ML13161A265

Redacted, Request for Additional Information, 3/12/2012 NRC Order EA 12-049 Related to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events (TAC Nos. MF0829-MF0831)

ML13161A265
Person / Time
Site:	Palo Verde
Issue date:	06/20/2013
From:	Jennivine Rankin Plant Licensing Branch IV
To:	Edington R Arizona Public Service Co
Rankin J
References
TAC MF0829, TAC MF0830, TAC MF0831
Download: ML13161A265 (19)

Text

OFFICIAL USE ONLY PROPRIETARY INFORMATION UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON. D.C. 20555-4)001 June 20, 2013 Mr. Randall K. Edington Executive Vice President Nuclearl Chief Nuclear Officer Mail Station 7602 Arizona Public Service Company P.O. Box 52034 Phoenix, AZ 85072*2034

SUBJECT:

PALO VERDE NUCLEAR GENERATING STATION, UNITS 1. 2. AND 3 REQUEST FOR ADDITIONAL INFORMATION REGARDING OVERALL INTEGRATED PLAN IN RESPONSE TO COMMISSION ORDER EA-12-049 MODIFYING LICENSE WITH REGARD TO REQUIREMENTS FOR MITIGATION STRATEGIES FOR BEYOND-DESIGN-BASIS EXTERNAL EVENTS (TAC NOS. MF0829. MF0830. AND MF0831)

Dear Mr. Edington:

On March 12,2012, the U.S. Nuclear Regulatory Commission (NRC) issued Order EA-12-049, "Order Modifying License with Regard to Requirements for Mitigation Strategies for Beyond Design-Basis External Events" (Agencywide Documents Access and Management System (ADAMS) AcceSSion No. ML12054A736). By letter dated February 28. 2013, Arizona Public Service Company (APS, the licensee) submitted its Overall Integrated Plan in response to the Commission Order dated March 12,2012, for Palo Verde Nuclear Generating Station, Units 1, 2, and 3 (ADAMS Accession No. ML13136A022).

The NRC staff reviewed the information provided by the licensee and determined that the additional information identified in Enclosure 1 is needed in order for the NRC staff to complete its review. The draft copy of this request for additional information (RAI) was provided to Mr. Robert Roehler of the APS staff via e-mail on May 17. 2013. and two publicly noticed RAI clarification telephone caUs were held on May 30 and June 6,2013 between the NRC and APS staffs. These public telephone calls were noticed on May 17 and May 23, 2013 (ADAMS Accession Nos. ML13135A370 and ML13143A089. respectively). On June 6,2013. Mr. Terry Curtiss of your staff agreed to respond by June 24,2013.

NOTICE: Enclosure 1 to this letter contains Proprietary Information. Upon separation from . this letter is DECONTROLLED.

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-2 is a proprietary version of the RAls and Enclosure 2 is a non-proprietary. redacted version of the RAls.

If circumstances result in the need to revise the requested response date, please contact me at (301) 415-1530 or via e-mail at jennivine.rankin@nrc.gov.

Sincerely, Jennivine K. Rankin, Project Manager Plant Ucensing Branch IV Division of Operating Reactor Ucensing OffICe of Nuclear Reactor Regulation Docket Nos. STN 50-528, STN 50-529.

and STN 50-530

Enclosures:

1. Request for Additional Information (proprietary)

2. Request for Additional Information (non-proprietary) cc w/Enclosure 2: Distribution via Ustserv OFFICIAL USE ONLY PROPRIETARY INFORMATION

ENCLOSURE 2 (NON*PROPRIETARY)

REqUEST FOR ADDITIONAL INFORMATION OVERALL INTEGRATED PLAN IN RESPONSE TO COMMISSION ORDER EA-12-49 MODIFYING LICENSES WITH REGARD TO REQUIREMENTS FOR MITiGATION STRATEGIES FOR BEYOND-DESiGN-BASIS EXTERNAL EVENTS ARIZONA PUBLIC SERVICE COMPANY PALO VERDE NUCLEAR GENERATING STATION. UNITS 1. 2. AND 3 DOCKET NOS. 50-528. 50-529. AND 50-530 Redacted information is identified by blank space enclosed within double brackets.

OFFICIAL USE ONLY PROPRI~TARY INFORMATION REQUEST FOR ADDITIONAL INFORMATION OVERALL INTEGRATED PLAN IN RESPONSE TO COMMISSION ORDER EA-12-049 MODIFYING LICENSES WITH REGARD TO REQUIREMENTS FOR MITIGATION STRATEGIES FOR BEYOND-DESIGN-BASIS EXTERNAL EVENTS ARIZONA PUBLIC SERVICE COMPANY PALO VERDE NUCLEAR GENERATING STATION, UNITS 1.2, AND 3 DOCKET NOS. 50-528. 50-529, AND 50-530 On March 12,2012, the U.S. Nuclear Regulatory Commission (NRC) issued Order EA-12-049, "Order Modifying Ucense with Regard to Requirements for Mitigation Strategies for Beyond Design-Basis External Events" (Agencywide Documents Access and Management System (ADAMS) Accession No. ML12054A736). By letter dated February 28, 2013, Arizona Public Service Company (APS, the licensee) submitted its Overall Integrated Plan in response to Commission Order EA-12-049 dated March 12, 2012, for Palo Verde Nuclear Generating Station, Units 1. 2, and 3 (ADAMS Accession No. ML13136A022).

The NRC staff reviewed the submitted information and determined that the following additional information is required to complete the review.

049-RAI-Palo Verde-1 Please identify any license amendment requests that are necessary for modifications proposed in the integrated plan.

049-RAI-Palo Verde-2 Attachment 1A of the APS integrated plan dated February 28,2013, lists the operator actions and associated completion times to mitigate the consequences of an extended loss of AC [alternating current] power (ELAP).

Please discuss how the plant-specific guidance and strategies and the aSSociated administrative controls and training program will be developed and implemented to assure that the required operator actions are consistent with that assumed in the CENTS

[Combustion Engineering Nuclear Transient Simulator] analysis and can be reasonably achievable within the required completion times.

049-RAI-Palo Verde-3 Pages 18 and 19 of the APS integrated plan dated February 28,2013, state, in part, that Table Item 9 - Open Control Room Doors: Block open doors to provide ventilation to maintain control room temperature. Reference 12, OFFICIAL US~ ONLY PROPRIETARY INFORM.\TION

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-2 Section IX.3 provides a list of rooms reviewed (including the control room) and predicted temperatures. Because load shed is to be completed within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. heat loads in the control room are minimal (only essential identified instrumentation is powered). It is predicted that long term control room temperature would approach outside air temperature, per deSign. The PVNGS FSG [FLEX support guideline] (Reference 13) will also include steps to open control room doors.

Section 9.2 of Nuclear Energy Institute (NEI) 12-06. Revision 0, "Diverse and Flexible Coping Strategies (FLEX) Implementation Guide" August 2012 (ADAMS Accession No. ML12242A378). states, in part, that Virtually every state in the lower 48 contiguous United States has experienced temperatures in excess of 110°F [degrees Fahrenheit}.

Many states have experienced temperatures in excess of 120°F.

Pages 51 and 52 of the APS integrated plan dated February 28,2013. state that ventilation is not required in Phase 1, and it will not be recovered until Phase 2 (approximately 28 hours3.240741e-4 days <br />0.00778 hours <br />4.62963e-5 weeks <br />1.0654e-5 months <br /> after the ELAP).

a. Has a plant-specific. thermal hydrauliC calculation been performed to determine what the maximum control room temperature would be based on the NE112-06 conditions? If so, please provide a summary of the calculation and its results concluding that control room habitability limits will be maintained in all phases of the ELAP event. If not. please provide the basis and justification for concluding that main control room ventilation will not be required to maintain habitability limits until Phase 2 (28-hour mark) of the ELAP event.

b. NEI12-06 relies on the guidance from NUMARC 87-00, Revision 1, -Guidelines and Technical Basis for NUMARC Initiatives AddreSSing station Blackout at Light Water Reactors," August 1991 (ADAMS Legacy Accession No. 9209020287). for a 11 OqF limit for efficient human performance. NUMARC 87-00 provides the technical basis for this habitability standard as MIL-STD-1472C. which concludes that 110°F is tolerable for light work for a 4-hour period while dressed in conventional clothing with a relative humidity of -30 percent. In light of this technical basis. please provide justification for the long-tenn habitability of the main control room and/or please indicate what additional relief efforts for the main control room staff will be provided (e.g., Short-stay time cycles, use of ice vests/packs. supplies of bottled water, etc.).

c. Please clarify the number of plant personnel assumed to be present in the control room for this analysis relative to the number of personnel that may be present during an ELAP event.

d. Please discuss the postulated outside air temperature.

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-3 049-RAI-Palo Verde-4 Page 24 of APS integrated plan dated February 2B, 2013, states that one train of atmospheric dump valve (ADV) solenoids will be de-energized during load shed. Please explain the necessity or prudence of this action and clarify the time required to restore power to the de-energized train if it becomes necessary.

049-RAI-Palo Verde-5 Page 15 of the APS integrated plan dated February 2B. 2013, states, Instrumentation on FLEX equipment will be used to confirm adequate performance of equipment functions.

Please describe the instrumentation that will be used to monitor portablelFLEX electrical power equipment including their associated measurement tolerances/accuracy to ensure that: (1) the electrical equipment remains protected (from an electrical power standpoint; e.g., power fluctuations) and (2) the operator is provided with accurate information to maintain core cooling, containment, and spent fuel COOling.

049-RAI-Palo Verde-6 Page 1B of the APS integrated plan dated February 2B, 2013, states the following:

Table Item 7 - Complete DC [direct current] Load Shed: DC load shed must be completed within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in order to achieve a battery coping time of 47 hours5.439815e-4 days <br />0.0131 hours <br />7.771164e-5 weeks <br />1.78835e-5 months <br /> on battery bank B (Reference 16, Section B.6). For Phase 1, PVNGS can cope on the installed DC batteries for up to 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> with no load shedding. If load shedding, as described in PVNGS Study 13-NS-A108 (Reference 12). is completed, the battery coping period is extended to 47 hours5.439815e-4 days <br />0.0131 hours <br />7.771164e-5 weeks <br />1.78835e-5 months <br />. This load shed strategy will preserve station batteries and provide additional time prior to needing to re-energize battery chargers.

a. Please proVide the DC load profile for the mitigating strategies to maintain core cooling.

b. Provide a detailed discussion on the loads that will be shed from the DC bus, the equipment location (or location where the required action needs to be taken), and the required operator actions needed to be performed and the time to complete each action. In your response, explain which functions are lost as a result of shedding each load and discuss any impact on defense in depth and redundancy.

i. Are there any plant components that will change state if vital alternating current (AC) or DC is lost, de-energized, during this evolution of DC load shed? When the operators manipulate DC breakers to load shed. will plant components actuate, de-energize pumps, etc.? The NRC staff is OFFICIAL USE ONLY PROPRlfITARY INFORM,:rION

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-4 particularly interested that a safety hazard is not created, such as de energizing the DC powered seal oil pump for the main generator, which would allow the hydrogen to escape to the atmosphere. This may cause an explosion or fire, and may be compounded by high heat from the main turbine bearings if not cooled, ii. Which breakers will operators open as part of the load shed evolutions?

iii. How will the DC breakers be physically identified to assist operators in manipulating the correct breakers?

c. The integrated plan states that the batteries can last up to 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> with no load shedding and up to 47 hours5.439815e-4 days <br />0.0131 hours <br />7.771164e-5 weeks <br />1.78835e-5 months <br /> with load shedding. The Institute of Electrical and Electronics Engineers (IEEE) Standard 535-1986, MIEEE Standard for Qualification of Class 1E Lead Storage Batteries for Nuclear Power Generating Stations,* as endorsed by NRC Regulatory Guide (RG) 1.158, "Qualification of Safety-Related lead Storage Batteries for Nuclear Power Plants," February 1989 (ADAMS Accession No. MlOO3740047), provides guidance for qualifying nuclear-grade batteries and describes a method acceptable to the NRC staff for complying with Commission regulatiOns with regard to qualification of safety related lead storage batteries for nuclear power plants. Please provide documentation that shows that your battery cells fully comply with the qualification principles in clause 5 and meet the requirements in clause 8.2 of IEEE Standard 535, for the duration you are crediting the station batteries in your mitigating strategies integrated plan (See ADAMS Accession No. Ml13094A3971 for additional information).

049-RAI-Palo Verde-7 Page 51 of the APS Integrated plan dated February 28, 2013, states. in part. that DC bus voltage is required to be monitored in order to ensure that the DC bus voltage remains above the minimum voltage.

Please provide the minimum voltage that must be maintained and the basis for the minimum voltage on the DC bus.

1 Fletcher, Robert, The Institute of Electrical and Electronics Engineers. Inc., letter to Tania Martinez Navedo, U.S. Nuclear Regulatory Commission, "Your email request for interpretation of IEEE Std 535-2006 dated November 17, 200S: dated April 15, 2013.

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-5 049-RAI-Palo Verde-8 NRC Regulatory Guide (RG) 1.128, Revision 2, "Installation Design and Installation of Vented Lead-Acid Storage Batteries for Nuclear Power Plants," February 2007 (ADAMS Accession No. ML070080013), states, in part, that Conformance with the IEEE Std. 484-2002 requirements (indicated by the verb *shall") for installation design and installation of vented lead-acid storage batteries for nuclear power plants provides an adequate basis for complying with the design, fabrication, erection, and testing requirements set forth in GDCs 1, 17. and 18 of Appendix A to 10 CFR Part 50, as well as Criterion III of Appendix B to 10 CFR Part 50, subject to the following stipulation ...*

6. In Subsection 5.4, *Ventilation," revise the second sentence to be consistent with Regulatory Guide 1.189, as follows:

"The ventilation system shall limit hydrogen accumulation to one percent of the total volume of the battery area.~

Please provide a discussion on how hydrogen concentration in the battery rooms will be maintained below the limits established by national standards and codes (Le., less than 1 percent according to the National Fire Code and RG 1.128, Revision 2, which endorses IEEE Standard 484, MIEEE Recommended Practice for Installation Design and Installation of Vented Lead-Acid Batteries for Stationary Applications,- with exceptions) when the batteries are being recharged during Phase 2 and 3.

049-RAI-Palo Verde-9 Page 21 of the APS integrated plan dated February 28,2013, states, in part, that PVNGS will use the standard EPRI [Electric Power Research Institute]

industry preventative maintenance template for establishing the maintenance and testing actions for FLEX components. The administrative program will include maintenance guidance, testing procedures and frequencies established based on type of equipment and considerations made within the EPRI templates.

Please provide details of the maintenance and testing plan for efectrical equipment that is credited for events that require mitigating strategies. The NRC staff is trying to understand how Regulatory Guidance documents, IEEE Standards, manufacturer recommendations, etc., will be utilized to establish the maintenance and testing programs for the portable/FLEX electrical equipment, especially for batteries and diesel generators.

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-6 049-RAI-Palo Verde-10 Page 59 of the APS integrated plan dated February 28,2013, states, in part, that The MV [medium voltage] FLEX generator will be connected to the Class 1E 4.1SkV [kilovolt1 switchgear via an installed FLEX junction box mounted outside on either the west or east wall of the diesel building as shown in Fjgure 3-39 and Figure 3-41.

Please describe how the MV FLEX generator and the Class 1E diesel generators are isolated to prevent simultaneously supplying power to the same Class 1E bus in order to conform to NEI12-06, Section 3.2.2, guideline (13), which specifieS that appropriate electrical isolations and interactions should be addressed in procedures and guidance.

049-RAI-Palo Verde-11 Attachment 18 lists as item 3, a deviation from the WCAP-17S01-P. "Reactor Coolant System Response to the Extended Loss of AC Power Event for Westinghouse, Combustion Engineering and Babcock &Wilcox NSSS Designs (Proprietary): January 2013, value for time initiating cool down from 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> for the site-specific analysis. The APS integrated plan shows the operators are performing numerous tasks during this first hour. Station blackout (S80) procedures require the operator to start the station blackout generator (SBOG) within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, plus the licensee credits performing a load shed on the DC bus within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> and opening doors within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. In addition, the licensee identified two actions with time constraints have been identified. observing the condition of the condensate storage tank (CSn and selecting valves that must be closed. In such a critical time operators will be stationed at critical components such as the steam driven auxiliary feedwater (AFW) pump. The licensee states that they will perform simulator validations to confirm recognizing ELAP entry conditions. Provide a description of tasks to be performed and the personnel available to perform these tasks to allow the staff to evaluate the basis for concluding that these tasks can be reasonably accomplished in the time allotted.

049-RAI-Palo Verde-12 (Means to move equipment)

In its integrated plan dated February 28.2013, APS has identified that there is a time constraint of 34 hours3.935185e-4 days <br />0.00944 hours <br />5.621693e-5 weeks <br />1.2937e-5 months <br /> to install portable 500 kiloWatt (kW) 480 Volt M generators in order to recharge the batteries. APS has not identified a means to move the generators along with the concomitant method for reasonable protection of that means from the identified hazards applicable to PVNGS as would be required to conform to the guidance of NEI12..()6, Section 5.3.2, consideration 5, and Section 9.3.2. APS has listed transportation equipment as equipment to be delivered in the final phase. but has identified an open item for the actual sequence and timing of delivery of the equipment.

Please discuss the basis for concluding that the time constraint of 34 hours3.935185e-4 days <br />0.00944 hours <br />5.621693e-5 weeks <br />1.2937e-5 months <br /> can reasonably be met for the installation of the portable generators as specified in NEI 12-06. Section 3.2.1.7, Principle 6, taking into consideration the specifications of NEI 12-0S, Section 5.3.2, consideration 5, and Section 9.3.2.

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-7 049-RAI-Palo Verde-13 (Seismic procedural interface considerations 2 through 4)

In its integrated plan dated February 28, 2013, APS provided insufficient information to support a conclusion that considerations 2 through 4 of NEI12-06. Section 5.3.3, will be taken into account in the development of the mitigating strategies pursuant to Order EA 12-049. These considerations address the potential impacts of large internal flooding sources that are not seismically robust and do not require AC power, the potential reliance on AC power to mitigate ground water, and the potential impacts of non seismically robust downstream dams. Please discuss the applicability of these considerations at PVNGS.

049-RAI-Palo Verde-14 (Effects of high temperatures on portable equipment)

In its integrated plan dated February 28, 2013, APS did not present information on the potential effects of high ambient temperatures at the locations where portable equipment would operate in the event it is necessary to use the strategies in order to allow the staff to evaluate conformance with NE112-06, Section 9.3.2. Please discuss the potential effects of high ambient temperatures on portable equipment in the locations such equipment would operate.

049-RAI-Palo Verde-15 (Portable lighting)

In its integrated plan dated February 28. 2013. APS did not present information on the identification in plant procedures and guidance of portable lighting such as flashlights or headlamps necessary for ingress and egress to plant areas required for deployment of the strategies in order to allow the staff to evaluate conformance with NEI12-06, Section 3.2.2. paragraph (8). Please discuss arrangements for the use of portable lighting.

049-RAI-Palo Verde-16 In its integrated plan dated February 28,2013, APS did not present information on access to the Protected Area and intemallocked areas in order to allow the staff to evaluate conformance with NEt 12-06. Section 3.2.2. paragraph (9). Please discuss the effects of AC power loss on area access and the need to gain entry to areas where remote equipment operation is necessary.

049-RAI-Palo Verde-17 (Use of CENTS for the Analysis of the ElAP Event)

Page 17. item 2 of the February 28, 2013, APS integrated plan submittal states, in part, that CENTS is approved by the NRC for modeling natural circulation heat removal for single phase flow with vapor is present in the reactor vessel head and pressurizer.

Item 16 on page 72 indicates that within 49 hours5.671296e-4 days <br />0.0136 hours <br />8.101852e-5 weeks <br />1.86445e-5 months <br /> of the event initiation. the reactor coolant system (RCS) makeup pump should be installed for use to maintain sub-cooling natural circulation (NC) and to prevent two-phase NC.

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Please discuss the ELAP coping analysis using CENTS and show that two-phase NC will not begin prior to initiating the required RCS makeup pump within 49 hours5.671296e-4 days <br />0.0136 hours <br />8.101852e-5 weeks <br />1.86445e-5 months <br />. Discuss the specific CENTS-predicted RCS conditions that are used to define the initiation of two-phase NC and address adequacy of the use of the specific RCS conditions for determination of the time when two-phase NC begins.

049-RAI-Palo Verde-18 (ADV Backup Nitrogen Supply and Manual operation of ADVs)

Item 13 on page 19 of the APS integrated plan dated February 28. 2013, indicates that the ADV backup nitrogen supply is sized for 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />, and item 13 on page 71 requires that the operator manually operate the ADVs once the nitrogen supply is depleted in 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />.

Please discuss the analysis determining the size of the subject nitrogen supply to show that the nitrogen source is available and adequate, lasting for 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> for use as motive force to operate the ADV.

Please discuss the electrical power supply that is required for operators to throttle steam flow through the ADVs within 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> and show that the power is available and adequate for the intended use before the operator takes actions to manually operate the ADVs. Also, discuss the operator actiOns that are required to operate ADVs manually and show that the required actions can be completed within the required times.

049-RAl-Palo Verde-19 Please clarify the accuracy With which steam generator pressure can be controlled by manual operation of ADVs after the nitrogen supply is depleted. For example, should steam generator pressure drop too low, turbine-driven auxiliary feedwater flow could be interrupted or accumulators could rapidly empty. Please provide adequate basis to confirm that manual operation of the ADVs under EtAP conditions would be conducive to maintaining a reasonably constant steam generator pressure. Please further describe how manual ADV control will be accomplished (e.g .* communication between the control room and a local operator stationed at the ADV), and, as applicable, whether environmental factors such as the potential for ambient noise and heat due to exiting steam have been considered.

049-RAI-Palo Verde-20 (AFW Sources)

Item 18 on page 19 of the integrated plan dated February 28.2013, indicates that when the CST depletes, the turbine driven auxiliary feed water pump (TDAFWP) suction path is required to realign to the Reactor Makeup Water Tank (RMWl) Within 45 hours5.208333e-4 days <br />0.0125 hours <br />7.440476e-5 weeks <br />1.71225e-5 months <br />.

Item 21 of Attachment 1A requires the operator to supply water from the water reclamation facility (WRF) to the CST within 116 hours0.00134 days <br />0.0322 hours <br />1.917989e-4 weeks <br />4.4138e-5 months <br /> when the available water in the CST and RMWT is depleted.

a. Please discuss the analysis to show that the required CST - RMWf switchover time is no greater than 45 hours5.208333e-4 days <br />0.0125 hours <br />7.440476e-5 weeks <br />1.71225e-5 months <br />, and realignment time of the WRF to the CST is within 116 hours0.00134 days <br />0.0322 hours <br />1.917989e-4 weeks <br />4.4138e-5 months <br />.

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b. The licensee stated in Table Item 18 on page 19, MCondensate Storage Tank (CST) Empties- Switchover to Reactor Makeup Water Tank (RMWT) (Refueling Water Tank (RWT) (for high Seismic Event>>: When the CST depletes, the TDAFWP suction path is realigned to RMWT: Please explain how core cooling will be maintained during this transition period.

c. Figure 3-3 on page 81 shows valve "VOSS" from the RMWT to the AFW suction piping. Please describe the location of this valve and the probable accessibility following an ElAP event, and describe how the RMWT can provide water to the AFWpump.

d. The description of Table Item 18 on page 19 indicates that for high seismic events, the operators will switch over to the RWT, but this is not reflected in Table Item 18 on page 72 or Figure 3-3 on page 81. Please describe how the RWT can provide AFW to the TDAFWP.

049-RAI-Palo Verde-21 Page 23 of the APS integrated plan dated February 28, 2013, indicates that the emergency operating procedures (EOPs) direct the operators to take action to confirm the closure of the main steam isolation valves (MSIVs). Simultaneous closure of MSIVs for all three units will result in loss of auxiliary steam to the air ejectors and loss of gland seal steam. Please provide a description of the affects of losin9 auxiliary steam to all three units, especially on the turbine if vacuum is lost rapidly.

049-RAI-Palo Verde--22 Page 24 ofthe APS integrated plan dated February 28,2013, states.

Without ventilation, the TDAFWP room temperature will exceed 130°F within four (4) hours. PVNGS has determined that opening the access doors to the room within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> will limit the temperature to a maximum of 130°F. thereby maintaining pump availability.

a. This description implies that there is no margin to the maximum temperature.

Please discuss if conservatisms exist in the analysis and/or the identification of additional operational margin with respect to the TDAFWP room temperature and the continued operation of the TDAFWP.

b. Please clarify whether the initial temperature condition assumed the worst-case outside temperature with the plant operating at full power. Provide the list of electrical components that are located in the TDAFWP room and are necessary to ensure successful operation of the TDAFWP. Also, please provide the qualification level for temperature and pressure for these electrical components for the duration that the TDAFWP is assumed to perform its mitigating strategies function.

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-10 049-RAI-Palo Verde-23 (Instrumentation and Systems)

a. Please list the safety and non-safety-related systems or equipment that are credited in the EtA? analysis. For the non-safely-related systems or equipment, please discuss the safety functions that they are intended to maintain and justify how the non-safety-related systems or equipment are available and reliable for their intended use.

b. Please justify that the instrumentation listed on pages 25-26 and pages 33-34 of the APS integrated plan dated February 28,2013, and the associated setpoints credited in the ELAP analysis for automatic actuations and indications required for the operator to take appropriate actions are reliable and accurate in the containment harsh conditions with high mOistUre levels, temperature. and pressure during the ELAP event.

049-RAI-Palo Verde-24 (Reactor Coolant Pump (RCP) Seal Leakage)

The last paragraph on page 32 and item 2 on page 74 of the APS integrated plan dated February 28, 2013, indicate that PVNGS RCP seals are assumed to have a maximum leakage of 17 gallons per minute (gpm) per pump at normal operating pressure.

Please discuss an analysis or RCP seal leakage testing data to show adequacy of the RCP seal leakage rate of 17 gprn per pump assumed in the ELAP analysis. The RCP seal leakage testing data used to support the assumed leakage rate should be applicable to the PVNGS RCP seals (with respect to the seal material, design and seal cooling systems) and ELAP conditions (in terms of the temperature and pressure, and seal failure mechanisms discussed in Section 6.4 of WCAP-17601-P) for an extended period consistent with the ELAP coping time. Also, please address applicability of the information in Section 4.4.2 ofWCAP-17601-P, Rev. 0, which states,

((

))

049--RAt-Palo Verde-25 (RCP Seal Model)

Item 36 on page 15 of the APS integrated plan dated February 28,2013, states, in part, that Operator actions are credited for cooling and depressurizing the RCS....

RCP seal leakage rates are dependent on ReS pressure and will decrease with deceasing pressure.

Please discuss how CENTS calculates the pressure-dependent RCP seal leakage rates.

If CENTS uses the equivalent size of the break area based on the initial leakage rate of 17 gpm per pump to calculate the pressure-dependent RCP seal leakage rates during the ELAP, please discuss whether the size of the break area is changed or not in the analysiS for the ELAP event. If the size is changed, discuss the changed sizes of the break area and address the adequacy of the sizes. If the break size remains OFFICIAl US, ONlY PROPRIETARY INFORMATION

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- 11 unchanged, address the adequacy of the unchanged break size throughout the ELAP event in conditions with various pressure, temperature (considering that the seal material may fail due to an increased stress induced by cooldown) and flow conditions that may involve two-phase flow which is different from the single phase flow modeled for the RCP seal tests that are used to determine the initial seal leakage rate of 17 gpm.

Q49-RAI-Palo Verde-26 (Core Sub-Criticality)

The third paragraph on page 35 of the APS integrated plan dated February 28,2013, states, in part. that PVNGS control rod shutdown margin and borated water inventory in the RCS and SITs [safety injection tanks] are sufficient to prevent recriticality of the core.

Please discuss the boron mixing model used for the re-criticality analysis in support of the plant FLEX mitigation strategies. and address the adequacy of the boron mixing model for the intended purpose with support of an analysis and/or boron mixing test data applicable to the ELAP conditions.

Q49-RAI-Palo Verde-27 (Tables A and B - Portable Equipment for Phase 2 and 3)

Tables A and B of the APS integrated plan dated February 28. 2013, list the phase 2 and 3 portable equipment required for the ELAP mitigation. Table A lists four self-priming pumps and four high-pressure RCS makeup pumps that are required during phase 2 of ELAP. The required capacities of the pumps are 370 gpm (at 500 pounds per square inch (psi>> and 30 gpm (at 1525 psQ for the priming pumps and high RCS makeup pumps, respectively. Table B lists high-pressure RCS makeup pumps and pumps to makeup to the CST from reservoirs that are required during phase 3 of ELAP. The required capacities of the respective pumps are 30 gpm (at 1525 psi) and 1200 gpm (at 130 psi).

Please specify the required times for the operator to realign each of the above-discussed pumps and confirm that the required times are consistent with the results of the ELAP analysis.

Please discuss how the operator actions are modeled in the ElAP to detennine the required flow rates of the portable pumps, and justify that the capacities of each of the above discussed pumps are adequate to maintain core cooling during phases 2 and 3 of ELAP.

049-RAI-Palo Verde-28 (Cooldown Analysis)

Attachment 1A of the APS integrated plan dated February 28. 2013, lists the sequence of events timeline for Mode 1~. On page 70. Item 11 indicates that the analysis assumes cooldown initiation time of 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and that the RCS cooldown to 350 OF is expected to complete within 4.11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br /> of initiation of the event.

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-12 Please list the operator actions credited in the analysis to complete the cooldown from 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to 4.11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br />, and discuss how the operator actions are modeled in the cooldown analysis for the 4.11-hour period using CENTS.

049-RAI-Palo Verde-29 (Time When TDAFWP Begins)

Item 2 on page 68 of the APS integrated plan dated February 28, 2013, indicates that at 0.017 hours1.967593e-4 days <br />0.00472 hours <br />2.810847e-5 weeks <br />6.4685e-6 months <br /> (60 seconds). the TDAFWP starts.

The above infonnation appears inconsistent with that listed in Table 5.1-1 of DAR-TDA12-2, (Reference 5 to the integrated plan), -Sequence of Events" for the case with the RCP leakage rate of 11 gpm/pump. Table 5.1-1 indicates that at 0.203 hours0.00235 days <br />0.0564 hours <br />3.356481e-4 weeks <br />7.72415e-5 months <br />, the AFW actuation signal actuates for steam generator (SG) 1. With a GO-second delay.

the AFWflow to both SGs begins from the TDAFWP at 0.22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br />. Please clarify and correct the inconsistency.

049-RAI-Palo Verde-30 (Section 3.2 ofWCAP-17G01-P Recommendations)

Section 3.2 ofWCAP-11G01-P discusses the PWR Owners Group's recommendations that cover the following subjects for consideration in developing FLEX mitigation strategies: (1) RCP seal leakage rates; (2) adequate shutdown margin; (3) time initiating cooldown and depressurization; (4) prevention ofthe RCS overfill; (5) blind feeding an SG with a portable pump; (G) SIT performance; and (7) asymmetric natural circulation cooldoYt/l'l (NCC).

Please discuss the licensee's position on each of the recommendations discussed above for developing the FLEX mitigation strategies. List the recommendations that are applicable to the plant, provide rationale for the applicability. address how the applicable recommendations are considered in the ELAP coping analysiS using CENTS. and discuss the plan to implement the recommendations. Also, provide rationale for each of the recommendations that are determined to not be applicable to the plant.

049-RAI-Palo Verde-31 Plant Specific Decay Heat Curve Item 1 on page 14 of the APS integrated plan dated February 28, 2013, indicates that the licensee uses a plant-specific best estimate (BE) decay heat curve in the thermal hydrauliC analysis for the ELAP event. The licensee states that the use of the plant specific BE decay heat curve is a deviation from WCAP-11601-P, but claims that the deviation is justified by CN-REA-12-36 (Reference 7 to the integrated plan).

Please provide justification for the deviation. Alternatively. jf CN-REA-12-36 has documented the appropriate justifICation, please provide the relevant pages.

049-RAI-Palo Vercle-32 Please describe the electrical power requirements for Phase 3 of the APS mitigating strategies integrated plan and provide the capacity of the power sources.

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- 13 049-RAI-Palo Verde-33 Core Cooling with SG Not Available The last paragraph on page 24 of the APS integrated plan dated February 28, 2013, states, in part. that Core cooling is maintained through once through heat removal from the RCS via coolant boil-off. .*. During this event, a hot leg vent will have been established such that a release path is available to supPOrt once through via boil-off.

Please discuss the analysis (including methods, assumptions, and results) to show that core cooling with SGs not available can be maintained through once throl!gh heat removal from the ReS via coolant boil-off. Include in the discussion:

a. Discussion of how gravity feed flow from the Rwr will be monitored and throttled to match core boil-off under ELAP conditions.

b. Discussion of the timing for providing primary makeup flow via gravity feed from the Rwr relative to the time of core uncovery under reduced RCS inventory conditions.

c. Discussion of what supporting eqUipment is implied to be operable when a steam generator is considered available to mitigate an ELAP (e.g.* TDAFWP, main steam relief valves, ADVs).

d. Discussion of scenarios wherein there is neither a hot leg vent nor a steam generator available. relative to the guidance of NEI12-06. The NRC staff understands that NRC Generic Letter 88-17. uLoss of Decay Heat Removal, dated October 17. 1988 (ADAMS Accession No. ML031200496). recommended establishing a hot leg vent under conditions of reduced RCS inventory (i.e., water level lower than 3 feet below the reactor vessel flange), rather than on the basis of SG availability under ELAP conditions in shutdown and refueling modes.

Furthermore, based on the requirement for high-pressure makeup specified for shutdown modes without SGs in Table 3-2 of NEI12-06, it is not clear that scenarios without a hot leg vent are considered beyond scope.

049-RAI-Palo Verde-34 In reference to pages 27 and 30 of the APS integrated plan dated February 28, 2013.

please provide the following items regarding the discussion of core cooling with SGs not available in Phases 2 and 3:

a. The basis for concluding that setting makeup flow to the steaming rate plus 10 percent is sufficient to prevent significant boric acid precipitation in the core.

b. The source of borated cool.mt once the inventory of the refueling water tank is depleted (e.g., reactor grade water, raw water mixed with boric acid),

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-14 049-RAI-Palo Verde-35 Please provide justification that version 4.07 of the modular accident analysis program (MAAP) code has adequate capability for performing analysis to demonstrate the integrity of large-dry containments during ELAP conditions. The justification may include discussion of the adequacy of the code's relevant models and correlations, benchmarking of code calculations against relevant experimental data, and relevant comparisons to calculations with state-of-the-art containment analysis codes. The justification may further include the presence of significant margin to acceptance criteria, if applicable. for scenarios at power as well as during shutdown and refueling.

049-RAI-Palo Verde-36 Please clarify whether the mass and energy leakage to containment detennined in the containment integrity analySis using the MMP code are consistent with the predictions of the CENTS code. To the extent that data is available from existing simulations, please indude plots comparing integrated mass and energy effluents from the two codes with and without the availability of the steam generators and provide justification if significant differences exist.

049-RAI-Palo Verde-37 Please discuss how the MAAP containment analysis models heat losses from the primary system to containment and provide justification for its adequacy.

049-RAI-Palo Verde-S8 Please discuss the quality assurance process under which the MAAP calculations were performed.

049-RAI-Palo Verde-39 Page 16 ofthe APS integrated plan dated February 28,2013, states, in part, that The actions specified for Mode 1 to Mode 4 conditions are bounding when compared to the Mode 5, Mode 6, and full core offload scenarios because the upper mode scenarios require the most personnel, actions, and time constraints.

Please provide the basis for this conclusion (e.g. analyses. studies, benchmarking, etc.)

with particular emphasis on maintaining containment conditions as identified by Open Item #4 on page 67 of the integrated plan.

Q49-RA/-Palo Verde-40 Please clarify whether the Open Item (01) Table on page 67 should include pages 40, 41, (potentially) 42. and 43 under Affected Pages by 014 rather than pages 45, 46, and OFFICiAl USE ONLY PROPRieTARY INFORMATION

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- 15

48. For 01 #4. please describe the evaluation and/or analysis to be performed, the expected completion date, and the date the results will be made available to the NRC.

049-RAI-Palo Verde-41 Please clarify how the planned strategies for providing makeup to the spent fuel pool (SFP) will be implemented while the pool is being cooled by boiling. For example, as noted on page 19 ofthe APS integrated plan dated February 28, 2013, the fuel building rollup door is opened at 11.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />. On page 45, the integrated plan further notes that, with a full core offload, the most conservative time to boil is 3.3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />. Finally, pages 45 47 refer to altemate mitigation equipment staging areas and connection points located inside the rollup door to the fuel building and the need to maintain accessibility to this area. Therefore, please identify the predicted peak temperature and humidity in the areas where accessibility is required during SFP boiling both prior and subsequent to the fuel building rollup door being opened, and confirm that conditions would be tolerable for operators over the expected exposure time for normal and core offload spent fuel heat loads. Provide validation that for escalated SFP boil off or leakage scenarios, implementation strategies indude analysis of personnel resource availability to complete actions within implementation strategy time limits. Analysis needs to include personnel resource availability in conSideration for other concurrent activities that also need to be performed site wide.

049-RAI-Palo Verde-42 Page 45 ct the APS integrated plan dated February 28, 2013, states, in part, that Diesel driven pumps will be used to deliver the required flow rate through monitor type nozzles to provide water to the spent fuel pool.

Please provide a discussion on the diesel fuel oil supply (e.g., fuel oil storage tank volume, supply pathway, etc.) for the diesel driven pumps and how continued operation to ensure core and spent fuel pool cooling is maintained indefinitely (Le., Phase 2 and 3).

049-RAI-Palo Verde-43 Please provide further information, and identify the methods to be used, which will provide the minimum flow rates necessary for the SFP sprays, and account for the rates required for boil off due to the design basis heat load, and postulated losses due to leakage.

049-RAI-Palo Verde-44 Please provide further information that will clarify whether PVNGS uses heat tracing for freeze protection to conform to NE112-0B, Section 3.2.2, guideline (12) as endorsed by JLO-ISG-2012-01, *Compliance with Order EA-12-049, Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events," dated August 29,2012 (ADAMS Accession No. ML12229A174).

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-2 is a proprietary version of the RAls and Enclosure 2 is a non-proprietary, redacted version of the RAls.

If circumstances result in the need to revise the requested response date, please contact me at (301) 415-1530 or via e-mail at jennivine.rankin@nrc.gov.

Sincerely, IRA!

Jennivine K. Rankin. Project Manager Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. STN 50-528, STN 50-529, and STN 50-530 cc w/Enclosure 2: Distribution via Ustserv

Enclosures:

1. Request for Additional Information (proprietary)

2. Request for Additional Information (non-proprietary)

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