ML15223B250

and Nine Mile Point Nuclear Station, Unit No. 2- Copy of License Amendment Nos. 313, 291, 118, and 150

ML15223B250
Person / Time
Site:	Calvert Cliffs, Nine Mile Point, Ginna
Issue date:	08/14/2015
From:	Alexander Chereskin Plant Licensing Branch 1
To:	Bryan Hanson Exelon Generation Co
Chereskin A
References
GL-08-001, TAC MF4405, TAC MF4406, TAC MF4407, TAC MF4408, TAC MF4409
Download: ML15223B250 (72)

Text

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 August 14, 2015 Mr. Bryan C. Hanson Senior Vice President Exelon Generation Company, LLC President and Chief Nuclear Officer (CNO)

Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555

SUBJECT:

CALVERT CLIFFS NUCLEAR POWER PLANT, UNIT NOS. 1AND2; RE.

GINNA NUCLEAR POWER PLANT; AND NINE MILE POINT NUCLEAR STATION, UNIT NO. 2- COPY OF LICENSE AMENDMENT NOS. 313, 291, 118, AND 150 (TAC NOS. MF4405, MF4406, MF4407, AND MF4409)

Dear Mr. Hanson:

On July 30, 2015, the Nuclear Regulatory Commission issued Amendment No. 313 to Renewed Facility Operating License No. DPR-53 for the Calvert Cliffs Nuclear Power Plant, Unit No. 1; Amendment No. 291 to Renewed Facility Operating License No. DPR-69 for the Calvert Cliffs Nuclear Power Plant, Unit No. 2; Amendment No. 118 to Renewed Facility Operating License No. DPR-18 for the R. E. Ginna Nuclear Power Plant; and Amendment No. 150 to Renewed Facility Operating License No. NPF-69 for the Nine Mile Point Nuclear Station, Unit No. 2 (Agencywide Documents Access and Management System No. ML15161A380). The amendments consist of changes to the Technical Specifications (TSs) in response to the application dated July 10, 2014, as supplemented by letter dated April 30, 2015.

The amendments revise the TSs by implementing Technical Specification Task Force Traveler 523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation." The amendments were inadvertently sent to the incorrect recipient. Enclosed please find a copy of the approved amendment.

8. Hanson Please contact me at 301-415-2549 if you have any questions.

Sincerely, Alex nder N. Chereskin, Project Manager Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-317, 50-318, 50-244, and 50-410

Enclosure:

As stated cc w/encls: Distribution via Listserv

ENCLOSURE CALVERT CLIFFS NUCLEAR POWER PLANT, UNIT NOS. 1 AND 2; R. E. GINNA NUCLEAR POWER PLANT; AND NINE MILE POINT NUCLEAR STATION, UNIT NO. 2 -

ISSUANCE OF AMENDMENTS REGARDING IMPLEMENTATION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER 523, "GENERIC LETTER 2008-01, MANAGING GAS ACCUMULATION" (TAC NOS. MF4405, MF4406, MF4407, AND MF4409)

Enclosure

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 July 30, 2015 Mr. David T. Gudger Manager - Licensing and Regulatory Affairs Exelon Generation Company, LLC Calvert Cliffs Nuclear Power Plant R. E. Ginna Nuclear Power Plant Nine Mile Point Nuclear Station 200 Exelon Way Kennett Square, PA 19348

SUBJECT:

CALVERT CLIFFS NUCLEAR POWER PLANT, UNIT NOS. 1AND2; R. E.

GINNA NUCLEAR POWER PLANT; AND NINE MILE POINT NUCLEAR STATION, UNIT NO. 2 - ISSUANCE OF AMENDMENTS REGARDING IMPLEMENTATION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER 523, "GENERIC LETTER 2008-01, MANAGING GAS ACCUMULATION" (TAC NOS. MF4405, MF4406, MF4407, AND MF4409)

Dear Mr. Gudger:

The Commission has issued the enclosed Amendment No. 313 to Renewed Facility Operating License No. DPR-53 for the Calvert Cliffs Nuclear Power Plant, Unit No. 1; Amendment No. 291 to Renewed Facility Operating License No. DPR-69 for the Calvert Cliffs Nuclear Power Plant, Unit No. 2 (CCNPP); Amendment No. 118 to Renewed Facility Operating License No. DPR-18 for the R. E. Ginna Nuclear Power Plant (Ginna); and Amendment No. 150 to Renewed Facility Operating License No. NPF-69 for the Nine Mile Point Nuclear Station, Unit No. 2 (NMP2). The amendments consist of changes to the Technical Specifications (TSs) in response to the application dated July 10, 2014, as supplemented by letter dated April 30, 2015.

The amendments revise the TSs by implementing Technical Specification Task Force Traveler 523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation." The proposed changes for CCNPP add new Surveillance Requirements (SRs) related to gas accumulation for the shutdown cooling (SOC) system, the emergency core cooling system (ECCS), and the containment spray (CS) system. The proposed changes for Ginna add new SRs related to gas accumulation for the residual heat removal (RHR) system, the ECCS, and the CS system. The proposed changes for NMP2 revise SRs related to gas accumulation for the ECCS, and reactor core isolation cooling (RCIC) system, and add new SRs related to gas accumulation for the RHR system. TS Bases changes associated with these SRs for each application would also be made.

D. Gudger A copy of the related Safety Evaluation is enclosed. A Notice of Issuance will be included in the Commission's next regular biweekly Federal Register notice.

Sincerely, Alexander N. Chereskin, Project Manager Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-317, 50-318, 50-244, and 50-410

Enclosures:

1. Amendment No. 313 to DPR-53

2. Amendment No. 291 to DPR-69

3. Amendment No. 118 to DPR-18

4. Amendment No. 150 to NPF-69

5. Safety Evaluation cc w/enclosures:

Mr. George H. Gellrich, Vice President Mr. Joseph E. Pacher, Vice President Calvert Cliffs Nuclear Power Plant R. E. Ginna Nuclear Power Plant Exelon Generation Company, LLC Exelon Generation Company, LLC 1650 Calvert Cliffs Parkway 1503 Lake Road Lusby, MD 20657-4702 Ontario, NY 14519 Mr. Peter Orphanos, Vice President Exelon Generation Company, LLC Nine Mile Point Nuclear Station, LLC P. 0. Box 63 Lycoming, NY 13093 Additional Distribution via Listserv

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE CALVERT CLIFFS NUCLEAR POWER PLANT, UNIT 1 CALVERT CLIFFS NUCLEAR POWER PLANT, LLC EXELON GENERATION COMPANY, LLC DOCKET NO. 50-317 Amendment No. 313 Renewed License No. DPR-53

1. The Nuclear Regulatory Commission (the Commission) has found that:

A. The application for amendment by Exelon Generation Company, LLC (Exelon, the licensee), dated July 10, 2015, as supplemented by letter dated April 30, 2015, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. DPR-53 is hereby amended to read as follows:

Enclosure 1

2. Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 313, are hereby incorporated into this license. The licensee shall operate the facility in accordance with the Technical Specifications.

3. This license amendment is effective as of the date of its issuance and shall be implemented within 120 days.

FOR THE NUCLEAR REGULATORY COMMISSION Michael I. Dudek, Acting Chief Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the License and Technical Specifications Date of Issuance: July 30, 2015

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE CALVERT CLIFFS NUCLEAR POWER PLANT, UNIT 2 CALVERT CLIFFS NUCLEAR POWER PLANT, LLC EXELON GENERATION COMPANY, LLC DOCKET NO. 50-318 Amendment No. 291 Renewed License No. DPR-69

1. The Nuclear Regulatory Commission (the Commission) has found that:

A. The application for amendment by Exelon Generation Company, LLC (Exelon, the licensee), dated July 10, 2015, as supplemented by letter dated April 30, 2015, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. DPR-69 is hereby amended to read as follows:

Enclosure 2

2. Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 291, are hereby incorporated into this license. The licensee shall operate the facility in accordance with the Technical Specifications.

3. This license amendment is effective as of the date of its issuance and shall be implemented within 120 days.

FOR THE NUCLEAR REGULATORY COMMISSION Michael I. Dudek, Acting Chief Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the License and Technical Specifications Date of lssuance:Jul y 30, 2015

ATTACHMENT TO LICENSE AMENDMENTS AMENDMENT NO. 313 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-53 AMENDMENT NO. 291 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-69 DOCKET NOS. 50-317 AND 50-318 Replace the following page of the Renewed Facility Operating License with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

Remove Page Insert Page 3 3 Replace the following pages of the Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Pages Insert Pages 3.4.6-3 3.4.6-3 3.4.7-3 3.4.7-3 3.4.8-2 3.4.8-2 3.5.2-2 3.5.2-2 3.5.2-3 3.5.2-3 3.6.6-3 3.6.6-3 3.6.6-4 3.6.6-4 3.9.4-3 3.9.4-3 3.9.4-4 3.9.4-4 3.9.5-4 3.9.5-4

(4) Exelon Generation pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use, in amounts as required, any byproduct, source, and special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and (5) Exelon Generation pursuant to the Act and 10 CFR Parts 30 and 70 to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C. This license is deemed to contain and is subject to the conditions set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act, and the rules, regulations, and orders of the Commission, now and hereafter applicable; and is subject to the additional conditions specified and incorporated below:

(1) Maximum Power Level Exelon Generation is authorized to operate the facility at reactor steady-state core power levels not in excess of 2737 megawatts-thermal in accordance with the conditions specified herein.

(2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 291 are hereby incorporated into this license. The licensee shall operate the facility in accordance with the Technical Specifications.

(a) For Surveillance Requirements (SRs) that are new, in Amendment 201 to Facility Operating License No. DPR-69, the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment 201. For SRs that existed prior to Amendment 201, including SRs with modified acceptance criteria and SRs whose frequency of performance is being extended, the first performance is due at the end of the first surveillance interval that begins on the date the Surveillance was last performed prior to implementation of Amendment 201.

(3) Less Than Four Pump Operation The licensee shall not operate the reactor at power levels in excess of five (5) percent of rated thermal power with less than four (4) reactor coolant pumps in operation. This condition shall remain in effect until the licensee has submitted safety analyses for less than four pump operation, and approval for such operation has been granted by the Commission by amendment of this license.

(4) Environmental Monitoring Program If harmful effects or evidence of irreversible damage are detected by the biological monitoring program, hydrological monitoring program, and the Amendment No. 291

(4) Exelon Generation pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use, in amounts as required, any byproduct, source, and special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and (5) Exelon Generation pursuant to the Act and 10 CFR Parts 30 and 70 to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C. This license is deemed to contain and is subject to the conditions set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act, and the rules, regulations, and orders of the Commission, now or hereafter applicable; and is subject to the additional conditions specified and incorporated below:

(1) Maximum Power Level Exelon Generation is authorized to operate the facility at steady-state reactor core power levels not in excess of 2737 megawatts-thermal in accordance with the conditions specified herein.

(2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 313, are hereby incorporated into this license. Exelon Generation shall operate the facility in accordance with the Technical Specifications.

(a) For Surveillance Requirements (SRs) that are new, in Amendment 227 to Facility Operating License No. DPR-53, the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment 227. For SRs that existed prior to Amendment 227, including SRs with modified acceptance criteria and SRs whose frequency of performance is being extended, the first performance is due at the end of the first surveillance interval that begins on the date the Surveillance was last performed prior to implementation of Amendment 227.

(3) Additional Conditions The Additional Conditions contained in Appendix C as revised through Amendment No. 305 are hereby incorporated into this license. Exelon Generation shall operate the facility in accordance with the Additional Conditions.

(4) Secondary Water Chemistry Monitoring Program Exelon Generation shall implement a secondary water chemistry monitoring program to inhibit steam generator tube degradation. This program shall include:

Amendment No. 313

RCS Loops - MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RCS or SOC loop is in operation. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.6.2 Verify secondary side water level in 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> required steam generator(s) is > -50 inches.

SR 3.4.6.3 Verify correct breaker alignment and 7 days indicated power available to the required loop components that are not in operation.

SR 3.4.6.4 -------------------NOTE-------------------

Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after entering MODE 4.

Verify required SOC train locations 31 days susceptible to gas accumulation are sufficiently filled with water.

CALVERT CLIFFS - UNIT 1 3.4.6-3 Amendment No. 313 CALVERT CLIFFS - UNIT 2 Amendment No. 291

RCS Loops - MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one SOC loop is in operation. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.7.2 Verify required SG secondary side water 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> level is> -50 inches.

SR 3.4.7.3 Verify correct breaker alignment and 7 days indicated power available to the required SOC loop components that are not in operation.

SR 3.4.7.4 Verify required SDC train locations 31 days susceptible to gas accumulation are sufficiently filled with water.

CALVERT CLIFFS - UNIT 1 3.4.7-3 Amendment No.

CALVERT CLIFFS - UNIT 2 Amendment No. 291

RCS Loops - MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required SOC loops B.1 Suspend operations Immediately inoperable. that would cause introduction of coolant into the RCS with boron No SOC loop in concentration less operation. than required to meet the SOM of LCO 3.1.1.

AND B.2 Initiate action to Immediately restore one SOC loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one SOC loop is in operation. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.8.2 Verify correct breaker alignment and 7 days indicated power available to the required SOC loop components that are not in operation.

SR 3.4.8.3 Verify SOC train locations susceptible to 31 days gas accumulation are sufficiently filled with water.

CALVERT CLIFFS - UNIT 1 3.4.8-2 Amendment No. 313 CALVERT CLIFFS - UNIT 2 Amendment No. 291

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> listed position with power to the valve operator removed.

Valve Number Position Function MOV-659 Open Mini-flow Isolation MOV-660 Open Mini-flow Isolation CV-306 Open Low Pressure Safety Injection Flow Control SR 3.5.2.2 -------------------NOTE-------------------

Not required to be met for system vent flow paths opened under administrative control.

Verify each ECCS manual, power-operated, and 31 days automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify each high pressure safety injection - In accordance and low pressure safety injection pump's with the developed head at the test flow point is Inservice greater than or equal to the required Testing Program developed head.

SR 3.5.2.4 Deleted CALVERT CLIFFS - UNIT 1 3.5.2-2 Amendment No. 313 CALVERT CLIFFS - UNIT 2 Amendment No. 291

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each ECCS automatic valve that is not 24 months locked, sealed, or otherwise secured in position, in the flow path actuates to the correct position on an actual or simulated actuation signal.

SR 3.5.2.6 Verify each ECCS pump starts automatically 24 months on an actual or simulated actuation signal.

SR 3.5.2.7 Verify each low pressure safety injection 24 months pump stops on an actual or simulated actuation signal.

SR 3.5.2.8 Verify, by visual inspection, each ECCS 24 months train containment sump suction inlet is not restricted by debris and the suction inlet strainers show no evidence of structural distress or abnormal corrosion.

SR 3.5.2.9 Verify the Shutdown Cooling System open- 24 months permissive interlock prevents the Shutdown Cooling System suction isolation valves from being opened with a simulated or actual Reactor Coolant System pressure signal of

~ 309 psia.

SR 3.5.2.10 Verify ECCS locations susceptible to gas 31 days accumulation are sufficiently filled with water.

CALVERT CLIFFS - UNIT 1 3.5.2-3 Amendment No. 313 CALVERT CLIFFS - UNIT 2 Amendment No. 291

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 -------------------NOTE-------------------

Not required to be met for system vent flow paths opened under administrative control.

Verify each containment spray manual, power- 31 days operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

SR 3.6.6.2 Operate each containment cooling train fan 31 days unit for ~ 15 minutes.

SR 3.6.6.3 Verify each containment cooling train 31 days cooling water flow rate is~ 2000 gpm to each fan cooler.

SR 3.6.6.4 Verify each containment spray pump's In accordance developed head at the flow test point is with the greater than .or equal to the required Inservice developed head. Testing Program SR 3.6.6.5 Verify each automatic containment spray 24 months valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.6.6 Verify each containment spray pump starts 24 months automatically on an actual or simulated actuation signal.

CALVERT CLIFFS - UNIT 1 3.6.6-3 Amendment No. 313 CALVERT CLIFFS - UNIT 2 Amendment No. 291

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6.7 Verify each containment cooling train starts 24 months automatically on an actual or simulated actuation signal.

SR 3.6.6.8 Verify each spray nozzle is unobstructed. Following maintenance that could result in nozzle blockage SR 3.6.6.9 Verify containment spray locations 31 days susceptible to gas accumulation are sufficiently filled with water.

CALVERT CLIFFS - UNIT 1 3.6.6-4 Amendment No. 313 CALVERT CLIFFS - UNIT 2 Amendment No. 291

SDC and Coolant Circulation-High Water Level 3.9.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (Continued) A.5 Close one door in 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> each air lock.

A.6.1 Close each 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> penetration providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.

A.6.2 Verify each 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> penetration is capable of being closed by an OPERABLE Containment Purge Valve Isolation System.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one SOC loop is in operation and 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> circulating reactor coolant at a flow rate of :::: 1500 gpm.

CALVERT CLIFFS - UNIT 1 3.9.4-3 Amendment No. 313 CALVERT CLIFFS - UNIT 2 Amendment No. 2S1

SOC and Coolant Circulation-High Water Level 3.9.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.9.4.2 Verify required SOC loop locations 31 days susceptible to gas accumulation are sufficiently filled with water.

CALVERT CLIFFS - UNIT 1 3.9.4-4 Amendment No. 313 CALVERT CLIFFS - UNIT 2 Amendment No. 291

SOC and Coolant Circulation-Low Water Level 3.9.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (Continued) 8.5.2 Verify each 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> penetration is capable of being closed by an OPERABLE Containment Purge Valve Isolation System.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify required SOC loops are OPERABLE and 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> one SOC loop is in operation.

SR 3.9.5.2 Verify SOC loop in operation is circulating 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> reactor coolant at a flow rate of

~ 1500 gpm.

SR 3.9.5.3 Verify correct breaker alignment and 7 days indicated power available to the required SOC loop components that are not in operation.

SR 3.9.5.4 Verify SOC loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

CALVERT CLIFFS - UNIT 1 3.9.5-4 Amendment No. 313 CALVERT CLIFFS - UNIT 2 Amendment No. 291

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 R. E. GINNA NUCLEAR POWER PLANT, LLC EXELON GENERATION COMPANY, LLC DOCKET NO. 50-244 R. E. GINNA NUCLEAR POWER PLANT AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 118 Renewed License No. DPR-18

1. The Nuclear Regulatory Commission (the Commission or the NRC) has found that A. The application for amendment by Exelon Generation Company, LLC (Exelon, the licensee), dated July 10, 2015, as supplemented by letter dated April 30, 2015, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance: (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. DPR-18 is hereby amended to read as follows:

Enclosure 3

(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 118 are hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications.

3. This license amendment is effective as of the date of its issuance and shall be implemented within 120 days.

FOR THE NUCLEAR REGULATORY COMMISSION Michael I. Dudek, Acting Chief Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the License and Technical Specifications Date of Issuance: July 30, 2015

ATTACHMENT TO LICENSE AMENDMENTS AMENDMENT NO. 118 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-18 DOCKET NO. 50-244 Replace the following page of the Renewed Facility Operating License with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

Remove Page Insert Page 3 3 Replace the following pages of the Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Pages Insert Pages 3.4.6-1 3.4.6-1 3.4.6-2 3.4.6-2 3.4.7-1 3.4.7-1 3.4.7-2 3.4.7-2 3.4.8-1 3.4.8-1 3.4.8-2 3.4.8-2 3.5.2-1 3.5.2-1 3.5.2-2 3.5.2-2 3.5.2-3 3.5.2-3 3.5.3-1 3.5.3-1 3.5.3-2 3.5.3-2 3.6.6-1 3.6.6-1 3.6.6-2 3.6.6-2 3.6.6-3 3.6.6-3 3.9.4-1 3.9.4-1 3.9.4-2 3.9.4-2 3.9.5-1 3.9.5-1 3.9.5-2 3.9.5-2

(b) Exelon Generation pursuant to the Act and 10 CFR Part 70, to possess and use four (4) mixed oxide fuel assemblies in accordance with the RG&E's application dated December 14, 1979 (transmitted by letter dated December 20. 1979). as supplemented February 20, 1980, and March 5, 1980; (3) Exelon Generation pursuant to the Act and 10 CFR Parts 30, 40, and 70 to receive, possess, and use at any time any byproduct, source, and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) Exelon Generation pursuant to the Act and 10 CFR Parts 30, 40, and 70 to receive, possess, and use in amounts as required any byproduct, source, or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and (5) Exelon Generation pursuant to the Act and 10 CFR Parts 30 and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C. This renewed license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Part 20. Section 30.34 of Part 30, Section 40.41 of Part 40, Sections 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; and is subject to all applicable provisions of the Act and rules, regulations and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified below:

(1) Maximum Power Level Exelon Generation is authorized to operate the facility at steady-state power levels up to a maximum of 1775 megawatts (thermal).

(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 118 are hereby incorporated in the renewed license.

Exelon Generation shall operate the facility in accordance with the Technical Specifications.

(3) Fire Protection (a) Exelon Generation shall implement and maintain in effect all fire protection features described in the licensee's submittals referenced in and as approved or modified by the NRC's Fire Protection Safety Evaluation (SE) dated February 14, 1979, and SE supplements dated December 17, 1980, February 6, 1981, June 22, 1981, February 27, 1985, and March 21, 1985 or configurations subsequently approved by the NRC, subject to provision (b) below.

Amendment No. 118

RCS Loops - MODE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops - MODE 4 LCO 3.4.6 Two loops consisting of any combination of RCS loops and residual heat removal (RHR) loops shall be OPERABLE, and one loop shall be in operation.

- NOTE -

1. All reactor coolant pumps (RCPs) and RHR pumps may be de-energized for s 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period provided:

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SOM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

2. No RCP shall be started with any RCS cold leg temperature less than or equal to the LTOP enable temperature specified in the PTLR unless:

a. The secondary side water temperature of each steam generator (SG) is s 50°F above each of the RCS cold leg temperatures; or

b. The pressurizer water volume is< 324 cubic feet (38% level).

APPLICABILITY: MODE 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RCS loop A.1 Initiate action to restore a Immediately inoperable. second loop to OPERABLE status.

Two RHR loops inoperable.

R.E. Ginna Nuclear Power Plant 3.4.6-1 Amendment 118

RCS Loops - MODE 4 3.4.6 CONDITION REQUIRED ACTION COMPLETION TIME B. One RHR loop ------------------

- NOTE -

inoperable. Required Action B.1 is not applicable if all RCS and AND RHR loops are inoperable and Condition C is entered.

Two RCS loops inoperable.

B.1 Be in MODE 5. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> C. All RCS and RHR loops C.1 Suspend operations that Immediately inoperable. would cause introduction of coolant into the RCS with OR boron concentration less than required to meet the No RCS or RHR loop in SDM of LCO 3.1.1.

operation.

AND C.2 Initiate action to restore one Immediately loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.6.2 Verify SG secondary side water level is ;,::: 16% for 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> each required RCS loop.

SR 3.4.6.3 Verify correct breaker alignment and indicated power 7 days are available to the required pump that is not in operation.

SR 3.4.6.4 ----------------------------N 0 TE---------------------------------- 31 days Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after entering MODE 4.

Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

R.E. Ginna Nuclear Power Plant 3.4.6-2 Amendment 118

RCS Loops - MODE 5, Loops Filled 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops - MODE 5, Loops Filled LCO 3.4.7 One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either:

a. One additional RHR loop shall be OPERABLE; or

b. The secondary side water level of at least one steam generator (SG) shall be~ 16%.

- NOTE -

1. The RHR pump of the loop in operation may be de-energized for

<:; 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period provided:

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SOM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

2. One required RHR loop may be inoperable for:<:; 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

3. No reactor coolant pump shall be started with one or more RCS cold leg temperatures less than or equal to the LTOP enable temperature specified in the PTLR unless:

a. The secondary side water temperature of each SG is :<:; 50°F above each of the RCS cold leg temperatures; or

b. The pressurizer water volume is < 324 cubic feet (38% level).

4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

APPLICABILITY: MODE 5 with RCS loops filled.

R.E. Ginna Nuclear Power Plant 3.4.7-1 Amendment ll8

RCS Loops - MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop A.1 Initiate action to restore a Immediately inoperable. second RHR loop to OPERABLE status.

AND OR Both SGs secondary side water levels not within A.2 Initiate action to restore Immediately limits. required SG secondary side water levels to within limits.

B. Both RHR loops B.1 Suspend operations that Immediately inoperable. would cause introduction of coolant into the RCS with OR boron concentration less than required to meet the No RHR loop in SOM of LCO 3.1.1.

operation.

AND B.2 Initiate action to restore one Immediately RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.7.2 Verify SG secondary side water level is ;:: 16% in the 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> required SG.

SR 3.4.7.3 Verify correct breaker alignment and indicated power 7 days are available to the required RHR pump that is not in operation.

SR 3.4.7.4 Verify required RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

R.E. Ginna Nuclear Power Plant 3.4.7-2 Amendment 118

RCS Loops - MODE 5, Loops Not Filled 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Loops - MODE 5, Loops Not Filled LCO 3.4.8 Two residual heat removal (RHR) loops shall be OPERABLE and one RHR loop shall be in operation.

- NOTE-

1. All RHR pumps may be de-energized for s 15 minutes when switching from one loop to another provided:

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature; and

c. No draining operations to further reduce the RCS water volume are permitted.

2. One RHR loop may be inoperable for s 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

APPLICABILITY: MODE 5 with RCS loops not filled.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop A.1 Initiate action to restore Immediately inoperable. RHR loop to OPERABLE status.

R.E. Ginna Nuclear Power Plant 3.4.8-1 Amendment 118

RCS Loops - MODE 5, Loops Not Filled 3.4.8 CONDITION REQUIRED ACTION COMPLETION TIME B. Both RHR loops 8.1 Suspend operations that Immediately inoperable. would cause introduction of coolant into the RCS with boron concentration less than required to meet the No RHR loop in SDM of LCO 3.1.1.

operation.

AND 8.2 Initiate action to restore one Immediately RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.4.8.2 Verify correct breaker alignment and indicated power 7 days are available to the RHR pump that is not in operation.

SR 3.4.8.3 Verify RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

R.E. Ginna Nuclear Power Plant 3.4.8-2 Amendment 1.18

ECCS - MODES 1, 2, and 3 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS - MODES 1, 2, and 3 LCO 3.5.2 Two ECCS trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

- NOTE -

1. In MODE 3, both safety injection (SI) pump flow paths may be isolated by closing the isolation valves for up to 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> to perform pressure isolation valve testing per SR 3.4.14.1. Power may be restored to motor operated isolation valves 878B and 878D for up to 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> for the purpose of testing per SR 3.4.14.1 provided that power is restored to only one valve at a time.

2. Operation in MODE 3 with ECCS pumps declared inoperable pursuant to LCO 3.4.12, "Low Temperature Overpressure Protection (LTOP) System," is allowed for up to 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> or until the temperature of both RCS cold legs exceeds 375°F, whichever comes first.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One train inoperable. A.1 Restore train to OPERABLE 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> status.

AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> C. Two trains inoperable. C.1 Enter LCO 3.0.3 Immediately R.E. Ginna Nuclear Power Plant 3.5.2-1 Amendment 118

ECCS - MODES 1, 2, and 3 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> Number Position Function 825A Open RWST Suction to SI Pumps 825B Open RWST Suction to SI Pumps 826A Closed BAST Suction to SI Pumps 826B Closed BAST Suction to SI Pumps 826C Closed BAST Suction to SI Pumps 8260 Closed BAST Suction to SI Pumps 851A Open Sump B to RHR Pumps 851B Open Sump B to RHR Pumps 856 Open RWST Suction to RHR Pumps 878A Closed SI Injection to RCS Hot Leg 878B Open SI Injection to RCS Cold Leg 878C Closed SI Injection to RCS Hot Leg 8780 Open SI Injection to RCS Cold Leg 896A Open RWST Suction to SI and Containment Spray 896B Open RWST Suction to SI and Containment Spray SR 3.5.2.2 -------------------------N 0 TE------------------------------------------ 31 days Not required to be met for system vent flow paths opened under administrative control.

Verify each ECCS manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

R.E. Ginna Nuclear Power Plant 3.5.2-2 Amendment 118

ECCS - MODES 1, 2, and 3 3.5.2 SURVEILLANCE FREQUENCY SR 3.5.2.3 Verify each breaker or key switch, as applicable, for each 31 days valve listed in SR 3.5.2.1, is in the correct position.

SR 3.5.2.4 Verify each ECCS pump's developed head at the test flow In accordance point is greater than or equal to the required developed with the head. lnservice Testing Program SR 3.5.2.5 Verify each ECCS automatic valve in the flow path that is 24 months not locked, sealed, or otherwise secured in position actuates to the correct position on an actual or simulated actuation signal.

SR 3.5.2.6 Verify each ECCS pump starts automatically on an actual 24 months or simulated actuation signal.

SR 3.5.2.7 Verify, by visual inspection, each RHR containment sump 24 months suction inlet is not restricted by debris and the containment sump screen shows no evidence of structural distress or abnormal corrosion.

SR 3.5.2.8 Verify ECCS locations susceptible to gas accumulation 31 days are sufficiently filled with water.

R.E. Ginna Nuclear Power Plant 3.5.2-3 Amendment 118

ECCS- MODE 4 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS - MODE 4 LCO 3.5.3 One ECCS train shall be OPERABLE.

APPLICABILITY: MODE 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS residual A.1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable. subsystem to OPERABLE status.

B. Required ECCS Safety B.1 Injection (SI) subsystem inoperable.

- NOTE -

LCO 3.0.4.b is not applicable.

Restore required ECCS SI 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 5. 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> associated Completion Time of Condition B not met.

R.E. Ginna Nuclear Power Plant 3.5.3-1 Amendment 118

ECCS- MODE 4 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 - NOTE -

An RHR train may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned to the ECCS mode of operation.

SR 3.5.2.4 and SR 3.5.2.8 are applicable for all In accordance with equipment required to be OPERABLE. applicable SR R.E. Ginna Nuclear Power Plant 3.5.3-2 Amendment 118

CS, CRFC, and NaOH Systems 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray (CS), Containment Recirculation Fan Cooler (CRFC), and NaOH Systems LCO 3.6.6 Two CS trains, four CRFC units, and the NaOH system shall be OPERABLE.

- NOTE -

In MODE 4, both CS pumps may be in pull-stop for up to 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> for the performance of interlock and valve testing of motor operated valves (MOVs) 857A, 857B, and 857C. Power may also be restored to MOVs 896A and 896B, and the valves placed in the closed position, for up to 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> for the purpose of each test.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CS train inoperable. A.1 Restore CS train to 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> OPERABLE status.

B. NaOH system inoperable. B.1 Restore NaOH System to 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> associated Completion Time of Condition A or B AND not met.

C.2 Be in MODE 5. 84 hours3.5 days <br />0.5 weeks <br />0.115 months <br /> D. One or two CRFC units D.1 Restore CRFC unit(s) to 7 days inoperable. OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> associated Completion Time of Condition D not AND met.

E.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> R.E. Ginna Nuclear Power Plant 3.6.6-1 Amendment 118

CS, CRFC, and NaOH Systems 3.6.6 CONDITION REQUIRED ACTION COMPLETION TIME F. Two CS trains inoperable. F.1 Enter LCO 3.0.3. Immediately Three or more CRFC units inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Perform SR 3.5.2.1 and SR 3.5.2.3 for valves 896A In accordance with and 8968. applicable SRs.

SR 3.6.6.2 -------------------------N 0 TE------------------------------------- 31 days Not required to be met for system vent flow paths opened under administrative control.

Verify each CS manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

SR 3.6.6.3 Verify each NaOH System manual, power operated, 31 days and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

SR 3.6.6.4 Operate each CRFC unit for ~ 15 minutes. 31 days SR 3.6.6.5 Verify cooling water flow through each CRFC unit. 31 days SR 3.6.6.6 Verify each CS pump's developed head at the flow In accordance with test point is greater than or equal to the required the lnservice developed head. Testing Program SR 3.6.6.7 Verify NaOH System solution volume is ~ 3000 gal. 184 days SR 3.6.6.8 Verify NaOH System tank NaOH solution 184 days concentration is ~ 30% and :<:;; 35% by weight.

SR 3.6.6.9 Perform required CRFC unit testing in accordance In accordance with with the VFTP. the VFTP R.E. Ginna Nuclear Power Plant 3.6.6-2 Amendment 118

CS, CRFC, and NaOH Systems 3.6.6 SURVEILLANCE FREQUENCY SR 3.6.6.10 Verify each automatic CS valve in the flow path that is 24 months not locked, sealed, or otherwise secured in position actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.6.11 Verify each CS pump starts automatically on an actual 24 months or simulated actuation signal.

SR 3.6.6.12 Verify each CRFC unit starts automatically on an 24 months actual or simulated actuation signal.

SR 3.6.6.13 Verify each automatic NaOH System valve in the flow 24 months path that is not locked, sealed, or otherwise secured in position actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.6.14 Verify spray additive flow through each eductor path. 5 years SR 3.6.6.15 Verify each spray nozzle is unobstructed. Following maintenance which could result in nozzle blockage SR 3.6.6.16 Verify CS locations susceptible to gas accumulation 31 days are sufficiently filled with water.

R.E. Ginna Nuclear Power Plant 3.6.6-3 Amendment 118

3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Residual Heat Removal (RHR) and Coolant Circulation - Water Level 2 23 Ft LCO 3.9.4 One RHR loop shall be OPERABLE and in operation.

- NOTE -

The required RHR loop may be removed from operation for~ 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period, provided no operations are permitted that would cause introduction of coolant into the Reactor Coolant System (RCS) with boron concentration less than that required to meet the minimum required boron concentration of LCO 3.9.1 .

APPLICABILITY: MODE 6 with the water level 2 23 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RHR loop requirements A.1 Suspend operations that Immediately not met. would cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

A.2 Suspend loading irradiated Immediately fuel assemblies in the core.

A.3 Initiate action to satisfy RHR Immediately loop requirements.

R.E. Ginna Nuclear Power Plant 3.9.4-1 Amendment 118

3.9.4 CONDITION REQUIRED ACTION COMPLETION TIME A.4 Close all containment 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one RHR loop is in operation and circulating 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> reactor coolant.

SR 3.9.4.2 Verify required RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

R.E. Ginna Nuclear Power Plant 3.9.4-2 Amendment 118

RHR and Coolant Circulation - Water Level < 23 Ft 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation - Water Level < 23 Ft LCO 3.9.5 Two RHR loops shall be OPERABLE, and one RHR loop shall be in operation.

APPLICABILITY: MODE 6 with the water level< 23 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Less than the required A.1 Initiate action to restore Immediately number of RHR loops RHR loop(s) to OPERABLE OPERABLE. status.

OR A.2 Initiate action to establish Immediately

~ 23 ft of water above the top of reactor vessel flange.

B. No RHR loop in B.1 Suspend operations that Immediately operation. would cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

AND B.2 Initiate action to restore one Immediately RHR loop to operation.

AND B.3 Close all containment 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> penetrations providing direct access from containment to outside atmosphere.

R.E. Ginna Nuclear Power Plant 3.9.5-1 Amendment 118

RHR and Coolant Circulation - Water Level < 23 Ft 3.9.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> reactor coolant.

SR 3.9.5.2 Verify correct breaker alignment and indicated power 7 days available to the required RHR pump that is not in operation.

SR 3.9.5.3 Verify RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

R.E. Ginna Nuclear Power Plant 3.9.5-2 Amendment 118

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 NINE MILE POINT NUCLEAR STATION. LLC EXELON GENERATION COMPANY. LLC DOCKET NO. 50-410 NINE MILE POINT NUCLEAR STATION. UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 150 Renewed License No. NPF-69

1. The U.S. Nuclear Regulatory Commission (the Commission) has found that:

A. The application for amendment by Exelon Generation Company, LLC (Exelon, the licensee), dated July 10, 2015, as supplemented by letters dated April 30, 2015, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's rules and regulations set forth in 10 CFR Chapter I;

8. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment 1s in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.2 of Renewed Facility Operating License No. NPF-69 is hereby amended to read as follows:

Enclosure 4

(2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, as revised through Amendment No. 150, are hereby incorporated into this license.

Exelon Generation Company, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3. This license amendment is effective as of the date of its issuance and shall be implemented within 120 days.

FOR THE NUCLEAR REGULATORY COMMISSION Michael I. Dudek, Acting Chief Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the License and Technical Specifications Date of Issuance: July 30, 2015

ATTACHMENT TO LICENSE AMENDMENTS AMENDMENT NO. 150 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-69 DOCKET NO. 50-410 Replace the following page of the Renewed Facility Operating License with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

Remove Page Insert Page 4 4 Replace the following pages of the Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Pages Insert Pages 3.4.9-3 3.4.9-3 3.4.10-2 3.4.10-2 3.5.1-4 3.5.1-4 3.5.2-3 3.5.2-3 3.5.3-2 3.5.3-2 3.6.2.3-2 3.6.2.3-2 3.6.2.4-2 3.6.2.4-2 3.9.8-3 3.9.8-3 3.9.9-3 3.9.9-3

(1) Maximum Power Level Exelon Generation is authorized to operate the facility at reactor core power levels not in excess of 3988 megawatts thermal (100 percent rated power) in accordance with the conditions specified herein.

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix 8, both of which are attached hereto, as revised through Amendment No. 150 are hereby incorporated into this license. Exelon Generation shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3) Fuel Storage and Handling (Section 9.1, SSER 4)*

a. Fuel assemblies, when stored in their shipping containers, shall be stacked no more than three containers high.

b. When not in the reactor vessel, no more than three fuel assemblies shall be allowed outside of their shipping containers or storage racks in the New Fuel Vault or Spent Fuel Storage Facility.

c. The above three fuel assemblies shall maintain a minimum edge-to-edge spacing of twelve (12) inches from the shipping container array and approved storage rack locations.

d. The New Fuel Storage Vault shall have no more than ten fresh fuel assemblies uncovered at any one time.

(4) Turbine System Maintenance Program (Section 3.5.1.3.10, SER)

The operating licensee shall submit for NRC approval by October 31, 1989, a turbine system maintenance program based on the manufacturer's calculations of missile generation probabilities.

(Submitted by NMPC letter dated October 30, 1989 from C.D. Terry and approved by NRC letter dated March 15, 1990 from Robert Martin to Mr. Lawrence Burkhardt, Ill).

The parenthetical notation following the title of many license conditions denotes the section of the Safety Evaluation Report (SER) and/or its supplements wherein the license condition is discussed.

Renewed License No. NPF-69 Amendment 117through 140, 141, 143, 144, 145, 146, 147, 150

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 --------------------------- N 0 TE ----------------------------

Not required to be met until 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> after reactor steam dome pressure is less than the RHR cut-in permissive pressure.

Verify one RHR shutdown cooling subsystem 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> or recirculation pump is operating.

SR 3.4.9.2 --------------------------- NO TE ----------------------------

Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after reactor steam dome pressure is less than the RHR cut-in permissive pressure.

Verify RHR shutdown cooling subsystem 31 days Locations susceptible to gas accumulation are sufficiently filled with water.

NMP2 3.4.9-3 Amendment 150

RHR Shutdown Cooling System - Cold Shutdown 3.4.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR shutdown B.1 Verify reactor 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from cooling subsystem in coolant circulating discovery of no operation. by an alternate reactor coolant method. circulation No recirculation pump in operation. Once per 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> thereafter AND B.2 Monitor reactor Once per hour coolant temperature and pressure.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify one RHR shutdown cooling subsystem 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> or recirculation pump is operating.

SR 3.4.10.2 Verify RHR shutdown cooling subsystem 31 days locations susceptible to gas accumulation are sufficiently filled with water.

NMP2 3.4.10-2 Amendment 150

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray 31 days subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

SR 3.5.1.2 --------------------------- NOTE ----------------------------

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat removal cut-in permissive pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable.

---

N 0 TE ----------------------------

Not required to be met for system vent paths opened under administrative control.

Verify each ECCS injection/spray subsystem 31 days manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.1.3 Verify: 31 days

a. For each ADS nitrogen receiver discharge header, the pressure is:::: 160 psig; and

b. For each ADS nitrogen receiver tank, the pressure is :::: 334 psig.

(continued)

NMP2 3.5.1-4 Amendment 150

ECCS - Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for the required High Pressure Core 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> Spray (HPCS) System, the:

a. Suppression pool water level is

195 ft; or

b. Condensate storage tank B water level is;::: 26.9 ft.

SR 3.5.2.3 Verify, for each required ECCS injection/ 31 days spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

SR 3.5.2.4 ---------------------------- N 0 TE---------------------------------

0 ne low pressure coolant injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned and not otherwise inoperable.

---

N0 TE --------------------------------

Not required to be met for system vent flow paths opened under administrative control.

Verify each required ECCS injection/spray 31 days subsystem manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

(continued)

NMP2 3.5.2-3 Amendment 150

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System locations susceptible to 31 days gas accumulations are sufficiently filled with water.

SR 3.5.3.2 ----------------------------N 0 TE -----------------------------

Not required to be met for system vent flow paths opened under administrative control.

Verify each RCIC System manual, power 31 days operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.3.3 --------------------------- N0 TE ----------------------------

Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify, with reactor pressure :5 1035 psig 92 days and<:: 935 psig, the RCIC pump can develop a flow rate <:: 600 gpm against a system head corresponding to reactor pressure.

SR 3.5.3.4 --------------------------- N 0 TE ----------------------------

Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify, with reactor pressure :5 165 psig, 24 months the RCIC pump can develop a flow rate

<:: 600 gpm against a system head corresponding to reactor pressure.

(continued)

NMP2 3.5.3-2 Amendment 150

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling 31 days subsystem manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position.

SR 3.6.2.3.2 Verify each required RHR pump develops a In accordance flow rate::::: 7450 gpm through the with the associated heat exchanger while operating lnservice in the suppression pool cooling mode. Testing Program SR 3.6.2.3.3 Verify RHR suppression pool cooling subsystem 31 days locations susceptible to gas accumulation are sufficiently filled with water NMP2 3.6.2.3-2 Amendment 150

RHR Suppression Pool Spray 3.6.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.4.1 Verify each RHR suppression pool spray 31 days subsystem manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position.

SR 3.6.2.4.2 Verify each required RHR pump develops a In accordance flow rate ~ 450 gpm while operating in with the the suppression pool spray mode. lnservice Testing Program SR 3.6.2.4.3 Verify RHR suppression pool spray subsystem 31 days locations susceptible to gas accumulation are sufficiently filled with water NMP2 3.6.2.4-2 Amendment 150

RHR- High Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> is operating.

SR 3.9.8.2 Verify required RHR shutdown cooling subsystem 31 days locations susceptible to gas accumulation are sufficiently filled with water NMP2 3.9.8-3 Amendment 150

RHR - Low Water Level 3.9.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.9.1 Verify one RHR shutdown cooling subsystem 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> is operating.

SR 3.9.9.2 Verify RHR shutdown cooling subsystem locations 31 days susceptible to gas accumulation are sufficiently filled with water NMP2 3.9.9-3 Amendment 150

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 313 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-53, AMENDMENT NO. 291 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-69, AMENDMENT NO. 118 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-18, AMENDMENT NO. 150 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-69 EXELON GENERATION COMPANY, LLC CALVERT CLIFFS NUCLEAR POWER PLANT, UNIT NOS. 1 AND 2 R. E. GINNA NUCLEAR POWER PLANT NINE MILE POINT NUCLEAR STATION, UNIT NO. 2 DOCKET NOS. 50-317, 50-318, 50-244, AND 50-410

1.0 INTRODUCTION

By application dated July 10, 2014 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML14191A255), as supplemented by letter dated April 30, 2015 (ADAMS Accession No. ML15120A284), Exelon Generation Company, LLC (the licensee),

requested changes to the Technical Specifications (TSs) for Calvert Cliffs Nuclear Power Plant, Unit Nos. 1 and 2 (CCNPP), RE. Ginna Nuclear Power Plant (Ginna), and Nine Mile Point Nuclear Station, Unit No. 2 (NMP2). The supplement dated April 30, 2015, provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the staff's original proposed no significant hazards consideration determination as published in the Federal Register (FR) on May 12, 2015 (80 FR 27197).

Specifically, the licensee requested to adopt U.S. Nuclear Regulatory Commission (NRC)-approved Technical Specifications Task Force (TSTF) Standard Technical Specifications (STS) Change Traveler TSTF-523, Revision 2 (TSTF-523), "Generic Letter [GL] 2008-01, Managing Gas Accumulation," (ADAMS Accession No. ML13053A075) dated February 21, 2013. The availability of this TS improvement was announced in the FR on January 15, 2014 (79 FR 2700), as part of the consolidated line item improvement process.

Enclosure 5

The proposed changes for CCNPP would add new Surveillance Requirements (SRs) related to gas accumulation for the shutdown cooling (SOC) system, the emergency core cooling system (ECCS), and the containment spray (CS) system. The proposed changes for Ginna would add new SRs related to gas accumulation for the residual heat removal (RHR) system, the ECCS, and the CS system. The proposed changes for NMP2 would revise SRs related to gas accumulation for the ECCS, and reactor core isolation cooling (RCIC) system, and would add new SRs related to gas accumulation for the RHR system. The proposed changes to the TS bases for each plant were included in the application for informational purposes.

The licensee stated that it has reviewed the information contained in the model safety evaluation dated December 23, 2013 (ADAMS Accession No. ML13255A169), and the license amendment request (LAR) is consistent with NRG-approved TSTF-523.

2.0 REGULATORY EVALUATION

2.1 Background Gas accumulation in reactor systems can result in water hammer, pump cavitation, and pumping of non-condensable gas into the reactor vessel. These effects may result in the subject system being unable to perform its specified safety function. The NRC issued GL 2008-01, "Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems," in January 2008 to address the issue of gas accumulation in the ECCS, decay heat removal (OHR), and CS systems (ADAMS Accession No. ML072910759). The industry and NRC staff agreed that a change to the STS and plant-specific TS would be necessary to address some issues discussed in GL 2008-01. The TSTF-523 contains changes to the TS SRs and TS Bases to address some of the concerns in GL 2008-01.

The licensee proposed amending the CCNPP, Ginna, and NMP2 TSs using a plant-specific adoption of the TSTF-523 changes.

2.2 Technical Specification Changes The proposed changes for CCNPP include revisions to SRs 3.5.2.2 and 3.6.6.1, and the addition of new SRs 3.4.6.4, 3.4.7.4, 3.4.8.3, 3.5.2.10, 3.6.6.9, 3.9.4.2, and 3.9.5.4 to TS 3.4.6, "RCS Loops - MODE 4," TS 3.4. 7, "RCS Loops - MODE 5, Loops Filled," TS 3.4.8, "RCS Loops

- MODE 5, Loops Not Filled," TS 3.5.2, "ECCS - Operating," TS 3.6.6, "Containment Spray and Cooling Systems," TS 3.9.4, "SOC and Coolant Circulation - High Water Level," and TS 3.9.5, "SOC and Coolant Circulation - Low Water Level," respectively.

The proposed changes for Ginna include revisions to SRs 3.5.2.2, 3.5.3.1, 3.6.6.2, and the addition of new SRs 3.4.6.4, 3.4.7.4, 3.4.8.3, 3.5.2.8, 3.6.6.16, 3.9.4.2, and 3.9.5.3 to TS 3.4.6, "RCS Loops - MODE 4," TS 3.4.7, "RCS Loops - MODE 5, Loops Filled," TS 3.4.8, "RCS Loops MODE 5, Loops Not Filled," TS 3.5.2, "ECCS - MODES 1, 2, and 3," TS 3.5.3, "ECCS -

MODE 4," TS 3.6.6, "CS, CRFC, and NaOH Systems," TS 3.9.4, "RHR and Coolant Circulation

- Water Level<::: 23 Ft," and TS 3.9.5, "RHR and Coolant Circulation - Water Level< 23 Ft,"

respectively.

The proposed changes for NMP2 include revisions to SRs 3.5.1.1, 3.5.1.2, 3.5.2.3, 3.5.2.4, 3.5.3.1, and 3.5.3.2, and the addition of new SRs 3.4.9.2, 3.4.10.2, 3.6.2.3.3, 3.6.2.4.3, 3.9.8.2, and 3.9.9.2 to TS 3.4.9, "RHR Shutdown Cooling System - Hot Shutdown," TS 3.4.10, "RHR

Shutdown Cooling System - Cold Shutdown," TS 3.5.1, "ECCS - Operating," TS 3.5.2, "ECCS

- Shutdown," TS 3.5.3, "RCIC System," TS 3.6.2.3, "RHR Suppression Pool Cooling,"

TS 3.6.2.4, "RHR Suppression Pool Spray," TS 3.9.8, "RHR - High Water Level," and TS 3.9.9, "RHR- Low Water Level," respectively.

2.3 Regulatory Review The regulations in Appendix A to Title 10 of the Code of Federal Regulations (1 O CFR) Part 50, or similar plant-specific principal design criteria, provide design requirements. Appendix B to 10 CFR Part 50, the TSs, and the licensee quality assurance programs provide operating requirements. The regulatory requirements of Appendix A to 10 CFR Part 50 applicable to gas management in the subject systems include General Design Criteria (GDC) 1, 34, 35, 36, 37, 38, 39, and 40. Regulations in GDC 1 require that the subject systems be designed, fabricated, erected, and tested to quality standards. Also, GDC 34 requires an RHR system designed to maintain specified acceptable fuel design limits and to meet design conditions that are not exceeded if a single failure occurs and specified electrical power systems fail. Regulations in GDC 35, 36, and 37 require an ECCS design that meets performance, inspection, and testing requirements. Additionally, the regulations in 10 CFR 50.46 provide specified ECCS performance criteria. Regulations in GDC 38, 39, and 40 require a containment heat removal (CHR) system design that meets performance, inspection, and testing requirements.

The construction permits for CCNPP were issued by the Atomic Energy Commission (AEC) on July 7, 1969, and the operating licenses were issued on July 31, 1974, for Unit No. 1, and August 13, 1976, for Unit No. 2. The AEC published the final rule that added 10 CFR Part 50, Appendix A, "General Design Criteria for Nuclear Power Plants," in the FR (36 FR 3255) on February 20, 1971, with the rule becoming effective on May 21, 1971. As stated in SECY 223, dated September 18, 1992, the Commission decided not to apply the Appendix A GDC to plants with construction permits issued prior to May 21, 1971. The CCNPP updated final safety analysis report (UFSAR), Revision 47, dated September 19, 2014, states that the plant was designed and constructed to meet the intent of the GDC published in July 1967. The plant's GDC are discussed in the UFSAR, Appendix 1C, "AEC Proposed General Design Criteria for Nuclear Power Plants."

Ginna was initially licensed to meet the design criteria from the Atomic Industrial Forum issued for comment by the AEC in 1967. As such, a review of the Ginna plant-specific requirements was performed against the requirements in the current Appendix A to 10 CFR Part 50. From this review, the NRC staff determined that the two sets of requirements are sufficiently similar, as related to the proposed change, so as not to warrant a separate discussion of the Ginna plant-specific requirements. Therefore, the remaining discussions pertaining to Appendix A to 10 CFR Part 50 in this safety evaluation are assumed to be applicable to the CCNPP and Ginna design criteria.

Quality assurance criteria provided in Appendix B to 10 CFR Part 50 applicable to gas management in the subject systems include: Criteria Ill, V, XI, XVI, and XVII. Criteria Ill and V require measures to ensure that applicable regulatory requirements and the design basis, as defined in 10 CFR 50.2, "Definitions," and as specified in the license application, are correctly translated into controlled specifications, drawings, procedures, and instructions. Criterion XI requires a test program to ensure that the subject systems will perform satisfactorily while in service, and requires that test results shall be documented and evaluated to ensure that test

requirements have been satisfied. Criterion XVI requires measures to ensure that conditions adverse to quality, such as failures, malfunctions, deficiencies, deviations, defective material and equipment, and nonconformances are promptly identified and corrected. Criterion XVI requires that significant conditions adverse to quality are documented and reported to management. Criterion XVII requires maintenance of records of activities affecting quality.

The NRC's regulatory requirements related to the content of the TSs are contained in 10 CFR 50.36(c). As required by 10 CFR 50.36(c), the TSs must include items in the following categories: (1) safety limits, limiting safety systems settings, and limiting control settings; (2) LCOs [Limiting Conditions for Operation]; (3) SRs; (4) design features; and (5) administrative controls. SRs are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, facility operation will be within safety limits, and LCOs will be met. Typically, TS Section 5 requires that licensees establish, implement, and maintain written procedures covering the applicable procedures recommended in Appendix A to Regulatory Guide (RG) 1.33, "Quality Assurance Program Requirements (Operation)." Appendix A to RG 1.33 identifies instructions for filling and venting the ECCS and OHR systems, as well as for draining and refilling heat exchangers. STSs and most licensee TSs include SRs to verify that at least some of the subject systems' piping is filled with water.

The NRC's guidance for the format and content of licensee TSs, with respect to CCNPP, can be found in NUREG-1432, "Standard Technical Specifications Combustion Engineering Plants."

The NRC's guidance for the format and content of licensee TSs, with respect to Ginna, can be found in NUREG-1431, "Standard Technical Specifications Westinghouse Plants." The NRC's guidance for the format and content of licensee TSs, with respect to NMP2, can be found in both NUREG-1433, "Standard Technical Specifications General Electric BWR/4 Plants," and NUREG-1434, "Standard Technical Specifications General Electric BWR/6 Plants."

The NRC staff recognizes that NUREG-0800, "Standard Review Plan [SRP] for the Review of Safety Analysis Reports for Nuclear Power Plants: LWR Edition," is not the regulatory basis of the proposed TSs changes, and that the licensee is not required to confirm that the SRP guidance is applicable to CCNPP, Ginna, or NMP2.

Regulatory guidance for the NRC staff's review of CHR systems, ECCS, and RHR systems is provided in the following revisions and sections of the SRP:

• Revision 3 of the SRP, Section 6.2.2, "Containment Heat Removal Systems," dated March 2007 (ADAMS Accession No. ML070160661) provides the procedures concerning the review of CHR systems under post-accident conditions to help ensure compliance with GDC 38, 39, and 40.

• Revision 3 of the SRP, Section 6.3, "Emergency Core Cooling System," dated March 2007 (ADAMS Accession No. ML070550068) provides the procedures concerning the review of ECCS to help ensure compliance with GDC 35, 36, and 37.

• Revision 5 of the SRP, Section 5.4.7, "Residual Heat Removal (RHR) System," dated May 201 O (ADAMS Accession Number ML100680577) provides the procedures concerning the review of RHR systems used to cool the Reactor Coolant System (RCS) during and following shutdown, to help ensure compliance with GDC 34.

3.0 TECHNICAL EVALUATION

3.1 CCNPP TS Changes The licensee proposed the following TS changes for CCNPP:

(1) Add SR 3.4.6.4, which states, Verify required SOC train locations susceptible to gas accumulation are sufficiently filled with water.

With a note that states:

Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after entering MODE 4.

And a frequency of 31 days.

(2) Add SR 3.4.7.4, which states, Verify required SOC train locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(3) Add SR 3.4.8.3, which states, Verify SOC train locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(4) Add a note to SR 3.5.2.2, which states, Not required to be met for system vent flow paths opened under administrative control.

(5) Add SR 3.5.2.10, which states, Verify ECCS locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(6) Add a note to SR 3.6.6.1, which states, Not required to be met for system vent flow paths opened under administrative control.

(7) Add SR 3.6.6.9, which states,

Verify containment spray locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(8) Add SR 3.9.4.2, which states, Verify required SOC loop locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(9) Add SR 3.9.5.4, which states, Verify SOC loop locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

The NRC staff evaluated the licensee's proposed change for CCNPP against the applicable regulatory guidance in the STS, as modified by TSTF-523. The staff also compared the proposed changes to the existing SRs, as well as the regulatory requirements of 10 CFR 50.36.

The staff determined that the proposed change adopted the TS format and content, to the extent practicable, contained in the changes made to NUREG-1432, "Standard Technical Specifications Combustion Engineering Plants," by TSTF-523.

3.2 Ginna TS Changes The licensee proposed the following TS changes for Ginna:

(1) Add SR 3.4.6.4, which states, Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

With a note that states:

Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after entering MODE 4.

And a frequency of 31 days.

(2) Add SR 3.4.7.4, which states, Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(3) Add SR 3.4.8.3, which states Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(4) Add a note to SR 3.5.2.2, which states, Not required to be met for system vent flow paths opened under administrative control.

(5) Add SR 3.5.2.8, which states, Verify ECCS locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(6) Revise the language for SR 3.5.3.1, from SR 3.5.2.4 is applicable for all equipment required to be OPERABLE.

to:

SR 3.5.2.4 and SR 3.5.2.8 are applicable for all equipment required to be OPERABLE.

(7) Add a note to SR 3.6.6.2, which states, Not required to be met for system vent flow paths opened under administrative control.

(8) Add SR 3.6.6.16, which states, Verify CS locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(9) Add SR 3.9.4.2, which states, Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(10) Add SR 3.9.5.3, which states,

Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

The NRG staff evaluated the licensee's proposed change for Ginna against the applicable regulatory guidance in the STS, as modified by TSTF-523. The staff also compared the proposed changes to the existing SRs, as well as the regulatory requirements of 10 CFR 50.36.

The staff determined that the proposed changes adopted the TS format and content, to the extent practicable, contained in the changes made to NUREG-1431, "Standard Technical Specifications Westinghouse Plants," by TSTF-523.

3.3 NMP2 TS Changes The licensee proposed the following TS changes for NMP2:

(1) Add SR 3.4.9.2, which states, Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

With a note that states:

Not required to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after reactor steam dome pressure is less than the RHR cut-in permissive pressure.

And a frequency of 31 days.

(2) Add SR 3.4.10.2, which states, Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(3) Revise the language for SR 3.5.1.1 from Verify, for each ECCS injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve.

to:

Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

(4) Add a note to SR 3.5.1.2, which states, Not required to be met for system vent flow paths opened under administrative control.

(5) Revise the language for SR 3.5.2.3 from Verify, for each ECCS injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve.

to:

Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

(6) Add a note to SR 3.5.2.4, which states, Not required to be met for system vent flow paths opened under administrative control.

(7) Revise the language for SR 3.5.3.1 from Verify the RCIC System piping is filled with water from the pump discharge valve to the injection valve.

to:

Verify the RCIC system locations susceptible to gas accumulation are sufficiently filled with water.

(8) Add a note to SR 3.5.3.2, which states, Not required to be met for system vent flow paths opened under administrative control.

(9) Add SR 3.6.2.3.3, which states, Verify RHR suppression pool cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(10) Add SR 3.6.2.4.3, which states, Verify RHR suppression pool cooling spray subsystem locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(11) Add SR 3.9.8.2, which states,

Verify required RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

(12) Add SR 3.9.9.2, which states, Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

With a frequency of 31 days.

The NRC staff evaluated the licensee's proposed change for NMP2, against the applicable regulatory guidance in the STS, as modified by TSTF-523. The staff also compared the proposed changes to the existing SRs, as well as the regulatory requirements of 10 CFR 50.36.

The staff determined that the proposed change adopted the TS format and content, to the extent practicable, contained in the changes made to NUREG-1433, "Standard Technical Specifications General Electric Plants BWR/4," by TSTF-523.

3.4 Technical Evaluation Conclusions The new language in the proposed SRs for CCNPP, Ginna, and NMP2 were developed using licensee responses to GL 2008-01, and the NRC discussion contained in Task Interface Agreement (TIA) 2008-03, "Emergency Core Cooling System (ECCS) Voiding Relative To Compliance With Surveillance Requirements (SR) 3.5.1.1, 3.5.2.3, and 3.5.3.1" (ADAMS Accession No. ML082560209). Several of the GL 2008-01 responses stated that licensees identified system locations that were susceptible to gas accumulation. In the TIA, the NRC stated that the intent of the TS SRs (which states "full of water") may be met if the licensee can establish that there is a reasonable expectation that the system in question will perform its specified safety function through an Operability Determination. Therefore, the phrase, "sufficiently filled with water" was recommended for the proposed TS changes. In the TS, "sufficiently filled with water" is understood to mean "sufficiently filled with water to support Operability." The regulation at 10 CFR 50.36(c)(3) states that one of the purposes of the SR is to verify that the LCO is met. Therefore, the NRC staff finds that the new SR language, "Verify the [system name] locations susceptible to gas accumulation are sufficiently filled with water," is acceptable since this language will allow the licensee to make a conclusion as to whether or not a system is Operable.

For NMP2, language is provided in the notes for SR 3.4.9.2 stating that the SR does not have to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after entering Mode 3 with reactor steam dome pressure less than the RHR cut-in permissive pressure. For CCNPP and Ginna, language is provided in the notes for SR 3.4.6.4 stating that the SR does not have to be performed until 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> after entering Mode 4. The NRC staff finds that the language provided for CCNPP, Ginna, and NMP2 is acceptable because the notes provide a limited time to perform the Surveillance after entering the Applicability of the LCO. As described in TSTF-523, Revision 2, during a rapid shutdown, there may be insufficient time to verify all susceptible locations in the system before entering the Applicability. A 12-hour limit to perform the surveillance requirement takes into account the time needed to perform these surveillance requirements in a controlled manner following a rapid shutdown. Also, under the STS usage rules {STS Section 1.4 ), the requirement to manage gas

accumulation is not affected. Licensees must have confidence that the SR can be met or the LCO must be declared not met.

For CCNPP, Ginna, and NMP2 the frequency for the proposed SRs is 31 days. As stated in TSTF-523, Revision 2, the 31-day frequency is based on the gradual nature of gas accumulation and the procedural controls governing system operation.

The language for the notes that allow the SRs to not be met for system vent flow paths opened under administrative control is necessary to allow the licensee to credit administratively controlled manual action to close the system vent flow path in order to maintain system Operability during system venting and performance of the proposed gas accumulation SR.

Therefore, the NRC staff finds these notes are acceptable.

The NRC staff determined that the proposed changes to the SRs for CCNPP, Ginna, and NMP2 meet the regulatory requirements of 10 CFR 50.36 because they provide assurance that the necessary quality of systems and components will be maintained and that the LCO will be met.

Therefore, the NRC staff finds the proposed changes for CCNPP, Ginna, and NMP2 acceptable.

4.0 STATE CONSULTATION

In accordance with the Commission's regulations, the Maryland and New York State officials were notified of the proposed issuance of the amendments. The State officials had no comments.

5.0 ENVIRONMENTAL CONSIDERATION

The amendments change requirements with respect to installation or use of facility components located within the restricted area as defined in 10 CFR Part 20 and changes SRs. The NRC staff has determined that the amendment involves no significant increase in the amounts, and no significant change in the types, of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission has previously issued a proposed finding that the amendment involves no significant hazards consideration, and there has been no public comment on such finding May 12, 2015 (80 FR 27197). Accordingly, the amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendment.

6.0 CONCLUSION

The Commission has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) there is reasonable assurance that such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of these amendments will not be inimical to the common defense and security or to the health and safety of the public.

7.0 REFERENCES

1. Letter to NRC Document Control Desk, Calvert Cliffs Nuclear Power Plant, Units 1 & 2, Nine Mile Point Nuclear Station, Unit 2, and R. E. Ginna Nuclear Power Plant transmitting Application to Revise Technical Specifications to Adopt TSTF-523, "Generic Letter 2008-01, Managing Gas Accumulation," using the Consolidated Line Item Improvement Process. for to add SRs related to gas accumulation for the shutdown cooling system, the emergency core cooling system, and the containment spray system, 07/10/14(ML14191A255).

2. Letter to NRC Document Control Desk, R. E. Ginna Nuclear Power Plant, transmitting Response to Request for Additional Information Regarding Proposed License Amendment to Revise Technical Specifications to Adopt TSTF-523, 04/30/15, (ML15120A284).

3. Letter to NRC Document Control Desk, Technical Specification Task Force, transmitting TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation," February 21, 2013, (ML13053A075).

4. Model Safety Evaluation for Plant-Specific Adoption of Technical Specifications Task Force Traveler TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation," "Using the Consolidated Line Item Improvement Process, 12/23/13, (ML13255A169).

5. U.S. Nuclear Regulatory Commission, "Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems (Generic Letter 2008-01 )," January 2008, (ML072910759).

6. Domestic Licensing of Production and Utilization Facilities - General Design Criteria for Nuclear Power Plants, Title 10 of the Code of Federal Regulations (10 CFR) Part 50, Appendix A.

7. Domestic Licensing of Production and Utilization Facilities - Quality Assurance Criteria for Nuclear Power Plants and Fuel Reprocessing Plants, Title 10 of the Code of Federal Regulations (10 CFR) Part 50, Appendix 8.

8. Provisional Construction Permit and for Calvert Cliffs Nuclear Power Plant, Construction Permit Nos. CPPR-63 and CPPR-64, 07/07/69, (ML010400206)

9. Facility Operating License for Calvert Cliffs Nuclear Power Plant, Unit 1, 07/31/74 (ML010400396)

10. Facility Operating License for Calvert Cliffs Nuclear Power Plant, Unit 2, 08/13/76 (ML003774209 and ML003774250)

11. Paper by Chilk, Samuel J., Secretary, Staff Requirements Memo, "SECY-92-223 -

Resolution of Deviations Identified During The Systematic Evaluation Program,"

09/18/92, (ML003763736).

12. Updated Final Safety Analysis Report ( UFSAR), for Calvert Cliffs Nuclear Power Plant, Units 1and2, 09119114 (ML14267A069).

13. The Atomic Energy Act of 1967, as Amended, Section 161A [42 United States Code (U.S.C.) §2201.a].

14. U.S. Nuclear Regulatory Commission, "Quality Assurance Program Requirements (Operation)," Regulatory Guide 1.33, ADAMS Accession No. ML13109A458.

15. Standard Technical Specifications - Combustion Engineering Plants, Revision 4.0, Volume 1 and 2, Specifications, NUREG-1432, (ML12102A165 and ML12102A169)

16. Standard Technical Specifications - Westinghouse Plants, Revision 4.0, Volume 1 and 2, Specifications, NUREG-1431, (ML12100A222 and ML12100A228).

17. Standard Technical Specifications - General Electric [Boiling Water Reactors] BWR/4 Plants, Revision 4.0, Volume 1 and 2, Specifications, NUREG-1433, (ML12104A192 and ML12104A193).

18. Standard Technical Specifications - General Electric [Boiling Water Reactors] BWR/6 Revision 4.0, Volume 1 and 2, SpecificationsNUREG-1434, (ML12104A195 and ML12104A196).

19. Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants: [Light-Water Reactors] LWR Edition, NUREG-0800.

20. Containment Heat Removal Systems, Section 6.2.2, Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants: [Light-Water Reactors]

LWR Edition, NUREG-0800, Rev. 3, March 2007 (ML070160661).

21. Emergency Core Cooling System, Section 6.3, Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants: [Light-Water Reactors] LWR Edition, NUREG-0800, Rev. 3, March 2007 (ML070550068).

22. Residual Heat Removal (RHR) System, Section 5.4. 7, Standard Review Plant for the Review of Safety Analysis Reports for Nuclear Power Plants: [Light-Water Reactors]

LWR Edition, NUREG-0800, Rev. 5., May 2010(ML100680577).

23. Emergency Core Cooling Systems (EGGS) Voiding Relative to Compliance with Surveillance Requirements (SR) 3.5.1.1, 3.5.2.3 and 3.5.3.1 (TIA 2008-03), October 21, 2008 (ML082560209).

Principal Contributor: William C. Satterfield Date:July 30, 2015

D. Gudger A copy of the related Safety Evaluation is enclosed. A Notice of Issuance will be included in the Commission's next regular biweekly Federal Register notice.

Sincerely, IRA RGuzman for/

Alexander N. Chereskin, Project Manager Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-317, 50-318, 50-244, and 50-410

Enclosures:

1. Amendment No. 313 to DPR-53

2. Amendment No. 291 to DPR-69

3. Amendment No. 118 to DPR-18

4. Amendment No. 150 to NPF-69

5. Safety Evaluation cc w/enclosures:

Mr. George H. Gellrich, Vice President Mr. Joseph E. Pacher, Vice President Calvert Cliffs Nuclear Power Plant R. E. Ginna Nuclear Power Plant Exelon Generation Company, LLC Exelon Generation Company, LLC 1650 Calvert Cliffs Parkway 1503 Lake Road Lusby, MD 20657-4702 Ontario, NY 14519 Mr. Peter Orphanos, Vice President Exelon Generation Company, LLC Nine Mile Point Nuclear Station, LLC P. 0. Box 63 Lycoming, NY 13093 Additional Distribution via Listserv DISTRIBUTION:

PUBLIC LPL 1-1 R/F RidsNrrDorlLpl 1-1 RidsNrrPMCalvertCliffs RidsNrrLAKGoldstein RidsACRS_MailCTR RidsRgn1 MailCenter RidsNrrPMREGinna RidsNrrDssStsb WSatterfield, NRR RElliott, NRR RidsNrrPMNineMilePoint MHamm, NRR CJackson, NRR AChereskin, NRR AGilbertson, NRR B. Mozafari, NRR ADAMS A ccess1on No.: ML15161A380 *b1y memo **b1y date d e-ma1*1 OFFICE DORL/LPLl-1 /PM DORL/LPLl-1/PM DORL/LPLl-1/PM DORL/LPLl-1/LA NAME AGilbertson (RGuzman for) BMozafari** KGoldstein AChereskin DATE 07/07/2015 07/06/2015 07/15/2015 07/06/2015 OFFICE DSS/STSB/BC* DSS/SRXB/BC OGC DORL/LPLl-1 /BC(A)

NAME RElliott CJackson BMizuno MDudek DATE 06/10/2015 7/15/2015 7/27/2015 7/30/2015 OFFICIAL RECORD COPY

B. Hanson Please contact me at 301-415-2549 if you have any questions.

Sincerely, IRA/

Alexander N. Chereskin, Project Manager Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-317, 50-318, 50-244, and 50-410

Enclosure:

As stated cc w/encls: Distribution via Listserv DISTRIBUTION:

PUBLIC LPLl-1 R/F RidsAcrsAcnw_MailCTR RidsNrrDorlDpr RidsNrrDorllpl1-1 RidsNrrPMCalvert Cliffs RidsNrrLAKGoldstein RidsRgn1 MailCenter ADAMS Accession No.: ML152238250 OFFICE NRR/DORL/LPU-!fPM [ NRR/DORL/LPLl-1/LA NRR/DORL/LPLl-1 /BC NAME AChereskin KGoldstein BBeasley

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DATE 8/14/2015 8/13/2015 8/14/2015

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-. ~OF-FTC1A L RECO~TI C-OPY