Text

Expedited Seismic Evaluation Process Report Response to NRC Request for Information Pursuant to 10 CFR 50.54(f) Re Recommendation 2.1 of the Near-Term Task Force Review of Insights from the Fukushima Dai-ichi Accident
	ML14353A085
Person / Time
Site:	LaSalle
Issue date:	12/19/2014
From:	Kaegi G; Exelon Generation Co
To:	; Document Control Desk, Division of Operating Reactor Licensing
References
	RS-14-298
	Download: ML14353A085 (71)
	v • d • e

Aaga"- Exelon Generation RS-14-298

10 CFR 50.54(f)

December 19, 2014 U.S. Nuclear Regulatory Commission Attn: Document Control Desk 11555 Rockville Pike, Rockville. MD 20852 LaSalle County Station, Units 1 and 2 Facility Operating License Nos. NPF-11 and NPF-18 NRC Docket Nos. 50-373 and 50-374

Subject:

Exelon Generation Company, LLC 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

References:

1. NRC Letter, 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, dated March 12, 2012 (ML12053A340)

2. NEI Letter, Proposed Path Forward for NTTF Recommendation 2.1: Seismic Re-evaluations, dated April 9, 2013 (ML13101A379)

3. Seismic Evaluation Guidance: "Augmented Approach for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1 Seismic", EPRI, Palo Alto, CA: May 2013. 3002000704 (ML13102A142)

4. NRC Letter, Electric Power Research Institute Report 3002000704, "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 Re-evaluations, dated May 7, 2013 (ML13106A331)

5. Exelon Generation Company, LLC, Seismic Hazard and Screening Report (Central and Eastern United States (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 (RS-14-068), dated March 31, 2014 (ML14091A013)

6. Exelon Generation Company, LLC Response to NRC Request for Information Pursuant to 10 CFR 50.54(f) Regarding the Seismic Aspects of Recommendation 2.1 of the Near-Term Task Force Review of Insights from the Fukushima Dai-ichi Accident 1.5 Year Response for CEUS Sites (RS-13-205), dated September 12, 2013 (ML13256A070)

U.S. Nuclear Regulatory Commission NTTF 2.1 Seismic Response for CEUS Sites December 19, 2014 Page 2 On March 12, 2012, the Nuclear Regulatory Commission (NRC) issued a 50.54(f) letter to all power reactor licensees and holders of construction permits in active or deferred status. of Reference 1 requested each addressee located in the Central and Eastern United States (CEUS) to submit a Seismic Hazard Evaluation and Screening Report within 1.5 years from the date of Reference 1.

In Reference 2, the Nuclear Energy Institute (NEI) requested NRC agreement to delay submittal of the final CEUS Seismic Hazard Evaluation and Screening Reports so that an update to the Electric Power Research Institute (EPRI) ground motion attenuation model could be completed and used to develop that information. NEI proposed that descriptions of subsurface materials and properties and base case velocity profiles be submitted to the NRC by September 12, 2013, (Reference 6), with the remaining seismic hazard and screening information submitted by March 31, 2014 (Reference 5). NRC agreed with that proposed path forward in Reference 4.

Reference 1 requested that licensees provide interim evaluations and actions taken or planned to address the higher seismic hazard relative to the design basis, as appropriate, prior to completion of the risk evaluation. In accordance with the NRC endorsed guidance in Reference 3, the enclosed Expedited Seismic Evaluation Process (ESEP) Report for LaSalle County Station, Units 1 and 2, provides the information described in the "ESEP Report" Section 7, of Reference 3 in accordance with the schedule identified in Reference 2.

All equipment evaluated for the ESEP for LaSalle County Station, Units 1 and 2 was found to have adequate capacity for the required seismic demand as defined by the Augmented Approach (ESEP) guidance (Reference 3). Therefore, no equipment modifications are required.

This ESEP report transmittal completes regulatory Commitment No. 3 of Reference 5.

No new regulatory commitments result from this transmittal.

If you have any questions regarding this report, please contact Ron Gaston at (630) 657-3359.

I declare under penalty of perjury that the foregoing is true and correct. Executed on the 19th day of December 2014.

Respectfully submitted, Glen T. Kaegi Director - Licensing & Regulatory Affairs Exelon Generation Company, LLC

Enclosure:

LaSalle County Station, Units 1 and 2, Expedited Seismic Evaluation Process (ESEP)

Report

U.S. Nuclear Regulatory Commission NTTF 2.1 Seismic Response for CEUS Sites December 19, 2014 Page 3 cc:

Director, Office of Nuclear Reactor Regulation Regional Administrator - NRC Region III NRC Senior Resident Inspector LaSalle County Station NRC Project Manager, NRR LaSalle County Station Mr. Nicholas J. DiFrancesco, NRR/JLD/JHMB, NRC Illinois Emergency Management Agency - Division of Nuclear Safety

Enclosure LaSalle County Station, Units 1 and 2 Expedited Seismic Evaluation Process (ESEP) Report (67 pages)

Printed Name

Sionature

1211ft Preparer

Hunter Young

12/17/2014 Reviewer A Karavoussianis

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12/17/2014 Approver Lead Responsible Engineer Branch Manager Senior Manager Design Engineering.

Corporate Acceptance:

A. Karavoussianis L.

4;441:e 1-1,./4, Jeffrey S. Clark 12/17/2014

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r 2/44 444)1 1/04,42 121111.4 EXPEDITED SEISMIC EVALUATION PROCESS (ESEP) REPORT IN RESPONSE TO THE 50.54(f) INFORMATION REQUEST REGARDING FUKUSHIMA NEAR-TERM TASK FORCE RECOMMENDATION 2.1: SEISMIC for the LaSalle County Generating Station Unit 1 and 2 2601 North 21st Road, Marseilles, Illinois, 61341-9757 Facility Operating License No. NPF-11 and NPF-18 NRC Docket No. STN 50-373 and STN 50-374 Correspondence No.: RS-14-298 A111111111, Exelon Exelon Generation Company, LLC (Exebn)

PO Box 805398 Chicago, IL 60680-5398 Prepared by:

Stevenson & Associates 1646 North Litchfield Road, Suite 250 Goodyear, AZ 85395 Report Number 1404238-RPT-004, Rev. 4

S&A Report 14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Document

Title:

EXPEDITED SEISMIC EVALUATION PROCESS (ESEP) REPORT IN RESPONSE TO THE 50.54(f) INFORMATION REQUEST REGARDING FUKUSHIMA NEAR-TERM TASK FORCE RECOMMENDATION 2.1: SEISMIC FOR THE LASALLE COUNTY GENERATING STATION Document Type:

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Drawing El Project Name: Exelon ESEP for LaSalle County Generating Station Job No.: 14Q4238 AINIONIP Client:

Exelon This document has been prepared in accordance with the SatA Quality Assurance Program Manual, Revision 17 and project requirements:

Initial Issue (Rev. 0)

Prepared by: See Page 3 Date:

Reviewed by: See Page 3 Date:

Approved by: See Page 3 Date:

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Drawing 0 Project Name: Exelon ESEP for LaSalle County Generating Station Job No.: 14Q4238 Agrimw Client:

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Initial Issue (Rev. 0)

Prepared by: Hunter Young Date: 12/9/2014 Reviewed by:

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14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 4 of 67 TABLE OF CONTENTS 1.0

Purpose and Objective

7 2.0

Brief Summary of the FLEX Seismic Implementation Strategies

8 3.0

Equipment Selection Process and ESEL

12 3.1

Equipment Selection Process and ESEL

12 3.1.1

ESEL Development

13 3.1.2

Power Operated Valves

15 3.1.3

Pull Boxes

15 3.1.4

Termination Cabinets

15 3.1.5

Critical Instrumentation Indicators

15 3.1.6

Phase 2 and Phase 3 Piping Connections

16 3.2

Justification for use of Equipment that is not the Primary Means for FLEX Implementation

16 4.0

Ground Motion Response Spectrum (GMRS)

17 4.1

Plot of GMRS Submitted by the Licensee

17 4.2

Comparison to SSE

20 5.0

Review Level Ground Motion (RLGM)

22 5.1

Description of RLGM Selected

22 5.2

Method to Estimate ISRS

24 6.0

Seismic Margin Evaluation Approach

25 6.1

Summary of Methodologies Used

25 6.2

HCLPF Screening Process

25 6.3

Seismic Walkdown Approach

26 6.3.1 Walkdown Approach

26 6.3.2 Application of Previous Walkdown Information

28 6.3.3

Significant Walkdown Findings

29 6.4

HCLPF Calculation Process

29 6.5

Functional Evaluation of Relays

31 6.6

Tabulated ESEL HCLPF Values (Including Key Failure Modes)

31 7.0

Inaccessible Items

32 7.1

Identification of ESEL Items Inaccessible for Walkdowns

32 7.2

Planned Walkdown / Evaluation Schedule / Close Out

32

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 5 of 67 8.0

ESEP Conclusions and Results

32 8.1

Supporting Information

32 8.2

Summary of ESEP Identified and Planned Modifications

34 8.3

Modification Implementation Schedule

34 8.4

Summary of Regulatory Commitments

34 9.0

References

35 Attachment A LaSalle County Generating Station Unit 1 ESEL

38 Attachment B LaSalle County Generating Station Unit 2 ESEL

45 Attachment C - LaSalle Unit 1 ESEP HCLPF Values and Failure Mode Tabulation

51 Attachment D - LaSalle Unit 2 ESEP HCLPF Values and Failure Mode Tabulation

59

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 6 of 67 LIST OF TABLES Table 2-1: Phase 1 FLEX Strategy

9 Table 2-2: Phase 2 FLEX Strategy

10 Table 2-3: Phase 3 FLEX Strategy

11 Table 3-1: Flow Paths Credited for ESEP

14 Table 4-1 : LaSalle County Generating Station GMRS (5% Damping)

18 Table 4-2: LaSalle County Generating Station GMRS and SSE (5% Damping) between 1-10Hz

20 Table 5-1: LaSalle County Generating Station Maximum GMRS/SSE Ratio (5% Damping)

22 Table 5-2 : LaSalle Generating Station RLGM (5% Damping)

23 Table 6-1: HCLPF Calculation Summary

30 LIST OF FIGURES Figure 4-1: LaSalle County Generating Station GMRS (5% Damping)

19 Figure 4-2 : LaSalle County Generating Station GMRS to SSE (5% Damping) Comparison

21 Figure 5-1 : LaSalle County Generating Station RLGM, GMRS & SSE (5% Damping)

24

140.4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 7 of 67 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 LaSalle County Generating Station (LaSalle County Station). The intent of the ESEP is to perform an interim action in response to the NRC's 50.54(f) letter [1] 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 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 for LaSalle County Generating Station. The level of detail provided in this 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.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 8 of 67 2.0

Brief Summary of the FLEX Seismic Implementation Strategies*

The LaSalle County Station FLEX strategies to maintain Core Cooling and to maintain Containment are summarized below. The Spent Fuel Pool Cooling strategies are not described because they are not included within the scope of the ESEP process. The LaSalle FLEX strategy summary is derived from the Overall Integrated Plan (01P) in Response to the March 12, 2012, Commission Order EA-12-049 [3]

including the required 6-Month Updates that have been prepared since the 01P was submitted.

The Phase 1 FLEX strategy relies on installed plant equipment. Reactor Core Cooling is achieved via operation of the Reactor Core Isolation Cooling (RCIC) system with injection from the suppression pool water source to the reactor vessel. Reactor vessel cooldown is achieved via manual operation of the Automatic Depressurization System (ADS) Safety/Relief Valves that discharge to the suppression pool.

Key reactor parameters are obtained via DC powered instrumentation. A DC load stripping strategy is employed to extend battery life. Containment Control during Phase 1 is maintained by the normal design features of the containment.

The Phase 2 FLEX strategy relies on installed plant equipment and portable on-site equipment. When RCIC is no longer available, Reactor Core Cooling is provided by a portable diesel-driven FLEX pump that draws a suction from the Ultimate Heat Sink (UHS) and pumps water to the reactor vessel via portable hoses and installed piping systems (Fuel Pool Cooling emergency makeup piping and Residual Heat Removal piping). The water flow path is established via manual operation of system valves. Portable 500Kw 480VAC diesel generators are used to re-power selected 480VAC buses such that installed battery chargers can be operated. An alternate Core Cooling method is available via connection to other divisions of the installed plant piping systems. Alternate electrical power supply is available via connection to receptacles at the battery chargers such that the majority of the installed electrical distribution system is bypassed. Key Reactor Parameters are obtained via DC powered instrumentation.

Containment control in Phase 2 is addressed via venting via the to-be-installed Severe Accident Capable Vent (SACV) system that is required per NRC Order EA-13-109. Makeup to the suppression pool (when inventory is lost via venting) will be provided by a portable diesel-driven FLEX pump that draws a suction from the Ultimate Heat Sink (UHS) and pumps water to the suppression pool via portable hoses and installed piping systems (fuel pool cooling emergency makeup piping and residual heat removal piping).

The Phase 3 FLEX strategy is an extension of the Phase 2 strategies. No new or different portable or installed plant systems are used.

This section is based upon input received from LaSalle County Station in [21].

Alternate Method Z.

z.

Primary Method RCIC with suction from the Suppression Pool RCS cooldown at <1=20 Deg F/hr to 150-250 psig via manual control of the ADS SRVs RPV Level and Pressure Use existing Battery Powered Indication Extend coping with DC Load Stripping

'None required maintained by normal design features Suppression Pool Water Temperature Suppression Pool Water Level Suppression Pool Pressure Drywell Pressure Use existing Battery Powered Indication Safety Function Reactor Core Cooling Key Reactor Parameters Containment Function Key Containment Parameters 6ulloo3 woo luatuulewoo 14Q4238-RPT-004 Rev. 4

Primary Method Containment Function luatuulewo3 Safety Function Reactor Core Cooling 5uiloo3 0.103 14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 10 of 67 Table 2-2: Phase 2 FLEX Strategy

ment Function

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Safety Function Reactor Core Cooling Key Reactor Parame 6 u 11003 0.103 4ueuffilewo3 14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 11 of 67 Table 2-3: Phase 3 FLEX Strategy

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 12 of 67 3.0

Equipment Selection Process and ESEL The selection of equipment for the Expedited Seismic Equipment List (ESEL) [18] followed the guidelines of EPRI 3002000704 [2]. The ESELs for Unit 1 and Unit 2 are presented in Attachments A and B, respectively.

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 seismic event, as outlined in the LaSalle County Generating Station Overall Integrated Plan (0(P) in Response to the March 12, 2012, Commission Order EA-12-049 [3] including subsequent 6 month updates through August 2014.

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 LaSalle County Generating Station 01P [3] including subsequent 6 month updates through August 2014. 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, Sub-criticality, and Containment Integrity functions.

Portable and pre-staged FLEX equipment (not permanently installed/anchored) are excluded from the ESEL per EPRI 3002000704 [2].

The ESEL component selection followed the EPRI guidance outlined in Section 3.2 of EPRI 3002000704 [2].

1. The scope of components is limited to that required to accomplish the core cooling and containment safety functions identified in Table 3-1 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 LaSalle Generating Station 01P [3]

including subsequent 6 month updates through August 2014.

2. The scope of components is limited to installed plant equipment, and FLEX connections necessary to implement the LaSalle County Generating Station 01P [3] including subsequent 6 month updates through August 2014 as described in Section 2.

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.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 13 of 67

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, check 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. reactor pressure vessel and internals, reactor coolant pumps and seals, etc.)

3.1.1 ESEL Development The ESEL was developed by reviewing the LaSalle County Generating Station 01P [3], including subsequent 6 month updates through August 2014, to determine equipment involved in the FLEX strategies. Further reviews of plant drawings (e.g., Process and Instrumentation Diagrams (P&IDs) and Electrical One Line Diagrams) were performed to identify the boundaries of the flow paths 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 power distribution or mechanical isolation device (e.g.,

circuit breaker, valve, etc.) in branch circuits / branch lines off the defined 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 diagrams, system descriptions, design basis documents, etc., as necessary.

The flow paths credited for the LaSalle County Generating Station ESEP are shown in Table 3-1 below.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 14 of 67 Table 3-1: Flow Paths Credited for ESEP Flow Path P&IDs [19]

Unit 1

Unit 2 Core Heat Removal using RCIC (Reactor Core Isolation Cooling) system: Coolant from the Suppression Pool to the RCS (Reactor Cooling System) via the RCIC pump. Also Main Steam providing motive force to the ROC pump turbine and exhausted to the Suppression Pool.

M-101 Sh. 1 M-101 Sh. 2 M-147 Sh. 1 M-147 Sh. 2 RPV (Reactor Pressure Vessel) Pressure Control using ADS (Automatic Depressurization System) system: Main Steam relieved through the ADS Safety/Relief Valves to the Suppression Pool M-55 Sh. 1 M-66 Sh. 2 M-66 Sh. 7 M-116 Sh. 1 M-66 Sh. 8 M-66 Sh. 4 M-66 Sh. 7 RPV Make Up: Coolant from the Ultimate Heat Sink via FLEX pump and Fuel Pool Cooling Emergency Makeup (FPC EMU) piping to the RHR (Residual Heat Removal) system, which injects coolant to the RPV.

M-87 Sh. 1 M-96 Sh. 1 m-96 Sh. 2 M-98 Sh. 1 M-134 Sh. 1 M-142 Sh. 1 M-142 Sh. 2 M-144 Sh. 1 Diesel Fuel Oil Supply: Fuel Oil from the Diesel Fuel Oil Storage Tank, via Diesel Generator Fuel Oil Transfer Pump and the Emergency Diesel Generator Day Tanks to FLEX Truck fuel tanks.

M-85 Sh. 1 M-132

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 15 of 67 3.1.2 Power Operated Valves Page 3-3 of EPRI 3002000704 [2] notes that power operated valves not required to change state 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. RCIC/AFW trips)."

To address this concern, the following guidance is applied in the LaSalle County Generating Station ESEL for functional failure modes associated with power operated valves:

Power operated valves that must remain energized during the Extended Loss of all AC Power (ELAP) events in order to maintain a credited FLEX flow path or pressure boundary (such as DC powered solenoid-operated 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.

3.1.3 Pull Boxes Pull boxes were deemed unnecessary to add to the ESELs as these components provide completely passive locations for pulling or installing cables. No breaks or connections in the cabling are included in pull boxes. Pull boxes were considered part of conduit and cabling, which are 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, and the connections are excluded from the ESEL.

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).

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 16 of 67 3.1.6 Phase 2 and Phase 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 LaSalle County Generating Station 01P [3], including subsequent 6 month updates through August 2014, 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 on to 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 existing, permanently-installed active valves in the 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 is not the primary means for FLEX implementation is specified on the LaSalle County Generating Station ESEL.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 17 of 67 4.0

Ground Motion Response Spectrum (GMRS) 4.1

Plot of GMRS Submitted by the Licensee In accordance with Section 2.4.2 of the SPID [12], the licensing design basis definition of the SSE control point for LaSalle County Generating Station is used for comparison to the GMRS. Reference 4 lists the LaSalle County Station SSE as being located at 666 feet MSL with a PGA of 0.2g.

The GMRS per the March 31, 2014 submittal report [4] is tabulated in Table 4-1 and shown Figure 4-1 below.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 18 of 67 Table 4-1 : LaSalle County Generating Station GMRS (5% Damping)

Freq. (Hz)

GMRS (unscaled, g) 0.1 0.024 0.125 0.029 0.15 0.035 0.2 0.047 0.25 0.059 0.3 0.071 0.35 0.082 0.4 0.094 0.5 0.118 0.6 0.143 0.7 0.169 0.8 0.193 0.9 0.214 1

0.232 1.25 0.284 1.5 0.330 2

0.403 2.5 0.428 3

0.461 3.5 0.480 4

0.491 5

0.517 6

0.572 7

0.627 8

0.664 9

0.686 10 0.695 12.5 0.635 15 0.574 20 0.507 25 0.486 30 0.454 35 0.426 40 0.404 50 0.373 60 0.354 70 0.341 80 0.331 90 0.324 100 0.317

0.80 0.70 0.60 3 0.50 c

o 1 0.40 r) a)

0.20 0.10 0.00 -

0.1 1

Frequency (Hz) 10 100 14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 19 of 67 GMRS Figure 4-1: LaSalle County Generating Station GMRS (5% Damping)

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 20 of 67 4.2

Comparison to SSE As identified in the March submittal report [4], the GMRS exceeds the SSE in the 1-10Hz range. A comparison of the GMRS to the SSE between 1-10Hz is shown in Table 4-2 and Figure 4-2.

Table 4-2: LaSalle County Generating Station GMRS and SSE (5% Damping) between 1-10Hz Freq. (Hz) GMRS (g) SSE (g) 1 0.232 0.27 1.25 0.284 0.34 1.5 0.330 0.41 2

0.403 0.54 2.5 0.428 0.54 3

0.461 0.54 3.5 0.480 0.54 4

0.491 0.54 5

0.517 0.54 6

0.572 0.54 6.4 0.6001 0.54 7

0.627 0.50 8

0.664 0.46 9

0.686 0.42 10 0.695 0.38 t Refer to Table 4-1. No control point is defined per [4] for 6.4 Hz in the GMRS; therefore the spectral acceleration is interpolated.

0.80 7 1:29- 0.70 to c

-6.

E 0.60 co 1:3 0.50

.5 0.40 E'

_ow 0.30 u

a

.t.'0.20*

Ti u oio v,

0.00 1

10

110 Frequency (Hz)

MD OM

-GMRS SSE 14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 21 of 67 Figure 4-2: LaSalle County Generating Station GMRS to SSE (5% Damping) Comparison

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 22 of 67 5.0

Review Level Ground Motion (RLGM) 5.1

Description of RLGM Selected The RLGM for LaSalle County Generating Station was determined in accordance with Section 4 of EPRI 3002000704 [2] by linearly scaling the LaSalle County Station SSE by the maximum GMRS/SSE ratio between the 1 and 10Hz range. This calculation is shown in Table 5-1.

Table 5-1: LaSalle County Generating Station Maximum GMRS/SSE Ratio (5% Damping)

Freq. (Hz) GMRS (g) SSE, (g) Ratio GMRS/SSE 1

0.232 0.27 0.86 1.25 0.284 0.34 0.84 1.5 0.330 0.41 0.80 2

0.403 0.54 0.75 2.5 0.428 0.54 0.79 3

0.461 0.54 0.85 3.5 0.480 0.54 0.89 4

0.491 0.54 0.91 5

0.517 0.54 0.96 6

0.572 0.54 1.06 6.4 0.600 0.54 1.11 7

0.627 0.5 I

1.25 8

0.664 0.46 1.44 9

0.686 0.42 1.63 10 0.695 0.38 1.83 As shown above, the maximum GMRS/SSE ratio for LaSalle occurs at 10 Hz and equals 1.83.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 23 of 67 The resulting 5% damped RLGM, based on scaling the horizontal SSE by the maximum GMRS/SSE ratio of 1.83 is shown in Table 5-2 and Figure 5-1 below. Note that the RLGM PGA is 0.37g.

Table 5-2: LaSalle Generating Station RLGM (5% Damping)

Freq. (Hz)

RLGM (g) 0.1 0.02 0.13 0.02 0.15 0.04 0.2 0.05 0.25 0.09 0.3 0.13 0.35 0.16 0.38 0.18 0.4 0.20 0.5 0.26 0.6 0.29 0.7 0.35 0.8 0.40 0.9 0.44 1

0.49 1.25 0.62 1.5 0.75 2

0.99 3

0.99 4

0.99 5

0.99 6

0.99 6.4 0.99 7

0.92 8

0.84 9

0.77 10 0.70 12.5 0.59 15 0.51 20 0.42 23.5 0.37 25 0.37 30 0.37 50 0.37 100 0.37

o*

die

e*

I

- - 4m.-4m,

1.2 10 Frequency (Hz) 1 c

0.8 tr.

co 8 0.6 cij V 0.4

0.

0.2 14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 24 of 67 Original SSE RLGM GM RS Figure 5-1 : LaSalle County Generating Station RLGM, GMRS & SSE (5% Damping) 5.2

Method to Estimate ISRS The method used to derive the ESEP in-structure response spectra (ISRS) was to uniformly scale existing SSE-based ISRS from DC-SE-02-LS, Revision 3, "Seismic Response Spectra Design Criteria"

[16] by the maximum GMRS/SSE ratio from Table 5-1 of 1.83. The scaled ISRS was determined for all buildings and elevations where ESEL items are located at LaSalle County Generating Station and are documented in 14Q4238-CAL-001 [7].

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 25 of 67 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 peak ground acceleration (PGA) for which there is a high confidence of a low probability of failure (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 [5].

2.

Probabilistic approach using the fragility analysis methodology of EPRI TR-103959 [6].

For LaSalle County Generating Station, the deterministic approach using the CDFM methodology of EPRI NP-6041 [5] was used to determine HCLPF capacities.

6.1

Summary of Methodologies Used LaSalle County Generating Station conservatively applied the methodology of EPRI NP-6041 [5] to all items on the ESEL [18]. The screening walkdowns used the screening tables from Chapter 2 of EPRI NP-6041 [5]. The walkdowns were conducted by engineers who, as a minimum, have attended the SQUG Walkdown Screening and Seismic Evaluation Training Course. The walkdowns were documented on Screening Evaluation Work Sheets from EPRI NP-6041 [5]. Anchorage capacity calculations use the CDFM criteria established within EPRI NP-6041 [5] with LaSalle County Station specific allowables and material strengths used as applicable. The input seismic demand used was the RLGM shown in Table 5-2 and Figure 5-1.

6.2

HCLPF Screening Process From Table 5-2, the spectral peak of the RLGM (amplified PGA) for LaSalle County Generating Station equals 0.99 g. The screening tables in EPRI NP-6041 [5] are based on ground peak spectral accelerations of 0.8g and 1.2g. All LaSalle County Station ESEL components were screened against the caveats of the 0.8g-1.2g column of Table 2-4 of NP-6041. Screening based on this lane with the RLGM spectral shape yields an equivalent HCLPF of 0.45 g PGA (witness 1.2g/0.99g*0.37g PGA =

0.45g PGA).

A number of components were located above 40 feet from grade. For components located 40 feet above grade or more, screening based on ground peak spectral acceleration is not applicable and additional consideration is required. In accordance with Appendix B of EPRI 1019200 [17],

components that are above 40 feet from grade and have corresponding ISRS at the base of component

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 26 of 67 not in exceedance of 1.8g in the component frequency range of interest may be screened using the caveats of the 2nd screening column.

The screening of anchorage for non-valve components was evaluated either by SRT judgment or simple analysis. For non-valve components whose anchorage could not readily be screened by SRT judgment or simple analysis, CDFM HCLPF calculations [7] were performed. This is documented in Attachments C and D.

6.3

Seismic Walkdown Approach 6.3.1 Walkdown Approach Walkdowns for LaSalle County Generating Station were performed in accordance with the criteria provided in Section 5 of EPRI 3002000704 [2], which refers to EPRI NP-6041 [5] for the Seismic Margin Assessment process. Pages 2-26 through 2-30 of EPRI NP-6041 [5] 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-radioactive or low radioactive environments. Seismic capability assessment of components which are inaccessible, in high-radioactive environments, or possibly within contaminated containment, will have to rely more on alternate means such as photographic inspection, more reliance on seismic reanalysis, and possibly, smaller inspection teams and more hurried inspections. A 100% "walk by" does not mean complete inspection of each component, nor does it mean requiring an electrician or other technician to de-energize and open cabinets or panels for detailed inspection 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 reasonable basis for assuming that the group of components are similar and are similarly anchored, 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 preparatory work (Step 3) by reference to drawings, calculations or specifications. The one component or each type which is selected should be thoroughly inspected which probably does mean de-energizing and opening cabinets or panels for this very limited sample. Generally, a spare representative component 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, anchorage should 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 correspondence is 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

140.4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 27 of 67 construction pattern is typical. This procedure for inspection should be repeated for 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 practices are 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 different from that shown on drawings or prescribed in criteria for that component, potential SI [Seismic Interaction] 1 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 responsible for the seismic adequacy of all elements which they screen from the margin review. Appendix D gives guidance for sampling selection."

The LaSalle County Generating Station walkdowns included, as a minimum, a 100% walk-by of all items on the ESEL except as noted in Section 7.0. Any previous walkdown information that was relied upon as the basis for SRT judgment is documented in Section 6.3.2.

EPRI 3002000704 [2] page 5-4 limits the ESEP seismic interaction reviews to "nearby block walls" and "piping attached to tanks" which are reviewed "to address the possibility of failures due to differential displacements."

Other potential seismic interaction evaluations are "deferred to the full seismic risk evaluations performed in accordance with EPRI 1025287 [12]."

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 28 of 67 6.3.2 Application of Previous Walkdown Information Previous seismic walkdowns conducted for the NTTF 2.3 [14] programs were used to supplement the NTTF 2.1 walkdowns of LaSalle County Station.

In general, detailed inspections were performed for NTTF 2.1 and included, as a minimum, a walk-by of all the components on the ESEL by the SRT with exception to the items listed below. A detailed discussion and resolution for each of the items listed below is provided in Section 7.0. This walkdown/walk-by was also used to confirm that no new Sr existed.

U1 Safety Relief Valves (SRV):

o 1621-F013C o 1621-F013D o 1621-F013E o 1621-F013R o 1621-F013S o 1621-F013U o 1621-F013V

U1 SRV Accumulators:

o 1B21-A003C o 1621-A003D o 1621-A003E o

11321-A003R o 1B21-A003S o 1B21-A003U o 1621-A003V

RCIC Suppression Pool Suction Valve, 2E51-F031 Photos taken during the NTTF Recommendation 2.3 seismic walkdowns [14], although available to the SRT during the ESEP walkdowns, were not necessary to the SRT at LaSalle County Station.

EPRI 3002000704 [2] page 5-4 limits the ESEP seismic interaction reviews to "nearby block walls" and "piping attached to tanks" which are reviewed "to address the possibility of failures due to differential displacements."

Other potential seismic interaction evaluations are "deferred to the full seismic risk evaluations performed in accordance with EPRI 1025287 [12]."

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 29 of 67 6.3.3 Significant Walkdown Observations Consistent with the guidance from NP-6041 [5], no significant outliers or anchorage concerns were identified during the LaSalle County Generating Station seismic walkdowns. The following observation was noted during the walkdowns:

Block walls and columns were identified in the proximity of ESEL equipment. These block walls and columns were assessed for their structural adequacy to withstand the seismic loads resulting from the RLGM. For any cases where the block wall represented the HCLPF failure mode for an ESEL item, it is noted on the ESEL HCLPF tables in Attachments C and D.

6.4

HCLPF Calculation Process ESEL items were evaluated using the criteria in EPRI NP-6041 [5]. Those evaluations included the following steps:

Performing seismic capability walkdowns for equipment to evaluate the equipment installed plant conditions

Performing screening evaluations using the screening tables in EPRI NP-6041 [5] as described in Section 6.2

Performing HCLPF calculations considering various failure modes that include both structural (e.g. anchorage, load path etc.) and functional failure modes.

All HCLPF calculations were performed using the CDFM methodology and are documented in LaSalle County Generating Station calculations [7].

Anchorage configurations for non-valve components were evaluated either by SRT judgment, large margins in existing design basis calculations, or CDFM based HCLPF calculations [7]. The results of these analysis methods are documented in Attachment C and Attachment D. For components beyond 40 feet above grade, Table 2-4 of NP-6041 [5] is not directly applicable.

EPRI 3002000704 [2] Section 5 references EPRI 1019200 [17] with respect to screening criteria beyond 40 feet above grade. This guide update allows multiplying the screening lane spectral acceleration value ranges by a factor of 1.5 in order to account for spectral accelerations at the base of the component. This screening level at the base of a component is compared to the ISRS demand corresponding to the RLGM. For example, by factoring the acceleration ranges for screening lane 2 of NP-6041-SL Table 2-4, the capacity at the base of a component is bounded by 1.2g*1.5 = 1.8g. This is compared with the seismic demand presented by the ISRS (as opposed to the RLGM).

tt Page A-22 of NP-6041 [5] also references the use of 1.5 times the bounding spectra for comparison against the floor spectra.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 30 of 67 As described in Section 6.0, for HCLPF calculations the Conservative, Deterministic Failure Margin (CDFM) analysis criteria established in Section 6 of EPRI NP-6041 [5] are used for a detailed analysis of components. The relevant CDFM criteria from EPRI NP-6041 [5] are summarized in Table 6-1.

Table 6-1: HCLPF Calculation Summary Load combination:

Normal + Seismic Margin Earthquake (SME)4 Ground response spectrum:

Conservatively specified (84% non-exceedance probability)

Damping:

Conservative estimate of median damping.

Structural model:

Best estimate (median) + uncertainty variation in frequency.

Soil-structure interaction Best estimate (median) + parameter variation Material strength:

Code specified minimum strength or 95% exceedance of actual strength if test data is available.

Static capacity equations:

Code ultimate strength (Ad), maximum strength (Al SC),

Service Level D (ASME) or functional limits. If test data is available to demonstrate excessive conservatism of code equations then use 84% exceedance of test data for capacity equations.

Inelastic energy absorption:

For non-brittle failure modes and linear analysis, use 80% of computed seismic stress in capacity evaluation to account for ductility benefits or perform nonlinear analysis and use 95% exceedance ductility levels.

In-structure (floor) spectra generation:

Use frequency shifting rather than peak broadening to account for uncertainty and use median damping.

The HCLPF capacity is equal to the PGA at which the strength limit is reached. The HCLPF earthquake load is calculated as follows:

U = Normal + Ec Where:

U = Ultimate strength per Section 6 of EPRI NP-6041 [5]

Ec = HCLPF earthquake load

Normal = Normal operating loads (dead and live load expected to be present, etc.)

For this calculation, the HCLPF earthquake load is related to a fixed reference earthquake:

Ec = SFc*Eref Where:

Eref = reference earthquake from the relevant in-structure response spectrum (ISRS)

SFc = component-specific scale factor that satisfies U = Normal +Ec The HCLPF will be defined as the PGA produced by Ec. Because the LaSalle RLGM PGA is 0.37g:

HCLPF = 0.37g*SFc u The SME pertaining to HCLPF calculations for LaSalle County Generating Station is equivalent to the RLGM.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 31 of 67 6.5

Functional Evaluation of Relays The LaSalle Unit 1 ESEL and Unit 2 ESEL [18] each had fifteen relays and eleven switches associated with the FLEX Phase 1 response, which required functional evaluations. Each relay was evaluated using the SMA relay evaluation criteria in Section 3 of NP-6041 [5].

HCLPF capacities for the relays and switches are calculated using established GERS capacities from the NP-7147 SQUG Advisory [19] and NP-5223 [20], respectively. Where GERS capacities were not available, specific seismic qualification test-based capacities were used. In-cabinet capacity to demand evaluations were performed using the aforementioned seismic capacities and the ESEP ISRS scaled with the NP-6041 in-cabinet amplification factors. In each case, the capacity exceeded the demand.

These results are included in Attachments C and D. The ESEP relay functional evaluations are documented in S&A calculation 14Q4238-CAL-005 [7].

6.6

Tabulated ESEL HCLPF Values (Including Key Failure Modes)

Tabulated ESEL HCLPF values including the key failure modes are included in Attachment C for Unit 1 and in Attachment D for Unit 2 items.

For items screened out using NP-6041 [5] screening tables, the HCLPF is listed as "> RLGM" and the failure mode is listed as "Screened."

For items where anchorage controls the HCLPF value, the anchorage HCLPF value is listed in the table and the failure mode is listed as "Anchorage."

For items where block wall interaction controls the HCLPF value, the associated block wall HCLPF value is listed in the table and the failure mode is listed as "Block Wall Interaction." In cases where finite element analysis was used, the HCLPF is listed as "> RLGM."

For items where a relay or switch HCLPF controls, the relay or switch HCLPF value is listed in the table and the failure mode is listed as "Functional Failure."

For items where an equipment capacity based upon the screening lane values of Table 2-4 of EPRI NP-6041 [5] controls the HCLPF value (e.g. anchorage, block wall, or relay HCLPF capacity exceeds the equipment capacity derived from screening lanes), the screening lane HCLPF value is listed in the table and the failure mode is listed as "Equipment Capacity." Based on NP-6041 Table 2-4 lane 2, this limit is equal to 0.45g for items below 40 feet above grade and 0.37g for items located greater than 40 feet above grade.

The "Equipment Capacity" limits from above are calculated as follows:

The upper-bound spectral peak to NP-6041 Table 2-4 lane 2 is 1.2g. From Table 5-2, the RLGM spectral peak is 0.99g and the PGA is 0.37g. Thus, for equipment less than 40 feet above grade, the "Equipment Capacity" HCLPF is limited to 1.2g / 0.99g

0.37g PGA = 0.45g PGA. For equipment located greater than 40 feet above grade, if the associated ISRS spectral accelerations in the component frequency range of interest do not exceed 1.5 times the NP-6041 Table 2-4 lane 2 bounding

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 32 of 67 spectrum (e.g. 1.8g peak spectral acceleration), the "Equipment Capacity" HCLPF is conservatively limited to the RLGM PGA of 0.37g.

7.0

Inaccessible Items 7.1

Identification of ESEL Items Inaccessible for Walkdowns Fifteen ESEL items were not accessible to the SRT during the ESEP walkdowns at LaSalle County Station. A description of circumstances and disposition for these items is provided below.

U1 SRVs and their accumulators (see Section 6.3.2 for component IDs):

The U1 SRVs were not walked down by the SRT due to Radiation Protection concerns given that the components are located within the Drywell and Unit 1 was not in outage during the available SRT walkdown window. In anticipation of not having at-power Drywell access, LaSalle County Station engineers entered the drywell during the U1 outage in February of 2014 and took photographs of the components to the satisfaction of the SRT. The photographs were reviewed by the SRT and determined to be acceptable for evaluation of the U1 SRVs and their accumulators (including the consideration of potential seismic interaction), with no further walkdowns, in accordance with the methodology of NP-6041.

2E51-F031:

This valve was not walked down by the SRT due to the component being located in a contaminated and high radiation area. Existing photos from Radiation Protection were reviewed by the SRT and determined to be acceptable for evaluation of 2E51-F031 (including the consideration of potential seismic interaction), with no further walkdowns, in accordance with the methodology of NP-6041.

7.2

Planned Walkdown / Evaluation Schedule / Close Out No additional walkdowns are required.

8.0

ESEP Conclusions and Results 8.1

Supporting Information LaSalle County Generating Station 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.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 33 of 67 The ESEP is part of the overall LaSalle County Generating Station response to the NRC's 50.54(f) letter [1]. On March 12, 2014, NEI submitted to the NRC results of a study [9] 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. 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 [11] concluded that the "fleetwide 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."

An assessment of the change in seismic risk for LaSalle was included in the fleet risk evaluation submitted in the March 12, 2014 NEI letter [9] therefore, the conclusions in the NRC's May 9 letter [11]

also apply to LaSalle County Generating Station.

In addition, the March 12, 2014 NEI letter [9] 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 of 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 the 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, and

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.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 34 of 67 8.2

Summary of ESEP Identified and Planned Modifications The results of the LaSalle County Generating Station ESEP performed as an interim action in response to the NRC's 50.54(f) letter [1] using the methodologies in the NRC endorsed guidance in EPRI 3002000704 [2] show that all equipment evaluated are adequate in resisting the seismic loads expected to result from the site RLGM. Therefore, no plant modifications are required as a result of the LaSalle County Generating Station ESEP.

8.3

Modification Implementation Schedule No modification implementation schedule is required because no modifications are required.

8.4

Summary of Regulatory Commitments No regulatory commitments are required.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 35 of 67 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

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

3

Order Number EA-12-049 responses:

3.1

Overall Integrated Plan in Response to March 12, 2012 Commission Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design Basis External Events (Order Number EA-12-049) dated February 28, 2013, Correspondence No. RS-13-021 3.2

First Six-Month Status Report in Response to March 12, 2012 Commission Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond Design-Basis External Events (Order Number EA-12-049) dated August 28, 2013, Correspondence No. RS-13-121 3.3

Second Six-Month Status Report in Response to March 12, 2012 Commission Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond Design-Basis External Events (Order Number EA-12-049) dated February 28, 2014, Correspondence No. RS-14-011 3.4

Third Six-Month Status Report in Response to March 12, 2012 Commission Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond Design-Basis External Events (Order Number EA-12-049) dated August 28, 2014, Correspondence No. RS-14-209 4

Seismic Hazard and Screening Report in Response to the 50.54(f) Information Request Regarding Fukushima Near-Term Task Force Recommendation 2.1: Seismic for LaSalle County Generating Station Units 1 and 2 dated 3/25/14, Correspondence No. RS-14-068 (S&L Report SL-012194, Revision 1) 5

A Methodology for Assessment of Nuclear Power Plant Seismic Margin, Rev. 1, August 1991, Electric Power Research Institute, Palo Alto, CA. EPRI NP-6041 6

Methodology for Developing Seismic Fragilities, August 1991, EPRI, Palo Alto, CA. 1994, TR-103959 7

LaSalle County Generating Station HCLPF Calculations for the ESEP project

a. 14Q4238-CAL-001 "Generation of In-Structure Response Spectra for Use in ESEP Evaluations" Rev. 1

b. 14Q4238-CAL-002 "Seismic Capacity of Components for ESEP" Rev. 0

c. 1404238-CAL-003 "Seismic Capacity of Masonry Structures for ESEP" Rev. 1

d. 14Q4238-CAL-004 "HCLPF Seismic Capacity of Miscellaneous ESEP Components". Rev. 1

e. 14Q4238-CAL-005 "ESEP HCLPFs for Relays" Rev. 1

f.

14Q4238-CAL-006 "Finite Element Analysis of Select Masonry Walls" Rev. 2 8

Nuclear Regulatory Commission, NUREG/CR-0098, Development of Criteria for Seismic Review of Selected Nuclear Power Plants, published May 1978 9

Nuclear Energy Institute (NEI), A. Pietrangelo, Letter to E. Leeds of the USNRC, "Seismic Risk Evaluations for Plants in the Central and Eastern United States", March 12, 2014 10 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

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 36 of 67 11

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-lchi Accident," May 9, 2014 12 Seismic Evaluation Guidance: Screening, Prioritization and Implementation Details (SPID) for the Resolution of Fukushima Near-Term Task Force Recommendation 2.1: Seismic. EPRI, Palo Alto, CA: February 2013. 1025287 13 NRC (E Leeds) Letter to NEI (J Pollock), Electric Power Research Institute Final Draft Report, "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 14 Seismic walkdown reports in response to the 50.54(f) information request regarding Fukushima Near-Term Task Force Recommendation 2.3:

14.1

Correspondence RS-12-163, Report 12Q0108.50-R-001, Revision 1, Unit 1 14.2

Correspondence RS-12-163, Report 12Q0108.50-R-002, Revision 1, Unit 2 15 LaSalle County Power Station Updated Final Safety Analysis Report (UFSAR), Revision 20 16 LaSalle Calculation DC-SE-02-LS, Rev. 03 "Seismic Response Spectra Design Criteria" 17 EPRI Technical Report (TR) 1019200, "Seismic Fragility Applications Guide Update," December 2009 18 S&A Report No.: 14Q4238-RPT-003 Rev 4, Validation of Expedited Seismic Equipment List 19 LaSalle County Generating Station Drawings

a. LAS Drawing M-142 Sheet 1, Rev. AY, P&ID Residual Heat Removal System (R.H.R.S)

b. LAS Drawing M-55 Sheet 1, Rev. Y, P&ID Main Steam

c. LAS Drawing M-66 Sheet 2, Rev. V, P&ID Dwell Pneumatic System

d. LAS Drawing M-66 Sheet 4, Rev. AB, P&ID Drywell Pneumatic System

e. LAS Drawing M-66 Sheet 8, Rev. H, P&ID Drywell Pneumatic System

f. LAS Drawing M-66 Sheet 7, Rev. U, P&ID Drywell Pneumatic System

g. LAS Drawing M-116 Sheet 1, Rev. N, P&ID Main Steam

h. LAS Drawing M-142 Sheet 2, Rev. AX, P&ID Residual Heat Removal System (R.H.R.S.)

I.

LAS Drawing M-87 Sheet 1, Rev. BG, P&ID Core Standby Cooling System Equipment Cooling Water System

j. LAS Drawing M-96 Sheet 2, Rev. AZ, P&ID Residual Heat Removal System (R.H.R.S.)

k. LAS Drawing M-96 Sheet 1, Rev. AZ, P&ID Residual Heat Removal System (R.H.R.S.)

I.

LAS Drawing M-101 Sheet 1, Rev. BH, P&ID Reactor Core Isolation Coolant (R.C.I.C)

m. LAS Drawing M-101 Sheet 2, Rev. AR, P&ID Reactor Core Isolation Coolant System (R.C.I.C)

n. LAS Drawing M-85 Sheet 1, Rev. AE, P&ID Diesel Oil System

o. LAS Drawing M-132, Rev. AC, P & ID Diesel Oil System

p. LAS Drawing M-98 Sheet 1, Rev AO, P&ID Fuel Pool Cooling Filter & Demineralizing System

q. LAS Drawing M-134 Sheet 1, Rev AU, P&I D CSCS Equipment Cooling Water System

r. LAS Drawing M-144 Sheet 1, Rev AL, P&ID Fuel Pool Cooling Filter & Demineralizing System

s. LAS Drawing M-147 Sheet 1, Rev BL, P&ID Reactor Core Isolation Coolant System (R.C.I.C.)

t. LAS Drawing M-147 Sheet 2, Rev AO, P&ID Reactor Core Isolation Coolant System (R.C.I.C.)

19 SQUG Advisory Memo No.: 2004-02, Relay GERS Corrections, September 2004

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 37 of 67 20 EPRI Report No.: NP-5223-SL Rev 1, Generic Ruggedness of Power Plant Equipment 21

S&A Letter Received from Client LRC-006, "ESEL Validation Report and Input to FLEX Plan."

October 27, 2014

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 38 of 67 Attachment A LaSalle County Generating Station Unit 1 ESEL

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 39 of 67 E

a).,

53 Equipment ID Description Equipment Normal State Equipment Desired State Notes 135X 480VAC Sw. Gr. (1AP19E) (Div. 1)

In Service In Service 4

135X-3 480VAC MCC (1AP73E)(Div. 1)

In Service In Service 54 136X 480VAC Sw. Gr. (1AP21E) (Div. 2)

In Service In Service 13 136X-3 480VAC MCC (1AP81E)(Div. 2)

In Service In Service 55 136Y 480VAC Sw. Gr. (1AP22E) (Div. 2)

In Service In Service 218 136Y-1 480V MCC (1AP82E)

In Service In Service 98 1B21-A003C "C" ADS SRV Accumulator In Service In Service Passive Component 101 1B21-A003D "D" ADS SRV Accumulator In Service In Service Passive Component 104 1B21-A003E "E" ADS SRV Accumulator In Service In Service Passive Component 107 1B21-A003R "R" ADS SRV Accumulator In Service In Service Passive Component 110 1B21-A003S "S" ADS SRV Accumulator In Service In Service Passive Component 113 1B21-A003U "U" ADS SRV Accumulator In Service In Service Passive Component 116 1B21-A003V "V" ADS SRV Accumulator In Service In Service Passive Component 99 1621C-S008A "C" ADS SRV Hand switch @ Panel 1H13-P628 In Service In Service 102 1B21C-S009A "D" ADS SRV Hand switch @ Panel 1H13-P628 In Service In Service 105 11321C-S010A "E" ADS SRV Hand switch @ Panel 1H13-P628 In Service In Service 108 1B21C-S011A "R" ADS SRV Hand switch @ Panel 1H13-P628 In Service In Service 111 11321C-S012A "S" ADS SRV Hand switch @ Panel 1H13-P628 In Service In Service 114 1B21C-S013A "U" ADS SRV Hand switch @ Panel 1H13-P628 In Service In Service 117 11321C-S014A "V" ADS SRV Hand switch @ Panel 1H13-P628 In Service In Service 97 1B21-F013C "C" ADS SRV In Service In Service 100 1B21-F013D "D" ADS SRV In Service In Service 103 1B21-F013E "E" ADS SRV In Service In Service 106 1B21-F013R "R" ADS SRV In Service In Service 109 1B21-F013S "S" ADS SRV In Service In Service 112 1B21-F013U "U" ADS SRV In Service In Service 115 1B21-F013V "V" ADS SRV In Service In Service 70 1B21-N026DA RPV Level Transmitter (feeds 1061-R010)

In Service In Service 68 1061-N006 RPV Pressure Transmitter (feeds 1061-R011)

In Service In Service 219 1061-P001 Panel In Service In Service 69 1061-R010 RPV Level (WR) Indicator @ Panel 1061-P001 Standby In Service 67 1061-R011 RPV Pressure Indicator @ Panel 1061-P001 Standby In Service 19 1DC01E 250V Battery (Div. 1)

In Service In Service 20 1DCO2E 250V0C Bus #1 In Service In Service 22 1DC03E 250V0C Battery Charger #1 In Service In Service

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 40 of 67 E

2 Equipment ID Description Equipment Normal State Equipment Desired State Notes 21 1DC06E 250VDC MCC 121Y In Service In Service 1

1DC07E 125V Battery 1A (Div. 1)

In Service In Service 2

1DC08E 125VDC Bus 1A (Div. 1)

In Service In Service 5

1DC09E 125VDC Battery Main Charger 1AA In Service In Service 3

1DC11E 125VDC Dist. Panel 111Y (Div. 1)

In Service In Service 12 1DC13E 125VDC Dist. Panel 112Y (Div. 2)

In Service In Service 10 1DC14E 125V Battery 1B (Div. 2)

In Service In Service 11 1DC15E 125VDC Bus 1B (Div. 2)

In Service In Service 14 1DC17E 125VDC Battery Main Charger IBA In Service In Setvice 220 1DGO3J Diesel Panel In Service In Service 61 1D001P Diesel Generator Fuel Transfer Pump (Div. 2)

In Service In Service 59 1D001T Diesel Fuel Storage Tank (Div. 2)

In Service In Service Passive Component 60 1D005T Diesel Generator Day Tank (Div. 2)

In Service In Service Passive Component 221 1E12-B001B B RHR HEAT EXCHANGER Available Available Passive Component 209 1E12-F016B B' RHR Outboard Primary Containment Spray Isolation Valve In Service In Service Manually open as needed 198 1E12-F027B "B" RHR Suppression Chamber Spray Valve In Service -

Closed In Service -

Open Manually open as needed 197 1E12-F042B "Be RHR (LPCI) RPV Injection Valve In Service -

Closed In Service -

Open Manually open as needed 222 1E31-N022A Pressure Switch in Cabinet 1H22-P017 Open Contact Open Contact 223 1E31-N022B Pressure Switch in Cabinet 1H22-P029 Open Contact Open Contact 224 1E31-N022C Pressure Switch in Cabinet 1H22-P017 Open Contact Open Contact 225 1E31-N022D Pressure Switch in Cabinet 1H22-P029 Open Contact Open Contact 226 1E51A-K015 Relay in Cabinet 1H13-P621 De-Energized De-Energized 227 1E51A-K029 Relay in Cabinet 1H13-P621 De-Energized De-Energized 228 1E51A-K032 Relay in Cabinet 1H13-P618 De-Energized De-Energized 4 second time delay pick-up relay controlled by 1E31-N007BA. Time delay prevents chatter on 1E31-N007BA from affecting control circuit.

229 1E51A-K033 Relay in Cabinet 1H13-P618 De-Energized De-Energized 230 1E51A-K039 Relay in Cabinet 1H13-P618 De-Energized De-Energized 231 1E51A-K047 Relay in Cabinet 1H13-P621 De-Energized De-Energized 4 second time delay pick-up relay controlled by 1E31-N013AA. Time delay prevents chatter on 1E31-N013M from affecting control circuit.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 41 of 67 a

E 2 Equipment ID Description Equipment Normal State Equipment Desired State Notes 232 1E51A-K048 Relay in Cabinet 1H13-P618 De-Energized De-Energized 4 second time delay pick-up relay controlled by 1E31-N013BA. Time delay prevents chatter on 1E31-N013BA from affecting control circuit.

233 1E51A-K054 Relay in Cabinet 1H13-P621 De-Energized De-Energized 234 1E51A-K055 Relay in Cabinet 1H13-P621 De-Energized De-Energized 235 1E51A-K057 Relay in Cabinet 1H13-P618 De-Energized De-Energized 236 1E51A-K058 Relay in Cabinet 1H13-P618 De-Energized De-Energized 237 1E51A-K006 Relay in Cabinet 1H13-P621 De-Energized De-Energized 238 1E51A-K060 Relay in Cabinet 1H13-P618 De-Energized De-Energized 239 1E51A-K007 Relay in Cabinet 1H13-P621 De-Energized De-Energized 240 1E51A-K008 Relay in Cabinet 1H13-P621 De-Energized De-Energized 152 1E51A-S003 RCIC Steam Inlet MOV Hand switch @ Panel 1H13-P601 In Service In Service 170 1E51A-S004 RCIC CST Suction Valve Hand switch @ Panel 1H13-P601 In Service In Service 161 1E51A-S005 RCIC Injection Valve Hand switch @ Panel 1H13-P601 In Service In Service 168 1E51A-S008 RCIC Lube Oil Cooling Flow Valve Hand switch

@ Panel 1H13-P601 In Service In Service 165 1E51A-S009 RCIC Min Flow Return to Suppression Pool Valve Hand switch @ Panel 1H13-P601 In Service In Service 162 1E51A-S010 RCIC Suppression Pool Suction Valve Hand switch @ Panel 1H13-P601 In Service In Service 157 1E51A-S014 RCIC Barometric Condenser Condensate Pump Hand switch @ Panel 1H13-P601 In Service In Service 159 1E51A-S015 RCIC Barometric Condenser Vacuum Pump Hand switch @ Panel 1H13-P601 in Service In Service 154 1E51A-S026 RCIC Turbine Trip & Throttle Valve Hand switch

@ Panel 1H13-P601 In Service In Service 148 1E51-0001 RCIC Pump Standby In Service 147 1E51-0002 RCIC Turbine & Barometric Condenser Standby In Service 156 1E51-0004 RCIC Barometric Condenser Condensate Pump (DC)

Standby In Service 158 1E51-0005 RCIC Barometric Condenser Vacuum Pump (DC)

Standby In Service 169 1E51-F010 RCIC CST Suction Valve (DC)

In Service -

Open In Service -

Closed 160 1E51-F013 RCIC Injection Valve (DC)

In Service -

Closed In Service -

Open 164 1E51-F019 RCIC Min Flow Return to Suppression Pool Valve (DC)

In Service In Service

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 42 of 67 4t E

2 Equipment ID Description Equipment Normal State Equipment Desired State Notes 163 1E51-F031 RCIC Suppression Pool Suction Valve (DC)

In Service -

Closed In Service -

Open 151 1E51-F045 RCIC Steam Inlet MOV (DC)

In Service -

Closed In Service -

Open 167 1E51-F046 RCIC Lube Oil Cooling Flow Valve In Service -

Closed In Service -

Open 153 1E51-F360 RCIC Turbine Trip & Throttle Valve (DC)

In Service -

Closed In Service -

Open 155 1E51-F361 RCIC Governor Valve (HO)

In Service -

Closed In Service -

Open 205 1E51-K601 RCIC Square Root Converter @ Panel 1H13-P601 In Service in Service 203 1E51-N003 RCIC Flow Transmitter @ Panel 1H22-P017 In Service In Service 241 1E51-N006 Pressure Switch in Cabinet 1H22-P017 Open Contact Open Contact 84 1E51-N007 RCIC Steam Supply Pressure Xmtr @ Panel 1H22-P017 In Service In Service 242 1E51-N009A Pressure Switch in Cabinet 1H22-P017 Open Contact Open Contact 243 1E51-N009B Pressure Switch in Cabinet 1H22-P017 Open Contact Open Contact 244 1E51-N012A Pressure Switch in Cabinet 1H22-P017 Open Contact Open Contact 245 1E51-N012B Pressure Switch in Cabinet 1H22-P029 Open Contact Open Contact 246 1E51-N012C Pressure Switch in Cabinet 1H22-P017 Open Contact Open Contact 247 1E51-N012D Pressure Switch in Cabinet 1H22-P029 Open Contact Open Contact 149 1E51-R600 RCIC Pump Discharge Flow Controller Standby In Service 83 1E51-R602 RCIC Steam Supply Pressure Indicator @

Panel 1H13-P601 In Service In Service 150 1E51-R606 RCIC Pump Discharge Flow Indicator @ Panel 1H13-P601 Standby In Service 23 1EI-DC055 250V0C System Battery Volts Indicator @

Panel 1PM01J In Service In Service 25 1EI-DC056 250VDC System Battery Charger Volts Indicator @ Panel 1PM01J In Service In Service 6

1EI-DC057 125VDC Battery Voltage indicator @ Panel 1PM01J (Div. 1)

In Service In Service 8

1EI-DC058 125VDC Battery Charger Volts Indicator @

Panel 1PM01J (Div. 1)

In Service in Service 15 1EI-DC059 125VDC Battery Voltage Indicator @ Panel 1PM01J (Div. 2)

In Service In Service 17 1EI-DC060 125VDC Battery Charger Volts Indicator @

Panel 1PM01J (Div. 2)

In Service In Service 248 1H13-P601 Emerg. Core Cool System Panel In Service In Service 249 1H13-P612 FEEDWATER / RECIRC VERTICAL BOARD In Service In Service 250 1H13-P618 DIVISION II RHR RELAY VERTICAL BOARD In Service In Service 251 1H13-P621 RCIC RELAY PANEL In Service In Service

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 43 of 67 n

E 2

Equipment ID Description Equipment Normal State Equipment Desired State Notes 252 1H13-P628 ADS SRV Panel In Service In Service 253 1H13-P629 DIVISION I - LPCS / RHR RELAY VERTICAL BOARD In Service In Service 254 1H13-P631 AUTOMATIC DEPRESSURIZATION SYS B RELAY VERTICAL BOARD In Service In Service 255 1H22-P017 RCIC Instrument Rack In Service In Service 256 1H22-P029 Instrumentation Cabinets In Service In Service 62 1HS-D001 Diesel Generator Fuel Transfer Pump Hand switch In Service In Service 24 111-DC049 250VDC System Battery Amps Indicator @

Panel 1PM01J In Service In Service 26 111-DC050 250V0C System Battery Charger Amps Indicator @ Panel 1PM01J In Service In Service 7

111-DC051 125VDC Battery Amps Indicator @ Panel 1PM01J (Div. 1)

In Service In Service 9

111-DC052 125VDC Battery Charger Amps Indicator @

Panel 1PM01J (Div. 1)

In Service In Service 16 111-DC053 125VDC Battery Amps Indicator @ Panel 1PM01J (Div. 2)

In Service In Service 18 111-DC054 125VDC Battery Charger Amps Indicator @

Panel 1PM01J (Div. 2)

In Service In Service 257 1IN035 A N2 MANIFOLD PRESS REG In Service In Service 258 11N038 B N2 MANIFOLD PRESS REG In Service In Service 139 11NO9MA Nitrogen Bottle Bank (South Side) Gas Manifold System In Service In Service Passive Component 140 11NO9MB Nitrogen Bottle Bank (North Side) Gas Manifold System In Service In Service Passive Component 215 1L1-CM192 Wide Range Suppression Pool Water Level

@1H13-P601 panel In Service In Service 259 1LT-CM030 SUP POOL WIDE RANGE LEVEL XMTR In Service In Service 211 1PI-CM029 Wide Range OW Pressure @1H13-P601 panel In Service in Service 213 1PI-CM056 S-POOL PRESS In Service in Service 260 1PM01J Battery Charger Panel In Service In Service 261 1PM16J ASSY - PANEL, P/C MONITOR/LEAK DETECTION In Service In Service 262 1PT-CM029 PAM WIDE RANGE DRYWELL PRESS TRANSMITTER In Service In Service 263 1PT-CM056 SUP POOL PRESS XMTR In Service In Service 91 1TI-CM037 Suppression Pool Water Temperature Indicator

@ Panel 1061-P001 In Service In Service 87 1TI-CM045 Drywell Temperature Indicator @ Panel 1061-P001 In Service In Service

140.4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 44 of 67 gt E

2 Equipment ID Description Equipment Normal State Equipment Desired State Notes 166 No EPN RCIC Lube Oil Cooler In Service In Service Passive Component; Rule of the Box (ROB) component to parent 1E51-0001 207 No EPN RCIC Woodward Governor (on RCIC Turbine)

In Service In Service ROB to parent 1E51-C001

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 45 of 67 Attachment B LaSalle County Generating Station Unit 2 ESEL

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 46 of 67 Item #

Equipment ID Description Equipment Normal State Equipment Desired State Notes 56 235X 480VAC Sw. Gr. (2AP19E) (Div. 1)

In Service In Service 30 235X-3 480VAC MCC (2AP73E)(Div. 1)

In Service In Service 57 236X 480VAC Sw. Gr. (2AP21E) (Div. 2)

In Service In Service 39 236X-3 480VAC MCC (2AP81E)(Div. 2)

In Service In Service 58 236Y 480VAC Sw. Gr. (2AP22E) (Div. 2)

In Service In Service 264 236Y-1 480V MCC (2AP82E)

In Service In Service 119 2B21-A003C "C" ADS SRV Accumulator In Service In Service Passive Component 122 2821-A003D "D" ADS SRV Accumulator In Service In Service Passive Component 125 21321-A003E "E" ADS SRV Accumulator In Service In Service Passive Component 128 2B21-A003R "R" ADS SRV Accumulator In Service In Service Passive Component 131 2B21-A003S "S" ADS SRV Accumulator In Service In Service Passive Component 134 2B21-A003U "U" ADS SRV Accumulator In Service In Service Passive Component 137 21321-A003V "V" ADS SRV Accumulator In Service In Service Passive Component 120 2B21C-5008A "C" ADS SRV Hand switch @ Panel 2H13-P628 In Service In Service 123 2821C-S009A "D" ADS SRV Hand switch @ Panel 2H13-P628 In Service In Service 126 2B21C-S010A "E" ADS SRV Hand switch @ Panel 2H13-P628 In Service In Service 129 2B21C-S011A "R" ADS SRV Hand switch @ Panel 2H13-P628 In Service In Service 132 2B21C-S012A "S" ADS SRV Hand switch @ Panel 2H13-P628 In Service In Service 135 2B21C-S013A "U" ADS SRV Hand switch @ Panel 2H13-P628 In Service In Service 138 2B21C-S014A "V" ADS SRV Hand switch @ Panel 2H13-P628 In Service In Service 118 2B21-F013C "C" ADS SRV In Service In Service 121 2B21-F013D "D" ADS SRV In Service In Service 124 2821-F013E "E" ADS SRV In Service In Service 127 2621-F013R "R" ADS SRV In Service In Service 130 2821-F013S "S" ADS SRV In Service In Service 133 2B21-F013U "U" ADS SRV In Service In Service 136 2821-F013V "V" ADS SRV In Service In Service 74 2821-N026DA RPV Level Transmitter (feeds 2C61-R010)

In Service In Service 72 2C61-N006 RPV Pressure Transmitter (feeds 2C61-R011)

In Service In Service 265 2C61-P001 Instrument Panel In Service In Service 73 2C61-R010 RPV Level (WR) Indicator @ Panel 2C61-P001 Standby In Service 71 2C61-R011 RPV Pressure Indicator @ Panel 2C61-P001 Standby In Service 45 2DC01E 250V Battery (Div. 1)

In Service In Service 46 2DCO2E 250VDC Bus #1 In Service In Service 48 2DC03E 250VDC Battery Charger #2 In Service In Service

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 47 of 67 a

E 2

Equipment ID Description Equipment Normal State Equipment Desired State Notes 47 2DC06E 250VDC MCC 221Y In Service In Service 27 2DC07E 125V Battery 2A (Div. 1)

In Service In Service 28 2DC08E 125VDC Bus 2A (Div. 1)

In Service In Service 31 2DC09E 125VDC Battery Main Charger 2AA In Service In Service 29 2DC11E 125VDC Dist. Panel 211Y (Div. 1)

In Service In Service 38 2DC13E 125VDC Dist. Panel 212Y (Div. 2)

In Service In Service 36 2DC14E 125V Battery 2B (Div. 2)

In Service In Service 37 2DC15E 125VDC Bus 2B (Div. 2)

In Service In Service 40 2DC17E 125VDC Battery Main Charger 2BA In Service In Service 266 2DGO3J Diesel Panel In Service In Service 65 20001P Diesel Generator Fuel Transfer Pump (Div. 2)

In Service In Service 63 2D001T Diesel Fuel Storage Tank (Div. 2)

In Service In Service Passive Component 64 2D005T Diesel Generator Day Tank (Div. 2)

In Service In Service Passive Component 267 2E12-B001B 2B RHR HEAT EXCHANGER Available Available Passive Component 210 2E12-F016B B' RHR Outboard Primary Containment Spray Isolation Valve In Service In Service Manually open as needed 202 2E12-F027B "B" RHR Suppression Chamber Spray Valve In Service -

Closed In Service -

Open Manually open as needed 201 2E12-F042B "B" RHR (LPCI) RPV Injection Valve In Service -

Closed In Service -

Open Manually open as needed 268 2E31-N022A Pressure Switch in Cabinet 2H22-P017 Open Contact Open Contact 269 2E31-N022B Pressure Switch in Cabinet 2H22-P029 Open Contact

-t Open Contact 270 2E31-N022C Pressure Switch in Cabinet 2H22-P017 Open Contact Open Contact 271 2E31-N0220 Pressure Switch in Cabinet 2H22-P029 Open Contact Open Contact 272 2E51A-K015 Relay in Cabinet 2H13-P621 De-Energized De-Energized 273 2E51A-K029 Relay in Cabinet 2H13-P621 De-Energized De-Energized 274 2E51A-K032 Relay in Cabinet 2H13-P618 De-Energized De-Energized Four second time delay pick-up relay controlled by 2E31-N007BA. Time delay prevents chatter on 2E31-NO07BA from affecting control circuit.

275 2E51A-K033 Relay in Cabinet 2H13-P618 De-Energized De-Energized 276 2E51A-K039 Relay in Cabinet 2H13-P618 De-Energized De-Energized 277 2E51A-K047 Relay in Cabinet 2H13-P621 De-Energized De-Energized Four second time delay pick-up relay controlled by 2E31-N013AA. Time delay prevents chatter on 2E31-NO13AA from affecting control circuit.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 48 of 67 E

S Equipment ID Description Equipment Normal State Equipment Desired State Notes

_I Four second time delay pick-up relay controlled by 2E31-N013BA. Time delay prevents chatter on 2E31-NO13BA from affecting control circuit.

278 2E51A-K048 Relay in Cabinet 2H13-P618 De-Energized De-Energized 279 2E51A-K054 Relay in Cabinet 2H13-P621 De-Energized De-Energized 280 2E51A-K055 Relay in Cabinet 2H13-P621 De-Energized De-Energized 281 2E51A-K057 Relay in Cabinet 2H13-P618 De-Energized De-Energized 282 2E51A-K058 Relay in Cabinet 2H13-P618 De-Energized De-Energized 283 2E51A-K006 Relay in Cabinet 2H13-P621 De-Energized De-Energized 284 2E51A-K060 Relay in Cabinet 2H13-P618 De-Energized De-Energized 285 2E51A-K007 Relay in Cabinet 2H13-P621 De-Energized De-Energized 286 2E51A-K008 Relay in Cabinet 2H13-P621 De-Energized De-Energized 176 2E51A-S003 RCIC Steam Inlet MOV Hand switch @ Panel 2H13-P601 In Service In Service 194 2E51A-S004 RCIC CST Suction Valve Hand switch @ Panel 2H13-P601 In Service In Service 185 2E51A-S005 RCIC Injection Valve Hand switch @ Panel 2H13-P601 In Service In Service 192 2E51A-S008 RCIC Turbine Cooling Water Supply Valve Hand switch @ Panel 2H13-P601 In Service In Service 189 2E51A-S009 RCIC Min Flow Bypass to Suppression Pool Valve Hand switch @ Panel 2H13-P601 In Service In Service 186 2E51A-S010 RCIC Suppression Pool Suction Valve Hand switch @ Panel 2H13-P601 In Service In Service 181 2E51A-S014 RCIC Barometric Condenser Condensate Pump Hand switch @ Panel 2H13-P601 In Service In Service 183 2E51A-S015 RCIC Barometric Condenser Vacuum Pump Hand switch @ Panel 2H13-P601 In Service In Service 178 2E51A-S026 RCIC Turbine Trip & Throttle Valve Hand switch

@ Panel 2H13-P601 In Service In Service 172 2E51-0001 RCIC Pump Standby In Service 171 2E51-0002 RCIC Turbine & Barometric Condenser Standby In Service 180 2E51-0004 RCIC Barometric Condenser Condensate Pump (DC)

Standby In Service 182 2E51-0005 RCIC Barometric Condenser Vacuum Pump (DC)

Standby In Service 193 2E51-F010 RCIC CST Suction Valve (DC)

In Service -

Open In Service -

Closed 184 2E51-F013 RCIC Injection Valve (DC)

In Service -

Closed In Service -

Open 188 2E51-F019 RCIC Min Flow Return to Suppression Pool Valve (DC)

In Service In Service

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 49 of 67 n

E co Equipment ID Description Equipment Normal State Equipment Desired State Notes 187 2E51-F031 RCIC Suppression Pool Suction Valve (DC)

In Service -

Closed In Service -

Open In Service -

Open 175 2E51-F045 RCIC Steam Inlet MOV (DC)

In Service -

Closed 191 2E51-F046 RCIC Lube Oil Cooling Flow Valve In Service -

Closed In Service -

Open 177 2E51-F360 RCIC Turbine Trip & Throttle Valve (DC)

In Service -

Closed In Service -

Open 179 2E51-F361 RCIC Governor Valve (HO)

In Service -

Closed In Service -

Open 206 2E51-K601 RCIC Square Root Converter @ Panel 2H13-P601 In Service In Service 204 2E51-N003 RCIC Flow Transmitter @ Panel 2H22-P017 In Service In Service 287 2E51-N006 Pressure Switch in Cabinet 2H22-P017 Open Contact Open Contact 86 2E51-N007 RCIC Steam Supply Pressure Xmtr @ Panel 2H22-P017 In Service In Service 288 2E51-N009A Pressure Switch in Cabinet 2H22-P017 Open Contact Open Contact 289 2E51-N009B Pressure Switch in Cabinet 2H22-P017 Open Contact Open Contact 290 2E51-N012A Pressure Switch in Cabinet 2H22-P017 Open Contact Open Contact 291 2E51-N012B Pressure Switch in Cabinet 2H22-P029 Open Contact Open Contact 292 293 2E51-N012C Pressure Switch in Cabinet 2H22-P017 Open Contact Open Contact 2E51-N012D Pressure Switch in Cabinet 2H22-P029 Open Contact Open Contact 173 2E51-R600 RCIC Pump Discharge Flow Controller Standby In Service 85 2E51-R602 RCIC Steam Supply Pressure Indicator @ Panel 2H13-P601 In Service In Service 174 2E51-R606 RCIC Pump Discharge Flow Indicator @ Panel 2H13-P601 Standby In Service 49 2EI-DC055 250VDC System Battery Volts Indicator @ Panel 2PM01J In Service In Service 51 2EI-00056 250VDC System Battery Charger Volts Indicator

@ Panel 2PM01J In Service In Service 32 2E1-DC057 125VDC Battery Voltage Indicator @ Panel 2PM01J (Div. 1)

In Service In Service 34 2E1-DC058 125VDC Battery Charger Volts Indicator @

Panel 2PM01J (Div. 1)

In Service In Service 41 2EI-DC059 125VDC Battery Voltage Indicator @ Panel 2PM01J (Div. 2)

In Service In Service 43 2E1-DC060 125VDC Battery Charger Volts Indicator @

Panel 2PM01J (Div. 2)

In Service In Service 294 2H13-P601 Emerg. Core Cool System Panel In Service In Service 295 2H13-P612 ASSY - PANEL, FEED WATER/RECIRCULATION In Service In Service 296 2H13-P618 ASSY - PANEL, DIV-2 RHR RELAY In Service In Service 297 2H13-P621 ASSY - PANEL, RI RELAY In Service In Service

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 50 of 67 Item #

Equipment ID Description Equipment Normal State Equipment Desired State Notes 298 2H13-P628 ADS SRV Panel In Service In Service 299 2H13-P629 ASSY - PANEL, DIV-1 LPCS/RHR RELAY In Service In Service 300 2H13-P631 ASSY - PANEL, AUTOMATIC DEPRESSION SYST B RELAY In Service In Service 301 2H22-P017 RCIC Transmitter Panel In Service In Service 302 2H22-P029 Instrumentation Cabinets In Service In Service 66 2HS-D001 Diesel Generator Fuel Transfer Pump Hand switch In Service In Service 50 211-DC049 250VDC System Battery Amps Indicator @

Panel 2PM01J In Service In Service 52 211-DC050 250VDC System Battery Charger Amps Indicator @ Panel 2PM01J In Service In Service 33 211-DC051 125VDC Battery Amps Indicator @ Panel 2PM01J (Div. 1)

In Service In Service In Service 35 211-DC052 125VDC Battery Charger Amps Indicator @

Panel 2PM01J (Div. 1)

In Service 42 211-DC053 125VDC Battery Amps Indicator @ Panel 2PM01J (Div. 2)

In Service In Service 44 211-DC054 125VDC Battery Charger Amps Indicator @

Panel 2PM01J (Div. 2)

In Service In Service 303 2IN035 VALVE, U2 SOUTH BANK IN REG In Service In Service 304 2IN038 VALVE, NORTH BANK IN REG In Service In Service 143 21NO9MA Nitrogen Bottle Bank (South Side) Gas Manifold System In Service In Service Passive Component 144 21NO9MB Nitrogen Bottle Bank (North Side) Gas Manifold System In Service In Service Passive Component 216 2L1-CM192 Wide Range Suppression Pool Water Level

@2H13-P601 panel In Service In Service 305 2LT-CM030 S-POOL WIDE RANGE LVL XMITTER In Service In Service 212 2PI-CM029 Wide Range DW Pressure @2H13-P601 panel In Service In Service 214 2P1-CM056 S-POOL PRESS In Service In Service 306 2PM01J Battery Charger Panel In Service In Service 307 2PM16J ASSY - PANEL, P/C MONITOR/LEAK DETECTION In Service In Service 308 2PT-CM029 D/W PRESS WIDE RANGE PRESS XMITTER In Service In Service 309 2PT-CM056 S-POOL PRESS XMITTER In Service In Service 92 2T1-CM037 Suppression Pool Water Temperature Indicator

@ Panel 2C61-P001 In Service In Service 88 2T1-CM045 Drywell Temperature Indicator @ Panel 2C61-P001 In Service In Service 190 No EPN RCIC Lube Oil Cooler In Service In Service Passive Component; ROB to parent 1E51-0001 208 No EPN RCIC Woodward Governor (on RCIC Turbine)

In Service In Service ROB to parent 1E51-0001

140.4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 51 of 67 Attachment C - LaSalle Unit 1 ESEP HCLPF Values and Failure Mode Tabulation Note: Some items listed on the ESEL were child components contained within host components. These child components are referred to as "Rule of Box" (ROB) items, for which the HCLPF capacities are identical to those of the host item.

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 52 of 67 Equipment ID Description Failure Mode HCLPF (9)

Basis 135X 480VAC Sw. Gr.

(1AP19E) (Div. 1)

Equipment Capacity 0.45 Component is Rule Of Box to 1AP19E. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

135X-3 480VAC MCC (1AP73E)(Div. 1)

Equipment Capacity 0A5 Component is Rule Of Box to 1AP73E. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

136X 480VAC Sw. Gr.

(1AP21E) (Div. 2)

Block Wall Interaction

>RLGM Component is Rule Of Box to 1AP21E. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

136X-3 480VAC MCC (1AP81E)(Div. 2)

Block Wall Interaction

>RLGM Component is Rule Of Box to 1AP81E. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

136Y 480VAC Sw. Gr.

(1AP22E) (Div. 2)

Equipment Capacity 0.45 Component is Rule Of Box to 1AP22E. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

136Y -1 480V MCC (1AP82E)

Equipment Capacity 0.45 Component is Rule Of Box to 1AP82E. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1B21-A003C "C" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40 above grade.

1621-A003D "D" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40' above grade.

1B21-A003E "E" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40' above grade.

1B21-A003R "R" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40' above grade.

1B21-A003S "S" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40' above grade.

1621-A003U "U" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40' above grade.

1821-A003V "V" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40' above grade.

1621C-SOO8A "C" ADS SRV Hand switch @ Panel 1H13-P628 Block Wall Interaction 0.41 Component is Rule Of Box to 1H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1821C-SOO9A "D" ADS SRV Hand switch @ Panel 1H13-P628 Block Wall Interaction 0.41 Component is Rule Of Box to 1H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

11321C-S010A "E" ADS SRV Hand switch @ Panel 1H13-P628 Block Wall Interaction 0.41 Component is Rule Of Box to 1H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1I321C-S011A "R" ADS SRV Hand switch @ Panel 1H13-P628 Block Wall Interaction 0.41 Component is Rule Of Box to 1H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

11321C-S012A "S" ADS SRV Hand switch @ Panel 1H13-P628 Block Wall Interaction 0.41 Component is Rule Of Box to 1H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

11321C-S013A "U" ADS SRV Hand switch @ Panel 1H13-P628 Block Wall Interaction 0.41 Component is Rule Of Box to 1H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1821C-S014A "V" ADS SRV Hand switch @ Panel 1H13-P628 Block Wall Interaction 0.41 Component is Rule Of Box to 1H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1821-F013C "C" ADS SRV Screened

>RLGM Component screened by SRT analysis" 1821-F013D "D" ADS SRV Screened

>RLGM Component screened by SRT analysis 1821-F013E "E" ADS SRV Screened

>RLGM Component screened by SRT analysis 1B21-F013R "R" ADS SRV Screened

>RLGM Component screened by SRT analysis 1821-F013S "S" ADS SRV Screened

>RLGM Component screened by SRT analysis "SRT analysis" involves the quantitative evaluation of applicable screening criteria or failure modes whereas "SRT judgment" relies upon SRT experience and training with qualitative basis for disposition.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 53 of 67 Equipment ID Description Failure Mode HCLPF (9)

Basis 1621-F013U "U" ADS SRV Screened

>RLGM Component screened by SRI analysis 1621-F013V "V" ADS SRV Screened

>RLGM Component screened by SRI analysis 1B21 -

NO26DA RPV Level Transmitter (feeds 1061-R010)

Screened

>RLGM Component screened by SRI judgment 1061-N006 RPV Pressure Transmitter (feeds 1061-R011)

Screened

>RLGM Component screened by SRI judgment 1061-P001 Panel Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1061-R010 RPV Level (WR)

Indicator @ Panel 1061-P001 Block Wall Interaction

>RLGM Component is Rule Of Box to 1061-P001. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-_CAL-002.

1061-R011 RPV Pressure Indicator @ Panel 1061-P001 Block Wall Interaction

>RLGM Component is Rule Of Box to 1061-P001. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

1DC01E 250V Battery (Div. 1)

Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1DCO2E 250VDC Bus #1 Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1DC03E 250VDC Battery Charger #1 Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1DC06E 250VDC MCC 121Y Equipment Capacity 0.45 Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1DC07E 125V Battery 1A (Div. 1)

Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1DC08E 125VDC Bus 1A (Div. 1)

Block Wall Interaction 0.4 Adjacent block wall evaluated in 14Q4238-CAL-003. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1DC09E 125VDC Battery Main Charger 1AA Block Wall Interaction 0.4 Adjacent block wall evaluated in 1404238-CAL-003. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1DC11E 125VDC Dist. Panel 111Y (Div. 1)

Block Wall Interaction 0.4 Component is Rule of Box to 1DC08E. Adjacent block wall evaluated in 1404238-CAL-003. Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

1DC13E 125VDC Dist. Panel 112Y (Div. 2)

Equipment Capacity 0.45 Component is Rule of Box to 1DC15E. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1DC14E 125V Battery 16 (Div. 2)

Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1DC15E 125VDC Bus 16 (Div. 2)

Equipment Capacity 0.45 Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1DC17E 125VDC Battery Main Charger IBA Block Wall Interaction

>RLGM Adjacent block wall evaluated in 14Q4238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1DGO3J Diesel Panel Equipment Capacity 0.45 Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1D001P Diesel Generator Fuel Transfer Pump (Div. 2)

Screened

>RLGM Component screened by SRI judgment.

1D001T Diesel Fuel Storage Tank (Div. 2)

Equipment Capacity 0.45 Component evaluated by HCLPF calculation 14Q4238-CAL-004.

1D005T Diesel Generator Day Tank (Div. 2)

Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 14Q4238-CAL-004.

1E12-60016 B RHR HEAT EXCHANGER Anchorage

/ Block Wall Interaction 0.37 Adjacent block wall evaluated in 1404238-CAL-003. Component per screened; evaluated by HCLPF calculation 1404238-CAL-004.

1E12-F0166 B' RHR Outboard Primary Containment Spray Isolation Valve Screened

>RLGM Component screened by SRI analysis.

1E12-F027B "B" RHR Suppression Chamber Spray Valve Block Wall Interaction 0.37 Adjacent block wall evaluated in 1404238-CAL-003. Component screened by SRI judgment.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 54 of 67 Equipment ID Description Failure Mode HCLPF (3)

Basis 1E12-F042B "8" RHR (LPCI) RPV Injection Valve Screened

>RLGM Component screened by SRT analysis.

1E31-N022A Pressure Switch in Cabinet 1H22-P017 Screened

>RLGM Component is Rule Of Box to 1H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E31-N022B Pressure Switch in Cabinet 1H22-P029 Screened

>RLGM Component is Rule Of Box to 1H22-P029. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E31-N022C Pressure Switch in Cabinet 1H22-P017 Screened

>RLGM Component is Rule Of Box to 1H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E31-N022D Pressure Switch in Cabinet 1H22-P029 Screened

>RLGM Component is Rule Of Box to 1H22-P029. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E51A-K015 Relay in Cabinet 1H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K029 Relay in Cabinet 1H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P621.

Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K032 Relay in Cabinet 1H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K033 Relay in Cabinet 1H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K039 Relay in Cabinet 1H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K047 Relay in Cabinet 1H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K048 Relay in Cabinet 1H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K054 Relay in Cabinet 1H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K055 Relay in Cabinet 1H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K057 Relay in Cabinet 1H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

1 E51A-K058 Relay in Cabinet 1H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K006 Relay in Cabinet 1H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K060 Relay in Cabinet 1H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 55 of 67 Equipment ID Description Failure Mode HCLPF (g)

Basis 1 E51A-K007 Relay in Cabinet 1H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-K008 Relay in Cabinet 1H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 1H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 1404238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1E51A-S003 RCIC Steam Inlet MOV Hand switch @

Panel 1H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40 '

above grade.

1E51A-S004 RCIC CST Suction Valve Hand switch

@ Panel 1H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1E51A-S005 RCIC Injection Valve Hand switch @

Panel 1H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40 '

above grade.

1E51A-S008 RCIC Lube Oil Cooling Flow Valve Hand switch @

Panel 1H13-P601 Equipment Capacity 0.37 above grade.

Component is Rule Of Box to 1H-13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' 1E51A-S009 RCIC Min Flow Return to Suppression Pool Valve Hand switch

@ Panel 1H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40 '

above grade.

1E51A-S010 RCIC Suppression Pool Suction Valve Hand switch @

Panel 1H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1E51A-S014 RCIC Barometric Condenser Condensate Pump Hand switch @

Panel 1H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1E51A-S015 RCIC Barometric Condenser Vacuum Pump Hand switch

@ Panel 1H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1E51A-S026 RCIC Turbine Trip &

Throttle Valve Hand switch @ Panel 1H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 1H 1 3-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1E51-0001 RCIC Pump Block Wall Interaction 037 Adjacent block wall evaluated in 14Q4238-CAL-003. Component per se screened; anchorage is evaluated in 14Q4238-CAL-004.

1E51-0002 RCIC Turbine &

Barometric Condenser Block Wall Interaction 0.37 Component and anchorage screened by SRT judgment. Adjacent block wall evaluated in 14Q4238-CAL-003 1E51-0004 RCIC Barometric Condenser Condensate Pump (DC)

Block Wall Interaction 0.37 Component is Rule Of Box to 1E51-0002. Host component screened by SRT judgment. Adjacent block wall evaluated in 14Q4238-CAL-003 1E51-0005 RCIC Barometric Condenser Vacuum Pump (DC)

Block Wall Interaction 0.37 Component is Rule Of Box to 1E51-0002. Host component screened by SRT judgment. Adjacent block wall evaluated in 14Q4238-CAL-003.

1E51-F010 RCIC CST Suction Valve (DC)

Screened

>RLGM Component screened by SRT judgment.

1E51-F013 RCIC Injection Valve (DC)

Screened

>RLGM Component screened by SRT judgment.

1E51-F019 RCIC Min Flow Return to Suppression Pool Valve (DC)

Screened

>RLGM Component screened by SRT analysis.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 56 of 67 Equipment ID Description Failure Mode HCLPF (g)

Basis 1E51-F031 RCIC Suppression Pool Suction Valve (DC)

Screened

>RLGM Component screened by SRT judgment.

1E51-F045 RCIC Steam Inlet MOV (DC)

Block Wall Interaction 0.37 Adjacent block wall evaluated in 14Q4238-CAL-003. Component screened by SRT judgment.

1E51-F046 RCIC Lube Oil Cooling Flow Valve Screened

>RLGM Component screened by SRT analysis.

1E51-F360 RCIC Turbine Trip &

Throttle Valve (DC)

Block Wall Interaction 0.37 Adjacent block wall evaluated in 14Q4238-CAL-003. Component screened by SRT judgment.

1E51-F361 RCIC Governor Valve (HO)

Block Wall Interaction 0.37 Component is Rule of Box to 1E51-0001. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per screened; anchorage is evaluated in 14Q4238-CAL-004.

1E51-K601 RCIC Square Root Converter @ Panel 1H13-P601 Equipment 0,37 Capacity Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40 '

above grade.

1E51-N003 RCIC Flow Transmitter @ Panel 1H22-P017 Screened

>RLGM Component is Rule Of Box to 1H22-P017. Host component screened by SRT analysis.

1E51-N006 Pressure Switch in Cabinet 1H22-P017 Screened

>RLGM Component is Rule Of Box to 1H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E51-N007 RCIC Steam Supply Pressure Xmtr @

Panel 1H22-P017 Screened

>RLGM Component is Rule Of Box to 1H22-P017. Host component screened by SRT analysis.

1E51-N009A Pressure Switch in Cabinet 1H22-P017 Screened

>RLGM Component is Rule Of Box to 1H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E51-N009B Pressure Switch in Cabinet 1H22-P017 Screened

>RLGM Component is Rule Of Box to 1H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E51-N012A Pressure Switch in Cabinet 1H22-P017 Screened

>RLGM Component is Rule Of Box to 1H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E51-N012B Pressure Switch in Cabinet 1H22-P029 Screened

>RLGM Component is Rule Of Box to 1H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E51-N012C Pressure Switch in Cabinet 1H22-P017 Screened

>RLGM Component is Rule Of Box to 1H22-P017.

Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E51-N012D Pressure Switch in Cabinet 1H22-P029 Screened

>RLGM Component is Rule Of Box to 1H22-P017.

Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

1E51-R600 RCIC Pump Discharge Flow Controller Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40 '

above grade.

1E51 RCIC Steam Supply Pressure Indicator

@ Panel 1H13-P601 Equipment

-R602 Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1E51-R606 RCIC Pump Discharge Flow Indicator @ Panel 1H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1EI-DC055 250VDC System Battery Volts Indicator @ Panel 1PM01J Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade.

1EI-DC056 250VDC System Battery Charger Volts Indicator @

Panel 1PM01J Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

lEI-DC057 125VDC Battery Voltage Indicator @

Panel 1PM01J (Div.

1)

Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

lEI-DC058 125VDC Battery Charger Volts Indicator @ Panel 1PM01J (Div. 1)

Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 57 of 67 Equipment ID Description Failure Mode HCLPF (g)

Basis lEI-DC059 125VDC Battery Voltage Indicator @

Panel 1PM01J (Div.

2)

Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1E I-DC060 125VDC Battery Charger Volts Indicator @ Panel 1PM01J (Div. 2)

Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade.

1H13-P601 Emerg. Core Cool System Panel Equipment Capacity 0.37 Component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40 above grade..

1H13-P612 FEEDWATER /

RECIRC VERTICAL BOARD Block Wall Interaction 0.41 Adjacent block wall evaluated in 1404238-CAL-003. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1H13-P618 DIVISION II RHR RELAY VERTICAL BOARD Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1H13-P621 RCIC RELAY PANEL Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1H13-P628 ADS SRV Panel Block Wall Interaction 0.41 Adjacent block wall evaluated in 14Q4238-CAL-003. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1H13-P629 DIVISION I - LPCS /

RHR RELAY VERTICAL BOARD Block Wall Interaction 0.41 Adjacent block wall evaluated in 1404238-CAL-003. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1H13-P631 AUTOMATIC DEPRESSURIZATI ON SYS B RELAY VERTICAL BOARD Block Wall Interaction

>RLGM Adjacent block wall evaluated in 14Q4238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

1H22-P017 RCIC Instrument Rack Screened

>RLGM Component screened by SRI analysis.

1H22-P029 Instrumentation Cabinets Screened

>RLGM Component screened by SRI analysis.

1HS-D001 Diesel Generator Fuel Transfer Pump Hand switch Equipment Capacity 0.45 Component is Rule Of Box to 1DGO3J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

111-00049 250VDC System Battery Amps Indicator @ Panel 1PM01J grade.

Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above 111-DC050 250VDC System Battery Charger Amps Indicator @

Panel 1PM01J Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade.

111-DC051 125VDC Battery Amps Indicator @

Panel 1PM01J (Div.

1)

Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

111-DC052 125VDC Battery Charger Amps Indicator @ Panel 1PM01J (Div. 1)

Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade.

111-DC053 125VDC Battery Amps Indicator @

Panel 1PM01J (Div.

2)

Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade.

111-DC054 125VDC Battery Charger Amps Indicator @ Panel 1PM01J (Div. 2)

Equipment Capacity 0.37 Component is Rule Of Box to 1PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1IN035 A N2 MANIFOLD PRESS REG Screened

>RLGM Component screened by SRI judgment.

1IN038 B N2 MANIFOLD PRESS REG Screened

>RLGM Component screened by SRI judgment.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 58 of 67 Equipment ID Description Failure Mode HCLPF (9)

Basis 11NO9MA Nitrogen Bottle Bank (South Side) Gas Manifold System Screened

>RLGM Component screened by SRT judgment.

11NO9MB Nitrogen Bottle Bank (North Side) Gas Manifold System Screened

>RLGM Component screened by SRI judgment.

1LI-CM192 Wide Range Suppression Pool Water Level @1H13-P601 panel Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade..

1LT-CM030 SUP POOL WIDE RANGE LEVEL XMTR Screened

>RLGM Component screened by SRI judgment.

1PI-CM029 Wide Range DW Pressure @1H13-P601 panel Equipment 0.37 Capacity Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1PI-CM056 S-POOL PRESS Equipment Capacity 0.37 Component is Rule Of Box to 1H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1PM01J Battery Charger Panel Equipment Capacity 0.37 Component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1PM16J ASSY - PANEL, P/C MONITOR/LEAK DETECTION Equipment Capacity 0.37 Component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1PT-CM029 PAM WIDE RANGE DRYWELL PRESS TRANSMITTER Screened

>RLGM Component screened by SRI judgment.

1PT-CM056 SUP POOL PRESS XMTR Screened

>RLGM Component screened by SRI judgment.

1TI-CM037 Suppression Pool Water Temperature Indicator @ Panel 1061-P001 Block Wall Interaction

>RLGM Component is Rule Of Box to 1061-P001. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

1TI-CM045 Drywell Temperature Indicator @ Panel 1061-P001 Block Wall Interaction

>RLGM Component is Rule Of Box to 1061-P001. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

No EPN 1 RCIC Lube Oil Cooler Block Wall Interaction 0.37 Component is Rule of Box to 1E51-0001. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per screened; anchorage is evaluated in 14Q4238-CAL-004.

No EPN 2 ROC Woodward Governor (on RCIC Turbine)

Block Wall Interaction 0.37 Component is Rule of Box to 1E51-0001. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per screened; anchorage is evaluated in 14Q4238-CAL-004.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 59 of 67 Attachment D - LaSalle Unit 2 ESEP HCLPF Values and Failure Mode Tabulation Note: Some items listed on the ESEL were child components contained within host components. These child components are referred to as "Rule of Box" (ROB) items, for which the HCLPF capacities are identical to those of the host item.

140.4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 60 of 67 Equipment ID Description Failure Mode HCLPF (9)

Basis 235X 480VAC Sw. Gr.

(2AP19E) (Div. 1)

Equipment Capacity 0.45 Component is Rule Of Box to 2AP19E. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

235X-3 480VAC MCC (2AP73E)(Div. 1)

Equipment Capacity 0'45 Component is Rule Of Box to 2AP73E. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

236X 480VAC Sw. Cr.

(2AP21E) (Div. 2)

Block Wall Interaction

>RLGM Component is Rule Of Box to 2AP21E. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

236X-3 480VAC MCC (2AP81E)(Div. 2)

Block W all

>RLGM Interaction Component is Rule Of Box to 2AP81E. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

236Y 480VAC Sw. Cr.Equipment (2AP22E) (Div. 2)

Capacity 0.45 Component is Rule Of Box to 2AP22E. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

236Y -1 480V MCC (2AP82E)

Equipment Capacity 0'45 Component is Rule Of Box to 2AP82E. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2B21-A003C "C" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40 above grade.

2B21-A003D "D" ADS SRV Accumulator Equipment Capacity located 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and

>40' above grade.

2621-A003E "E" ADS SRV Accumulator Equipment Capacity located 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and

>40' above grade.

21321-A003R "R" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40' above grade.

2B21-A003S "S" ADS SRV Accumulator Equipment Capacity n '

Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40' above grade.

2821-A003U "U" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40' above grade.

2B21-A003V "V" ADS SRV Accumulator Equipment Capacity 0.37 Component evaluated by HCLPF calculation 14Q4238-CAL-002 and located >40 above grade.

2B21C-S008A "C" ADS SRV Hand switch © Panel 2H13-P628 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2B21C-S009A "D" ADS SRV Hand switch @ Panel 2H13-P628 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

21321C-S010A "E" ADS SRV Hand switch @ Panel 2H13-P628 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2621C-S011A "R" ADS SRV Hand switch @ Panel 2H13-P628 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2B21C-S012A "S" ADS SRV Hand switch @ Panel 2H13-P628 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2821C-S013A "U" ADS SRV Hand switch @ Panel 2H13-P628 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P628. Adjacent block wall evaluated in 1404238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2B21C-S014A "V" ADS SRV Hand switch @ Panel 2H13-P628 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P628. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

21321-F013C "C" ADS SRV Screened

>RLGM Component screened by SRT analysis*"

2B21-F013D "D" ADS SRV Screened

>RLGM Component screened by SRT analysis 2B21-F013E "E" ADS SRV Screened

>RLGM Component screened by SRT analysis 2621-F013R "R" ADS SRV Screened

>RLGM Component screened by SRT analysis 2B21-F013S "S" ADS SRV Screened

>RLGM Component screened by SRT analysis

- "SRT analysis" involves the quantitative evaluation of applicable screening criteria or failure modes whereas "SRT judgment" relies upon SRT experience and training with qualitative basis for disposition.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 61 of 67 Equipment ID Description Failure Mode HCLPF (g)

Basis 2B21-F013U "U" ADS SRV Screened

>RLGM Component screened by SRI analysis 2621-F013V "V" ADS SRV Screened

>RLGM Component screened by SRI analysis 2621-N026DA RPV Level Transmitter (feeds 2C61-R010)

Screened

>RLGM Component screened by SRI judgment 2C61-N006 RPV Pressure Transmitter (feeds 2C61-R011)

Screened

>RLGM Component screened by SRI judgment 2C61-P001 Instrument Panel Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2C61-R010 RPV Level (WR)

Indicator @ Panel 2C61-P001 Block Wall Interaction

>RLGM Component is Rule Of Box to 2C61-P001. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2C61-R011 RPV Pressure Indicator @ Panel 2C61-P001 Block Wall Interaction

>RLGM Component is Rule Of Box to 2C61-P001. Adjacent block wall evaluated in 1404238-CAL-006. Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DC01E 250V Battery (Div.

1)

Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DCO2E 250VDC Bus #1 Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2DC03E 250VDC Battery Charger #2 Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2DC06E 250VDC MCC 221Y Equipment Capacity 0.45 Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DC07E 125V Battery 2A (Div. 1)

Block Wall Interaction

>RLGM Adjacent block wall evaluated in 14Q4238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DC08E 125VDC Bus 2A (Div. 1)

Equipment Capacity 0.45 Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2DC09E 125VDC Battery Main Charger 2AA Block Wall Interaction

>RLGM Adjacent block wall evaluated in 14Q4238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DC11E 125VDC Dist.

Panel 211Y (Div. 1)

Equipment Capacity 0.45 Component is Rule of Box to 2DC08E. Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DC13E 125VDC Dist.

Panel 212Y (Div. 2)

Equipment Capacity 0.45 Component is Rule of Box to 2DC15E. Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DC14E 125V Battery 2B (Div. 2)

Block Wall Interaction 0.37 Adjacent block wall evaluated in 1404238-CAL-003. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DC15E 125VDC Bus 2B (Div. 2)

Equipment Capacity 0.45 Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DC17E 125VDC Battery Main Charger 2BA Block Wall Interaction

>RLGM Adjacent block wall evaluated in 14Q4238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2DGO3J Diesel Panel Equipment Capacity 0.45 Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2D001P Diesel Generator Fuel Transfer Pump (Div. 2)

Screened

>RLGM Component screened by SRI judgment.

2D001T Diesel Fuel Storage Tank (Div.

2)

Equipment 0.45 Capacity Component evaluated by HCLPF calculation 1404238-CAL-004.

2D005T Diesel Generator Day Tank (Div. 2)

Block Wall Interaction

>RLGM Adjacent block wall evaluated in 14Q4238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-004.

2E12-B001B 2B RHR HEAT EXCHANGER Anchorage

/

Equipment Capacity 0.37 Adjacent block wall evaluated in 14Q4238-CAL-003. Component per screened; evaluated by HCLPF calculation 14Q4238-CAL-004.

2E12-F016B B' RHR Outboard Primary Containment Spray Isolation Valve Screened

>RLGM Component screened by SRI analysis.

2E12-F027B "B" RHR Suppression Chamber Spray Valve Block Wall Interaction 0.37 Adjacent block wall evaluated in 1404238-CAL-003. Component screened by SRI judgment.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 62 of 67 Equipment ID Description Failure Mode HCLPF (g)

Basis 2E12-F042B "B" RHR (LPCI)

RPV Injection Valve Screened

>RLGM Component screened by SRT analysis.

2E31-N022A Pressure Switch in Cabinet 2H22-P017 Screened

>RLGM Component is Rule Of Box to 2H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E31-N022B Pressure Switch in Cabinet 2H22-P029 Screened

>RLGM Component is Rule Of Box to 2H22-P029. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E31-N022C Pressure Switch in Cabinet 2H22-P017 Screened

>RLGM Component is Rule Of Box to 2H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E31-N0220 Pressure Switch in Cabinet 2H22-P029 Screened

>RLGM Component is Rule Of Box to 2H22-P029. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E51A-K015 Relay in Cabinet 2H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2E51A-K029 Relay in Cabinet 2H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P621.

Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 1404238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2E51A-K032 Relay in Cabinet 2H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2E51A-K033 Relay in Cabinet 2H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2E51A-K039 Relay in Cabinet 2H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2E51A-K047 Relay in Cabinet 2H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P621. Relay capacity evaluated in 1404238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2E51A-K048 Relay in Cabinet 2H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 1404238-CAL-006.

Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2E51A-K054 Relay in Cabinet 2H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2E51A-K055 Relay in Cabinet 2H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P621. Relay capacity evaluated in 1404238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2E51A-K057 Relay in Cabinet 2H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 1404238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2E51A-K058 Relay in Cabinet 2H13-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 1404238-CAL-006.

Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

2E51A-K006 Relay in Cabinet 2H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 63 of 67 Equipment ID Description Failure Mode HCLPF (9)

Basis 2E51A-K060 Relay in Cabinet 21-113-P618 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P618. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2E51A-K007 Relay in Cabinet 2H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2E51A-K008 Relay in Cabinet 2H13-P621 Block Wall Interaction

>RLGM Component is Rule Of Box to 2H13-P621. Relay capacity evaluated in 14Q4238-CAL-005. Adjacent block wall evaluated in 14Q4238-CAL-006.

Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2E51A-S003 RCIC Steam Inlet MOV Hand switch

@ Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51A-S004 RCIC CST Suction Valve Hand switch

@ Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51A-5005 RCIC Injection Valve Hand switch

@ Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51A-S008 RCIC Turbine Cooling Water Supply Valve Hand switch @ Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51A-S009 RCIC Min Flow Bypass to Suppression Pool Valve Hand switch

@ Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51A-S010 RCIC Suppression Pool Suction Valve Hand switch @

Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51A-S014 RCIC Barometric Condenser Condensate Pump Hand switch @

Panel 2H13-P601 Equipment Eq.

Capacity 0'37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51A-5015 RCIC Barometric Condenser Vacuum Pump Hand switch @

Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51A-S026 RCIC Turbine Trip

& Throttle Valve Hand switch @

Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51-0001 RCIC Pump Block Wall Interaction 0.37 Adjacent block wall evaluated in 14Q4238-CAL-003. Component per se screened; anchorage is evaluated in 14Q4238-CAL-004.

2E51-0002 RCIC Turbine &

Barometric Condenser Block Wall Interaction 0.37 Component and anchorage screened by SRI judgment. Adjacent block wall evaluated in 14Q4238-CAL-003 2E51-0004 RCIC Barometric Condenser Condensate Pump (DC)

Block Wall Interaction 0.37 Component is Rule Of Box to 2E51-0002. Host component screened by SRT judgment. Adjacent block wall evaluated in 14Q4238-CAL-003

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 64 of 67 Equipment ID Description Failure Mode HCLPF (g)

Basis 2E51-0005 RCIC Barometric Condenser Vacuum Pump (DC)

Block Wall Interaction 0.37 Component is Rule Of Box to 2E51-0002. Host component screened by SRT judgment. Adjacent block wall evaluated in 14Q4238-CAL-003 2E51-F010 RCIC CST Suction Valve (DC)

Screened

>RLGM Component screened by SRT judgment.

2E51-F013 RCIC Injection Valve (DC)

Screened

>RLGM Component screened by SRT judgment.

2E51-F019 RCIC Min Flow Return to Suppression Pool Valve (DC)

Screened

>RLGM Component screened by SRT analysis.

2E51-F031 RCIC Suppression Pool Suction Valve (DC)

Screened

>RLGM Component screened by SRT judgment.

2E51-F045 RCIC Steam Inlet MOV (DC)

Screened

>RLGM Component screened by SRT judgment.

2E51-F046 RCIC Lube Oil Cooling Flow Valve Screened

>RLGM Component screened by SRT analysis.

2E51-F360 RCIC Turbine Trip

& Throttle Valve (DC)

Block Wall Interaction 0.37 Adjacent block wall evaluated in 14Q4238-CAL-003. Component screened by SRT judgment.

2E51-F361 RCIC Governor Valve (HO)

Block Wall Interaction 0.37 Component is Rule of Box to 2E51-0001. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per screened; anchorage is evaluated in 14Q4238-CAL-004.

2E51-K601 RCIC Square Root Converter @ Panel 2H13-P601 Equipment Capacity Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2E51-N003 RCIC Flow Transmitter @

Panel 2H22-P017 Screened

>RLGM Component is Rule Of Box to 2H22-P017. Host component screened by SRT analysis.

2E51-N006 Pressure Switch in Cabinet 2H22-P017 Screened

>RLGM Component is Rule Of Box to 2H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E51-N007 RCIC Steam Supply Pressure Xmtr @ Panel 2H22-P017 Screened

>RLGM Component is Rule Of Box to 2H22-P017. Host component screened by SRT analysis.

2E51-N009A Pressure Switch in Cabinet 2H22-P017 Screened

>RLGM Component is Rule Of Box to 2H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E51-N009B Pressure Switch in Cabinet 2H22-P017 Screened

>RLGM Component is Rule Of Box to 2H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E51-N012A Pressure Switch in Cabinet 2H22-P017 Screened

>RLGM Component is Rule Of Box to 2H22-P017. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E51-N012B Pressure Switch in Cabinet 2H22-P029 Screened

>RLGM Component is Rule Of Box to 2H22-P029. Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E51-N012C Pressure Switch in Cabinet 2H22-P017 Screened

>RLGM Component is Rule Of Box to 2H22-P017.

Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E51-N012D Pressure Switch in Cabinet 2H22-P029 Screened

>RLGM Component is Rule Of Box to 2H22-P029.

Switch capacity evaluated in 14Q4238-CAL-005. Host component screened by SRT analysis.

2E51-R600 RCIC Pump Discharge Flow Controller Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40 '

above grade.

2E51-R602 RCIC Steam Supply Pressure Indicator @ Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

1404238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 65 of 67 Equipment ID Description Failure Mode HCLPF (9)

Basis 2E51-R606 RCIC Pump Discharge Flow Indicator @ Panel 2H13-P601 Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2EI-DC055 250VDC System Battery Volts Indicator @ Panel 2PM01J grace.

Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40 above 2E1-DC056 250VDC System Battery Charger Volts Indicator @

Panel 2PM01J Equipment Capacity grade.

0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above 2E1-DC057 125VDC Battery Voltage Indicator

@ Panel 2PM01J (Div. 1)

Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade.

2EI-DC058 125VDC Battery Charger Volts Indicator

Panel 2PM01J (Div. 1)

Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade.

2E1-DC059 125VDC Battery Voltage Indicator

@ Panel 2PM01J (Div. 2)

Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade.

2E1-00060 125VDC Battery Charger Volts Indicator @ Panel 2PM01J (Div. 2)

Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2H13-P601 Emerg. Core Cool System Panel Equipment Capacity 0.37 Component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade..

2H13-P612 ASSY - PANEL, FEED WATER/RECIRCU LATION Equipment Capacity 0.45 Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2H13-P618 ASSY - PANEL, DIV-2 RHR RELAY Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2H13-P621 ASSY - PANEL, RI RELAY Block Wall Interaction

>RLGM Adjacent block wall evaluated in 14Q4238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2H13-P628 ADS SRV Panel Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2H13-P629 ASSY - PANEL, D1V-1 LPCS/RHR RELAY Block Wall Interaction

>RLGM Adjacent block wall evaluated in 1404238-CAL-006. Component per se screened; anchorage is evaluated in 1404238-CAL-002.

2H13-P631 ASSY - PANEL, AUTOMATIC DEPRESSION SYST B RELAY Block Wall Interaction

>RLGM Adjacent block wall evaluated in 14Q4238-CAL-006. Component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2H22-P017 RCIC Transmitter Panel Screened

>RLGM Component screened by SRT analysis.

2H22-P029 Instrumentation Cabinets Screened

>RLGM Component screened by SRT analysis.

2HS-D001 Diesel Generator Fuel Transfer Pump Hand switch Equipment Capacity 0.45 Component is Rule Of Box to 2DGO3J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002.

211-DC049 250VDC System Battery Amps Indicator @ Panel 2PM01J Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

211-DC050 250VDC System Battery Charger Amps Indicator @

Panel 2PM01J Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 1404238-CAL-002 and located >40' above grade.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 66 of 67 Equipment ID Description Failure Mode HCLPF (g)

Basis 211-DC051 125VDC Battery Amps Indicator @

Panel 2PM01J (Div. 1)

Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

211-DC052 125VDC Battery Charger Amps Indicator @ Panel 2PM01J (Div. 1)

Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

211-DC053 125VDC Battery Amps Indicator @

Panel 2PM01J (Div. 2)

Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

211-DC054 125VDC Battery Charger Amps Indicator @ Panel 2PM01J (Div. 2)

Equipment Capacity 0.37 Component is Rule Of Box to 2PM01J. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2IN035 VALVE, U2 SOUTH BANK IN REG Screened

>RLGM Component screened by SRT judgment.

2IN038 VALVE, NORTH BANK IN REG Screened

>RLGM Component screened by SRT judgment.

21NO9MA Nitrogen Bottle Bank (South Side)

Gas Manifold System Screened

>RLGM Component screened by SRT judgment.

21NO9MB Nitrogen Bottle Bank (North Side)

Gas Manifold System Screened

>RLGM Component screened by SRT judgment.

2L1-CM192 Wide Range Suppression Pool Water Level

@2H13-P601 panel Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade..

2LT-CM030 S-POOL WIDE RANGE LVL XMITTER Screened

>RLGM Component screened by SRT judgment.

2P1-CM029 Wide Range DW Pressure @2H13-P601 panel Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2P1-CM056 S-POOL PRESS Equipment Capacity 0.37 Component is Rule Of Box to 2H13-P601. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2PM01J Battery Charger Panel Equipment Capacity 0.37 Component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2PM16J ASSY - PANEL, P/C MONITOR/LEAK DETECTION Equipment Capacity 0.37 Component per se screened; anchorage is evaluated in 14Q4238-CAL-002 and located >40' above grade.

2PT-CM029 DNV PRESS WIDE RANGE PRESS XMITTER Screened

>RLGM Component screened by SRT judgment.

2PT-CM056 S-POOL PRESS XMITTER Screened

>RLGM Component screened by SRT judgment.

2TI-CM037 Suppression Pool Water Temperature Indicator @ Panel 2C61-P001 Block Wall Interaction

>RLGM Component is Rule Of Box to 2C61-P001. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

2TI-CM045 Drywell Temperature Indicator @ Panel 2C61-P001 Block Wall Interaction

>RLGM Component is Rule Of Box to 2C61-P001. Adjacent block wall evaluated in 14Q4238-CAL-006. Host component per se screened; anchorage is evaluated in 14Q4238-CAL-002.

No EPN 1 RCIC Lube Oil Cooler Block Wall Interaction 0.37 Component is Rule of Box to 2E51-0001. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per screened; anchorage is evaluated in 14Q4238-CAL-004.

14Q4238-RPT-004 Rev. 4 Correspondence No.: RS-14-298 Page 67 of 67 Equipment ID Description Failure Mode HCLPF (9)

Basis No EPN 2 RCIC Woodward Governor (on RCIC Turbine)

Block Wall Interaction

7 Component is Rule of Box to 2E51-0001. Adjacent block wall evaluated in 14Q4238-CAL-003. Host component per screened; anchorage is evaluated in 14Q4238-CAL-004.