ML14345A339

Submittal of Report of Changes, Tests and Experiments

ML14345A339
Person / Time
Site:	Byron
Issue date:	12/11/2014
From:	Kearney F Exelon Generation Co
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
Byron 2014-0154
Download: ML14345A339 (76)

Text

{{#Wiki_filter:Byron Generating Station Exe[on Generation 4450 North German Church Rd Byron, IL 61010-9794 www.exeloncorp.com December 11,2074 10 CFR 50.59(d)(2) LTR: Byron 2014-0154 FILE: 1.10.0101 (1 D.1 01, 5A.109) 2.07.0610 (5A.109) 2.07.0611 (1D.101) United States Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Byron Station, Unit 1 and 2 Facility Operating License Nos. NPF-37 and NPF-66 NRC Docket Nos. STN 50-454 and STN 50-455

Subject:

Report of Changes, Tests and Experiments Pursuant to the requirements of 10 CFR 50.59, Changes, tests and experiments, paragraph (d)(2), Byron Station is providing the required report for Facility Operating License Nos. NPF-37 and NPF-66. This report is provided for the evaluations implemented for the time period of January 1, 2012 through November 30, 2014 and consists of 50.59 Review Coversheets for changes to the facility or procedures as described in the Updated Final Analysis Report (UFSAR) and test or experiments not described in the UFSAR. Please direct any questions regarding this submittal to Mr. Douglas Spitzer, Regulatory Assurance Manager, at (815) 406-2800. Respecffully,

-abet Site Vice President Byron Generating Station FAKILZ/sg cc:    NRC Regional Administrator    NRC Region III

Enclosure:

Byron Station 10 CFR 50.59 Review Coversheets for January 1,2012 through November 30, 2014

Byron Station 10 CFR 50.59 Report 10 CFR 50.59 Review Coversheets for January 1, 2012 through November 30, 2014

Tracking No. Revision Number or Identifier Subject or Title 6G-12-001 0 EC384279 Unit 1 Lower Plenum Flow Anomaly Evaluation Install Ui / U2 VD Fan Auto-Restarts to Support HELB 6G-12-003 1 EC 388479 / EC 388894 Project Install Ui / U2 VX Fan Auto-Restarts to Support HELB 6G-12-007 0 EC 388478/ EC 388893 Project 6G-12-008 2 EC 389897 U2 SAT Loss of Phase Relay Installation Main Control Room Ventilation (VC) High Energy Line Break (HELB) Pressure Sensor to Control Emergency 6G-12-011 0 EC 389728 Intake Dampers Modification (Unit Common) 6G-12-012 1 EC 389896 Ui SAT Loss of Phase Relay Installation 6G-12-013 0 EC 377550 / DRP 15-040 HUT Design Analysis and UFSAR Update Install Ui / U2 VD HELB Dampers and High 6G-12-014 0 EC 388443 / EC 388896 Temperature Thermal Links to Support HELB Project Install Ui / U2 VX HELB Dampers and High 6G-12-015 0 EC 388442 / EC 388895 Temperature Thermal Links to Support HELB Project Install Ui / U2 VE HELB Dampers and High 6G-12-016 0 EC 387362 / EC 389144 Temperature Thermal Links to Support HELB Project Install Ui / U2 VE Fan Auto-Restarts to Support HELB 6G-i2-017 0 EC 388477 / EC 388892 Project Install larger trims in Unit 2 SG PORVs 6G-12-018 0 EC 390008 2MSO18NB/C/D for MTO Project 6G-1 3-008 0 EC 392306 Install Drain Line on Bonnet Vent of 2CV81 19 Unit 2 Main Turbine Roll in Mode 3 for Ventilation 6G-13-009 1 SPP-13-001, Rev. 0 Testing Turbine Building High Energy Line Break Design and 6G-13-010 0 EC 391394 Licensing Basis (Rollup EC) 6G-1 3-01 1 0 EC 386524 / EC 386525 Design Change to AF Suction Pressure Logic Unit 1 Main Turbine Roll in Mode 3 for Ventilation 6G-i3-0i4 0 SPP 13-004 Testing 6G-13-015 0 EC394715 Install Drain Line on Bonnet Vent of 1CV8119 EC 395574 and Revise Analysis BYR1O-136 and TRM 3.9.A Curves for 6G-i4-002 0 TRM Change 14-004 MUR (ICDT) 6G-i4-004 0 BOP CV-12 N2 on VCT BOP CV-12 Site Acceptance of Westinghouse WCAP-1 7867-P Revision 1, Westinghouse SSPS Board Replacement 6G-14-005 0 EC 3961 44/EC 399736 Licensing Summary Report

50.59 REVIEW COVERSHEET FORM LS-AA-104-IOO1 Revision 3 Page 1 of6 Station/Unit(s): Byron I Activity/Document Number: EC # 384279 Revision Number: I

Title:

Changes to Assumptions and Inputs in the Calculation of DNBR to Regain Margin for Byron Unit 1 Cycle 18 with Indications of Lower Plenum Flow Anomaly NOTE: For 50.59 Evaluations, information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CER 50.59(d)(2). Description of Activity: (Provide a brief, concise description of what the proposed activity involves.) Byron Unit I began exhibiting indications of the Lower Plenum F low Anomaly (LPFA) during the startup for Cycle 1$. This anomaly results in flow vortices forming in random locations in the lower plenum region of the reactor vessel, leading to reduced coolant flow to the fuel assemblies above that core location for short periods of time. Because this anomaly results in reduced flow to certain areas of the core, the local coolant temperatures around the area experiencing the flow vortex increase, which adversely affects the departure from nucleate boiling ratio (DNBR). The LPFA was first identified in the 1980s at several Westinghouse PWR facilities. Westinghouse performed an evaluation of the anomaly in WCAP-1 1528, RCS F low Anomaly Investigation Report, April, 1988. The anomaly that was identified at Callaway was determined to be the largest in magnitude, so data from Callaway was used to establish the bounding parameters for evaluating LPFA at other plants. This includes establishing the flow impact as a result of the vortices and the generic DNBR penalty. In order to determine the impact on the Byron Unit I DNBR margin as a result of the LPFA, Westinghouse first confirmed in letter NF-CB-l1-184, Byron Unit I Lower Plenum Flow Anomaly (LPFA) Confirmation. that the Byron indications were bounded by the indications seen at Callaway. This confirmation was performed in order to ensure that the generic analysis that had previously been performed by Westinghouse to determine DNBR penalties would be applicable to Byron Unit 1. Westinghouse divided the evaluation of the impact of the LPFA DNBR penalties on the Byron Unit I DNBR margins into evaluations of the Over Temperature-Delta Temperature (OTAT) events and non OTAT events. The evaluation of the non-OTAT events was very straightforward and determined that adequate margin existed to offset the penalty associated with the LPFA. No further analysis was needed for the non-OTAT events. Westinghouse further divided the evaluation of the DNBR impact for OTAT events into an evaluation based on the core thermal limits and an evaluation based on axial offset (AO). As a starting point for both evaluations, Westinghouse first consulted the Westinghouse Reload Safety Analysis Checklist (RSAC) confirmation calc note for Byron Unit I Cycle 1$ (CN-CAI 8-029) to determine what the previous assessment of DNBR margin was without taking the LPFA into account. For the core thermal limits evaluation, the minimum DNBR occurred in the mixing vane region of the fuel where the WRB-2 critical heat flux (CHF) correlation was applicable. Based on the Westinghouse RSAC confirmation, there was 6.0% DNBR margin. When the WRB-2 based rod bow DNBR penalty of 1.8% was applied, there was 4.2% DNBR margin to the safety assessment letter (SAL) DNBR limit of 1 .33 remaining. Based on the Westinghouse Thermal-Hydraulic Design Procedure Manual (THDPM), Section 4.9, the generic LPFA DNBR penalty for the 17x17 V-S fuel used by Byron with the WRB-2 Cl-IF correlation is 3.3%. When the 3.3% LPFA DNBR penalty is applied to the 4.2% DNBR margin previously calculated, there remains 0.9% margin to the SAL DNBR limit of 1.33. This shows that, for the evaluation based on the core thermal

50.59 REVIEW COVERSHEET FORM LS-AA-104-1001 Revision 3 Page 2 of 6 Station/Unit(s): Byron I Activity/Document Number: EC # 384279 Revision Number: I

Title:

Changes to Assumptions and Inputs in the Calculation of DNBR to Retain Margin for Byron Unit I Cycle 18 with indications of Lower Plenum Flow Anomaly limits and the WRB-2 CHF correlation, adequate margin exists to offset the impacts of the LPFA, so no further evaluation is required. For the evaluation based on the AO, Westinghouse consulted the caic note that documented the SPNOVA models and 3DFAC analysis with the rod bow penalty for Byron Unit I Cycle 1 8 (CN-CA 1 8-031) to determine how much margin was available to the DNBR limit. Westinghouse used generic limiting power shapes, as selected in Westinghouse calc note CN-GEN-METHODS-9, as the starting point for the DNBR calculations. These limiting power shapes were for extremely bottom-skewed power shapes that resulted during cootdown events. These bottom-skewed power shapes occurred in the region of the core below the first mixing grid, so the W-3 CHF correlation applies for DNBR calculations. Based on the information from these limiting power shapes, Westinghouse calculated the lowest system pressure that would be allowed by the OTc\T trip protection system. Next, Westinghouse took the results of the THINC-IV calculations that were performed using these limiting power shapes in caic note CN-COMED-161, Rev. 6, to determine which of the power shapes yielded the most limiting DNBR results. The limiting power shape, designated as Case I, provided the most limiting DNBR value with an assumed cooldown of 30°. The Byron Unit I Cycle 18 RSAC, in Tables 2.7.4.3 and 2.8.4.1 of Westinghouse letter LTR-TA-l0-l 18 (contained in TODI Nfl 100042), showed that for the HFP Main Steamline Break and HFP Feedwater Malfunction events, the amount of cooldown that would be expected to occur is less than 20°. Based on this calculated amount of cooldown, Westinghouse decided to use Case 2A, which is the same power shape as Case I but assumes a cooldown of 20° instead of 30°, in the DNBR calculations for the LPFA evaluation. Once the limiting case was determined, Westinghouse reviewed the information from Case 2A and compared itto the generic W-3 correlation rod bow penalties that were calculated in CN-COMED-195. Based on the fuel assembly average burnup of 25885 MWD/MTU for Case 2A, the rod bow DNBR penalty is 5.7%. Westinghouse took the THINC-lV input for Case 2A from CN-COMED-161, Rev. 6 to use as the starting point for the DNBR calculations. first, the input for Case 2A was modified in order to account for the generic, bounding LPFA flow vortex. When Westinghouse first performed the updated THINC-IV calculations, the local quality that was calculated for the limiting DNBR location was outside the approved local quality range for the Cold Wall factor (CWF), which is used in conjunction with the W-3 Critical Heat flux (CHf) correlation to determine the DNBR for thimble cells (the area between three fuel rods and one guide tube), as defined in the Westinghouse Thermal-Hydraulic Design Procedure Manual. In order to bring the calculated local quality back within the constraints for the CWF, Westinghouse performed iterations by lowering the input core pressure until a local quality of greater than -15% was obtained. This resulted in a reactor core pressure well below the pressure at which the reactor would trip, based on the settings of the OTAT trip protection system, which means that it is conservative for use in this application. The results of the final iteration showed that there was -3.7% margin to the W-3 design limit DNBR of 1.369 (as obtained from CN-COMED-161, Rev. 6). When the 5.7% rod bow penalty for the W-3 correlation was applied on top of the -3.7% margin obtained by the THINC-IV calculations, Westinghouse determined that Byron Unit I Cycle 18 had -9.4% margin to the design limit DNBR of 1 .369, when the generic, bounding assumptions are maintained.

50.59 REVIEW COVERSHEET FORM LS-AA-104-lOO1 Revision 3 Page 3 of 6 Station/Unit(s): Byron I Activity/Document Number: EC # 384279 Revision Number: I

Title:

Changes to Assumptions and Inputs in the Calculation of DNBR to Regain Margin for Byron Unit 1 Cycle 18 with Indications of Lower Plenum Flow Anomaly In order to regain DNBR margin, Westinghouse identified three areas in which design or operating margins existed, as welt as a potential to extend the use of the W-3 CHF correlation and the CWF down to the W-3 CHE tower local quality limit of -25%. In order to justify the use of the W-3 CHF correlation and the CWF down to the W-3 CHF lower local quality limit of -25%, Westinghouse first reviewed their THDPM. The THDPM currently restricts the use of the CWF to local qualities between -15% and +10%. However, a review of TID-25887, where the applicability ranges for the W-3 CHF correlation and the CWF are first defined, shows that the W-3 CHF correlation is valid for a local quality range of -25% to +15%. In addition, TID-25887 says that the CWF is valid for all local qualities <+10%. A review of WCAP-7988-P-A and WCAP-$296-P-A and their SERs shows that these documents do not specify a lower bound on the applicability of the CWF. Westinghouse determined, in CE-l2-54, Form EPF-125 for the Lower Quality Limit of the Cold Wall Factor, that the lower bound on the CWF that is ctirrentty contained in the THDPM is applicable only when the CWF is used in conjunction with the modified spacer factor, which is applicable only in the mixing grid region of the assembly. Since the bottom-skewed power shapes that are being utilized in this evaluation occur in the region of the core below the first mixing grid, the modified spacer factor does not need to be applied, which means that the lower bound on the CWF also is no longer applicable. This conclusion allows the use of the W-3 CHF and the CWF down to the W-3 CHF lower local quality limit of -25%. The first way in which Westinghouse gained margin was by calculating an analysis-specific rod bow penalty. The same methodology and computer code that were utilized in CN-COMED-195 was utilized, but the power, pressure, and FdH associated with the limiting power shape in Case 2A were input into the calculation instead of the generic, bounding parameters which had previously been utilized. This calculation reduced the rod bow DNBR penalty at a fuel assembly average burnup of 25885 MWD/MTU from 5.7% to 2.5%. Next, Westinghouse modified the Case 2A input for THINC-lV that accounted for the LPFA to include a RCS flow of 386,000 gpm in order to gain back some DNBR margin. This is allowed because plant procedures already prohibit operation with a flow less than 386,000 gpm (COLR item 2.12.3), and this is still well below the Cycle 18 expected RCS flow of >400,000 gpm, as documented in TODI NF1000163, Rev. 0 (Byron Unit I Cycle 18 Reload Design Initialization). Next, the amount of bypass flow assumed was reduced to 5.6%. This amount of bypass flow is lower than the highest amount allowed per RSAC item 0.1.4.1 (as documented in Westinghouse letter LTR-TA- 10-118, contained within TODI NE 1100042, Rev. 0, Byron Unit I Cycle 18 RSAC), and higher than the estimated bypass flow calculated based on the actual core loading, as documented in TODI NF1000163. Once these changes were incorporated into the THINC-IV input, Westinghouse began iterating on the core pressure until a local quality of>-25% was calculated for the minimum DNBR. The minimum DNBR margin that was calculated in the final iteration was 5.6%. When the analysis-specific rod bow DNBR penalty of 2.5% was applied on top of this, it resulted in a total DNBR margin of 3.1% with respect to the W-3 design limit DNBR of 1.369. The results of this evaluation show that, by taking credit for some of the operating and design margins that exist and utilizing the W-3 CHF correlation and CWF within the full range of applicability for the W-3

50.59 REVIEW COVERSHEET FORM LS-AAIO4-lOO1 Revision 3 Page 4 of 6 Station/Unit(s): Byron I Activity/Document Number: EC # 384279 Revision Number: I

Title:

Changes to Assumptions and Inputs in the Calculation of DNBR to Regain Margin for Byron Unit I Cycle 1$ with Indications of Lower Plenum Flow Anomaly correlation, but still maintaining a large degree of conservatism, adequate DNBR margin exists to offset the DNBR penalties associated with the LPFA. Reason for Activity: (Discuss why the proposed activity is being performed.) The proposed Activity, namely changing some of the inputs and assumptions in the safety analysis calculations of DNBR, is being performed in order to regain DNBR margin for Byron Unit I Cycle 1$, after it began exhibiting indications of the LPFA. When Byron Unit I started up at the beginning of Cycle 18, the unit began exhibiting indications of LPFA. This anomaly starves flow to random locations in the core when vortices form in the lower plenum region of the reactor vessel. The lower flow through the affected bundles results in elevated surface temperatures for the fuel, which lowers the DNBR. Westinghouse previously performed a generic analysis for the LPFA after Callaway and other plants first began exhibiting indications of the flow anomaly in the 1980s. Westinghouse determined the generic DNBR penalty for the WRB-2 correlation associated with the LPFA, as well as determining the shape of the normalized flow reductions for the affected area. Westinghouse performed an evaluation of the DNBR for Byron Unit I Cycle 18, incorporating the effects of the LPFA but otherwise leaving the inputs to the previous DNBR calculation untouched, and determined that the generic, bounding analysis that was previously performed did not provide enough DNBR margin to offset the penalties associated with the LPFA. Therefore, Westinghouse and Exelon discussed several different options that could be pursued in order to regain DNBR margin for Byron Unit 1 Cycle I 8 while still ensuring that adequate margin existed such that the evaluation remained conservative. The options that were ultimately implemented were raising the RCS flow from the TS MMF value of 380,900 gprn to the COLR MMF value of 386,000 gpm; lowering the bypass flow from 7.6% to 5.6%; calculating an analysis-specific rod bow penalty; and utilizing the W-3 CHF correlation and the CWF down to the lower local quality limit for W-3 CKF of -25%. By implementing these changes to the inputs and assumptions to the DNBR calculation, Westinghouse was able to regain enough DNBR margin to offset the penalties associated with the LPFA. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) This Activity confirms that Byron Unit I Cycle 1$ has enough DNBR margin to offset the penalties associated with the LPFA. There are no impacts to plant operations or the design bases as a result of the evaluation that was performed. The safety analyses described in the UFSAR are not impacted; the analyses of record are not being revised or updated based on the evaluation that was performed. The changes that were made to the assumptions and inputs into the DNBR calculation in order to regain margin were made by taking credit for existing design and operational margins, and ensure that the DNBR calculation remains conservative. The ability of BEACON PDMS to monitor for DNBR is not impacted by the LPFA. Per COLR item 2.9.1, BEACON monitors to a DNBR of 1 .539 for the Loss-of-Flow accident. The LPFA DNBR penalty

50.59 REVIEW COVERSHEET FORM LS-AA-104-IO0I Revision 3 Page 5 of 6 Station/Unit(s): Byron I Activity/Document Number: EC # 384279 Revision Number: I

Title:

Chances to Assumptions and Inputs in the Calculation of DNBR to Regain Mar2in for Byron Unit I Cycle 18 with Indications of Lower Plenum Flow Anomaly associated with this accident is 3.3%. The DNBR limit for this accident, as described in the RSAC, is 1.33. There is approximately 15.7% margin between the DNBR limit that BEACON uses for monitoring (1.539) and the design limit DNBR for this accident (1.33), which is more than enough to offset the 3.3% DNBR penalty associated with LPFA without making any changes to the BEACON model or the DNBR value that BEACON uses for monitoring. Summary of Conclusion for the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) There were a total of five changes made to the original DNBR calculation as documented in CN-COMED 161, Rev. 6 and the rod bow penalty as documented in CN-COMED-195:

• Incorporating the normalized flow reductions associated with the LPFA into the input deck for Case 2A
• Calculating an analysis-specific rod bow penalty using the power, pressure, and FdH associated with Case 2A
• The MMF was raised from the TS value of 380,900 gpm to the COLR value of 386,000 gpm
• The bypass flow assumption was lowered from 7.6% to 5.6%
• The W-3 CHF correlation and the CWF were utilized down to the lower local quality limit for the W-3 correlation of -25%

Of these five changes, the incorporation of the LPFA flow reductions into the input deck, use of an analysis-specific rod bow penalty, and use of the W-3 CHF correlation and the CWF down to the lower local quality limit for the W-3 correlation were found to be potentially adverse to the safety analyses as described in the UFSAR, while raising the MMF and lowering the bypass flow were not. When the three potentially adverse changes were evaluated further, it was determined that all three changes are permitted by and in accordance with the methodology for calculating DNBR, calculating the rod bow penalty, and utilizing the W-3 CHF correlation and CWF; therefore, these changes do not result in a departure from a method of evaluation described in the UFSAR used in establishing the design bases or in the safety analyses. While the analyses of the OTAT events are impacted by LPFA, no changes were required or made to the constants used to calculate the OTAT trip setpoints. These changes were made within the constraints that were used in the generation of the constants used to calculate the OTAT setpoints. No physical changes to any SSC are being made, nor are any restrictions being placed on plant operation, therefore. the changes do not affect any UFSAR described design functions. These changes do not affect any procedures, therefore. they do not have any effect on how UFSAR described SSC design functions are performed or controlled. While the calculation of DNBR is discussed in the UFSAR, it describes only the computer code that is to be used and that a rod bow penalty needs to be applied. There is no discussion regarding the specific inputs or conservatisms that must be used in the DNBR calculation. The incorporation of the normalized flow reduction into the input for the DNBR calculation is allowed per the methodology and the Westinghouse THDPM. The use of application-specific parameters in the calculation of the rod bow

50.59 REVIEW COVERSHEET FORM LS-AA-104-100l Revision 3 Page 6 of 6 Station/Unit(s): Byron I Activity/Document Number: EC # 384279 Revision Number: I

Title:

Changes to Assumptions and Inputs in the Calculation of DNBR to Regain Margin for Byron Unit 1 Cycle 18 with Indications of Lower Plenum Flow Anomaly penalty is allowed per the rod bow methodology and the Westinghouse THDPM. The use of the W-3 CHF correlation and CWF down to a local quality of -25% is within the range of applicability for the W-3 Cl-IF correlation. While some changes were made to the inputs of the DNBR calculation, these are not considered elements of an UFSAR described evaluation methodology, so there is no adverse change to an element of an UFSAR described evaluation methodology. Likewise, no alternative evaluation methodology is being utilized; the same methods and computer codes that were previously used to calculate the DNBR for Byron Unit I are being utilized with updated/revised inputs. The changes that are being made to the inputs to the DNBR calculation are still conservative to actual plant operation, and do not place any restrictions on plant operations. The design basis is not affected, and the analysis of record for Byron Unit I is not being updated or revised. These changes do not involve any tests or experiments, described in the UFSAR or not, and do not result in an SSC being utilized or controlled in a manner that is outside the reference bounds of the design or inconsistent with the analyses or descriptions in the UFSAR. These changes were made to confirm that the DNBR limits listed in the Technical Specifications will continue to be met, even if a DNBR-limited OTAT event were to occur. Making these changes does not impact the Technical Specifications or the Facility Operating License, so no changes to either will be required. In summary, these changes can be made to the calculation of the DNBR in order to regain DNBR margin for Byron Unit I Cycle 18 with indications of LPFA without prior NRC approval. Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) Applicability Review 50.59 Screening 50.59 Screening No. 6E-12-068 Rev. 0 50.59 Evaluation 50.59 Evaluation No. 6G-12-OOJ Rev. 0

50.59 REVIEW COVERSHEET FORM LS-AA-104-IOOl Revision 3 Page I of3 StationlUnit(s): Byron Units I and 2 ActivitylDocument Number: EC 388479 / EC 388894 Revision Number: 4 / 2

Title:

Install Time Delayed Auto-Restart for U-I (U-2) VD Fans in Support of HELB Mitigation Strategy NOTE: For 50.59 Evaluations, information on thisform will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d) (2). Description of Activity: (Provide a brief concise description of what the proposed activity involves.) The proposed activity consists of two engineering changes, one for Unit 1 and one for Unit 2:

• EC 388894 Install Time Delayed Auto-Restart for U-I VD Supply Fans in Support of HELB Mitigation Strategy
• EC 388479 Install Time Delayed Auto-Restart for U-2 VD Supply Fans in Support of HELB Mitigation Strategy The proposed activity consists of the installation of a time-delayed auto restart for the diesel generator room and day tank room ventilation (VD) system supply fans in support of a new high energy line break (HELB) mitigation strategy. The ECs will install new timers and circuit changes to automatically restart the fans, following a short time delay, after a high differential pressure trip. This feature will work with the new HELB damper installation under EC 388896 and EC 388443 to mitigate the consequences of a HEIB in the turbine building. The 50.59 assessment for the installation of the new HELB dampers is performed as part of the damper installation design changes (EC 388896 and EC 388443).

The final configuration considered in this screening includes the installation of the new timers and circuit changes via the completion of these ECs along with the installation of the new HELB dampers. The proposed activity (along with EC 388896 and EC 388443) is being undertaken to address a vulnerability identified during a review of the effects of certain high energy line breaks in the turbine building which could affect redundant trains of safety-related equipment. EC 388894 and EC 388479 modit the control circuits for the following fans:

• l(2)VDOICADivision 11(21) DG Room Ventilation Supply Fan
• 1(2)VDOICB Division 12(22) DG Room Ventilation Supply Fan A new time delay relay will be installed to automatically restart the fan after a fan trip on high differential pressure occurs. The auto restart will occur a short time after the differential pressure trip. The time delay is intended to restart the supply fan after a brief time following momentary isolation of the exhaust path a condition that could occur following a nearby high energy line break in the turbine building (which may close the new HELB dampers added by EC 388896 and EC 388443). The new time delay relays will be installed in existing local panels.

The new HELB dampers are designed to close upon reverse flow from the turbine building to the auxiliary building. Closure of the HELB dampers with the VD ventilation supply fans running wilt create back pressure to the fan which may cause it to trip on high differential pressure, disrupting supply airflow to the EDG Room. In order to minimize the heat up of the room, the proposed activity will modify the control logic for the EDG Room supply fans such that the fans will auto-restart one time following a high differential pressure trip after a time delay of sufficient duration to allow the HELB pressure transient to dissipate and allow restart of the fans, thereby re-establishing ventilation through the new HELB dampers. The UFSAR will require updates to reflect the design of the differential pressure trip to allow one automatic fan restart attempt. These changes will be processed under DRP 14-084. Reason for Activity: (Discuss why the proposed activity is being performed.) The proposed activity is part of an improved method for mitigating turbine building HELB effects in areas serviced by the VD system.

50.59 REVIEW COVERSHEET FORM LS-AA-l04-l00l Revision 3 Page2of3 Station/Unit(s): Byron Units I and 2 Activity/Document Number EC 388479 / EC 388894 Revision Number: 4 / 2

Title:

tnstall Time Delayed Auto-Restart for U-I (U-2) VD Fans in Support of HELB Mitigation Strategy The current strategy for mitigating the effects of such breaks, as described in the UFSAR, credits closure of the affected fire dampers as the result of the thermal link temperature exceeding its setting due to the high temperatures in the vicinity of the piping failure. The fire damper closure results in tripping of the VD supply fans (when running) on high differential pressure once the damper closes and blocks the normal ventilation path from the affected room to the turbine building. Room ventilation is restored at a later time via operator action. Analyses were performed to demonstrate that the room heat up during the period that ventilation is lost would not cause required electrical equipment to become unavailable. However, a recent review of the effects of a turbine building high energy line break determined that the closure of the affected fire dampers might not occur in the time frame assumed in the analyses. In order to address this vulnerability, the proposed activity will reconfigure the dampers and ventilation systems to provide for automatic restoration of the VD system shortly after a high energy line break in the turbine building. The prompt restoration of the system, following a time delay of sufficient duration to allow the HELB pressure to dissipate, will allow for maintaining the diesel generator room rooms as a mild environment following a turbine building HELB to help ensure that electrical equipment in the affected rooms wilt remain available. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) The new fan auto restart feature will not affect normal fan operation (starting and stopping by the operator). In the event of a high differential pressure, the fan that is running will trip, as at present. However, the auto restart feature will attempt to restart the supply fan after a short time. If the high differential pressure was due to HELB damper closure (see EC 388443 and EC 38$896) following a turbine building high energy line break, the turbine building pressure will have decreased to the point where the restarted fan can re-open the HELS dampers and return the ventilation system to operation. Likewise, if a VD supply fan start attempt occurs after initiation of the turbine building HELB event, the turbine building pressure will have decreased to the point where the fan can start or restart, thereby re-opening the HELB dampers and returning the ventilation system to operation. tf the high differential pressure was due to a condition that does not clear within approximately I . time the fan restart time delay setpoint, the restarted fan wilt trip again on high differential pressure and will then be blocked from further restart attempts until an operator investigates and resets the trip. The automatic restoration of an affected VD system following a high energy line break in the turbine building will eliminate the need for a manual restoration of room ventilation by an operator following the initial VD fan high differential pressure trip. Like the existing VD equipment, a malfunction of the new equipment would not affect the availability of the redundant VD train. This is consistent with the system design bases and safety analyses requirements. Summary of Conclusion for the Activitys 50.59 Review: (Provide just/ication for the conclusion, including sufficient derail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) The proposed activity involves the installation of a new auto restart feature on the diesel generator room and day tank room ventilation (VD) system supply fans to help mitigate the consequences of a high energy line break (HELB) in the turbine building. Following installation of this feature, the VD system will continue to be capable of performing its UFSAR-described design functions of: (1) continuous ventilation for the day tank room during normal plant operation, (2) ventilation for the diesel generator when it operates, and (3) a source of combustion air for the diesel generator. As at present, the failure of a ventilation supply fan would lead to the loss of one train of the VD system. The toss of one train does not affect the safe shutdown capability of the station since independent ventilation systems are provided for each redundant division. New HELB dampers, installed under a separate activity, will be available to permit air flow through the room both during normal ventilation system operation and shortly after a nearby turbine building high energy line break, allowing the ventilation system to continue to perform its ventilation and cooling functions. A 50.59 Evaluation (6G-l2-003) was performed to address two potential adverse effects of the proposed activity:

50.59 REVIEW COVERSHEET FORM LS-AA-I04-IOOI Revision 3 Page3 of3 Station/Unit(s): Byron Units I and 2 Activity/Document Number: EC 388479 I EC 388894 Revision Number: 4 / 2

Title:

Install Time Delayed Auto-Restart for U-I (U-2) VD Fans in Supøort of HELB Mitigation Strategy

• The replacement of the current manual method of restoring room ventilation following its isolation in the event of a nearby high energy line break in the turbine building with an automatic method involving auto restart of the affected fans and the resultant re-opening of the HELB dampers
• The automatic restarting of a VD fan after an existing equipment protection feature (fan high differential pressure trip) had stopped the fan Based on the quality classification and testing of the new components, and because the proposed activity reduces the likelihood of a malfunction of the electrical equipment in the VD areas, Evaluation 6G-12-003 concluded that the potential adverse effects of the automatic system restoration following a HELB and the automatic fan restart following a trip on high differential pressure did not cause more than a minimal increase in the frequency or occurrence of an accident previously evaluated in the UFSAR and did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR.

The new fan auto restart feature does not involve a change to a procedure that adversely affects how UFSAR-descnbed SSC design functions are performed or controlled. However, the change from manual to automatic restoration of room ventilation following its isolation in response to a turbine building high energy line break was addressed in the evaluation. As discussed in the previous paragraph, the evaluation concluded that this change did not cause more than a minimal increase in the frequency or occurrence of an accident previously evaluated in the UFSAR and did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previousty evaluated in the UFSAR. The analyses performed as part of this activity do not involve UFSAR-described methodologies or alternate methodologies used in establishing the design bases or in the safety analyses. The VD system and associated components will not be utilized or controlled in a manner that is outside the reference bounds for their design or that is inconsistent with analyses or descriptions in the UFSAR. Since the VD system is not addressed in the Technical Specification or Operating License, no change to these documents is required. In conclusion, the proposed activity does not require prior approval by the NRC, and the activity can be implemented per the governing procedure. Attachments: Attach alt 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) Applicability Review 50.59 Screening 50.59 Screening No. 6E-12-15l Rev. I 50.59 Evaluation 50.59 Evaluation No. 6G-l2-003 Rev. I

50.59 REVIEW COVERSHEET FORM LS-AA-104-1001 Revision 3 Page I of3 StationlUnit(s): Byron Units I and 2 Activity/Document Number; EC 38847$! EC 388893/ DRP 14-0$4 Revision Number: I / 0/0

Title:

Install Time Delayed Auto-Restart for li-I (U-2) VX Fans in Supnort of HELB Mitigation Strategy NOTE: For 50.59 Evaluations, information on thisform will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d) (2). Description of Activity: (Provide a brief concise description ofwhat the proposed activity involves.) The proposed activity consists of two engineering changes, one for Unit I and one for Unit 2;

• EC 388893 Install Time Delayed Auto-Restart for U-I VX fans in Support of HELB Mitigation Strategy
• EC 38847$ Install Time Delayed Auto-Restart for U-2 VX fans in Support of HELB Mitigation Strategy The proposed activity consists of the installation of a time delayed auto-restart for the Switchgear Room Ventilation System (VX) fans l(2)VXOIC, l(2)VXO2C, I(2)VXO3C, l(2)VXO4C in support of a high energy line break (HELB) mitigation strategy.

These ECs will install new timers and circuit changes to auto restart the VX fans, following a short time delay, after a high differential pressure trip. This feature will work with the new HELB damper installation under EC 388442 and EC 388895 to mitigate the consequences of a postulated turbine building KELB. The 50.59 assessment for the installation of the new HELB dampers was performed as part of the damper installation design changes (EC 388442 and EC 388895). The final configuration considered in this screening includes the installation of new timers and circuit changes via the completion of these ECs along with the installation of HELB dampers. The proposed activity (along with EC 388442 and EC 38$$95) is being undertaken to address a vulnerability identified during a review of the effects of certain high energy line breaks in the turbine building which could affect redundant trains of safety-related equipment. EC 388893 and EC 388478 modit the control circuits for the following fans:

• l(2)VXOIC Division 12 (22) ESF Switchgear Supply Fan
• t(2)VXO2C Non-ESF Switchgear Supply Fan
• l(2)VXO3C Division 12 (22) Cable Spreading Room Supply Fan
• l(2)VXO4C Division 11(21) ESF Switchgear Supply Fan A new time delay relay will be installed to automatically restart the fan after a fan trip on high differential pressure occurs. The auto restart will occur approximately 60 seconds after the differential pressure trip. The time delay is intended to restart the fan after a brief time following momentary isolation of the exhaust path a condition that could occur following a nearby high energy line break in the turbine building (which may close the new HELB dampers added by EC 388442 and EC 388895). The new time delay relays will be installed in existing local panels (l(2)VXOIJ, l(2)VXO2J, and 1(2)VXO4J).

Redundant HELB dampers will be installed in series with fire dampers via EC 388442 and EC 388895. The new HELB dampers are designed to close upon reverse flow from the turbine building to the auxiliary building. Closure of the I-IELB dampers with the VX ventilation fans running will create back pressure to the operating fan which may cause it to trip on high differential pressure, disrupting the supply airflow. In order to minimize the heat up of the affected areas, the proposed activity fEC 388478 and EC 388893) will modi& the control logic for the fans listed above, such that the fans will auto-restart one time following a high differential pressure trip after a time delay of sufficient duration to allow the F[ELH pressure transient to dissipate and allow restart of the fans, thereby re-establishing ventilation through the new HELB dampers. The UFSAR will require updates to reflect the design of the differential pressure trip to allow one automatic fan restart attempt. This will require changes to Section 7.3.1.1.11 Essential Switchgear Rooms, Miscellaneous Electrical Equipment Rooms and Battery Rooms Ventilation Systems Instrumentation and Controls, Section 9.4.5.4 ESF Switchgear Ventilation Systems and Table 9.4-16 Switchgear Room Ventilation System Failure Analysis. These changes will be processed under DRP 14-084.

50.59 REVIEW COVERSHEET FORM LS-AA-104-l001 Revision 3 Page 2 of 3 Station/Unit(s): Byron Units I and 2 Activity/Document Number: IC 388478 I IC 388893 I DRP 14-084 Revision Number: 1 / 0/0

Title:

Install Time Delayed Auto-Restart for U-I (U-TI VX Fans in Support of NELB Mitigation Strategy Reason for Activity: (Discuss why the proposed activity is being performed.) The proposed activity is part of an improved method for mitigating turbine building HELB effects in areas serviced by the VX system. The current strategy for mitigating the effects of such breaks, as described in the UF$AR, credits closure of the affected fire dampers as the result of the thermal link temperature exceeding its setting due to the high temperatures in the vicinity of the piping failure. The fire damper closure results in tripping of the ventilation system fans on high differential pressure once the damper closes and blocks the normal ventilation path from the affected room to the turbine building. Room ventilation is restored at a later time via operator action. Analyses were performed to demonstrate that the room heat up during the period that ventilation is lost would not cause qualified electrical equipment to become unavailable. However, a recent review of the effects of a turbine building high energy line break determined that the closure of the affected fire dampers might not occur in the time frame assumed in the analyses. In order to address this vulnerability, the proposed activity will reconfigure the dampers and ventilation systems to provide for automatic restoration of the VX system shortly after a high energy line break in the turbine building. The prompt restoration of the system, following a time delay of sufficient duration to allow the FIELB pressure to dissipate, will allow for maintaining the switchgear rooms as a mild environment following a Turbine Building HELB to help ensure that electrical equipment in the affected rooms will remain available. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) The new fan auto restart feature will not affect normal fan operation (starting and stopping by the operator). In the event of a high differential pressure, the fan will trip, as it does at present. However, the auto restart feature will attempt to restart the fan after approximately 60 seconds. If the high differential pressure was due to HELB damper closure (see IC 388442 and IC 388895) following a turbine building high energy line break, the turbine building pressure will have decreased to the point where the restarted fan can re-open the HELB damper and return the ventilation system to operation. If the high differential pressure was due to a condition that does not clear within approximately 60 seconds, the restarted fan will trip again on high differential pressure and will then be blocked from further restart attempts until an operator investigates and resets the trip. The automatic restoration of an affected VX system following a high energy line break in the turbine building will eliminate the need for a manual restoration of room ventilation by an operator following the initial VX fan high differential pressure trip. Like the existing VX equipment, a malfunction of the new equipment would not affect the availability of the redundant VX train. This is consistent with the system design bases safety analyses requirements. Summary of Conclusion for the Activitys 50.59 Review: (Provide jusrifi cation for the conclusion, including sufficient derail to recognize and understand rite essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) The proposed activity involves the installation of a new fan auto restart feature on the engineered safety features switchgear ventilation system fans to help mitigate the consequences of a high energy line break in the turbine building. Following installation of this feature, the VX system will continue to be capable of performing its UFSAR-described design function of removing equipment heat to maintain the room temperatures in accordance with equipment requirements under normal, abnormal, and accident conditions, as described in the UFSAR. As at present, the failure of a ventilation system fan would lead to the loss of one train of the VX ventilation system. The loss of one train does not affect the safe shutdown capability of the station since independent switchgear ventilation systems are provided for each redundant division of switchgear. New HELB dampers, installed under a separate activity, will be available to permit airflow through the room both during normal ventilation system operation and shortly after a nearby turbine building high energy line break, allowing the ventilation system to continue to perform its ventilation and cooling functions.

50.59 REVIEW COVERSHEET FORM LS-AA-104-100l Revision 3 Page 3 of 3 Station/Unit(s): Byron Units 1 and 2 Activity/Document Number: EC 38847$ / EC 388893! DRP 14-084 Revision Number: I / 0 / 0

Title:

Install Time Delayed Auto-Restart for U-I (U-2) VX Fans in Support of HELB Mitigation Strategy A 5059 Evaluation (6G-l2-007) was performed to address two potential adverse effects of the proposed activity:

• The replacement of the current manual method of restoring room ventilation following its isolation in the event of a nearby high energy line break in the turbine building with an automatic method involving auto restart of the affected fans and the resultant re-opening of the HELB dampers
• The potential adverse effect on a VX fan from automatically restarting the fan after an existing equipment protection feature (fan high differential pressure trip) had stopped the fan Based on the quality classification and testing of the new components, and because the proposed activity reduces the likelihood of a malfunction of the electrical equipment in the VX areas, Evaluation 6G-12-007 concluded that the potential adverse effects of the automatic system restoration following an HELB and the automatic fan restart following a trip on high differential pressure did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR.

The new fan auto restart feature does not involve a change to a procedure that adversely affects how UFSAR-descnbed SSC design functions are performed or controlled. However, the change from manual to automatic restoration of room ventilation following its isolation in response to a turbine building high energy line break was addressed in the evaluation. As discussed in the previous paragraph, the evaluation concluded that this change did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR. The analyses performed in support of the new fan auto restart feature do not involve UfSAR-described methodologies or alternate methodologies used in establishing the design bases or in the safety analyses. The VX system and associated components will not be utilized or controlled in a manner that is outside the reference bounds for their design or that is inconsistent with analyses or descriptions in the UFSAR. Since the VX system is not addressed in the Technical Specification or Operating License, no change to these documents is required. In conclusion, the proposed activity does not require prior approval by the NRC, and the activity can be implemented per the governing procedure. Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) fl Applicability Review 50.59 Screening 50.59 Screening No. 6E-12-122 Rev. 0 50.59 Evaluation 50.59 Evaluation No. 6G-12-007 Rev. 0

389897 Rev4 Page 742 of 765 5O59 REVIEW COVERSHEET FORM LS-AA-104-lO0l Revision 3 Page 1 of 4 Station/Unit(s): Byron Unit 2 Activity/Document Number: EC 389897 DRP 14-090 Revision Number: 004:N/A

Title:

SAT Loss of Phase Detection Scheme Phase Unbalance Relay Installation p,rQ7. for 50.59 Evaluations, information on thisform will provide the basis for preparing the biennial sunmiwy report submitted to the NRC in accordance with the requirements of 10 CFR 50,59fd)t2..). Description of Activity: (Provide a brief concise description ofwhat the proposed activity involves.) The proposed activity will add a new relaying scheme to detect a lossofphase condition on the 345kv side of the Unit 2 System Auxiliety Transformers (SATs) to isolate the (SATs) and to alarm the condition so that the appropriate operator action can be taken. The equipment for the new loss-of-phase proteethe relay system will be housed in one new cabinet to be installed in the Unit 2 Auxiliary Electric Equipment Room (AEER). The new relaying scheme will consist of two loss-otphase relays with new test switches mounted in the new cabinet. The new relays will be electrically connected to the SAT high side (345kV) current transformers (CT) at existing panel 2PA23J, Note that the relays will detect an open phase condition in one or in two phases. lhroughout the remaining discussion tIme use of open phase refers to either or both conditions. The new lwotecti.e relay scheme monitors the current input from existing CTs on the high side of the SATs to tleteet a loss of phase and to proside an alarm when load is below the MINLOAD (All Generators Otfline)setpoini (defined in EC 389897), The new loss-of-phase relays will compare the positive sequence currents, the negative sequence currents and the zero sequence Currents at both of the unit SA ls 345kV side, and on a detected toss of phase, these relays will, ttepending upon transformer loading respond as folloss

• Vliemi the primary current in the SAT is above the established relay MINLOAD (All Generators Offlumme) setpoini the low load condition (as defined in the EC 389897), the relay will initiate a SAT lockout for 311 open phase condition via actuation of the existing SAT lockout relays and initiate a Loss of Phase Alarm.
• When the primary current in the SAT is below the established relay MINLOAD (All Generators Offline) serpoint (as defined in LC 389897), a Low Loafi Alarm will aCtuate in the control room and the trips that may be susceptible to spurious actuation will he blocked.

A one-out-of-two coincidence logic is used for the two loss-of-phase relays, such that a current imbalance on either division will actuate the loss-of-phase protection system to isolate the .SATs and to provide the toss-of-phase alarm, The sequence current logic foe alarm and trip functions is provided with a short time delay. The time delay allows the detection scheme to differentiate between an open phase conditiomi (hich will actuate the lossofphase trip function and alarm) and a iiulr condition (such as a line fault in the transmission system which sliouW be cleared by the existing etwrdinated protective circuits) or normal operational actMties (such as pump starts and slops). Under Revision 004 to EC 389897, the following changes fma.e been implemented:

• the changes to the relay setpoint calculation anti new supporting calculations have been added to the EC. These include:

o B\ Rt3l76176, Loss of Phase Detection EMTP \nalysis o BVRI3-l77177. Loss of Phase Detection Relay Settings o B\ RI 3221, OpenPhase Concurrent with C,OCA Analysis

• Incorporate changes to enable the new Loss-of-Phase Relays to provide the trip function to the SAT lockout rela s Reason far Activity:

(Discuss why the proposed activity is being performed.) The activity is being undertaken to address a vulnerability identified during an event that occurred on January 30, 2012 at Byron Station, when the mechanical failure of a porcelain insulator on the C phase of the 345kV teed to $Al 242-1 and SAT 242-2

389897 Rev 4 Page 743 of 765 5O59 REVIEW COVERSHEET FORM LS-AA-104-lOQl Revision 3 Page2of4 Station/Unit(s): Byron Unit 2 Activity/Document Number: EC 389$97 DRP 14-090 Revision Number: )f4N/A

Title:

SAT Loss of Phase Detection Scheme Phase Unbalance Relay Installation created a single phase voltage condition in the switchyard that propagated through the SATs to the buses fed from the SATs, thereby causing a degraded power condition on those buses. The plant transient that followed resulted in a reactor trip, but the 4kV engineered safety features (ESF) buses remained in a degraded condition until operator action isolated the defective (open phase) power supply to the 4kV ESF buses. It was discovered that, although one channel of the measured voltage at the 4kV ESF buses during this event fell below the degraded voltage setpoint value, the other channel of measured voltage remained above the setpoint, thereby preventing actuation of the degraded voltage relays (which operate on a two-out-of-two coincidence logic). further analysis determined that the measured voltage difference between any two of the three phases at the 4kV ESF buses during a similar open phase event, but under different system operating conditions, might remain near normal levels. In such a situation, the loss of phase could not be detected at the 4kV ESF buses. As a result, the loss-of-phase sensing equipment to be installed by the proposed activity is not placed on the 4kV buses or in the Class tE system but, rather, is placed in the non-Class IE system upstream of the 4kV buses. The intent of the new lossntphase detection scheme is to enhance the protection for the Class IF. system from, and to alert the operators to. a potential degradett condition caused by a loss ofa single, or two phases thai could adversely affect both the Class I E and the nonClass IL systems. In addition, the j)rUposetl change is consistent with Industry uifhelines provided by NF.I in 1n<lustry liiitiative on Open Phase Condition, Project Number: 689, dated October 9, 2013. This guideline iclentitles that it is important that an open phase in the offsite poi er circuits not prevent ttinctioning of important to safety SSCs. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) This activity will install a new relaying scheme to: (I) detci a loss of phase upstream of the SAf and (2) actuate the eistiug SAT lockout relays to isolate the SATs upon detection of a loss of phase, shen in the uclay operating regions as described above When a SAl is isolated, its assnciafc(l 4kV ESE bus wilt experience an uunderoltagc confhtion. ibis will start the emergency tiesel generator (LOG), load shed the bus, and then toad the bus isith the required ESF loads. When the SAT is isolated, the feed to the associated 6.9kV htis will automatically be transferred from the SAT to the unit auxiliary transformer (1 T). if it is available. That is, the actuation of the new scheme will produce the same results as the actuation of existing SAT protection devices. The new relays are not capable ut providing reliable loss of phase detection, when the primary current in the associated SAT is below the established relay slINLOAI) (All Generators Ornine) setpoint. To this situation the trips that may be susceptible to sptlrious actuation will be btoeketL In addition, the relay wilt provide an alarm in the control room on an internal failure of the uelay for all operational considerations. Ibis alarm proxhles indication to Operations retarding the loss of phase functionality. The new scheme does not impact the manual opening or closing of the 345kV bus tie breakers or of the feed breakers to the 4kV and 6.9kv buses, and will not alter the method of operating the SATs or the 4kV or 6.9kv buses. The manual realignment of power supplies to the 4kV and 6.9kv buses, described in UFSAR Section 8.3.1.1.2, is not affected. Therefore, there is no change I in how the SAT, 4kV bus, or 6.9kV bus UfSAR-described design functions are performed or controlled. The proposed activity, EC 389897, is based, in part, on an engineering evaluation of the plant design and licensing basis (EC 387590) which concluded that the event w:is caused by a failure of a switchy:ircl component and that detection down to the level of this type of failure is beyond the requirements t,f G DC I? and was not contemplated as part ot the original plant design. Therefore, the Iunction of automatically separating 11w off site source during this event wns not cpeciticallv identified as an automatic action is ithin the original plant design criteria .As such, the 1)roposedI actk itv has been developed as an enhancement to plant safety that adtiresses a condition that is outside the current design and licensing basis tur the plant.

389897 Rev4 Page 744 of 765 50.59 REVIEW COVERSHEET FORM LS-AA-I04-tOOl Revision 3 Page3of4 I Station/Unit(s): Byron Unit 2 Activity/Document Number: EC 389897 DRP 14-090 Revision Number: 0()4;N/A

Title:

SAT Loss of Phase Detection Scheme Phase Unbalance Relay Installation Summary of Conclusion for the Activitys 50.59 Review: (Provide just flcationJbr the conclusion, including s:fflcient detail to recognize and understand the essernia! arguments leading to the conclusion, Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) Since the proposed activity is cousulered an enhancement ot the preferred (offsite) power source to protect the C lass I E system from a condition that is outside the current desiitn and licensing basis tot the plant, the failure of the new s)stem to perform its intended function of isohttixtg the units SATs Upon detection ot a loss of phase upstream of a SAt does not adversely atTect any IFS R-describcd design function. The proposed activity will add a new relaying scheme to detect and alarm a loss-of-phase condition on the 345kV side of the Unit 2 SATs so that the degraded offsite source can be removed from the onsite electrical distribution system. The proposed activity does not adversely affect SAT capacity or the existing automat:ic and manual sitcliing capabilities involving the normal. reserve. or cmerency teeds to the 3kv FSF buscs 4kV non-F.SF bu%es or the 6k buses, the proposed activity does not adversely affect the existing equipment protection. inclufling protection from overcurrent, undervoltage, or degraded voltage conditions. tn addition, there is no adverse impact on UFSAR-described design functions for the I25VDC, control room annunciator, or HVAC systems, all of which interface with the new alarm system. Therefore, the installation of the new alarm system does not adversely affect any Uf$AR-described design function. If a loss of phase is detected as discussed above, the protective rein system 4ill actuate the ST lockout relays to isolate the SATs and will alert the operators to the degraded condition of the offsite power source feeding the SATs, These actions will produce the same results as actuation of existing SAT protection that is, isolation of the station electrical distribution system from the problem and re-alignment of the affected buses to alternate AC sources. [he procedure changes involved sith this activity do not do involve a change to a procedure that adversely affects how UF$AR-described SSC design functions are performed or controlled. However, the installation of a new system antI new equipment shose spurious actuation, due to a relay maittmnction. could result in a loss of offcite povcr to the 4kV ESF buses or (if one or more of the UAT feeds to the (i.9lV buses were not availal)le) loss ofa unit adversely atTects the UFSAR (Section 3.1.2.2.5) described design functiomi that: provisiomas must he included to minimize the probability ot losing electric power from the transmission network, as is required by GD( I?. *Fherefore, a 50.59 evaluation was performed for 50.59 Screening Question 1. The $0.59 Evaluation determined that due to the balautciuig of the positive effects (isolating a degraded posser source) and the potential unlikely negative effects (inappropriate isolation of a functioning power source). the proposed activity does hot result it, more thauu a minimnal increase in the frequency of occurrence of an accident previously evaluated in the U ESAR or result in a more then minimal increase in the freqtmencv ot a malfunction of an SSC. The new protective relays being installed as part of the loss-of-phase protective system are non-safety-related devices and, therefore, not subject to the protective relay setpoint methodology described in the UFSAR for safety-related protective relay setpoints. The rnetltodohnty used to determine a successful bus transfer is nut described in the tIFSAR. In addition, assessments for combustible loading, battery sizing (for added relay DC loading), AEER heat loading, conduit supports and structural loading performed to support this activity have been performed utilizing methodology consistent with that described in the UFSAR. The proposed activity involves the installation of a new scheme to detect, isolate the SAts. and alarm a loss of phase upstream of the Unit 2 SATs. No SSC is operated or controlled in a manner that is outside the reference bounds for design for that S5C. [he I ES R cliscuissions of protective uclays and associated evaluation methodologies arc aimed at (lass I E protective devices. therefore, this change does not involve an ndveuse ch:uiuge to an element of a UVSARclescrilwd evaluation methothilogy. or muse of an airernathe methodology, that is used in establishing the design bases ni used in the safety analyses.

389897 Rev 4 Page 745 of 765 50.59 REVIEW COVERSHEET FORM LS-AA-104-IO0l Revision 3 Page4of4 Station/Unit(s): Byron Unit 2 Activity/Document Number: EC 389$97 DRP 14-090 Revision Number: 004:N/A

Title:

SAT Loss of Phase Detection Scheme Phase Unbalance Relay Installation Eistiiig p ()tectlve features protect the SAT in the event of various electrical system failures. While the new protective feature does not protect the SAT but, rather, protects the equipment powered from the 4kV and 6.9kV buses, the new protective featttre utilizes the SAT lockout in a similar manner to isolate a degraded or faulted offsite power supply from the 4kV and 6.9kv busses. Therefore, this manner of utilizing the SAT lockout is not outside the reference bounds ol the design for the 8.U nor is it inconsistent with anal3ses or descriptions in the UFSAR. The proposed activity involves the installation ot an additional feature so that the power supply to a 4kV ESF bus will be controlled in the same manner as at presentthat is, an unreliable power supply to the 4kV ESF buses will be disconnected. Tlwrefoie. the proposed activity does not in ohe a test or eperiInent not described in the UFSAR, where an SSC is utilized or controlled in a manner that is outside the reference bounds of the design før that SSC or is inconsistent with analysis or description in the UFSAR. The new protectIve scheme is not specitically considered a Loss ofOfisite Power (LOOP) protective system as described in the Technical Specification or in the Technical Specification Bases because it does not sense voltage at the 4kV ESF buses. In addition, the new scheme does not affect the times or functions of the existing required degraded or undervoltage protective relay systems that are described in the Technical Specifications, Existing SAT protection features are not addressed in the Technical Specifications; therefore, the eistirig Technical Specifications are not affected by the proposed acthity. Since the pioposed activity is considered an enhancement of the preferred (offsite) p1mer source to protect the Class IF. system trum a condition that is outside the current design anti licensing basis fur the plant, no new Technical Specifications are needed. The St).59 evaluation demonstrated that all of the questions were answered as NO anti, therefore, the proposed activity can L)e installed without prior approval by the NRC, in accordance with the governing procedures. Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) Applicability Review 50.59 Screening 50.59 Screening No. 6E-12-203 Rev. , 50.59 Evaluation 50.59 Evaluation No, 6C-l%-Of)8 Rev. 2

50.59 REVIEW COVERSHEET FORM LS-AA-104-l00I Revision 3 Page 1 o13 Station/Unit(s): Byron / Unit 0 Activity/Document Number: EC 389728; DRP#14-095, Basis Change Requests 12-008,009 Revision Number:0,O,0,0

Title:

Main Control Room Main Control Room Ventilation (VC) High Energy Line Break (HELB) Pressure Sensor to Control Emergency Intake Dampers Modification (Unit Common) NOTE: For 50.59 Evaluations, information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CfR 50.59fd)(2). Description of Activity: (Provide a brief, concise description of what the proposed activity involves.) The proposed activity will install pressure sensors and controls to keep the emergency make-up air Turbine Building intake damper (OVC25Y / OVCO9Y) closed on high intake pressure (resulting from HELB) and automatically transfer to the outside air intake (OVC3I2Y I OVC313Y) for emergency make-up. This will be accomplished via the installation of three pressure sensors that will detect overpressure in the turbine building intake damper ductwork. The sensors will be configured in a normally energized 2 out of 3 logic to prevent spurious actuation and to build redundancy into the design. The logic will be powered by an uninterruptible source to enable detection of a KELB concurrent with a loss of power and wilt be designed to fail the dampers to the Emergency Outside Air mode on loss of power to the control logic. The Control Room make-up filter inlet selector switch will be replaced with a 3 position (Turbine-Auto-Outside Air) switch. Operating Procedures wilt normally maintain the hand switch in Auto. Additionally, the failure position for the Turbine Building intake dampers OVC2SY and OVC09Y will be changed from Fail Open to Fail Closed. Finally, the ductwork from L-row wall to the intake damper OVC25Y

   / OVCO9Y will be qualified such that it can withstand the HELB pressure pulse.

The UFSAR Change Request DRP 14-095 will update UF$AR Sections 6.4, 6.5.1, 7.3.1, 7.3.1, 7.3.2, 15.1.5, Table 7.3-5. Table 15.0-I 1: UFSAR Figures 6.4-5, 6.4-6, 6.4-7, 6.4-8 to reflect the installation of the new HELB detection instrumentation and controls and modified system operation and updated Chapter accident analysis consequences. The fire protection report will be updated by FDRP 26-001. Technical Specification Basis Change request 12-008 (A Train) and 12-009 (B Train) will update the basis for Technical Specification B.3.7. 10 to reflect the modified system operation during a HELB event in the turbine building. Reason for Activity: (Discuss why the proposed activity is being performed.) The proposed activity is intended to protect the Control Room from the effects of a HELB in the Turbine Building. A HELB in the Turbine Building can adversely affect the Main Control Room (MCR) via a make-up ventilation connection in the Turbine Building. The ventilation connection could allow steam from a HELB to enter the MCR, exposing the equipment and personnel to high temperatures and humidity. The design of the Control Room Ventilation fVC) System is currently configured such that emergency make-up air following a Main Steam Line Break, Reactor Coolant Pump Shaft Seizure (Locked Rotor), Loss of Coolant Accident, Steam Generator Tube Rupture (SGTR) Event and Fuel Handling Accident is drawn from the Turbine Building (versus outside). Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) The control room HVAC system (VC) will function under normal conditions as described in UFSAR Section 9.4.1. Under post-accident conditions, the UFSAR will be revised to reflect that the control room envelope will be protected from a HELB in the turbine building by ensuring the Turbine Building intake dampers (OVC25Y / OVCO9Y) are closed and the outside intake dampers (OVC3I2Y/OVC3I3Y) are open. IfHELB conditions are not present in the turbine building, the system will function as currently described in the UPSAR (makeup air from the turbine building). The Turbine Building intake dampers (OVC25Y/OVCO9Y) will be changed from fail open to fail closed. The loading on I2OVAC Instrument Buses IIPOIJ and 1IPO4J will be increased which has been reviewed and is within the capacity of the inverter feeding the instrument bus with adequate design margin. The change also adds a minor amount of heat load to the control room envelope impacting the control room ventilation system and is well within the systems cooling capability.

50.59 REVIEW COVERSHEET FORM is--io-iorn Revision 3 Page 2 of 3 StationfUnit(s): Byron / Unit 0 Activity/Document Number: EC 389728; DRP#14-095, Basis Change Requests 12-008.009 Revision Number:0,0,0,0

Title:

Main Control Room Main Control Room Ventilation (VC) High Energy Line Break (HEEB) Pressure Sensor to Control Emergency Intake Dampers Modification (Unit Common) Summary of Conclusion for the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50,59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) The modification to install new HELB detection instrumentation and changes the failure position of the turbine building emergency intake damper will not affect the control room ventilation system operation during normal operation. The abnormal operation of the VC system is not affected except for the HELB accident. During a HELB the emergency makeup air will be drawn from the emergency outside air intake preventing an adverse environment in the control room. Therefore, this modification will ensure the control room environment is maintained with the design basis limits for critical instrumentation and controls. As a result, the possibility of failures of safety related control system due to adverse environmental conditions which could initiate a transient or accident is not created. The Control Room Ventilation System (VC) is not an accident initiating system. Therefore, it is concluded that the modified control room emergency intake damper controls and the modified turbine building emergency intake damper failure position does not result in an increase in the frequency of occurrence of an accident previously evaluated in the UFSAR.

2. The modification to install new HELB detection instrumentation and change the failure position of the turbine building emergency intake damper will not result in more than a minimal increase in the likelihood of occurrence of a malfunction of an SSC important to safety previously evaluated in the UFSAR because the new components are qualified, safety related components and failure of the turbine building intake damper is less likely by changing the damper to fail closed since the hydraulic system will no longer be required to hold the damper closed. The impact on control room ventilation due to the minor increase in heat loads was evaluated and well within the system capability.

Inverter loading due to the increased load on the instrument buses was evaluated and the loading was within the capacity of the inverter with adequate design margin. The battery evaluations consider the inverter fully loaded. Given the inverters are tested and evaluated for full loading and the battery evaluation considers the inverters fully loaded the addition of the new controls on the instrument buses does not result in more than a minimal increase in the likelihood of occurrence of a malfunction of the inverter or batteries.

3. The modification to install new IIELB detection instrumentation and change the failure position of the turbine building emergency intake damper will decrease the dose to the control room operator following a Main Steam line break. The Steam Generator Tube Rupture, Loss of Coolant Accident, fuel Handling Accident, Reactor Coolant Pump Shaft Seizure (Locked Rotor) dose calculations remain bounding. Therefore, the modification to install the HELB detection control system and change the failure position of the turbine building emergency intake damper will not result in a more than a minimal increase in the consequences of an accident previously evaluated in the UFSAR.

4. UFSAR Chapter 9 Section 9.4.1.3 discusses that redundant equipment is provided to assure safety system function.

Table 9.4-2 described the existing control room system failure analysis. The table reviews various failures including a Make-up Air Filter Unit fan Failure which would result in an alarm in the main control room and switching to the redundant train. The consequences of these failures have not been affected. The consequences of the new fail closed turbine building emergency intake damper failing to open have been reviewed and are bounded by the existing malfunction consequences. In addition, the failure of the HELB Detection instrumentation and controls have been reviewed and determined to be bounded by the existing malfunction consequences. Therefore, the modification to install the NELB detection control system and change the failure position of the turbine building emergency intake damper does not result in a more than minimal increase in the consequences of a malfunction of an SSC important to safety previously evaluated in the UFSAR.

5. The installation of the new HELB detection instruments and changing the turbine building damper to fail closed from fail open does not introduce the possibility of a new accident because the control room ventilation system is not an initiator of any accident and the change will not affect the control room temperature controls such that it could introduce failure of control circuits located within the area served by the control room ventilation. Failure of the

50.59 REVIEW COVERSHEET FORM LS-AA-l04-lOOl Revision 3 Page 3 of 3 Station/Unit(s): Byron / Unit 0 Activity/Document Number: EC 389728; DRP#14-095, Basis Change Reguests 12-008,009 Revision Number:0,0,0,0

Title:

Main Control Room Main Control Room Ventilation (VC) High Energy Line Break (HELB) Pressure Sensor to Control Emergency Intake Damprs Modification (Unit Common) turbine building emergency intake damper to open when required is similar to a fan failure on the makeup air handing unit which has previously been evaluated and a redundant train is available.

6. This change does change the failure position of the turbine building emergency intake damper from fail open to fail closed. As a result, the makeup fan could start and the turbine building intake damper could fail to open when required. Currently, the damper is de-energized to open and a spring drives the damper to the open position. In the modified configuration, the hydraulic operator would be required to open the damper. If the hydraulic operator failed to open the damper, the makeup system low flow alarm in the main control room would alert the operator and the alternate train could be started. This failure has the same result as a makeup fan failure, a filter unit high DP causing low flow or a fire damper failure. Based on the above, the failure to open the emergency turbine building intake damper has the same result as failures previously evaluated and would be mitigated by switching to the alternate train of ventilation.

7. Installation of the new controls and modifying the failure position of the turbine building intake dampers does not affect the integrity of the fission product barriers utilized for mitigation of radiological dose consequences as a result of an accident. Plant response as modeled in the safety analyses is unaffected since the control room ventilation system can still be configured in the emergency make up mode within the thirty minutes credited in the accident analysis and no parameter which impacts a fission product barrier is changed. Hence, the mass and radioactivity releases used as input to the dose calculations are unchanged from those previously assumed. Therefore, it is concluded that the modified control room emergency intake damper controls and the modified turbine building emergency intake damper failure position does not result in a design basis limit for a fission product barrier as described in the UFSAR being exceeded or altered.

8. The methods used in the plant accident analyses are not affected by the modified control room emergency intake damper controls and the modified turbine building emergency intake damper failure position. The atmospheric dispersion factor (XJQ) inputs for the main steam line break accident have changed as a result of this change since the air will be drawn from a different outside air instead of the turbine building, however the methodology has not changed. As stated above, none of the accident analyses credits the control room ventilation system filtration for the first 30 minutes. This input is not changed. All other accident dose analyses are not changed. Therefore, it is concluded that the modified controt room emergency intake damper controls and the modified turbine building emergency intake damper failure position does not result in a departure from a method of evaluation described in the UFSAR used in establishing the design bases or in the safety analyses.

Based on the above, the proposed activity may be implemented without prior NRC approval. Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) LI Applicability Review LI 50.59 Screening 50.59 Screening No. Rev. 50.59 Evaluation 50.59 Evaluation No. 6G12011 -- Rev. 0

389896 Rev4 Page 749 of 772 50.59 REVIEW COVERSHEET FORM LS-AA-104-100l Revision 3 Page 1 of4 Station/Unit(s): Byron Unit I Activity/Document Number: EC 389896 Revision Number: Ot)4

Title:

SAT Loss of Phase Detection Scheme Phase Unbalance Relay Installation iYOTE: for 50.59 Evaluations, information on thisform wilt provide the basis for preparing the biennial summaiy report submitted to the NRC in accordance with the requirements of 10 CfR 50.59d2,). Description of Activity: (Provide a brief concise description ofwhat the proposed activity involves.) The proposed activity will add a new retaying scheme to detect a loss-of-phase condition on the 345kV side of the Unit 1 System Auxiliary Transformers (SATs) to isolate the (SATs) and to alarm the condition so that the appropriate operator action can be taken. The equipment for the new loss-of-phase protective relay system will be housed in one new cabinet to be installed in the Unit I Auxiliary Electric Equipment Room (AEER). The new relaying scheme will consist of two loss-of-phase relays with new test switches mounted in the new cabinet. The new relays will be electrically connected to the SAT high side (345kV) current transformers (CT) at existing panel IPA23J. Note that the relays will detect an open phase condition in one ot in two phases. Throughout (he remniajing discussion the use of open phase refers to either or both conditions. The new proteethe relay scheme monitors the current input froni existing CTs on the high side of the SATS to detect a toss of phase and to provide an alarm when load is below the MINLOAD (All Generators Offline) setpoint (as described in EC 389896). The new loss-of-phase relays will compare the positive sequence currents, the negative sequence currents amid the zero sequence currents at both of the unit SATs 345kV side, and on a detected loss of phase, these relays will, depentling upon transformer loading respond as follows:

• When the primary current in the SAT is above the established relay MINLOAD (All Generators Offline) setpoint (defined in EC 389896), the relay will initiate a SAT lockout tr an open phase condition via actuation of the existing SAT lockout relays and initiate a Loss of Phase Mania.

a When the primary current in the SAT is below the established relay MINLOAD (Alt Generators Offliaw) setpoint (defined in EC 389896), a Low Load alarm will actuate in the control room and the trips that may be susceptible to spurious actuation will he blocked. A one-out-of-two coincidence logic is used for the two toss of phase relays, such that a current imbalance on either division will actuate the loss-of-phase protection system to isolate the SATs and to provide the loss-of-phase alarm. The sequence current logic for alarm and trip functions is provided with a short time delay. The time delay allows the detection scheme to differentiate between an open phase condition (which will actuate the loss-of-phase trip function and alarm) and a fault condition (such as a line fault in the transmission system which should be cleared by the existing coordinated protective circuits) or normal operational activities (such as pump starts and stops). Under Revision (N)4 to EC 389896, the following changes have been implemented:

• The changes to the relay setpoint calculation and new supporting calculations have been added to the EC. These include:

o BYRI3-l76, Loss of Phase Detection EMTP Analysis o BYRI3-l77, Loss of Phase t)etection Relay Settings o BYRI3-221. Open-Phase Concurrent with LOCA Analysis

• Incorporate changes to enable the new LossofPhase Relays to provide the trip function to the SAT kmckout relays Reason for Activity:

(Discuss why the proposed activity is being peiformed.) The activity is being undertaken to address a vulnerability identified during an event that occurred on January 30, 2012 at Byron Station, when the mechanical failure of a porcelain insulator on the C phase of the 345kV feed to SAT 242-1 and SAT 242-2

389896 Rev4 Page 750 of 772 50.59 REVIEW COVERSHEET FORM LS-AA-104-l0O1 Revision 3 Page2of4 Station/Unit(s): Byron Unit 1 Activity/Document Number: EC 389896 Revision Number: Ot)4

Title:

SAT Loss of Phase Detection Scheme Phase Unbalance Relay Installation created a single phase voltage condition in the switchyard that propagated through the SATs to the buses fed from the SATs, thereby causing a degraded power condition on those buses. The plant transient that followed resulted in a reactor trip, but the 4kV engineered safety features (ESF) buses remained in a degraded condition untiL operator action isolated the defective (open phase) power supply to the 4kV ESF buses. It was discovered that, although one channel of the measured voltage at the 4kV ESF buses during this event fell below the degraded voltage setpoint value, the other channel of measured voltage remained above the setpoint, thereby preventing actuation of the degraded voltage relays (which operate on a two-out-of-two coincidence logic). Further analysis determined that the measured voltage difference between any two of the three phases at the 4kV ESF buses during a similar open phase event, but under different system operating conditions, might remain near normal levels. In such a situation, the loss of phase could not be detected at the 4kV ESF buses. As a result, the loss-of-phase sensing equipment to be installed by the proposed activity is not placed on the 4kV buses or in the Class 1E system but, rather, is placed in the non-Class IE system upstream of the 4kV buses. The intent of the new lossof-phase detection scheme is to enhance the protection for the Class I £ system froni, and to alert the operators to, a potential degraded condition caused by a loss of a single, or two phases that could adversely affect both the Class I £ and the non-Class 1£ systems. In addition, the proposed change is consistent with Industry guidelines provided by NEt in tndustry Initiative on Open Phase Condition, Project Number: 689, dated October 9, 2013. This guideline identifies that it is important that an open phase in the oftsite power circuits not prevent functioning of important to safety SSCs. Effect of Activity: (Discuss how the activity impacts plant operations, design baser, or safety analyses described in the UFSAR.) This activity will install a new relaying scheme to: (I) detect a loss of phase upstream of the SAT and 2) actuate the existing SAT lockout relays to isolate the SATs upon detection nm loss of phase, when in the relay operating regions as described above When a SAT is isolated. its associated 4kV ESF bus will experience an undervokage condition. This will start the emergency diesel generator (E1)G), load shed the bus, and then load the bus with the required ESF loads. When the SAT is isolated, the feed to the associated 6.9kV bus will automatically he transferred from the SAT to the unit auxiliary transformer (UAf), if it is available. That is, the actuatioii of the new scheme will produce the same results as the actuation of existing SAT protection devices. The new relays are not capable of providing reliable loss of phase detection, when the primary current in the associated SAT is below the estabhishetl relay NIINLOAD (All Generators Offline) setpoint. in this situation the trips that may be susceptible to spurious actuation will be blocked. In addition, the relay will provide an alarm in the control room on an internal failure of the relay for all operational considerations. This alarm provides indication to Operations regarding the loss of phase functionality. The new scheme does not impact the manual opening or closing of the 345kV bus tie breakers or of the feed breakers to the 4kV and 6.9kv buses, and wilt not alter the method of operating the SATs or the 4kV or 6.9kV buses. The manual realignment of power supplies to the 4kV and 6.9kV buses, described in UFSAR Section 8.3.1.1.2, is not affected. Therefore, there is no change in how the SAT, 4kV bus, or 6.9kv bus UfSAR-described design functions are performed or controlled. The proposed activity, EC 389896, is based, in part, on an engineering evaluation of the plant design and licensing basis (EC 3$7590) which concluded that the event was caused by a failure of a switchyard component and that detection down to the level of this type of failure is beyond the requirements of GDC 17 atid was not contemplated as part of the original plant design. Therefore, the function of automatically separating the off site source during this event was not specifically identified as nit atitomatic action within the original tlaItt design criteria. As such, the proposed activity has been developed as an enhancement to plant safety that addresses a condition that is outside the current design and licensing basis for the plant.

389896 Rev 4 Page 751 of 772 50.59 REVIEW COVERSHEET FORM LS-AA-104-l001 Revision 3 Page3 of 4 Station/Unit(s): Byron Unit I Activity/Document Number: EC 389896 Revision Number: 004

Title:

SAT Loss of Phase Detection Scheme Phase Unbalance Relay lastallation Summary of Conclusion for the Activitys 50.59 Review: (ProvidejustWcationfor the conclusion, including sufficient detaIl to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) Since the proposed activity is considered an enhancement of the preferred (otfsite) power source to protect the Class I E s)stem from a condition that is outside the current design arid licensing basis for the plant, the failure of the new system In perform its intended function of isolating the units $ATs upon detection ota loss of phase upstream of a SAT does not adversely affect any UFSAR-described design function. The proposed activity will add a new relaying scheme to detect and alarm a loss-of-phase condition on the 345kV side of the Unit I SATs so that the degraded offsite source can be removed from the onsite electrical distribution system. 11w proposed activity does not adversely affect SAT capacity or the existing automatic and manual switching capabilities involving the itormal, reserve, or emergency feeds to the 4kV ESF buses, 4kV non-ESF buses or the 6.9kV buses. The proposed activity does not adversely affect the existing equipment protection, including Protection from overcurrent, undervoltage, or degraded voltage conditions, In addition, there is no adverse impact on UFSAR-described design functions for the 125V0C, control room annunciator, or HVAC systems, all of which interface with the new alarm system. Therefore, the installation of the new alan-rn system does not adversely affect any UFSAR-described design function. If a loss of phase is detected as discussed above, the protective relay system will actuate the SAT lockout relays to isolate the SATs and will alert the operators to the degraded condition of the offsite power source feeding the SATs. These actions will produce the same results as actuation of existing SAT protection devicesthat is, isolation of the station electrical distribution system from the problem and re-alignment of the affected buses to alternate AC sources. The procedure changes involved with this activity do not involve a change to a procedure that adversely affects how UFSAR-described SSC design functions are performed or controlled. However, the installation of a new system and new equipment whose spurious actuation, clue to a relay malfunction, could result in a loss of offsite power to the 4kV ESE buses or (if one or more ot the UAT feeds to the 6.9kV buses ere not available) loss of a twit adversely affects the UFSAR <Section 3.1.2.2.8) desetihed design function that: provisions must he included to minimize the probability of losing electric power from (he transmission network, as is required by GDC l7 Therefore, a 50.59 evaluation was performed for 50.59 Screening Question I. The 50.59 Evaluation determined that due to the balancing of the positive effects (isolating a degraded power source) and the potential unlikely negative effects (inappropriate isolation of a functioning power source), the proposed activity does not result in more than a minimal increase in the frequency of occurrence of an accident previously evaluated itt the UFSAR or result in a more then minimal increase in the frequency of a malfunction of an SSC. The new protective relays being installed as part of the loss-of-phase protective system are non-safety-related devices and, therefore, not subject to the protective relay setpoint methodology described in the UFSAR for safety-related protective relay setpoints. The methodology used to determine a successful bus transfer is not described in the UFSAR. In addition, assessments for combustible loading, battery sizing (for added relay DC loading), AEER heat loading, conduit supports and structural loading performed to support this activity have been performed utilizing methodology consistent with that described in the UFSAR. The proposed activity involves the installation of a new scheme to detect, isolate the SATs, and alarm a loss of phase upstream of the Unit I SATs. No SSC is operated or controlled in a manner that is outside the reference hounds [or design for that SSC. The UFSAR discussions of protective relays and associated evaluation methodologies are aimed at Class IE protective devices. Therefore, this change does not involve an adverse change to an element of a UfSAR-described evaluation methodology, or use of an alternative methodology, that is used in establishing the design bases or used in the safety analyses.

389896 Rev4 Page 752 of 772 50.59 REVIEW COVERSHEET FORM L$-AA-104-l00l Revision 3 Page4 of4 Station/Unit(s): Byron Unit 1 Activity/Document Number: EC 389896 Revision Number: 004

Title:

SAT Loss of Phase Detection Scheme Phase Unbalance Relay Installation Existing protective features protect the SAT in the event of various electrical system failures. While the new protective feature does not protect the SAT but, rather, protects the equipment powered from the 4kV and 6.9kV buses, the new protective feature utilizes the SAT lockout in a similar manner to isolate a degraded or faulted offsite povci supply from the 4kV and 6.9kV tuisses. Therefore, this manner of utilizing the SAT lockout is not outside the reference bounds of the design for the SAl nor is it inconsistent with analyses or descriptions in the UFSAR. The proposed activity involves the installation of an additional tenture so that the power supply to a 4kV E$F bus will be controlled in the same manner as at presentthat is, an unreliable power suppiy to the 4kV ESF buses will be disconnected. Therefore, the proposed activity does not involve a test or e-periment not described in the UFSAR, where an SSC is utilized or controlled in a manner that is outside the reference bounds of the design ftw that SSC or is inconsistent with analysis or description in the UFSAR. The new protective scheme is not speciflcalb considered a Loss of Offsite Power (LOOP) protective system as described in the Technical Specification or in the Technical Specification Bases because it does not sense voltage at the 4kV ESP buses. In addition, the new scheme does not affect the times or functions of the existing required degraded or undervoltage protective relay systems that are described in the Technical Specifications. ttisting SAT protection features are not acId ressed in the Technical Specilications therefore, the e\isting Technical Specifications are not affected by the proposed activity. Since the proposed activity is considered an enhancement of the preferred (ofisite) power source to protect the Class 1 E system from a condition that is outside the current design and licensing basis for the plant no new Technical Specitications are aiecdcd. Attachments: Attach alt 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) Applicability Review 50.59 Screening 50.59 Screening No. 6E-12-207 Rev. 50.59 Evaluation 50.59 Evaluation No. 66-12-012 Rev. 1

50.59 REVIEW COVERSHEET FORM LS-AA-104-l0Ol Revision 3 Page I of5 Station/Unit(s): Byron and Braidwood Units I & 2 Activity/Document Number: EC 377550 (Byron). EC 384898 (Braidwood), DRP 15-040 Revision Number:

Title:

CONFIGUR4TION CHANGE DOCUMENTS ASSOCIATED WITH RH RELIEF VALVE DISCHARGE TO THE RECYCLE HOLD UP TANK (HUT) NOTE: For 50.59 Evaluations, information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d)(2). Description of Activity: ECs 377550 and 384898 revise the design basis analysis associated with the RH relief valve discharge piping and the Boron Recycle Holdup Tanks (HUTs): I. Revised dose analysis for an atmospheric release from a postulated failure of the Boron Recycle Holdup Tank.

2. Revised atmospheric diffusion factors (yJQ) for the Exclusion Area Boundary (EAB) and Low Population Zone (LPZ) calculated based on finer wind speed categories from Regulatory Guide 1.23 Revision 1.

3. Analyses of the boron recycle holdup tank associated with postulated discharge of RCS liquid with a temperature greater than 200° F to the HUT from a RHR suction side relief valve.

The design changes include new and revised design analysis, corrections to drawings, and revisions to the UFSAR description. Reason for Activity: The design basis analyses associated with the Boron Recycle Holdup Tanks (HUTs) were revised to address findings identified in a November 72, 2008, Byron Station NRC Baseline Inspection Report and a February 9, 2009, Braidwood Station NRC Integrated Inspection Report. The NRC inspection reports identified the following:

1. A minor violation associated with the UFSAR analysis for rupture of a HUT. Discrepancies were identified between the inputs and assumptions used in the analysis and actual configuration. Specifically the existing analysis for the rupture of a recycle holdup tank failed to recognize that the gas spaces of the HUTs are normally cross-connected and that a gas decay tank normally had open communication with at least one HUT.

2. A Non-Cited Violation (NCV), associated with the licensees failure to analyze and establish an adequate quench volume within the boron recycle system holdup tanks and failure to analyze the water hammer loads on boron recycle system holdup tank inlet piping induced by relief valve discharges.

3. A NCV, for failure to adequately update the Updated Final Safety Analysis Report. Specifically, the description of: (1) the boron recycle system did not identify if the system was designed or capable of handling discharges from the safety injection and residual heat removal relief valves; (2) the residual heat removal system did not identify deviations from the system design standard with respect to the suction pipe relief valve single failure analysis and collection of relief valve discharges outside containment.

New atmospheric diffusion factors (xfQ values) were calculated to satisfy a commitment made to the NRC to reevaluate x/Q values based on finer wind speed categories provided in the latest appropriate regulatory guidance the next time calculations associated with the dose consequences are revised. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) The safety analysis description in the UFSAR is revised to indicate that the radiological consequences for a atmospheric release of a Boron Recycle Holdup Tank failure utilizes the Alternate Source Term methodology per Regulatory Guide t.l83 with dose acceptance criteria per 10 CFR 50.67. The UFSAR description of the input parameters and assumptions are revised to reflect that the gas space in both HUTs are connected to a common header, a waste gas decay tank is normally aligned to provide cover gas for the HUTs, that the water in the un-ruptured HUT could also drain via the cross-tie piping that inter-connects the two tanks, and the potential for higher activity RCS water from a RH suction side relief valve discharge to the HUT to be released to the HUT cubicle following a tank rupture.

50.59 REVIEW COVERSHEET FORM LS-AA-104-l00l Revision 3 Page 2 of 5 Station/Unit(s): Byron and Braidwood Units I & 2 Activity/Document Number: EC 377550 (Byron), EC 38459$ (Eraidwood). DRP 15..040 Revision Number: jQ1

Title:

CONFIGURATION CHANGE DOCUMENTS ASSOCIATED WITH RH RELIEF VALVE DISCHARGE TO THE RECYCLE HOLD UP TANK (HUT) The calculated Control Room, EAB, and LPZ doses increase but the dose is small compared to the regulatory limit. The increase in dose was determined to be less than minimal. The UFSAR is changed to reflect the revised dose results for a Recycle Holdup Tank failure. Branch Technical Position R$B 5-I states that fluid discharged through the RHR system pressure relief valves must be collected and contained such that a stuck open relief valve will not: (c) Result in a non-isolatable situation in which the water provided to the RCS to maintain the core in a safe condition is discharged outside of containment. Byron/Braidwood is subject to the technical requirements of RSB 5-1 as they apply to Class 2 plants. For Class 2 plants compliance with the BTP requirement for collection and containment of the relief discharge is not required if it is shown that adequate alternate methods of disposing of discharge are available. The fluid discharge by the RHR suction side relief valves and the discharge side relief valves is collected in the recycle holdup tank of the boron recycle system. The recycle holdup tank is located outside of containment. An analysis has been made to evaluate the Recycle Holdup Tank response to the opening of a relief valve. The analysis indicates the pressure in the HUT remains below the tank design pressure. The following operator actions are assumed in the analysis:

1) The analysis is based on the most limiting event of a letdown/charging flow mismatch with one charging pump running.

Operator action is assumed to be taken within 30 minutes to allow the relief valve to close or to isolate the relief valve.

2) Initial liquid level in the HUT aligned to receive input from the RH relief valve is assumed to 40%. This level provides a quench of the input from the relief valves. When RH is aligned for shutdown cooling and the RCS temperature is above 2000 F the level in the HUT aligned to receive input from the RH relief valves is administratively controlled above 40%.

Summary of Conclusion for the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) As described in UFSAR Section 15.7.2.1 an unspecified event causes the complete release of the radioactive inventory of the boron recycle holdup tanks. UFSAR Section 15.7.2. 1 states: Postulated events that could cause the release of the radioactive inventory of the spent resin storage tank and the boron recycle holdup tanks are cracks in the tanks and operator error. A failure of the HUT is expected to occur with the frequency of a limiting fault. The changes in the design basis analysis do not result in a more than a minimal increase in the frequency of a system leak or failure for the following reasons:

• The change to the dose analysis and the revised /Q analysis has no impact on any accident initiators.
• Analysis of a postulated RHR suction side relief discharge shows that the recycle holdup tank pressure remains below the tank design pressure.
• Analysis of the recycle holdup tank indicates that the localized increase in temperature in the tank that may occur due to discharge from the Ri-I suction side relief valves does adversely affect the tank design. The tank stresses remain below the allowable stress values.
• As discussed in UFSAR Section 15.7.2.1 a radioactive release from a tank caused by operator error is also considered a remote possibility. The UFSAR credits Operating techniques and administrative procedures emphasize detailed system and equipment operating instructions for minimizing the risk of tank failure due to operator error. The revised analysis utilizes similar administrative procedure controls on HUT water level to provide a quench for possible discharge from the RH suction side relief valves.

The change to the design basis does not result in more than a mininial increase in the likelihood of occurrence of a malfunction of a SSC important to safety previously evaluated in the USFAR. The recycle holdup tank pressure remains below the tank design pressure during a postulated RI-JR suction side relief discharge. The tank stresses remain below the allowable stress values. The revised dose analysis, revised analysis of atmospheric dispersion factors, and analysis of HUT conditions during a relief valve lift does not change system/equipment redundancy, diversity, or independence.

50.59 REVIEW COVERSHEET FORM LS-AA-l04-100l Revision 3 Page 3 of 5 StationIUnit(s): Byron and Braidwood Units 1 & 2 Activity/Document Number: EC 377550 (Byron). EC 384898 (Braidwood), DRP 15-040 Revision Number: Q1Q

Title:

CONFIGURATION CHANGE DOCUMENTS ASSOCIATED WITH RH RELIEF VALVE DISCHARGE TO THE RECYCLE HOLD UP TANK (HUT) Failure of the main control room ventilation system to automatically realign to the emergency mode of operation is evaluated in UFSAR Section 7.3.1.1.9.1 and UFSAR Section 9.4.1. In the event one train fails to automatically realign to the emergency mode of operation the redundant equipment, instrumentation, and controls would automatically realign the redundant train. During a postulated Boron Recycle Holdup Tank rupture event, operator action is conservatively assumed to be taken within 30 minutes to manually realign the Main Control Room (MCR) ventilation system to the emergency mode of operation. This action would be required if both trains of the MCR ventilation system do not automatically realign upon detection of high radiation. As described in Technical Specification Bases 3.3.7: The radiological dose assessments performed for the applicable Design Bases Accidents (DBAs) assume initiation of the VC Filtration System within 30 minutes. Thus the action to manually realign the MCR ventilation system to the emergency mode of operation within 30 minutes is consistent with existing radiological dose assessments and does not increase the likelihood of occurrence of a malfunction of an SSC important to safety. This action is already included in the stations operator response time program procedures, OP-BY-l02-106 and OP-l3R-l02-l06. During an event that results in a RHR suction relief valve lift, operator action is assumed to be taken within 30 minutes to stop RCS discharge to the HUT. Operating procedures B(w)OA PRI-1 and B(w)OA SID-2 would be used to diagnose and perform the action to stop the relief valve discharge. The operators are trained on these procedure actions. The subject action can be taken from the control room and based on input from Operations the action can be completed within the time required. ECs 377550 and 38489$ revise procedures OP-BY-102-106 and OP-BW-l02-l06 to add the required action to the operator response time program for Byron and Braidwood. Thus this operator action does not increase the likelihood of occurrence of a malfunction of an SSC important to safety. The proposed activity revises the dose analysis for an atmospheric release from a postulated failure of the Boron Recycle Holdup Tank (HUT) as described in Section 15.7.2 of the UFSAR. The failure of the Boron Recycle Holdup Tank is the only accident affected by this change. The revised analysis addresses the following:

• Minimum initial water volume (maximum gas space volume) in the HUT.
• Maximum initial water volume in the HUT.
• Interconnection of the HUT with one waste gas decay tank. As described in UFSAR Section 11.3.2.5, one waste gas decay tank is normally aligned to provide cover gas for the HUTs.
• RCS water from a postulated RH suction relief valve discharge.

There is only a minimal change in the consequences of postulated failure of the HUT from the current UFSAR analysis. The increase in consequences meets the NEt 96-07 Section 4.3.3 and LS-AA-l04-lOOl Section 6.2.3 definition to be no more than minimal based on; I) The increase is less than 10 percent of the difference between the current calculated dose value and the regulatory guideline value, and 2) the increase in dose does not exceed the current SRP guideline value for the particular design basis event. The proposed activity involves analysis associated with the RH system relief valves, the discharge piping from the valves to the recycle holdup tank, and the recycle holdup tanks. The proposed activity does not change how the RH system relief valves function or the failure modes. Thus the consequences of a RH system relief valve failure are unchanged. The proposed activity revises the dose analysis for an atmospheric release from a postulated failure of the HUT. The proposed activity results in less than a minimal increase in the consequences of a failure of the HUT or piping connected to the HUT. Thus the proposed activity does not result in more than a minimal increase in the consequences of a malfunction of a SSC important to safety previously in the UFSAR. As described in UFSAR Section 15.7.2.1 an unspecified event causes the complete release of the radioactive inventory of the boron recycle holdup tanks. UFSAR Section 15.7.2.1 states: Postulated events that could cause the release of the radioactive inventory of the spent resin storage tank and the boron recycle holdup tanks are cracks in the tanks and operator error. A failure of the HUT is expected to occur with the frequency of a limiting fault. The change does not introduce the possibility of a new accident because the revised analyses are not an initiator of any accident and no new failure modes are introduced. The most limiting failure mode of a recycle holdup tank rupture is already evaluated in the UFSAR.

50.59 REVIEW COVERSHEET FORM IS-AA-I04-Io0l Revision 3 Page 4 of 5 SbtionlUnit(s); Byron and Braidwood Units I & 2 Activity/Document Number: EC 377550 (Byron), EC 384898 (Braidwood), DRP 15-040 Revision Number: gj

Title:

CONFIGURATION CHANGE DOCUMENTS ASSOCIATED WITH RH RELIEF VALVE DISCHARGE TO THE RECYCLE HOLD UP TANK (HUT) As discussed in the UFSAR the rupture of the boron recycle tank would leave little recourse to the operator and no credit is taken for operator action or for ventilation system isolation in evaluating the event. The proposed activity does not credit any new equipment for mitigation of a boron recycle tank rupture event. Thus the change does not introduce a new failure result. Failure of the main control room ventilation system to automatically realign to the emergency mode of operation is evaluated in UFSAR Section 7.3.1.1.9.1 and UFSAR Section 9.4.1. In the event one train fails to automatically realign redundant equipment, instrumentation, and controls would automatically realign the redundant train. The revised calculated dose to the control room operators assumes both trains of the main control room ventilation system do not automatically realigned to the emergency mode of operation and that operator action is taken within 30 minutes to manually realign the Main Control Room (MCR) ventilation system to the emergency mode of operation. Thus the revised analysis assumption is mote conservative and bounded by the UFSAR described malfunction result. The proposed UFSAR change adds a description of failure effects for the postulated malfunction of the RHR suction or discharge relief valves to UFSAR Table 5.4-18. If any one of the normally closed relief valves fails open water will be will be discharged to the Recycle Holdup Tank. The inventory loss would be diagnosed by either by the decreasing level in the pressurizer and/or the increasing level in the recycle holdup tank. Failed relief valves RH87OSA, RH870$B, S18856A, and S18856B can be isolated by closing the isolation valves for one train of RH cooling. The result of this malfunction (loss of one train of RH cooling) is the same as other malfunctions of an SSC important to safety evaluated in UFSAR Table 5.4-18. A failed S18842 relief valve can be isolated by closing valves RH87 I 6A/B. Isolation of valves RH87 1 6AIB would not adversely impact the system function to cool down from 350° F to cold shutdown. The proposed changes to the design basis analysis associated with the Boron Recycle Holdup Tanks and revised atmospheric diffusion factors does not result in a design basis limit for a fission product barrier described in the UFSAR being exceeded or altered. The changes affect the operation of the Boron Recycle System. The proposed changes do not affect the design basis limits associated with the fuel cladding, RCS boundary, or containment. The proposed changes to the design basis analysis associated with the Boron Recycle Holdup Tanks and revised atmospheric diffusion factors involves new and revised methods of evaluation. The method used for the revised dose analysis was previously approved by the NRC for radiological analyses at Byron and Braidwood. Thus the change in dose analysis method does not result in a departure from a method of evaluation described in the UFSAR used in the establishing the design bases or in the safety analysis. The change in method for calculating atmospheric diffusion factors was previously accepted by the NRC through issuance of a SER, thus the change does not result in a departure from a method of evaluation described in the UFSAR used in the establishing the design bases or in the safety analysis. The method of evaluation used in analyses of the boron recycle holdup tank pressurization is not specified in the UFSAR. Based on the 50.59 review the proposed activity may be implemented without obtaining a License Amendment.

50.59 REVIEW COVERSHEET FORM LS-AA-104-l00I Revision 3 Page 5 of 5 StationfUnit(s): Byron and Braidwood Units I & 2 ActivityfDocument Number: EC 377550 (Byron). EC 384$98 (Braidwood). DRP 15-040 Revision Number: QIQLO

Title:

CONFIGURATION CHANGE DOCUMENTS ASSOCIATED WITH RH RELIEF VALVE DISCHARGE TO THE RECYCLE HOLD UP TANK (HUT) Attachments: Attach alt 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) E Applicability Review 50.59 Screening 50.59 Screening No. Rev. 50.59 Evaluation 50.59 Evaluation No. 6G-12-013 Rev. 0 BRW-E-2013-155 0

50.59 REVIEW COVERSHEET FORM LS-AA-104-100I Revision 3 Page 1 of4 Station/Unit(s): Byron Units I and 2 Activity/Document Number: EC 388896 / EC 388443 / DRP 14-084 Revision Number: 0 / 0 / 0

Title:

Install FIELB Dampers and Install High Temperature Thermal Links on fire Dampers for Div. 11/12 EDG Room and Install FIELB Dampers and High Temperature Thermal Links for Div. 2 1/22 EDG Room Fire Dampers NOTE. for 50.59 Evaluations, information on thisform will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d) (2). Description of Activity: (Provide a brief concise description ofwhat the proposed activity involves.) The proposed activity consists of two engineering changes, one for Unit I and one for Unit 2: EC 388896 Install HELB Dampers and Install High Temperature Thermal Links on Fire Dampers for Div. 11/12 EDG Room

• EC 388443 Install HELB Dampers and High Temperature Thermal Links for Div. 2 1/22 EDO Room Fire Dampers The proposed activity consists of the installation of new Diesel Generator Room Ventilation System (VD) high energy line break (HELB) damper assemblies. These assemblies consist of new backdraft / reverse flow damper sections and fire dampers which replace existing fire dampers l(2)VDI7YA, 1(2)VDI7YB, l(2)VD24YA, and l(2)VD24YB. The HELB damper assemblies are to be installed, as part of a turbine building J-IELB mitigation strategy, in ventilation openings that supply air to the diesel generator rooms.

These engineering changes will result in the following:

• Installation of new backdtaft / reverse flow damper sections, in the openings connecting the diesel generator room ventilation systems with the turbine building, which will close on a turbine building FWLB in order to prevent the effects of the HELB from impacting the room environment.
• Replacement of the fire dampers and associated electra-thermal links (ETLs) in the openings connecting the diesel generator room ventilation systems with the turbine building.

The activity along with EC 388894 and EC 388479, which install a time-delayed automatic restart feature for the VD supply fans is being undertaken to address a vulnerability identified during a review of the effects of certain high energy line breaks in the turbine building which could affect redundant trains of safety-related equipment. EC 388896 and EC 388443 modify the configuration of the following VD system fire dampers:

• I (2)VD I 7YA DG Room 1(2)3 fire damper
• l(2)VDI7YB DG Room 1(2)8 fire damper
• I (2)VD24YA DG Room I (2)A fire damper
• 1(2)VD24YB DG Room l(2)A fire damper The existing fire dampers, which are installed in the opening between the VD-served room and the turbine buitding, allow for the flow of air between the diesel generator rooms and the turbine building. These fire dampers will be removed, and a new assembly consisting of a new fire damper and two backdraft / reverse flow damper sections will be installed in each opening to provide faster closure in response to a turbine building HELB. The new HBLB backdraft / reverse flow damper sections are open when the VD supply or exhaust fans are in operation but will close upon detection of HELB flow from the turbine building into the room. After the HELB pressure dissipates in the turbine building, the HELB dampers will reopen. In this way, the HELB backdtaft / reverse flow dampers will perform the immediate high energy line break mitigation function for which the affected fire dampers were previously credited and will support the restoration of room ventilation following the turbine building I-IELB.

Consistent with the existing fire dampers, the replacement fire dampers are designed to remain normally open but to close on a high temperature caused by a fire or fire detection signal for the room fire protection system, in order to interrupt the flow of air and to restrict the passage of flame. The closure of the fire dampers will also help contain the carbon dioxide (C02) released as part of the fire protection system response to a fire within the diesel generator rooms.

50.59 REVIEW COVERSHEET FORM LS-AA-104-100l Revision 3 ( Station/Unit(s): Byron Units 1 and 2 Page 2 of 4 Activity/Document Number: EC 388896 / EC 388443 / DRP 14-084 Revision Number: 0/0 / 0

Title:

Install FIELD Dampers and Install High Temperature Thermal Links on Fire Dampers for Div. 11/12 EDG Room and Install FIELD Dampers and High Temperature Thermal Links for Div. 21/22 EDG Room Fire Dampers The existing ETLs for the affected rooms are designed to melt upon exposure to temperatures of 165°F or greater. The replacement ETLs are designed to melt at temperatures of 281°F or greater. (Like the existing ETLs, the replacement ETLs will also be actuated by the fire detection system.) The temperature rating of the replacement links is high enough that the fire dampers will remain open in the event of a nearby high energy line break. However, the dampers will close after the links reach the rated temperature in the event of afire. In this way, the fire damper can continue to perform its fire protection function, but its closure will no longer be credited with any high energy line break mitigation function. Because the new damper assemblies will extend a few inches into the turbine building, deflectors will be installed (under a separate activity, EC 390800) to protect the new HELD dampers from damage due to any overhead objects in the turbine building which might come loose during a seismic event. Reason for Activity: (Discuss why the proposed activity is being performed) The proposed activity provides an improved method for protecting electrical equipment in areas serviced by the VD system from the effects of a nearby high energy line break in the turbine building. The current strategy for mitigating the effects of such breaks, as described in the UFSAR, credits closure of the affected fire dampers as the result of the thermal link temperature exceeding its setting due to the high temperatures in the vicinity of the piping failure. The fire damper closure results in tripping of the ventilation system fans on high differential pressure once the damper closes and blocks the normal ventilation path between the affected room and the turbine building. Room ventilation is restored at a later time via operator action. Analyses were performed to demonstrate that the room heat up during the period that ventilation is lost would not cause required electrical equipment to become unavailable. However, a recent review of the effects of a turbine building high energy line break determined that the closure of the affected fire dampers might not occur in the time frame assumed in the analyses. In order to address this vulnerability, the proposed activity will reconfigure the dampers to allow for restoration of the VD system shortly after a high energy line break in the turbine building. The installation of the FEELS dampers will provide for quick isolation of the turbine building ventilation path following a turbine building HELB event. These new HELD dampers will provide protection to the affected rooms from a turbine building HELD steam release and will also allow for restoration of the ventilation system in the affected room after the turbine building HELB event is over. The prompt restoration of the affected room ventilation systems will allow for maintaining the affected rooms as a mild environment following a turbine building I-EELB to ensure that electrical equipment in the affected rooms will remain available. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) As described above, the current strategy for coping with a nearby high energy line break in the turbine building relies on closure of the fire damper, which results in trip of the fan on high differential pressure, and manual restoration of room ventilation by the operator at a tater time. The new FEELS dampers will remain open during normal operation when either the VD supply or VD exhaust fans are running. The new HELB dampers are fast acting and will close quickly upon detection of FEELB reverse flow from the turbine building to minimize the affected room exposure to a turbine building FIELD. After the HELD pressure dissipates in the turbine building, the FEELS dampers will reopen. The fire dampers will remain open unless the thermal links are actuated by the high temperatures characteristic ofa fire. The higher temperature setpoint (increased from the original 165°F to 28 1°F) on the fire damper ETLs will help to reduce the possibility of closure of the fire dampers in the event ofa turbine building 1-EELS, allowing for prompt restoration of the ventilation systems following the FIELD event. Thus the new dampers will not require new operator actions. The HELD dampers will allow for restoration ofan affected VD system following a high energy line break in the turbine building and eliminate the need for a manual restoration of room ventilation by an operator.

50.59 REVIEW COVERSHEET FORM LS-AA-104-100l Revision 3 Page 3 of 4 Station/Unit(s): Byron Units I and 2 Activity/Document Number: EC 328896/ EC 388443 / DRP 14-084 Revision Number: 0/0 / 0

Title:

Install HELB Dampers and Install High Temperature Thermal Links on Fire Dampers for Div. 11/12 EDO Room and Install FELB Dampers and High Temperature Thermal Links for Div. 2 1/22 EDG Room Fire Dampers Like the existing VD equipment, a malfunction of the new equipment would not affect the availability of the redundant VD train. This is consistent with the system design bases safety analyses requirements. Summary of Conclusion for the Activitys 50.59 Review: (Provide just fi cationfor the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required) Following installation of the new damper assemblies, the diesel generator room and day tank room ventilation (VD) system will continue to be capable of performing its UfSAR-described design functions of: (1) continuous ventilation for the day tank room during normal plant operation, (2) ventilation for the diesel generator when it operates, and (3) a source of combustion air for the diesel generator. The system will continue to maintain the room temperatures in accordance with equipment requirements. The failure of a damper to open when required would lead to the same failure effects as the failure of an existing fire damper to open: loss of one train of the VD system. The loss of one train does not affect the safe shutdown capability of the station since independent ventilation systems are provided for each redundant division. New HEL3 dampers will be available to perform the immediate high energy line break mitigation function for which the affected fire dampers were previously credited. The fire dampers will no longer be needed for rapid isolation of the affected areas from the adverse environmental effects of a turbine building high energy line break, but will remain open to permit air flow through the room both during normal ventilation system operation and following a nearby high energy line break, allowing the ventilation system to continue to perform its ventilation and cooling functions. A 50.59 evaluation was performed (60-12-014) to address two potential adverse effects of the proposed activity:

• The replacement of the current manual method of restoring room ventilation following its isolation in the event ala nearby high energy line break in the turbine building with an automatic method involving re-opening of the FIELB dampers
• The potential adverse effect on the reliability of the VD system caused by the addition of the new backdraft/ reverse flow damper sections, where the failure of either could result in a loss of one VD train Based on the quality classification and testing of the new components, and because the proposed activity reduces the likelihood of a malfunction of the electrical equipment in the VD areas, the evaluation concluded that the potential adverse effects did not cause more than a minimal increase in the likelihood of a malfunction olan SSC important to safety previously evaluated in the UFSAR.

The replacement damper assemblies do not involve a change to a procedure that adversely affects how UFSAR-described SSC design functions are performed or controlled. However, the change from manual to automatic restoration (unassisted opening of HELB dampers) of room ventilation following its isolation in response to a turbine building high energy line break was addressed in 50.59 Evaluation 6G-12-014. As discussed in the previous paragraph, the evaluation concluded that this change did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR. The analyses performed as part of the replacement damper assemblies do not involve UfSAR-described methodologies or alternate methodologies used in establishing the design bases or in the safety analyses. The VD system and associated components will not be utilized or controlled in a manner that is outside the reference bounds for their design or that is inconsistent with analyses or descriptions in the UFSAR. Since the VD system is not addressed in the Technical Specification or Operating License, and since implementation of the new design feature does not alter existing functions such addition to the Technical Specifications is required, no change to these documents is required. In conclusion, the proposed activity does not require prior approval by the NRC, and the activity can be implemented per the governing procedure.

50.59 REVIEW COVERSHEET FORM LS-AA-104-1001 Revision 3 Page 4 of 4 Station/Unit(s): Byron Units 1 and 2 Activity/Document Number: EC 388896 / EC 38Z443 / DRP 14-084 Revision Number: 0 / 0 /0

Title:

Install HELB Dampers and Install High Temperature Thermal Links on Fire Dampers for Div. 11/12 EDG Room and Install HELB Dampers and High Temperature Thermal Links for Div. 2 1/22 EDG Room F ire Dampers Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) Applicability Review 50.59 Screening 50.59 Screening No. 6E-12-215 Rev. 0 50.59 Evaluation 50.59 Evaluation No. 6G-12-014 Rev. 0

50.59 REVIEW COVERSHEET FORM LS-AA-104-100l Revision 3 Page 1 of4 Station/Unit(s): Byron Units 1 and 2 Activity/Document Number: EC 388895 / EC 388442 / DRP 14-084 Revision Number: 0 / 0 / 0

Title:

Install HELB Dampers and Install High Temp. Thermal Links on Fire Dampers for Div. 11/12 ESF Switchgear Rooms and Div. 12 Cable Spreading Rm. Install HELB Damper on Non-ESF Room and Install NELB Dampers and High Temperature Thermal Links for Div. 2 1/22 ESF Switchgear Rooms and Div. 22 Cable Spreading RM F ire Dampers. Install NELB Damper on Non-ESF Switchgear Room NOTE. for 50.59 Evaluations, information on thisform wilt provide the basisfor preparing the biennial summary report submitted to the NRC in accordance with the requirements of10 CfR 50. 59(d)(2). Description of Activity: (Provide a brief concise description of what the proposed activity involves.) The proposed activity consists of two engineering changes, one for Unit I and one for Unit 2:

• EC 388895 Install HELB Dampers and Install High Temp. Thermal Links on fire Dampers for Div. 11/12 ESF Switchgear Rooms and Div. 12 Cable Spreading Rm. Install HELB Damper on Non-ESf Room
• EC 388442 Install HELB Dampers and High Temperature Thermal Links for Div. 2 1/22 ESF Switchgear Rooms and Div. 22 Cable Spreading RM Fire Dampers. Install HELB Damper on Non-ESF Switchgear Room The proposed activity consists of the installation of new Switchgear Room Ventilation System fVX) high energy line break (HELB) damper assemblies. These assemblies consist of new backdraft / reverse flow dampers and fire dampers which replace existing fire dampers l(2)VXI3Y, 1(2)VXI7Y, 1(2)VX2OY, l(2)VX2IY and 1(2)VX28Y. The HELB damper assemblies are to be installed, as part of a turbine building HELB mitigation strategy, in ventilation openings that supply air to the ESF Switchgear

( Rooms, Div 12 (22) Cable Spreading Room, Electrical Pipe Tunnel Rooms, and Non-ESF Switchgear Rooms. These engineering changes will result in the following:

• Installation of new backdraft / reverse flow damper sections, in the openings connecting the switchgear and cable spreading room ventilation systems with the turbine building, which will close on a turbine building HELB in order to prevent the effects of the HELB from impacting the room environment.
• Replacement of the fire dampers and associated thermal links (electro-thermal link (ETL) or fusible link) in the openings connecting the switchgear and cable spreading room ventilation systems with the turbine building.

The activity along with EC 388478 and EC 388893, which install a time-delayed automatic restart feature for the VX fans is being undertaken to address a vulnerability identified during a review of the effects of certain high energy line breaks in the turbine building which could affect redundant trains of safety-related equipment. EC 388442 and EC 388895 modii the configuration of the folLowing VX system fire dampers:

• l(2)VXI3Y, Non-ESf Switchgear Room fire damper
• l(2)VXI7Y, Div 12(22) ESF Switchgear Room fire damper
• l(2)VX2OY, Div 11(21) ESF Switchgear Room fire damper
• 1(2)VX2IY, Electrical Pipe Tunnel fire damper
• l(2)VX28Y, Div 12 (22) Cable Spreading Room fire damper The existing fire dampers, which are installed in the openings between the VX-served room and the turbine building, allow air in the room to be exhausted to the turbine building. These fire dampers will be removed, and a new assembly consisting of a new fire damper and two backdrafl / reverse flow damper sections will be installed in each opening to provide faster closure in response to a turbine building HELB. The new HELB backdrafi / reverse flow damper sections are open when the associated VX fan is in operation and requires exhaust to the turbine building, but will close upon detection of reverse flow (air flow from turbine building into the room). In this way, they will perform the immediate high energy line break mitigation function for which the affected fire dampers were previously credited. Consistent with the existing fire dampers, the replacement fire dampers are designed to remain normally open but to close on a high temperature caused by a fire or fire detection signal for the room fire protection system, in order to interrupt the flow of air and to restrict the passage of flame. The closure of fire dampers

50.59 REVIEW COVERSREET FORM LS-AA-104-1001 Revision 3 ( Page2of4 Station/Unit(s): Byron Units I and 2 Activity/Documeiit Number: EC 388895 I EC 388442 / DRP 14-084 Revision Number: 0 / 0/0

Title:

Install HELB Dampers and Install High Temp. Thermal Links on Fire Dampers for Div. 11/12 ESF Switchgear Rooms and Div. 12 Cable Spreading Rn,. Install HELB Damper on Non-ESf Room and Install HELB Dampers and High Temperature Thermal Links for Div. 21/22 ESF Switchgear Rooms and Div. 22 Cable Spreading Rivi Fire Dampers. Install HELB Damper on Non-ESf Switchgear Room I (2)VX2 I Y and I (2)VX28Y will also help contain the carbon dioxide (C02) released as part of the fire protection system response to the fire within the Electrical Pipe Tunnel and Cable Spreading Rooms. The existing thermal links (ETLs and fusible links) for the affected rooms have a temperature rating of 165°F. The fusible links on fire dampers I(2)VXJ7Y and 1(2)VX2OY are replaced with fusible links designed to melt at 286°F, whereas the ETLs on fire dampers 1(2)VX2J Y and I (2)VX2$Y are replaced with new ETLs designed to actuate at 281°f. The fusible link on fire damper J(2)VXI3Y, however, will be replaced with a new fusible link designed to melt at the original 165°F. The temperature rating of the replacement links are high enough that the fire dampers will remain open in the event of a nearby high energy line break. However, the dampers will close after the links reaches the rated temperature in the event of a fire. In this way, the fire damper can continue to perform its fire protection function, but its closure will no longer be credited with any high energy line break mitigation function. Because the new damper assemblies will extend a few inches into the turbine building, deflectors will be installed (under a separate activity, EC 390800) to protect the new HELD dampers from damage due to any overhead objects in the turbine building which might come loose during a seismic event. Reason for Activity: (I)iscuss why the proposed activity is being performed.) The proposed activity provides an improved method for protecting electrical equipment in areas serviced by the VX system from the effects ofa nearby high energy line break in the turbine building. The current strategy for mitigating the effects of such breaks, as described in the UFSAR, credits closure of the affected fire dampers as the result of the thermal link temperature exceeding its setting due to the high temperatures in the vicinity of the piping failure. The fire damper closure results in tripping of the ventilation system fans on high differential pressure once the damper closes and blocks the normal ventilation path from the affected room to the turbine building. Room ventilation is restored at a later time via operator action. Analyses were performed to demonstrate that the room heat up during the period that ventilation is lost would not cause required electrical equipment to become unavailable. However, a recent review of the effects of a turbine building high energy line break determined that the closure of the affected fire dampers might not occur in the time frame assumed in the analyses. In order to address this vulnerability, the proposed activity will reconfigure the dampers to allow for restoration of the VX system shortly after a high energy line break in the turbine building. The installation of the HELD dampers will provide for quick isolation of the turbine building ventilation path following a turbine building HELB event. These new HELB dampers will provide protection to the affected rooms from a turbine building HELB steam release and will also allow for restoration of the ventilation system in the affected room after the turbine building HELD event is over. The prompt restoration of the affected room ventilation systems, will allow for maintaining the affected rooms as a mild environment following a turbine building HELD to ensure that electrical equipment in the affected rooms will remain available. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) As described above, the current strategy for coping with a nearby high energy line break in the turbine building relies on closure of the fire damper, which results in a trip of the fan on high differential pressure and manual restoration of room ventilation by the operator at a later time. Ifa fan high differential pressure condition occurs due to I-IELB damper closure following a turbine building high energy line break, the turbine building pressure will then decrease to the point where the fans can be restarted and re-open the HELD dampers and return the ventilation system to operation.

50.59 REVIEW COVERSHEET FORM LS-AA-104-100I Revision 3 ( Page3of4 Station/Unit(s): Byron Units I and 2 Activity/Document Number: IC 388895 / EC 388442 / DRP 14-084 Revision Number: 0 / 0/0

Title:

Install HELB Dampers and Install High Temp. Thermal Links on Fire Dampers for Div. 11/121Sf $witchgear Rooms and Div. 12 Cable Spreading Rm. Install HELB Damper on Non-ESf Room and Install HELB Dampers and High Temperature Thermal Links for Div. 2 1/22 1Sf Switchgear Rooms and Div. 22 Cable Spreading RM Fire Dampers. Install HELB Damper on Non-ESF Switchgear Room The new HELB dampers will remain open when the VX system supply fan is exhausting to the turbine building. The new HELB dampers are fast acting and will close quickly upon detection of reverse flow from the turbine building to minimize the affected room exposure to a turbine building HELS. The fire dampers will remain open unless the thermal links are actuated by the high temperatures characteristic of afire. The higher temperature setpoint (increased from the original 165 °F) fusible links on fire dampers I (2)VXI 7Y and I (2)VX2OY (replaced with fusible links designed to melt at 286°f) and ETLs on fire dampers 1(2)VX2IY and I(2)VX28Y (replaced with new ETLs designed to melt at 281°F) will help to reduce the possibility of closure of the fire dampers in the event ofa turbine building HELB, allowing for prompt restoration of the ventilation systems following the HELB event. Thus the new dampers will not require new operator actions. The HELB dampers will allow for restoration of an affected VX system following a high energy line break in the turbine building and eliminate the need for a manual restoration of room ventilation by an operator. Like the existing VX equipment, a malfunction of the new equipment would not affect the availability of the redundant VX train. This is consistent with the system design bases safety analyses requirements. Summary of Conclusion for the Activitys 50.59 Review: (Providejustficationfor the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50,59 Evaluation, or a License Amendment Request, as applicable, is not required.) Following installation of the new damper assemblies, the engineered safety features switchgear ventilation (VX) system will continue to be capable of performing its UFSAR-described design function of removing equipment heat to maintain the room temperatures in accordance with equipment requirements under normal, abnormal, and accident conditions, as described in the UFSAR. The failure of a damper to open when required would lead to the same failure effects as the failure of an existing fire damper to open: loss of one train of the VX ventilation system. The loss of one train does not affect the safe shutdown capability of the station since independent switchgear ventilation systems are provided for each redundant division of switchgear. New HELB dampers will be available to perform the immediate high energy line break mitigation function for which the affected fire dampers were previously credited. The fire dampers will no longer be needed for rapid isolation of the affected areas from the adverse environmental effects of a turbine building high energy line break, but will remain open to permit air flow through the room both during normal ventilation system operation and following a nearby high energy line break, allowing the ventilation system to continue to perform its function of removing equipment heat to maintain the room temperatures in accordance with equipment requirements. A 50.59 Evaluation was performed (6G-12-015) to address two potential adverse effects of the proposed activity:

• The replacement of the current manual method of restoring room ventilation following its isolation in the event of a nearby high energy line break in the turbine building with an automatic method involving re-opening of the HELB dampers when the fans are restarted
• The potential adverse effect on the reliability of the VX system caused by the addition of the new backdraft/ reverse flow damper sections, where the failure of either could result in a loss of one VX train Based on the quality classification and testing of the new components, and because the proposed activity reduces the likelihood of a malfunction of the electrical equipment in the VX areas, the evaluation concluded that these potential adverse effects did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR.

The replacement damper assemblies do not involve a change to a procedure that adversely affects how UFSAR-described SSC design functions are performed or controlled, However, the change from manual to automatic restoration (unassisted opening of HELB dampers) of room ventilation following its isolation in response to a turbine building high energy line break was addressed in 50.59 Evaluation 6G-12-015. As discussed in the previous paragraph, the evaluation concluded that this change did not cause

50.59 REVIEW COVERSHEET FORM LS-AA-104-1001 Revision 3 ( Page4of4 Station/Unit(s): Byron Units I and 2 Activity/Document Number: EC 388895 / EC 388442 / DRP 14-084 Revision Number: 0 / 0/0

Title:

Install HELB Dampers and Install High Temp. Thermal Links pn Fire Dampers for Div. 11/12 ESF Switchgear Rooms and Div. 12 Cable Spreading Rm. Install HELB Damper on Non-ESf Room and Install HELB Dampers and High Temperature Thermal Links for Div. 21/22 ESF Switchgear Rooms and Div. 22 Cable Spreading RM F ire Dampers. Install HELB Damper on Non-ESf Switchgear Room more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR. The analyses performed in support of the replacement damper assemblies do not involve UFSAR-described methodologies or alternate methodologies used in establishing the design bases or in the safety analyses. The VX system and associated components will not be utilized or controlled in a manner that is outside the reference bounds for their design or that is inconsistent with analyses or descriptions in the UFSAR. Since the VX system is not addressed in the Technical Specification or Operating License, no change to these documents is required. In conclusion, the proposed activity does not require prior approval by the NRC, and the activity can be implemented per the governing procedure. Attachments: Attach all 50.59 Reviewforms completed, as appropriate. Forms Attached: (Check all that apply.) D Applicability Review 50.59 Screening 50.59 Screening No. 6E-12-216 Rev. 50.59 Evaluation 50.59 Evaluation No. 6G-12-015 Rev. 0

50.59 REVIEW COVERSHEET FORM LS-AA-104-I00l Revision 3 StationiUnit(s): Byron Unit 1 and 2 Page 1 of4 ActivityIDocument Number: EC 389144 / EC 387362 / DRP 14-084 Revision Number: 0/0 /0

Title:

Install HELD Dampers for the Div 11/12 tvIEER Rooms to Support E-WLB Project and Install FIELD Dampe MEER Room Div 21/22 to Support FIELD Project rs for NOTE. For 50.59 Evaluations, information on thisform wilt provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d) (2). Description of Activity: (ProvEde a brief concise description of what the proposed activity involves.) The proposed activity consists of two engineering changes, one for Unit I and one for Unit 2:

• EC 389144Install HELD Dampers for Div 11/12 MEER Rooms to Support HELB Project
• EC 387362 [nstall FIEL3 Dampers for MEER Room Div 21/22 to Support HELD Project The proposed activity consists of the installation of new Miscel laneous Electrical Equipment Room (MEER) Ventilation (VE) high energy line break (FIELD) damper assemblies. These System assemblies consist of new backdraft / reverse flow dampe fire dampers which replace existing fire dampers 1(2)VEO5Y rs and and 1(2)VEO7Y. The FIELB damper assemblies are to be in ventilation openings in the Div 11/12(21/22) Miscellaneou installed s Electrical Equipment Rooms in support of a High Energy Break (HELD) Mitigation Strategy. Line This engineering change will result in the following:
• Installation of new backdraft/ reverse flow damper Sectio ns, in the openings connecting the MEER ventilation system with the turbine building, which will close on a turbine buildin s g I-IELB in order to prevent the effects of the HELB from impacting the room environment
• Replacement of the fire dampers and associated thermal links (fusible link) in the openings connecting the MEER ventilation systems with the turbine building The activity along with EC 388477 and EC 388892, which install a time-delayed automatic restart feature for the VE being undertaken to address a vulnerabitity identified during review fans is a of the effects of certain high energy line breaks in the turbine building which could affect redundant trains of safety-related equipment.

EC 389144 and EC 387362 modi& the configuration of the follow ing VE system fire dampers:

• 1(2) VEO5Y Div 12 (22) MEER fire damper
• 1(2) VEO7Y Div 11(21) MEER fire damper The existing fire dampers, which are installed in the openings betwee n the VE-served room and the turbine building, allow the room to be exhausted to the turbine building. These fire dampe air in rs will be removed, and a new assembly consisting of fire damper and two backdraft / reverse flow damper sections will a new be installed in each opening to provide faster closure in response to a turbine building FIELD. The new HELD backdr aft / reverse flow damper sections are open when the associa exhaust fan is in operation and requires exhaust to the turbine ted VE building, but will close upon detection of reverse flow (air flow from turbine building to the room). In this way they will perform the immediate high energy line break mitigation function which the affected fire dampers were previously credited. Consis for tent with the existing fire dampers, the replacement fire dampe are designed to remain normally open but to close on a high temper rs ature caused by a fire or fire detection signal for the room fire protection system, in order to interrupt the flow of air and to restrict the passage of flame.

The existing thermal links (fusible links) for the affected rooms have a temperature rating of 165°F. The fusible links on fire dampers 1(2)VEO5Y and I(2)VEO7Y maintain the same setpoin t temperature. The temperature rating of the fusible links enough that the fire dampers will remain open in the event is high of a nearby high energy line break. However, the dampers after the links reaches the rated temperature in the event of will close a fire. In this way, the fire damper can continue to perform protection function, but its closure will no longer be credite its fire d with any high energy line break mitigation function.

50.59 REVIEW COVERSHEET FORM LS-AA-104-tOOI Revision 3 Station/Unit(s): Byron Unit I and 2 Page 2 of 4 Activitylflocument Number: EC 389144/ EC 387362 / DRP 14-084 Revision Number: 0 / 0/0

Title:

Install HELB Dampers for the Div 11/12 MEER Rooms to Support HELB Project and Install I-IELB Dampers for MEER Room Div 2 1/22 to Support fELB Project Because the new damper assemblies will extend a few inches into the turbine building, deflectors will be installed (under a separate activity, EC 390800) to protect the new HELB dampe rs from damage due to any overhead objects in the turbine buildin which might come loose during a seismic event. g Reason for Activity: (Discuss why the proposed activity is being performed.) The proposed activity provides an improved method for protecting electrical equipment in areas serviced by the VE system from the effects of a nearby high energy line break in the turbine buildin g. The current strategy for mitigating the effects of such breaks, as describ ed in the UFSAR, credits closure of the affected fire dampers as the result of the thermal link temperature exceeding its setting due to the high temperatures in the vicinity of the piping failure. The fire damper closure results in tripping of the ventilation system fans on high differential pressure once the damper closes and blocks the normal ventilation path from the affecte d room to the turbine building. Room ventilation is restored at a later time via operator action. Analyses were performed to demon strate that the room heat up during the period that ventilation is lost would not cause required electrical equipment to become unavailable. However, a recent review bf the effects of a turbine building high energy line break determined that the closure of the affected fire dampers might not occur in the time frame assumed in the analys es. In order to address this vulnerability, the proposed activity will reconfigure the dampers to allow for restoration of the VE system shortly after a high energy line break in the turbine building. The installation of the HELB dampers will provide for quick isolation of the turbine building ventilation path following a turbine building HELB event. These new I-IELB dampers will provid e protection to the affected rooms from a turbine building HELB steam release and will also allow for restoration of the ventila tion system in the affected room after the turbine building HELB event is over. The prompt restoration of the affected room ventila tion systems will allow for maintaining the affected rooms as a mild environment following a turbine building 1-IELB to ensure that electrical equipment in the affected rooms will remain available. Effect of Activity: (Discuss how the aclivily impacts plant operations, design bases, or safety analyses described in the UPSAR.) As described above, the current strategy for coping with a nearby high energy line break in the turbine building relies on closure of the fire damper, which results in a trip of the fan on high differe ntial pressure and manual restoration of room ventilation by the operator at a later time. If a fan high differential pressure condition occurs due to HELB dampe r closure following a turbine building high energy line break, the turbine building pressure will then decrease to the point where the fans can be restarted and re-open the HELB dampe and return the ventilation system to operation. rs The new F[ELB dampers will remain open when the VE system exhaust fan is exhausting to the turbine building. The new HELB dampers are fast acting and will close quickly upon detection of reverse flow from the turbine building to minimize the affected room exposure to a turbine building HELB. The fire dampers will remain open unless the thermal links are actuated by the high temperatures characteristic of a fire. The temperature setpoint (165

                                                                         °f) of the fusible links on fire dampers l(2)VEO5Y and 1(2)VEO7Y has been evaluated to ensure this setpoint is adequate to reduce the possibility of closure of the fire dampers in the event of a turbine building HELB, allowing for prompt restoration of the ventilation systems following the E-IELB event. Thus the new dampers will not requite new operator actions. The HELB dampers will allow for restoration of an affected VE system following a high energy line break in the turbine building and elimin ate the need for a manual restoration of room ventilation by an operator.

Like the existing VE equipment, a malfunction of the new equipment would not affect the availability of the redundant VE train. This is consistent with the system design bases and safety analyses requirements.

50.59 REVIEW COVERSHEET FORM LS-AA-104-l001 Revision 3 Station/Unit(s): Byron Unit I and 2 Page 3 of 4 Activity/Document Number: EC 389144/ IC 387362 / DRP 14-084 Revision Number: 0 / 0/0

Title:

Install HELB Dampers for the Div 11/12 MEER Rooms to Support HELB Project and Install fIELB Dampers for MEER Room Div 2 1/22 to Support HELB Project Summary of Conclusion for the Activitys 50.59 Review: (Providejust/Icationfor the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) following installation of the new damper assemblies, the miscel laneous electric equipment room ventilation (yE) system will continue to be capable of performing its UfSAR-described design functions of: maintaining the room temperatures in accordance with equipment requirements, maintaining the room at atmosp heric pressure when the supply fans are in full outside air mode, and maintaining ventilation of the battery area to limit the accum ulation of hydrogen, as described in the UFSAR. The failure a damper to open when required would lead to the same failure of effects as the failure of an existing fire damper to open: loss one train of the VE system. The loss of one train does not affect of the safe shutdown capability of the station since independent ventilation systems are provided for each redundant division. New HELB dampers will be available to perform the immediate high energy tine break mitigation function for which the affecte fire dampers were previously credited. The fire dampers will d no longer be needed for rapid isolation of the affected areas from adverse environmental effects of a turbine building high energy the tine break, but will remain open to permit air flow through the rooms both during normal ventilation system operation and follow ing a nearby high energy line break, allowing the ventilation system to continue to perform its ventilation and cooling functio ns. A 50.59 Evaluation was performed (6G-l2-016) to address two potential adverse effects of the proposed activity:

• The replacement of the current manual method of restori ng room ventilation following its isolation in the event of a nearby high energy line break in the turbine building with an automatic method involving re-opening of the E-IELB dampers when the fans are restarted
• The potential adverse effect on the reliability of the VE system caused by the addition of the new backdraft/ reverse flow damper sections, where the failure of either could result in a toss of one VI train Based on the quality classification and testing of the new compo nents, and because the proposed activity reduces the likelihood a malfunction of the electrical equipment in the VE areas, the evalua of tion concluded that these potential adverse effects did not cause more than a minimal increase in the likelihood of a malfun ction of an SSC important to safety previously evaluated in the UFSAR.

The replacement damper assemblies do not involve a change to a procedure that adversely affects how UFSAR-described SSC design functions are performed or controlled. However, the change from manual to automatic restoration (unassisted opening of HELB dampers) of room ventilation following its isolation in response to a turbine building high energy line break was addres in 50.59 Evaluation 6G-t2-0t6. As discussed in the previous sed paragraph, the evaluation concluded that this change did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR. The analyses performed in support of the replacement damper assemb lies do not involve UFSAR-descnbed methodologies or alternate methodologies used in establishing the design bases or in the safety analyses. The VE system and associated components will not be utilized or controlled in a manner that is outside the reference bounds for their design or that is inconsistent with analyses or descriptions in the UFSAR. Since the VE system is not addressed in the Technical Specification or Operating License, no change to these documents is required. In conclusion, the proposed activity does not requite prior approv al by the NRC, and the activity can be implemented per the governing procedure.

50.59 REVIEW COVERSHEET FORM LS-AA-104-lO0l Revision 3 Station/Unit(s): Byron Unit I and 2 Page 4 of 4 Activity/Document Number: EC 389144 / EC 387362 / DRP 14-084 Revision Number: 0/0/0

Title:

Install HELB Dampers for the Div 11/12 MEER Rooms to Support HELB Proiect and Install HELB Dampers for MEER Room Div 2 1/22 to Support 1-ffiLB Project Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) Applicability Review 50.59 Screening 50.59 Screening No. 6E-12-217 Rev. 0 50.59 Evaluation 50.59 Evaluation No. 6G-l2-016 Rev. 0

50.59 REVIEW COVERSHEET FORM LS-AA-l04-l0O1 Revision 3 Page 1 of3 StationlUnit(s): Byron Units I and 2 Activity/Document Number: EC 3$$477 I 388892 I DRP 14-084 Revision Number: I / 0 / 0

Title:

Install Time Delaved Auto-Restart For U-I (U-2) VE Fans tn Support of KELB Mitiaation Stratev 1VOTE: For 50.59 Evaluations, information on thisform will provide the basisfor preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d) (2). Description of Activity: (Provide a brief concise description ofwhat the proposed activity involves.) The proposed activity consists of two engineering changes, one for Unit I and one for Unit 2:

• EC 388477- Install Time Delayed Auto-Restart for U-I VE Fans In Support of HELB Mitigation Strategy
• EC 388892 Install Time Delayed Auto-Restart For U2 VE Fans In Support of HELB Mitigation Strategy The proposed activity consists of installation of a time delayed auto-restart for UI (U2) Miscellaneous Electric Equipment Room (MEER) VE fans (l(2)VEOIC/l(2)VEO4CII(2)VEOSC) in support of a high energy line break (HELB) mitigation strategy. These ECs will install new timers and circuit changes to automatically restart the VE fans, following short a time delay, after a high differential pressure trip. This feature will work with the new HELB damper installation under EC 387362 and EC 389144 to mitigate the consequences of a postulated turbine building HELB. The 50.59 assessment for the installation the of new HELB dampers was performed as part of the damper installation design changes (EC J87362 and EC 389144).

The final configuration considered in this screening includes the installation of the new timers and Circuit changes via the completion of these ECs along with the installation of the new KELB dampers. The proposed activity (along with EC 387362 and EC 389144) is being undertaken to address a vulnerability identified during a review of the effects of certain high energy line breaks in the turbine building which could affect redundant trains of safety-related equipment. EC 388477 and EC 388892 modify the control circuits for the following fans:

• l(2)VEOIC Division 12(22) MEER Supply Fan
• l(2)VEO4C Division 11(21) MEER Exhaust fan
• 1(2)VEOSC Division 12(22) MEER Exhaust Fan A new time delay relay will be installed to automatically restart the fan after a fan trip on high differential pressure occurs. The auto restart will occur approximately 60 seconds after the differential pressure trip. The time delay is intended to restart the fan after a brief time following momentary isolation of the exhaust path a condition that could occur following a nearby high energy line break in the turbine building, which may close the new HELB dampers added by EC 387362 and EC 389144. The new time delay relays will be installed in existing local panels (l(2)VEOIJ and l(2)VXOIJ).

Redundant FIELB dampers will be installed in series with tire dampers via EC 387362 and EC 389144. The new HELB dampers are designed to close upon reverse flow from the turbine building to the auxiliary building. Closure of the KELB dampers with the VE ventilation fans running will create back pressure to the operating fan which may cause It to trip on high differential pressure, disrupting supply airflow to the MEER In order to minimize the heat up of the MEER, the proposed activity fEC 388477 and EC 388892) will modify the control logic for fans l(2)VEOIC, 1(2)VEO4C, and l(2)VEO5C, such that the fans will auto-restart one time following a high differential pressure trip after a time delay of sufficient duration allow to the KELB pressure transient to dissipate and allow restart of the fans, thereby re-establishing ventilation through the new F{ELB dampers. The UFSAR will require updates to reflect the design of the differential pressure trip to allow one automatic fan restart attempt. This will require changes to Section 7.3.1.1.11 Essential Switchgear Rooms, Miscellaneous Electrical Equipment Rooms and Bauey Rooms Ventilation Systems Instrumentation and Controls, Section 9.4.5.3 Miscellaneous Electric Equipment Room Ventilation System and Table 9.4-14 Miscellaneous Electric Equipment Room Ventilation System Failure Analysis. These changes will be processed under DRP 14-084.

50.59 REVIEW COVERSHEET FORM LS-AA-t04-tOOt Revision 3 Station/Unit(s): Byron Units I and 2 Page 2 of 3 ActivityfDocument Number: IC 388477 I 388892 I DRP 14-084 Revision Number: I / 0/0

Title:

Install Time Delayed Auto-Restart for U-I C U-2) VI fans In Suppo rt of I-WLB Mitigation Strategy Reason for Activity: (Discuss why the proposed activity is being pe,fonned.) The proposed activity provides an improved method for mitigating HELB effects in areas serviced by the VI system from the effects of a nearby high energy line break in the turbine building. The current strategy for mitigating the effects of such breaks, as described the in UFSAR, credits closure of the affected fire dampers as the result of the thermal link temperature exceeding its setting due to the high temperatures in the vicinity of the piping failure. The lire damper closure results in tripping of the ventila tion system fans on high differential pressure once the damper closes and blocks the normal ventilation path from the affecte d room to the turbine building. Room ventilation is restored at a later time via operator action. Analyses were performed to demon strate that the room heat up during the period that ventilation is lost would not cause qualified electrical equipment to becom e unavailable. However, a recent review of the effects of a turbine building high energy line break determined that the closure of the affected fire dampers might not occur in the time frame assumed in the analyses. In order to address this vulnerability, the proposed activity will reconfigure the dampers and ventilation systems to provide for automatic restoration of the VI system shortly after a high energy line break in the turbine building. The prompt restoration of the system

                                                                                        , following a time delay of sufficient duration to allow the HELB pressure to dissipate, will allow for maintaining the M.EER as a mild environment following a Turbine Building HELB to help ensure that electrical equipment in the affected rooms will remain available.

Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety anatyses described in the UFSAR.) The new fan auto restart feature will not affect normal fan operation (startin g and stopping by the operator). In the event of a high differential pressure, the fan will trip, as it does at present. However, the auto restart feature will attempt to restart the fan after approximately 60 seconds. If the high differential pressure was due to reverse flow damper closure (IC 387362 and EC 389144) following a turbine building high energy line break, the turbine buildin g pressure should have decreased to the point where the restarted fan can re-open the reverse flow dampers and return the ventila tion system to operation. If the high differential pressure was due to a condition that does not clear within approximately 60 second s, the restarted fan will trip again on high differential pressure and will then be blocked from further restart attempts until an operator investigates and resets the trip. The automatic restoration of an affected VI system following a high energy line break in the turbine building will eliminate the need for a manual restoration of the system by an operator following the initial VE fan high differential pressure trip. Like the existing VE equipment, a malfunction of the new equipment would not affect the availability of the redundant VE train. This is consistent with the system design bases and safety analyses require ments. Summary of Conclusion for the Activitys 50.59 Review: (Provide jusr&Ication for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) The proposed activity involves the installation of a new fan auto restart feature on the miscellaneous electric equipment room ventilation (VI) system fans to help mitigate the consequences of a high energy line break in the turbine building. Following installation of this feature, the VI system will continue to be capable of performing its UFSAR-described design functions of: maintaining the room temperatures in accordance with equipment require ments, maintaining the room at atmospheric pressure when the supply fans are in full outside air mode, and maintaining ventila tion of the battery area to limit the accumulation of hydrogen, as described in the UFSAR. As at present, the failure of a ventilation system fan would lead to the loss of one train of the VE ventilation system. The loss of one train does not affect the safe shutdown capability of the station since independent ventilation systems are provided for each redundant division.

50.59 REVIEW COVERSHEET FORM LS-AA-l04-tOOl Revision 3 Page 3 of 3 StationlUnit(s): Byron Units I and 2 Activity/Document Number: EC 388477 / 388892 / DRP 14-084 Revision Number: I / 0 / 0

Title:

Install Time Delayed Auto-Restart For U-I (U-2) VE Fans In Supprt of HELB Mitigation Stratev New HELB dampers, installed under a separate activity, will be available to permit air flow through the room both during normal ventilation system operation and shortly after a nearby turbine building high energy line break, allowing the ventilation system to continue to perform its ventilation and cooling functions. A 50.59 Evaluation(6G-12-017) was performed to address two potential adverse effects of the proposed activity:

• The replacement of the current manual method of restoring room ventilation following its isolation in the event of a nearby high energy line break in the turbine building with an automatic method involving auto restart of the affected fans and the resultant re-opening of the HELB dampers
• The potential adverse effect on a VE fan by automatically restarting the fan after an existing equipment protection feature (fan high differential pressure trip) had stopped the fan Based on the quality classification and testing of the new components, and because the proposed activity reduces the likelihood of a malfunction of the electrical equipment in the VE areas, Evaluation 60-12-0 17 concluded that the potential adverse effects of the automatic system restoration following a I-{ELB and the automatic fan restart following a trip on high differential pressure did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important-to.safety previously evaluated in the UFSAR.

The new fan auto restart feature does not involve a change to a procedure that adversely affects how UFSAR-descnbed SSC design functions are performed or controlled. However the change from manual to automatic restoration of room ventilation following its isolation in response to a turbine building high energy line break was addressed in the evaluation. As discussed in the previous paragraph, the evaluation concluded that this change did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR. The analyses performed in support of the new tan auto restart feature and replacement damper assemblies do not involve UfSAR described methodologies or alternate methodologies used in establishing the design bases or in the safety analyses. The VE system and associated components will not be utilized or controlled in a manner that is outside the reference bounds for their design or that is inconsistent with analyses or descriptions in the UFSAR. Since the VE system is not addressed in the Technical Specification or Operating License, no change to these documents is required. In conclusion, the proposed activity does not require prior approval by the NRC, and the activity can be implemented per the governing procedure. Attachments:

,lttach all 50.59 Reviewforms completed, as appropriate.

Forms Attached: (Check all that apply.) U Applicability Review 50.59 Screening 50.59 Screening No. 6E-I2-218 Rev. 50.59 Evaluation 50.59 Evaluation No. 6G-12-0l7 Rev. 0

(PDF INSIDE) 50.59 REVIEW COVERSHEET FORM LS-AA- 104-tool Revision 3 Page 1 of 3 Station/Unit(s): Byron Unit 2 ActivityiDocument Number EC 39000$ Revision Number: __L Tide: STEAM GENEPATOR MARGIN TO OVERFILl. (SO MTO) P0KV TRIM REPLACEMEIIM1D VALVE BLOCK INSTALLATION NOTE: For 50.59 Evaluations, information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59fd)(2). Description of Activity: (Provide a brief, concise description of what the proposed activity involves.) The proposed activity wilt install a new valve internal trim in the Steam Generator (SG) Power Operated Relief Valve (PORV) valves (2M5018A-D) and a valve block which will limit the flow to the current design basis flows consistent with the Steam Generator Tube Rupture (SGTR) Margin to Overfill (MTO) and Dose Case analyses. This change will also increase the actuator setpoints which is required to support opening the valve with the increase trim size. Reason for Activity: (Discuss why the proposed activity is being performed.) IR 1359137 documented unexpected vendor flow testing results which demonstrated that the existing valve capacity is actually less than originally assumed in the accident analysis. As a result, the margin to overfill has been significantly reduced. To increase the margin to overfill, the station has elected to restore the capacity of the SG PORVs on Unit 2 to be consistent with the original design basis capacity. This change will install a new trim in the $0 PORVs which will increase the valve capacity at full open. This modification will also install a valve block to limit the stroke of the valve which will limit the valve capacity to be consistent with the flow rate utilized in the current design basis analysis. The maximum flow raw of the modified valves will not exceed the flow assumed in the SGTR Dose Case analysis. The sespoint change for the actuator is required to increase the actuator capability with the new trim installed. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) During normal operation the SO PORVs are closed. In the event the pressure increases, the valves automatically begin opening in response to a pressure controller to maintain $G pressures below the safety valve setpoints if possible. The modified SG PORVs will essentially perform the same. IR 1359137 documented unexpected vendor flow testing results which demonstrated that the existing valve capacity is actually less than originally credited in the accident analysis. Therefore, by installing the new trim and valve block the actual valve capacity will increase which will improve the cooldown capability of the SO PORVs. The stroke time to open and close will decrease with the reduced stroke with the valve block installed. The piping has been conservatively analyzed for the maximum flow through the valve assuming the valve block is removed. This condition is bounding for the configuration with the valve block installed. During a SG tube rupture event, operator actions require the operators isolate the ruptured $G by closing the feedwater, auxiliary feedwater and main steam isolation valves and the affected SG P0KV. The intact $G PORVs are then used to cool down the RCS below the saturation temperature of the ruptured steam generator. Once the cooldown is complete, the RCS is then depressunzed to equalize pressure with the ruptured steam generator and terminate the primary to secondary leakage. Given the capacity will be consistent with the current design basis, there is no adverse impact on the SGTR Dose Case and margins will improve for the MTO Case. The operator action times associated with the SGTR event are not changed.

50.59 REVIEW COVERSHEET FORM LS-AA-104.lOOl Revision 3 Page 2 of 3 Station/Unit(s): Byron Unit 2 Activitymocunwnt Number. EC 390008 Revision Number: ... Tide: STh& GENERATOR MARGIN TO OVERFILL CSG MUll P0KV TRIM REPLACEMENT AND VALVE BLOCK INSTALLATION Summary of Condusion for the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening. 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.)

1. The SG PORV (often described as a SO Relief Vaive) valve control system is not changed, so the likelihood of a failure of the control system which could cause an inadvertent opening of the SO relief valve remains the same. The installation of the block does not contribute to failing the valve open since it does not directly operate the valve. The valve block will limit the travel of the valve. The valve is a flow over the seat. Therefore, pressure helps maintain this valve in the closed position. This would tend to decrease the frequency of occurrence of a SO PORV valve failing open. Section 15.6.3 discusses the Steam Generator Tube Rupture Event. The SG PORVs are credited in this analysis but are not the accident initiator. Therefore, the installation of the new trim, actuator setpoint change, and valve block does not increase the frequency of occurrence of an accident previously evaluated in the UF$AR.

2. UFSAR Section 15.1.4 discusses the possible malfunction of the SO P0KV (SO Relief) to open inadvertently. As discussed above the likelihood of this malfunction has not increased. LWSAR Sections 15.6.3 and 15.3.3 discuss the possibility of the valve to fail to recluse once opened in response to a transient. The valve is a flow over the seat, therefore flow will tend to close the valve. The required force from the actuator to close the valve will be decreased due to the increase trim size and as a result, decrease the likelihood of the malfunction. Various sections in Chapter 15 discuss that the valve opens in response to transients. The modified valve will require increased thrust to open the valve due to the increase in the trim size. The valve operator has been evaluated by the manufacturer and is capable of operating the valve with sufficient margin with the hydraulic actuator selpoint change described above. Furthermore, flow testing has demonstrated that the modified valve is capable of opening under maximum differential pressure conditions. Therefore, the likelihood of a failure to open malfunction is not increased for the modified valve. In addition, the UFSAR sections often do not credit the SO PORV function but instead rely on the main steam safety valves to open to provide the heat removal function. Therefore, the installation of new trim, actuator setpoint change and valve block will not result in more than a minimal increase in the likelihood of occurrence of a malfunction of an SSC important to safety previously evaluated in the UFSAR.

3. Various accidents discuss the SO PORV as a potential release path that is evaluated as part of the dose calculations.

These accidents will not be affected since the new flow capacity of the valve is bounded by the flow assumed in the safety analyses. Also many of the accidents are not based on the flow rate from the valve but the primary to secondary allowable tube leakage which will not be affected by this modification. Failure of the valve block is not considered credible. This is because the device is passive, it is safety related, and the blocking device is a robust design and a similar design was tested with satisfactory results. furthermore, the stresses are conservatively calculated for the blocking device are in the same range as other critical pans of the valve and are less than their respective allowable stresses. Therefore, it is concluded that the installation of the new thin, actuator setpomt change and valve block does not result in more than a minimal increase in the consequences of an accident previously evaluated in the UFSAR.

4. The SG tube rupture accident and Reactor Coolant Pump Shaft Seizure dose analysis assumes a single SG PORV sucks open. ibis is still considered a credible failure mode. The consequences of this accident are not affected by the new trim and valve block installation since the maximum flow rate from the valve will not be affected and failure of the blocking device is not considered credible. The actions to mitigate this malfunction are unchanged as an operator will be dispatched to close the SG PORV upstream block valve. Therefore, it is concluded that the installation of the new trim, actuator setpoint change and valve block does not result in more than a minimal increase in the consequences of a malfunction of an SSC important to safety previously evaluated in the UFSAR.

5. The new valve trim and valve block do not affect accident initiation sequences or response scenarios as modeled in the safety analyses. No new operating configuration is being imposed by the proposed change. The actuator setpoint

50.59 REVIEW COVERSHEET FORM IS-AA-104-Wol Revision 3 Page 3 of 3 Station/Unit(s): Byron Unit 2 Activity/Document Number: ECZ390008 Revision Number: ,Q_

Title:

STEAM GENERATOR MARGIN TO OVERFILL (SO MTO) PORV TRIM REPLACEMENT AND VALVE BLOCK INSTALLATION change will allow the valve to continue to operate the valve similar to the existing operation but with increased capability and within the design limits of the actuator. Therefore, it is concluded that the installation of the new trim, actuator setpoint change and valve block does not create a possibility for an accident of a different type than any previously evaluated in the UFSAR

6. The current malfunctions evaluated are failure of the SG PORV to open and a failure of the SO PORV to close when required. The valve failing closed wilt have the same result The valve block will be set such that the valve capacity will be consistent with the current design basis flow rate. When the vaLve fails open, the result would be the same because the flow rate would not be affected. Failure of the valve block is not considered credible. This is because the device is passive, it is safety related, and the blocking device is a robust design and a similar design was tested with satisfactory results. Furthermore, the stresses are conservatively calculated for the blocking device are in the same range as other critical parts of the valve and are less than their respective allowable stresses. Therefore, the installation of the new trim, actuator setpoint change and valve block does not create a possibility for a malfunction of an SSC important to safety with a different result than any previously evaluated in UPSAR.

7. Installation of the new trim, actuator setpoint change and valve block installation does not affect the integrity of the fission product barriers utilized for mitigation of radiological dose consequences as a result of an accident. Plant response as modeled in the safety analyses is unaffected and no parameter which impacts a fission product barrier is changed. Hence, the mass and radioactivity releases used as input o the dose calculations are unchanged from those previously assumed. Therefore, it is concluded that the new trim, actuator setpoint change and valve block installation does not result in a design basis limit for a fission product barrier as described in the UFSAR being exceeded or altered.

S. The assumptions and methods used in the plant accident analyses are not affected by the new trim, actuator setpoint change and valve block installation. The current SG Tube Rupture accident analysis margin to overfill case assumes two SO PORVs are available for cooldown and depressurization of the RCS. This is not affected by this change. The dose case assumes one SG PORV fails open. This input is not changed nor is the evaluation methodology. The piping analysis performed for this design change uses the methodologies and criteria described in UFSAR Chapter 3.9. Therefore, it is concluded that the new trim, actuator setpoint change and valve block installation does not result in a departure from a method of evaluation described in the UF$AR used in establishing the design bases or in the safety analyses. Based on the above, the replacement of the SO PORV valve trim, actuator setpoint change and support modification does not result in an unreviewed safety question and maybe implemented without NRC approval. Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) C Applicability Review C 50.59 Screening 50.59 Screening No. Rev. 50.59 Evaluation 50.59 Evaluation No. 6G-12-018 Rev. 00

(PDF INSIDE) 50.59 REVIEW COVERSHEET FORM LS.AA-lC)4-ItX)l Revision 3 Page I ol2 Statio&Unitts): Byron Unit 2 Activity/Document Number: EC 3923Oi Revision Number: (toO

Title:

CVCS Relief Valve 2CV81 t9 Bonnet Vent Drain Line Description of Activity: (Provide a brief, concise description of what the proposed activity involves.) The proposed activity will install a combination of metallic flex line and hard piping from the chemical and volume control system (CVCS) letdown heat exchanger outlet header relief valve 2CV8 119 bonnet vent to a floor drain. This vent tine will include a locked open isolation valve to maintain an open vent and a sight glass for identification of leakage. Relief valve 2CVXI 19 provides overpressure protection for the piping and associated components between the letdown low pressure control valve, 2CVI3I, and the volume control lank (VCT). In the event that the letdown flow downstream of the letdown heat exchangers becomes obstructed or inadvertently isolated, relief valve 2CV8I 19 opens to relieve the overpressure by directing letdown flow to the VCT. Relief valve 2CV8 119 is equipped with a bellows which surtounds the valve spindle and which vents into the valve bonnet. An opening in the bonnet vents the bonnet to the atmosphere. The bellows forms part of the pressure boundary at the valve outlet and allows the relief valve to open at its set pressure despite a varying back pressure. In the case o 2CV8 119, the back pressure varies with the pressure in the VCT. Reason for Activity: (Discuss why the proposed activity is being performed.) The proposed activity is being undertaken to: (I) prevent radiological contamination of the area surrounding 2CV8 119 in the event of bellows leakage/failure and (2) facilitate maintenance on the relief valve in the event of bellows leakage/failure. This design change provides a path to a local floor drain in the auxiliary building floor drain (WF) system for contaminated bonnet vent leakage from a failed bellows. In the event of bellows leakage/failure, the tiuld on the discharge side of the relief valve can leak through the bellows and into the relief valve bonnet, which is open to the auxiliary building atmosphere. The relief valve 2CVS 119 has experienced bellows failure and subsequent relief valve repair. including bellows replacement as a result of high cycle, low-stress fatigue because the set pressure of the relief valve was repeatedly reached due to the clogging of reactor coolant filter 2CV03F. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR) The proposed activity will have minimal impact on plant operations. The new vent line isolation valve will be maintained in the locked-open position during operations. The new sight glass will be monitored in order to detect bellows leakage/failure. If a bellows leak develops, the leakage will be routed through the new vent line directly to an auxiliary building floor drain. This will minimize the spread of radioactive contamination. If it is necessary to replace the leaking bellows, the low pressure letdown line will be isolated and removed from service and the vent line isolation valve will be closed to facilitate maintenance activities on the relief valve. The locked-open bonnet vent line isolation valve will allow the bonnet to continue to be vented to the auxiliary building atmosphere. thereby allowing the relief valve to continue to perform its function of protecting the low pressure letdown line from overpressurization and consequent failure. Therefore, the proposed activity does not impact design bases or safety analyses including the safety analysis of a failure of a small line carrying primary coolant outside containment described in the UFSAR. Summary of Conclusion for the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion, Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) The proposed activity will install a combination of metallic flex line and hard piping from the chemical and volume control system (CVCS) letdown heat exchanger outlet header relief valve 2CV8 119 bonnet vent to a floor drain. This vent line will include a locked open isolation valve to maimain an open vent and a sight glass for identification of leakage.

50.59 REVIEW COVERSHEET FORM Ls-AA-w4-IOOt Revision 3 Page 2 of 2 Station/Unit(s): I3yron Unit 2 Actavity(Document Number EC_392306 Revision Number: OUG

Title:

CVCS Relief Valve 2CV81 19 Bonnet Vent Drain Line Relief valve 2CVS 119 provides overpressure protection fit the piping and associated components between the letdown low pressure control valve. 2CV13), and the volume control tank (VCfl. In the event that the letdown flow downstream of the letdown heat exchangers becomes obstructed or inadvertently isolated, relief valve 2CV81 19 opens to relieve the overpressure by directing letdown how to the VCT. Relief valve 2CVRJ 19 is equipped with a bellows. The bellows is vented to the bonnet and an opening in the bonnet vents the bonnet to the atmosphere. The bellows allows the relief valve to open at its set pressure despite a varying back pressure. In the case of 2CV8 119. the back pressure varies with the pressure in the VCT. Although the proposed activity includes the installation of a manual isolation valve in the previously unobstructed bonnet vem path, the use of an administratively controlled locked-open manual isolation valve in this application is consistent with code requirements as described in the UFSAR. However, the installation of a vent line with an administratively controlled locked-open manual isolation valve in the previously unobstructed bonnet vent path involves a change to a procedure that represents a fundamental change in the method of performing or controlling a UFSAR-described SSC design function. As such, this change was considered adverse and was the subject of 50.59 Evaluation 6G-13-O08. That evaluation determined that the design controls for the new vent line and the administrative controls on the new locked-open manuat isolation valve were sufficient to ensure the proposed activity did not cause more than a minimal increase in the frequency or occurrence of an accident previously evaluated in the UFSAR (i.e., failure of a small line carrying primary coolant outside containment) and did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR. The analyses performed as part of this activity do not involve UFSAR-describcd methodologies or alternate methodologies used in establishing the design bases or in the safety analyses. The CVCS system and associated components will not be utilized or controlled in a manner that is outside the reference bounds for their design or that is inconsistent with analyses or descriptions in the UFSAR. Since the low pressure portion of the letdown system is not addressed in the Technical Specification or Operating License, no change to Lhese documents is required. In conclusion, the proposed activity does not require prior approval by the NRC. and the activity can be implemented per the governing procedure. Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) U Applicability Review 50.S9Screening 50.S9ScreeningNo. 6E-l3-038 Rev. 0 50.59 EvaluatIon 50.59 Evaluation No. fiG- 13-008 Rev. 0

50.59 REVIEW COVERSHEET FORM is--1o4-lool Revision 3 Page 1 of 2 Station/Unit(s): Byron Station Unit 2 Activity/Document Number: SPP 13-001 Revision Number: _j.._

Title:

Unit 2 Main Turbine Roll in Mode 3 for Ventilation Testing NOTE: For 50.59 Evaluations, information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d)(2). Description of Activity: (Provide a brief, concise description of what the proposed activity involves.) This Special Procedure, Test, or Experiment (SPP) will provide the instructions required to perform a Unit 2 main turbine roll from zero speed to the 450 and 600 rpm plateaus for main generator ventilation testing following replacement of the generator hydrogen cooler in the generator during refueling outage B2R17. Main turbine speed wifi be controlled using the installed Ovation Digital Electro-hydraulic (DEH) system in the same manner as a turbine roll during unit startup. The difference between the normal unit startup and the turbine roll for the generator ventilation testing is that the reactor will not be critical, and the generator will not be pressurized with Hydrogen. The plant wifi be in Mode 3 at Normal Operating Pressure (NOP) and Normal Operating Temperature (NOT) with the steam dumps controlling Reactor Coolant System (RCS) temperature in the steam pressure mode of operation. The steam created from Reactor Coolant Pump (RCP) heat and decay heat, which would normally be dumped to the main condenser through the steam dumps, will be used to roll the turbine to the test speed plateaus. The proposed activity (SPP 13-001) only provides the directions for operation of the DEH system in order to roll the main turbine and establish the conditions required for testing of the main generator and hydrogen cooler. Performance of the actual ventilation testing will be evaluated separately. Reason for Activity: (Discuss why the proposed activity is being performed.) The performance of this SPP will allow the Unit 2 main turbine to be rolled to 450 and then 600 rpm so that internal generator air flows can be checked following replacement of the hydrogen cooler. The new hydrogen cooler is being installed during B2R17 and must be checked to ensure proper air flows through the cooler is obtained to ensure proper cooling of the hydrogen in the main generator. The air test is following Siemens test recommendations. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) There is the potential for an RCS cooldown; however the SPP provides guidance in the form of abort criteria to prevent an adverse plant effect. The SPP will roll the main turbine to the designated speed plateaus to allow Engineering to obtain the required data in order to ensure proper air flow through the new cooler and therefore adequate cooling of the hydrogen in the main generator. The main turbine will not be operated near the resonant speed ranges starting at $50 rpm. Abort criteria in the form of minimum Pressurizer (PZR) level, RCS temperature, Steam Generator (SG) level and pressure, as well as a loss of DEH control is provided. The abort criteria will ensure an adequate margin exists to prevent inadvertent Engineered Safety Features (1SF) actuation (Safety Injection, Auxiliary Feedwater, Main Steam Isolation, Letdown Line Isolation), excessive cooldown or turbine trip. Summary of Conclusion for the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) The activity being implemented (SPP 13.001) does not operate the Main Steam, Turbine, or DEH systems in a manner that is outside of the reference bounds of their design basis or in a manner that is inconsistent with the descriptions found in the UFSAR. The implementation and performance of the SPP does not result in more than a minimal increase in the frequency of the Inadvertent Operation of the Emergency Core Cooling Systems. There are no physical changes required to any UFSAR described SSCs as a result of the performance of the SPP. The systems are being operated in the same manner for which they were designed. Performance of the turbine roll for ventilation testing is not the initiator of any new acUdent and no new failure modes are introduced. The actions performed in the SPP for rolling the main turbine to the required speed plateaus are the same as those performed during a normal unit startup therefore the activity does not create the possibility for a malfunction of an SSC that is important to safety with a different result that has been evaluated in the UFSAR. There is no effect on any

50.59 REVIEW COVERSHEET FORM LS-AA-104-1001 Revision 3 Page 2 of 2 Station/Unit(s): Byron Station Unit 2 Activity/Document Number: SPP 13-001 Revision Number: 1

Title:

Unit 2 Main Turbine Roll in Mode 3 for Ventilation Testing design basis limits for fission product barriers, any UFSAR described evaluation methodologies as a result of the performance of the SiP. The performance of the turbine roll for ventilation testing does not introduce the possibility of a change in the likelihood of a malfunction because the directions for rolling the main turbine to the required speeds for testing as well as the actual turbine rolls are not the initiators of any new malfunctions. The actions for raising turbine speed to the testing plateaus do not introduce any new failure modes. The performance of this activity (5?? 13-001) operates the systems as designed. The performance of the turbine roll for ventilation testing does not introduce the possibility of a change in the consequences of an accident evaluated in the UFSAR because the performance of a turbine roll is not an initiator of any new accidents and no new failure modes are introduced. The performance of this activity (SPP 13-001) operates plant equipment in the manner it was designed. There are no physical changes to any UFSAR described SSC required to perform the turbine roll or as a result of the turbine roll. Since the systems are being operated in the same manner for which they were designed, there is no potential for an increase in the probability of a malfunction or the consequences of a malfunction of an SSC important to safety previously evaluated in the IWSAR. The performance of SPP 13.001 does not create the possibility of a new accident because the performance of a turbine roil is not the initiator of any accident and no new failure modes are introduced. The actions performed for the turbine roll will operate the equipment in the manner it was designed and for its intended purpose. The performance of SPP 13.001 does not introduce the possibility for a malfunction of an SSC with a different result because the activity is consistent with a normal turbine-generator startup with all appropriate support and protective systems in place. The significant difference is that the reactor is shutdown with the RCS at NOP/NOT conditions. The heat input to the RCS is limited to decay heat post B2R17 core reload and the amount of heat generated by the RCPs. The procedure also contains abort criteria to ensure that RCS cooldown limitations are not challenged since the total cooldown between starting conditions and abort conditions is 17°F. The performance of SPP 13-001 does not result in a change that would alter or have any impact on any system parameters or values associated with any design basis limit for any fission product barriers. Therefore, the turbine roll to the required speed plateaus for ventilation testing of the main generator and hydrogen cooler will not result in any design basis limits for fission product barriers as described in the UFSAR to be exceeded or altered. SPP 13-001 provides the instructions for rolling the main turbine from zero speed to the required plateaus for ventilation testing of the main generator and hydrogen cooler. There are no evaluations being performed by the procedure. Therefore the performance of the procedure does not result in a departure from a method of evaluation described in the UFSAR used in establishing the design basis or in any safety analyses. Therefore based upon the above, the SPP may be implemented as proposed without prior permission from the NEC. Attachments: Attach all 50.59 Review forms completed, as appropriate. None Forms Attached: (Check all that apply.) Q Applicability Review [] 50.59 Screening 50.59 Screening No. Rev. 50.59 Evaluation 50.59 Evaluation No. 6G-13.009 Rev. 1

50.59 REVIEW COVERSHEET FORM s--io-ioo; Revision 3 Page 1 of 4 Station/Unit(s): Byron Station. Units 1 and 2 Activity/Document Number £C-391 394. DRP 14484 Revision Number: 0/0

Title:

Turbine Building High Energy Line Break Licensing and Design Basis NOTE: For 5(159 Evaluations, information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(dX2). Description of Activity: (Provide a brief, concise description of what the proposed activity involves.) The proposed activity is a change in the thermal-hydraulic analysis of a High Energy Line Break (HELB) in the Turbine Building, and the resulting environmental affects in rooms containing safety-related equipment that have ventilation intake and or exhaust openings to the Turbine Building. The changes include the mitigation strategy for these rooms/areas that are currently credited to demonstrate these rooms/areas maintain suitable environmental conditions to safely shut down the plant following a HELB in the Turbine Building. Engineering Change EC-391394 describes the changes in design being credited and in the thermal-hydraulic analysis of the Turbine Building HELB and the resulting environmental profiles in the affected moms/areas, and the justification that demonstrates the environmental conditions in these rooms/areas are suitable to safety shutdown the plant following the HELB. The EC describes the changes to the UFSAR that will be made to incorporate the new thermal-hydraulic analysis as well as the analysis to reflect that safety-related equipment/components are protected from HELB induced jet effects. The affected ventilation systems are the Emergency Diesel Generator EDt)) Room Ventilation (VD) System, the Engineered Safeguards features (ESI Switchgear Room Ventilation (VX) System, the Miscellaneous Eecthc Equipment Rooms (MEEks) Ventilation (VE) System.. In summary, the mitigation strategy to protect against a HELB in the Turbine Building is being changed from:

• allowing the Turbine Building environment into the affected Auxiliary Building rooms for a short period of time (no dampers in the ventilation exhaust opening to the Turbine Building that automatically close in response to a HBLB in the Turbine Building),

isolating the affected rooms following closure of the fire damper in the ventilation exhaust opening (alLowing the fire damper to actuate due to a HELB, which is a function in addition to its fire protection function),

• room cooling manually restored by operator action (room fans trip due to closure of the exhaust flowpath, with subsequent loss-of-HVAC resulting in room temperatures substantially exceeding design basis temperatures), and
• thermal-hydraulic event analyzed to predict environmental conditions (limited number of line breaks analyzed, Mass &

Energy releases analyzed in a way that did not maximize enthalpy, and the thermal-hydraulic event analyzed utilizing a proprietary software similar to COMPARE and RELAP4. to:

• keeping the Turbine Building environment our of the Auxiliary Building rooms (isolating the rooms by means of new HELB dampers in the ventilation exhaust openings),
• configuring the fire dampers to close only in the event of a fire (keeping them open during the HELB),
• room cooling automatically restored (automatically restarting of the room ventilation fans following a time delay after tripping on high differential pressure, to minimize the temperanue peak and to minimize time room temperatures are elevated; i.e., keep the rooms within their design basis temperature limits), and
• performing a new analysis of the thermal-hydraulic event to environmental conditions following the HELB (a larger spectrum of line breaks considered, Mass & Energy releases for steam lines performed utilizing WCAP-W961, which maximizes enthalpy, Mass & Energy releases for liquid lines that maximize enthalpy, and the thermal-hydraulic event analyzed utilizing GOTHIC [Generation of Thennal-Hydraulic Information for Containments), Version 7.2a, which has been widely used in analyzing HELBs outside containment).

Changes are also made to the Control Room ventilation system to automatically prevent a Turbine Building HELB environment from entering the Control Room envelope in lieu of the current protection strategy of relying on manual action to react to the condition and prevent the environment from entering the Control Room envelope. In a similar manner, modifications are made

50.59 REVIEW COVERSHEET FORM LS-AA-104-1001 Revision 3 Page 2 of 4 Station/Unit(s): Byron Station, Units 1 and 2 Activity/Document Numbcr EC-391394. DRP 14484 Revision Number: Tide: Turbine Building High Energy Line Break Licensing and Design Basis to automatically sense the NELB environment and prevent the environment from adversely affecting the safety-related S$Cs in the Diesel Oil Storage Tank (DOST Rooms. In addition, modifications are installed to ensure divisional separation walls and other safety-related structures that may be exposed to the Turbine Building IIELE environment can withstand the transient pressure loads that they may experience and modifications also installed to protect vulnerable SSCs from jet impingement resulting from a HELB. Reason tar Activity: (Discuss why the proposed activity is being performed.) A review of the current HELB mitigation strategy has determined that the closure of the affected fire dampers might not occur in the manner assumed in the analyses, and the temperatures in these rooms following the event deviating from the design temperature more than and for a longer duration than is considered suitable for demonstrating that the equipment in these rooms can support safe shutdown of the plant. Also, the design of the DOST Room ventilation system, in which air is exhausted into the Turbine Building on the 401 Elevation and which draws its suction source from the Turbine Building on the 401 Elevation, is such that these areas could be subjected to a Turbine Building HEL3 environment. Therefore, it must be demonstrated that the equipment in the DOST rooms can support safe shutdown of the plant. Additionally, the robustness of relying on operator action to detect a HELB in the Turbine Building and to take manual action to provide protection for the Control Room is being re-considered. finally, the absence of consideration of the impact of a Turbine Building HELB on the L-row wall barrier 4 between the Turbine Building and the Auxiliary Building, and the absence of a IJBLB-induced load on the divisional separation walls is lacking, as single failure mechanisms that could result in adjacent rooms experiencing different environmental conditions (e.g., room pressure) are not considered. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) The new HELB dampers will remain open during normal operation when the VD, VX, or VU fans are running. The new HELB dampers are fast acting and will close quickly upon detection of HELB reverse flow from the turbine building to minimize the affected room exposure to a Turbine Building HELB. After the HELE pressure dissipates in the turbine building, the HELB dampers will reopen. The fire dampers wilt remain open unless the thermal links are actuated by the high temperatures characteristic of a fire. The setpoinrs for the fire damper links are changed as appropriate to reduce the possibility of closure of the fire dampers in the event of a Turbine Building HELB, allowing for prompt restoration of the ventilation systems following the IJELB event. Thus the new dampers will not require new operator actions. The HELB dampers will allow for restoration of an affected VD, IX, and VU systems following a high energy line break in the turbine building and eliminate the need for a manual restoration of room ventilation by an operator. Likewise, the new fan auto restart feature will not affect normal fan operation (starting and stopping by the operator). In the event of a high differential pressure, the fan that is running will trip, as at present. However, the auto restart feature will attempt to restart the supply fan after a short time delay. If the high differential pressure was due to HELB damper closure following a Turbine Building RET_B, the turbine building pressure will have decreased to the point where the restarted fan can re-open the HELB dampers and return the ventilation system to operation. Likewise, if a VI), VX, or VU fan start attempt occurs after initiation of the Turbine Building HELB event, the Turbine Building pressure will have decreased to the point where the fan can start or restart, thereby re-opening the HELH dampers and returning the ventilation system to operation. If the high differential pressure was due to a condition that does not clear within the time delay period, the restarted fan will top again on high differential pressure and will then be blocked from further restart attempts until an operator investigates and resets the trip. The automatic restoration of an affected VD, VX, and YE systems following a HELB in the Turbine Building will eliminate the ( need for a manual restoration of room ventilation by an operator following the initial fan high differential pressure trip. Like the existing VD, YX, and VU equipment, a malfunction of the new equipment would not affect the availability of the redundant VI), IX, or VU train. This is consistent with the system design bases safety analyses requirements.

50.59 REVIEW COVERSHEET FORM LS-AA-104-W01 Revision 3 Page 3 of 4 Station/Unit(s): Byron Station, Units 1 and 2 Activity/Document Number EC-391394. DRP 14.084 Revision Number:

Title:

Turbine Building Hip.h Energy Line Break Licensing and Design Basis Summary of Conclusion tot the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) The proposed activity involves crediting 1). the installation of a new auto restart feature to various fans in the Emergency Diesel Generator (EDG) Room Ventilation (VI)) system, the Engineered Safeguards Features (ESF) Switchgear Room Ventilation (VX) System, and the Miscellaneous Electric Equipment Rooms (MEERs) Ventilation (yE) System, 2). the installation of new HELB dampers in the VI), VX, and VE system exhaust openings between the affected rooms and the Turbine Building, and 3) the changes to ensure the fire dampers in the VI), V3C, and VE system exhaust openings between the affected moms and the Turbine Building remain open under all ptant conditions exclusive of a fire, to help mitigate the consequences of a HELB in the Turbine Building. following installation of these features, the VI), V3C, and VE systems will continue to be capable of performing their UFSAR-described design functions. As at present, the fIihue of a ventilation fan would lead to the loss of one train of the VI), VX, or VE system. The loss of one train does not affect the safe shutdown capability of the station since independent ventilation systems arc provided for each redundant division. A new thermal-hydraulic analysis of the Turbine Building HELB and the resulting environmental profiles in the affected rooms/areas was performed to credit these new design features. The change in HELB mitigation strategy results in the affected room environmental results for the event being less severe and for a much shorter duration than those identified in UFSAR Table ( 3.11-2. The revised analysis demonstrates that the environmental parameters within these zones would not be significantly more severe than the environment that would occur during normal plant operation. Therefore, the change is not adverse and the changed room environmental profiles do not represent an adverse change to a UFSAR described design function. New HELB dampers, installed under a separate activity, will be available to permit air flow through the room both during normal ventilation system operation and shortly after a nearby turbine building high energy line break, allowing the ventilation system to continue to perform its ventilatiDn and cooling functions. 50.59 Evaluations 60-12-003, 6G-l2-00?, 6G-t2-017, 60-12-014, 6G-12-0lS, and 60-12-016 were perfonned for the stand alone Engineering Changes installing the new HELB dampers and fan auto-restart features to address the following potential adverse effects of the proposed activity

• The replacement of the current manual method of restoring room ventilation following its isolation in the event of a nearby high energy line break in the turbine building with an automatic method involving auto restart of the affected fans and the re-opening of the HBLB dampers
• The automatic restarting of a VI), VX, or lB fan after an existing equipment protection feature (fan high differential pressure trip) had stopped the fan
• The potential adverse effect on the reliability of the VI), VX, or VE system caused by the addition of the new HBLB damper sections, where the fai1ur of either could result in a loss of one VI), WC, or YE train As EC-39 1394 is for the integrated change in response to a Turbine Building HELB, the evaluations documented in 50.59 Evaluations 6G-12-003, 60-12-007, 6G.l2-017, 6G-12-014, 60-12-015, and 60-12-016 were repeated in 50.59 Evaluation 60-13-010.

Based on the quality classification and testing of the new components, and because the proposed activity reduces the likelihood of a malfunction of the electhcal equipment in the VI), VX and VE areas, the evaluation concluded that tim potential adverse effects did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR Based on the quality classification and testing of the new components, and because the proposed activity reduces the likelihood of a malfunction of the electrical equipment in the VI), VX, and yE areas, 50.59 Evaluation 6G-13-010 concluded that the potential adverse effects of the automatic system restoration following a HELB and the automatic fan restart fullowing a trip on high differential pressure did not cause more than a minimal increase in the frequency or occurrence of

50.59 REVIEW COVERSIWET FORM LS-AA-104-1001 Revision 3 4 Page4of4 Station!LJnk(s): Byron Station. Units 1 and 2 Activity/Document Number: EC-391394. DRP 14-O$4 Revision Number QJJ T1de Turbine Buildlnr High Energy Line Break Licensing and Design Basis an accident previously evaluated in the UFSAR anti did not cause more than a minimal increase in the likelihood of a malfunction of an S$C important to safety previously evaluated in the UFSAR. The new fan auto restart feature does not involve a change to a procedure that adversely affects how UFSAR-described SSC design functions are performed or controlled. However, the change from manual to automatic restoration of room ventilation following its isolation in response to a Turbine Building HELD was addressed in 50.59 Evaluation 6G-13-010. As discussed in the previous paragraph, the evaluation concluded that this change did not cause more than a minimal increase in the frequency or occurrence of an accident previously evaluated in the UFSAR and did not cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR. The replacement damper assemblies do not involve a change to a procedure that adversely affects how UFSAR-described SSC design functions are performed or controlled. However, the change from manual to automatic restoration (unassisted opening of HELD dampers) of room ventilation following its isolation in response to a Turbine Building HELD was addressed in 50.59 Evaluation 6G-13-0lD. As discussed in the previous paragraph, the evaluation concluded that this change did net cause more than a minimal increase in the likelihood of a malfunction of an SSC important to safety previously evaluated in the tWSAR. The analyses performed as part of the replacement damper assemblies do not involve UFSAR-described methodologies or alternate methodologies used in establishing the design bases or in the safety analyses. ( The Vt), VX, and VE systems and associated components will not be utilized or controlled in a manner that is outside the reference bounds for their design or that is inconsistent with analyses or descriptions in the UFSAR. Since the Vt), VX, and VE systems are not addressed in the Technical Specification or Operating License, and since implementation of the new design feature does not alter existing functions such addition to the Technical Specifications is required, no change to these documents is required. In addition, the modilications installed for the VC system did not require a change to the Technical Specifications or Operating License. The thermal-hydraulic analysis performed to credit the aforementioned modifications to the Vt), V7C, and VE systems and determine the resulting environmental profiles in the moms served by the Vt), VX, and VE systems involves the use of an alternative methodology from what was previously used in establishing the design basis. However 50.59 Evaluation 6G-13-0l0, determined that the use of GOTHIC to evaluate the effects of a high energy tine break effects on various rooms at Byron is not a departure from a method of evaluation described in the UFSAR because it is appropriate for the intended application and the method has been approved by the NRC. Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) Applicabifity Review 50.59 Screening 50.59 Screening No. 6E-13..090 Rev. 0 50.59 Evaluation 50.59 Evaluation No. 60-13-010 Rev. 0

50.59 REVIEW COVERSHEET FORM LS-AA-l04-tO0t Revision 3 Page I of4 StatloafUmt(s): Byron Units 1 & 2 AcdvltyIDocument Number: EC 386524. 386525: DRP# 15-024, 15-025: TS Bases# 13-005, 13-006; TRM# 14-002. 14-003 Revision Number: 1.0,0,0,0.0,0,0

Title:

Auxiliary Feedwater Suction Switchover Channel Modification NOTE: for 50.59 Evaluations, information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d)(2). Description of Activity: (Provide a brief, concise description of what the proposed activity involves.) The proposed activity involves the following permanent plant changes: Modify the Auxiliary feedwater (AF) suction line from the Condensate Storage Tank (CST) to each AF pump to install a new SOR pressure switch (PS-Af300 and AF3OI) upstream of the existing AFOO1 and AFOO2 valves to monitor CST level when the AF pump is secured. This pressure switch will be used in the Diesel Driven AF Pump (DDAFP) and Motor Driven AF Pump (MDAFP) control circuits and will prevent the pump from starting if Suction pressure is insufficient to support pump operation (due to a postulated pipe break on the turbine building side of the L-wall or CST failure). This pressure switch is interlocked with the DDAFP and MDAFP control circuits and will protect the pump only when it is secured. When operating, the existing pressure transmitters, PT-AFO5 I and PT-AF055, will provide pump protection. Modify the PT-AF05 1 and PT-AFOS5 instrument loops to add an additional comparator card output. This output corresponds to a level above minimum Essential Service Water (SX) system pressure. This pressure, referred to as the Reset Pressure corresponds to a pressure that indicates that the AF pump suction is aligned to the SX system and the SX pumps are operating. This Resct Pressure will be used in the DDAFP and MDAFP control circuits.

• For the MDAFP the EC adds new time delay relay (AFJAX3) in parallel to existing relay PSAF5IX. These relays will energize on low-low CST or low-low pump suction pressure fPS-AF300or PT-AFOSI) to inhibit a pump start lithe pump is running, PT-AF051 will energize existing relay PSAF5IX and initiate a pump nip. A contact from relay PSAF5IX will seal in relay AFLAX3 and this relay will remain energized until the Reset Pressure is exceeded. The existing MDAFP control circuit uses relay AFIAX1 to bypass the low-low suction pressure trip for 2.5 seconds after pump start. The AFIAX3 seal-in circuit includes a contact from AFIAXI to prevent the seal-in from occurring for the first 2.5 seconds following pump start. The MDAFP will be allowed to restart five (5) seconds after time delay relay AFIAX3 is dc-energized and times out. To allow PSL-AFO5I to initiate a low-tow pressure trip but prevent PSL-AFO5I from directly switching the nip coil a blocking diode is added to the low-low pressure nip circuit.
• For the MDAFP this EC revises MOV AFOO6A control circuit to add a contact from Relay PSAF5IX in parallel to the existing PSL-AFO5 1 contact This relay contact will open the MOV should AFt AX3 and PSAF5 IX seal in following a lvfl)AFP trip on low-low suction pressure and PSL-AFO5 I resets. This condition could occur should the CST pump suction header pipe fail at or near grade elevation.
• F or the DDAFP the EC adds new time delay relay (K6). This relay will energize on tow-low CST suction pressure to inhibit a pump start. A contact from relay K6 will interlock with existing relay K12 to prevent the pump from starting on low-low CST level. If the pump is running, relay K12 will initiate a pump nip. Relay K6 will seal-in and remain energized until the Reset Pressure is exceeded. The DDAFP wifl be allowed to restart five (5) after time delay relay K6 is deenergized and times out
• This EC also ensures that the DDAFP will be available following a Beyond Design Basis External Event (BDBEE). En a BDBEE all AC sources of 4kV and 48OVAC power are assumed to be unavailable, and as a result, the 1vLDAFP, Essential Service Water (SX) pump and MOVs AFOO6B and AfO17B would be unavailable.

If the CST is lost (i.e.CST level below the PS-AF3OI setpoint) the DDAFP wilt not start and will be prevented from starting. To defeat the Low-Low pressure nip/inhibit interlock following a BDBEE, a FLEX bypass hand-switch, HS-AF 158, is added to DDAFP local control panel 1/2AFOIJ (located in the pump room). This three position, maintained contact, hand-switch nlinimi7es the time required for the local operator to bypass the PSL-AFOS5fPS-AF3O1 interlock and start the DDAFP once the required manual operator actions to align the pump to the SX system and isolate the CST fiowpath have been completed.

• Install new alarm window indicating relay K-6 or AFIAX3 is energized.
• IJFSAR change #15-024 & 025
• Tech Spec Bases change # 13-005 & 006
• Technical Requirements Manual change # 14-002 & 14-003

50.59 REVIEW COVERSHEET FORI4 LS-AA-104-l001 Revision 3 Station/Unit(s): Byron Units 1 & 2 Page 2 o[4 ActivityfDocument Number: EC 386524. 3S6525 DRP# 15-024, 15-025; TS Bases# 13-005. 13-006; TRN# 14-002. 14-003 Revision Number: 1,0,0.0,0.0.0.0

Title:

Auxiliary Feedwater Suction Switchover Channel Modification Reason for Activity: (Discuss why the proposed activity is being performed.) The proposed modification is intended to eliminate multiple pump start/stop cycles as well as inhibit the pump from starting in the event of an L-walt break to prevent potential air ingestion. The APP pump start circuitry prevents the pump from starting if low-tow suction pressure (J 6.5 psia) is present prior to pump start and trips the pump if these conditions occur during operation. Curren tly, the location where AF pump suction pressure is sensed is downstream of a check valve (AFOOt A/B) that forms the safety class break in the AF pump suction piping. In this case, a failure of the upstream non-safety-related piping before the AF pump starts may not be sensed because elevated pressure (indicative of an intact CST before the event) would be trapped by the check valve (pressure not allowed to equalize with the upstream piping because by design the check valve is preventing reverse flow.). As such, the pump will ancmpt to start, but as soon as flow movement opens the check valve and exposes the pressure transm itter to the prevailing low suction pressure, a trip signal will be processed (after a 2.5 second time delay for the MDAFP). Depending on the break location, this situation could result in air ingestion into the pump during the 2.5 second interim (MDAFP) or during the multiple start attempts. At the same time, a signal (18.1 psia) has been sent to open the SX system crosstie valves (AFOO6 & Af017) to provide the A1 pumps with their only credited safety-related water source. After a time delay (4 second s if pump doesnt start) for the MDAFP (no delay for DDAFP), the SX valves wilt automatically begin to open. While the motor operate d SX valves are opening, and depending on the break elevation, the AF suction pressure may recover (because flow is now static) above the I 65 psia trip setpoint and allow another restart. The success of the restart depends on these cross-tie valves being at least partially open (at least 5 seconds of travel). In the case of the DDAFP, it may start and stop more times than the MDAF P (due to the absence of a time delay) until the SX suction valves are sufficiently aligned, which could also lead to air ingestion in the event of an upstream pipe break. Therefore, to significantly reduce the Af pumps multi startltrip scenarios and the potential for air ingestion when considering the loss of the normal non-safety-related suction source (CST), corrective measu are res required. Since the CST (and its AF pump supply piping in the Turbine Building) is not seismi cally qualified and the CST is not protected from tornado born missiles, it cannot be credited as being available following these natural phenomena. The multi start/trip scenario is only a concern when the AF pumps are started with lower than norma l suction pressure (indicative of a loss of the CST). The AF pumps supply cooling water to the steam generators upon loss of main feedwater supply and are automatically started in the event of an SI signal, LOOP signal, RCP UV signal, ATWS, or low-lo w SG level signal. While, consistent with Criterion 2, structures, systems, and components important to safety shall be design ed to withstand the effects of natural phenomena such as earthquakes, tornadoes, hurricanes, floods, tsunami, and seiches without loss of capability to perform their safety functions, these natural phenomena are not spec(ficatly identified as an initiati ng event in the Chapter 15 analyses. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analys es described in the UFSAR) The proposed activity will resolve the Af Pump air ingestion concern expressed above by an NRC inspector and outlined in JR 1202766 (Byron). The proposed activity will not impact normal plant operations. It will however delay the responsc time of the AF system to various transients/accidents credited/assumed in the UFSAR in the event the CST or associated AF pump suction piping is lost. Westinghouse has reviewed the current licensing basis and evaluated or reanalyzed the impacted safety analysis for an increased time delay in the auxiliary feedwater injection of 12 seconds (which bounds the time delay introduced by this activity). Theyve concluded that the licensing basis acceptance criteria continu e to be met with the increased AFW delay time as follows:

• for the Main Steam Line Break (MSLB) outside containment, the results show that the BWI SGs (Unit 1) are more limiting for the overall peak compartment temperature outside the containment than the original Westinghouse Model D5 SGs (Unit 2) at MUR conditions, and an increased AFW delay, by 16.9°F. The results also show that the BWI SGs are more limiting prior to SLI by 0.4°F. These (peak) values, both prior to Steam Line Isolation (SLI) and overall, are bounded by previous analyses.

50.59 REVIEW COVERSHEET FORM LS-AA-104-l001 Revision 3 Page 3 of4 Station/Unit(s): Byron Units I & 2 Activity/Document Number: EC 386524. 386525 DRP# 15424. l5-025TS Bases# 13-005. 13-006: TRM# 14-002. 14-003 Revision Number: 1.0.0.0.0.0.0.0

Title:

Auxiliary feedwater Suction Switchover Channel Modification

• For the Loss of Normal Fcedwater(LONF) and Loss of NC (LOAC) events, the results show that margin to pressurizer filling is maintained.
• For the feedline Break (FIB) event, the results show that no bulk boiling occurs in the RCS because a margin is maintained to hot leg saturation such that core cooling is maintained.
• For the LOAC with RCP seal injection event, the results show that for one hour after transient initiation the pressurizer safety valve (PSV) cycling conditions are acceptable with respect to ensuring the PSVs will not be damaged.
• For the Anticipated Transient Without Scram (ATWS) event, no single failure is required to be taken in the analysis.

Additionally, it is permissible to assume that non-safety grade equipment such as the ATWS Mitigation System Actuation Circuitry (AM SAC) system and SG steam dump system are operable in the analysis. It is therefore not necessary to assume concurrent failure of the non-safety grade CST at the time that the ATWS occurs. As such, the current analysis remains applicable and the CST failure scenario need not be considered with respect to the ATWS event. The normally idle AF system automatic operation will change as follows: a An APP will be allowed one (1) unsuccessful start while aligned to the CST. Any subsequent start will be locked-out until the pump is re-aligned to the SX system. Currently, the APP will immediately attempt to restart provided suction pressure is not below 16.5 psia.

• Following an APP nip (DDAFP or MDAFP) on low-low suction pressure from the CST and subsequent transfer to the SX system, or a transfer to the SX system before a start because suction pressure is inadequate (S 16.5 psia), a pump start will be delayed 5 seconds from the instant when both SX cross-tie valves have begun to open (indicated when APP suction pressure reaches the reset value). Currently, the APP will immediately attempt to restart provided suction pressure is not below 16.5 psia.
• The AFOO6A valve will auto-open if APP suction pressure is < 18.1 psia or relay PSAF5 lX is energized.

Relay PSAF51X is energized by low-low Suction pressure (16.5 psia as measured byPT-AFO51) and/or low pressure as measured by PS-AF300. Currently, the AFOO6A valve will auto-open only if AFP suction pressure as measured by PT AFO51 is 5 18.1 psia.

• The AFOO6B valve will auto-open if AFP suction pressure is 5 18.1 psia or relay K-6 is energized.

Relay K-6 is energized by low-low suction pressure (16.5 psia as measured by ?T-AF055) and/or low pressure as measured by PS AF3OI. Currently, the AFOO6B valve will auto-open only if APP suction pressure as measured by PT-AF055 is 5 18.1 psia. An FMEA comparison was performed between the existing AF pump control circuit and the proposed modified circuit for each pump. From the comparison it can be concluded that the proposed modification does not introduce any new failure modes. Summary of Conclusion for the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) Screening Question I was answered yes since the proposed activity will delay (by less than 12 seconds) the injection of AF water into the SGs which could be adverse. Therefore, a 50.59 Evaluation was performed to address the increased time delay. The changes to the AF pump control circuitry by the proposed activity will not have an adverse effect on UPSAR described design functions. AF pump capacity will remain unchanged. The proposed change will require a number of UFSAR statements be revised since an additional instrument will provide a source of permissive signal to prevent automatic operation of the auxiliary feedwater pump unless permissive conditions are satisfied. Also, chapter 15 will be revised to reflect the new delay times in AF delivery to the steam generators. The proposed activity does not involve an adverse change to an element of a UFSAR described evaluation methodology. However an input parameter, AFW injection delay time, will change for select even&conditionslaccidents. The proposed activity does not involve a test or experiment not described in the UFSAR, where the SX/AF system is utilized or controlled in a manner that is outside the reference bounds of the desigit

50.59 REVIEW COVERSHEET FORM LS-AA-104-l00l Revision 3 StatlonfUnit(s): Byron Units I & 2 Page4 of4 Activity/Document Number: EC 386524. 386525; DRP# t5-824. 15425

                                                                         ; IS Bases# 13-005. 13-006: TRM# 14-002, 14403 Revision Number: 1,0,0.0.0,0.0,0

Title:

Auxiliary Feedwater Suedon Switchover Channel Modlflcatlon The proposed activity will not require a Tech Spec change. However, a Technical Specification Bases change is necessary to include the addition oft pressure sensor upstream of the pump suction check valve (AFOOIAIB) to work in conjunction with the existing pressure sensor (installed downstream of check valve) per channe l (train) in support of function 6.f, Auxiliary Feedwater Pump Suction Transfer on Suction Pressure-Low, Table 3.3.2-1, ESF Actuat ion System Instrumentation. Also, the TRM, Table T2.O.b- 1, will be revised for the same function (Auxiliary feedwater Pump Suctio n Transfer on Suction Pressure-Low) to include the pressure switch setpoint. All Evaluation questions were answered no and therefore the proposed activit y may be installed without an amendment to the license. Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) Q Applicability Review 50.59 Screening 50.59 ScreenIng No. 6E-13-129 Rev. 0 50.59 Evaluation 50.59 Evaluation No. 6G-13-O11 Rev. 0

50.59 REVIEW COVERSHEET FORM LAA-1o4-1oo1 Revision 3 Page 1 of 2 Station/Unit(s): Byron Station Unit 1 Activity/Document Number: SPP 13-004 Revision Number: 0

Title:

Unit 1 Main Turbine Roll in Mode 3 for Ventilation Testing NOTE: For 50.59 Evaluations, information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d)(2). Description of Activity: (Provide a brief, concise description of what the proposed activity involves.) This Special Procedure, Test, or Experiment (SPP) will provide the instructions required to perform a Unit main turbine roll from zero speed to the 450 and 600 rpm plateaus for main generator ventilation testing following replacement of the generator hydrogen cooler in the generator during refueling outage B1R19. Main turbine speed will be controlled using the installed Ovation Digital Etectro-hydraulic (DEH) system in the same manner as a turbine roll during unit startup. The difference between the normal unit startup and the turbine roll for the generator ventilation testing is that the reactor will not be critical, and the generator will not be pressurized with Hydrogen. The plant will be in Mode 3 at Normal Operating Pressure (NOP) and Normal Operating Temperature (NOT) with the steam dumps controlling Reactor Coolant System (RCS) temperature in the steam pressure mode of operation. The steam created from Reactor Coolant Pump (RCP) heat and decay heat, which would normally be dumped to the main condenser through the steam dumps, will be used to roll the turbine to the test speed plateaus. The proposed activity (SPP 13-004) only provides the directions for operation of the DElI system in order to roll the main turbine and establish the conditions required for testing of the main generator and hydrogen cooler. Performance of the actual ventilation testing will be evaluated separately. Reason for Activity: (Discuss why the proposed activity is being performed.) The performance of this SPP will allow the Unit 1 main turbine to be rolled to 450 and then 600 rpm so that internal generator air flows can be checked following replacement of the hydrogen cooler. The new hydrogen cooler is being installed during B1R19 and must be checked to ensure proper air flows through the cooler is obtained to ensure proper cooling of the hydrogen in the main generator. The air test is following Siemens test recommendations. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety anaLyses described in the UFSAR.) There is the potential for an RCS cooldown; however the SPP provides guidance in the form of abort criteria to prevent an adverse plant effect. The SPP will roll the main turbine to the designated speed plateaus to allow Engineering to obtain the required data in order to ensure proper air flow through the new cooler and therefore adequate cooling of the hydrogen in the main generator. The main turbine will not be operated near the resonant speed ranges starting at 850rpm. AbOrt criteria in the form of minimum Pressurizer (PZR) level, RCS temperature, Steam Generator (SG) level and pressure, as well as a loss of DEH control is provided. The abort criteria will ensure an adequate margin exists to prevent inadvertent Engineered Safety Features (ESF) actuation (Safety Injection, Auxiliary Feedwater, Main Steam Isolation, Letdown Line Isolation), excessive cooldown or turbine trip. Summary of Conclusion for the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) The activity being implemented (SPP 13-004) does not operate the Main Steam, Turbine, or DEH systems in a manner that is outside of the reference bounds of their design basis or in a manner that is inconsistent with the descriptions found in the UFSAR. The implementation and performance of the SPP does not result in more than a minimal increase in the frequency of the Inadvertent Operation of the Emergency Core Cooling Systems. There are no physical changes required to any UfSAR described SSCs as a result of the performance of the SPP. The systems are being operated in the same manner for which they were designed. Performance of the turbine roll for ventilation testing is not the initiator of any new accident and no new failure modes are introduced. The actions performed in the SPP for rolling the main turbine to the required speed plateaus are the same as those performed during a normal unit startup therefore the activity does not create the possibility for a malfunction of an SSC that is important to safety with a different result that has been evaluated in the UFSAR. There is no effect on any

50.59 REVIEW COVERSHEET FORM Ls-AA-1o4-lool Revision 3 Page 2 of 2 Station/Unit(s): Byron Station Unit 1 Activity/Document Number: SPP 13-004 Revision Number: 0 Title; Unit 1 Main Turbine Roll hi Mode 3 for Ventilation Testina design basis limits for fission product barriers, any UFSAR described evaluation methodologies as a result of the performance of the SPP. The performance of the turbine roll for ventilation testing does not introduce the possibility of a change in the likelihood of a malfunction because the directions for roiling the main turbine to the required speeds for testing as well as the actual turbine rolls are not the initiators of any new malfunctions. The actions for raising turbine speed to the testing plateaus do not introduce any new failure modes. The performance of this activity (SPP 13-004) operates the systems as designed. The performance of the turbine roil for ventilation testing does not introduce the possibility of a change in the consequences of an accident evaluated in the UFSAR because the performance of a turbine roll is not an initiator of any new accidents and no new failure modes are introduced. The performance of this activity (SPP 13-004) operates plant equipment in the manner it was designed. There are no physical changes to any UFSAR described SSC required to perform the turbine roll or as a result of the turbine roll. Since the systems are being operated in the same manner for which they were designed, there is no potential for an increase in the probability of a malfunction or the consequences of a malfunction of an SSC important to safety previously evaluated in the UFSAR. The performance of SPP 13-004 does not create the possibility of a new accident because the performance of a turbine roll is not the initiator of any accident and no new failure modes are introduced. The actions performed for the turbine roll will operate the equipment in the manner it was designed and for its intended purpose. The performance of SPP 13-004 does not introduce the possibility for a malfunction of an SSC with a different result because the activity is consistent with a normal turbine-generator startup with all appropriate support and protective systems in place. The significant difference is that the reactor is shutdown with the RCS at NOPINOT conditions. The heat input to the RCS is limited to decay heat post 31R19 core reload and the amount of heat generated by the RCPs. The procedure also contains abort criteria to ensure that RCS cooldown limitations are not challenged since the total cooldown between starting conditions and abort conditions is 17°F. The performance of SPP 13-004 does not result in a change that would alter or have any impact on any system parameters or values associated with any design basis limit for any fission product barriers. Therefore, the turbine roll to the required speed plateaus for ventilation testing of the main generator and hydrogen cooler will not result in any design basis limits for fission product barriers as described in the UFSAR to be exceeded or altered. SPP 13-004 provides the instructions for rolling the main turbine from zero speed to the required plateaus for ventilation testing of the main generator and hydrogen cooler. There are no evaluations being performed by the procedure. Therefore the performance of the procedure does not result in a departure from a method of evaluation described in the UFSAR used in establishing the design basis or in any safety analyses. Therefore based upon the above, the SPP may be implemented as proposed without prior permission from the NRC. Attachments: Attach all 50.59 Review forms completed, as appropriate. None Forms Attached: (Check all that apply.) [] Applicability Review [] 50.59 Screening 50.59 Screening No. Rev. 50.59 Evaluation 50.59 Evaluation No. 6G-13-014 Rev. 0

(PDF INSIDE) 50.59 REViEW COVERSHEET FORM LS-AA- 04-I 001 Revision 3 Page I ol2 Station/Unit(s): Ilyron Unit I 1clivity/I)ocument Number: EC 394715 Rcvisinn Number: (I

Title:

CVCS Letdown Relief Valve I CV 119 Bonnet Vent Drain Line NOTE: For 50.59 Evahiations. information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in aecoidmce with the reqirirements of 10 CFR 50.59(d)2). Description of Activity: Provide a brief, concise description of what the proposed activity involves.) rite proposed activity will install a combination of metallic flex line and hzLrd piping from the chemical and voltime control sysieni (CVCS) letdown hear exchanger outlet header relict valve ICVSI 19 bonnet vent port to a floor drain and modify the floor drain cover to allow insertion of the drain line. This vent line will incltide a locked open isolation valve to maintain an open vent and a sight glass for identification of leakage. Relief valve ICV$l 19 provides overpressure protect ion for the piping and associated components between the letdown low pressure control valve, I CVI 31. and the volume control tank (VCT). In the event I hat he letdt,wn flew downstream of the letdown hear. echangers becomes obstructed or inaclverwntly isolaiccl. relief valve I CVS 119 opens to relieve the overpressure by mlireelingletctown flow no the VCT. Relief valve ICVSI 19 is equipped with a bellows wIdth sumnttncls the valve spindle and which veins into the valve bonnet. An opening in the bonnet vents the bonnet to the atmosphere. The bellows forms part of the pressure boundary at the valve millet and allows the relief valve to open at its set pressure despite a varying back pressure. In the case of ICVSI 19. the back pressure varies with the pressure in the VC1. Reason tot Activity: (1)iscniss why the proposed activity is being performed.) The proposed activity is being undertaken to: (I) allow plant operators to isolate reactor coolant leakage from the VCT in the event ofa relief valve lCVSl 19 bellows failure. (2) prevent radiological contamination of the area surrounding ICVI 19 in the event, of bellows failure, and (3) facilitate maintenance on the relief valve in the event of bellows leakage/failure. This proposed design change will provide a drain path to a local floor drain in the au.iliary building floor drain (WF) system for cirntanninaictl bonnet vent leakage horn a failed bellows. In the event of bellows linilute. the fluid on the discharge side oh the relief valve can leak ihrotmh the bellows and into the relief valve bonnet, which is open to the auxiliary building Area 5 atmosphere. Relief valve ICVSI 19 has experienced previous bellows failure and required subsequent relict valve repair. including bellows replacenicoit as a result of high cycle, low-stress lirtigue, because the set pressure of the relief valve was repeatedly reached due to the clogging of reactor coolant fllier ICVO3F. Effect of Activity: (Discuss how the activity impacts plain operations. design bases, orsafily analyses described in the UFSAR.) the proposed activity will have minimal impact on plant operations. IThe new vent line isolation valve wilt be maintained in the locked-open position during operations. The new sight glass will foeilitate the detection of bellows leakage/failure, If a bellows leak dcveh.tps, the leakage will be routed through the new vent line directly to an auxiliary building Area S floor drain. This will minimize the spread of rndioactive contamination and will have no adverse effect on the floor drain system. If it is necessary to replace the leaking bellows, the low pressure letdown line will be isolated and removed front service and the vent line isolation valve will be closed to facilitate maintenance activities on the relief valve. the locked-open bonnet vent line isolation valve will allow the bonnet to continue to be vented to the auxiliary building Area 5 atmosphere, thereby ensuring the relief valve continues to perform its function of protecting the low presstmrc letdown line and downstream components from overpresstmrization anti consequent foilure, Therefore, the proposed activity will wit impact design bases or safety analyses including the safety analysis ofa failure ofa small line carrying primary coolant outside containrnenL as described in the UFSAR. Summary of Conclusion for the Activitys 50.59 Review: (Provide justification for the conclusion. including sufficient detail to reeognie and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 5t).59 Screening. 50.59 Evaluation, or License a Amendment Request. as applicable, is not required.)

50.59 REVIEW COVERSHEET FORM LS-AA- 104-I (X)l Revision 3 Pave 2 of 2 Station/Unit(si: Byron Unit I Activity/Document Number: FC 394715 Revision Number: (I

Title:

CVCS Letdown Relief Valve ICVU 19 Bonnet Vent Drain Line Atthottgh the proposed activity includes the installation of a manual isolation valve in the previously tinohstructcct bonnet vent path, the use of an administratively controlled locked-open manual isolation valve in this application is consistent with code requirements as described in the UFSAR. However, the installation of a vent line with an adinittistratively cnntmllcd locked-open manual isolation valve. in the previously unobstructed bonnet vent path involves a ch:inge to a procedure that repiesents a change in the method oIperforming or controlling a UFSAR-described SSC design function. 50.59 Evaluation 6G13t)i5 fletermitued tJiut the design controls tot the new vent line and the administrativ e controls on the new locked-open manual isolation valve were stifficient to ensure the proposed activity did not cause more than a minimal increase in the irequency or occurrence of an accident previously evaluated in the UfSAR (i.e.. failure of a small line carrying primary coolant outside containment) and did not cause more than a minimal increase in he likelihood of a malfunction of an SSC important to safety previously evaluated in the UFSAR. the 51)59 lvaluatinn determined that the radiological dose consequences of the failure of a small line carrying primary coolant outside containment or ofa failure of the low pressure letdown line relief valve were not adversely affected. The Evaluation also determitteci that the proposed activity would not introduce the potential for a different type of letdown tine taiture or flooding event and that the proposed activity would not result in a design basis limit for a hssion product barrier as described in the UFSAR being exceeded or altered. The piping and support analyses perli7rnicd as part of this activity do not result in a departure from a method of evaluation described in the VPSAR used in establishing the design bases or in mIte safety analyses. the CVCS system and associated components will nut be utilized or controlled in a manner that is outside the reference bounds (or their design or that is inconsistent with analyses or descriptions in the UESAR. Since the low pressure portion of the letdown system is mint addressed in the Technical Specificatiotm or Operating License, no change to these documents is requited. En conclusion, the proposed activity does tmot require prior approval by the NRC. and the activity can he implemented per the governing procedume. Attachments: Attach all 50.59 Review forms completed. as appropriate. Forms Attached: (Check all that apply.) U Applicability Rcview 50.59 Screening 50.59 Screening No. GE 13174 Rev. 0 50.59 Evaluation 50.59 Evaluation No. 6013015 Rev. 0

50.59 REVIEW COVERSHEET FORM LS-AA-l04-l0Ol Revision 3 Page 1 of4 Station/Unit(s): Byron/Units I and 2 Activity/Document Number: EC 395574, Technical Requirements Manual (TRM) Change 14-004 Revision Numbers: 0/NA

Title:

REVISE ANALYSIS BYR1O-136 AND TRM 3.9.A CURVES FOR MUR (ICDT) NOTE: For 50.59 Evaluations, information on this tbrm will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d)(2). Description of Activity: (Provide a brief, concise description of what the proposed activity involves.) EC 395574 issues calculation BYRIO- 136, Spent fuel Pool Background Heat Load Margin Analysis for TRM 3.9.a, Revision

1. As a result of the revised analysis the following Technical Requirements Manual (TRM) changes will be made to revise the Incore Decay Time (ICDT) for future outages:

Byron TRM Section 3.9.a, Decay Time, TLCO states, The reactor shall be subcritical for the last 100 hours; OR the reactor shall be subcritical for the last 48 hours AND the point described by the number of assemblies offloaded and the time after shutdown shall be within the Acceptable Regions of the appropriate figure (Figure 3.9.a-l through 3.9.a-9, as applicable), based on cycle-specific SFP Background Heat Load Margin. This will be changed to read: The reactor shall be subcritical for the last 113 hours; OR the reactor shall be subcritical for the last 50.33 hours AND the point described by the number of assemblies offloaded and the time after shutdown shall be within the Acceptable Regions of the appropriate figure (Figure 3.9.a-1 through 3.9.a-9, as applicable), based on cycle-specific SFP Background Heat Load Margin. Byron TRM Section 3.9.a Condition A states, Reactor subcritical for < 100 hours; OR Reactor subcritical <48 hours OR the point described by the number of assemblies offloaded and the time after shutdown not within the Acceptable Regions of the appropriate figure (figure 3.9.a-1 through 3.9.a-9). This shall be changed to read: Reactor subcritical for < 50.33 hours; OR Reactor subcritical < 113 hours AND the point described by the number of assemblies offloaded and the time after shutdown not within the Acceptable Regions of the appropriate figure (figure 3.9.a-l through 3.9.a-9). Byron TRM Surveillance TSR 3.9.a.l states, Verify the reactor subcritical 100 hours by confirming the date and time of subctiticality; OR Verify the reactor subcritical 48 hotirs by confirming the date and time of subcriticality AND verify the point described by the number of assemblies offloaded and the time after shutdown is within the Acceptable Regions of the appropriate figure (Figure 3.9.a-1 through 3.9.a-9, as applicable), based on cycle-specific SFP Background Heat Load Margin determined by TSR 3.9.a.2. This shall be changed to read: Verify the reactor subcritical 113 hours by confirming the date and time of subcriticality; OR Verify the reactor subcritical 50.33 hours by confirming the date and time of subcriticality AND verify the point described by the number of assemblies offloaded and the time after shutdown is within the Acceptable Regions of the appropriate figure (figure 3.9.a- I through 3.9.a-9, as applicable), based on cycle-specific SFP Background Heat Load Margin determined by TSR 3.9.a.2. Figures 3.9.a-1 through 3.9.a-9, for SFP Background Heat Load Margins of4l METUThr through 49 MBTU/hr respectively, will be replaced with new figures. To implement EC 395574 and the proposed TRM changes various station procedures will also be revised to reflect the new ICDT limits and the changes for determining the SFP Background Heat Load Margin.

50.59 REVIEW COVERSHEET FORM LS-AA-l04-lOOl Revision 3 Page 2 of 4 StatioWUnit(s): yLon/Units I and 2 Activity/Document Number: EC 395574. Technical Requirements Manual fTRM) Change 14-004 Revision Numbers: 0/NA

Title:

REVISE ANALYSIS BYRJO-136 AND TRM 3.9.A CURVES FOR MUR (ICDT) Reason for Activity: (Discuss why the proposed activity is being performed.) Analysis performed for the increase in operating power associated with the Measurement Uncertainty Recapture (MUR) Power Uprate for Byron Units I and 2, restilted in revised acceptable regions for the TRM 3.9.a Figures. The Spent Fuel Pool Background Heat Load Analysis for TRM 3.9.a also identified that for future conditions where old assemblies currently in the spent fuel pool are moved to dry cask storage and then are replaced with assemblies operated at the higher MUR power level, the current unrestricted 100 hour ICDT limit needs to be increased to 113 hours. Additionally the MUR evaluation for in-mast sipping identified that the earliest offload time that maintains the in-mast sipping tool thermal-hydraulic margin with assembles operated at the higher MUR power level is 50 hottrs and 20 minutes (50.33 houts). This new earliest offload time limit is more restrictive than the current 48 hour limit that supports the Fuel Handling Accident Dose Analysis assumptions. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UPSAR.) The proposed activity will allow starting fuel offloading activities as early as 50.33 hours. If offload begins this early, the UFSAR allowed maximum transfer rate of 8 assemblies per hour is acceptable; however the decay heat load margin limit will ultimately restrict the offload rate as the number of assemblies offloaded increases. The analysis for TRM 3.9.a also identified Ihat for future conditions where old assemblies currently in the spent fuel pool are moved to dry cask storage and then are replaced with assemblies operated at the higher MUR power level, the current unrestricted tOO hour ICDT limit needs to be increased to 113 hours. This change in the TRM only impacts the time refueling can start for conditions where the background heat load is not determined or if the offload surveillance is not performed. The revision in the earliest allowed offload time from 48 hours to 50.33 hours maintains the in-mast sipping tool thermal hydraulic margin. The decay heat from the offloaded fuel assembly heats up the coolant in the handling tool mast which could cause boiling in the fuel in the mast during movement or sipping. for the MUR uprated power level, the decay heat produced within the offloaded fuel assembly will be greater relative to the pre-MUR power level. To maintain margins to the DNB and bulk boiling limits ftiel must remain in the reactor core for at least 50 hours and 20 minutes after shutdown. No changes to the UFSAR are required for this change. UFSAR Section 9.1.4.2.2 (as revised by DRP 14-066 for MIJR) reflects the in-mast sipping tool ICDT limit of 50.33 hours. UFSAR Section 9. t .3.1 already describes that outage speci tic evaluations may be performed in support of shorter fciel decay times in the reactor, by taking credit for existing margin in the design basis analysis. Summary of Conclusion for the Activitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) The proposed TRM changes are associated with the required in core decay time (ICDT) prior to movement of irradiated fuel. The proposed TRM changes do not change the frequency of occurrence of a fuel handling accident because the proposed change does not increase the failure rate of refueling equipment or increase the risk of a fuel handling accident due to human error. The total number of fuel assemblies to be transferred remains the same. Spent fuel handling equipment and tools are not changed, nor are the method/procedures used for handling spent fuel assemblies. The refueling machine can accommodate the IvIUR heat load of the revised earliest time for fuel movement of 50.33 hours. The proposed change does not change the design and use of the fuel transfer equipment or the Spent Fuel Pool (SFP) cooling

50.59 REVIEW COVERSHEET FORM LS-AA-104-l00I Revision 3 Page 3 of 4 Station/Unit(s): Byron/Units I and 2 Activity/Document Number: EC 395574, Technical Reguirements Manual (TRM) Change 14-t)04 Revision Numbers: 0/NA

Title:

REVISE ANALYSIS BYR1O-136 AND TRM 3.9.A CURVES FOR MUR (ICDT) equipment. Byron calculation BYRIO-l36 Revision I was completed to evaluate the impact of higher heat input to the SFP associated with the Measurement Uncertainty Recapture (MUR) uprate. The revised TRM times and Background Heat Load Margin ICDT curves provide limits for the start of the offload ann/or the number of assemblies that may be offloaded after shutdown to remain within the design parameters of the SFP cooling system. Thus, the likelihood of occurrence of a malfunction of the SFP cooling system is tinchanged. Westinghouse analysis, NF-CB- 13-101, evaluated the impact of the higher MUR power level (decay heat) on the in-mast sipping toot. The evaluation determined that with the higher MUR power level, the fuel must remain in the core 50 hotirs and 20 minutes after shutdown to maintain the current analysis margins. The proposed TRM change includes the revised 50.33 hour limit for the earliest time to move fuel. The maximum UFSAR fuel transfer rate (8 assemblies per hour) is not being changed. As described in UFSAR Section 15.7.4, Fuel Handling Accidents (FHA) have been analyzed for both recently irradiated fuel (i.e. fuel that has occupied part of the reactor core within the previous 48 hours) and assuming that 48 hours has passed from shutdown to the beginning of fuel operation. Additional compensatory measures apply to movement of fuel that has occupied part of the reactor core within the previous 48 hours. The proposed TRM change requires the reactor to be stibcritical for greater than or equal to 50.33 hours prior to fuel movement, thus the incore decay times used in the fl-IA analyses remain bounding. The TRIvI change does not impact the required minimum water depths in the spent fuel pool or the refueling cavity. The proposed change does not impact any equipment used to mitigate a poslulated fciel handling accident. Thus the proposed TRM changes do not impact the consequences of postulated fuel handling accidents. The design basis for preventing criticality outside the reactor is not adversely affected. The SF1 criticality analysis uses a pool temperature of 4°C (39.2°F) and a negative reactivity coefficient. Using the temperature of maximum possible water density (i.e., 4°C); therefore, assures that the true SFP reactivity will always be lower than the calculated value regardless of temperature. The fuel storage rack design is not changed. Therefore, the proposed TRM change will have no impact the spent fuel pool criticality analysis. Criticality during fuel handling operations is prevented by the geomeirically safe configuration of the fuel handling equipment and the boric acid concentration in the water in all filled portions of the RCS, the refiteling canal, and the refueling cavity, that are hydraulically coupled to the reactor core. The proposed TRM change does not impact the configuration of the fuel handling equipment or the required boric acid concentration of the water. The proposed TRIvI change does not introduce the possibility of a change in the consequence of a malfunction because the change in required ICDT prior to movement of irradiated fuel is not an initiator of any new malfunctions and no new failure modes are introduced. The proposed change does not involve any physical alteration of the plant or the procedures used in response to postulated malfunctions of $SCs important to safety. The revised TRM times and Background Heat Load Margin ICDT curves provide limits for the start of the offload and/or the number of assemblies that may be offloaded after shutdown to remain within the design parameters of the SF1 cooling system. The proposed change does not involve any physical alteration of the plant. No new equipment is being introduced and no installed equipment is being operated in a new or different manner. The proposed change does not affect the operating capability of the fuel handling equipment since the maximum UFSAR fuel transfer rate (8 assemblies per hour) is not being changed. The current maximum UFSAR fuel transfer rate is administratively controlled. The maximum number of offloaded fuel assemblies as a function of time after shutdown is also administratively controlled. Until the point determined by the number of fuel assemblies offloaded and the time after shutdown moves into Acceptable Region II on the applicable TRM figure, the number of assemblies in the SFP will be determined prior to moving each fuel assembly out of containment. Therefore, it is concluded that the proposed change does not create the possibility of an accident of a different type than any previously evaluated in the UFSAR. The proposed change only affects the required time that the spent fuel assemblies must remain in the reactor vessel before being moved from the reactor core into the SFP. There will be no changes to the fuel handling equipment. The SF1 temperature resulting from the full core fuel transfer has been evaluated in Byron Calculation BYRIO-136 to be below the design limits for the SFPCS equipment provided that the fuel transfer does not start prior to 50.33 hours, with the total number of fuel assemblies offloaded based on total heat load and time after shutdown. Therefore, the proposed

50.59 REVIEW COVERSHEET FORM LS-AA-l04-l00l Revision 3 Page 4 of 4 Station/Unit(s): Byron/Units I and 2 Activity/Document Number: EC 395574, Technical Requirements Manual (TRM) Change 14-004 Revision Numbers: 0/NA

Title:

REVISE ANALYSIS BYR1O-136 AND TRM 3.9.A CURVES FOR MUR (ICDT) activity does not create a possibility for a malfunction of an SSC important to safety with a different result than any previously evaluated in the UFSAR. The fIssion product barriers potentially affected by this change ate the fuel clad and the reactor containment. The proposed TRM change associated with the required incore decay time (ICDT) for movement of irradiated fuel does not result in a change to the internal containment pressure that would represent a challenge to the containment design basis limit of 50 psig. Byron calculation BYR 10-136 evaluates the number of fuel assemblies that may be placed in the SFP without exceeding the SFP Background Heat Load Margin. Thus the changes have no impact on the calculated maximum bulk spent fuel pool temperature. The analysis also verified the maximum calculated local water temperature, the maximum calculated cladding temperature, and the acttial maximum clad heat flux fDNB) remain acceptable, with the total number of fuel assemblies offloaded based on total heat load and time after shutdown. The revision in the earliest time for fuel movement maintains the margin to DNB in the in-mast sipping tool. Therefore, no design basis limit for a fission product barrier as described in the UFSAR is being exceeded or altered. The changes made by this activity represent changes in input parameters to the design basis analysis. Decay heat input to the SFP was calculated using the method described in NRC Branch Technical Position ASB 9-2. This is the same method used in the analysis for the existing TRM curves and is described in the NRC Safety Evaluation tor the B/B Spent fuel Storage Racks, UFSAR Section 9.1.3 states that NUREG-0800, Branch Technical Position ASB 9-2, is titilized to compute the heat dissipation requirements in the pool. Therefore, this activity does not result in a departure from a method of evaluation described in the UFSAR used in establishing the design bases or safety analyses. Since all the Evaluation questions have been answered No, this activity does not require NRC review and approval. This activity may be implemented per the applicable governing procedures. Attachments: Attach all 50.59 Review forms completed, as appropriate. Forms Attached: (Check all that apply.) Applicability Review 50.59 Screening 50.59 Screening No. Rev. X 50.59 Evaluation 50.59 Evaluation No. 6G-14-002 Rev. 0

5U.5 REVIEW COVENSUEET FURM *nwin Revision 4 Page 1 f 3 Slcdesltlnft(i): tvr Units 1 aa1 2 AedvftvIDoemntit Nuseher DO? CV-12. DRP 15.110 IRevlsion Numbes: 21.0 T1de ESTABLISHING A NITROGEN BLANKET ON ThENOLUME COWEROL TANK (VCfl NOTE: for 50.59 EvaFi*thns, information on this form will provide the besis for preparing the biennial summary report submitted to the NRC in accordance with the requiremnnla of 10 CFR 50.59fd)(2). Description of Activity: (Provide a brief concise description of what the proposed activity involves.) The proposed change to SOP CV-] 2 will allow nitrogen to be placed on the Vokunc Coarol Tank (VCT) within 3 boors of the Reactor Shutdown (Mode 3 Entry). T prerequisite for the reactor to be Idown will be changed to allow nitrogen to be placed on the VCT 3 hoiua prior to Reactor Shutdown. UFSAR Section 93.4116, Cold Shutdown VCT Oporatian will be updated to reflect the allowance Laplace nitrogen on the VCT 3 hears prior to Reactor Sbmdown (Mode 3) by DRP 15-110. Reason for Acthity (Discuss why die proposed activity is being porformed.) Allowing the nitrogen blanket to be placed on the VCr pnor to shutdown will reduce critical path dialog an outage. Effect of Adivity; (Discuss bow the activity impacts plant opcrntions, dwign bases, oi safety analyses described in the UFSAL) By placing nitrogen on the VCr prior to shutdown, Reactor Coolant Syatom (RCS) Chemistry will be affected. The dissolved by&ogen in the RCS will be reduced and die nitrogen becomes a dissolved gas that is tramported to the RCS. LWSAR Section 9.3.4 sod 5.2.12.1 dsnua RCS hamisfty. Dissolved hydrogen is employed to cautrol and scavenge oxygen produced due to rediolysin of wntu in the core region. Sufficient partial presume of hydrogen is minrid in die vohnne control teak such that the specified equilibritmi concentration ofhydrogen is mnnd in die menctor coolant A uv controller a in the vapor space of the volume control teak. Ths valve can be adjusted to provide die desired hydrogen concentration (25 to 50cc h3áogrn at Si? per kilogram of water). By placing nitrogen on the VCT prior to shutdown, the hydrogen concentration in the RCS is expected to be lees then the desired concentration (25 to 50 ccikgj at some point prior to Tractor shutdown. As a result dissolved oxygen may increase hut is not expected to chull.sige the TRM 3.4.b, RCS Chemistry, lim Uuumrnry of Cemdudou for the Activity. 50.59 Revlew (Provide justification for the conclusion, including nfflfit detail to recognize and imdorseand the essential arguments leg to the oouclicm. Provide mere thea a simple sWa.it that a 50.59 Scree.bg 50.59 Evaluation, or a Ticeuse Ame,dnIerd Request, as applicable, is not required.) Saiirsniag Review Sunmiy

1. Screening Question 1 was answered yes since the replacing hydrogen with nitrogen an the cover gas on the VCf will adversely affect RCS rh,misuy as described in Cbiphu 9.3.4.

2. Sctaenng Question 2 wan also answered since the replacing hydrogen with nitrogen an the cover gas on the VCT will adversely act how the VCT described fisuction is pdued daring normal plant aperationa.

3. The eJnge does not impact, revise or replace any analysis methodology that is used in estebhhng the design base. or used in the safety analyses since this activity does not affect any gn basis analysis.

4. The rhange does not involve a now or experiment The VCT is dgud to utilize hydrogen or nitrogen in the gas space. Dining Model, RCS chmitry is expected to be within normal operation parameters. As part of the ihnMrwn, the is cooled such that Tavg is less than 250F where corrosion is not a concern. Therefore, this activity does not involve a test or experiment not described in the UFSAR, whore the VCT is utilized or controlled ins m*nr that is outside the 1Le boi of the heiign for the VCf or is incnnsistint with analyse. or descriptions in the UFSAL

5. The ECCS (3.52 and 3.5.2), Bcmu Dilution Pmevicc (33.9) and Refueling Operation Technical Specifications 3.9.1 and 3.92 were reviewed. The rducal specification sod bases do not discuss the gas in the volume control tank nor credit the cover gas or cover gas presamnc for any functions. Based on the review ofthe Technical Specifications, allowing nitrogen to be placed on the VCT 3 home prior to shutdown doe. not require a Tedemical Specification Change.

54.59 kEVIEW CVERSHEET FRM Revision 4 Page2of3 StsIloriIUal$(s): Utd 1 and 2 Acdvtty/Documsnt N.mber 80? CV-12. DRP 15-110 RevIsion Nnmbee 21.0 flde ESTABliSHING ANflROGEN BLANKET ON THE VOLUME C0ROL TANK (VCT) Evaluation Qusutions. I. Placing a nitrogen blanket on the Volume Control Tank (VCF) 3 hours prior to a reactor shutdown will not increase the frequency of occurrence of an accident previously evaluated itrthe tJFSAR because RCS chemisby is expected to remain within the ThM limits in Mode I. Eventually the RCS dimolved hydrogen is expected to decrease below 15 cc/kg during the slundown, howevor at Ike same time the RCS teniorire is decreasing to a level U which RCS cesronon is not a coecern. Thuthre, the likelihood of adverse effts to RCS piping integrity is considered negligible mid the frequency of ocmacc of a RCS piping failure is not increased. The Chemical Food and Volume Control System (CVCS) preemnee and tampuranues am not expected to change such that the frequency of a CV line break outside of cO,drIt,wwt in not changed.

2. Placing a nitrogen blank on the Volume Control Tank (VCT) 3 hours prior to a reactor 1utown will not result in than a nimmnt increase in the likelihood ofoccurrence ofa realfuietitm of an SSC important to safety previously evaluated in the UFSAR becKne RCS chemistry is expected to ramais within the ThM limits in Model. Eventually the RCS dissolved hydrogen in expected to deanmo below 15 cc/kg during the shutdown, however at the same time the RCS in decreaaig to a level at which RCS corrosion in ns4 a concrtn. RCS ammonia concentrations are expected to remain below I ppm which is within normal operating parameter. and will net adversely affect the CVCS The nitrogen concentration in the RCS is net to be at a level that would remit in any signi&ant gas voiding.

Plant psoedmcs rcquhe venting of the RCS heed prior to decreasing the pressurizer level to less thea 5% such te would be an effect on Reactor Vessel level 4oa Nitrogen accoumlatisu in the RCP seals is riot a coecem since seal ngection will be nmntRfned. Eaceasive nitrogen in the prumuiner steam space would to lessen the ect ofsprays dining shutdown C%arden), howmcr, the effect ofintroducing additional nitrogen into Ike pressurizer is *imil,,t to that enperlamed during the nrrrmt practice of placing nitrogen on eke V just Sulbwisg reactor shutdown. In addition, the premurI space sample line is maintained on purge to the aociunttin of gases in the steam space. Ass result, the effect nitrogen in the pressurizer steam space is cossidsasd

3. 1 VCT will be operated within normal presmac range. No new failure modes have been created. Therefore, the system integrity will act be c 1Inged such that ECC leakage wruJd be expected to increase. No other accident mitigating features are affcted by the proposed change. Thucfocn, placing a nitrogen blanket on die Volume Control Tank (VCI) 3 hows prior to a xor sb,hkiwn will u6 remit in wise than a ,ninmRI increase in the consequences of as accident previously evaluated in the UPSAL

4. Placing a nitrogen hIket on the Volume Control Tank (VCI) 3 harm prior to a ruactor shutdown does nec introduce the possibility of a change in the consequences of a malfunction basame placing nitrogen on the VCT prior to___

will net be the niitev of any new ma1fuaons and no ew failure wodsa am crcatcd because CVCS operating pammeters, pressures and tempuhos am expected to remain the e. The VCT is digad to have nitrogen in the gas space. Given the system preaneres and empaC am expected to remain the same, the comequcuces of ECCS lltge following any accident am net increased. Thusfnie, placing a nitrogen blanket on die Volume Control Task (VCI) 3 harm prior to a reac shutdown will not result in more than a imniI inwcasc in the consequences of a malfunction of an SSC important to safety previously avaluated in the UFSAR.

5. IJFSAR Table 93-5 was seviawad and na new failure suede. am aadrmd crsdibls cnmpaed to the existing failure modes disoussed. Failure of Small Lines Candug Primary Coolant Outside Co,iinmmt is already reviewed in Chapter 15.62. Thfoue, placing a nitrogen blanket on the Volume Control Tank (id) 3 hows prior to a reactor hurdnwn does ant introduce the possibility ofa new accident because the placing nitrogen on the VCT prior to shutdown 1. not en initiator of any accident and no new faihue modes are introduced. Therefore, there is no increase in the possibility of an accident ofa differaut type than is already analyzed in the UFSAK

6. UFSAR Table 93-5 was reviewed mel no new failure modes am considered credible. Therefore, placing a nitrogen blanket on the Volume Control Tank (VCT) 3 hours prior to a reactor shutdown does not introduce the possibility for a malfmction of an SSC with a diff4 result because there am no new failure modes created.

5(.59 kEVIEW C()VEkSHEET FUkM CS-AA-104-I0Ol Revision 4 Page 3 of 3 Stxdon!UaI$(s): L Usr 1 and 2 Acdvfty/Documont Number: BOFCV-12. DRP 15-110 vfsiou Number: 21.0 Tithe ESTABlISHING A NITROGEN 3LAiJKEf ON ThE VOLUME CONTROL TANK (VCfl

7. Placing a nitrogen blanket on the Volume Control Tank (VC1) 3 bows prior to a renctor shutdown does not affect the Fuel C1414ng. RCS Boundary or the Cont1nn Presawe limits. No change in oridiTing coaditiona or fuel cnid is OxIk4tcd prior to unit ofiliuc. Therefore, the effect on fuel cladding taq,uattare is coneidesed negligible. 1efore placing a mixogen blanket on the Volume Control Tank (VCE) 3 bows prior to a reactor shutdown does act result in a

design basis limit for a fission product barrier as described in the UFSAR being exceeded or Itered.

8. The assumptions and methods used in the plant accident analyses ore not affected by placing a nitrogen blanket on the Vol Control Tank (VCI) 3 hews prior to a raac shutdown. The evaluation methodology utilized in accid analysis is not affected by this change. The method ofevaluation of RCS chemistry is not described in the UFSAR.

Therefore, the proposed activity does not zrh ins dopartwe from a hod of evaluation described in the UFSAR used in establishing the design bases or in the safety analyses. Attach all 50.59 Review forum compteted, as appropriate. Forum M*ebedi (Check all that apply.) D AppllcabWty Review 0 50.59 Scruenlug 50.59 Screening No. 6D-14-021 Rev. 0 0 50.59 Eviluado. 5059 Evaluado. No. 6G-14-004 Rev. 0 See LS-AA- 104, Section 5, Documentation, fur record retention requirements for this aed all other 50.59 forms associated with the Activity.

50.59REVIEWCOVERSHEET F()IM LS-AA-104-1001 Revision 4 Page 1 of4 StatlonlUnlt(s): ..jijfe4 ttaiaj42jrrn Units I and 2 Activity/Document Number W 15.107. 3975S9. EC 399325. EC 399326. EC 396144 RevIsion Number: 0.0.0.0.0

Title:

hnolonentaicn otWCAP. 15)63-P. A. RevI*qn 1.wlh Errsts.Westi,buse I mnroved PerfOrmanceAn S1va and Deslan Model (PAD 4,01. pad WCAJj4 a CENPD 403-P-A *u,,2A.Westinahouse Clad Corrosion Model tor ZIRLO sad itImIrdZflJAP NOTh For 50.59 Evaluations, information on this form will provide the basis for preparing the biennial summary report submitted to the NRC in accordance with the requirements of 10 CFR 50.59(d12). Description of Activity: (Provide a bnef, concise description of what the proposed activity involves.) The activity is the Implementation of the Nudeac Regu l*ory Commission (NRC) approved Westinghouse Improved Performance Analysis and Design Model (PA D4.0) as described In WCAP-15063J-A, Rtvton 1, wIth Errata, Westinghouse Improved Performance Analysis id Design Model (PA D4.0), .hly, 2000; Implementation ot as updated NRC approved Integral Form ZIRW CJ*ldlng Corrosion Model as described In Westinghouse WCA P.12610-P-A & C ENPD4O4.P-A Addendum 2-A, Westinghouse Clad Corrosion l4hdel tar ZIRW *,d Optimized ZIRW, October 2013; and the accompanying UFSA Rchanges to sections 1.6 and 4.2. The Westinghouse PAD model Is a best estimate fuel rod performance model used tot both fuel rod performasce analysis and safety analysis Input. The PAD code consists otseverfud rod performasce models integrated to predict fuel temperature, rod pressure, fission gas release, cladding elastic and plastic bebwior, cladding growfh, daddln:gcornnion, tud dens1flcadon, asd fuel swelling U a function of linear power and lime. PA D4.0 Introduces a new creep model to be used lathe overall PAD fuel rod performance modeL Th new creep model accounts for ith*nces In the understanding of in- reactor creep and represents a description of In-reactor creep relative to the information asd data that Is mrs liable. WCAP.15063.P-A, RevisIon 1, with Errata describes PAD 4.0 and is intended tor use In Westinghouse fuel design methodologies for Pressurized Water Reactors (PWRs). The results from the Improved PAD 4.0 model are more consistent with in- reactor expeden Ce using a mechanistic approach. The N lD concluded that the use of PAD 4.0 is acceptable for fuel llcenslngapplicatlons up to rod average burnup of 62,000 1flVD/MTU. The fuel rod average bumup for all Braldwood end Byron units Is limited to 60,000 MWWMTU per NF.AP-1 004000, WesdngbousexSSS Reload Design Control hoplamentadon. PAD 4.0 has been reviewed by the NRC Md has been approved tot use In Westinghouse fuel rod design analyses on atorwacd fit basis Within the limitations and conditions described In the Safety Evalnadon Report (SER). The new Integral Form Zi RL asd Optimized Z1L*LO I*gh brformasce Fuel Cladding Me tin Cladding Corrosion Model was developed based on an Lmpmvemeat In the concept of the modified fuel duty Index and has Incorporated all the ZIRLO and Optimized ZIKUYdaddng corrosion mesewed oxide thkkaess dats. The newmodel more accurately reflects the temperature profile In the boiling region reIred to predict the measured oxides. Th, new model rep laces the cladding co rrtdon model as described In WCAP-15063- PA, RevisIon 1, with Errita. WCAP-t2610-P.A & CENPD4O4-P-A Addendum 2-A presents the new corrosion model, and Is intended tor use In Westinghouse fuel design methodologies for Pressurized Water Reactors (PWR4 The cladding corrosion criterion adopted with the new Wes*bghosse claddIng corrosion model ensures that cladding EMchanical properties Capable ot retaining cladding Integrity under operational conditions are malnblasd. The Integral form ZIRW and Optimized ZIRW cladding corrosIon model has been reviewed by theNRC md has been approved for use In Westhighouse fuel rod design asalyses on a forward fit basis within the lImItations and conditions described in the Safety Evaluation Report (SER). Reason for Activity: (Discuss why the proposed activity is being performed.) The current UFSAR sections 1.6 and 4.2 Include a reference to PAD 33/3.4. The revision to PAD 4.0 mes several changes to the model. Tb results from the Improved PAD 4.0 model are more consistent with In-reactor experience usIng a mechbtic approach. Tb model chasges are to the cladding creep, cladding Irradiation growth, Zr-4 asd ZIRLO dad thermal conductivity, Zr-oxide thermal conductivity, Equation Of State (EOS) gas pressure,the oxide-metal

5ft59 REVEE W COVERSHEET FORM LS-AA- 104-1001 Revision 4 Page 2 of4 Station/Unit(s): Braktwood Units I and 2. Byron Units land 2 Activity/Document Number: DRP 15-107. EC 397549. EC 399325. EC 399326. EC 396144 RevisIon Number: 0.0.0.0.0

Title:

ImzftmeetsthR otw C.P- I 5063-?- A. Revision t.w lb Errsta.W estinsk.useimw,vcd Pertormce Ah%Is and Deslas MoeI (PAD 4.0). and WCAP- 12610-P- A & CENPD.404 4ri4jm Z*.Westhehousc Clad Corrosion Model tar ZIRW and Ontimized ZIRLO ratio, and Zt4 dad gas dsorpdon models. While the form of the pp conductance atad Fission Gas Release (FGR) models have not changed, the coefficients and uncertainties for these models have changed. The current ZIRLO corrosion model, asdescribed In UFS4Rsecdon 42, in basedon a model that was originsily developed tot zircaloy4 cladding. As utilities moved to Increased fuel thermal duty asaodated fth higher peeking factor, up raced core power, and longer cycle length, cladding corrosion has become one of the Impo Ftust tactors In assessing the potential to achieve these goals The rate of corrosion could eventually determine the fuel rod lifetime. The Weslingbo use corrosion model was developed to predict bes(-esd*e values for the observed data of ZlRW and Opthalzed ZTRLO cladding over a lacge rangeof ope radng conditions. The UFSAR revisions to sections 1.6 and 4.2 ace required to ensure the correct PAD version d corrosion model are described. Effect of Activity: (Discuss how the activity impacts plant operations, design bases, or safety analyses described in the UFSAR.) The m eth.ds describing the PAD version d corrosion modeling in the UFSAR have been revised or replaced as outlined in WCAP-1506.3-P-A, RevisIon 1, with Errata aad WCAP-12610-P-A and C PD-4O4-P-A Addendum 2-A. The Westinghouse PAD model is a best estimate fuel rod performasce model used for both fUel rod performance asatysis and safety asalysis Input. The PAD code consists ot several fuel rod performance models Integrated to predict fuel temperature, rod pressure, fisiba pa release, cladding elastic and plastic behavior, cladding growth, cladding corrosion, fuel densificadon, andtud swelling as atUncdoa oflineac power asd time. The results from the ImprovedPAD 4.0 model are more consistent with In-reactor experience using a mechanistic approach. Therefore, there is no Impact as a result ot Implementing PAD 4.0. The corrosion models are mod to account tot the fuel rod clad o zidadon and hydriding design criteria for ZI RLO cladding. There is no Impact to plast operations as a result of Implemaiting the new corrosion model. The new corrosion model results documented in Westinghouse csiculadon notes CN-CC19305 (Brdwood Unit 1) md CN-C819429 (Byron Unit 2) show that clad corrosion design limits tor the associated units are met. Thin check is completed for every reloadandduetothenatureotthecoredesignkisexpected that Byronsnd baldwoodunltswlllbavealmllar macgin. Based on a review of the LThA R acd Input from N F-CB-14-I 09, the Byron and Brakiwood UFSARsectlons 1.6 and 42 will be updated to Incorporate PAD 4.0 and the new corrosloamodeL TheUFSAR section 15.6 reference to WCAP 12610 de with steady-state ZW cladding oxidation that Is not Impacted by the revised corrosion model. No satety an1yses (Chapter 15) were required to be re-performed nsa result of Implementing PAD 4.0 nid the new corrosion model. This change is not outside the bounds of WCAP-9272-P-A, stlnghouse Reload Safety Evaluation Methodology, therefore the limits ad a&ytlc1 methods disciased within Techniosi Specifications Section 5.6.5 aw not luspactedas a result of Implementing PAD 4.0 atid the new corrosion model in WCAP 15063-P-A, Revision 1, wIth Errata, and WCAP-12610-P-A *sd CENPD-404-P-A Addendum 2-A.

50.59 REVIEWCOVERSHEET FoRM LS.AA-104-lOOl Revision 4 Page 3 of 4 Station/Unit(s): Braidwood Units I and 2. Byron Umts I and 2 Activity/Document Number: DRP 15-107. CC 397549. EC 399325. EC 399326. EC 396144 Revision Number: 0.0.0.0.0

Title:

imoltmentatI ofWCAP-i. 5063-P-A. Revinon l.withrratLWestlnebouse Improved PnlQrmaflCeAnIlWIS and Deslan Model (PAD 4.0). and WCAP426IO-P-A & CENPD-404-P-A Addendum 2-A. 9*esdnahouae Clad Corrosion Model for ZIRLO and Ontimbed ZIRLO Summ y of Conclusion for the ActIvitys 50.59 Review: (Provide justification for the conclusion, including sufficient detail to recognize and understand the essential arguments leading to the conclusion. Provide more than a simple statement that a 50.59 Screening, 50.59 Evaluation, or a License Amendment Request, as applicable, is not required.) PAD4.0, described In WCAP-15063.P-A, Revision I, with Erra, has been approved by the NRC. The result; from the improved PAD4.0 model are moieconslstent with ln-retor experience using SmechanIstkapproh. The NRC has accepted these changes based on the teuItS baring been evaluated to be conservative or emen t1ty the same. T1 NRC concludes th the use ot PAD 40 is kceptable tot fuel licensing applbc*lons up to rod average burnup of 62,000 MWD/MTLL The ftI rod average bunwp tot #1 Bra Idod d Byron unlt is limited to 60,000MW DMTU per NF AP-100-7000. Utilization of PAD 4.0 does constitute a deVattte from a method ot evaluation described In the UFS AR however, sines It is used within the limits d constraint; of the SEll, It does not require NRC approval prior to Its use tSA Rsecdoni 1.6 and 4.2 need to be updated to reference this new corrosion modeL The corrosion model described In VCAP-126 10-P-A and CEN PD404-P-A Addendum 2-A han been qproved by the N . Both Byron and Braidwood units meet the limitations and conditions otsectlon 5.0 ot the NRC SER for implementation of tile new corrosion model for ZIRLO and Optimized ZIRLO drddlng, UFSAR section 42 needs to be u pded to reference this new corrosion model. The new clad corrosion model does not constitute a departure tram a method of evaluadon described in the LSA limed In establishing the design bases or In the safety analyses, and thus does not recIre NRC q,pmval prior to its use. Th attached 50.59 ScreenIng concludes that the proposed arthity does not involve a change to an SSC that adversely affect; an UFSAR described design (unction (Question 1), nor does It involve a test or experiment not described In the UFSA Rwhere an SSC is utilized or controlled In a manner than is outsid. the reference bounds of th edestgn tar than SSC or In a manner that is Inconsistent with the analyses or descriptions In the UISAR (Question 4) or require a ChMge to the Technical Specificanions or Facility Op. r*Iag License (Question 5). The proposed Activity does not Involve ithaie to

• procedure than adversely affect; how U FSAR described design functions are performed or controlled (Question 2).

UFSAR Sections 1.6 and 42 cu rreqjy cout;Ia references to an outdmed version ot PAD, which is a code used to provide I nldaltherm4 CofldIdOos(fud centerline and volume avertg*temperutures) and rod premnres for the start of the LOCA analysis. Since the Implementation of PAD 4.0 involves dmnghi an evaluation method described In the UFSAR, and the Implementation of the new dad corrosion model involves a change to an element of an UFSAR described methodolOgy, bqft at these changes are considered adverse and require further review In a IOCFRSO.59 Evalumlon. The tached 50.59 Eva luqion concluded that the PAD 4.0 model and the new dad corrosion model have been ipproved by the NRC for use on atoiward fit basis, within the constraints described In the associated SERa. Since thefbel rod arere burnup tor all Brnldwood and Byron Units Is limited to 60,000 MM)/MTU, WCAP-15063- P.A, RevIsion 1, wIth Crrata is accep t*le for implemeirtanion at Byron and B tdwood Stanlons. WCAP-12610- P-A and CIFD-404P-A Addendum 2-A is accept*Ie for all 5rdWOOd and Byron Units since the new dad corrosion model baibeen ipproved by the NRCfor Westinghouse NSSS plants that use ZIRLO for their cladding m*erial with consideFanlon of the conditions as described In section 5.0 of the SER.. Additionally, TechnIcal Spedflcation changes are not required since the Byron and aIdwood Technical Specification section 5.6.5 does not contain:: the corrosion model relmed topical report. Tile PA D4.0 and the new corrosion model top led reports do not define the technical basis tor a Core Operating Lnlts Report (COLR) limIt. No other Instances of reference to the topical report occurred within the Byron and Brddwood Technical Specifications.

5O59 REVIEW COVERSHEET FoRM Ls-AA-104-lO0l Revision 4 Page4of4 Station/Unit(s): Mraldwood Units I and 2. Byron Units 1 and 2 Activity/Document Number II) RP 15107. EC 397549. EC 399325. EC 39932k EC 396144 RevIsion Number 0.0.0.0.0

Title:

Imnkmentatloa oCWCAP-15063-P-A. RevisIon 1. with Errata. Wesdn1house ImDroved hrformance Analysis and Desien Model (PAD 4.0k and WCAP. 12l0-PA & CEN?D414-P.A Addendum 2.A. Westinehouse Clad Corrosion Model for ZIRW and Oadmbed ZIRLO Attachments: Attach all 50.59 Review forms completed, as appmpnate. Forms Attached: (Check all that apply.) 1] ApplIcability Review 50.59 Screening 50.59 ScreenIng No. BRW-S-2014-119 Rev. 0

                                                                    /6E-14492                            0 0       50.59 Evaluation           50.59 Evaluation No. BRW-E-2014-120               Rev. 0
                                                                    /6G-14403                            0 See LS-AA-104, SectionS, Documentation, for record retention requirements for this and all other 50.59 forms associated with the Activity.}}