP-32, Condensate and Feedwater System Operating Procedure 2.15 1(2)OP-34, Extraction Steam System Operating Procedure 2.16 1(2)OP-35, Heater Drains, Vents, and Level Control Operating Procedure IOGP-03 Rev. 69 Page 3 of 241

2.0 REFERENCES

(Continued) 2.17 1(2)OP-36, Moisture Separator Reheater and Moisture Separator Reheater Drains System Operating Procedure 2.18 OOP-46, Instrument and Service Air System Operating Procedure 2.19 OPT-01.8D, Core Thermal Power Calculation 2.20 1(2)PT-01.11, Core Performance Parameter Check 2.21 OPT-13.1, Reactor Recirculation Jet Pump Operability 2.22 OPT-40.2.6, Turbine Overspeed Trip Test IR231 2.23 Response to Generic Letter 84-09, Hydrogen Control in Primary Containment 10CFR50.44(c)(3)(ii).

2.24 Shearon Harris Nuclear Power Plant LER 89-023-00 IR2S1 2.25 INPO SOER 90-03, Nuclear Instrument Miscalibration 2.26 GE SIL 614, Backup Pressure Regulator 3.0 PRECAUTIONS AND LIMITATIONS 3.1 This procedure is to be used in accordance with the procedure compliance guidelines of OGP-01, Section 5.0.

3.2 The loading limits of the generator should be maintained within the limits of 1(2)OP-27, Figure 1.

3.3 WHEN increasing reactor power, THEN APRM GAFs should be periodically monitored to ensure GAFs are less than or equal to 1.00.

IOGP-03 Rev. 69 Page 4 of 241

4.0 PREREQUISITES Unit DatelTime Started - - - - - -

Initials 4.1 Reactor pressure is between 925 and 930 psig with one turbine bypass valve open at least 20%.

4.2 Reactor mode switch is in STARTUP/HOT STBY.

4.3 OGP-02 is complete AND reviewed by the Unit SeQ.

IOGP-03 Rev. 69 Page 5 of 241

5.0 PROCEDURAL STEPS Initials 5.1 Transferring The Reactor Mode Switch To RUN 5.1.1 ENSURE A and B bus main generator output breaker generator side AND bus side manual disconnects are closed.

5.1.2 IF this startup is following reactor vessel disassembly, THEN CONFIRM drywell head shield plug 1 - 4 installation has been completed.

5.1.3 CONFIRM the following Low Steam Line Pressure Relays are energized by observing they are pulled in from their stop screws:

1. Relay A 71-K4A on Panel H12-P609.

2. Relay A71-K4C on Panel H12-P609.

3. Relay A71-K48 on Panel H12-P611.

4. Relay A71-K4D on Panel H12-P611.

5.1.4 CONFIRM the following MSIV Limit Switch Relays are energized by observing they are pulled in from their stop screws:

1. Relay C71(72)-K3A on Panel H12-P609.

2. Relay C71(72)-K3C on Panel H12-P609.

3. Relay C71(72)-K3E on Panel H12-P609.

4. Relay C71(72)-K3G on Panel H12-P609.

5. Relay C71 (72)-K38 on Panel H12-P611

6. Relay C71 (72)-K3D on Panel H12-P611.

7. Relay C71 (72)-K3F on Panel H12-P611.

8. Relay C71 (72)-K3H on Panel H12-P611.

IOGP-03 Rev. 69 Page 6 of 241

5.1 Transferring The Reactor Mode Switch To RUN (Continued) Initials 5.1.5 INCREASE reactor power to 6-10 % by withdrawing control rods, following the OGP-10 designated sequence, in accordance with 1(2)OP-07.

NOTE: During Low Power operations, one Feedwater Flow instrument may indicate flow before the other Feedwater Flow instrument due to pipe flow characteristics. The Process computer requires both Feedwater Line flows to perform a valid Heat Balance calculation.

NOTE: IF the APRM GAFs require adjustment in the following step, AND the process computer is NOT available or the process computer can not perform a Heat Balance calculation, THEN OPT-01.8C, OPT-01.8D, or 1(2)OP-09, should be used as necessary.

5.1.6 ENSURE APRM GAFs are less than or equal to 1.00 for all operable APRMs.

IOGP-03 Rev. 69 Page 7 of 24 I

5.1 Transferring The Reactor Mode Switch To RUN (Continued) Initials 5.1e7 CONFIRM overlap by observing all operable APRMs indicate between 3e4% and 10% on the APRM/RBM recorderse 5.1e8 CONFIRM all operable APRM downscale lights are ofte 5e1e9 CONFIRM no operable IRMs are upscalee 5e1 e10 EVALUATE reactor water chemistry parameters in accordance with OAI-81 e 5.1.11 IF any reactor water chemistry parameter exceeds the limit, THEN REFERENCE OAI-81 for the appropriate action level requirement 5e1e12 ENSURE all items in the AO AND CO Daily Surveillance Report (DSR) which are applicable in Mode 1 have been checked AND are within the specified surveillance interval.

5.1 e13 CONFIRM all Temporary Modifications in the Unit sea Active TPM Book permit entry into Mode 1e 5e1e14 NOTIFY Radiation Control the Reactor Mode Switch is being transferred to RUN and to implement OE&RC-0040 as requirede 5.1 e15 REVIEW all LCOs (active, tracking, and on-hold) to ensure outstanding LCOs are in compliance with Technical Specification 3eOe4 for entry into Mode 1e NOTE: The Hardened Wet-Well vent path is required to be available to comply with the NRC Safety Evaluation for Tech Spec amendments 233 and 260, Increased Flexibility in Mode Restraints.

ENSURE the Hardened Wet-Well vent path is availablee IOGP-03 Rev. 59 Page 8 of 241

5..1 Transferring The Reactor Mode Switch To RUN (Continued) Initials OBTAIN concurrence Section 4.0 and Steps 5.1.1 through 5.1.16 are complete AND Entry into Mode 1 is authorized.

Unit SCQ Date Time SS Date Time PLACE the reactor mode switch to RUN.

ENSURE APRM/RBM recorders are in a mode to display all APRMs/RBMs.

FULLY WITHDRAW all operable IRM detectors AND THEN PLACE all IRM range switches to Position 3.

WHEN reactor power is approximately 150/0, as indicated by performing a HEAT BALANCE using the Plant Process Computer or OPT-01.8D, THEN PERFORM the following:

1. CONFIRM reactor power levels using Attachment 1 from 150/0 power to placing the turbine on-line.

2. PERFORM conservative APRM GAF adjustments, as required, in accordance with 1(2)OP-09.

IOGP-03 Rev. 69 Page 9 of 241

5.1 Transferring The Reactor Mode Switch To RUN (Continued) Initials 5.1.22 ENSURE backfill flow for each reference leg condensing pot is adjusted in accordance with 1(2)OP-01:

Condo Pot. Flow Ind.

0004A 821-FI-6061 0004B 821-FI-6066 0004C 821-FI-6060 00040 821-FI-6064 0002 821-FI-6062 COU-001 821-FI-6063 CDU-002 821-FI-6065 5.2 Placing the Feedwater Heaters in Operation 5.2.1 OPEN the following MVO startup vent valves:

1. DRAIN COOLER 1A SU VENT, MVD-V37.

2g FW HTR 1A AND 2A SU VENT, MVD-V33 and MVD-V34.

3. FW HTR 3A SU VENT, MVD-V92.

4. FW HTR 4A AND 5A SU VENT, MVD-V95 and MVD-V97.

5. DRAIN COOLER 18 SU VENT, MVD-V38.

6. FW HTR 18 AND 28 SU VENT, MVD-V35 and MVD-V36.

7. FW HTR 38 SU VENT, MVD-V94.

8. FW HTR 48 AND 58 SU VENT, MVD-V96 and MVD-V98.

IOGP-03 Rev. 69 Page 10 of 241

5.2 Placing the Feedwater Heaters in Operation (Continued) Initials 5.2.2 MONITOR condenser vacuum closely while placing the feedwater heaters in operation.

5.2.3 SET the following heater level controllers for the respective normal drain level control valves as follows:

1. FW HEA TER 2A LEVEL CONTROLLER, HD-LC-61 J located on Instrument Rack IR-TB-5, black striped indicator to 0 AND in AUTO.

2. FW HEA TER 28 LEVEL CONTROLLER, HD-LC-64, located on Instrument Rack IR-TB-5, black striped indicator to 0 AND in AUTO.

3. FW HEA TER 4A LEVEL CONTROLLER, HD-LC-75, located on Instrument Rack IR-TB-4, black striped indicator to +1 for Unit 1 or to 0 for Unit 2 AND in AUTO.

4. FW HEA TER 5A LEVEL CONTROLLER, HD-LC-83, located on Instrument Rack IR-TB-4, black striped indicator to +1 on Unit 1 or to 0 on Unit 2 AND in AUTO.

5. FW HEA TER 48 LEVEL CONTROLLER, HD-LC-79, located on Instrument Rack IR-TB-3, black striped indicator to 0 on Unit 1 or to +1 on Unit 2 AND in AUTO.

FW HEA TER 58 LEVEL CONTROLLER, HD-LC-87, located on Instrument Rack IR-TB-3, black striped indicator to +1 on Unit 1 or to 0 on Unit 2 AND in AUTO.

5.2.4 SLOWLY OPEN DEAERA TOR FILL & DRAIN VL V, HD-V57, while observing condenser vacuum and off-gas flow until valve indicates full open or condenser vacuum starts to decrease.

IOGP-03 Rev. 69 Page 11 of 241

5.2 Placing the Feedwater Heaters in Operation (Continued) Initials 5~2.5 IF any of the following alarm conditions exist, THEN CLOSE DEAERATOR FILL & DRAIN VLV, HD-V57, to isolate cleanup of feedwater heater piping:

- RFP A TURB DRAINS LEVEL HI, UA-04 1-5.

- RFP 8 TURB DRAINS LEVEL HI, UA-04 2-5.

- High deaerator level (57 inches).

- Low deaerator level (43 inches).

5.2.6 ENSURE the following valves are open:

1. FW HTR SA OUTLET VL V, FW-V6.

2. FW HTR 58 OUTLET VL V, FW-V8.

5.2.7 CONFIRM SULCV, FW-LV-3269 is full open, AND SLOWLY THROTTLE OPEN the following valves:

1. FW HTR 48 INLET VLV, FW-V119.

2. FW HTR 4A INLET VLV, FW-V118.

5.2.8 WHEN FW-V118 and FW-V119 are full open, THEN CONFIRM SULCV FW-LIC-3269, Control Station, is in M (manual) AND DECREASE the VALVE OEM signal to 0 0/0.

THROTTLE CLOSED FEEDWATER RECIRC TO CONDENSER VLV, FW-FV-177, as RFPT A(B) load increases, maintaining greater than 20% output demand signal on MSTR RFPT SP/RX LVL CTL, C32-SIC-R600.

IOGP-03 Rev. 69 Page 12 of 241

5.2 Placing the Feedwater Heaters in Operation (Continued) Initials 5.2.10 WHEN FEEDWATER RECIRC TO CONDENSER VLV, FW-FV-177, is closed, THEN CLOSE FW-FV-177/S0L VLV, FW-V10.

CONFIRM the Backup Nitrogen System is aligned to the drywell in accordance with OOP-46.

5.2.12 IF available, THEN PLACE the drywell pneumatic loads on nitrogen in accordance with OOP-46, prior to exceeding 150/0 reactor power.

1. IF drywell pneumatic loads can NOT be placed on nitrogen, THEN ENSURE drywell pneumatic loads are on nitrogen during all periods that drywell oxygen concentration is required to be less than 40/0 in accordance with Technical Specification 3.6.3.1.

5.2.13 RECORD the time reactor power exceeds 150/0 in the Reactor Operator's log AND INFORM Unit SCO.

5.2.14 INITIATE tracking LCOs on the following items when reactor power exceeds 15%, if necessary:

- CAD. (T.S.3.6.3.2)

Containment oxygen concentration. (T.S. 3.6.3.1)

IOGP-03 Rev. 69 Page 13 of 241

5.2 Placing the Feedwater Heaters in Operation (Continued) Initials 5.2.15 WHEN reactor power reaches 20%, ENSURE the following Reactor Feed Pump seal water temperature controllers are set to 165°F:

- RFP A INBOARD GLAND SEAL DRAIN TEMPERATURE CONTROLLER, COD-TIC-184.

- RFP A OUTBOARD GLAND SEAL DRAIN TEMPERA TURE CONTROLLER, COD-TIC-185.

- RFP B INBOARD GLAND SEAL DRAIN TEMPERA TURE CONTROLLER, COD-TIC-18B.

- RFP B OUTBOARD GLAND SEAL DRAIN TEMPERA TURE CONTROLLER, COD- TIC-187.

5.2.16 PERFORM OPT-13.1 prior to exceeding 25% reactor power.

5.2.17 RAISE reactor power to 20-220/0 by withdrawing control rods in accordance with 1(2)OP-07 in the sequence designated by OGP-10.

5.2.18 ENSURE the surveillance requirement for stroking the Recirculation Pump Discharge Valves, SR 3.5.1.5, is current prior to exceeding 250/0 power.

IOGP-03 Rev. 69 Page 14 of 241

5.3 Turbine Generator Startup and Synchronization Initials 5.3.1 VERIFY the applicable Power-Flow Map based on /

current equipment conditions is selected. Ind.Ver.

NOTE: To minimize the time spent at rated speed prior to synchronizing the generator, preliminary steps in the 1(2)OP-27 generator startup section may be performed concurrent with the 1(2)OP-26 section on rolling the turbine to rated speed.

5.3.2 ROLL the main turbine to rated speed in accordance with 1(2)OP-26.

5.3.3 SYNCHRONIZE the main generator to system grid in accordance with 1 (2)OP-27.

5.3.4 PERFORM APRM GAF adjustments, as required, in accordance with 1 (2)OP-09.

NOTE: The turbine will normally be the limiting factor on load changes since the generator loading is NOT as critical as the turbine.

5.3.5 WHEN greater than 100 MWe is reached, THEN PERFORM the following actions:

1. CLOSE MAIN SV & CV ABOVE SEA T DRN, MVD-GV.

2. CLOSE STM TO EAST MSR DRAIN VLV, MS-V43.

3. CLOSE STM TO WEST MSR DRAIN VLV, MS-V44.

4. CLOSE DRN.VLV, MS-V45.

IOGP-03 Rev. 69 Page 15 of 241

5.3 Turbine Generator Startup and Synchronization (Continued) Initials 5~ ENSURE EAST (WEST) RH STM DRAIN, EBPV-1 is closed.

6. ENSURE WEST (EAST) RH STM DRAIN, EBPV-2 is closed .

7. CONFIRM Unit 1(2) EAST MSR DRAIN VL V, 1-MSDCV-C-1(2-MSDCV-C-2), closes and returns drain tank to automatic level control.

8. CONFIRM Unit 1(2) WEST MSR DRAIN VL V, 1-MSDCV-C-2(2-MSDCV-C-1), closes and returns drain tank to automatic level control.

9. CONFIRM Unit 1(2) EAST 1ST STAGE DRN VLV, 1-1SRDGV-C-1(2-1SRDGV-G-2), closes and returns drain tank to automatic level control.

10. CONFIRM Unit 1(2) WEST 1ST STAGE DRN VLV, 1-1SRDGV-G-2(2-1SRDGV-G-1), closes and returns drain tank to automatic level control.

11. CONFIRM E REHEATER FIRST STAGE LEVEL HI-LOW (UA-23 4-4) annunciator is clear.

12~ CONFIRM W REHEATER FIRST STAGE LEVEL HI-LOW (UA-23 4-5) annunciator is clear.

13. CONFIRM E MOIST SEP LEVEL-LOW (UA-23 3-4) annunciator is clear.

14. CONFIRM W MOIST SEP LEVEL-LOW (UA-23 3-5) annunciator is clear.

15. CONFIRM cross around pipe temperatures are tracking as appropriate on Recorder TSI- TXR-638, Points 10, 11, 12, and 13.

IOGP-03 Rev. 69 Page 16 of 241

5a3 Turbine Generator Startup and Synchronization (Continued) Initials 5.3.6 CLOSE the following MVD startup vent valves:

1. DRAIN COOLER 1A SU VENT, MVD-V37.

2~ FW HTR 1A AND 2A SU VENT, MVD-V33 and MVD-V34.

3. FW HTR 3A SU VENT, MVD-V92.

4. FW HTR 4A AND 5A SU VENT, MVD-V95 and MVD-V97.

5. DRAIN COOLER 18 SU VENT, MVD-V38.

6. FW HTR 18 AND 28 SU VENT, MVD-V35 and MVD-V36.

7. FW HTR 38 SU VENT, MVD-V94.

8. FW HTR 48 AND 58 SU VENT, MVD-V96 and MVD-V98.

NOTE: The frequency for OPT-40.2.6 is: At least once per operating cycle.

NOTE: The PT PMID numbers are: Unit 1 - 00008883-02 (Unit 2- 00009747-02).

5.3.7 IF due, THEN PERFORM OPT-40.2.6.

5.4 Preparation of Heater Drain System for Forward Pumping 5.4.1 PERFORM applicable section of 1(2)OP-35 for recirculating the heater drains in preparation for pumping forward prior to 250/0 turbine load.

IOGP-03 Rev. 69 Page 17 of 241

5.5 Transferring Auxiliary Power From The SAT to the UAT Initials 5.5.1 ENSURE all synchronizing switches on the RTGB are in OFF.

NOTE: Unit 2 components are in parenthesis.

NOTE: WHEN the feeder breaker from the UAT is closed, THEN the feeder breaker from the SAT automatically opens.

5.5.2 PLACE UA T TO BUS 1(2)0 SYNCHRONIZING SWITCH in ON.

5.5.3 CONFIRM synchroscope is at "12 o'clock" position, AND CLOSE VA T TO BUS 1(2)0 BREAKER, A07(A06).

5.5.4 CONFIRM VA T TO BUS 1(2)0 BREAKER, A07(A06),

has closed using the breaker indicating lights.

5.5.5 CONFIRM SA T TO BUS 1(2)0 BREAKER, AD5(A04),

has opened using the breaker indicating lights.

5.5.6 PLACE UA T TO BUS 1(2)0 SYNCHRONIZING SWITCH in OFF.

5.5.7 PLACE UA T TO BUS 1(2)C SYNCHRONIZING SWITCH in ON.

5.5.8 CONFIRM synchroscope is at "12 o'clock" position, AND CLOSE UA T TO BUS 1(2)C BREAKER, AC5(AC4).

5.5.9 CONFIRM UA T TO BUS 1(2)C BREAKER, AC5(AC4),

has closed using the breaker indicating lights.

5.5.10 CONFIRM SAT TO BUS 1(2)C BREAKER, AC7(AC6),

has opened using the breaker indicating lights.

5.5.11 PLACE UA T TO BUS 1(2)C SYNCHRONIZING SWITCH in OFF.

IOGP-03 Rev. 69 Page 18 of 241

5.5 Transferring Auxiliary Power from SAT to UAT (Continued)

Date/Time Completed _

Performed By (Print) Initials Reviewed By: _

COMMENTS:

IOGP-03 Rev. 59 Page 19 of 241

ATTACHMENT 1 Page 1 of 4 IR2S1 Verification Of Reactor Power Level Using Alternate Indications Unit Date: - - - - -

TABLE 1 TIME APPROX. BYPASS STEAM LPRM HEAT APRM INIT.

RXPWR VALVE FLOW % BALANCE GAFs o~ PWR ok PWR PWR 0/0 PWR ~ 1.00 15%

20%

N/A TURBINE N/A N/A N/A N/A N/A N/A ON LINE

1. USE this attachment to validate the heat balance between 15% reactor power and placing the turbine on line, by performing the following:

aft OBTAIN valid Heat Balance (Display 820 or OPT-01.8D) AND RECORD heat balance % power in Table 1.

b. OBTAIN LPRM % PWR (Display 861, Filtered LPRM Readings Edit) AND RECORD in Table 1.

c. OBTAIN Total Steam Flow (Mlb/hr).

Steam Line (A) (B) (C) (D)

(ERFIS) C32FA014 C32FA015 C32FA016 C32FA017 (P603) C32-R603A C32-R603B C32-R603C C32-R603D Total Steam Flow =(A) + (8) + (C) + (D) = _

OR USE Computer Point B041 IOGP-03 Rev. 69 Page 20 of 241

ATTACHMENT 1 Page 2 of 4 Verification Of Reactor Power Level Using Alternate Indications Unit Date:- - - - -

da OBTAIN total bypass valve position (0/0 open):

ERFIS computer point EHCXA002: %

OR RTGB Panel XU1: (record the position (0/0 open) of each)

Unit 1: MS-BPV-1 MS-BPV-2 MS-BPV-3 MS-BPV-4 Total BPV % open = (The sum of adding BPV-1 through BPV-4) = %

4 Unit 2: MS-BPV-1 MS-BPV-2 MS-BPV-3 MS-BPV-4 MS-BPV-5

_ _ _ _0/0 % % % %

MS-BPV-6 MS-BPV-7 MS-BPV-8 MS-BPV-9 MS-BPV-10 Total BPV % open = (The sum of adding BPV-1 through BPV-10) = 0/0 10 NOTE: Typing MAN runs an interactive program called MAN_ALTDSP that performs alternate power calculations based upon user supplied plant inputs.

Remember to enter decimal points for all values. Use the equivalent %

power output from this program for the comparison in the next stepa

e. LOG on to the ERFIS terminal on the SRO's desk:

1) TYPE: SET HOST EC01B (EC02B)

OR SET HOST EC01A (EC02A)

2) TYPE: GEPACUSER, at USERNAME prompt

3) TYPE: GEPAC, at PASSWORD prompt

4) TYPE: MAN (for manual input)

IOGP-03 Rev. 69 Page 21 of 241

ATTACHMENT 1 Page 3 of 4 Verification Of Reactor Power Level Using Alternate Indications Unit Date:- - - - - -

NOTE: The equivalent °/0 power output from this program is to be used for the comparison in the next step.

f. RECORD BYPASS valve, and STEAM FLOW °/0 power alternate indications on Table 1 of this attachment using the values obtained from MAN_ALTDSP in Step eD

g. COMPARE the Heat Balance (0/0) with the other alternate indications (0/0) recorded on Table 1.

Power Ascension may continue IF:

1) The heat balance is greater than all alternate indications (conservative as is).

OR

2) One or more alternate indications are within +/- 5°1o of the heat balance (normal acceptance).

OR

3) There are no alternate indications within +/- 5% of the heat balance provided the APRMs are adjusted greater than or equal to the next highest alternate indication above the heat balance (conservative action) in accordance with 1(2)OP-09.

OTHERWISE, STOP power ascension AND CONTACT Reactor Engineering to account for the differences in agreement.

h. REPEAT the above steps at 20°/0 reactor power and in 10°10 increments until the turbine is placed on line.

2. Definitions for Table 1:

HEAT BALANCE % POWER - A calculation of core thermal power obtained by solving an energy balance on the reactor vessel. Valid heat balance calculations may be obtained from Display 820 edits or manually by performing OPT-01.8D.

Caution must be taken to ensure any failed sensors have valid substituted values .

IOGP-03 Rev. 69 Page 22 of 241

ATTACHMENT 1 Page 4 of 4 Verification Of Reactor Power Level Using Alternate Indications Unit Oate: _

LPRM % POWER - An alternate indication of reactor power calculated only on the process computer which is obtained by averaging calibrated LPRM readings.

This uses points U1NSSALTP and U2NSSALTP.

STEAM FLOW % POWER - An alternate indication of reactor power obtained by correlating the total steam flow to a valid heat balance. Total steam flow can be obtained from Plant Process Computer Point B041, the summation of ERFIS points C32FA014, C32FA015, C32FA016, C32FA017 (main steam lines A, B, C, D), or the summation of RTGB indications C32-R603A, B, C, D, on P603.

BYPASS VALVE % POWER - An alternate indication of reactor power obtained by correlating the total bypass valve position (percent open) to a valid heat balance. Total bypass valve position can be obtained from ERFIS point EHCXA002, or RTGB Panel XU1.

IOGP-03 Rev. 69 Page 23 of 241

REVISION

SUMMARY

Revision 69 removes requirement for Backup Nitrogen to be placed in service prior to 150/0 reactor power.

Revision 68: Steps are added to set RFPT seal water temperature controllers to 165°F when reactor power is 20% in accordance with NCR 165801.

Revision 67 clarifies information regarding Feedwater Line flow indication and what is required for APRM GAF adjustments when the Process Computer is not calculating a Heat Balance.

Revision 66 incorporates NCR 156480 to ensure the correct Power-Flow Map is selected prior to rolling the Turbine.

Revision 65 deletes Precaution and Limitation for guidance associated with pressure regulator inoperability.

Revision 64 incorporates Tech Spec amendments 233 and 260, Increased Flexibility in Mode Restraints, which affects mode changes with respect to LCO 3.0.4; revises step to ensure drywell pneumatics are on nitrogen during all periods the drywell is required to be inerted iaw the FSAR.

Revision 63 reflects Unit 2 pressure set change to 928 psi iaw EC 50554.

Revision 62 adds step to ensure SR 3.5.1.5 is satisfied prior to exceeding 25% power.

Revision 61 places Unit 1 4A FWH level controller to +1 iaw FWH replacement in EC 50045; changes prerequisite values for reactor pressure on Unit 1 due to change in initial pressure set iaw EC 50552.

Revision 60 incorporated changes for the following: 1) EC 47907, Implement Extended Power Uprate for Unit 2 Operation, 2) EC 46737, Phase 2 Obsolete Recorder Replacement for PRNM, 3) EC 47750, Feedwater Heater 4B Replacement, and

4) EC 46730, Replace Unit 2 Power Range Neutron Monitoring System.

Revision 59 added initial PRA analysis recommendations to Step 3.4 on operation with an inoperable pressure regulator. (AR 75598 Unit 1 EHC Pressure Regulator Action Plan)

Revision 58 added a Section 5.1 step to confirm the drywell head shield plugs 1-4 have been installed prior to placing the mode switch in Run.

Revision 57 incorporated changes to the Unit 1, 5 AlB heater level controller setup in Step 5.2.3 to set the level controller at +1". This agrees with the setup in 10P-35 per vendor recommendations in accordance with the final test data of ESR 01-00021, which replaced the heaters.

IOGP-03 Rev. 69 Page 24 of 241

Unit 2 APP A-OS 1-4 Page 1 of 2 IRM DOWNSCALE AUTO ACTIONS

1. Rod withdrawal block (bypassed when IRM range switch for the affected channel is on Range 1 or when the reactor mode switch is in RUN) .

2. Computer printout.

CAUSE

1. IRM channel(s) indicating less than or equal to 6.5 on the 0-125 scale when its range switch is not on Range 1.

2. Improper ranging of IRM channels during reactor startup or shutdown.

3. IRM detector not fully inserted.

4. IRM detector failure.

5. Circuit malfunction.

OBSERVATIONS

1. IRM channel indicating less than or equal to 6.5 on the 0-125 scale.

2. IRM downscale (DNSC) white indicating light is on.

3. ROD OUT BLOCK (A-OS 2-2) alarm, if affected IRM channel is not on Range 1.

4. If the affected IRM channel(s) is not on Range 1, the rod withdrawal permissive indicating light will be off.

ACTIONS

1. Monitor IRM indications to determine affected channel(s).

2. If the affected IRM detector white In light is not on, attempt to fully insert the detector.

3. Adjust the range switch for the affected IRM channel(s) until the indication reads more than 6.5 on the 0-125 scale.

4. If the alarm still exists, perform the following:

a. Refer to technical specifications for IRM channel operability requirements.

b. Notify the Unit SCo.

c. Bypass the affected IRM channel using the IRM bypass switch.

!2APP-A-05 Rev. 52 Page 10 of 941

Unit 2 APP A-OS 1-4 Page 2 of 2 DEVICEjSETPOINTS Relay C51-Z2A-K90 Deenergized IRM A, B, C/ D, E, F, G, or H 3.5-6.5 on a 0-125 scale downscale trip unit POSSIBLE PLANT EFFECTS

1. If an IRM channel is bypassed or inoperable, a technical specification LCO may result.

REFERENCES I. LL-9364 - 77

2. FP-5852 - 8

3. Technical Specification 3.3.1.1

4. APP A-OS 2-2/ ROD OUT BLOCK 12APP-A-05 Rev. 52 Page 11 of 941

Unit 2 APP A-05 2-2 Page 1 of 2 ROD OUT BLOCK AUTO ACTIONS 1~ Rod withdrawal prohibited~

CAUSE 1~ South SDV not drained~

2~ North SDV not drained.

3~ SRM downscale and any IRM is below Range 3~

4~ IRM downscale and affected IRM channel is not on Range 1~

5~ SRM upscale/inoperative and any IRM channel is below Range 8~

6~ IRM upscale and the reactor system mode switch is not in the RUN position~

7~ IRM A upscale/inoperative and the reactor system mode switch is not in the RUN position~

8~ SRM detector not fully inserted and log count rate is less than or equal to 100 cps (bypassed when all IRM channels are above Range 2 or the reactor system mode switch is in the RUN position) ~

9. IRM B upscale/inoperative and the reactor system mode switch is not in the RUN position~

10. APRM downscale and the reactor system mode switch is in the RUN position.

11~ APRM UPSCALE alarm.

12. APRM UPSCALE TRIP/INOP alarm.

13~ Less than 17 LPRM inputs to any APRM or less than 3 LPRMs per axial level for any APRM~

14~ RBM downscale and reactor system mode switch is in the RUN position.

15~ RBM upscale/inoperative.

16~ Recirc flow signal to any APRM greater than or equal to 110%~

17. Discharge Volume Hi Water Level Trip Bypass switch in Bypass with the Reactor System Mode Switch in Shutdown or Refuel.

18. Reactor System Mode Switch in Refuel with a second rod selected and another rod not full in.

NOTE: The Service Platform has been removed. Associated refuel interlocks are non-functional, but available.

19. Reactor System Mode Switch in Startup AND the refuel bridge is over the core OR the service platform is loaded.

20. Reactor System Mode Switch in Refuel with the service platform loaded~

21. Reactor System Mode Switch in Refuel with the refuel bridge over the core AND the grapple loaded OR not full up.

22. Reactor System Mode Switch in Refuel with the refuel bridge over the core AND any refuel bridge hoist loaded.

23. No power to the refuel bridge.

24. Reactor System Mode Switch in Shutdown.

25. Any IRM detector not fully inserted and the reactor mode switch is not in RUN.

26. Circuit malfunction.

!2APP-A-05 Rev. 52 Page 20 of 941

Unit 2 APP A-OS 2-2 Page 2 of 2 OBSERVATIONS

1. Selected rod will not withdraw.

2. Rod withdraw permissive light is off.

3. SOUTH SDV NOT DRND (A-OS 1-1) alarm.

4. NORTH SDV NOT DRND (A-OS 2-5) alarm.

5. SRM DOWNSCALE (A-OS 1-3) alarm.

6. IRM DOWNSCALE (A-OS 1-4) alarm.

7. SRM UPSCALE/INOP (A-OS 2-3) alarm.

8. IRM UPSCALE (A-OS 2-4) alarm.

9. IRM A UPSCALE/INOP (A-OS 3-4) alarm.

10. SRM DET RETRACT NOT PERMITTED (A-OS 4-3) alarm.

11. IRM B UPSCALE/INOP (A-OS 4-4) alarm.

12. APRM DOWNSCALE (A-06 2-7) alarm.

13. APRM UPSCALE (A-06 2-8) alarm.

14. APRM TROUBLE (A-06 3-7) alarm.

15. APRM UPSCALE TRIP/INOP (A-06 3-8) alarm.

16. RBM DOWNSCALE/TROUBLE (A-06 4-7) alarm.

17. RBM UPSC/INOP (A-06 4-8) alarm.

18. FLOW REF OFF NORMAL (A-06 5-7) alarm.

ACTIONS

1. Refer to appropriate Annunciator procedure listed in OBSERVATIONS.

2. Verify proper position of the Discharge Volume Hi Water Level Trip Bypass switch, refer to APP A-OS 1-5.

3. Verify proper positioning of the refueling equipment and power supplies.

DEVICE/SETPOINTS Rod Out Block Relays C12A-Kl or CI2A-K2 Deenergized POSSIBLE PLANT EFFECTS

1. Control rods may not be withdrawn from the core while the rod block is in effect.

REFERENCES

1. LL-9364 - 74 20 FP-S0012 - 6 12APP-A-05 Rev. 52 Page 21 of 941

6-1 CRD ACCUM LO PRESS/HI LEVEL Page 1 of 1 1.0 OPERATOR ACTIONS:

1.1 CONFIRM which CRD is causing the annunciator by observation of the amber light on the affected HCU on the Full Core Display.

1.2 OBSERVE Automatic Functions:

1.2.1 At the local CRD HCU Panel, the red indication light is ON for the affected HCU.

1.3 PERFORM Corrective Actions:

NOTE: Accumulator pressure less than 940 psig will render the accumulator inoperable.

NOTE: IF this annunciator is sealed in, THEN the other accumulator alarms will be masked, AND contingency plans should be made to monitor the other accumulator alarms at the discretion of the Unit SeQ.

1.3.1 DETERMINE if alarm is due to low pressure or high water level in the HCU by depressing the lighted indication on the local HCU panel and observing the status of the light (light out indicates water).

1.3.2 IF nitrogen pressure is low, THEN CHARGE the accumulator per 2QP-08, CRD Hydraulic System Operating Procedure.

1.3.3 IF alarm is due to high water level, THEN DRAIN the accumulator per 20P-08, CRD Hydraulic System Operating Procedure.

2.0 CAUSES

2.1 Leaking accumulator rings.

2.2 Low nitrogen charge pressure.

3.0 DEVICES

SETPOINT:

3.1 Level Switch C12-LDSH-129 60 cc (Each HCU) 3.2 Pressure Switch C12-PSL-130 955 psig (Each HCU)

4.0 REFERENCES

4.1 LL-9364 - 98 4.2 Technical Specification 3.1.5 4.3 20P-08, Control Rod Drive Hydraulic System Operating Procedure 12APP-A-07 Rev. 31 Page 38 of 451

Control Rod Scram Accumulators 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Control Rod Scram Accumulators LCO 3.1.5 Each control rod scram accumulator shall be OPERABLE.

APPLICABI LITY: MODES 1 and 2.

ACTIONS

~()TE-----------------------------------------------------------

Separate Condition entry is allowed for each control rod scram accumulator.

CONDITION REQUIRED ACTION COMPLETION TIME A. One control rod scram A. 1 --------------N()TE--------------

accumulator inoperable with Only applicable if the reactor steam dome associated control rod pressure ~ 950 psig. . scram time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the associated 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months control rod scram time "slow."

OR A.2 Declare the associated 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months control rod inoperable.

(continued)

Brunswick Unit 2 3.1-15 Amendment No. 233

Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Two or more control rod B.1 Restore charging water 20 minutes from scram accumulators header pressure to discovery of inoperable with reactor ~ 940psig. Condition B steam dome pressure concurrent with

~ 950 psig. charging water header pressure

< 940 psig AND 8.2.1 ----------NOTE----------

Only applicable if the associated control rod scram time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months control rod scram time "slow."

8.2.2 ' Declare the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months control rod inoperable.

(continued)

Brunswick Unit 2 3.1-16 Amendment No. 233

Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more control rod C.1 Verify all control rods Immediately upon scram accumulators associated with inoperable discovery of inoperable with reactor accumulators are fully charging water steam dome pressure inserted. header pressure

< 950 psig. < 940 psig AND C.2 Declare the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months control rod inoperable.

D. Required Action B.1 or C.1 D.1 -------------~OTE--------------

and associated Completion Not applicable if alt Time not met. inoperable control rod scram accumulators are associated with fully inserted control rods.

Manually scram the reactor. Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each control rod scram accumulator pressure is 7 days

~ 940 psig.

Brunswick Unit 2 3.1-17 Amendment No. 233

Unit 2 APP-UA-02 2-5 Page 1 of 2 STM PACKING EXHAUSTER B OVLD TRIP AUTO ACTIONS

1. Steam Packing Exhauster B trips.

2. Steam Packing Exhauster B discharge valve closes.

CAUSE

1. Steam Packing Exhauster B overload due to:

a. Discharge valve open too far.

b. Impeller rubbing.

c. Bearing damaged.

d. Motor winding faulty.

e. Impeller flooded due to tube leaks in heat exchanger.

f. Insufficient sealing steam to turbine.

g. Operation with excessive steam seal header pressure.

h. Insufficient condensate flow resulting in steam/moisture in exhauster.

2. Circuit malfunction.

OBSERVATIONS

1. Steam packing exhauster suction header vacuum on OG-PI-EPT9 below normal (10 inches H20) .

2. Exhauster discharge valve closed indication.

3. Main condenser vacuum is decreasing.

4. Off-gas flow increasing.

5. Steam seal header pressure high.

ACTIONS

1. Start Steam Packing Exhauster A and verify that its suction valve opens per 20P-26.1.

2. Adjust the Steam Packing Exhauster A discharge valve to maintain the vacuum on OG-PI-EPT9 at 10 inches H20.

3. Reset SPE B and verify that the loop seal is drained.

4. If steam seal header pressure is above 7 psig, check the Steam Seal Feed Valve MS-SSFV operating correctly as follows:

a. Throttle closed, Mn Steam to Seals Vlv MVD-Sl to restore steam seal header pressure between 1.5 and 4.0 psig.

b. If throttling the MVD-Sl was successful in restoring steam seal header pressure, then bypass the Steam Seal Feed Valve per 20P-26.1 Section 8.3.

c. If throttling the MVD-Sl was not successful then reopen MVD-Sl and bypass the Steam Seal Unloading valve by throttling open Steam Seal Bypass Unload Vlv, MVD-B.

5. If moisture is suspected in Steam Packing Exhauster instrument lines, drain per 20P-26.1 Section 8.2.

12APP-UA-02 Rev. 33 Page 29 of 921

Unit 2 APP-UA-02 2-5 Page 2 of 2 DEVICE/SETPOINTS Overload device 49 in breaker Thermal overload 480V MCC 2TD Compartment CMS POSSIBLE PLANT EFFECTS

1. If the turbine gland seals are lost, the Turbine Building may become an airborne radiation area.

2. Turbine trip due to low condenser vacuum.

3. If the turbine gland sealing vacuum is lost, water vapor may be entering the main lube oil system through the shaft oil deflectors.

REFERENCES

1. LL - 93 53 - 15

2. 20P-26.1, Turbine Gland Sealing Steam System 12APP-UA-02 Rev. 33 Page 30 of 921

Unit 2 APP-UA-02 4-5 Page 1 of 2 GLAND SEAL VACUUM LOSS AUTO ACTIONS NONE CAUSE

1. Steam packing exhauster not operating.

2. Steam packing exhauster suction/discharge valve throttled closed, so gland seal vacuum cannot be maintained.

3. Tube leaks in gland exhauster condenser.

4. Steam Seal Feed Valve or the Steam Packing Unloading valves are not controlling steam seal header pressure correctly.

5. Insufficient condensate flow through the steam packing exhauster.

6. Circuit malfunction.

OBSERVATIONS

1. Gland seal vacuum on OG-PI-EPT9-SPE below 5 inches of water.

2. Main condenser vacuum decreasing.

3. Increased off-gas flow.

4. Steam seal header pressure high.

ACTIONS

1. Start standby exhauster and adjust its discharge valve to maintain vacuum between 10 and 20 inches H2 0 per 20P-26.1.

2. If gland seal regulator is not operating properly, refer to 2APP-UA-02 3-5, STEAM SEAL REGULATOR PRESS-LOW.

3. Drain the loop seals on the in-service steam packing exhauster.

4. If steam seal header pressure is above 7 psig, check the Steam Seal Feed Valve MS-SSFV operating correctly as follows:

a. Throttle closed, Mn Steam to Seals Vlv MVD-Sl to restore steam seal header pressure between 1.5 and 4.0 psig.

b. If throttling the MVD-S1 was successful in restoring steam seal header pressure, then bypass the Steam Seal Feed Valve per 20P-26.1 Section 8.3.

c. If throttling the MVD-S1 was not successful then reopen MVD-S1 and bypass the Steam Seal Unloading Valve by throttling open Steam Seal Bypass Unload Vlv r MVD-B.

5. If moisture is suspected in Steam Packing Exhauster instrument lines, drain per 20P-26.1 Section 8.2.

DEVICE/SETPOINTS Pressure Switch OG-PS-VS-SPE 5 inches of water 12APP-UA-02 Rev. 33 Page 55 of 921

Unit 2 APP-UA-02 4-5 Page 2 of 2 POSSIBLE PLANT EFFECTS

1. If the turbine gland sealing vacuum is lost, radioactive steam may be released to the Turbine Building atmosphere.

2. If the turbine gland sealing vacuum is lost, water vapor may be entering the main lube oil system through the shaft oil deflectors.

REFERENCES

1. LL-9353 - 15 Rev. 6

2. 20P-26.1, Turbine Gland and Seal System

3. 2APP-UA-02 3-5, STEAM SEAL REGULATOR PRESS-LOW 12APP-UA-02 Rev. 33 Page 56 of 921

8.0 INFREQUENT OPERATIONS R Reference Use 8.1 Shifting Steam Packing Exhausters 8.1.1 Initial Conditions

1. Gland Sealing Steam System is in operation in D accordance with Section 5.1.

8.1.2 Procedural Steps

1. IF STEAM PACKING EXHAUSTER, SPE A, is operating, THEN PERFORM the following:

a. OPEN FLOA T TRAP OUTLET VAL VE, MVD- V52. D

b. START STEAM PACKING EXHAUSTER, SPE B. D

c. ENSURE STEAM SEAL SPE 28 MO INLET VL V, D OG-MO V-E2, is open.

d. THROTTLE CLOSED STEAM SEAL SPE 2A MO D DISCH VLV, OG-MOV-D1, AND THROTTLE OPEN STEAM SEAL SPE 28 MO DISCH VL V, OG-MOV-D2, while maintaining GLAND EXHAUST HEADER, OG-PI-EPT-9, located on Panel XU-2, between 10 and 20 inches water vacuum.

e. ENSURE STEAM SEAL SPE 2A MO DISCH VL V, D OG-MOV-D1, is closed.

f. STOP STEAM PACKING EXHAUSTER, SPE A. D

g. CLOSE FLOAT TRAP OUTLET VALVE, MVD-V51. D

h. ENSURE STEAM SEAL SPE 2A MO INLET VALVE, D OG-MOV-E1, is closed.

!20P-26.1 Rev. 37 Page 13 of 281

8.1.2 Procedural Steps

2. IF STEAM PACKING EXHAUSTER, SPE B, is operating, THEN PERFORM the following:

a. OPEN FLOA T TRAP OUTLET VAL VE, MVD- V51. D

b. START STEAM PACKING EXHAUSTER, SPE A. D

c. ENSURE STEAM SEAL SPE 2A MO INLET VL V, D OG-MOV-E1, is open.

d. THROTTLE CLOSED STEAM SEAL SPE 2B MO D DISCH VLV, OG-MOV-D2, AND THROTTLE OPEN STEAM SEAL SPE 2A MO DISCH VL V, OG-MOV-D1, while maintaining GLAND EXHAUST HEADER, OG-PI-EPT-9, located on Panel XU-2, between 10 and 20 inches water vacuum.

e. ENSURE STEAM SEAL SPE 28 MO DISCH VL V, D OG-MOV-D2, is closed.

f. STOP STEAM PACKING EXHAUSTER, SPE 8. D

g. CLOSE FLOAT TRAP OUTLET VALVE, MVD-V52. D

h. ENSURE STEAM SEAL SPE 28 MO INLET VALVE, D OG-MOV-E2, is closed.

120P-26.1 Rev. 37 Page 14 of 281

,~

W Progress Energy BRUNSWICK NUCLEAR PLANT PLANT OPERATING MANUAL VOLUME XXI ABNORMAL OPERATING PROCEDURE UNIT o

OAOP-13.0 OPERA TION DURING HURRICANE, FLOOD CONDITIONS, TORNADO, OR EARTHQUAKE REVISION 37 IOAOP-13.0 Rev. 37 Page 1 of 40 I

1.0 SYMPTOMS NOTE: Notification of a hurricane or tornado warning will be provided to the control room from contract Meterological Services, the Raleigh Load Dispatcher, or Security personnel.

1.1 A watch or warning has been issued by the National Weather Service.

1.2 News or weather report indicates possible flooding in the area.

1.3 Unstable weather conditions.

1.4 Increasing intake canal level (SCW-LR-285ICW-LR-761 on XU-2).

1.5 INTAKE CANAL LEVEL-HIGH (UA-24 6-8) is in alarm.

1.6 SEISMIC EVENT (UA-28 6-4) is in alarm.

NOTE: Additional weather information may be obtained from the National Weather Service. Telephone numbers are in EPL-001.

2.0 AUTOMATIC ACTIONS None 3.0 OPERATOR ACTIONS 3.1 Immediate Actions None 3.2 Supplementary Actions NOTE: Actions contained in this procedure for abnormal operating conditions are addressed as foHows:

Condition Step Tornado 3.2.1 Earthquake 3.2.2 Hurricane 3.2.3 Flood 3.2.4 IOAOP-13.0 Rev. 37 Page 2 of40 I

3.0 OPERATOR ACTIONS 3.2.1 IF a Tornado Warning OR Tornado Watch has been issued, THEN PERFORM the following:

1. REFER to OAI-68 for additional actions. D

2. IF a Tornado Warning has been issued, THEN PERFORM the following:

a. TERMINATE all unnecessary activities. D

b. IF off-site power is NOT available, THEN ENTER D OAOP-36.1.

c. IF Control Room Air Conditioning Units are NOT D available AND Control Room temperature is greater than or equal to 104°F, THEN EXECUTE compensatory actions in accordance with Attachment 5.

3. IF a Tornado Watch has been issued, THEN PERFORM the following:

a. SURVEY outside areas to determine potential D damages and preventive measures.

b. REVIEW all LCOs for equipment out of service. D

c. EXPEDITE the return to service of all safety D equipment, especially equipment required for loss of off-site power.

d. NOTIFY Maintenance to immediately unload and D secure the Unit 1 and Unit 2 Reactor Building 117' cranes until the severe wind threat has passed.

e. IF time permits, THEN ENSURE the following:

- All doors on transformer cubicles, switchyard D cubicles, fire hose cubicles, other cubicles and panels in outside areas are properly closed

- All gas bottles and fire extinguishers are D properly secured

- All outside cranes are secure D IOAOP-13.0 Rev. 37 Page 3 of 40 I

3.0 OPERATOR ACTIONS

- All outside windows, doors, and severe D weather doors are closed. (Attachment 3)

NOTE: A Control Operator key is required to unlock SYA and SYB Cabinet doors.

Security must be notified prior to unlocking these doors.

f. IF time permits THEN ENSURE all outside lights on as follows:

- PLACE light switch at MCC-SYA, Compt. BZ3 D in MANUAL.

- PLACE light switch at MCC-SYB, Compt. CC3 D in MANUAL.

- PLACE light switch at U1 TB, 70' between Dist D Panel 1E-480V and S/E hot side entrance ON.

- PLACE light switch at U2 TB, 70' between Dist D Panel 2E-480V and N/E hot side entrance in MANUAUON.

g. IF time permits, THEN REVIEW the following procedures with shift personnel:

- OAOP-36.1 D

- OAOP-36.2 D

- The remainder of this procedure. D

4. WHEN the Tornado Warning OR Tornado Watch has D expired, THEN RETURN plant equipment to normal.

IOAOP-13.0 Rev. 37 Page 4 of 40 I

3.0 OPERATOR ACTIONS NOTE: A Control Operator key is required to unlock SYA and SYB Cabinet doors.

Security must be notified prior to unlocking these doors.

5. WHEN the Tornado Warning OR Tornado Watch has expired, THEN RETURN plant lighting to normal as follows:

- PLACE light switch at MCC-SYA, Compt. BZ3 D in AUTO.

- PLACE light switch at MCC-SYB, Compt. CC3 D in AUTO.

- PLACE light switch at U1 TB, 70' between Dist D Panel 1E-480V and S/E hot side entrance OFF.

- PLACE light switch at U2 TB, 70' between Dist D Panel 2E-480V and N/E hot side entrance in AUTO/OFF.

IOAOP-13.0 Rev. 37 Page 5 of 40 I

3.0 OPERATOR ACTIONS 3.2.2 IF an Earthquake has occurred, THEN PERFORM the following:

1. DISPATCH an operator to determine the earthquake D acceleration in accordance with Attachment 4.

2. CHECK the following plant parameters to provide a quick check on the status of the units:

Reactor Power D Reactor Pressure D

- Reactor Level D

- Area Radiation Monitors D Feedwater Flow D

- Generator Load D

- Condenser Vacuum D

- Turbine Vibration and Bearing Temperature. D

3. CHECK the following for changes which may indicate core shroud movement at the top guide support ring reinforcing brackets:

Power/Flow relationship D Flux variations (determined by the Nuclear Engineer) D Rising suction temperature in one or both D recirculation loops.

4. CHECK the following for indications of power losses:

Electrical Distribution System D

- Switchyard D Grid System D

5. CHECK all annunciator panels (including local panels) D for indications of abnormal conditions.

IOAOP-13.0 Rev. 37 Page 6 of 40 I

3.0 OPERATOR ACTIONS

6. CHECK the following systems for indications of abnormal conditions:

- Main Steam Leak Detection D RWCU System Leak Detection D

- RCle System Leak Detection D HPCI System Leak Detection D

- RHR System Leak Detection D

- ADS Leak Detection D

- Radwaste Equipment Area Leak Detection D Reactor Recirculation Pump Leak Detection. D

7. CONFIRM the occurrence of the seismic event by D contacting the National Earthquake Center at 1-303-273-8500.

8. IF the plant can NOT operate in a safe condition OR the acceleration exceeded 0.08g during a confirmed earthquake} THEN INITIATE the following:

- A controlled shutdown of both units in accordance D with OGP-05

- An LCO for secondary containment integrity in D accordance with 001-01.08, due to possible link seal failure

- A WO to inspect the core shroud in the area of the D core shroud brackets for evidence of shifting or movement.

9. IF the acceleration did NOT exceeded 0.08g, THEN D INITIATE an operability determination for secondary containment integrity, including an evaluation for link seals, in accordance with OPS-NGGC-1305.

10. INITIATE a plan to inspect all plant equipment AND D evaluate damage as soon as practical.

IOAOP-13.0 Rev. 37 Page 7 of 40 I

3.0 OPERATOR ACTIONS

11. IF damage is suspected on any system, THEN D PERFORM the appropriate testing to ensure operability as soon as practical.

12. IF a seismic event is confirmed, THEN INITIATE a WO to remove the record plates from the peak shock recorders so that they may be forwarded to the vendor for evaluation (reference TRM 3.9 condition A and bases):

- OMST-SEIS21R (after 5 days and within 10 days of D the event).

- 2MST-SEIS22R (after 5 days and within 10 days of D the event).

13. IF Control Room Air Conditioning Units are NOT D available AND Control Room temperature is greater than or equal to 104°F, THEN EXECUTE compensatory actions in accordance with Attachment 5.

IOAOP-13.0 Rev. 37 Page 8 of 40 I

3.0 OPERATOR ACTIONS NOTE: A hurricane is defined as a weather condition with sustained wind speeds in excess of 73 miles per hour as provided by the National Weather Service.

3.2.3 IF a Hurricane Watch or Warning has been issued OR Hurricane Conditions exist, THEN PERFORM the following:

1. REFER to OAI-68 for additional actions. D

2. IF a Hurricane Watch has been issued, THEN PERFORM the following:

a. SURVEY outside areas to determine potential D damages and preventive measures.

b. REVIEW all LCOs for equipment out of service. D

c. EXPEDITE the return to service of all safety D equipment, especially equipment required for loss of off-site power.

3. IF a Hurricane Warning has been issued, THEN PERFORM the following:

a. REVIEW the following procedures with shift personnel:

OAOP-36.1 D OAOP-36.2 D

- The remainder of this procedure. D

b. ENSURE the following:

- All doors on transformer cubicles, switchyard D cubicles, fire hose cubicles, other cubicles and panels in outside areas are properly closed

- All gas bottles and fire extinguishers are D properly secured

- All outside cranes are secure D IOAOP-13.0 Rev. 37 Page 9 of 40 I

3.0 OPERATOR ACTIONS

- All outside windows, doors, and severe D weather doors are closed. (Attachment 3)

NOTE: A Control Operator key is required to unlock SYA and SYB Cabinet doors.

Security must be notified prior to unlocking these doors.

c. ENSURE all outside lights on as follows:

PLACE light switch at MCC-SYA, Compt. BZ3 D in MANUAL.

- PLACE light switch at MCC-SYB, Compt. CC3 D in MANUAL.

- PLACE light switch at U1 TB, 70' between Dist D Panel 1E-480V and S/E hot side entrance ON.

PLACE light switch at U2 TB, 70' between Dist D Panel 2E-480V and N/E hot side entrance in MANUAUON.

d. COMPLETE Attachments 1 and 2 to track the hurricane path and record anticipated hurricane arrival at the site.

e. SHUTDOWN the Storage Tank Lube Oil D Conditioner in accordance with OOP-49.

NOTE: MUD tank transfer should NOT fill the CSTs such that normal Radwaste processing to the CSTs will be restricted.

f. TRANSFER available water from MUD Tank to D the CST.

g. CONTACT maintenance to secure the Reactor D Building Chillers prior to storm arrival.

h. NOTIFY Maintenance to immediately unload and D secure the Unit 1 and Unit 2 Reactor Building 117' cranes until the severe wind threat has passed.

IOAOP-13.0 Rev. 37 Page 10 of 40 I

3.0 OPERATOR ACTIONS NOTE: Both Units must be in Mode 3 at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months prior to the anticipated arrival of the hurricane at the site.

NOTE: Loss of all AC power would result in a loss of all low pressure cooling water injection capability.

i. INITIATE actions necessary to prepare to place D both units in at least Mode 3.

j. IF the Units are being taken to Mode 4, THEN D MAINTAIN plant conditions as necessary to allow entering Mode 3 during the storm.

k. START AND LOAD TEST each diesel generator D that has NOT been load tested in the previous 7 days in accordance with OOP-39.

I. IF flood conditions are expected at the site or D Caswell Beach Pumping Station, THEN GO TO Step 3.2.4 AND PERFORM CONCURRENTLY.

m. TERMINATE all unnecessary activities. D NOTE: Drywell pressure changes will occur as the eye of the hurricane approaches and departs the site.

n. WHEN the anticipated arrival of the hurricane is within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , THEN PERFORM the following at Caswell Beach Pumping Station:

ENSURE all equipment is stowed and secure D ENSURE all controls in remote D BACKWASH lube water strainers D IOAOP-13.0 Rev. 37 Page 11 of 40 I

3.0 OPERATOR ACTIONS PLACE all available lube water pumps in D operation

- MONITOR discharge canal level. D NOTE: The individual below should be assigned prior to conditions that would prevent or delay access. Adequate food supplies should be available if an extended stay is expected.

o. ASSIGN at least one individual dedicated locally to the following buildings:

Diesel Generator Building D

- Service Water Building. D

p. ARRANGE with diesel fuel suppliers for deliveries D following passage of the hurricane.

4. IF Hurricane Conditions exists, THEN PERFORM the following:

a. MAINTAIN communications with Load Dispatcher D for weather conditions.

b. IF off-site power is NOT available, THEN ENTER D OAOP-36.1.

c. MONITOR the intake canal water level. D

- IF the intake canal water level increases to D greater than or equal to +15 feet MSL, THEN RECORD canal level at least once per two hours AND COMPLY with the Technical Requirements Manual 3.20.

PRIOR to intake canal water level reaching -5 D feet MSL, REFERENCE 1(2)OP-29 Precautions for required actions associated with the circulating water system.

IOAOP-13.0 Rev. 37 Page 12 of 40 I

3.0 OPERATOR ACTIONS NOTE: RBCCW and RHR service water flows may be reduced as necessary to maintain NSW pressure.

- IF the intake canal water level decreases to D less than or equal to -5 feet MSL, THEN MAINTAIN greater than 63 psig in the NSW headers.

- IF the intake canal water level decreases to D less than or equal to - 6 feet MSL, THEN REFERENCE Tech Spec 3.7.2.

d. IF flooding conditions occur at the site or Caswell D Beach Pumping Station, THEN GO TO Step 3.2.4 AND PERFORM CONCURRENTLY.

e. IF the Caswell Beach Substation is lost, THEN PERFORM the following:

- OPEN the 23 Kv feeder D

- PLACE the feeder under clearance. D NOTE: A Control Operator key is required to unlock SYA and SYB Cabinet doors.

Security must be notified prior to unlocking these doors.

5. WHEN the Hurricane Watch or Warning OR Hurricane Conditions have expired, THEN RETURN plant lighting to normal as follows:

- PLACE light switch at MCC-SYA, Compt. BZ3 D in AUTO.

- PLACE light switch at MCC-SYB, Compt. CC3 D in AUTO.

- PLACE light switch at U1 TB, 70' between Dist D Panel 1E-48QV and S/E hot side entrance OFF.

- PLACE light switch at U2 TB, 70' between Dist D Panel 2E-480V and N/E hot side entrance in AUTO/OFF.

IOAOP-13.0 Rev. 37 Page 13 of 40 I

3.0 OPERATOR ACTIONS 3.2.4 IF flooding of the site or Caswell Beach Pumping Station is expected OR has occurred, THEN PERFORM the following:

1. IF flooding of the site is expected, THEN PERFORM the following:

a. ENSURE the following:

- All doors on transformer cubicles, switchyard D cubicles, fire hose cubicles, other cubicles and panels in outside areas are properly closed

- All gas bottles and fire extinguishers are D properly secured

- All outside cranes are secure D

- All outside windows, doors, and severe D weather doors are closed. (Attachment 3)

NOTE: A Control Operator key is required to unlock SYA and SYB Cabinet doors.

Security must be notified prior to unlocking these doors.

b. ENSURE all outside lights on as follows:

- PLACE light switch at MCC-SYA, Compt. BZ3 D in MANUAL.

- PLACE light switch at MCC-SYB, Compt. CC3 D in MANUAL.

- PLACE light switch at U1 TB, 70' between Dist D Panel 1E-480V and S/E hot side entrance ON.

- PLACE light switch at U2 TB, 70' between Dist D Panel 2E-480V and N/E hot side entrance in MANUAUON.

c. CONFIRM proper operation of sump pumps AND D PLACE their control switches in AUTO.

IOAOP-13.0 Rev. 37 Page 14 of 40 I

3.0 OPERATOR ACTIONS

d. CONTACT maintenance to ensure installation of o portable pumps in accordance with OAI-58 and additional locations as necessary.

e. ENSURE a temporary engine driven pump has been installed at the Storm Drain Collection Basin.

o (Reference PMID 9922-3)

f. CLOSE the seal openings to the Diesel Generator Building and fuel oil four-day tank vaults.

o NOTE: The individual below should be assigned prior to conditions that would prevent or delay access. Adequate food supplies should be available if an extended stay is expected.

g. ASSIGN at least one individual dedicated locally to the following buildings:

Diesel Generator Building o

- Service Water Building. o

h. IF the intake canal increases to greater than or o equal to +4 feet MSL, THEN SECURE service water chlorination to prevent carryover to the Screen Wash System.

i. IF the intake canal water level increases to greater than or equal to +15 feet MSL, THEN PERFORM the following:

RECORD canal level at least once per two 0 hours0 days 0 hours 0 weeks 0 months

- COMPLY with the Technical Requirements 0 Manual 3.20.

IOAOP-13.0 Rev. 37 Page 15 of 40 I

3.0 OPERATOR ACTIONS NOTE: The plant should reach Mode 4 within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of reaching the +20 feet MSL is reached.

j. IF the flood is expected to increase to greater than D or equal to +20 feet MSL, THEN COMMENCE a plant shutdown.

2. IF flooding of the site has occurred, THEN PERFORM the following:

a. CONTACT the National Weather Service or Load D Dispatcher to determine the predicted flood crest time and level.

b. IF the intake canal water level increases to greater than or equal to +15 feet MSL, THEN PERFORM the following:

RECORD canal level at least once per two D hours

- COMPLY with the Technical Requirements D Manual 3.20.

c. CONFIRM proper operation of sump pumps. D

d. MONITOR the following panels in conjunction with local tours to determine if any areas are being flooded:

Panel UA-12 D Panel UA-28 D Panel XU-51 D

e. OPERATE permanent or portable sump pumps as D necessary to control water level inside the buildings.

IOAOP-13.0 Rev. 37 Page 16 of 40 I

3.0 OPERATOR ACTIONS NOTE: Temporary engine driven pumps should be placed in service only if both permanently installed Storm Drain Basin pumps are unavailable.

f. IF temporary Storm Drain Basin pumps are required, THEN PERFORM the following:

NOTIFY E&RC to sample the Storm Drain D Basin

- WHEN Storm Drain Basin sampling has been D completed, THEN OPERATE the temporary pumps as necessary to control water level.

NOTE: Releasing water directly to the discharge canal through the Storm Drain Basin overflow valves is prohibited by the NPDES permit except

- Where unavoidable to prevent loss of life or severe property damage (Preventing basin level from reaching 15'_6" satisfies this condition)

- Where excessive storm drainage or run-off would damage any facilities necessary for compliance with the effluent limitations of the NPDES permit.

g. IF flooding occurs at the Storm Drain Basin, THEN PERFORM the following:

MAINTAIN the Strom Drain Basin level in D accordance with GOP-54.

NOTIFY E&RC immediately D NOTIFY Environmental Compliance Unit within D 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months IOAOP-13.0 Rev. 37 Page 17 of 40 I

3.0 OPERATOR ACTIONS

3. IF flooding at the Caswell Beach Pumping Station is expected, THEN PERFORM the following within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of the anticipated arrival:

a. ENSURE the following:

- All equipment is stowed and secure D

- All controls are in remote D Lube Water Strainers are backwashed D

- All available lube water pumps are in D operation.

4. IF flooding Caswell Beach Pumping Station has occurred, THEN PERFORM the following:

a. ATTEMPT to restart any pumps that have been D lost.

NOTE: Attempts should be made to maintain at least one 00 Pump running on each ocean discharge pipe.

b. IF necessary, THEN STOP Circulating Water D Intake Pumps to maintain discharge canal level.

c. IF the Caswell Beach Substation is lost, THEN PERFORM the following:

- OPEN the 23 Kv feeder D PLACE the feeder under clearance. D

d. INITIATE a safe shutdown of the units. D IOAOP-13.0 Rev. 37 Page 18 of 40 I

3.0 OPERATOR ACTIONS

e. IF Caswell Beach Pumping Station is lost, THEN D MAINTAIN the condenser available as a heat sink as long as possible.

5. WHEN notified by the Raleigh Load Dispatcher or the National Weather Service the flood has crested and is NOT likely to reoccur, THEN PERFORM the following as areas become accessible:

a. INSPECT all equipment submerged by water. D

b. CLEAN all areas and flush piping, sumps, etc., as D required.

c. WHEN all sump pump levels are normal, THEN D REMOVE all portable pumps.

d. MEGGER all electrical equipment, power and D control cables submerged by water AND INITIATE appropriate maintenance activities.

e. REPLACE OR REPAIR damaged equipment. D

f. IF secured, THEN RESTART Caswell Beach D Pumping Station equipment as conditions permit.

g. IF Storm Drain Basin overflow valves were D opened to maintain level, THEN ENSURE valves are closed in accordance with GOP-54.

IOAOP-13.0 Rev. 37 Page 19 of 40 I

3.0 OPERATOR ACTIONS NOTE: A Control Operator key is required to unlock SYA and SYB Cabinet doors.

Security must be notified prior to unlocking these doors.

h. RETURN plant lighting to normal as follows:

- PLACE light switch at MCC-SYA, Compt. BZ3 0 in AUTO.

- PLACE light switch at MCC-SYB, Compt. CC3 0 in AUTO.

- PLACE light switch at U1 TB, 70' between Dist 0 Panel 1E-480V and S/E hot side entrance OFF.

- PLACE light switch at U2 TB, 70' between Dist 0 Panel 2E-480V and N/E hot side entrance in AUTO/OFF.

6. WHEN the flood has receded to less than +17 feet 6 inches MSL, THEN REFER to the following:

OGP-01 o Technical Requirements Manual 3.20. o IOAOP-13.0 Rev. 37 Page 20 of 40 I

4.0 GENERAL DISCUSSION This abnormal operating procedure (AOP) partially fulfills the requirements of Regulatory Guide 1.33, Quality Assurance Program Requirements (Operation)

(November 1972) and Regulatory Guide 1.155, Station Blackout. This AOP also address SOER 2002-01, Severe Weather recommendations 2 (emergency planning arrangements), 4a (securing equipment and placement of pumps), 4c (verification of safety related equipment operability), 5a (authority and responsibility of the operations shift staff), and 5b (decision making such as unit shutdown requirements.

Brunswick is geographically located in close proximity to the Atlantic coastal storm track and has an approximate grade elevation of 20 feet above mean sea level (MSL). Hurricanes and tropical storms are therefore, the most extreme weather phenomena that affect the site area. Potential subsequent flooding should be considered even though the plant structures were designed to compensate, via installed sump pumps, for a maximum site flooding depth of 22 feet above MSL during the maximum probable hurricane. Tornados should also be a concern since they are frequently observed to be associated with hurricanes and tropical storms.

Transformers, switchyard equipment, and transmission lines are very vulnerable to high speed wind conditions. Therefore, a loss of off-site power should be expected. Other equipment and structures in the outside areas are likely to be damaged and supplemental precautionary measures should be taken.

Brunswick Units have been designed to meet a Design Basis Earthquake (DBE) of 0.16g ground acceleration at the Reactor Building Foundation. This correlates to an earthquake with a magnitude of -6.0 on the Richter Scale. An earthquake with a magnitude of -7.0 on the Richter Scale occurred in Charleston, S.C., on August 31, 1886.

5.0 REFERENCES

5.1 Regulatory Guide 1.33, Quality Assurance Program Requirements (Operation) (November 1972), Appendix A, Item F.24 5.2 Regulatory Guide 1.155, Station Blackout 5.3 ANSI Standard N18.7-1976, Administrative Controls and Quality Assurance for the Operational Phase of Nuclear Power Plants, Section 5.3.9.2, Item (11 )

IOAOP-13.0 Rev. 37 Page 21 of 40 I

5.0 REFERENCES

5.4 NUMARC-87-00, Guidelines and Technical Bases for NUMARC Initiatives Addressing Station Blackout at Light Water Reactors 5.5 PEP-02.1, Initial Emergency Actions 5.6 OAI-68, Brunswick Nuclear Plant Response to Severe Weather Warnings 5.7 OAOP-36.1, Loss Off Any 4160 Buses Or 480V E-Buses 5.8 OAOP-36.2, Station Blackout 5.9 OMST-SEIS21 R, SMA 3 Seismic Monitoring System Chan Cal 5.10 2MST-SEIS22R, Peak Shock Recorder Seismic Monitoring System Chan Cal 5.11 00P-54, Storm Drain Collector Basin Operating Procedure 5.12 00P-39, Diesel Generator Operating Procedure 5.13 001-01.07, Notifications 5.14 001-01.08, Control Of Equipment And System Status 5.15 ELP-001, Emergency Phone List 5.16 OGP-05, Unit Shutdown 5.17 EER 90-0084, Consolidation of Previous EERs Re. SWS 5.18 Technical Manual FP-82351, Seismic Monitoring System 5.19 EER 93-0536, Evaluation of Unit 1 Core Shroud Indications and Operability Assessment of Units 1 and 2 5.20 PM 93-038, Unit 1 Core Shroud Modification IOAOP-13.0 Rev. 37 Page 22 of 40 I

5.0 REFERENCES

5.21 PM 94-007, Unit 2 Core Shroud Modification 5.22 OE&RC-2009, Radioactive Liquid Effluent Releases and Reports 5.23 8S42-P-1 01, BNP Station Blackout Coping Analysis Report 5.24 Technical Specifications 5.25 Technical Requirements Manual IR26 1 5.26 SOER 02-1, Severe Weather 5.27 OPS-NGGC-1305, Operability Determinations 6.0 ATTACHMENTS 1 Hurricane Tracking Data 2 Hurricane Tracking Map 3 Severe Weather Doors 4 Earthquake Acceleration Determination 5 Compensatory Actions for Control Room Heat Removal IOAOP-13.0 Rev. 37 Page 23 of 40 I

ATTACHMENT 1 Page 1 of 1 Hurricane Tracking Data Date Time Longitude Latitude Anticipated Hurricane Arrival at BSEP*

Required only after Hurricane Warning issued.

IOAOP-13.0 Rev. 37 Page 24 of 40 I

ATTACHMENT 2 Page 1 of 1 Hurricane Tracking Map

/lPCape Hatteras

~

~ ~ ---..IIt----4IIIIe.....

35. 0 ..... .-

80°

+ * * * * * * * *

Cape Canaveral t

Beach Nassau

Bahama Islands * * *

IOAOP-13.0 Rev. 37 Page 25 of 40 I

ATTACHMENT 3 Page 1 of 4 Severe Weather Doors NOTE: When completed, this attachment shall be retained as a QA record.

NOTE: All doors are required to be closed as indicated. Doors not required to be closed for the type of sever weather expected may be marked N/A.

Rx Bldg Description Elev. Unit Door Remarks Initial No.

Railroad Doors 20 ft. 1 209 Railroad Doors 20 ft. 1 210 Airlock-West Wall 20 ft. 1 203 Airlock-West Wall 20 ft. 1 204 Airlock-West WaH 50 ft. 1 301 Airlock-West Wall 50 ft. 1 302 Airlock-South Wall 50 ft. 1 303 Airlock-South Wall 50 ft. 1 304 Airlock 80 ft. 1 402 Airlock 80 ft. 1 403 Airlock 167 ft. 1 801 Confirm with Security Roof Hatch 179 ft. 1 901 Confirm with Security Railroad Doors 20 ft. 2 209 Railroad Doors 20 ft. 2 210 Airlock-West Walt 20 ft. 2 203 Airlock-West Walt 20 ft. 2 204 Airlock-West Wall 50 ft. 2 301 Airlock-West Wall 50 ft. 2 302 Airlock-North Wall 50 ft. 2 303 Airlock-North Wall 50 ft. 2 304 Airlock 80 ft. 2 402 Airlock 80 ft. 2 403 Airlock 167 ft. 2 801 Confirm with Security Roof Hatch 179 ft. 2 901 Confirm with Security IOAOP-13.0 Rev. 37 Page 26 of 40 I

ATTACHMENT 3 Page 2 of 4 Severe Weather Doors Control Bldg Description Elev. Unit Door Remarks Initial No.

North Cable Access Way 49 ft. - 218 Elevator Room 70 ft. - 301 HVAC Equipment Room South 70 ft. - 302A Hatch HVAC Equipment Room South 70 ft. - 3028 Entrance HVAC Equipment Room East Wall 70 ft. 1 304A HVAC Equipment Room East Wall 70 ft. - 3048 Cable Spread Area-West Wall 23 ft. 2 101A Tornado Only Cable Spread Area-West Wall 23 ft. 2 1018 Tornado Only Cable Spread Area-West Wall 23 ft. 1 104A Tornado Only Cable Spread Area-West Wall 23 ft. 1 1048 Tornado Only South Stair-West Wall 23 ft. - 102 Tornado Only North Stair-West Wall 23 ft. - 103 Tornado Only Cable Spread Area-East Wall 23 ft. 1 105 Tornado Only Cable Spread Area-East Wall 23 ft. 2 106 Tornado Only South Cable Access Way 23 ft. - 107 Tornado Only North Cable Access Way 23 ft. - 111 Tornado Only South Stair-West Wall 45 ft. - 201 Tornado Only North Stair-West Wall . 45 ft - 202 Tornado Only Control Room East Entrance 49 ft. - 203 South Cable Access Way 49 ft. - 205 IOAOP-13.0 Rev. 37 Page 27 of 40 I

ATTACHMENT 3 Page 3 of 4 Severe Weathe"f Doors AOG Bldg Description Elev. Unit Door Remarks Initial No.

Northeast Exterior 22 ft. - 101 Northeast Interior 22 ft. - 102 Tornado Only East Interior 21 ft. - 114 Flood Only West Interior 21 ft. - 112 Flood Only Northwest Exterior 22 ft. - 104 Northwest Interior 22 ft. - 103 Tornado Only Northwest 37 ft. - 201 Southwest Exterior 20 ft. - 106 Southwest Interior 22 ft. - 105 Tornado Only Southeast Exterior 20 ft. - 107 Southeast Interior 22 ft. - 108 Tornado Only CAD Room 49 ft. - 301 CAD Room East Floor Plate 49 ft. - 302 Tornado Only CAD Room West Floor Plate 49 ft. - 303 Tornado Only DG Bldg Description Elev. Unit Door No.

South Stairs 20 ft. - 101 South Interior 23 ft. - 103 Roll Up, Exterior 23 ft. - 126 Roll Up, Interior 23 ft. - 104 North Stairs 20 ft. - 114 North Interior 23 ft. - 113 4 Day Tank Room, South 23 ft. - 124 4 Day Tank Room, North 23 ft. - 119 IOAOP-13.0 Rev. 37 Page 28 of 40 I

ATTACHMENT 3 Page 4 of4 Severe Weather Doors Radwaste Bldg Description Elev. Unit Door Remarks Initial No.

Loading Dock 23 ft. - 106 South Pipe Tunnel -3 ft. - 013 Flood Only North Pipe Tunnel -3 ft. - 013 Flood Only Service Water Bldg Description Elev. Unit Door Remarks Initial No.

North Entrance 23 ft. - 2 South Entrance 23 ft. - 1 Date/Time Completed /_ _

Name (Print) Initials Performed by _

Unit sca Date Shift Superintendent Date IOAOP-13.0 Rev. 37 Page 29 of 40 I

ATTACHMENT 4 Page 1 of 6 Earthquake Acceleration Determination NOTE: When completed, this attachment shall be retained as a QA record.

NOTE: The following equipment is required for completion of this attachment:

- Key for the Seismic Event Monitor (located in WCC key locker)

- Two blank Kinemetrics tape cassettes (Kinemetric Part No. 700030; BNP Part No. 726-079-63)

- One stopwatch.

Initials

1. CONFIRM the Event Alarm light on the strong motion accelerograph panel is off.

NOTE: The following step is time sequenced. The times should be stopwatch accurate; therefore, the key switch should be turned with as close to a snap action as possible.

2. RECORD a calibration record on the magnetic tape cassettes as follows:

a. TURN the key switch (clockwise) to test for ten seconds.

b. TURN the key switch (clockwise) to CALIBRATE AND HOLD for two seconds (or less).

c. TURN the key switch (clockwise) to NATURAL FREQUENCY AND HOLD for two seconds (or less).

d. TURN the key switch back (counterclockwise) to CALIBRA TE AND HOLD for two seconds.

e. TURN the key switch back (counterclockwise) to TEST AND HOLD for ten seconds.

f. TURN the key switch (counterclockwise) to OFF AND WAIT 20 seconds for the time delay to reset IOAOP-13.0 Rev. 37 Page 30 of 40 I

ATTACHMENT 4 Page 2 of 6 Earthquake Acceleration Determination Initials

g. TURN the key switch to OPERA TE AND REMOVE the key.

h. CONFIRM the AC ON indicator lamp is on.

i. CONFIRM the Event Alarm light is off.

j. CONFIRM the Event Indicator is black.

3. REMOVE one of the magnetic tape cassettes from the recorder AND REPLACE with a new blank cassette.

4. ENSURE the blank tape is wound up past the light colored leader portion to ensure all of any ensuing events are completely recorded.

5. RECORD accelerograph location, time, and date of removal on the removed cassette.

6. LOAD the cassette into the magnetic tape playback unit, label side out.

7. ENSURE the Power Select switch in AC RUN. (BATTERY RUN may be selected if AC power is not available.)

8. TURN the cassette tape Transport On/Off switch to ON AND ENSURE the tape runs smoothly.

9. REWIND the tape by pulling down and to the left on the slide handle.

10. TURN the cassette tape Transport On/Off switch to OFF.

11. TURN the Stylus Drive On/Off switch to ON.

IOAOP-13.0 Rev. 37 Page 31 of 40 I

ATTACHMENT 4 Page 3 of 6 Earthquake Acceleration Determination Initials

12. PLACE AND HOLD the Stylus Drive RUNICAUZERO switch to ZERO and use the position control to center the stylus. This is best done with the Chart Drive switch in 25 mm/sec to overcome stylus friction.

13. RELEASE the Stylus Drive RUNICA*UZERO switch.

14. ENSURE the Gain Factor switch to 10.

15. TURN the Channel Select switch to Channel 1 to playback the signal from the longitudinal axis of the accelerometer.

16. TURN the Chart Drive switch to the desired speed.

17. TURN the cassette tape Transport On/Off switch to ON.

18. WHEN the recording is over (timing marker on right hand side of chart paper stops marking), THEN REWIND the tape by pulling the slide handle down to the left.

19. TURN the cassette tape Transport On/Off switch to OFF.

20. TURN the Channel Select switch to Channel 2 to playback the signal from the traverse axis of the accelerometer.

21. TURN the cassette tape Transport On/Off switch to ON.

22. WHEN the record is over, THEN REWIND the tape by pulling the slide handle down and to the left.

23. TURN the cassette tape Transport On/Off switch to OFF.

24. TURN the Channel Select switch to Channel 3 to playback the signal from the vertical axis of the accelerometer.

25. TURN the cassette tape Transport On/Off switch to ON.

IOAOP-13.0 Rev. 37 Page 32 of 40 I

ATTACHMENT 4 Page 4 of 6 Earthquake Acceleration Determination Initials

26. WHEN the record is over, THEN REWIND the tape by pulling the slide handle down and to the left.

27. TURN the cassette tape Transport On/Off switch to OFF.

28. TURN the Chart Drive switch to OFF.

NOTE: The centerline on the chart is O.OOg. With a gain factor of 10, each dark demarcation on the chart paper is 0.02g. (Full scale deflection is 0.1 Og.)

29. REVIEW the charts recorded from the cassette to determine the earthquake acceleration.

30. IF acceleration exceeded 0.08g, THEN PERFORM the appropriate supplemental actions in Section 3.0 of this procedure.

31. IF acceleration exceeded 0.10g (off scale), THEN PERFORM the following:

a. TURN the Gain Factor switch to 4.

b. REPEAT Steps 15 through 28 of this attachment.

NOTE: The centerline on the chart is O.OOg. With a gain factor of 4, each dark demarcation on the chart paper is 0.05g. (Full scale deflection is 0.25g.)

c. REVIEW the charts to determine the actual earthquake acceleration for evaluation and classification of the event.

IOAOP-13.0 Rev. 37 Page 33 of 40 I

ATTACHMENT 4 Page 5 of 6 Earthquake Acceleration Determination Initials

32. IF acceleration did NOT exceeded 0.08g, THEN PERFORM the following:

a. REMOVE the cassette from the magnetic tape playback unit.

b. REPEAT Steps 3 through 6,8 through 10, and 14 through 31 of this attachment for the other tape.

c. PERFORM the appropriate supplemental actions in Section 3.0 of this procedure.

33. WHEN operation of the magnetic tape playback unit is no longer required, THEN PERFORM the following:

a. ENSURE the cassettes are removed from the magnetic tape playback unit AND FORWARD to Engineering for disposition.

b. TURN the Stylus Drive On/Off switch to OFF.

c. PLACE the Power Select switch to OFF.

IOAOP-13.0 Rev. 37 Page 34 of 40 I

ATTACHMENT 4 Page 6 of 6 Earthquake Acceleration Determination Comments:

DatelTime Completed ,_ _

Name (Print) Initials Performed by _

Reviewed by _

Unit sca Date Shift Superintendent Date IOAOP-13.0 Rev. 37 Page 35 of 40 I

ATTACHMENT 5 Page 1 of 4 Compensatory Actions For Control Room Heat Removal 1~ ISOLATE the chlorine tank car as a minimum AND REMOVE the D car, if possible.

2. CONTACT Security AND ENSURE security requirements are in D place for opening Security Doors.

3. CONTACT E&RC for any additional monitoring requirements are D implemented.

4. REVIEW Technical Specification 3.7.3, Control Room Emergency D Ventilation (CREV) System, for any additional requirements.

5. OPEN AND SECURE the following Elevation 49 ft. Control Room doors:

WCC North entrance door D 2-CTB-DR-EL049-203 D 2-CTB-DR-EL049-204. D

6. IF necessary to increase flow, OPEN AND SECURE the following Elevation 49 ft. Control Room doors:

2-CTB-DR-EL049-201 D 1-CTB-DR-EL049-202 D 2-CTB-DR-EL049-20B D 1-CTB-DR-EL049-215 D IOAOP-13.0 Rev. 37 Page 36 of 40 I

ATTACHMENT 5 Page 2 of 4 Compensatory Actions For Control Room Heat Removal

7. OPEN AND SECURE the following Elevation 70 ft. Control Building Mechanical Equipment Room doors:

2-CTB-DR-EL070-302A D 2-CTB-DR-EL070-302B D 2-CTB-DR-ELO 70-303 D 2-CTB-DR-EL070-304A D 2-CTB-DR-EL070-308B. D

8. REMOVE insulation covers from the access doors located directly above the following dampers:

1-VA-ISOL-DMP-CB D 2- VA-ISOL-DMP-CB. D

9. OPEN the following damper access doors:

1-VA-ISOL-DMP-CB D 2-VA-ISOL-DMP-CB. D

10. CLOSE the following dampers by turning the crank mechanism located on the side of each damper:

1-VA-ISOL-DMP-CB D 2- VA-ISOL-DMP-CB. D IOAOP-13.0 Rev. 37 Page 37 of 40 I

ATTACHMENT 5 Page 3 of 4 Compensatory Actions For Control Room Heat Removal RESTORATION NOTE: When completed, this attachment shall be retained as a QA record.

Initials

1. OPEN the following dampers by turning the crank mechanism located on the side of each damper:

1-VA-ISOL-DMP-CB I Ind.Ver.

2-VA-ISOL-DMP-CB. I Ind.Ver.

2. CLOSE the following damper access doors:

1-VA-ISOL-DMP-CB I Ind.Ver.

2-VA-ISOL-DMP-CB, I Ind.Ver.

3. INSTALL insulation covers from the access doors located directly above the following dampers:

a, 1-VA-ISOL-DMP-CB I Ind.Ver.

b, 2-VA-ISOL-DMP-CB, I Ind.Ver.

4. ENSURE the following Elevation 49 ft. Control Room doors are closed:

2-CTB-DR-EL049-201 I Ind.Ver.

1-CTB-DR-EL049-202 I Ind.Ver.

2-CTB-DR-EL049-208 I Ind.Ver.

1-CTB-DR-EL049-215 I Ind.Ver.

2-CTB-DR-EL049-203 I Ind.Ver.

2-CTB-DR-EL049-204. I Ind.Ver.

IOAOP-13.0 Rev. 37 Page 38 of 40 I

ATTACHMENT 5 Page 4 of 4 Compensatory Actions For Control Room Heat Removal RESTORATION Initials 5~ ENSURE the following Elevation 70 ft. Control Building Mechanical Equipment Room doors are closed:

2-CTB-DR-EL070-302A ,

2-CTB-DR-EL070-302B ,

Ind.Ver.

2-CTB-DR-EL070-303 ,

Ind.Ver.

2-CTB-DR-EL070-304A ,

Ind.Ver.

2-CTB-DR-EL070-308B. ,

Ind.Ver.

Comments:

DatelTime Completed ,_ _

Name (Print) Initials Performed by _

Reviewed by _

Unit sca Date Shift Superintendent Date IOAOP-13.0 Rev. 37 Page 39 of 40 I

REVISION

SUMMARY

Revision 37: In response to AR 208970-05, revised the procedure to require notification of maintenance to unload and secure the 117' RB cranes when high winds are expected. In response to PRR 197585, deleted the requirement to perform an equalizing charge of station batteries prior to storm arrival. In response to PRR 215571 ,

moved the step for confirming an earthquake has occurred before the steps that required actions to be taken in response to an earthquake and clarified that the actions apply to a confirmed earthquake. Corrected typo in door number for the southwest interior door on Attachment 3.

Revision 36 converted the note concerning outside lighting into steps, clarified the steps regarding secondary containment LCOs following an earthquake, removed reference to 001-01.07 for storm drainage basin overflow valve operation, and adds a step to notify maintenance for removing reactor building chillers prior to a hurricane.

Revision 35 adds detail to the step for seismic monitoring instrumentation calibration following an event to ensure the frequency specified in the TRM and Bases are met.

This revision also changes font of the check boxes.

Revision 34 changes the. section on monitoring the intake canal level to make it consistent with the circ water op and the CO daily surveillance report. This revision also updates the seismic monitoring system reference.

Revision 33 incorporates EC 55955 by adding a clarification to the note for opening the basin overflow valves.

Revision 32 adds a step to shutdown the Storage Tank Lube Oil Conditioner prior to a hurricane to preclude loss of oil if the conditioner water seal is lost. AR 105098 Revision 31 - Format changes to meet the requirements of OAP-005 and Microsoft Word XP. Steps re-ordered to provide an easier transition to events that occur rapidly.

Attachments modified to remove actions steps from notes and footers added for QA records. These changes do NOT implement an intent change. Additional administrative changes classified as "editorial": are bolding action verbs, italicizing components, change of cover page logo, removal of the "bar code" from the cover page, and adding place keeping aids.

Revision 30 adds a note to clarify portable sump pumps are installed per OAI-68 and the associated step was changed to ensure installation portable pumps rather than install. The step to seal manways was deleted since permanent seals have been installed. This revision also updates several references IAOP-13.0 Rev. 37 Page 40 of 40 I

7.0 SHUTDOWN C Continuous Use Diesel Generator No.

7.1 Diesel Generator Shutdown 7.1.1 Initial Conditions

1. All applicable prerequisites as listed in Section 4.0 are D met.

2. The diesel generator has automatically started AND:

a. It is no longer required to supply electrical power, D OR

b. The automatic start signal is NOT a valid signal. D OR

3. The diesel generator was manually started AND is no D longer required to supply electrical power.

4. The diesel generator output breaker is open in D accordance with OOP-50.1.

7.1.2 Procedural Steps

1. IF the diesel generator is in the AUTO start mode AND D the auto start signal is clear OR the diesel generator was started locally AND is to be shut down from the Control Room, THEN DEPRESS CONTROL ROOM MANUAL push button located on Panel XU-2.

2. IF it is desired to shut down the diesel generator from the D local Engine Control Panel, THEN DEPRESS LOCAL MANUAL push button located on Panel XU-2.

3. OBSERVE governor oil level is between high and low D marks on governor oil sight glass.

IOOP-39 Rev. 115 Page 27 of 2291

7.1.2 Procedural Steps

4. RUN diesel engine unloaded (idle) until all of the diesel D generator cylinder exhaust temperatures are less than 500°F.

5. RUN diesel engine unloaded (idle) for an additional D 5 minutes for engine cooldown.

6. PLACE the AUX LUBE OIL PUMP control switch in D HAND to prevent pump cycling during engine cootdown.

7. PLACE MANUAL STOP START switch located on Panel D XU-2 OR ENGINE LOCAL START STOP switch located on Engine Control Panel in STOP.

8. RECORD the time the diesel generator engine was D stopped.

Time

9. CONFIRM locally the following automatic operations occur:

a. JACKET WA TER COOLER SERVICE WA TER D INLET VALVES, 1 (2)-SW-V679 (V680, V681, V682) , close or are closed.

b. FUEL OIL BOOSTER PUMP stops. D

c. JACKET WA TER PUMP starts. D

10. CONFIRM the field shorting device (17-Device), located D in the rear lower left section of the Excitation Control Cubicle, is in the RESET position by observing the contacts labeled NO AUX (Normally open auxiliary contacts) are closed and the NC AUX (Normally closed auxiliary contacts) are open.

11. RESET the flags on the diesel generator output breaker. D IOOP-39 Rev. 115 Page 28 of 2291

7.1.2 Procedural Steps

12. ENSURE the following valves are in the indicated position:

a. LUBE OIL AUTOMA TIC - THERMOSTA TIC D TEMPERATURE CONTROL VALVE, LO-TCV-1463 (2054, 2077, 2100)

b. JACKET WA TER - THERMOSTA TIC D COOLER OUTLET AUTOMATIC TEMPERA TURE CONTROL VAL VE, MUD-TCV-2129 (2155, 2183, 2210)

c. TEMPERA TURE - Closed D CONTROL VAL VE BYPASS VALVE, MUD-V160 (V196, V232, V268)

IR291 d. DG#1 JACKET WA TER **Throttled Open D COOLER SERVICE and Locked WATER OUTLET VAL VE, 2-SW- V206 I R29 1

e. DG#2 JACKET WA TER **Throttled Open D COOLER SERVICE and Locked WATER OUTLET VAL VE, 2-SW-V207 IR291 f. DG#3 JACKET WA TER **Throttled Open D COOLER SERVICE and Locked WATER OUTLET VAL VE, 2-SW- V208 IR291 ** 2'y., turns open from full closed position after handwheel engages gears.

IOOP-39 Rev. 115 Page 29 of 2291

7.1.2 Procedural Steps IR29 1 g. OG#4 JA CKET WA TER COOLER SERVICE

- Throttled Open and Locked 0

WATER OUTLET VAL VE, 2-SW- V209

13. PERFORM Steps 5.1.2.7.b through 5.1.2.16, AND 0 RETURN TO Step 7.1.2.14.

14. IF any of the following conditions exist, THEN FILL the Diesel 4-Day Tank in accordance with Section 8.6,

a. The associated 4-Day Tank Annunciator FUEL 0 STORAGE TANK LEVEL LOW, UA-19 (20, 21,

22) 3-2, is in alarm.

b. The Engine-Mounted Day Tank is less than 9/16 0 full.

c. The Engine-Mounted Day Tank was filled 0 manually or automatically during this procedure.

15. Approximately 20 minutes after the diesel generator 0 engine has been shutdown (time recorded in Step 7.1.2.8), PLACE the AUX LUBE OIL PUMP control switch in AUTO.

I R2S 1 16. IF the diesel generator operated more than one hour OR 0 IF fuel oil was added to the 4-Day fuel Oil Storage Tank from the Main (7-day) Fuel Oil Storage Tank, THEN NOTIFY E&RC to sample the Saddle Tank AND Four-day Tank fuel oil in accordance with E&RC-1010.

17. MAKE an entry in the Control Operator's log that the 0 diesel generator has been placed in the standby mode.

IR291 ** 2% turns open from full closed position after handwheel engages gears.

IOOP-39 Rev. 115 Page 30 of 2291

7.1.2 Procedural Steps

18. WHEN approximately 20 minutes have elapsed, THEN CONFIRM the following automatic operations:

a. JACKET WA TER PUMP stops. D

b. AUXILIARY LUBE OIL PUMP stops. D

c. CRANKCASE VACUUM pump stops. D

d. JACKET WA TER HEATER PUMP starts. D

e. JACKET WA TER HEATER starts. D

f. LUBE OIL FIL TER AND PRELUBE FLOW D CONTROL VAL VE is in the 5/8 OPEN position (solenoid valve energized) which directs oil flow to the engine.

g. LUBE OIL FIL TER HEA TER starts. D

19. PERFORM Attachment 4. D IOOP-39 Rev. 115 Page 31 of 2291

ATTACHMENT 4 C Continuous Page 1 of 2 Use Section 7.1, Diesel Generator Shutdown Documentation Diesel Generator No. --------

Number Description Positionl Checked Verified Indication Step 7.1 .2.11 Diesel Generator Output RESET Breaker Flags LO-TCV-1463 Lube Oil Automatic Temperature THERMO-(2054,2077,2100) Control Valve STATIC MUD-TCV-2129 Jacket Water Cooler Outlet THERMO-(2155,2183, 2210) Automatic Temperature Control STATIC Valve MUD-V160 (V196, Temperature Control Valve CLOSED V232, V268) Bypass Valve 2-SW-V206 DG#1 Jacket Water Cooler THROTTLED Service Water Outlet Valve OPEN AND LOCKED *

(JR29 I 2-SW-V207 DG#2 Jacket Water Cooler THROTTLED Service Water Outlet Valve OPEN AND LOCKED

I R291 2-SW-V208 DG#3 Jacket Water Cooler THROTTLED Service Water Outret Valve OPEN AND LOCKED

2-SW-V209 DG#4 Jacket Water Cooler THROTTLED Service Water Outlet Valve OPEN AND LOCKED

Step 7.1.2.13 Steps 5.1.2.7.b through 5.1.2.16 COMPLETED completed.

Step 7.1.2.15 Auxiliary Lube Oil Pump AUTO

2% tums open from full closed position after handwheel engages gears.

- Perform Concurrent Verification instead of Independent Verification.

IOOP-39 Rev. 115 Page 202 of 2291

ATTACHMENT 4 Page,2 of 2 Section 7.1, Diesel Generator Shutdown Documentation Date/Time Completed _

Performed By (Print) Initials Reviewed By: _

Unit sea IOOP-39 Rev. 115 Page 203 of 2291

ML072960488

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