Text

Additional Information Regarding Entergy'S Expedited Seismic Evaluation Process Report (CEUS Sites), Response to NRC Request for Information, Per 10CFR50.54(f) Regarding Recommendation 2.1 of the Near-Term Task Force Review Of..
	ML15182A249
Person / Time
Site:	Indian Point
Issue date:	06/25/2015
From:	Coyle L; Entergy Nuclear Northeast
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	NL-15-081
	Download: ML15182A249 (68)
	v • d • e

Enterqy Nuclear Northeast Indian Point Energy Center

-- Entergy 450 Broadway, GSB P.O. Box 249 Buchanan, NY 10511-024 Tel 914 254 6700 Lawrence Coyle Site Vice President NL-15-081 June 25, 2015 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk 11545 Rockville Pike, TWFN-2F1 Rockville, MD 20852-2738

SUBJECT:

Additional Information Regarding Entergy's Expedited Seismic Evaluation Process Report (CEUS Sites), Response to NRC Request for Information Pursuant to 10 CFR 50.54(f) Regarding Recommendation 2.1 of the Near-Term Task Force Review of Insights from the Fukushima Dai-ichi Accident Indian Point Unit Number 3 Docket No. 50-286 License No. DPR-64

REFERENCES:

1. Entergy Letter (NL-14-152) to NRC regarding "Entergy's Expedited Seismic Evaluation Process Report (CEUS Sites), Response to NRC Request for Information Pursuant to 10 CFR 50.54(f) Regarding Recommendation 2.1 of the Near-Term Task Force Review of Insights from the Fukushima Dai-ichi Accident", dated December 22, 2014

Dear Sir/ Madam:

On December 22, 2014, Entergy issued Reference 1 in response to the Nuclear Regulatory Commission (NRC) request for each Licensee located in the Central and Eastern United States (CEUS) to submit a Seismic Hazard Evaluation and Screening Report. The purpose of this letter is to update the Seismic Hazard Evaluation and Screening Report (enclosure) to address commitments made for Indian Point 3 (IP3) in Reference 1 as follows:

Entergy will perform seismic walkdowns at IP3 for inaccessible items listed in Section 7.1. Status - Complete as discussed in the enclosure, Section 7.1 a Entergy will generate HCLPF calculations for IP3 inaccessible items listed in Section 7.1.

Status - Complete with HCLPF screening (identified by note 3) in Appendix B of the enclosure.

Entergy will implement any necessary IP3 modifications for inaccessible items listed in Section 7.1 based on the schedule commitment to complete this activity in NL-13-069 dated April 29, 2013 - Complete with no new modifications required per calculations in Appendix B.

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NL-15-081 Docket No. 50-286 Page 2 of 2 dated April 29, 2013 - Complete with no new modifications required per calculations in Appendix B.

" Entergy will modify the IP3 Fire Water Storage Tanks (FWSTs) 31 and 32 and anchorages so that HCLPF>RLGM on the schedule commitment to complete this activity in NL-13-069 dated April 29, 2013- In process and on schedule.

" Entergy will submit a letter to NRC summarizing the IP3 HCLPF results and confirming implementation of the plant modifications associated with the IP3 commitments to complete modifications for inaccessible items and modifications of the FWSTs 31 and 32

- In process with this letter closing all commitments except for FWSTs 31 and 32. A letter will be issued when they are complete in accordance with this commitment.

This letter contains no new regulatory commitments. If you have any questions regarding this report, please contact Mr. Robert Walpole, Manager, Regulatory Assurance at (914) 254-6710.

I declare under penalty of perjury that the foregoing is true and correct. Executed on June

. *_, 2015 Respectfully, LC/sp

Enclosure:

Expedited Seismic Evaluation Process Report for Indian Point Unit 3 9230673-002

Attachment:

List of Regulatory Commitments cc: Mr. Douglas Pickett, Senior Project Manager, NRC NRR DORL Mr. John Boska, Senior Project Manager, NRC NRR DJLL Mr. Daniel H. Dorman, Regional Administrator, NRC Region 1 NRC Resident Inspector Mr. John B. Rhodes, President and CEO, NYSERDA Ms. Bridget Frymire, New York State Dept. of Public Service

ENCLOSURE TO NL-15-081 EXPEDITED SEISMIC EVALUATION PROCESS REPORT FOR INDIAN POINT UNIT 3 9230673-002 ENTERGY NUCLEAR OPERATIONS, INC.

INDIAN POINT NUCLEAR GENERATING UNIT NO. 3 DOCKET NO. 50-286

ATTACHMENT 9.1 ENGINEERING REPORT COVER SHEET & INSTRUCTIONS SHEET I OF 2 Engineering Report No. IP-RPT-14-00038 Rev I I Page 1 of . 6*

Entergy ENTERGY NUCLEAR Engineering Report Cover Sheet Engineering Report

Title:

Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit 3 Engineering Report Type:

New El Revision [D Cancelled El Superseded El Superseded by:

Applicable Site(s)

IPI El IP2 13 IP3 0 JAFE PNPS El VYo wpo El ANO! E] ANO2 [] ECH El GGNS El RBS [ WF3 [I PLP El EC No. 58094 Report Origin: [] Entergy 0 Vendor Vendor Document No.: 51-9230673-002 Quality-Related: [E Yes 0 No Prepared by: Areva Date: 6/1/15 Responsible Engineer (Print Name/Sign)

Design Verified: N/A Date:

Design Verifier (if require) rint Name/Sign)

Reviewed by: 1/2,51 s-Frank Madero/,t,-7,faj, t- Date:

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Approved by: Richard Drak.e/,' Date: $'*/s)-

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Supvr Manager ( t Nam e/SiIgn)

EN-DC-147 REV 6

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AREVA AREVA Inc.

Engineering Information Record Document No.: 51 - 9230673 - 002 Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit 3

Page 1 of 64

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Document No.: 51-9230673-002 AREVA Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit 3 Record of Revision Revision Pages/Sectionsl No. Paragraphs Changed Brief Description I Change Authorization 000 All Initial release 001 Section 2.0 Section 2.0 0 References were added due to additional components based on new Appendix A - Section 2.0, revision of supporting document.

3.0, 3.1, 3.1.3, 4.2, 5.1, 6.0, Appendix A 6.1, 6.2, 6.3.3, 6.4, 6.5, 7.1,

Section 2.0, 3.0, 3.1, 3.1.3, 4.2, 5.1, 6.0, 6.1, 6.2, 6.3.3, 6.4, 6.5, 7.2, 8.1, 8.2, 8.3, 8.4, 9.0, 7.1, 7.2, 8.1, 8.2, 8.3, and 8.4 were modified to incorporate Entergy Attachment A, and Comments [84] on Revision 0 of the document and updated with Attachment B additional components based on new revision of supporting document.

Attachment A - modified to incorporate Entergy Comments [84]

and to update with additional components based on new revision of supporting document.

Attachment B - modified to incorporate Entergy Comments [84]

and to update with additional components based on new revision of supporting document.

002 Section 2.0 Section 2.0 0 Updated the revision level for References 79a and 80.

Appendix A - Section 5.2, a Added Reference 79h.

6.2, 6.3.3, 6.4, 6.6, 7.1, 7.2, Appendix A 8.4, 9.0, Attachment A, and Att,,Ace B t ,a Section 5.2 updated to address CR 2015-3376.

Attachment B 0 Section 6.2 was updated to reflect the removal of a duplicate component.

Section 6.3.3 & 6.4 were modified to include the components identified during the inaccessible components walkdown as requiring HCLPF evaluation.

Section 6.6 was modified to address the conclusions of HCLPF evaluations to address CR 2015-3376.

Section 7.1 was updated to remove a duplicate component. Also to include the information on the walkdowns of the inaccessible components that were performed during the 3R1 8 outage (March 2015).

Section 7.2 was updated t results of inaccessible walkdowns

Section 8.4 updated for results of inaccessible walkdowns

Section 9.0 was modified to update the revision level for References 79a, and also added Reference 79h.

" Attachment A - Revised to reflect the removal of the duplicate component from the ESEL.

Attachment B - Revised to reflect the the removal of the duplicate component and to include results of the walkdowns for the inaccessible components.

Page 3

For Information Only A Document No.: 51-9230673-002 AR EVA Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit 3 Table of Contents Page S IGNA T UR E B LO C K............................................................................................................................. 2 R E C O R D O F R EV IS IO N ....................................................................................................................... 3 1.0 DO C UME NT A T ION.................................................................................................................... 5 2 .0 R E FER ENC E S ........................................................................................................................... 5 APPENDIX A: EXPEDITED SEISMIC EVALUATION PROCESS (ESEP) REPORT FOR INDIAN PO INT UNIT 3 ..................................................................................... A-1 Page 4

For Information Only A Document No.: 51-9230673-002 AREVA Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit 3 1.0 DOCUMENTATION This document contains the Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit

3. This document is located in Appendix A and is presented in the customer requested format.

2.0 REFERENCES

References identified with an (*) are maintained within Indian Point Unit 3 Records System and are not retrievable from AREVA Records Management. These are acceptable references per AREVA Administrative Procedure 0402-01, Attachment 8. See page 2 for Project Manager Approval of customer references.

1. NRC (E Leeds and M Johnson) Letter to All Power Reactor Licensees et al., "Request for Information Pursuant to Title 10 of the Code of Federal Regulations 50.54(f) Regarding Recommendations 2.1, 2.3 and 9.3 of the Near-Term Task Force Review of Insights from the Fukushima Dai-Ichi Accident," March 12, 2012.

2. EPRI 3002000704, "Seismic Evaluation Guidance, Augmented Approach for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1: Seismic," May 2013.

3. Entergy Letter to U.S. NRC, letter number NL-13-042 "Overall Integrated Plan in Response to March 12, 2012, Commission Order to Modify Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events (Order Number EA-12-049),"

February 28, 2013, NRC ADAMS Accession No. ML13079A348.

4. Entergy Letter to U.S. NRC, letter number NL-14-031, "Indian Point Energy Center's Second Six-Month Status Report for the Implementation of Order EA-1 2-049 Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events,"

February 27, 2014, NRC ADAMS Accession No. ML14070A365.

5. Entergy Letter to U.S. NRC, letter number NL-14-1 10, "Indian Point Energy Center's Third Six-Month Status Report for the Implementation of Order EA-1 2-049 Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events,"

August 27, 2014, NRC ADAMS Accession No. ML14251A227.

6. *Entergy Engineering Evaluation, EC No. 45874, Revision 1, "FLEX-Beyond Design Basis External Event Phases 1,11, and III Strategy Development Evaluation."

7. *Entergy Drawing 9321-F-20173, Revision 72, "Flow Diagram Main Steam."

8. *Entergy System Design Description 21.2, Revision 8, "System Description 21.2, Auxiliary Feedwater System."

9. *Entergy Drawing 9321-F-70313, Revision 17, "Auxiliary Boiler Feed Pump Room Instrument Piping Sheet No.1 Instrumentation."

10. *Entergy Drawing 9321-F-27233, Revision 40, "Flow Diagram Nitrogen to Nuclear Equipment."

11. *Entergy Plant Equipment Database for IP3.

12. *Entergy Drawing 9321-F-20193, Revision 62, "Flow Diagram Boiler Feedwater."

13. *Entergy Drawing 9321-LD-72123, Sheet 9, Revision 2, "Aux. F.W. Flow to Steam Generator

31 Loop F-1200 Diagram."

14. *Entergy Drawing 9321-LD-72123, Sheet 10 Revision 2, "Aux. F.W. Flow to Steam Generator

32 Loop F-1201 Diagram."

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For Information Only A Document No.: 51-9230673-002 AREVA Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit 3

15. *Entergy Drawing 9321-LD-72123, Sheet 11, Revision 2, "Aux. F.W. Flow to Steam Generator

33 Loop F-1202 Diagram."

16. *Entergy Drawing 9321-LD-72123, Sheet 12, Revision 2, "Aux. F.W. Flow to Steam Generator

34 Loop F-1203 Diagram."

17. *Entergy Drawing 9321-F-31673, Revision 28, "Wiring Diagram 480V Switchgear Miscellaneous."

18. *Entergy Drawing 9321-F-70033, Revision 17, "Transmitter Racks Piping Arrangement - Sheet No. 2 Instrumentation for Indian Point Energy Center Unit No. 3."

19. *Entergy System Design Description 21.1, Revision 4, "System Description 21.1, Steam Generator Water Level Control."

20. *Entergy Drawing 9321-F-70253, Revision 10, "Primary Plant Instrument Piping & Supports -

Sheet No. I Instrumentation."

21. *Entergy Drawing 9321-H-39903 Sheet 70, Revision 5, "Rack D-9 Layout."

22. *Entergy Drawing 9321-F-32273, Revision 41, "Wiring Diagram Supervisory Control Panel SC."

23. *Entergy Drawing 9321-F-70513, Revision 17, "Transmitter Racks Piping Arrangement - Sheet No. 4 Instrumentation."

24. *Entergy Drawing 9321-F-10023, Revision 22, "Plot Plan."

25. *Entergy Drawing 9321-F-20183 Sheet 1, Revision 63, "Flow Diagram Condensate & Boiler Feed Pump Suction."

26. *Entergy Drawing 9321-F-27353, Revision 42, "Flow Diagram Safety Injection System Sheet No. 1."

27. *Entergy System Design Description 10.1, Revision 10, "System Description 10.1, Safety Injection System."

28. *Entergy System Design Description 3.0, Revision 8, "System Description 3.0, Chemical and Volume Control System."

29. *Entergy System Design Description 4.2, Revision 7, "System Description 4.2, Residual Heat Removal System."

30. *Entergy System Design Description 1.4, Revision 7, "System Description 1.4, Pressurizer &

Pressurizer Relief Tank."

31. *Entergy Drawing 9321-F-33853, Revision 19, "Electrical Distribution & Transmission System."

32. *Entergy Drawing 9321-F-30063 Sheet 1, Revision 81, "Single Line Diagram 480V Motor Control Center No.'s 36A, 36B & 36C."

33. *Entergy Drawing 9321-F-27363, Revision 52, Flow Diagram Chemical & Volume Control System Sheet No. 1."

34. *Entergy Drawing 9321-F-27513 Sheet 1, Revision 31, "Flow Diagram Auxiliary Coolant System In PAB & FSB Sheet No. 1."

35. *Entergy Drawing 9321-F-27503, Revision 55, "Flow Diagram Safety Injection System Sheet No. 2."

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36. *Entergy Drawing 9321-F-27203, Revision 29, "Flow Diagram Auxiliary Coolant System Inside Containment."

37. *Entergy Drawing 9321-F-27473, Revision 43, "Flow Diagram Reactor Coolant System Sheet No. 2."

38. *Entergy Drawing 9321-F-36383, Revision 4, "Miscellaneous Wiring Details RCS-SOV-652, RCS-SOV-653, RCS-SOV-654, & RCS-SOV-655."

39. *Entergy Drawing 9321-F-30053, Revision 72, "Single Line Diagram 480V Motor Control Centers 37, 38, 39, & 311."

40. *Entergy Drawing 9321-F-30083, Revision 60, "Single Line Diagram D.C. System."

41. *Entergy Drawing IP3V-0454-0041, Revision 1, Structural Detail for Seismic Category 1 Instrument Rack."

42. *Entergy Calculation IP-CALC-07-00154, Revision 0, "Containment Atmospheric Temperature."

43. *Entergy Drawing 9321-F-33433, Revision 7, "Containment Parameters System Wiring Diagram."

44. *Entergy Drawing 9321-H-39913 Sheet 8, Revision 8, "External Connection Diagram R.P.S.

Rack No. 8 (A-7)."

45. *Entergy Drawing 9321-H-36723, Revision 0, "Cover Plates on Flight Pnl. "FCF" & Supervisory Pnl. "SCF"- Fabrication Mounting Details."

46. *Entergy Drawing 9321-F-20303, Revision 30, "Flow Diagram Fuel Oil to Diesel Generators."

47. *Entergy Drawing 9321-F-39893, Revision 43, "Single Line Diagram 118VAC Instrument Buses 31, 31A, 32, 32A, 33, 33A, 34, & 34A."

48. *Entergy Document IP3-RPT-UNSPEC-02182, Indian Point Three Nuclear Power Plant Individual Plant Examination of External Events," September 1997.

49. *Entergy Drawing 9321-F-32723, Revision 28, Wiring Diagram Flight Control Pnl. FCF & FCR."

50. *Entergy Drawing 9321-LD-72453 Sheet 21A, Revision 2, "Overpressurization System Channel 1 Loop P/T-413 Diagram."

51. *Entergy Drawing 9321-LD-72453 Sheet 23A, Revision 2, "Overpressurization System Channel 4 Loop P/T-443 Diagram."

52. *Entergy Drawing 9321-LD-72453 Sheet 21, Revision 3, "Overpressurization System Channel 1 Loop P/T-413 Diagram."

53. *Entergy Drawing 9321-LD-72453 Sheet 23, Revision 3, "Overpressurization System Channel 4 Loop P/T-443 Diagram."

54. *Entergy Drawing 9321-F-27383, Revision 28, "Flow Diagram Reactor Coolant System Sheet No. 1."

55. *Entergy Drawing 9321-LL-36853, Sheet 1, Revision 3, "Schematic Block Diagram Reactor Vessel Level Instrument System Train "A"."

56. *Entergy Drawing 9321-F-33203, Sheet 1, Revision 24, "Conduit & Tray Connection Schematic Containment Building."

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For Information Only A Document No.: 51-9230673-002 AR EVA Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit 3

57. *Entergy Drawing 9321-F-33313, Sheet 2, Revision 6, "Conduit & Tray Connection Schematic Fan House."

58. *Entergy Drawing 9321-F-30793, Revision 50, "Conduit Layout Containment Building Piping Penetration Area - Fan House."

59. *Entergy Drawing 9321-F-72043, Revision 7, "Containment Building Reactor Vessel Level Instrumentation System Flow Diagram."

60. *Entergy Drawing 9321-F-70283, Revision 25, Containment Building Instrument Arrangement Sheet No. 2 Instrumentation."

61. *Entergy Drawing 9321-F-39933, Revision 19 "Conduit Layout TSI Room, CFM Multiplexer Room, Control Building EL. 53'-0" & Roof El. 72'-7."

62. *Entergy Drawing 9321-F-95273 Sheet 1, Revision 6, "Control Room RVLIS Rack- Train "A" Interconnection Wiring Diagram."

63. *Entergy Procedure 3-ECA-0.0, Revision 9, "Loss of All AC Power."

64. *Entergy Drawing 9321-F-32383, Revision 31, "Wiring Diagram Supervisory Control Panel SB2."

65. *Entergy System Design Description 1.1, Revision 5, "System Description 1.1, Reactor Coolant System."

66. *Entergy Drawing IP3V-0245-0001, Revision 0, "40'-0" OD x 40'-0" High Fire Protection Water Storage Tanks "FP-Tk-I" & "FP-Tk-2" Pipe Support Details."

67. *Entergy System Design Description 18.0, Revision 7, "System Description 18.0, Main and Reheat Steam."

68. EPRI 1025287, "Seismic Evaluation Guidance: Screening, Prioritization and Implementation Details (SPID) for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1:

Seismic. Electric Power Research Institute," February 2013.

69. Entergy Letter NL-14-043, John A. Ventosa to NRC, "Entergy Seismic Hazard and Screening Report (CEUS Sites), Response to NRC Request for Information Pursuant to 10 CFR 50.54(f)

Regarding Recommendation 2.1 of the Near-Term Task Force Review of Insights from the Fukushima Dai-ichi Accident dated March 31, 2014." NRC ADAMS Accession No. ML14099A111.

70. *"Indian Point Energy Center Unit 3 Updated Final Safety Analysis Report," Revision 5, Docket No. 50-286, 2013.

71. EPRI-NP-6041-SL, "Methodology for Assessment of Nuclear Power Plant Seismic Margin,"

Revision 1, August 1991.

72. EPRI TR-1 03959, "Methodology for Developing Seismic Fragilities," July 1994.

73. NRC NUREG-1407, "Procedural and Submittal Guidance for the Individual Plant Examination of External Events (IPEEE) for Severe Accident Vulnerabilities," June 1991.

74. SQUG, "Generic Implementation Procedure (GIP) for Seismic Verification of Nuclear Plant Equipment, Seismic Qualification Utility Group," Revision 3A, December 2001.

75. NRC (E. Leeds) Letter to All Power Reactor Licensees et al., "Screening and Prioritization Results Regarding Information Pursuant to Title 10 of the Code of Federal Regulations 50.54(F)

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AR EVA Document No.: 51-9230673-002 Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit 3 Regarding Seismic Hazard Re-Evaluations for Recommendation 2.1 of the Near-Term Task Force Review of Insights From the Fukushima Dai-Ichi Accident," May 9, 2014.

76. Nuclear Energy Institute (NEI), A. Pietrangelo, Letter to D. Skeen of the USNRC, "Seismic Core Damage Risk Estimates Using the Updated Seismic Hazards for the Operating Nuclear Plants in the Central and Eastern United States," March 12, 2014.

77. Nuclear Energy Institute (NEI), A. Pietrangelo, Letter to D. Skeen of the USNRC, "Proposed Path Forward for NTTF Recommendation 2.1: Seismic Reevaluations," April 9, 2013, NRC ADAMS Accession No. ML13101A379.

78. NRC (E Leeds) Letter to NEI (J Pollock), "Electric Power Research Institute Final Draft Report xxxxx, "Seismic Evaluation Guidance: Augmented Approach for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1: Seismic," as an Acceptable Alternative to the March 12, 2012, Information Request for Seismic Reevaluations," May 7, 2013.

79. *Entergy Document EC54071, "ESEP Reports," the following AREVA documents are captured in the plant document management system:

a. AREVA Document 51-9212951-007, "ESEP Expedited Seismic Equipment List (ESEL) -

Indian Point Unit 3."

b. AREVA Calculation 32-9227208-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Station Service Transformers 2, 3, 5, and 6."

c. AREVA Calculation 32-9227381-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Battery Bank 33 (BATT 33)."

d. AREVA Calculation 32-9227576-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Battery Chargers 31, 32, & 34."

e. AREVA Calculation 32-9230353-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Refueling Water Storage Tank, RWST-31."

f. AREVA Calculation 32-9230692-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

RCS Overpressure Racks H-1 and H-3."

g. AREVA Document 32-9232897-000, "Indian Point Unit 3 ESEP Calculation - Fire Water Storage Tanks FP-T-1 and FP-T-2."

h. AREVA Calculation 32-9238938-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Residual Heat Exchangers ACAHRS1 and ACAHRS2."

The following references are AREVA references which were used as input for Appendix A.

80. AREVA Calculation 32-9224585-003, "Indian Point Unit 3 ESEP Binning and Screening."

81. AREVA Document 51-9230419-001, "Input to Entergy ESEP Report Sections 2 and 3 for Indian Point 3."

82. AREVA Document 51-9227403-000, "Input to Entergy ESEP Report Sections 4 and 5 for Indian Point Unit 3."

83. AREVA Document 51-9230505-000, "Input to Entergy ESEP Report Sections 6, 7, and 8 for Indian Point Unit 3."

84. AREVA Document 38-9232223-000, "Indian Point Unit 3 ESEP Report Comment Resolution Form."

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For Information Only A Document No.: 51-9230673-002 AR EVA Expedited Seismic Evaluation Process (ESEP) Report for Indian Point Unit 3 APPENDIX A: EXPEDITED SEISMIC EVALUATION PROCESS (ESEP) REPORT FOR INDIAN POINT UNIT 3 Note: Customer requested formatting begins on the following page.

Page A-1

For information Only EXPEDITED SEISMIC EVALUATION PROCESS (ESEP) REPORT FOR INDIAN POINT UNIT 3 (IP3)

Page 1

For Information Only Indian Point Unit 3 ESEP Report Table of Contents Page LIST O F TABLES ............................................................................................................................................ 4 LIST O F FIG URES .......................................................................................................................................... 5 1.0 PURPOSE AND OBJECTIVE ....................................................................................................... 6 2.0 BRIEF SUM MARY OF THE FLEX SEISMIC IMPLEMENTATION STRATEGIES .................................. 6 3.0 EQUIPMENT SELECTION PROCESS AND ESEL .............................................................................. 7 3.1 Equipment Selection Process and ESEL ......................................................................... 8 3.1.1 ESEL Development ........................................................................................... 9 3.1.2 Power Operated Valves .................................................................................... 9 3 .1 .3 Pu ll Bo xe s ........................................................................................................... 10 3.1.4 Termination Cabinets .................................................................................... 10 3.1.5 Critical Instrumentation Indicators ................................................................. 10 3.1.6 Phase 2 and 3 Piping Connections ................................................................. 10 3.2 Justification for Use of Equipment That is Not the Primary Means for FLEX Im p le m e ntatio n ................................................................................................................ 10 4.0 GROUND MOTION RESPONSE SPECTRUM (GM RS) .................................................................. 10 4.1 Plot of GM RS Submitted by the Licensee ..................................................................... 10 4.2 Comparison to SSE ............................................................................................................ 12 5.0 REVIEW LEVEL GROUND MOTION (RLGM) ............................................................................... 14 5.1 Description of RLGM Selected ...................................................................................... 14 5.2 Method to Estimate In-Structure Response Spectra (ISRS) ........................................... 16 6.0 SEISM IC MARGIN EVALUATION APPROACH ............................................................................. 16 6.1 Summary of Methodologies Used ............................................................................... 17 6.2 HCLPF Screening Process ............................................................................................... 17 6.3 Seismic W alkdown Approach ...................................................................................... 18 6.3.1 W alkdown Approach ...................................................................................... 18 6.3.2 Application of Previous W alkdown Information .......................................... 19 6.3.3 Significant W alkdown Findings ..................................................................... 19 6.4 HCLPF Calculation Process ............................................................................................. 19 6.5 Functional Evaluations of Relays .................................................................................. 20 6.6 Tabulated ESEL HCLPF Values (Including Key Failure Modes) ...................................... 20 7.0 INACCESSIBLE ITEMS ..................................................................................................................... 21 7.1 Identification of ESEL Item Inaccessible for W alkdowns ............................................... 21 7.2 Planned W alkdown / Evaluation Schedule / Close Out ............................................... 21 8.0 ESEP CONCLUSIONS AND RESULTS ........................................................................................... 21 8.1 Supporting Information .................................................................................................... 21 Page 2

For Information Only Indian Point Unit 3 ESEP Report Table of Contents (continued)

Page 8.2 Identification of Planned M odifications ...................................................................... 23 8.3 M odification Im plem entation Schedule ....................................................................... 23 8.4 Sum mary of Regulatory Com mitments ....................................................................... 23 9 .0 REFER EN CES .................................................................................................................................. 24 ATTACHM ENT A - INDIAN POINT UNIT 3 ESEL .................................................................................. A-1 ATTACHMENT B - ESEP HCLPF VALUES AND FAILURE MODES TABULATION .................................... B-1 Page 3

For Information Only Indian Point Unit 3 ESEP Report List of Tables Page TABLE 4-1: GM RS FOR INDIAN POINT UNIT 3 ...................................................................................... 11 TABLE 4-2: SSE FO R INDIAN PO INT UNIT 3 .......................................................................................... 13 TABLE 5-1: RLGM FOR INDIAN POINT UNIT 3 ...................................................................................... 14 Page 4

For information Only Indian Point Unit 3 ESEP Report List of Figures Page FIGURE 4-1: GM RS FOR INDIAN POINT UNIT3 .................................................................................... 12 FIGURE 4-2: GMRS TO SSE COMPARISON FOR INDIAN POINT UNIT 3 ............................................... 13 FIGURE 5-1: RLGM FOR INDIAN POINT UNIT3 .................................................................................... 16 Page 5

For Information Only Indian Point Unit 3 ESEP Report 1.0 PURPOSE AND OBJECTIVE Following the accident at the Fukushima Dai-ichi nuclear power plant resulting from the March 11, 2011, Great Tohoku Earthquake and subsequent tsunami, the Nuclear Regulatory Commission (NRC) established a Near-Term Task Force (NTTF) to conduct a systematic review of NRC processes and regulations and to determine if the agency should make additional improvements to its regulatory system. The NTTF developed a set of recommendations intended to clarify and strengthen the regulatory framework for protection against natural phenomena. Subsequently, the NRC issued a 50.54(f) letter on March 12, 2012 [1], requesting information to assure that these recommendations are addressed by all U.S. nuclear power plants. The 50.54(f) letter requests that licensees and holders of construction permits under 10 CFR Part 50 reevaluate the seismic hazards at their sites against present-day NRC requirements and guidance. Depending on the comparison between the reevaluated seismic hazard and the current design basis, further risk assessment may be required. Assessment approaches acceptable to the staff include a seismic probabilistic risk assessment (SPRA), or a seismic margin assessment (SMA). Based upon the assessment results, the NRC staff will determine whether additional regulatory actions are necessary.

This report describes the Expedited Seismic Evaluation Process (ESEP) undertaken for Indian Point Unit

3. The intent of the ESEP is to perform an interim action in response to the NRC's 50.54(f) letter to demonstrate seismic margin through a review of a subset of the plant equipment that can be relied upon to protect the reactor core following beyond design basis seismic events.

The ESEP is implemented using the methodologies in the NRC endorsed guidance in Electric Power Research Institute (EPRI) 3002000704, Seismic Evaluation Guidance: Augmented Approach for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1: Seismic [2].

The objective of this report is to provide summary information describing the ESEP evaluations and results. The level of detail provided in the report is intended to enable the NRC to understand the inputs used, the evaluations performed, and the decisions made as a result of the interim evaluations.

2.0 BRIEF

SUMMARY

OF THE FLEX SEISMIC IMPLEMENTATION STRATEGIES The Indian Point Unit 3 FLEX strategies for Reactor Core Cooling and Heat Removal, Reactor Inventory Control/Long Term Subcriticality, and Containment Function are summarized below. This summary is derived from the Indian Point Energy Center Overall Integrated Plan (OIP) in Response to the March 12, 2012, Commission Order EA-12-049 [3], and is consistent with the second and third six-month status reports [4][5] and supplemented by supporting FLEX engineering calculations [6].

Core Cooling and Heat Removal The Phase 1 FLEX strategy at Indian Point Unit 3 for this function is to use Atmospheric Dump Valves (ADVs) and Main Steam Safety Valves (MSSVs) to remove heat, with the steam generator being fed by the turbine-driven Auxiliary Feedwater (AFW) pump. Suction for the AFW pump is from the Condensate Storage Tank (CST). Backup nitrogen cylinders are available to support cycling the ADVs.

During Phase 2 of the FLEX strategy, portable diesel-driven pumps will be staged to provide makeup to the CST or to the steam generator feedwater pump suction. The diesel-driven steam generator FLEX feed pump will be staged to provide feedwater to steam generators in the event that the turbine-driven AFW pump becomes unavailable. The Primary Water Storage Tank (PWST) or Fire Water Storage Tanks (FWSTs) will be used as makeup sources to the CST. Diesel fuel for FLEX equipment can be provided from existing onsite Emergency Diesel Generator (EDG) Fuel Oil Storage Tanks.

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For InfrmCration Onlyv Indian Point Unit 3 ESEP Report The key parameters to be monitored are: steam generator level, steam generator pressure, CST level, Reactor Coolant System (RCS) pressure, and RCS temperature.

RCS Inventory Control ForAt Power modes In Phase 1, plant cooldown and depressurization will occur. Inventory control is achieved via the accumulators.

During Phase 2, to avoid adverse effects on the RCS natural circulation flow, the cold-leg accumulator isolation valves are electrically closed during the cooldown to prevent nitrogen injection into the RCS.

A FLEX pump will be used to provide RCS makeup with borated water supplied by the Refueling Water Storage Tank (RWST). To allow borated water injection into the RCS, the reactor head vent can be opened, if necessary, to provide a letdown path.

If the Extended Loss of AC Power (ELAP) event occurs during cold weather months when freezing of the RWST could possibly occur, a FLEX diesel generator can be used to repower the Electric Heat Trace (EHT) system.

For Shutdown modes In Phase 1, if the refueling canal is full, RCS makeup will be supplied by gravity feed from the RWST.

During Phase 2, a FLEX pump will be used to provide RCS makeup from the RWST in the same manner as for the At Power modes.

Additional key parameters to be monitored are pressurizer level and reactor vessel level and nuclear instrumentation.

Containment Function Containment function is not expected to be challenged during Phase 1 or Phase 2 for an ELAP event occurring when the plant is in Mode 1-4. Therefore, no FLEX strategy beyond monitoring containment pressure and temperature was developed to support containment function.

For Modes 5 and 6, containment pressure could be challenged unless a vent path is established.

Methods to establish a vent path will be used and include: opening penetration UU, which is used during outages as an additional air supply, deflating the sealing ring of the equipment hatch (if installed), or another vent path identified and evaluated.

Supporting Systems Necessary electrical components are outlined in the Indian Point Unit 3 QIP and primarily entail station batteries, Direct Current (DC) buses, distribution panels, inverters, battery chargers, and instrument buses.

3.0 EQUIPMENT SELECTION PROCESS AND ESEL The selection of equipment for the Expedited Seismic Equipment List (ESEL) followed the guidelines of EPRI 3002000704 [2]. The ESEL for Indian Point Unit 3 is presented in Attachment A. Information presented in Attachment A is drawn from the following references [3], [4], [5], [6], [7], [8], [9], [10],

[11], [12], [13], [14], [15], [16], [17], [18], [19], [20], [21], [22], [23], [24], [25], [26], [27], [28], [29], [30],

[31], [32], [33], [34], [35], [36], [37], [38], [39], [40], [41], [42], [43], [44], [45], [46], [47], [48], [49], [50],

[51], [52], [53], [54], [55], [56], [57], [58], [59], [60], [61], [62], [63], [64], [65], [66], and [67].

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For Information Only Indian Point Unit 3 ESEP Report 3.1 Equipment Selection Process and ESEL The selection of equipment to be included on the ESEL was based on installed plant equipment credited in the FLEX strategies during Phase 1, 2 and 3 mitigation of a Beyond Design Basis External Event (BDBEE), as outlined in the Indian Point Unit 3 OIP in Response to the March 12, 2012, Commission Order EA-12-049 [3] and is consistent with the second and third six-month status report issued to the NRC [4][5]. The OIP provides the Indian Point Unit 3 FLEX mitigation strategy and serves as the basis for equipment selected for the ESEP.

The scope of "installed plant equipment" includes equipment relied upon for the FLEX strategies to sustain the critical functions of core cooling and containment integrity consistent with the Indian Point Unit 3 0IP. FLEX recovery actions are excluded from the ESEP scope per EPRI 3002000704 [2]. The overall list of planned FLEX modifications and the scope for consideration herein is limited to those required to support core cooling, reactor coolant inventory and subcriticality, and containment integrity functions. Portable and pre-staged FLEX equipment (not permanently installed) are excluded from the ESEL per EPRI 3002000704.

The ESEL component selection followed the EPRI guidance outlined in Section 3.2 of EPRI 3002000704.

1. The scope of components is limited to that required to accomplish the core cooling and containment safety functions identified in Table 3-2 of EPRI 3002000704. The instrumentation monitoring requirements for core cooling/containment safety functions are limited to those outlined in the EPRI 3002000704 guidance, and are a subset of those outlined in the Indian Point Unit 3 OIP.

2. The scope of components is limited to installed plant equipment, and FLEX connections necessary to implement the Indian Point Unit 3 OIP as described in Section 2 of this report.

3. The scope of components assumes the credited FLEX connection modifications are implemented, and are limited to those required to support a single FLEX success path (i.e.,

either "Primary" or "Back-up/Alternate").

4. The "Primary" FLEX success path is to be specified. Selection of the "Back-up/Alternate" FLEX success path must be justified.

5. Phase 3 coping strategies are included in the ESEP scope, whereas recovery strategies are excluded.

6. Structures, systems, and components excluded per the EPRI 3002000704 [2] guidance are:

Structures (e.g. containment, reactor building, control building, auxiliary building, etc.).

Piping, cabling, conduit, HVAC, and their supports.

" Manual valves and rupture disks.

" Power-operated valves not required to change state as part of the FLEX mitigation strategies.

" Nuclear steam supply system components (e.g. RPV and internals, reactor coolant pumps and seals, etc.).

7. For cases in which neither train was specified as a primary or back-up strategy, then only one train component (generally 'A' train) is included in the ESEL.

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For Information Only Indian Point Unit 3 ESEP Report 3.1.1 ESEL Development The ESEL was developed by reviewing the Indian Point OIP [3], second and third six-month status reports [4][5] to determine the major equipment involved in the FLEX strategies. Further reviews of plant drawings (e.g., Piping and Instrumentation Diagrams (P&IDs) and Electrical One Line Diagrams) were performed to identify the boundaries of the flow paths to be used in the FLEX strategies and to identify specific components in the flow paths needed to support implementation of the FLEX strategies. Boundaries were established at an electrical or mechanical isolation device (e.g., isolation amplifier, valve, etc.) in branch circuits/ branch lines off the defined strategy electrical or fluid flow path. P&IDs were the primary reference documents used to identify mechanical components and instrumentation. The flow paths used for FLEX strategies were selected and specific components were identified using detailed equipment and instrument drawings, piping isometrics, electrical schematics and one-line drawings, system descriptions, design basis documents, as necessary.

Cabinets and equipment controls containing relays, contactors, switches, potentiometers, circuit breakers and other electrical and instrumentation that could be affected by high-frequency earthquake motions and that impact the operation of equipment in the ESEL are required to be on the ESEL. These cabinets and components were identified in the ESEL.

For each parameter monitored during the FLEX implementation, a single indication was selected for inclusion in the ESEL. For each parameter indication, the components along the flow path from measurement to indication were included, since any failure along the path would lead to failure of that indication. Components such as flow elements were considered as part of the piping and were not included in the ESEL.

3.1.2 Power Operated Valves Page 3-3 of EPRI 3002000704 [2] notes that power operated valves not required to change state as part of the FLEX mitigation strategies are excluded from the ESEL. Page 3-2 also notes that "functional failure modes of electrical and mechanical portions of the installed Phase 1 equipment should be considered (e.g. AFW trips)." To address this concern, the following guidance is applied in the Indian Point Unit 3 ESEL for functional failure modes associated with power operated valves:

Power operated valves that remain energized during the'ELAP events (such as DC powered valves), were included on the ESEL.

Power operated valves not required to change state as part of the FLEX mitigation strategies were not included on the ESEL. The seismic event also causes the ELAP event; therefore, the valves are incapable of spurious operation as they would be de-energized.

" Power operated valves not required to change state as part of the FLEX mitigation strategies during Phase 1, and are re-energized and operated during subsequent Phase 2 and 3 strategies, were not evaluated for spurious valve operation as the seismic event that caused the ELAP has passed before the valves are re-powered.

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For Information Only Indian Point Unit 3 ESEP Report 3.1.3 Pull Boxes Pull boxes were deemed unnecessary to be added to the ESEL as these components provide completely passive locations for pulling or installing cables. No breaks or connections in the cabling were included in pull boxes. Pull boxes were considered part of conduit and cabling, which were excluded in accordance with EPRI 3002000704 [2].

3.1.4 Termination Cabinets Termination cabinets, including cabinets necessary for FLEX Phase 2 and Phase 3 connections, provide consolidated locations for permanently connecting multiple cables. The termination cabinets and the internal connections provide a completely passive function; however, the cabinets are included in the ESEL to ensure industry knowledge on panel/anchorage failure vulnerabilities is addressed.

3.1.5 Critical Instrumentation Indicators Critical indicators and recorders are typically physically located on panels/cabinets and are included as separate components; however, seismic evaluation of the instrument indication may be included in the panel/cabinet seismic evaluation (rule-of-the-box).

3.1.6 Phase 2 and 3 Piping Connections Item 2 in Section 3.1 above notes that the scope of equipment in the ESEL includes "... FLEX connections necessary to implement the Indian Point Unit 3 OIP as described in Section 2." Item 3 in Section 3.1 also notes that "The scope of components assumes the credited FLEX connection modifications are implemented, and are limited to those required to support a single FLEX success path (i.e., either "Primary" or "Back-up/Alternate")."

Item 6 in Section 3.1 above goes onto explain that "Piping, cabling, conduit, HVAC, and their supports" are excluded from the ESEL scope in accordance with EPRI 3002000704 [2].

Therefore, piping and pipe supports associated with FLEX Phase 2 and Phase 3 connections are excluded from the scope of the ESEP evaluation. However, any active valves in FLEX Phase 2 and Phase 3 connection flow path are included in the ESEL.

3.2 Justification for Use of Equipment That is Not the Primary Means for FLEX Implementation No equipment that was not part of the primary success path was selected for the Indian Point Unit 3 ESEL.

4.0 GROUND MOTION RESPONSE SPECTRUM (GMRS) 4.1 Plot of GMRS Submitted by the Licensee In accordance with the guidance provided in Section 2.4.2 of the SPID [68] for rock sites, the Safe Shutdown Earthquake (SSE) control point elevation is defined at the top of hard-rock and is applicable at grade in the free field as well as the various foundations elevations [69]. Table 4-1 shows the GMRS acceleration for a range of spectral frequencies [69]. The GMRS at the control point is shown in Figure 4-1.

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For Information Only Indian Point Unit 3 ESEP Report Table 4-1: GMRS for Indian Point Unit 3 Frequency GMRS (Hz) (g) 100 4.12E-01 90 4.46E-01 80 5.04E-01 70 5.94E-01 60 7.04E-01 50 8.06E-01 45 8.42E-01 40 8.66E-01 35 8.77E-01 30 8.75E-01 25 8.58E-01 20 8.28E-01 15 7.67E-01 12.5 7.17E-01 10 6.48E-01 9 6.04E-01 8 5.55E-01 7 5.02E-01 6 4.46E-01 5 3.85E-01 4 3.14E-01 3 2.36E-01 2.5 1.94E-01 2 1.59E-01 1.5 1.17E-01 1.25 9.42E-02 1 7.04E-02 0.9 6.40E-02 0.8 5.71E-02 0.7 4.99E-02 0.6 4.25E-02 0.5 3.48E-02 Page 11

For Information Only Indian Point Unit 3 ESEP Report Table 4-1: GMRS for Indian Point Unit 3 (continued)

Frequency GMRS (Hz) (g) 0.4 2.78E-02 0.3 2.09E-02 0.2 1.39E-02 0.167 1.16E-02 0.125 8.69E-03 0.1 6.95E-03 GMRS at Control Point for Indian Point Unit 3, 5% Damping 1.00 0.90 0.80 0.70 0.60

"0.50 0.40 0.30 0.20 0.10 0.00 0.1 10 100 Frequency (Hz)

Figure 4-1: GMRS for Indian Point Unit 3 4.2 Comparison to SSE The SSE corresponds to a horizontal acceleration of 0.15g [70]. The SSE is defined in the Updated Final Safety Analysis Report [70] in terms of a Peak Ground Acceleration (PGA) and a design response spectrum. These spectra have been digitized and tabulated [69]. Table 4-2 shows the spectral acceleration values at selected frequencies for the 5% damped horizontal SSE.

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Indian Point Unit 3 ESEP Report Table 4-2: SSE for Indian Point Unit 3 Frequency Spectral Acceleration (Hz) (g) 100 0.15 25 0.15 10 0.168 5 0.228 2.5 0.234 1 0.127 0.5 0.075 GMRS to SSE Comparison for Indian Point Unit 3, 5% Damping 0.90 0.80 0.70 0.60 0.50 0.40 0.30 0.20 0.10 0.1 10 100 Fr- ency (Mi)

Figure 4-2: GMRS to SSE Comparison for Indian Point Unit 3 The SSE envelops the GMRS for lower frequencies up to nearly 3 Hz. The GMRS exceeds the SSE beyond that point. As the GMRS exceeds the SSE in the I to 10 Hz range, the plant does not screen out of the ESEP according to Section 2.2 of EPRI 3002000704 [2]. The two special screening considerations as described in Section 2.2.1 of EPRI 3002000704, namely a) Low-frequency GMRS exceedances at Low Seismic Hazard Sites and b) Narrow Band Exceedances in the 1 to 1OHz range, provide criteria for accepting specific GMRS exceedances. However, the GMRS exceedances occur in the frequency range of interest and cannot be characterized as narrow-band exceedances. Therefore, these special screening considerations do not apply for Indian Point Unit 3 and High Confidence of a Low Probability of Failure (HCLPF) evaluations are to be performed.

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For Information Only Indian Point Unit 3 ESEP Report 5.0 REVIEW LEVEL GROUND MOTION (RLGM) 5.1 Description of RLGM Selected The RLGM is selected based on Approach 1 in Section 4 of EPRI 3002000704 [2]. The RLGM is developed based on the SSE. The maximum GMRS/SSE ratio between 1 and 10 Hz range occurs at 10 Hz where the ratio is 0.648/0.168 = 3.86. As the maximum ratio of the GMRS to the SSE over the i to 10 Hz range exceeds a value of 2, the GMRS/SSE ratio is set to the maximum scaling factor value of 2.0 for IP3 in accordance with Section 4 of EPRI 3002000704. Table 5-1 lists the horizontal ground RLGM acceleration at 5% damping at selected frequencies and the plot is shown in Figure 5-1. The RLGM is generated by plotting the digitized data on a log/linear graph paper, and connecting the points with straight lines.

Table 5-1: RLGM for Indian Point Unit 3 Frequency RLGM at 5% Damping (Hz) (g) 100.00 0.30 33.00 0.30 15.78 0.31 13.65 0.31 12.20 0.32 10.09 0.34 8.43 0.36 7.23 0.38 6.55 0.40 5.89 0.43 5.34 0.44 4.94 0.46 4.59 0.47 4.17 0.48 3.83 0.49 3.67 0.49 3.41 0.50 3.15 0.49 2.89 0.49 2.65 0.48 2.55 0.47 2.24 0.45 2.02 0.42 Page 14

For Information Only Indian Point Unit 3 ESEP Report Table 5-1: RLGM for Indian Point Unit 3 (continued)

Frequency RLGM at 5% Damping (Hz) (g) 1.78 0.40 1.64 0.38 1.57 0.36 1.46 0.34 1.34 0.32 1.23 0.30 1.16 0.28 1.09 0.27 1.01 0.26 0.96 0.24 0.91 0.23 0.86 0.22 0.81 0.21 0.76 0.21 0.74 0.20 0.71 0.19 0.68 0.19 0.64 0.18 0.60 0.17 0.56 0.16 0.53 0.15 0.10 0.14 Page 15 V

For Information Only Indian Point Unit 3 ESEP Report Review Level Ground Motion (2xSSE) Response Spectra - Horizontal Direction 0.60 0.50 0.40

~0.30-0.20 0.10 0.00 0.10 Frequency (Hz)

Figure 5-1: RLGM for Indian Point Unit 3 5.2 Method to Estimate In-Structure Response Spectra (ISRS)

The RLGM ISRS for Indian Point Unit 3 are generated by scaling the SSE ISRS [70]. The following steps are used to generate the RLGM ISRS.

1. Obtain the horizontal direction SSE ISRS for a particular damping value.

2. Calculate the horizontal RLGM ISRS by scaling the horizontal direction SSE ISRS by a factor of 2.0.

3. Repeat steps 1 and 2 to obtain RLGM ISRS for multiple damping values.

For each relevant floor elevation, the vertical direction RLGM ISRS is calculated as two thirds of the horizontal in-structure floor response.

6.0 SEISMIC MARGIN EVALUATION APPROACH It is necessary to demonstrate that ESEL items have sufficient seismic capacity to meet or exceed the demand characterized by the RLGM. The seismic capacity is characterized as the PGA for which there is a HCLPF. The PGA is associated with a specific spectral shape, in this case the 5%-damped RLGM spectral shape. The HCLPF capacity must be equal to or greater than the RLGM PGA. The criteria for seismic capacity determination are given in Section 5 of EPRI 3002000704 [2].

There are two basic approaches for developing HCLPF capacities:

1. Deterministic approach using the conservative deterministic failure margin (CDFM) methodology of EPRI NP-6041-SL, A Methodology for Assessment of Nuclear Power Plant Seismic Margin (Revision 1) [71].

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For Information Only Indian Point Unit 3 ESEP Report

2. Probabilistic approach using the fragility analysis methodology of EPRI TR-103959, Methodology for Developing Seismic Fragilities [72].

6.1 Summary of Methodologies Used Indian Point Unit 3 was classified as a 0.3g full scope plant in NUREG-1407 [73] and performed a SPRA as part of Individual Plant Examination for External Events (IPEEE) program. The SPRA is documented in [48]. Indian Point Unit 3 IPEEE program followed the NUREG-1407 methodology for seismic evaluation with plant seismic walkdowns using the EPRI NP-6041-SL [71] and Generic Implementation Procedure [74]. Walkdown efforts were coordinated for evaluations pertaining to the IPEEE and Unresolved Safety Issue (USI) A-46. Section 3.3 and Appendix B of [69] established that in accordance with the criteria established in SPID [68] Section 3.3, the IPEEE and reassessment of IHS are adequate to support screening of the updated seismic hazard for Indian Point Unit 3. Hence, the risk insights obtained from the IPEEE are used to assess risk for ESEP where applicable.

For ESEP, the evaluation consisted of screening walkdowns and HCLPF calculations. The screening walkdowns used the screening tables from Chapter 2 of EPRI NP-6041-SL. The walkdowns were conducted by engineers trained in EPRI NP-6041-SL and were documented on Screening Evaluation Work Sheets (SEWS) from EPRI NP-6041-SL. Anchorage capacity calculations used the CDFM criteria from EPRI NP-6041-SL. Seismic demand was based on EPRI 3002000704 [2] using an RLGM of 2xSSE with a PGA of 0.3g PGA as shown on Figure 5-1.

6.2 HCLPF Screening Process For ESEP, the components are screened considering RLGM (2xSSE) with a 0.3g PGA. The screening tables in EPRI NP-6041-SL [71] are based on ground peak spectral accelerations of 0.8g and 1.2g. These both exceed the RLGM peak spectral acceleration.

The ESEL components were prescreened based on Table 2-4 of EPRI NP-6041-SL. Additional pre-screening, specifically for anchorage, considered walkdown results and documentation from NTTF 2.3 and SEWS from IPEEE and USI A-46. Equipment anchorage was screened out in cases where previous evaluations showed large available margin against SSE. The remaining components (i.e., components that do not screen out), were identified as requiring HCLPF calculations. ESEL components were walked down and based on the equipment and anchorage conditions, prescreening decisions were confirmed and a final list of required HCLPF calculations was generated. Equipment for which the screening caveats were met and for which the anchorage capacity exceeded the RLGM seismic demand are screened out from ESEP seismic capacity determination because the HCLPF capacity exceeds the RLGM.

The Indian Point Unit 3 ESEL contains 193 items. Of these, 30 are valves. In accordance with Table 2-4 of EPRI NP-6041-SL, valves may be assigned a functional capacity of 0.8g peak spectral acceleration without any review other than looking for valves with large extended operators on small diameter piping, and anchorage is not a failure mode. Therefore, valves on the ESEL are screened out from ESEP seismic capacity determination, subject to the caveat regarding large extended operators on small diameter piping.

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For Information Only Indian Point Unit 3 ESEP Report 6.3 Seismic Walkdown Approach 6.3.1 Walkdown Approach Walkdowns were performed in accordance with the criteria provided in Section 5 of EPRI 3002000704

[2], which refers to EPRI NP-6041-SL [71] for the Seismic Margin Assessment process. Pages 2-26 through 2-30 of EPRI NP-6041-SL describe the seismic walkdown criteria, including the following key criteria.

"The SRT [Seismic Review Team] should "walk by" 100%of all components which are reasonably accessible and in non-radioactiveor low radioactive environments. Seismic capability assessment of components which are inaccessible,in high-radioactiveenvironments, or possibly within contaminatedcontainment, will have to rely more on alternatemeans such as photographicinspection, more reliance on seismic reanalysis,and possibly, smaller inspection teams and more hurriedinspections. A 100% "walk by" does not mean complete inspection of each component, nor does it mean requiringan electrician or other technician to de-energize and open cabinets or panels for detailedinspection of all components. This walkdown is not intended to be a QA or QC review or a review of the adequacy of the component at the SSE level.

If the SRT has a reasonablebasisfor assuming that the group of components are similar and are similarlyanchored, then it is only necessary to inspect one component out of this group. The "similarity-basis"should be developed before the walkdown during the seismic capability preparatorywork (Step 3) by reference to drawings, calculationsor specifications. The one component or each type which is selected should be thoroughly inspected which probably does mean de-energizing and opening cabinets or panelsfor this very limited sample. Generally, a spare representativecomponent can be found so as to enable the inspection to be performed while the plant is in operation. At least for the one component of each type which is selected, anchorageshould be thoroughly inspected.

The walkdown procedure should be performed in an ad hoc manner. For each class of components the SRT should look closely at the first items and compare the field configurations with the construction drawings and/or specifications. If a one-to-one correspondenceis found, then subsequent items do not have to be inspected in as great a detail. Ultimately the walkdown becomes a "walk by" of the component class as the SRT becomes confident that the construction pattern is typical. This procedurefor inspection should be repeatedfor each component class; although, during the actual walkdown the SRT may be inspecting several classes of components in parallel. If serious exceptions to the drawings or questionable construction practicesare found then the system or component class must be inspected in closer detail until the systematic deficiency is defined.

The 100% "walk by" is to look for outliers,lack of similarity,anchorage which is differentfrom thatshown on drawings or prescribedin criteriafor that component, potentialSI [Seismic Interaction]problems, situations that are at odds with the team members' past experience, and any other areas of serious seismic concern. If any such concerns surface, then the limited sample size of one component of each type for thorough inspection will have to be increased.

The increase in sample size which should be inspected will depend upon the number of outliers and different anchorages,etc., which are observed. It is up to the SRT to ultimately select the sample size since they are the ones who are responsiblefor the seismic adequacy of all elements which they screenfrom the margin review. Appendix D gives guidancefor sampling selection."

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For Information Only Indian Point Unit 3 ESEP Report 6.3.2 Application of Previous Walkdown Information Several ESEL items were previously walked down during the Indian Point Unit 3 seismic IPEEE program, for seismic IPEEE outlier resolutions in accordance with USI A-46 evaluation program and NTTF Recommendation 2.3. Those walkdown results were reviewed and the following steps were taken to confirm that the previous walkdown conclusions remained valid.

" A walk by was performed to confirm that the equipment material condition and configuration is consistent with the walkdown conclusions and that no new significant interactions related to block walls or piping attached to tanks exist.

If the ESEL item was screened out based on the previous walkdown, that screening evaluation was reviewed and reconfirmed for the ESEP.

6.3.3 Significant Walkdown Findings Consistent with the guidance from EPRI NP-6041-SL [71], no significant outliers or anchorage concerns were identified during the Indian Point Unit 3 seismic walkdowns. Based on walkdown results, HCLPF capacity evaluations were recommended for the following fifteen (15) components:

" RWST-31, Refueling Water Storage Tank

BATT CHGR 31, Battery Charger 31

" BATT CHGR 32, Battery Charger 32

" BATT CHGR 34, Battery Charger 34

BATT 33, Battery Bank 33

" BUS2A, Bus 2A480V

BUS3A, Bus3A480V

" BUS5A, Bus 5A480V

" BUS6A, Bus 6A480V

" Rack Hi, CCR Aux. Panel Analog Rack Hi

" Rack H3, CCR Aux. Panel Analog Rack H3

" FP-T-1, 31 Fire Water Storage Tank

" FP-T-2, 32 Fire Water Storage Tank

ACAHRS1, RHR HTEXCH # 31

" ACAHRS2, RHR HTEXCH # 32 6.4 HCLPF Calculation Process ESEL items identified for ESEP at Indian Point Unit 3 were evaluated using the criteria in EPRI NP-6041-SL [71] and Section 5 of EPRI 3002000704 [2]. Those evaluations included the following steps:

Performing seismic capability walkdowns for equipment not included in previous seismic walkdowns (SQUG, IPEEE, or NTTF 2.3) to evaluate the equipment installed plant conditions Page 19

For Information Only Indian Point Unit 3 ESEP Report

Performing screening evaluations using the screening tables in EPRI NP-6041-SL as described in Section 6.2

Performing HCLPF calculations considering various failure modes that include both structural failure modes (e.g. anchorage, load path etc.) and functional failure modes All HCLPF calculations were performed using the CDFM methodology. A total of Seven (7) HCLPF calculations were performed to address the fifteen (15) components.

" Calculation "Battery Chargers 31, 32, & 34" addressing three (3) components BATT CHGR 31, BATT CHGR 32 and BATT CHGR 34

" Calculation "Battery Bank 33" addressing a single component BATT 33

Calculation "Refueling Water Storage Tank" addressing a single component RWST-31

" Calculation "Station Service Transformers 2, 3, 5, and 6" addressing transformers adjacent to our (4) components BUS2A, BUS3A, BUS5A and BUS6A

" Calculation "RCS Overpressure Racks H-1 and H-3" addressing two (2) instrument racks H1 and H3

Calculation "Fire Water Storage Tanks FP-T-1 and FP-T-2" addressing two (2) components FP-T-1 and FP-T-2

Calculation "Residual Heat Exchangers ACAHRS1 and ACAHRS2" addressing two (2) components ACAHRS1 and ACAHRS2 6.5 Functional Evaluations of Relays No seal in/lockout type relays were identified on Indian Point Unit 3 ESEL. Therefore, no relay evaluations were performed.

6.6 Tabulated ESEL HCLPF Values (Including Key Failure Modes)

Tabulated ESEL HCLPF values are provided in Attachment B. The following notes apply to the information in the tables.

For items screened out using EPRI NP-6041-SL [71] screening tables, the HCLPF capacity is provided as >RLGM and the failure mode is listed as "Screened", (unless the controlling HCLPF value is governed by anchorage).

For items where anchorage controls the HCLPF value, the HCLPF value is listed in the table and the failure mode is noted as "anchorage." For the items where the component function controls the HCLPF value, the HCLPF value is listed in the table and the failure mode is noted as "functional."

After performing the HCLPF calculations, ESEL components were determined to have adequate capacity for the design basis loads and HCLPF greater than RLGM for all components except the following:

FP-T-1, 31 Fire Water Storage Tank

FP-T-2, 32 Fire Water Storage Tank Page 20

For Information Only Indian Point Unit 3 ESEP Report 7.0 INACCESSIBLE ITEMS 7.1 Identification of ESEL Item Inaccessible for Walkdowns Forty (41) components on the ESEL were previously identified as inaccessible and not walked down since they are located in the Primary Containment Building in a locked high radiation area. These items were walked down during 3R18 refueling outage in March 2015. During these walkdowns, two temperature elements were determined to be the same component. Thus the results for the remaining forty (40) components are now detailed in Attachment B.

Also, the two (2) Hydraulic Isolators, one (1) valve and one (1) Terminal Box listed below were not walked down due to the plant condition (inaccessible due to contamination/high radiation) at the time of the walkdowns. Subject components were evaluated based on the review of the recent photos of the components and the general area.

" LIS-1311, Hydraulic Isolator

LIS-1312, Hydraulic Isolator

" MOV-882, RHR Pump Suction Isolation Valve

" Y29, Terminal Box 7.2 Planned Walkdown / Evaluation Schedule / Close Out No follow up walkdowns are required.

8.0 ESEP CONCLUSIONS AND RESULTS 8.1 Supporting Information Indian Point Unit 3 has performed the ESEP as an interim action in response to the NRC's 50.54(f) letter

[1]. It was performed using the methodologies in the NRC endorsed guidance in EPRI 3002000704 [2].

The ESEP provides an important demonstration of seismic margin and expedites plant safety enhancements through evaluations and potential near-term modifications of plant equipment that can be relied upon to protect the reactor core following beyond design basis seismic events.

The ESEP is part of the overall Indian Point Unit 3 response to the NRC's 50.54(f) letter. On March 12, 2014, NEI submitted to the NRC results of a study [76] of seismic core damage risk estimates based on updated seismic hazard information as it applies to operating nuclear reactors in the Central and Eastern United States (CEUS). The study concluded that "site-specific seismic hazards show that there has not been an overall increase in seismic risk for the fleet of U.S. plants" based on the re-evaluated seismic hazards [69]. As such, the "current seismic design of operating reactors continues to provide a safety margin to withstand potential earthquakes exceeding the seismic design basis."

The NRC's May 9, 2014 NTTF 2.1 Screening and Prioritization letter [75] concluded that the "fleet wide seismic risk estimates are consistent with the approach and results used in the GI-199 safety/risk assessment." The letter also stated that "As a result, the staff has confirmed that the conclusions reached in GI-199 safety/risk assessment remain valid and that the plants can continue to operate while additional evaluations are conducted."

Page 21

For Information Only Indian Point Unit 3 ESEP Report An assessment of the change in seismic risk for Indian Point Unit 3 was included in the fleet risk evaluation submitted in the March 12, 2014 NEI letter [76]; therefore, the conclusions in the NRC's May 9 letter also apply to Indian Point Unit 3.

In addition, the March 12, 2014 NEI letter provided an attached "Perspectives on the Seismic Capacity of Operating Plants," which (1) assessed a number of qualitative reasons why the design of Structures, Systems and Components (SSCs) inherently contain margin beyond their design level, (2) discussed industrial seismic experience databases of performance of industry facility components similar to nuclear SSCs, and (3) discussed earthquake experience at operating plants.

The fleet of currently operating nuclear power plants was designed using conservative practices, such that the plants have significant margin to withstand large ground motions safely. This has been borne out for those plants that have actually experienced significant earthquakes. The seismic design process has inherent (and intentional) conservatisms which result in significant seismic margins within SSCs.

These conservatisms are reflected in several key aspects of the seismic design process, including:

" Safety factors applied in design calculations

" Damping values used in dynamic analysis of SSCs

" Bounding synthetic time histories for in-structure response spectra calculations

" Broadening criteria for in-structure response spectra

" Response spectra enveloping criteria typically used in SSC analysis and testing applications

" Response spectra based frequency domain analysis rather than explicit time history based time domain analysis

" Bounding requirements in codes and standards

" Use of minimum strength requirements of structural components (concrete and steel)

Bounding testing requirements

Ductile behavior of the primary materials (that is, not crediting the additional capacity of materials such as steel and reinforced concrete beyond the essentially elastic range, etc.)

These design practices combine to result in margins such that the SSCs will continue to fulfill their functions at ground motions well above the SSE.

The intent of the ESEP is to perform an interim action in response to the NRC's 50.54(f) letter to demonstrate seismic margin through a review of a subset of the plant equipment that can be relied upon to protect the reactor core following beyond design basis seismic events. The RLGM used for the ESEP evaluation is a scaled version of the plant's SSE rather than the actual GMRS. To more fully characterize the risk impacts of the seismic ground motion represented by the GMRS on a plant specific basis, a more detailed seismic risk assessment (SPRA or risk-based SMA) is to be performed in accordance with EPRI 1025287 [68]. As identified in the Indian Point Unit 3 Seismic Hazard and GMRS submittal [69], Indian Point Unit 3 screens in for a risk evaluation. The complete risk evaluation will more completely characterize the probabilistic seismic ground motion input into the plant, the plant response to that probabilistic seismic ground motion input, and the resulting plant risk characterization. Indian Point Unit 3 will complete that evaluation in accordance with the schedule identified in NEI's letter dated April 9, 2013 [77] and endorsed by the NRC in their May 7, 2013 letter

[78].

Page 22

For Information Only Indian Point Unit 3 ESEP Report 8.2 Identification of Planned Modifications Insights from the ESEP identified the following items where the HCLPF is below the RLGM and plant modifications will be made in accordance with EPRI 3002000704 [2] to enhance the seismic capacity of the plant. Subject modifications are planned to provide additional seismic margin such that the HCLPF will exceed the RLGM.

" FP-T-1, 31 Fire Water Storage Tank

FP-T-2, 32 Fire Water Storage Tank 8.3 Modification Implementation Schedule Plant modifications described in Section 8.2 will be performed in accordance with the schedule identified in NEI letter dated April 9, 2013 [77], which states that plant modifications not requiring a planned refueling outage will be completed by December 2016 and modifications requiring a refueling outage will be completed within two planned refueling outages after December 31, 2014.

8.4 Summary of Regulatory Commitments The following actions will be performed as a result of the ESEP.

Equipment Action # Equipment ID Description Action Description Completion Date 31 Fire Water Modify tank and anchorage such As described in 1 FP-T-1 Storage Tank that HCLPF>RLGM Section 8.3 2 FP-T-2 32 Fire Water Modify tank and anchorage such As described in Storage Tank that HCLPF>RLGM Section 8.3 Submit a letter to NRC summarizing the HCLPF results of Within 60 days Items I and 2 confirming following 3 N/A N/A implementation of the plant completion of ESEP modifications associated with activities, including items 1 and 2.

Page 23

For Information Only Indian Point Unit 3 ESEP Report

9.0 REFERENCES

1. NRC (E Leeds and M Johnson) Letter to All Power Reactor Licensees et al., "Request for Information Pursuant to Title 10 of the Code of Federal Regulations 50.54(f) Regarding Recommendations 2.1, 2.3 and 9.3 of the Near-Term Task Force Review of Insights from the Fukushima Dai-lchi Accident," March 12, 2012.

2. EPRI 3002000704, "Seismic Evaluation Guidance, Augmented Approach for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1: Seismic," May 2013.

3. Entergy Letter to U.S. NRC, letter number NL-13-042 "Overall Integrated Plan in Response to March 12, 2012, Commission Order to Modify Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events (Order Number EA-12-049),"

February 28, 2013, NRC ADAMS Accession No. ML13079A348.

4. Entergy Letter to U.S. NRC, letter number NL-14-031, "Indian Point Energy Center's Second Six-Month Status Report for the Implementation of Order EA-12-049 Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events,"

February 27, 2014, NRC ADAMS Accession No. ML14070A365.

5. Entergy Letter to U.S. NRC, letter number NL-14-110, "Indian Point Energy Center's Third Six-Month Status Report for the Implementation of Order EA-12-049 Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events,"

August 27, 2014, NRC ADAMS Accession No. ML14251A227.

6. Entergy Engineering Evaluation, EC No. 45874, Revision 1, "FLEX-Beyond Design Basis External Event Phases I, II, and III Strategy Development Evaluation."

7. Entergy Drawing 9321-F-20173, Revision 72, "Flow Diagram Main Steam."

8. Entergy System Design Description 21.2, Revision 8, "System Description 21.2, Auxiliary Feedwater System."

9. Entergy Drawing 9321-F-70313, Revision 17, "Auxiliary Boiler Feed Pump Room Instrument Piping Sheet No.1 Instrumentation."

10. Entergy Drawing 9321-F-27233, Revision 40, "Flow Diagram Nitrogen to Nuclear Equipment."

11. Entergy Plant Equipment Database for Indian Point Unit 3.

12. Entergy Drawing 9321-F-20193, Revision 62, "Flow Diagram Boiler Feedwater."

13. Entergy Drawing 9321-LD-72123, Sheet 9, Revision 2, "Aux. F.W. Flow to Steam Generator #31 Loop F-1200 Diagram."

14. Entergy Drawing 9321-LD-72123, Sheet 10 Revision 2, "Aux. F.W. Flow to Steam Generator #32 Loop F-1201 Diagram."

15. Entergy Drawing 9321-LD-72123, Sheet 11, Revision 2, "Aux. F.W. Flow to Steam Generator #33 Loop F-1202 Diagram."

16. Entergy Drawing 9321-LD-72123, Sheet 12, Revision 2, "Aux. F.W. Flow to Steam Generator #34 Loop F-1203 Diagram."

17. Entergy Drawing 9321-F-31673, Revision 28, "Wiring Diagram 480V Switchgear Miscellaneous."

Page 24

For Information Only Indian Point Unit 3 ESEP Report

18. Entergy Drawing 9321-F-70033, Revision 17, "Transmitter Racks Piping Arrangement - Sheet No. 2 Instrumentation for Indian Point Energy Center Unit No. 3."

19. Entergy System Design Description 21.1, Revision 4, "System Description 21.1, Steam Generator Water Level Control."

20. Entergy Drawing 9321-F-70253, Revision 10, "Primary Plant Instrument Piping & Supports -

Sheet No. 1 Instrumentation."

21. Entergy Drawing 9321-H-39903 Sheet 70, Revision 5, "Rack D-9 Layout."

22. Entergy Drawing 9321-F-32273, Revision 41, "Wiring Diagram Supervisory Control Panel SC."

23. Entergy Drawing 9321-F-70513, Revision 17, "Transmitter Racks Piping Arrangement - Sheet No. 4 Instrumentation."

24. Entergy Drawing 9321-F-10023, Revision 22, "Plot Plan."

25. Entergy Drawing 9321-F-20183 Sheet 1, Revision 63, "Flow Diagram Condensate & Boiler Feed Pump Suction."

26. Entergy Drawing 9321-F-27353, Revision 42, "Flow Diagram Safety Injection System Sheet No.

1."

27. Entergy System Design Description 10.1, Revision 10, "System Description 10.1, Safety Injection System."

28. Entergy System Design Description 3.0, Revision 8, "System Description 3.0, Chemical and Volume Control System."

29. Entergy System Design Description 4.2, Revision 7, "System Description 4.2, Residual Heat Removal System:"

30. Entergy System Design Description 1.4, Revision 7, "System Description 1.4, Pressurizer &

Pressurizer Relief Tank."

31. Entergy Drawing 9321-F-33853, Revision 19, "Electrical Distribution & Transmission System."

32. Entergy Drawing 9321-F-30063 Sheet 1, Revision 81, "Single Line Diagram 480V Motor Control Center No.'s 36A, 36B & 36C."

33. Entergy Drawing 9321-F-27363, Revision 52, Flow Diagram Chemical & Volume Control System Sheet No. 1."

34. Entergy Drawing 9321-F-27513 Sheet 1, Revision 31, "Flow Diagram Auxiliary Coolant System In PAB & FSB Sheet No. 1."

35. Entergy Drawing 9321-F-27503, Revision 55, "Flow Diagram Safety Injection System Sheet No.

2."

36. Entergy Drawing 9321-F-27203, Revision 29, "Flow Diagram Auxiliary Coolant System Inside Containment."

37. Entergy Drawing 9321-F-27473, Revision 43, "Flow Diagram Reactor Coolant System Sheet No.

2."

Page 25

For Information Only Indian Point Unit 3 ESEP Report

38. Entergy Drawing 9321-F-36383, Revision 4, "Miscellaneous Wiring Details RCS-SOV-652, RCS-SOV-653, RCS-SOV-654, & RCS-SOV-655."

39. Entergy Drawing 9321-F-30053, Revision 72, "Single Line Diagram 480V Motor Control Centers 37, 38, 39, & 311."

40. Entergy Drawing 9321-F-30083, Revision 60, "Single Line Diagram D.C. System."

41. Entergy Drawing IP3V-0454-0041, Revision 1, Structural Detail for Seismic Category 1 Instrument Rack."

42. Entergy Calculation IP-CALC-07-00154, Revision 0, "Containment Atmospheric Temperature."

43. Entergy Drawing 9321-F-33433, Revision 7, "Containment Parameters System Wiring Diagram."

44. Entergy Drawing 9321-H-39913 Sheet 8, Revision 8, "External Connection Diagram R.P.S. Rack No. 8 (A-7)."

45. Entergy Drawing 9321-H-36723, Revision 0, "Cover Plates on Flight Pnl. "FCF" & Supervisory Pnl.

"SCF" - Fabrication Mounting Details."

46. Entergy Drawing 9321-F-20303, Revision 30, "Flow Diagram Fuel Oil to Diesel Generators."

47. Entergy Drawing 9321-F-39893, Revision 43, "Single Line Diagram 118VAC Instrument Buses 31, 31A, 32, 32A, 33, 33A, 34, & 34A."

48. Entergy Document IP3-RPT-UNSPEC-02182, Indian Point Three Nuclear Power Plant Individual Plant Examination of External Events," September 1997.

49. Entergy Drawing 9321-F-32723, Revision 28, Wiring Diagram Flight Control Pnl. FCF & FCR."

50. Entergy Drawing 9321-LD-72453 Sheet 21A, Revision 2, "Overpressurization System Channel 1 Loop P/T-413 Diagram."

51. Entergy Drawing 9321-LD-72453 Sheet 23A, Revision 2, "Overpressurization System Channel 4 Loop P/T-443 Diagram."

52. Entergy Drawing 9321-LD-72453 Sheet 21, Revision 3, "Overpressurization System Channel 1 Loop P/T-413 Diagram."

53. Entergy Drawing 9321-LD-72453 Sheet 23, Revision 3, "Overpressurization System Channel 4 Loop P/T-443 Diagram."

54. Entergy Drawing 9321-F-27383, Revision 28, "Flow Diagram Reactor Coolant System Sheet No.

1."

55. Entergy Drawing 9321-LL-36853, Sheet 1, Revision 3, "Schematic Block Diagram Reactor Vessel Level Instrument System Train "A"."

56. Entergy Drawing 9321-F-33203, Sheet 1, Revision 24, "Conduit & Tray Connection Schematic Containment Building."

57. Entergy Drawing 9321-F-33313, Sheet 2, Revision 6, "Conduit & Tray Connection Schematic Fan House."

58. Entergy Drawing 9321-F-30793, Revision 50, "Conduit Layout Containment Building Piping Penetration Area - Fan House."

Page 26

For Information Only Indian Point Unit 3 ESEP Report

59. Entergy Drawing 9321-F-72043, Revision 7, "Containment Building Reactor Vessel Level Instrumentation System Flow Diagram."

60. Entergy Drawing 9321-F-70283, Revision 25, Containment Building Instrument Arrangement Sheet No. 2 Instrumentation."

61. Entergy Drawing 9321-F-39933, Revision 19 "Conduit Layout TSI Room, CFM Multiplexer Room, Control Building EL. 53'-0" & Roof El. 72'-7."

62. Entergy Drawing 9321-F-95273 Sheet 1, Revision 6, "Control Room RVLIS Rack -Train "A" Interconnection Wiring Diagram."

63. Entergy Procedure 3-ECA-0.0, Revision 9, "Loss of All AC Power."

64. Entergy Drawing 9321-F-32383, Revision 31, "Wiring Diagram Supervisory Control Panel SB2."

65. Entergy System Design Description 1.1, Revision 5, "System Description 1.1, Reactor Coolant System."

66. Entergy Drawing IP3V-0245-0001, Revision 0, "40'-0" OD x 40'-0" High Fire Protection Water Storage Tanks "FP-Tk-1" & "FP-Tk-2" Pipe Support Details."

67. Entergy System Design Description 18.0, Revision 7, "System Description 18.0, Main and Reheat Steam."

68. EPRI 1025287, "Seismic Evaluation Guidance: Screening, Prioritization and Implementation Details (SPID) for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1:

Seismic. Electric Power Research Institute," February 2013.

69. Entergy Letter NL-14-043, John A. Ventosa to NRC, "Entergy Seismic Hazard and Screening Report (CEUS Sites), Response to NRC Request for Information Pursuant to 10 CFR 50.54(f)

Regarding Recommendation 2.1 of the Near-Term Task Force Review of Insights from the Fukushima Dai-ichi Accident dated March 31, 2014." NRC ADAMS Accession No. ML14099A111.

70. "Indian Point Energy Center Unit 3 Updated Final Safety Analysis Report," Revision 5, Docket No. 50-286, 2013.

71. EPRI-NP-6041-SL, "Methodology for Assessment of Nuclear Power Plant Seismic Margin,"

Revision 1, August 1991.

72. EPRI TR-103959, "Methodology for Developing Seismic Fragilities," July 1994.

73. NRC NUREG-1407, "Procedural and Submittal Guidance for the Individual Plant Examination of External Events (IPEEE) for Severe Accident Vulnerabilities," June 1991.

74. SQUG, "Generic Implementation Procedure (GIP) for Seismic Verification of Nuclear Plant Equipment, Seismic Qualification Utility Group," Revision 3A, December 2001.

75. NRC (E. Leeds) Letter to All Power Reactor Licensees et al., "Screening and Prioritization Results Regarding Information Pursuant to Title 10 of the Code of Federal Regulations 50.54(F)

Regarding Seismic Hazard Re-Evaluations for Recommendation 2.1 of the Near-Term Task Force Review of Insights From the Fukushima Dai-Ichi Accident," May 9, 2014.

Page 27

For Information Only Indian Point Unit 3 ESEP Report

76. Nuclear Energy Institute (NEI), A. Pietrangelo, Letter to D. Skeen of the USNRC, "Seismic Core Damage Risk Estimates Using the Updated Seismic Hazards for the Operating Nuclear Plants in the Central and Eastern United States," March 12, 2014.

77. Nuclear Energy Institute (NEI), A. Pietrangelo, Letter to D. Skeen of the USNRC, "Proposed Path Forward for NTTF Recommendation 2.1: Seismic Reevaluations," April 9, 2013, NRC ADAMS Accession No. ML13101A379.

78. NRC (E Leeds) Letter to NEI (J Pollock), "Electric Power Research Institute Final Draft Report xxxxx, "Seismic Evaluation Guidance: Augmented Approach for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1: Seismic," as an Acceptable Alternative to the March 12, 2012, Information Request for Seismic Reevaluations," May 7, 2013.

79. Entergy Document EC54071, "ESEP Reports," the following AREVA documents are captured in the plant document management system:

a. AREVA Document 51-9212951-007, "ESEP Expedited Seismic Equipment List (ESEL) -

Indian Point Unit 3."

b. AREVA Calculation 32-9227208-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Station Service Transformers 2, 3, 5, and 6."

c. AREVA Calculation 32-9227381-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Battery Bank 33 (BATT 33)."

d. AREVA Calculation 32-9227576-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Battery Chargers 31, 32, & 34."

e. AREVA Calculation 32-9230353-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Refueling Water Storage Tank, RWST-31."

f. AREVA Calculation 32-9230692-000, "Indian Point Unit 3 ESEP HCLPF Calculation - RCS Overpressure Racks H-1 and H-3."

g. AREVA Document 32-9232897-000, "Indian Point Unit 3 ESEP Calculation - Fire Water Storage Tanks FP-T-1 and FP-T-2."

h. AREVA Calculation 32-9238938-000, "Indian Point Unit 3 ESEP HCLPF Calculation -

Residual Heat Exchangers ACAHRS1 and ACAHRS2."

Page 28

For Information Only Indian Point Unit 3 ESEP Report ATTACHMENT A - INDIAN POINT UNIT 3 ESEL Page A-1

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 1 MS452 Steam Generator 32 Safety Closed Open [7]

Relief Valve 2 MS45-3 Steam Generator 33 Safety Closed Open [7]

Relief Valve 3 PCV-1135 ATM Steam Relief Valve 32 17]

Steam Generator Closed Cycled [

4 PCV-1136 ATM Steam Relief Valve 33 Closed Cycled [

Steam Generator 5 PNL #1 ATM Steam Dump Panel #1 On On [9][67]

6 PNL #2 ATM Steam Dump Panel #2 On On [9][67]

7 32 ABFP Turbine Driven Auxiliary Standby Operating [7][12][8]

Feedwater Pump No. 32 Pressure Control Valve for 8 BFD-PCV-1213 Closed Open [12][8]

Bearing Cooler 9 HCV-1118 32 AFW Pump Turbine Closed Open [10][8]

Governor Main Steam to AFW Turbine 10 MS-PCV-1139 Closed Open [7][8]

PCV 32 Auxiliary Boiler Feed Fails open on loss of instrument air or 11 MS-PCV-1310A Pump Steam Supply First Closed Open manually open per procedure [7][63][8]

Isolation 32 Auxiliary Boiler Feed Fails open on loss of instrument air or 12 MS-PCV-1310B Pump Steam Supply Second Closed Open manually open per procedure [7][63][8]

Isolation 13 PNL PT2 Auxiliary Boiler Feed Pump Off On [17][8]

Control Station Page A-2

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 14 FT-1201 AFW to SG 32 Flow Off On [12][14]

Transmitter 15 FT-1202 AFW to SG 33 Flow Off On [12][15]

Transmitter 16 FI-1201 AFW to SG 32 Flow Indicator On On [12][14]

17 FI-1202 AFW to SG 33 Flow Indicator On On [12][15]

Pressure Transmitter Rack On On [18][13][14]

18 RACK26

26 [15][16]

[21]

19 RACK D-9 CCR Rack u 9 (NIS MISC On On [13][14][15]

Instrument) [16]

PNL SC Condenser & Feedwater [22]

20 Supervisory Supervisory Panel On On [13][14][15]

Panel [16]

No. 32 AFW Pump Manual Per Local Equipment Procedure 21 BFD-FCV-405B Flow Control to 32 SG Closed Open Manually Open Valves [12][8]

22 BFD-FCV-405C No. 32 AFW Pump Manual Closed Open Per Local Equipment Procedure 22_______B F 4 Flow Control to 33 SG Manually Open Valves [12][8]

23 LT-427D SG 32 Level Transmitter On On -[12][23][19 24 LT-437D SG 33 Level Transmitter On On - [12][23][19]

_________ 1]20]-

25 LI-427D SG 32 Level Indicator On On - [19]

26 LI-437D SG 33 Level Indicator On On - [19]

Page A-3

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 27 RACK 21 Steam Generators Level On On [23][20]

Transmitter Rack 28 PT-429C SG 32 Steam Pressure On On [7][18]

Transmitter 29 PT-439C SG 33 Steam Pressure On On [7][18]

Transmitter 30 PI-1354 SG 32 Steam Pressure On On Indication in AFW Pump Local Control [7]

Indicator Station 31 P1-1355 SG 33 Steam Pressure On On Indication in AFW Pump Local Control [7]

Indicator Station 32 RACK 9 Instrument Rack 9 Operating Operating [18]

33 CST Condensate Storage Tank Available Available [24][25]

34 LI 1102-S CST Level Indicator Operating Operating [25]

35 LCV-1158-2 CST Low Level Control Valve Open Closed [25]

CST to Condensers Level 36 LCV-1158-1 Control Valve Open Closed [25]

No. 31 Accumulator Isolation 37 SI-MOV-894A No. Open Closed [26][27]

ValIve No. 32 Accumulator Isolation 38 SI-MOV-894B No. Open Closed [26][27]

ValIve No. 33 Accumulator Isolation 39 SI-MOV-894C No. Open Closed [26][27]

Val ve 40 SI-MOV-894D No. 34 Accumulator Isolation Open Closed [26][27]

Valve Page A-4

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description

_____Notes/Comments Normal State Desired State References 41 36AMCC Primary Auxiliary Building On On [31][32]

Motor Control Center 36A 42 36BMCC Primary Auxiliary Building On On [31][32]

Motor Control Center 36B 43RCP Seal Valve Isolation Water Return Open Closed Per Loss of Manually All AC Close Power Procedure Valves [33][63]

Thermal Barrier Isolation Per Loss of All AC Power Procedure [34][631 A-FC-44 5 ThermValve Open Closed Manually Close Valves 45 RWST-31 Refueling Water Storage Available Available - [35]

Tank 46 ACAHRS1 RHR HTEXCH # 31 Intact Intact Gravity feed path from RWST through [36][29]

heat exchanger 47 ACAHRS2 RHR HTEXCH # 32 Intact Intact Gravity feed path from RWST through [36][29]

heat exchanger 48 RCS-SOV-652 Reactor Head Vent Closed Open 125VDC Distribution Panel 32A [37][38][65]

49 RCS-SOV-653 Reactor Head Vent Closed Open 125VDC Distribution Panel 32A [37][38][65]

50 PNL SBF-1 Supervisory Panel SBF1 On On - [38]

51 EHT Panel 34 Electric Heat Trace Panel 34 On On Powered by MCC 37 [39]

480VAC Bus 6A feeds to Primary 52 37MCC PrimaryControl Motor Auxiliary Building Center 37 On On Auxiliary Building 480V MCC 37 which [31][39]

powers Battery Charger 32 125 VDC Distribution Panel 53 PNL K49 32A On On [31][40]

54 PT-1421 CTMT Pressure Transmitter On On [35][41]

Page A-5

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal

___________________________________Notes/Comments State Desired State References 55 PR-1421 CTMT Pressure Recorder On On [43]

56 TE-1416-1 Fan 31 Temperature Element On On [44][42]

57 TE-1416-2 Fan 32 Temperature Element On On [44][42]

58 TE-1416-3 Fan 33 Temperature Element On On [44][42]

59 TE-1416-4 Fan 34 Temperature Element On On [44][42]

60 TE-1416-5 Fan 35 Temperature Element On On [44][42]

61 RACK 24A Instrument Rack On On [41]

EDG-31-FO-62 STNK Fuel Oil Storage Tank 31 Available Available [46][48]

EDG-32-FO-63 STNK Fuel Oil Storage Tank 32 Available Available [46][48]

EDG-33-FO-64 STNK Fuel Oil Storage Tank 33 Available Available [46][48]

118V AC Instrument Bus 31 65 311B Channel II On On [31][47]

66 32113 118V AC Instrument Bus 32 On On [31][471 Channel I 67 34113 118V AC Instrument Bus 34 On On [31][47]

Channel III 68 331B 118V AC Instrument Bus 33 On [31][47]

Channel IV On [

Page A-6

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 118V AC Instrument Bus 31A 69 31AIB CanlOn On -[31][471 Channel I 7032AIB 7032AIB

~~118V AC Instrument Bus 32A

~Channel O nO n[1[7

[1[7 71 34A1B 118V AC Instrument Bus 34A On On -31][47]

Channel III 72 33AIB 118V AC Instrument Bus 33A On On [31][47]

Channel IV 73 34 iNVERTER Static Inverter 34 On On [31][40][48]

74 33 INVERTER Static Inverter 33 On On [31][40][48]

75 31 INVERTER Static Inverter 31 On On [31][40][48]

76 32 INVERTER Static Inverter 32 On On [31][40][48]

77 31DP 125VDC Distribution Panel 31 On On [31][40][48]

78 32DP 125VDC Distribution Panel 32 On On [31][40]

79 33DP 125VDC Distribution Panel 33 On On [31][40][48]

80 34DP 125VDC Distribution Panel 34 On On [31][40][48]

81 PNLK48 125 VDC Distribution Panel On n [31][40][48]

31A 82 31PP 125VDC Power Panel 31 On On [31][40][48]

Page A-7

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 83 32PP 125VDC Power Panel 32 On On [31][40][48]

84 33PP 125VDC Power Panel 33 On On [31][40][48]

85 34PP 125VDC Power Panel 34 On On [31][40][48]

86 BATT CHGR 31 Battery Charger 31 On On [31][40]

87 BATT CHGR 32 Battery Charger 32 On On [31] [40]

88 BATT CHGR 33 Battery Charger 33 On On [31][40]

89 BATT CHGR 34 Battery Charger 34 On On [31][401 90 BAT- 31 Battery Bank 31 On On [31] [40]

91 BATT 32 Battery Bank 32 On On [31][40]

92 BATT 34 Battery Bank 34 On On [31][40]

93 BATT 33 Battery Bank 33 On On [31][40]

94 BUS2A 48OV(SWGR 31) Bus 2A On On [31]

95 BUS3A 480V(SWGR 32) Bus 3A On On [31]

96 BUSSA 480V(SWGR31) Bus 5A On On [31]

Page A-8

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 97 BUS6A 480V(SWGR 32) Bus 6A On On [31]

98 36CMCC Primary Auxiliary Building On On [31]

Motor Control Center 36C 99 39MCC Control Building Motor On On [31]

Control Center 39 100 32MCC Turbine-Generator Building On On [31]

Motor Control Center 32 101 NI 31B Source Range Count Rate On On [48]

Meter 102 NI 31D Source Range Count Rate On On [48]

Meter 103 FE1 Preamplifier For NE-31 On On [48]

104 PNL FCF Flight Control Panel FC On On [48][49]

105 PI-413K Loop 31 Hot Leg Pressure On On [50]

Indicator 106 PI-443K Loop 34 Hot Leg Pressure On On [51]

Indicator 107 PT-413 Loop 31 Hot Leg Pressure On On [52][54]

Transmitter 108 PT-443 Loop 34 Hot Leg Pressure On On [53][54]

Transmitter 109 TE-1313 Upper Tap Compensation On On [59]

Temperature Element 110 TE-1314 Upper Tap Compensation On On [59]

Temperature Element Page A-9

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 111 TE-1317 RVWL Conduit Compensation On On [59]

Temperature Element 112 TE-1318 RVWL Conduit Compensation On On [59]

113 TE-1319 RVWL Lower Tap Capillary On On [59]

Temperature Element 114 TE-413A RCS Loop 31 Hot Leg Wide on On [60]

Range Temperature Element 115 TE-423A RCS Loop 32 Hot Leg Wide On On [48][60]

Range Temperature Element 116 CAB JR9 RVLIS Cabinet On On [48][61][62]

117 LI-1311 RVWL Narrow Range On On [48]

Indicator 118 LI-1312 RVWL Wide Range Indicator On On [48]

119 LT-1311 Reactor Vessel Level On On [48][59]

Transmitter Narrow Range 120 LT-1312 Reactor Vessel Level On On [48][59]

Transmitter Narrow Range 121 TI-1416 Containment Atmospheric On On [44]

Temperature Indicator 122 PM-413K Loop 31 Hot Leg Pressure On On [50]

Containment Parameters 123 31AIB-2 (101) Recording Cabinet (Channel On On [43]

I) 124 PM-443K Loop 34 Hot Leg Pressure On On [51]

Page A-l0

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 125 PC-413 Loop 31 Hot Leg Pressure On On [52]

126 PC-443 Loop 34 Hot Leg Pressure On On [53]

127 PQ-413 Loop 31 Hot Leg Pressure On On [52]

128 PQ-443 Loop 34 Hot Leg Pressure On On [53]

129 PNL SBF-2 Supervisory Control Panel SB- On On [64]

2 130 RACK Hi CCR Auxiliary Panel Analog On On [52]

Rack H1 131 RACK H3 CCR Auxiliary Panel Analog On On [53]

Rack H3 132 Panel 5FF Supervisory Panel SF On On [50][51]

133 RVLIS RACK RVLIS Rack Train A On On [48][59]

TRAIN A 134 MS-45-1 Steam Generator 31 Safety Closed Open [7]

Relief Valve 135 MS-45-4 Steam Generator 34 Safety Closed Open [7]

Relief Valve 136 PCV-1134 ATM Steam Relief Valve 31 Closed Cycled Manual Operation [7]

Steam Generator 137 PCV-1137 ATM Steam Relief Valve 34 Closed Cycled Manual Operation [7]

Steam Generator 138 N2TANKS Backup Nitrogen Cylinders Intact Intact [67][9]

Page A-11

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State

________________Notes/Comments Desired State References 139 IA-PCV-1278 Nitrogen Pressure Regulator Closed Open [67][9][10]

Nitrogen Pressure Regulator Closed Open [67][9][10]

140 IA-PCV-1277 1____________ [11]

141 MS-577 32 AFW Pump Overspeed Intact Intact Part of the TDAFWP Skid [8][11]

Trip & Governor Valve 142 FT-1200 AFW to SG 31 Flow Off On [12][13]

Transmitter 143 FT-1203 AFW to SG 34 Flow Off On [12][16]

Transmitter 144 FI-1200 AFW to SG 31 Flow Indicator On On [12][13]

145 FI-1203 AFW to SG 34 Flow Indicator On On [12][16]

146 BPD-FCV-405A No. 32 AFW Pump Manual Closed Open Manually Open Valves [121 Flow Control to 31 SG 147 BFD-FCV-405D No. 32 AFW Pump Manual Closed Open Manually Open Valves [12]

Flow Control to 34 SG LT-417D SG 31 Level Transmitter On On [12][23][19]

148

[11][20]

149 LT-447D SG 34 Level Transmitter On On [12][23][19]

[11][20]

150 LI-417D SG 31 Level Indicator On On [19]

151 LI-447D SG 34 Level Indicator On On [19]

152 LQ-417D Steam Generator Level On On [11]

Page A-12

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 153 LQ-427D Steam Generator Level On On [11]

154 LQ-437D Steam Generator Level On On [11]

155 LQ-447D Steam Generator Level On On [11]

156 RACK B10 Instrument Rack On On [11]

157 RACK B5 Instrument Rack On On [11]

158 P1-1353 SG 31 Steam Pressure On On Local Indication [7]

Indicator 159 P1-1356 SG 34 Steam Pressure On On Local Indication [7]

Indicator 160 ACCUM. 31 Accumulator Tank 31 Intact Intact [26][27][11]

161 ACCUM. 32 Accumulator Tank 32 Intact Intact [26][27][11]

162 ACCUM. 33 Accumulator Tank 33 Intact Intact [26][27][11]

163 ACCUM. 34 Accumulator Tank 34 Intact Intact [26][27][11]

164 CH-LCV-459 Letdown Isolation Valve Open Closed Fail Closed on Loss of instrument air [28][11]

165 CH-HCV-133 RHR LP Bypass Valve Open Closed - [28][11]

166 MOV-882 RHR Pump Suction Isolation Closed Open Powered from MCC 36B [29]

Valve Page A-13

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 167 LT-459 Pressurizer Level Transmitter On On [30]

168 LI-459A Pressurizer Level Indicator On On [301 169 LM-459A Pressurizer Level On On [11]

170 Rack A4 CCR Rack A4 On On [11]

171 Rack 19 Instrument Rack On On [11]

172 Y39 Terminal Box Intact Intact [55]

173 Y32 Terminal Box Intact Intact [55]

174 Y36 Terminal Box Intact Intact [55][56]

175 LIS-1311 Hydraulic Isolators Intact Intact [55][11]

176 LIS-1312 Hydraulic Isolators Intact Intact [55][11]

177 Y29 Terminal Box Intact Intact [55][57][58]

178 PNL SN Supervisory Panel SN (JB9) On On [55]

179 PT-402 Pressure Transmitter On On [55]

180 RACK 22 (C9) Instrument Rack On On [55][11]

Page A-14

For Information Only Indian Point Unit 3 ESEP Report Equipment Operating State ESEL Item Number ID Description Normal State Desired State Notes/Comments References 181 RACK 6 (A9) Instrument Rack On On - [55][11]

182 TDAFWP Turbine Standby Operating Part of the TDAFWP skid [7][12][8]

183 -TDAFWP Lube Oil Coolers Standby Operating Part of the TDAFWP skid [7][12][8]

184 TC-1416-1 Temperature Converter On On [42]

185 TC-1416-2 Temperature Converter On On [42]

186 TC-1416-3 Temperature Converter On On [42]

187 TC-1416-4 Temperature Converter On On [42]

188 TC-1416-5 Temperature Converter On On [42]

189 Rack A-7 CCR Rack A-7 On On [42]

190 FP-T-1 31 Fire Water Storage Tank Intact Intact - [66]

191 FP-T-2 32 Fire Water Storage Tank Intact Intact - [66]

192 PW-S-TK 31 Primary Water Storage Intact Intact - [11]

Tank 193 Rack B4 CCR Rack B-4 On On - [11]

Page A-15

For Information Only Indian Point Unit 3 ESEP Report ATTACHMENT B - ESEP HCLPF VALUES AND FAILURE MODES TABULATION Page B-i

For Information Only Indian Point Unit 3 ESEP Report Item HCLPF (g) / Failure Equipment Description Screening Mode Comments No. Equipment ID Level 1 MS-45-2 Steam Generator 32 >RLGM Screened Safety Relief Valve 2 MS-45-3 Steam Generator 33 >RLGM Screened Safety Relief Valve 3 PCV-1135 ATM Steam Relief Valve >RLGM Screened 32 Steam Generator 4 PCV-1136 ATM Steam Relief Valve >RLGM Screened 33 Steam Generator 5 PNL#1 ATM Steam Dump Panel >RLGM Screened Note 2

1 6 PNL #2 ATM Steam Dump Panel >RLGM Screened Note 2

2 7 32 ABFP Turbine Driven Auxiliary >RLGM Screened Note 1 Feedwater Pump No. 32 Pressure Control Valve for 8 BFD-PCV-1213 >RLGM Screened Bearing Cooler 9 HCV-1118 32 AFW Pump Turbine >RLGM Screened Governor 10 MS-PCV-1139 Main Steam to AFW >RLGM Screened Turbine PCV 32 Auxiliary Boiler Feed 11 MS-PCV-1310A Pump Steam Supply First >RLGM Screened Isolation 32 Auxiliary Boiler Feed 12 MS-PCV-1310B Pump Steam Supply >RLGM Screened Second Isolation 13 PNL PT2 Auxiliary Boiler Feed >RLGM Screened Note 1 Pump Control Station 14 FT-1201 AEW to SG 32 Flow >RLGM Screened Transmitter 15 FT-1202 AFW to SG 33 Flow Transmitter 16 FI-1201 AFW to SG 32 Flow >RLGM Screened Indicator 17 FI-1202 AEW to SG 33 Flow >RLGM Screened Indicator 18 RACK 26 Pressure Transmitter Rack >RLGM Screened Note 2

26 19 RACK D-9 CCR Rack "D9" (NIS MISC >RLGM Screened Note 2 Instrument)

PNL SC Condenser & Feedwater 20 Supervisory Supervisory>RLGM Screened Note 2 Panel SupervisoryPanel Page B-2

For Information Only Indian Point Unit 3 ESEP Report Item HCLPF (g) / Failure Equipment Description Screening Mode Comments No. Equipment ID Level 21 BFD-FCV-405B No. 32 AFW Pump Manual >RLGM Screened Flow Control to 32 SG 22 BFD-FCV-405C No. 32 AFW Pump Manual >RLGM Screened Flow Control to 33 SG 23 LT-427D SG 32 Level Transmitter >RLGM Screened Note 3 24 LT-437D SG 33 Level Transmitter >RLGM Screened Note 3 25 LI-427D SG 32 Level Indicator >RLGM Screened 26 LI-437D SG 33 Level Indicator >RLGM Screened 27 RACK 21 Steam Generators Level >RLGM Screened Note 3 Transmitter Rack 28 PT-429C SG 32 Steam Pressure >RLGM Screened Transmitter 29 PT-439C SG 33 Steam Pressure >RLGM Screened Transmitter 30 P1-1354 SG 32 Steam Pressure >RLGM Screened Indicator 31 P1-1355 SG 33 Steam Pressure >RLGM Screened Indicator 32 RACK 9 Instrument Rack 9 >RLGM Screened Note 2 33 CST Condensate Storage Tank >RLGM Screened Note 1 34 LI 1102-S CST Level Indicator >RLGM Screened 35 LCV-1158-2 CST Low Level Control >RLGM Screened Valve 36 LCV-1158-1 CSTto Condensers Level >RLGM Screened Control Valve 37 SI-MOV-894A No. 31 Accumulator >RLGM Screened Note 3 Isolation Valve 38 SI-MOV-894B No. 32 Accumulator >RLGM Screened Note 3 Isolation Valve 39 SI-MOV-894C No. 33 Accumulator >RLGM Screened Note 3 Isolation Valve 40 SI-MOV-894D No. 34 Accumulator >RLGM Screened Note 3 Isolation Valve 41 36AMCC Primary Auxiliary Building >RLGM Screened Note 1 Motor Control Center 36A Page B-3

For Information Only Indian Point Unit 3 ESEP Report Item HCLPF (g) Failure Equipment Description Screening Mode Comments No. Equipment ID Level 42 36BMCC Primary Auxiliary Building >RLGM Screened Note 1 Motor Control Center 36B 43 CH-MOV-222 RCP Seal Water Return >RLGM Screened Isolation Valve Thermal Barrier Isolation 44 AC-FCV-625 Val Valve >RLGM Screened 45 RWST-31 Refueling Water Storage 0.41 Tank Tank Sloshing Steel 46 ACAHRS1 RHR HTEXCH # 31 0.35 Pl Platform Note 3 Steel 47 ACAHRS2 RHR HTEXCH # 32 0.35 Note 3 Platform 48 RCS-SOV-652 Reactor Head Vent >RLGM Screened Note 3 49 RCS-SOV-653 Reactor Head Vent >RLGM Screened Note 3 50 PNL SBF-1 Supervisory Panel SBF1 >RLGM Screened Note 2 51 EHT Panel 34 Electric Heat Trace Panel >RLGM Screened 34 52 37MCC Primary Auxiliary Building >RLGM Screened Note 1 Motor Control Center 37 53 PNL125 VDC Distribution >RLGM Screened Note 2 Panel 32A 54 PT-1421 CTMT Pressure >RLGM Screened Transmitter 55 PR-1421 CTMT Pressure Recorder >RLGM Screened 56 TE-1416-1 Fan 31 Temperature >RLGM Screened Note 3 Element 57 TE-1416-2 Fan 32 Temperature >RLGM Screened Note 3 Element 58 TE-1416-3 Fan 33 Temperature >RLGM Screened Note 3 Element 59 TE-1416-4 Fan 34 Temperature >RLGM Screened Note 3 Element 60 TE-1416-5 Fan 35 Temperature >RLGM Screened Note 3 Element 61 RACK 24A Instrument Rack >RLGM Screened Note 2 62 EDG-31-FO- Fuel Oil Storage Tank 31 >RLGM Screened Note 2 STNPK Page B-4

For Information Only Indian Point Unit 3 ESEP Report Item HCLPF (g) ' Failure Equipment Description Screening Mode Comments No. Equipment ID Level 63 EDG-32-FO- Fuel Oil Storage Tank 32 >RLGM Screened Note 2 STNK 64 EDG-33-FO- Fuel Oil Storage Tank 33 >RLGM Screened Note 2 STNK 65 311B 118V AC Instrument Bus >RLGM Screened Note 2 31 Channel II 66 321B 118V AC Instrument Bus >RLGM Screened Note 2 32 Channel I 67 341B 118V AC Instrument Bus >RLGM Screened Note 2 34 Channel III 68 331B 118V AC Instrument Bus >RLGM Screened Note 2 33 Channel IV 69 31AIB 118V AC Instrument Bus >RLGM Screened Note 2 31A Channel II 70 32AIB 118V AC Instrument Bus >RLGM Screened Note 2 32A Channel 1 71 34A1B 118V AC Instrument Bus >RLGM Screened Note 2 34A Channel III 72 33AIB 118V AC Instrument Bus >RLGM Screened Note 2 33A Channel IV 73 34 INVERTER Static Inverter 34 >RLGM Screened Note 1 74 33 INVERTER Static Inverter 33 >RLGM Screened Note 2 75 31 INVERTER Static Inverter 31 >RLGM Screened Note 2 76 32 INVERTER Static Inverter 32 >RLGM Screened Note 2 77 31DP 125VDC Distribution Panel >RLGM Screened Note 2 31 78 32DP 125VDC Distribution Panel >RLGM Screened Note 2 32 79 33DP 125VDC Distribution Panel >RLGM Screened Note 2 33 80 34DP 12SVDC Distribution Panel >RLGM Screened Note 2 34 81 PNLK48 125 VDC Distribution >RLGM Screened Note 2 Panel 31A 82 31PP 125VDC Power Panel 31 >RLGM Screened Note 2 83 32PP 125VDC Power Panel 32 >RLGM Screened Note 2 Page B-5

For Information Only Indian Point Unit 3 ESEP Report HCLPF (g) F No. Equipment ID Equipment Description Screening Made Comments Level 84 33PP 125VDC Power Panel 33 >RLGM Screened Note 2 85 34PP 125VDC Power Panel 34 >RLGM Screened Note 2 86 BATT CHGR 31 Battery Charger 31 0.36 Anchorage 87 BATT CHGR 32 Battery Charger 32 0.36 Anchorage 88 BATT CHGR 33 Battery Charger 33 >RLGM Screened Note 1 89 BATT CHGR 34 Battery Charger 34 0.36 Anchorage 90 BATT 31 Battery Bank 31 >RLGM Screened Note 1 91 BATT 32 Battery Bank 32 >RLGM Screened Note 1 92 BATT 34 Battery Bank 34 >RLGM Screened Note 2 93 BATT 33 Battery Bank 33 0.41 Anchorage 94 BUS2A 480V(SWGR 31) Bus 2A >RLGM Screened Note 2 95 BUS3A 480V(SWGR 32) Bus 3A >RLGM Screened Note 2 96 BUS5A 480V(SWGR31) Bus 5A >RLGM Screened Note 2 97 BUS6A 480V(SWGR 32) Bus 6A >RLGM Screened Note 2 98 36CMCC Primary Auxiliary Building >RLGM Screened Note 2 Motor Control Center 36C 99 39MCC Control Building Motor >RLGM Screened Note 2 Control Center 39 Turbine-Generator 100 32MCC Building Motor Control >RLGM Screened Note 1 Center 32 101 NI 31B Source Range Count Rate >RLGM Screened Meter 102 NI 31D Source Range Count Rate >RLGM Screened Meter 103 FE1 Preamplifier For NE-31 >RLGM Screened Note 3 Page B-6

For Information Only Indian Point Unit 3 ESEP Report Item HCLPF (g) / Failure Equipment Description Screening Mode Comments No. Equipment ID Level 104 PNL FCF Flight Control Panel FC >RLGM Screened Note 2 Loop 31 Hot Leg Pressure >RLGM Screened 105 PI-413K Indicator Loop 34 Hot Leg Pressure >RLGM Screened 106 PI-443K Indicator Loop 31 Hot Leg Pressure >RLGM Screened Note 3 107 PT-413 Transmitter Loop 34 Hot Leg Pressure >RLGM Screened Note 3 108 PT-443 Transmitter Upper Tap Compensation >RLGM Screened Note3 109 TE-1313 Temperature Element 110 TE-1314 Upper Tap Compensation >RLGM Screened Note 3 Temperature Element RVWL Conduit 111 TE-1317 Compensation >RLGM Screened Note 3 Temperature Element 112 TE-1318 RVWL Conduit >RLGM Screened Note 3 Compensation 113 TE-1319 RVWL Lower Tap Capillary >RLGM Screened Note 3 Temperature Element RCS Loop 31 Hot Leg Wide 114 TE-413A Range Temperature >RLGM Screened Note 3 Element RCS Loop 32 Hot Leg Wide 115 TE-423A Range Temperature >RLGM Screened Note 3 Element 116 CAB JR9 RVLIS Cabinet >RLGM Screened Note 2 LI-1311 RVWL Narrow Range >RLGM Screened 117 Indicator LI-1312 RVWL Wide Range >RLGM Screened 118 Indicator 119 LT-1311 Reactor Vessel Level Range Transmitter Narrow 120 LT-1312 Reactor Vessel Level Range Transmitter Narrow 121 TI-1416 Containment Atmospheric >RLGM Screened Temperature Indicator 122 PM-413K Loop 31 Hot Leg Pressure >RLGM Screened Page B-7

For Information Only Indian Point Unit 3 ESEP Report Item HCLPF (g) / Failure No. Equipment ID Equipment Description Screening Mode Comments Level Containment Parameters 123 31AIB-2 (J01) Recording Cabinet >RLGM Screened Note 2 (Channel I) 124 PM-443K Loop 34 Hot Leg Pressure >RLGM Screened 125 PC-413 Loop 31 Hot Leg Pressure >RLGM Screened 126 PC-443 Loop 34 Hot Leg Pressure >RLGM Screened 127 PQ-413 Loop 31 Hot Leg Pressure >RLGM Screened 128 PQ-443 Loop 34 Hot Leg Pressure >RLGM Screened 129 PNL SBF-2 Supervisory Control Panel >RLGM Screened Note 1 SB-2 130 Rack H1 CCR Auxiliary Panel Analog 0.47 Functional Rack H1 131 Rack H3 CCR Auxiliary Panel Analog 0.47 Functional Rack H3 132 PANEL SFF Supervisory Panel SF >RLGM Screened Note 2 133 RVLIS RACK RVLIS Rack Train A >RLGM Screened Note 2 TRAIN A 134 MS-45-1 Steam Generator 31 >RLGM Screened Safety Relief Valve Steam Generator 34 135 MS-45-4 >RLGM Screened Safety Relief Valve 136 PCV-1134 ATM Steam Relief Valve >RLGM Screened 31 Steam Generator 137 PCV-1137 ATM Steam Relief Valve >RLGM Screened 34 Steam Generator 138 N2 TANKS Backup Nitrogen Cylinders >RLGM Screened Note 2 139 IA-PCV-1278 Nitrogen Pressure >RLGM Screened Regulator 140 IA-PCV-1277 Nitrogen Pressure >RLGM Screened Regulator 141 MS-577 32 AFW Pump Overspeed >RLGM Screened Trip & Governor Valve 142 FT-1200 AFW to SG 31 Flow >RLGM Screened Transmitter Page B-8

For Information Only Indian Point Unit 3 ESEP Report ItemHCLPF (g) Failure No. Equipment ID Equipment Description Screening Mode Comments Level 143AFW to SG 34 Flow >RLGM Screened Transmitter 144 FI-1200 AFW to SG 31 Flow >RLGM Screened Indicator 145 FI-1203 AFW to SG 34 Flow >RLGM Screened Indicator 146 BFD-FCV-405A No. 32 AFW Pump Manual >RLGM Screened Flow Control to 31 SG 147 BFD-FCV-405D No. 32 AFW Pump Manual >RLGM Screened Flow Control to 34 SG 148 LT-417D SG 31 Level Transmitter >RLGM Screened Note 3 149 LT-447D SG 34 Level Transmitter >RLGM Screened Note 3 150 LI-417D SG 31 Level Indicator >RLGM Screened 151 LI-447D SG 34 Level Indicator >RLGM Screened 152 LQ-417D Steam Generator Level >RLGM Screened 153 LQ-427D Steam Generator Level >RLGM Screened 154 LQ-437D Steam Generator Level >RLGM Screened 155 LQ-447D Steam Generator Level >RLGM Screened 156 RACK B10 Instrument Rack >RLGM Screened Note 1 157 RACK B5 Instrument Rack >RLGM Screened Note 1 SG 31 Steam Pressure 158 P1-1353 Indicat Indicator >RLGM Screened 159 P1-1356 SG 34 Steam Pressure >RLGM Screened Indicator 160 ACCUM. 31 Accumulator Tank 31 >RLGM Screened Note 3 161 ACCUM. 32 Accumulator Tank 32 >RLGM Screened Note 3 162 ACCUM. 33 Accumulator Tank 33 >RLGM Screened Note 3 163 ACCUM. 34 Accumulator Tank 34 >RLGM Screened Note 3 Page B-9

For Information Only Indian Point Unit 3 ESEP Report Item HCLPF (g) / Failure Equipment Description Screening Mode Comments No. Equipment ID Level 164 CH-LCV-459 Letdown Isolation Valve >RLGM Screened Note 3 165 CH-HCV-133 RHR LP Bypass Valve >RLGM Screened Note 3 166 MOV-882 RHR Pump Suction >RLGM Screened Isolation Valve 167 LT-459 Pressurizer Level >RLGM Screened Note 3 Transmitter 168 LI-459A Pressurizer Level Indicator >RLGM Screened 169 LM-459A Pressurizer Level >RLGM Screened 170 Rack A4 CCR Rack A4 >RLGM Screened Note 1 171 Rack 19 Instrument Rack >RLGM Screened Note 3 172 Y39 Terminal Box >RLGM Screened Note 3 173 Y32 Terminal Box >RLGM Screened Note 3 174 Y36 Terminal Box >RLGM Screened Note 3 175 LIS-1311 Hydraulic Isolators >RLGM Screened Note 2 176 LIS-1312 Hydraulic Isolators >RLGM Screened Note 2 177 Y29 Terminal Box >RLGM Screened Note 2 178 PNL SN Supervisory Panel SN (JB9) >RLGM Screened Note 1 179 PT-402 Pressure Transmitter >RLGM Screened Note 3 180 RACK 22 (C9) Instrument Rack >RLGM Screened Note 1 181 RACK 6 (A9) Instrument Rack >RLGM Screened Note 1 182 - TDAFWP Turbine >RLGM Screened 183 - TDAFWP Lube Oil Coolers >RLGM Screened 184 TC-1416-1 Temperature Converter >RLGM Screened Page B-10

For Information Only Indian Point Unit 3 ESEP Report HCLPF (g) / Failure No. Equipment ID Equipment Description Screening Mode Comments Level 185 TC-1416-2 Temperature Converter >RLGM Screened 186 TC-1416-3 Temperature Converter >RLGM Screened 187 TC-1416-4 Temperature Converter >RLGM Screened 188 TC-1416-5 Temperature Converter >RLGM Screened 189 Rack A-7 CCR Rack A-7 >RLGM Screened Note 1 190 FP-T-1 31 Fire Water Storage 0.24 Anchorage Modifications required.

Tank 191 FP-T-2 32 Fire Water Storage 0.24 Anchorage Modifications required.

Tank 192 PW-S-TK 31 Primary Water Storage >RLGM Screened Note 1 Tank 193 Rack B4 CCR Rack B-4 >RLGM Screened Note 1 Notes:

1. Anchorage screened out based on available margin during walkdown by SRT.

2. Anchorage screened out during walkdown validation by SRT.

3. Inaccessible components were walked down during 3R18 outage (March 2015).

Page B-11

v t e Letter Sequence Response to RAI
TAC:MF5245, (Approved, Closed)
Initiation Acceptance... Administration Questions Answers 31 March 2014 31 March 2014 22 December 2014 21 April 2015 25 June 2015 Results Approval Other: ML15231A392
MONTHYEAR2015-04-21 [Table View]

NL-15-081, Additional Information Regarding Entergy'S Expedited Seismic Evaluation Process Report (CEUS Sites), Response to NRC Request for Information, Per 10CFR50.54(f) Regarding Recommendation 2.1 of the Near-Term Task Force Review Of..

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NL-15-081, Additional Information Regarding Entergy'S Expedited Seismic Evaluation Process Report (CEUS Sites), Response to NRC Request for Information, Per 10CFR50.54(f) Regarding Recommendation 2.1 of the Near-Term Task Force Review Of..

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