ML092040273

Issuance of Amendments Delete Obsolete License Conditions and Revised Technical Specifications (TAC MD9616 & MD9617)

ML092040273
Person / Time
Site:	LaSalle
Issue date:	08/27/2009
From:	Goodwin C Plant Licensing Branch III
To:	Pardee C Exelon Generation Co
Sands S,NRR/DORL, 415-3154
References
TAC MD9616, TAC MD9617
Download: ML092040273 (46)

Text

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 August 27, 2009 Mr. Charles G. Pardee President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555

SUBJECT:

LASALLE COUNTY STATION, UNITS 1 AND 2, ISSUANCE OF AMENDMENTS RE: DELETE OBSOLETE LICENSE CONDITIONS AND REVISE TECHNICAL SPECIFICATIONS (TAC NOS. MD9616 AND MD9617)

Dear Mr. Pardee:

The U.S. Nuclear Regulatory Commission (the Commission) has issued the enclosed Amendment No. 193 to Facility Operating License No. NPF-11 and Amendment No. 180 to Facility Operating License No. NPF-18 for the LaSalle County Station, Units 1 and 2, respectively. The amendments are in response to your application dated September 11, 2008 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML082550530), as supplemented by letter dated August 11, 2009 (ADAMS Accession No. ML092240199).

The amendments remove time, cycle, or modification-related items from the operating licenses and Technical Specifications (TS). Additionally, the amendment corrects a typographical error introduced into the TS from a previous amendment.

A copy of the Safety Evaluation is also enclosed. The Notice of Issuance will be included in the Commission's biweekly Federal Register notice.

Sincerely,

&m~

Cameron S. Goodwin, Project Manager Plant Licensing Branch 111-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-373 and 50-374

Enclosures:

1. Amendment No. 193 to NPF-11

2. Amendment No.180 to NPF-18

3. Safety Evaluation cc w/encls: Distribution via ListServ

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 EXELON GENERATION COMPANY, LLC DOCKET NO. 50-373 LASALLE COUNTY STATION, UNIT 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 193 License No. NPF-11

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

A. The application for amendment filed by the Exelon Generation Company, LLC (the licensee), dated September 11, 2008, as supplemented by letter dated August 11, 2009, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's 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 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 set forth in 10 CFR Chapter I; 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 the Facility Operating License No. NPF-11 is hereby amended to read as follows:

-2 (2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 193 , and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license. The licensee 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 30 days of the date of issuance.

~:EQ:QQTORY COMMISSION Stephen J. Campbell, Chief Plant Licensing Branch 111-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications and Facility Operating License Date of Issuance: August 27, 2009

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 EXELOI\I GENERATION COMPANY. LLC DOCKET NO. 50-374 LASALLE COUNTY STATION, UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 180 License No. NPF-18

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

A. The application for amendment filed by the Exelon Generation Company, LLC (the licensee), dated September 11, 2008, as supplemented by letter dated August 11, 2009, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's 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 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 set forth in 10 CFR Chapter I; 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 enclosure to this license amendment and paragraph 2.C.(2) of the Facility Operating License No. NPF-18 is hereby amended to read as follows:

-2 (2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 180 ,and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license. The licensee 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 30 days of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION St~~I'C~

Plant Licensing Branch 111-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications and Facility Operating License Date of Issuance: August 27, 2009

ATTACHMENT TO LICENSE AMENDMENT NOS. 193 AND 180 FACILITY OPERATING LICENSE NOS. NPF-11 AND NPF-18 DOCKET NOS. 50-373 AND 50-374 Replace the following pages of the Facility Operating Licenses and Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert License NPF-11 License NPF-11 Pages 3 through 10 Pages 3 through 10 Pages 11 through 17 Attachment 1 License NPF-18 License NPF-18 Pages 3 through 9 Pages 3 through 9 Pages 9a through 11 Attachment 1 Attachment 2 TSs TSs 3.7.1-1 3.7.1-1 3.7.1-2 3.7.1-2 3.7.1-3 3.7.2-1 3.7.2-1 3.7.2-2 3.7.2-3 3.8.1-4 3.8.1-4 3.8.1-6 3.8.1-6 3.8.1-7 3.8.1-7 3.8.1-8 3.8.1-8 3.8.1-9 3.8.1-9 3.8.1-10 3.8.1-10 3.8.1-11 3.8.1-11 3.8.1-12 3.8.1-12 3.8.1-13 3.8.1-13 3.8.1-14 3.8.1-14 3.8.1-15 3.8.1-15 3.8.1-16 3.8.1-16 3.8.1-17 3.8.1-17 3.8.1-18 3.8.1-18 3.8.1-19 3.8.1-19 5.6-3 5.6-3

-3 License No. NPF-11 Am. 146 (4 ) Exelon Generation Company, LLC, pursuant to the Act and 10 CFR Parts 01/12/01 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 Am. 146 (5) Exelon Generation Company, LLC, pursuant to the Act and 10 CFR 01/12/01 Parts 30, 40, and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of LaSalle County Station, Units 1 and 2.

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

(1) Maximum Power Level The licensee is authorized to operate the facility at reactor core power levels not in excess of full power (3489 megawatts thermal).

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No.193 and the Environmental Protection Plan contained in Appendix 8, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3) DELETED (4) DELETED (5) DELETED (6) DELETED (7) DELETED

-4 License No. NPF-11 (8) DELETED (9) DELETED (10) DELETED (11) DELETED (12) DELETED (13) DELETED (14) DELETED (15) DELETED (16) DELETED Am.10 (17) DELETED 12/09/82 (18) DELETED (19) DELETED (20) DELETED (21) DELETED (22) DELETED (23) DELETED

- 5 License No. NPF-11 (24) DELETED Am. 127 (25) Fire Protection Program 06/10/98 The licensee shall implement and maintain all provisions of the approved Fire Protection Program as described in the Final Safety Analysis Report for LaSalle County Station, and as approved in NUREG-0519, "Safety Evaluation Report related to the operation of LaSalle County Station, Units 1 and 2," dated March 1981; Supplement 2 dated February 1982; Supplement 3 dated April 1982; Supplement 5 dated August 1983; Supplement 7 dated December 1983; Supplement 8 dated March 1984; and SERs for the following:

LaSalle Unit 1 License Amendment 1, dated June 18, 1982; LaSalle Unit 1 License Amendment 18, dated August 8, 1984; LaSalle Unit 1 License Amendment 23, dated May 22, 1985; LaSalle Unit 1 License Amendment 44, dated June 20, 1986; LaSalle Unit 1 License Amendment 127, dated June 10, 1998; and NRC Evaluation of the Consequences of Postulated Failures of 1 Hour Fire Rated Darmatt KM-1 Fire Barrier under Seismic Loading at LaSalle County Station, dated March 29,1996.

The Licensee may make changes to the approved Fire Protection Program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

Am. 14 (26) DELETED 5/05/83 Letter dated (27) Industrial Security (Section 13.6, SER. SSER #3) 05/16/07 Exelon Generation Company shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, and safeguards contingency plans includin amendments made pursuant to provisions of the Miscellaneous Amen ments and Search Requirements revisions to 10 CFR 73.55 (51 FR 7817 and 27822), and the authority of 10 CFR 50.90 and 10 CFR 0.54(p). The combined set of plans 1 , which contain Safeguards Infor ation protected under 10 CFR 73.21, is entitled: "LaSalle County Station Security Plan, Training and Qualification Plan, and Safeguards Conting ncy Plan, Revision 5," submitted by letter dated May 17, 2006.

The Training and Qualification Plan and Safeguards Contingency Plan are ~ppendices to the Security Plan. I

-6 License No. NPF-11 (28) DELETED (29) DELETED (30) DELETED (31) DELETED (32) DELETED (33) DELETED Am. 103 (34) DELETED 04/13/95 (35) DELETED (36) DELETED Am. 147 (37) DELETED 03/30/01 Am. 146 (38) Exelon Generation Company, LLC shall provide the Director of the Office 01/12/01 of Nuclear Reactor Regulation a copy of any application, at the time it is filed, to transfer (excluding grants of security interests or liens) from Exelon Generation Company, LLC to its direct or indirect parent, or to any other affiliated company, facilities for the production, transmission, or distribution of electric energy having a depreciated book valve exceeding ten percent (10%) of Exelon Generation Company, LLC's consolidated net utility plant, as recorded on Exelon Generation Company, LLC's books of account.

Am. 146 (39) Exelon Generation Company, LLC shall have decommissioning trust 01/12/01 funds, for LaSalle Unit 1, in the following minimum amount, when LaSalle, Unit 1, is transferred to Exelon Generation Company, LLC:

LaSalle, Unit 1 $226,262,522

-7 License No. NPF-11 Am. 146 (40) The decommissioning trust agreement for LaSalle, Unit 1, at the time the 01/12/01 transfer of the unit to Exelon Generation Company (EGC), LLC is effected and thereafter, is subject to the following:

(a) The decommissioning trust agreement must be in a form acceptable to the NRC.

(b) With respect to the decommissioning trust fund, investments in the securities or other obligations of Exelon Corporation or affiliates thereof, or their successors or assigns are prohibited. Except for investments tied to market indexes or other non-nuclear sector mutual funds, investments in any entity owning one or more nuclear power plants are prohibited.

Am. 146 (c) The decommissioning trust agreement for LaSalle, Unit 1, must 01/12/01 provide that no disbursements or payments from the trust shall be made by the trustee unless the trustee has first given the Director of the Office of Nuclear Reactor Regulation, 30 days prior written notice of payment. The decommissioning trust agreement shall further contain a provision that no disbursements or payments from the trust shall be made if the trustee receives prior written notice of objection from the NRC.

(d) The decommissioning trust agreement must provide that the agreement can not be amended in any material respect without 30 days prior written notification to the Director of the Office of Nuclear Reactor Regulation.

(e) The appropriate section of the decommissioning trust agreement shall state that the trustee, investment advisor, or anyone else directing the investments made in the trust shall adhere to a "prudent investor" standard, as specified in 18 CFR 35.32(a)(3) of the Federal Energy Regulatory Commission's regulations.

Am. 146 (41 ) Exelon Generation Company, LLC shall take all necessary steps to 01/12/01 ensure that the decommissioning trust is maintained in accordance with the application for approval of the transfer of the LaSalle, Unit 1, license and the requirements of the Order approving the transfer, and consistent with the safety evaluation supporting the Order.

(42) DELETED (43) DELETED

-8 License No. NPF-11 Letter dated (44) Mitigation Strategy License Condition 08/09/07 Develop and maintain strategies for addressing large fires and explosions and that include the following key areas:

(a) Fire fighting response strategy with the following elements:

1. Pre-defined coordination fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets

3. Designated staging areas for equipmeht and materials

4. Command and control

5. Training of response personnel (b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged

6. Training or integrated fire response strategy

7. Spent fuel pool mitigation measures (c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders Am. 186 (45) Upon implementation of Amendment No. 186 adopting TSTF-448, 10/31/07 Revision 3, the determination of control room envelope (CRE) unfiltered air inleakage as required by SR 3.7.4.5, in accordance with TS 5.5.15.c.(i), the assessment of CRE habitability as required by Specification 5.5.15.c.(ii), and the measurement of CRE pressure as required by Specification 5.5.15.d, shall be considered met. Following Implementation:

(a) The first performance of SR 3.7.4.5, in accordance with Specification 5.5.15.c.(i), shall be within the specified Frequency of 6 years, plus the 18-month allowance of SR 3.0.2, as measured from 1998, the date of the most recent successful tracer gas test, as stated in the December 9, 2003 letter response to Generic Letter 2003-01, or within the next 18 months if the time period since the most recent successful tracer gas test is greater than 6 years.

-9 License No. NPF-11 (b) The first performance of the periodic assessment of CRE habitability, Specification 5.5.15.c.(ii), shall be within 3 years, plus the 9-month allowance of SR 3.0.2, as measured from 1998, the date of the most recent successful tracer gas test, as stated in the December 9, 2003 letter response to Generic Letter 2003-01, or within the next 9 months if the time period since the most recent successful tracer gas test is greater than 3 years.

(c) The first performance of the periodic measurement of CRE pressure, Specification 5.5.15.d, shall be within 24 months, plus 6 months allowed by SR 3.0.2, as measured from the date of the most recent successful pressure measurement test, or within 6 months if not performed previously.

Am.102 D. The facility requires exemptions from certain requirements of 10 CFR Part 50, 03/16/95 10 CFR Part 70, and 10 CFR Part 73. These include:

(a) Exemptions from certain requirements of Appendices G, Hand J and 10 CFR Part 73 are described in the Safety Evaluation Report and Supplement No.1, No.2, NO.3 to the Safety Evaluation Report.

(b) DELETED (c) DELETED (d) DELETED (e) An exemption from the requirement of paragraph 111.0 of Appendix J to conduct the third Type A test of each ten-year service period when the plant is shutdown for the 1O-year plant inservice inspections. Exemption (e) is described in the safety evaluation accompanying amendment No. 102 to this License.

Am.112 (f) An exemption was granted to remove the Main Steam Isolation Valves 04/05/96 (MSIVs) from the acceptance criteria for the combined local leak rate test (Type B and C), as defined in the regulations of 10 CFR Part 50, Appendix J, Option B, Paragraph III.B. Exemption (f) is described in the safety evaluation accompanying Amendment No. 112 to this License.

These exemptions are authorized by law and will not endanger life or property or the common defense and security and are otherwise in the public interest.

Therefore, these exemptions are hereby granted. The facility will operate, to the extent authorized herein, in conformity with the application, as amended, and the rules and regulations of the Commission (except as hereinafter exempted there from), and the provisions of the Act.

- 10 License No. NPF-11 E. This license is subject to the following additional condition for the protection of the environment:

Before engaging in additional construction or operational activities which may result in a significant adverse environmental impact that was not evaluated or that is significantly greater than that evaluated in the Final Environmental Statement and its Addendum, the licensee shall provide a written notification to the Director of the Office of Nuclear Reactor Regulation and receive written approval from that office before proceeding with such activities.

Am.178 F. Deleted 06/14/06 G. The licensee shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims.

Am.4 H. This license is effective as of the date of issuance and shall expire April 17, 2022.

08/13/82 FOR THE NUCLEAR REGULATORY COMMISSION Original Signed By HAROLD R. DENTON, DIRECTOR OFFICE OF NUCLEAR REACTOR REGULATION

Attachment:

1. DELETED

2. Appendix A - Technical Specifications (NUREG-0861)

3. Appendix B - Environmental Protection Plan Date of Issuance: April 17, 1982

-3 License No. NPF-18 Am. 34 (5) Pursuant to the Act and 10 CFR Parts 30, 40, and 70, to possess, but not 12/08/87 separate, such byproduct and special nuclear materials as may be produced by the operation of LaSalle County Station, Units 1 and 2.

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

Am. 125 (1 ) Maximum Power Level 05/09/00 The licensee is authorized to operate the facility at reactor core power levels not in excess of full power (3489 megawatts thermal). Items in Attachment 1 shall be completed as specified. Attachment 1 is hereby incorporated into this license.

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

(3) DELETED (4) DELETED (5) DELETED (6) DELETED (7) DELETED (8) DELETED (9) DELETED

-4 License No. NPF-18 (10) DELETED (11) DELETED (12) DELETED (13) DELETED (14) DELETED Am.112 (15) Fire Protection Program 06/10/98 The licensee shall implement and maintain all provisions of the approved Fire Protection Program as described in the Final Safety Analysis Report for LaSalle County Station, and as approved in NUREG-0519, "Safety Evaluation Report related to the operation of LaSalle County Station, Units 1 and 2," dated March 1981; Supplement 2 dated February 1982; Supplement 3 dated April 1982; Supplement 5 dated August 1983; Supplement 7 dated December 1983; Supplement 8 dated March 1984; and SERs for the following:

LaSalle Unit 2 License Amendment 11, dated May 22, 1985; LaSalle Unit 2 License Amendment 14, dated October 2, 1985; LaSalle Unit 2 License Amendment 112, dated June 10, 1998; and NRC Evaluation of the Consequences of Postulated Failures of 1 Hour Fire Rated Darmatt KM-1 Fire Barrier under Seismic Loading at LaSalle County Station, dated March 29, 1996.

The Licensee may make changes to the approved Fire Protection Program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

-5 License No. NPF-18 Letter dated (16) Industrial Security (Section 13.6, SER, SSER #3, SSER #5) 05/16/07 Exelon Generation Company shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822), and the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The combined set of plans 1, which contain Safeguards Information protected under 10 CFR 73.21, is entitled: "LaSalle County Station Security Plan, Training and Qualification Plan, and Safeguards Contingency Plan, Revision 5," submitted by letter dated May 17, 2006.

(17) DELETED (18) DELETED (19) DELETED (20) DELETED Am. 133 (21) Deleted.

03/30/01 Am. 132 (22) EGC shall provide the Director of the Office of Nuclear Reactor 01/12/01 Regulation a copy of any application, at the time it is filed, to transfer (excluding grants of security interests or liens) from EGC to its direct or indirect parent, or to any other affiliated company, facilities for the production, transmission, or distribution of electric energy having a depreciated book valve exceeding ten percent (10%) of EGC's consolidated net utility plant, as recorded on EGC's books of account.

Am. 132 (23) EGC shall have decommissioning trust funds for LaSalle, Unit 2, in the 01/12/01 following minimum amount, when LaSalle, Unit 2, is transferred to EGC:

LaSalle, Unit 2 $221,885,059 1 The Training and Qualification Plan and Safeguards Contingency Plan are Appendices to the Security Plan.

-6 License No. NPF-18 Am. 132 (24) The decommissioning trust agreement for LaSalle, Unit 2, at the time the 01/12/01 transfer of the unit to EGC is effected and thereafter, is subject to the following:

(a) The decommissioning trust agreement must be in a form acceptable to the NRC.

(b) With respect to the decommissioning trust fund, investments in the securities or other obligations of Exelon Corporation or affiliates thereof, or their successors or assigns are prohibited. Except for investments tied to market indexes or other non-nuclear sector mutual funds, investments in any entity owning one or more nuclear power plants are prohibited.

(c) The decommissioning trust agreement for LaSalle, Unit 2, must provide that no disbursements or payments from the trust shall be made by the trustee unless the trustee has first given the Director of the Office of Nuclear Reactor Regulation, 30 days prior written notice of payment. The decommissioning trust agreement shall further contain a provision that no disbursements or payments from the trust shall be made if the trustee receives prior written notice of objection from the NRC.

(d) The decommissioning trust agreement must provide that the agreement can not be amended in any material respect without 30 days prior written notification to the Director of the Office of Nuclear Reactor Regulation.

(e) The appropriate section of the decommissioning trust agreement shall state that the trustee, investment advisor, or anyone else directing the investments made in the trust shall adhere to a "prudent investor" standard, as specified in 18 CFR 35.32(a)(3) of the Federal Energy Regulatory Commission's regulations.

Am. 132 (25) EGC shall take all necessary steps to ensure that the decommissioning 01/12/01 trust is maintained in accordance with the application for approval of the transfer of the LaSalle, Unit 2, license and the requirements of the Order approving the transfer, and consistent with the safety evaluation supporting the Order.

(26) DELETED (27) DELETED

-7 License No. NPF-18 Letter dated (28) Mitigation Strategy License Condition 08/09/07 Develop and maintain strategies for addressing large fires and explosions and that include the following key areas:

(a) Fire fighting response strategy with the following elements:

1. Pre-defined coordination fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets

3. Designated staging areas for equipment and materials

4. Command and control

5. Training of response personnel (b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged

6. Training or integrated fire response strategy

7. Spent fuel pool mitigation measures (c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders Am. 173 (29) Upon implementation of Amendment No. 173 adopting TSTF-448, 10/31/07 Revision 3, the determination of control room envelope (CRE) unfiltered air inleakage as required by SR 3.7.4.5, in accordance with TS 5.5.15.c.(i), the assessment of CRE habitability as required by Specification 5.5.15.c.(ii), and the measurement of CRE pressure as required by Specification 5.5.15.d, shall be considered met. Following implementation:

(a) The first performance of SR 3.7.4.5, in accordance with Specification 5.5.15.c.(i), shall be within the specified Frequency of 6 years, plus the 18-month allowance of SR 3.0.2, as measured from 1998, the date of the most recent successful tracer gas test, as stated in the December 9, 2003 letter response to Generic Letter 2003-01, or within the next 18 months if the time period since the most recent successful tracer gas test is greater than 6 years.

(b) The first performance of the periodic assessment of CRE habitability, Specification 5.5.15.c.(ii), shall be within 3 years, plus the 9-month allowance of SR 3.0.2, as measured from 1998, the date of the most recent successful tracer gas test, as stated in the December 9, 2003 letter response to Generic Letter 2003-01, or within the next 9 months if the time period since the most recent successful tracer gas test is greater than 3 years.

-8 License No. NPF-18 (c) The first performance of the periodic measurement of CRE pressure, Specification 5.5.15.d, shall be within 24 months, plus the 6 months allowed by SR 3.0.2, as measured from the date of the most recent successful pressure measurement test, or within 6 months if not performed previously.

Am. 87 D. The facility requires exemptions from certain requirements of 10 CFR Part 50, 03/16/95 10 CFR Part 70, and 10 CFR Part 73. These include:

(a) Exemptions from certain requirements of Appendices G, Hand J to 10 CFR Part 50, and to 10 CFR Part 73 are described in the Safety Evaluation Report and Supplement Numbers 1, 2, 3, and 5 to the Safety Evaluation Report.

(b) DELETED (c) An exemption from the requirement of paragraph 111.0 of Appendix J to conduct the third Type A test of each ten-year service period when the plant is shutdown for the 1O-year plant inservice inspections.

(d) DELETED Am. 97 (e) An exemption was granted to remove the Main Steam Isolation Valves 04/05/96 (MSIVs) from the acceptance criteria for the combined local leak rate test (Type B and C), as defined in the regulations of 10 CFR Part 50, Appendix J, Option B, Paragraph III.B. Exemption (e) is described in the safety evaluation accompanying Amendment No. 97 to this License.

These exemptions are authorized by law and will not endanger life or property or the common defense and security and are otherwise in the public interest.

Therefore, these exemptions are hereby granted. The facility will operate, to the extent authorized herein, in conformity with the application, as amended, and the rules and regulations of the Commission (except as hereinafter exempted therefrom), and the provisions of the Act.

E. Before engaging in additional construction or operational activities which may result in a significant adverse environmental impact that was not evaluated or that is significantly greater than that evaluated in the Final Environmental Statement and its Addendum, the licensee shall provide a written notification to the Director of the Office of Nuclear Reactor Regulation and receive written approval from that office before proceeding with such activities.

Am.164 F. Deleted 06/14/06

-9 License No. NPF-18 Am.164 G. Deleted 06/14/06 H. The licensee shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims.

I. This license is effective as of the date of issuance and shall expire at Midnight on December 16, 2023.

FOR THE NUCLEAR REGULATORY COMMISSION Original signed by D.C. Eisenhut for HAROLD R. DENTON, DIRECTOR OFFICE OF NUCLEAR REACTOR REGULATION Attachment/Appendices:

1. DELETED

2. DELETED

3. Appendix A - Technical Specifications (NUREG-1013)

4. Appendix B - Environmental Protection Plan Date of Issuance: December 16, 1983

RHRSW System 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Residual Heat Removal Service Water (RHRSW) System LCO 3.7.1 Two RHRSW subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIOI~S CONDITION REQUIRED ACTION CO~IPLETION TIME A. One RHRSW subsystem A.1 - - - - - - -NOTE - - - - -

inoperable. Enter applicable Conditions and Required Actions of LCO 3.4.9, "Residual Heat Removal (RHR)

Shutdown Cooling System-Hot Shutdown," for RHR shutdown cooling subsystem made inoperable by RHRSW System.

Restore RHRSW 7 days subsystem to OPERABLE status.

(continued)

LaSalle 1 and 2 3.7.1-1 Amendment No. 193/180

RHRSW System 3.7.1 ACT IONS CONDITION REQU I RED ACTI ON COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not met.

C. Both RHRSW subsystems C.1 - - - - - - - - NOTE - - - - - - -

inoperable. Enter applicable Conditions and Required Actions of LCO 3.4.9 for RHR shutdown cooling subsystems made inoperable by RHRSW System.

Restore one RHRSW 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> subsystem to OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition C AND not met.

D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Veri fy each RHRSW 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 or can be aligned to the correct position.

LaSalle 1 and 2 3.7.1-2 Amendment No. 193/180

DGCW System 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Diesel Generator Cooling Water (DGCW) System LCO 3.7.2 The following DGCW subsystems shall be OPERABLE:

a. Three DGCW subsystems; and

b. The opposite unit Division 2 DGCW subsystem.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

Separate Condition entry is allowed for each DGCW subsystem.

CONDITION REQlI I RED ACT! ON COMPLETION TIME A. One or more DGCW A.l Declare supported Immediately subsystems inoperable. component(s) inoperable.

SURVEILLANCE REQUIREMENTS SliRVEI LLANCE FREQUENCY SR 3.7.2.1 Verify each DGCW subsystem manual, power 31 days operated, and automatic valve in the flow path, that is not locked, sea 1ed, or otherwise secured in position, is in the correct position.

SR 3.7.2.2 Verify each DGCW pump starts automatically 24 months on each required actual or simulated initiation signal.

LaSalle 1 and 2 3.7.2-1 Amendment No. 193/180

AC Sources-Operating 3.8.1 ACTI ONS CONDITION REQU I RED ACTI ON COMPLETION TIME C. Required Division 3 DG C.l Perform SR 3.8.1.1 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. for OPERABLE required offsite circuit(s). AND Once per One required Division 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 1, 2, 0 r 3 DG thereafter inoperable and the required opposite unit AND Division 2 DG inoperable. C.2 Declare required 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from feature(s), supported discovery of by the inoperable Condition C DG(s), inoperable concurrent with when the redundant i noperabi 1 ity required feature(s) of redundant are inoperable. required feature(s)

C.3.1 Determine OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> DG(s) are not inoperable due to common cause failure.

C.3.2 Perform SR 3.8.1.2 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for OPERABLE DG(s).

A.tiD.

C.4 Restore required 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> DGCs) to OPERABLE status.

17 days from discovery of failure to meet LCO 3.8.1. a or b (continued)

LaSalle 1 and 2 3.8.1-4 Amendment No. 193/100

AC Sources-Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. Two required Division F.l Restore one required 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 1, 2, or 3 DGs DG to OPERABLE inoperable. status. OR 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> if Division 3 DG Division 2 DG and the is inoperable required opposite unit Division 2 DG inoperable.

G. Required Action and G.l Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, B, C, D, E, or F not met.

H. Three or more required H.l Enter LCO 3.0.3. Immediately AC sources inoperable.

LaSalle 1 and 2 3.8.1-6 Amendment No. 193/100

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

1. SR 3.8.1.1 through SR 3.8.1.20 are applicable only to the given unit's AC electrical power sources.

2. SR 3.8.1.21 is applicable to the required opposite unit's DG.

SURVEI LLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and 7 days indicated power availability for each required offsite circuit.

SR 3.8.1.2 - - - - - - - - - - - - - - - - - - - NOT ES- - - - - - - - - - - - - - - - - -

1. All DG sta rts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

2. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

3. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.

Verify each required DG starts from standby 31 days conditions and achieves steady state voltage ~ 4010 V and ~ 4310 V and frequency

~ 58.8 Hz and ~ 61.2 Hz.

(continued)

LaSalle 1 and 2 3.8.1-7 Amendment No. 193/100

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.3 - - - - - - - - - - - - - - - - - - - NOT ES - - - - - - - - - - - - - - - - - -

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

5. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.

Verify each required DG is synchronized and 31 days loaded and operates for ~ 60 minutes at a load ~ 2400 kW and ~ 2600 kW.

SR 3.8.1.4 Verify each required day tank contains 31 days

~ 250 gal of fuel oil for Divisions 1 and 2 and ~ 550 gal for Division 3.

SR 3.8.1.5 Check for and remove accumulated water from 31 days each required day tank.

SR 3.8.1.6 Verify each required fuel oil transfer 92 days system operates to automatically transfer fuel oil from storage tanks to the day tank.

(continued)

LaSalle 1 and 2 3.8.1-8 Amendment No. 193/180

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.7 - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -

1. All DG starts may be preceded by an engine prelube period.

2. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.

Verify each required DG starts from standby 184 days condition and achieves:

a. In ~ 13 seconds, voltage ~ 4010 V and frequency ~ 58.8 Hz; and

b. Steady state voltage ~ 4010 V and ~ 4310 V and frequency ~ 58.8 Hz and ~ 61.2 Hz.

SR 3.8.1.8 - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - - - -

This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify manual transfer of unit power supply 24 months from the normal offsite circuit to the alternate offsite circuit.

(continued)

LaSalle 1 and 2 3.8.1-9 Amendment No. 193/100

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.9 ----------------- -I~ OTE S - - - - - - - - - - - - - - - - - - -

1. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Credit may be taken for unplanned events that satisfy this SR.

2. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.

Verify each required DG rejects a load 24 months greater than or equal to its associated single largest post-accident load and following load rejection, the frequency is

66.7 Hz.

SR 3.8.1.10 - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - - -

1. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Credit may be taken for unplanned events that satisfy this SR.

2. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.

Verify each required DG does not trip and 24 months voltage is maintained:;; 5000 V during and following a load rejection of a load

~ 2600 kW.

(continued)

LaSalle 1 and 2 3.8.1-10 Amendment No. 193/100

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 - - - - - - - - - - - - - - - - - - - NOT ES- - - - - - - - - - - - - - - - - -

1. All DG sta rts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of 24 months offsite power signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses for Divisions 1 and 2 only; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in ~ 13 seconds,

2. energizes auto-connected shutdown loads,

3. maintains steady state voltage

~ 4010 V and ~ 4310 V,

4. maintains steady state frequency

~ 58.8 Hz and ~ 61.2 Hz, and

5. supplies permanently connected and auto-connected shutdown loads for

~ 5 minutes.

(continued)

LaSalle 1 and 2 3.8.1-11 Amendment No. 193/180

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLMCE FREQUENCY SR 3.8.1.12 - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Emergency 24 months Core Cooling System (ECCS) initiation signal each required DG auto-starts from standby condition and:

a. In ~ 13 seconds after auto-start, achieves voltage ~ 4010 V and frequency ~ 58.8 Hz;

b. Achieves steady state voltage ~ 4010 V and ~ 4310 V and frequency ~ 58.8 Hz and ~ 61.2 Hz; and

c. Operates for ~ 5 minutes.

(continued)

LaSalle 1 and 2 3.8.1-12 Amendment No. 193/180

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8. 1. 13 - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - -

This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify each required DG's automatic trips 24 months are bypassed on an actual or simulated ECCS initiation signal except:

a. Engine overspeed; and

b. Generator differential current.

(continued)

LaSalle 1 and 2 3.8.1-13 Amendment No. 193/180

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.14 - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

2. This Surveillance shall not normally be performed in MODE 1 or 2 unless the other two DGs are OPERABLE. If either of the other two DGs becomes inoperable, this Surveillance shall be suspended. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

3. If grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable.

4. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.

Verify each required DG operating within 24 months the power factor limit operates for z 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:

a. For z 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded z 2860 kW; and

b. For the remaining hours of the test loaded z 2400 kW and ~ 2600 kW.

(continued)

LaSalle 1 and 2 3.8.1-14 Amendment No. 193/100

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.15 - - - - - - - - - - - - - - - - - - - NOT ES- - - - - - - - - - - - - - - - - -

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated ~ 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded ~ 2400 kW and $ 2600 kW.

Momentary transients outside of load range do not invalidate this test.

2. All DG sta rts may be preceded by an engine prelube period.

3. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.

Verify each required DG starts and 24 months achieves:

a. In $ 13 seconds, voltage ~ 4010 V and frequency ~ 58.8 Hz; and

b. Steady state voltage ~ 4010 V and

$ 4310 V and frequency ~ 58.8 Hz and $ 61.2 Hz.

(continued)

LaSalle 1 and 2 3.8.1-15 Amendment No. 193/100

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.16 - - - - - - - - - - - - - - - - - - -NOT E- - - - - - - - - - - - - - - - - - -

This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify each required DG: 24 months

a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b. Transfers loads to offsite power source; and

c. Returns to ready-to-load operation.

(continued)

LaSalle 1 and 2 3.8.1-16 Amendment No .193/100

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVE I LLMCE FREQUENCY SR 3.8.1.17 - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - - - -

This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify, with a required DG operating in 24 months test mode and connected to its bus:

a. For Division 1 and 2 DGs, an actual or simulated ECCS initiation signal overrides the test mode by returning DG to ready-to-load operation; and

b. For Division 3 DG, an actual or simulated DG overcurrent trip signal automatically disconnects the offsite power source while the DG continues to supply normal loads.

SR 3.8.1.18 - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - -

This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify interval between each sequenced load 24 months block, for Division 1 and 2 DGs only, is

~ 90% of the design interval for each time delay relay.

(continued)

LaSalle 1 and 2 3.8.1-17 Amendment No. 193/180

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLMCE FREQUENCY SR 3.8.1.19 - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -

1. All DG sta rts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify, on an actual or simulated loss of 24 months offsite power signal in conjunction with an actual or simulated ECCS initiation signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses for Divisions 1 and 2 only; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in ~ 13 seconds,

2. energizes auto-connected emergency loads including through time delay relays, where applicable,

3. maintains steady state voltage

~ 4010 V and ~ 4310 V,

4. maintains steady state frequency

~ 58.8 Hz and ~ 61.2 Hz, and

5. supplies permanently connected and auto-connected emergency loads for

~ 5 minutes.

(continued)

LaSalle 1 and 2 3.8.1-18 Amendment No. 193/100

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.20 - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - - - -

All DG starts may be preceded by an engine prelube period.

Verify, when started simultaneously from 10 years standby condition, each required DG achieves, in s 13 seconds, voltage ~ 4010 V and frequency ~ 58.8 Hz.

SR 3.8.1.21 - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - - - -

When the opposite unit is in MODE 4 or 5, or moving irradiated fuel assemblies in secondary containment, the following opposite unit SRs are not required to be performed: SR 3.8.1.3, SR 3.8.1.9 through SR 3.8.1.11, SR 3.8.1.14 through SR 3.8.1.16.

For required opposite unit DG, the SRs of In accordance the opposite unit's Specification 3.8.1, with applicable except SR 3.8.1.12, SR 3.8.1.13, SRs SR 3.8.1.17, SR 3.8.1.18, SR 3.8.1.19, and SR 3.8.1.20, are applicable.

LaSalle 1 and 2 3.8.1-19 Amendment No. 193/100

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

4. The Rod Block Monitor Upscale Instrumentation Setpoint for the Rod Block Monitor-Upscale Function Allowable Value for Specification 3.3.2.1.

5. The OPRM setpoints for the trip function for SR 3.3.1.3.3.

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

1. ANF-524(P)(A), "MF Critical Power Methodology for Boiling Water Reactors."

2. ANF-913(P)(A), "COTRANSA 2: A Computer Program for Boiling Water Reactor Transient Analysis."

3. ANF-CC-33(P)(A), "HUXY: A Generalized Multirod Heatup Code with 10 CFR 50, Appendix K Heatup Option."

4. XN-NF-80-19(P)(A), "Advanced Nuclear Fuel Methodology for Boiling Water Reactors."

5. XN-NF-85-67(P)(A), "Generic Mechanical Design for Exxon Nucl ear Jet Pump BWR Reload Fuel."

6. EMF-CC-074(P)(A), Volume 4 - "BWR Stability Analysis:

Assessment of STAIF with input from MICROBURN-B2."

7. XN-NF-81-58(P)(A), "RODEX2 Fuel Rod Thermal-Mechanical Response Evaluation Model."

8. XN-NF-84-105(P)(A), "XCOBRA-T: A Computer Code for BWR Transient Thermal-Hydraulic Core Analysis."

(continued)

LaSalle 1 and 2 5.6-3 Amendment No. 193/100

"V\.~"p. Rf GU(

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.;'" c UNITED STATES Ul '  ::

~ NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001

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~1< O~

/) ****1< ~ SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 193 TO FACILITY OPERATING LICENSE NO. NPF-11 AND AMENDMENT NO. 100 TO FACILITY OPERATING LICENSE NO. NPF-18 EXELON GENERATION COMPANY, LLC LASALLE COUNTY STATION, UNITS 1 AND 2 DOCKET NOS. 50-373 AND 50-374

1.0 INTRODUCTION

By letter to the U.S. Nuclear Regulatory Commission (NRC) dated September 11, 2008, (Agencywide Documents Access and Management System (ADAMS) Accession No. ML082550530), as supplemented by letter dated August 11, 2009 (ADAMS Accession No. ML092240199), Exelon Generation Company, LLC (the licensee), requested, among other things, changes to the Technical Specifications (TS) for the LaSalle County Station (LaSalle),

Units 1 and 2. The proposed TS changes would remove changes that were applicable in the following refueling outage&: Unit 1 Refueling Outage 11, Unit 2 Refueling Outage 11 and Unit 1 Refueling Outage 12. The TS were approved and issued to the licensee in two letters dated February 23,2006 (ADAMS Accession No. ML060270103) and November 20,2006 (ADAMS Accession No. ML063250247).

1.1 Proposed License Amendment The proposed TS changes would remove the TS that applied only during Unit 1 Refueling Outage 11, Unit 2 Refueling Outage 11 and Unit 1 Refueling Outage 12 in TS 3.7.1, "Residual Heat Removal (RHR) Service Water (RHRSW) System," TS 3.7.2, "Diesel Generator (DG)

Cooling Water (DGCW) System" and TS 3.8.1, "AC Sources-Operating." Specifically, the proposed changes would remove the following notes, conditions, required actions and completion times as described below:

• Remove a condition note that states, "Not applicable to Unit 2 during replacement of the Division 1 CSCS isolation valves during Unit 1 Refueling 11 while Unit 1 is in Mode 4,5, or defueled" from TS 3.7.1 Condition A.

• Remove TS 3.7.1 Condition B, Required Action B.1 and the associated completion time, "Restore RHRSW subsystem to OPERABLE status," associated with TS 3.7.1 in 10 days. Condition B is only applicable to Unit 2 during replacement of the Division 1 core standby cooling system (CSCS) isolation valves during Unit 1 Refueling 11 while Unit 1 is in Mode 4, 5, or defueled.

• Remove a condition note that states, "1. Not applicable to Division 1 during replacement of the Division 1 CSCS isolation valves during Unit 1 Refueling 11 while Unit 1 is in Mode

-2 4, 5, or defueled. 2. Not applicable to Division 2 during replacement of the Division 2 CSCS isolation valves during Unit 2 Refueling 11 while Unit 2 is in Mode 4, 5, or defueled and during Unit 1 Refueling 12 while Unit 1 is in Mode 4, 5 or defueled" from TS 3.7.2 Condition A.

• Remove Condition 8, Required Action 8.1 and the associated completion time, a 6-day (for Division 2 CSCS valve maintenance) or 10-day (for Division 1 CSCS valve maintenance) completion time for TS 3.7.2 when one or more required DG cooling water subsystems(s) are inoperable. Condition 8 is only applicable for two specific times:

(1) only applicable to Division 1 during replacement of the Division 1 CSCS isolation valves during Unit 1 Refueling 11 while Unit 1 is in Mode 4, 5, or defueled; (2) only applicable to Division 2 during replacement of the Division 2 CSCS isolation valves during Unit 2 Refueling 11 while Unit 2 is in Mode 4, 5, or defueled and during Unit 1 Refueling 12 while Unit 1 is in Mode 4, 5 or defueled.

• Remove TS 3.7.2 Condition C, "Required Action and the associated Completion Time of Condition 8 not met."

• Remove a condition note that states, "1. Not applicable to Unit 1 during replacement of the Unit 2 Division 2 CSCS isolation valves during Unit 2 Refueling 11 while Unit 2 is in Mode 4, 5, or defueled. 2. Not applicable to Unit 2 during replacement of the Unit 1 Division 2 CSCS isolation valves during Unit 1 Refueling 12 while Unit 1 is in Mode 4, 5, or defueled" from TS 3.8.1 Condition C.

• Remove a condition note that states, "1. Not applicable to Unit 1 during replacement of the Unit 2 Division 2 CSCS isolation valves during Unit 2 Refueling 11 while Unit 2 is in Mode 4, 5, or defueled. 2. Not applicable to Unit 2 during replacement of the Unit 1 Division 2 CSCS isolation valves during Unit 1 Refueling 12 while Unit 1 is in Mode 4, 5, or defueled" from TS 3.8.1 Condition F.

• Remove Condition G, "Division 2 DG and the required opposite unit Division 2 DG inoperable" which is only applicable when, "1. Only applicable to Unit 1 during replacement of the Unit 2 Division 2 CSCS isolation valves during Unit 2 Refueling 11 while Unit 2 is in Mode 4, 5, or defueled. 2. Only applicable to Unit 2 during replacement of the Unit 1 Division 2 CSCS isolation valves during Unit 1 Refueling 12 while Unit 1 is in Mode 4, 5, or defueled" in TS 3.8.1.

• Remove TS 3.8.1 Condition I, "Required Action and associated Completion Time of Condition A, 8, C, D, E, or F not met."

These approved TS notes, conditions, required actions, and completion times were only used during Unit 1 Refueling Outage 11 (spring 2006), Unit 2 Refueling Outage 11 (spring 2007), and Unit 1 Refueling Outage 12 (spring 2008).

The proposed amendment also corrects an administrative error in TS section 5.6.5, "Core Operating Limits Report (COLR)". TS Section 5.6.5 is being changed to align with the title used in the COLR.

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2.0 REGULATORY EVALUATION

Section 50.36, "Technical Specifications," of Title 10 of the Code of Federal Regulations (10 CFR) establishes the regulatory requirements related to the content of TS. Pursuant to 10 CFR 50.36, TS include items in the following five specific categories related to station operation: (1) safety limits, limiting safety system settings, and limiting control settings; (2) limiting condition for operation; (3) surveillance requirements; (4) design features; and (5) administrative controls. The rule does not specify the particular requirements to be included in a plant's TS. As stated in 10 CFR 50.36(c)(2)(i), the "Limiting conditions for operation are the lowest functional capability or performance levels of equipment required for safe operation of the facility. When a limiting condition for operation of a nuclear reactor is not met, the licensee shall shut down the reactor or follow any remedial action permitted by the technical specifications."

TS changes can be grouped into four general categories as follows: administrative, relocated requirements, more restrictive requirements, and less restrictive requirements. These four general categories of changes to the TS requirements may be better understood as follows:

• Administrative Changes. Non-technical, administrative changes were intended to incorporate human-factors principles into the form and structure of the improved plant TS so that they would be easier to use for plant operations personnel. These changes are editorial in nature or involve the reorganization or reformatting of requirements without affecting technical content or operational requirements.

• Relocated requirements. Existing TS requirements which do not satisfy or fall within any of the four specified criteria may be relocated to appropriate licensee-controlled documents.

• More Restrictive Requirements. Licensee's can propose TS changes which include more restrictive requirements than are contained in the existing TS, which are either more conservative than corresponding requirements in the existing TS, or are additional restrictions which are contained in NUREG-1433 but are not contained in the existing TS.

• Less Restrictive Requirements. When requirements have been shown to provide little or no safety benefit, their removal from the TS may be appropriate. In most cases, relaxations in TS are the result of generic NRC actions, new NRC staff positions that have evolved from technological advancements and operating experience, or resolution of the Owners Groups' comments on the improved STS.

3.0 TECHNICAL EVALUATION

The proposed amendment removes time, cycle, or modification-related items from the TSs. The time, cycle, or modification-related items have been implemented or superseded, are no longer applicable, and no longer need to be maintained in the TS. Specifically, the proposed amendment removes conditional Notes related to TS associated with the Core Standby Cooling System (CSCS) valve replacement project. The refueling outages related to the extension of the Completion Times associated with the TS Sections 3.7.1, "Residual Heat Removal Service

-4 Water (RHRSW) System," 3.7.2, "Diesel Generator Cooling Water (DGCW) System," and 3.8.1, "AC Sources Operating," are complete and the added Conditions are no longer needed.

Additionally, there is an administrative correction to TS Section 5.6.5, "Core Operating Limits Report." The topical report XN-NF-524(P)(A), "ANF Critical Power Methodology for Boiling Water Reactors" referenced in TS 5.6.5 is being administratively changed to ANF-524(P)(A),

"ANF Critical Power Methodology for Boiling Water Reactors." LaSalle's core operating limit report references topical report ANF-524(P)(A) Revision 2, "ANF Critical Power Methodology for Boiling Water Reactors" which was evaluated by the NRC and found to be acceptable on August 8, 1990 (ADAMS Accession No. ML9008130091). Finally, the proposed amendment will result in various editorial and formatting changes to the TS.

The TS notes, conditions, required actions and completion times were only used during Unit 1 Refueling Outage 11, Unit 2 Refueling Outage 11, and Unit 'I Refueling Outage 12 which were approved and issued to the licensee in the letters, referenced above in Section 1.0, are no longer applicable and can no longer be applied at LaSalle. The proposed amendment does not change any items in the safety limits, limiting safety system settings, limiting control settings; limiting conditions for operation; surveillance requirements; design features; or administrative controls in 10 CFR 50.36.

All changes proposed by Exelon Generation Company, LLC in this amendment request are administrative in nature, and propose removing on~time requirements that are no longer applicable. There are no physical changes to the facilities, nor any changes to the station operating procedures, limiting conditions for operation, or limiting safety system settings. The proposed amendment does not deviate from existing regulatory requirements and compliance with existing regulations is maintained. Therefore, with respect to compliance with current regulations, the NRC staff considers the proposed TS changes to be acceptable.

4.0 STATE CONSULTATION

In accordance with the Commission's regulations, the Illinois State official was notified of the proposed issuance of the amendments. The State official had no comments.

5.0 ENVIRONMENTAL CONSIDERATION

The amendment changes a requirement with respect to installation or use of a facility component located within the restricted area as defined in 10 CFR Part 20. 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 amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9).

In addition, the amendment changes are administrative. Accordingly, the amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)( 10). 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.

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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) such activities will be conducted in compliance with the Commission s regulations, and (3) the issuance of the amendments will not be inimical to the common defense and security or to the health and safety of the public.

Principal Contributor: K. Bucholtz Date: August 27, 2009

Mr. Charles G. Pardee August27,2009 President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555

SUBJECT:

LASALLE COUNTY STATION, UNITS 1 AND 2, ISSUANCE OF AMENDMENTS RE: DELETE OBSOLETE LICENSE CONDITIONS AND REVISE TECHNICAL SPECIFICATIONS (TAC NOS. MD9616 AND MD9617)

Dear Mr. Pardee:

The U.S. Nuclear Regulatory Commission (the Commission) has issued the enclosed Amendment No. 193 to Facility Operating License No. NPF-11 and Amendment No. 180 to Facility Operating License No. NPF-18 for the LaSalle County Station, Units 1 and 2, respectively. The amendments are in response to your application dated September 11, 2008 (Agencywide Document Management and Access System (ADAMS) Accession No. ML082550530). as supplemented by letter dated August 11, 2009 (ADAMS Accession No. ML092240199).

The amendments remove time, cycle, or modification-related items from the operating licenses and Technical Specifications (TS). Additionally, the amendment corrects a typographical error introduced into the TS from a previous amendment.

A copy of the Safety Evaluation is also enclosed. The Notice of Issuance will be included in the Commission's biweekly Federal Register notice.

Sincerely, RA by C. Gratton for C. Goodwin/

Cameron S. Goodwin, Project Manager Plant Licensing Branch 111-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-373 and 50-374

Enclosures:

1. Amendment No. 193 to NPF-11

2. Amendment No. 180 to NPF-18

3. Safety Evaluation cc w/encls: See next page DISTRIBUTION:

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