ML092450404: Difference between revisions

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| number = ML092450404
| number = ML092450404
| issue date = 09/03/2009
| issue date = 09/03/2009
| title = LaSalle, Units 1 and 2 - Correction Letter for License Amendment Nos. 193 and 180 Obsolete License Conditions and Revise Technical Specifications (TAC Nos. MD9616 and MD9617)
| title = Correction Letter for License Amendment Nos. 193 and 180 Obsolete License Conditions and Revise Technical Specifications
| author name = Goodwin C S
| author name = Goodwin C
| author affiliation = NRC/NRR/DORL/LPLIII-2
| author affiliation = NRC/NRR/DORL/LPLIII-2
| addressee name = Pardee C G
| addressee name = Pardee C
| addressee affiliation = Exelon Nuclear
| addressee affiliation = Exelon Nuclear
| docket = 05000373, 05000374
| docket = 05000373, 05000374
Line 14: Line 14:
| page count = 48
| page count = 48
| project = TAC:MD9616, TAC:MD9617
| project = TAC:MD9616, TAC:MD9617
| stage = Approval
| stage = Acceptance Review
}}
}}


=Text=
=Text=
{{#Wiki_filter:UNITED NUCLEAR REGULATORY WASHINGTON, D.C. 20555-0001 September 3, 2009 Mr. Charles G. Pardee President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 LASALLE COUNTY STATION, UNITS 1 AND 2 -CORRECTION LETTER FOR LICENSE AMENDMENT NOS. 193 AND 180 RE: DELETE OBSOLETE LICENSE CONDITIONS AND REVISE TECHNICAL SPECIFICATIONS (TAC NOS. MD9616 AND MD9617)  
{{#Wiki_filter:UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 September 3, 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 - CORRECTION LETTER FOR LICENSE AMENDMENT NOS. 193 AND 180 RE: DELETE OBSOLETE LICENSE CONDITIONS AND REVISE TECHNICAL SPECIFICATIONS (TAC NOS. MD9616 AND MD9617)


==Dear Mr. Pardee:==
==Dear Mr. Pardee:==
By letter dated August 27, 2009 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML092040273), the Nuclear Regulatory Commission (NRC) staff issued Amendment Nos. 193 and 180 to Facility Operating License Nos. NPF-11 and NPF-18 for the LaSalle County Station, Units 1 and 2, respectively.
 
The amendments remove time, cycle, or modification-related items from the operating licenses and Technical Specifications in response to your application dated September 11, 2008 (ADAMS Accession No. ML082550530), as supplemented by letter dated August 11, 2009 (ADAMS Accession No. ML092240199).
By letter dated August 27, 2009 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML092040273), the Nuclear Regulatory Commission (NRC) staff issued Amendment Nos. 193 and 180 to Facility Operating License Nos. NPF-11 and NPF-18 for the LaSalle County Station, Units 1 and 2, respectively. The amendments remove time, cycle, or modification-related items from the operating licenses and Technical Specifications in response to your application dated September 11, 2008 (ADAMS Accession No. ML082550530), as supplemented by letter dated August 11, 2009 (ADAMS Accession No. ML092240199).
Administrative errors were identified in the amendments.
Administrative errors were identified in the amendments. The amendments were incorrectly dated. They should be dated for August 28, 2009. It was also noted that the amendment numbers used were incorrect. The correct amendment numbers are 194 and 181 for LaSalle County Station, Units 1 and 2, respectively. Please replace the amendments dated August 27, 2009, with the enclosed amendments.
The amendments were incorrectly dated. They should be dated for August 28, 2009. It was also noted that the amendment numbers used were incorrect.
The correct amendment numbers are 194 and 181 for LaSalle County Station, Units 1 and 2, respectively.
Please replace the amendments dated August 27, 2009, with the enclosed amendments.
The incorrect information was editorial in nature. The corrections do not change the approval conveyed by the amendments, or the conclusions reached by the associated safety evaluation.
The incorrect information was editorial in nature. The corrections do not change the approval conveyed by the amendments, or the conclusions reached by the associated safety evaluation.
We regret any inconvenience this may have caused you. Sincerely, 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 Amendments dated August 28, cc w/encl: Distribution via UNITED NUCLEAR REGULATORY WASHINGTON, D.C. 20555-0001 August28,2009 Mr. Charles G. Pardee President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 LASALLE COUNTY STATION, UNITS 1 AND 2, ISSUANCE OF AMENDMENTS RE: DELETE OBSOLETE LICENSE CONDITIONS AND REVISE TECHNICAL SPECIFICATIONS (TAC NOS. MD9616 AND MD9617)  
We regret any inconvenience this may have caused you.
Sincerely, 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
 
==Enclosure:==
 
Amendments dated August 28, 2009 cc w/encl: Distribution via ListServ
 
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 August28,2009 Mr. Charles G. Pardee President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 SUB.JECT:      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:==
==Dear Mr. Pardee:==
The U.S. Nuclear Regulatory Commission (the Commission) has issued the enclosed Amendment No. 194 to Facility Operating License No. NPF-11 and Amendment No. 181 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 U.S. Nuclear Regulatory Commission (the Commission) has issued the enclosed Amendment No. 194 to Facility Operating License No. NPF-11 and Amendment No. 181 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.
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.
A copy of the Safety Evaluation is also enclosed. The Notice of Issuance will be included in the Commission's biweekly Federal Register notice.
The Notice of Issuance will be included in the Commission's biweekly Federal Register notice. Sincerely, 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  
Sincerely, a~tL<!VJ,J/;--~~~/~
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:==
==Enclosures:==
: 1. Amendment No. 194 to NPF-11 2. Amendment No. 181 to NPF-18 3. Safety Evaluation cc wlencls: Distribution via ListServ UNITED NUCLEAR REGULATORY WASHINGTON, D.C. 20555-0001 EXELON GENERATION COMPANY, DOCKET NO. LASALLE COUNTY STATION, UNIT AMENDMENT TO FACILITY OPERATING Amendment No. 194 License No. NPF-11 The U.S. Nuclear Regulatory Commission (the Commission) has found that: 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; The facility will operate in conformity with the application, the provisions of the Act, and the regulations of the Commission; 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; 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 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. 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:
: 1. Amendment No. 194 to NPF-11
-Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 194, 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. This license amendment is effective as of the date of its issuance and shall be implemented within 30 days of the date of issuance.
: 2. Amendment No. 181 to NPF-18
Stephen J. Campbell, Chief Plant Licensing Branch 111-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation  
: 3. Safety Evaluation cc wlencls: 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. 194 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. 194, 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.
Stephen J. Campbell, Chief Plant Licensing Branch 111-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation


==Attachment:==
==Attachment:==
Changes to the Technical Specifications and Facility Operating License Date of Issuance: August 28, 2009
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 EXELON GENERATION COMPANY, LLC DOCKET NO. 50-374 LASALLE COUNTY STATION, UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 181 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:


Changes to the Technical Specifications and Facility Operating License Date of Issuance:
                                                  -2 (2)     Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 181, 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.
August 28, 2009 UNITED NUCLEAR REGULATORY WASHINGTON, D.C. 20555-0001 EXELON GENERATION COMPANY, DOCKET NO. LASALLE COUNTY STATION, UNIT AMENDMENT TO FACILITY OPERATING Amendment No. 181 License No. NPF-18 The U.S. Nuclear Regulatory Commission (the Commission) has found that: 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; The facility will operate in conformity with the application, the provisions of the Act, and the regulations of the Commission; 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; 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 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. 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:
: 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.
Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 181, 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. 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 NUCLEARc:4ULATORY COMMISSION s~m~~ell'~
FOR THE NUCLEAR c:4ULA TORY COMMISSION Plant Licensing Branch 111-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation  
Plant Licensing Branch 111-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation


==Attachment:==
==Attachment:==
Changes to the Technical Specifications and Facility Operating License Date of Issuance: August 28, 2009


Changes to the Technical Specifications and Facility Operating License Date of Issuance:
ATTACHMENT TO LICENSE AMENDMENT NOS. 194 AND 181 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.
August 28, 2009 ATTACHMENT TO LICENSE AMENDMENT NOS. 194 AND 181 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 License NPF-11 Pages 3 through 10 Pages 11 through 17 Attachment 1 License NPF-18 Pages 3 through 9 Pages 9a through 11 Attachment 1 Attachment 2 TSs 3.7.1-1 3.7.1-2 3.7.1-3 3.7.2-1 3.7.2-2 3.7.2-3 3.8.1-4 3.8.1-6 3.8.1-7 3.8.1-8 3.8.1-9 3.8.1-10 3.8.1-11 3.8.1-12 3.8.1-13 3.8.1-14 3.8.1-15 3.8.1-16 3.8.1-17 3.8.1-18 3.8.1-19 5.6-3 License NPF-11 Pages 3 through 10 License NPF-18 Pages 3 through 9 TSs 3.7.1-1 3.7.1-2 3.7.2-1 3.8.1-4 3.8.1-6 3.8.1-7 3.8.1-8 3.8.1-9 3.8.1-10 3.8.1-11 3.8.1-12 3.8.1-13 3.8.1-14 3.8.1-15 3.8.1-16 3.8.1-17 3.8.1-18 3.8.1-19 5.6-3 
Remove 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 01/12/01 (4) Exelon Generation Company, LLC, 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 Am. 146 01/12/01 (5) Exelon Generation Company, LLC, pursuant to the Act and 10 CFR 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 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
                                          -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.
-4 (8) (9) (10) (11)  
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:
(12) (13) (14) (15) (16) Am.10 (17) 12/09/82 (18) (19) (20) (21) (22) (23) DELETED DELETED DELETED DELETED DELETED DELETED DELETED DELETED DELETED DELETED DELETED DELETED DELETED DELETED DELETED DELETED License No. NPF-11 
(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).
-5 License No. I\JPF-11 Am. 127 06/10/98 Am. 14 5/05/83 Letter dated 05/16/07 (24) DELETED (25) Fire Protection Program 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:
(2)     Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment NO.19~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.
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. (26) DELETED (27) Industrial Security (Section 13.6, SER. SSER #3) 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).
(3)     DELETED (4)     DELETED (5)     DELETED (6)     DELETED (7)     DELETED
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. The Training and Qualification Plan and Safeguards Contingency Plan are Appendices to the Security Plan.
 
-6 Am. 103 04/13/95 Am. 147 03/30/01 Am. 146 01/12/01 Am. 146 01/12/01 License No. NPF-11 (28) DELETED (29) DELETED (30) DELETED (31) DELETED (32) DELETED (33) DELETED (34) DELETED (35) DELETED (36) DELETED (37) DELETED (38) Exelon Generation Company, LLC shall provide the Director of the Office 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. (39) Exelon Generation Company, LLC shall have decommissioning trust 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
                      -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
-7 License No. NPF-11 Am. 146 01/12/01 (40) The decommissioning trust agreement for LaSalle, Unit 1, at the time the 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 01/12/01 (c) The decommissioning trust agreement for LaSalle, Unit 1, 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.
                                              -5 License No. I\JPF-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:
Am. 146 01/12/01 (41 ) Exelon Generation Company, LLC shall take all necessary steps to 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
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.
-8 License No. NPF-11 Letter (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: Fire fighting response strategy with the following elements: Pre-defined coordination fire response strategy and guidance Assessment of mutual aid fire fighting assets Designated staging areas for equipment and materials Command and control Training of response personnel Operations to mitigate fuel damage considering the following: Protection and use of personnel assets Communications Minimizing fire spread Procedures for implementing integrated fire response strategy Identification of readily-available pre-staged Training or integrated fire response strategy Spent fuel pool mitigation measures Actions to minimize release to include consideration of: 1. Water spray scrubbing  
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.
: 2. Dose to on site responders Am. 186 Upon implementation of Amendment No. 186 adopting TSTF-448, 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: 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.
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 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.
-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.
The Training and Qualification Plan and Safeguards Contingency Plan are Appendices to the Security Plan.
Am.102 03/16/95 D. The facility requires exemptions from certain requirements of 10 CFR Part 50, 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 1 O-year plant inservice inspections.
 
Exemption (e) is described in the safety evaluation accompanying amendment No. 102 to this License. Am.112 04/05/96 (f) An exemption was granted to remove the Main Steam Isolation Valves (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.
                                    -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.
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.
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:
-License No. NPF-11 E. This license is subject to the following additional condition for the protection of the environment:
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 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. 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.
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 06/14/06 F. Deleted 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 08/13/82 H. This license is effective as of the date of issuance and shall expire April 17, 2022. FOR THE NUCLEAR REGULATORY COMMISSION Original Signed By HAROLD R. DENTON, DIRECTOR OFFICE OF NUCLEAR REACTOR REGULATION  
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:==
==Attachment:==
: 1. DELETED Appendix A -Technical Specifications (NUREG-0861) Appendix B -Environmental Protection Plan Date of Issuance:
: 1. DELETED
April 17, 1982
: 2. Appendix A - Technical Specifications (NUREG-0861)
-3 License No. NPF-18 Am. 34 12/08/87 (5) Pursuant to the Act and 10 CFR 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. 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 05/09/00 (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).
: 3. Appendix B - Environmental Protection Plan Date of Issuance: April 17, 1982
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 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 Speci'f!cations and the Environmental Protection Plan. (3) DELETED (4) DELETED (5) DELETED (6) DELETED (7) DELETED (8) DELETED (9) DELETED
                                          -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.
-4 License No. NPF-18 Am.112 06/10/98 (10) DELETED (11) DELETED (12) DELETED (13) DELETED (14) DELETED (15) Fire Protection Program 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:
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:
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.
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.
-5 License No. I\IPF-18 Letter dated 05/16/07 (16) Industrial Security (Section 13.6, SER, SSER #3, SSER #5) 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).
(2)     Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No.18~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 Speci'f!cations and the Environmental Protection Plan.
The combined set of plans\ 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 03/30/01 (21) Deleted. Am. 132 01/12/01 (22) EGC shall provide the Director of the Office 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 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 01/12/01 (23) EGC shall have decommissioning trust funds for LaSalle, Unit 2, in the 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.
(3)     DELETED (4)     DELETED (5)     DELETED (6)     DELETED (7)     DELETED (8)     DELETED (9)     DELETED
-6 License No. NPF-18 Am. 132 01/12/01 (24) The decommissioning trust agreement for LaSalle, Unit 2, at the time the 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 01/12/01 (25) EGC shall take all necessary steps to ensure that the decommissioning 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
                                  -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:
-7 License No. t\lPF-18 Letter dated Mitigation Strategy License Condition 08/09/07 Develop and maintain strategies for addressing large fires and explosions and that include the following key areas: Fire fighting response strategy with the following elements:  
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.
: 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  
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.
: 4. Command and control 5. Training of response personnel Operations to mitigate fuel damage considering the following:  
 
: 1. Protection and use of personnel assets 2. Communications  
                                              -5 License No. I\IPF-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\ 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.
: 3. Minimizing fire spread 4. Procedures for implementing integrated fire response strategy 5. Identification of readily-available pre-staged  
(17) DELETED (18) DELETED (19) DELETED (20) DELETED Am. 133           (21)  Deleted.
: 6. Training or integrated fire response strategy 7. Spent fuel pool mitigation measures Actions to minimize release to include consideration of: 1. Water spray scrubbing  
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.
: 2. Dose to onsite responders Am. 173 Upon implementation of Amendment No. 173 adopting TSTF-448, 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: 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. 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.
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:
-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.
LaSalle, Unit 2                         $221,885,059 1 The Training and Qualification Plan and Safeguards Contingency Plan are Appendices to the Security Plan.
Am. 87 03/16/95 D. The facility requires exemptions from certain requirements of 10 CFR Part 50, 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 1 O-year plant inservice inspections. (d) DELETED Am. 97 04/05/96 (e) An exemption was granted to remove the Main Steam Isolation Valves (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.
                                      -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:
Am.164 06/14/06 F. Deleted 
(a)     The decommissioning trust agreement must be in a form acceptable to the NRC.
-9 License No. NPF-18 Am.164 G. Deleted 06/14/06 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. 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:  
(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.
: 1. DELETED 2. DELETED Appendix A -
(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.
Specifications (NUREG-1 Appendix B -
(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.
Protection Date of Issuance:
(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.
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.
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.
APPLICABILITY:
(26) DELETED (27) DELETED
MODES 1, 2, and 3. ACTI ONS CONDITION REQU I RED ACTI ON  
 
                                          -7 License No. t\lPF-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-1 013)
: 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.
ACTI ONS CONDITION                   REQU I RED ACTI ON                     CO~IPLETION TI~IE A. One RHRSW subsystem      A.l      - - - -  - - 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. 194/181
 
RHRSW System 3.7.1 ACTIONS CONDITION                    REQU I RED ACTI ON                      COMP LETI Ol~ TIME B. Required Action and      B.1      Be in MODE 3.                          [[estimated NRC review hours::12 hours]] 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                      [[estimated NRC review hours::8 hours]] subsystem to OPERABLE status.
D. Required Action and      D.1      Be in MODE 3.                          [[estimated NRC review hours::12 hours]] associated Completion Time of Condition C      AND not met.
D.2      Be in 1"10DE 4.                        [[estimated NRC review hours::36 hours]] SURVEILLANCE REQUIREMENTS SURVEI LLANCE                                              FREQUENCY SR  3.7.1.1    Verify 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. 194/181


A. One RHRSW subsystem inoperable.
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.l ------NOTE -----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 subsystem to OPERABLE status. 7 days (continued)
: a.       Three DGCW subsystems; and
LaSalle 1 and 2 3.7.1-1 Amendment No. 194/181 RHRSW System 3.7.1 ACTIONS CONDITION REQU I RED ACTI ON COMP LETI  TIME B. Required Action and associated Completion Time of Condition A not met. B.1 Be in MODE 3. 12 hours C. Both RHRSW subsystems inoperable.
: b.       The opposite unit Division 2 DGCW subsystem.
C.1 --------NOTE --------Enter applicable Conditions and Required Actions of LCO 3.4.9 for RHR shutdown cooling subsystems made inoperable by RHRSW System.
APPLICABILITY:                   MODES 1, 2, and 3.
Restore one RHRSW subsystem to OPERABLE status. 8 hours D. Required Action and associated Completion Time of Condition C not met. D.1 AND D.2 Be in MODE 3. Be in 1"10DE 4. 12 hours 36 hours SURVEILLANCE SURVEI LLANCE FREQUENCY SR 3.7.1.1 Verify each RHRSW 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 or can be aligned to the correct position.
ACTI ONS
31 days LaSalle 1 and 2 3.7.1-2 Amendment No. 194/181 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:  
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
: a. Three DGCW subsystems; and b. The opposite unit Division 2 DGCW subsystem.
APPLICABILITY:
MODES 1, 2, and 3. ACTI ONS -------------------------------------
NOTE------------------------------------
Separate Condition entry is allowed for each DGCW subsystem.
Separate Condition entry is allowed for each DGCW subsystem.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGCW subsystems inoperable.
CONDITION                                             REQUIRED ACTION                               COMPLETION TIME A.     One or more DGCW                                 A.1             Declare supported                           Immediately subsystems inoperable.                                          component(s) inoperable.
A.1 Declare supported component(s) inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                                 FREQUENCY SR     3.7.2.1               Veri fy each DGCW subsystem manua 1, 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.
Immediately SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.7.2.1 Veri fy each DGCW subsystem manua 1, 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     3.7.2.2               Verify each DGCW pump starts automatically                                             24 months on each required actual or simulated initiation signal.
31 days SR 3.7.2.2 Verify each DGCW pump starts automatically on each required actual or simulated initiation signal. 24 months LaSalle 1 and 2 3.7.2-1 Amendment No. 194/181 AC Sources-Operating 3.8.1 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME C. Required Division 3 DG inoperable.
LaSalle 1 and 2                                                       3.7.2-1                                 Amendment No. 194/181
One required Division 1, 2, 0 r 3 DG inoperable and the required opposite unit Division 2 DG inoperable.
 
C.1 AND C.2 Perform SR 3.8.1.1 for OPERABLE required offsite circuit(s).
AC Sources-Operating 3.8.1 ACTIONS CONDITION                 REQU I RED ACTI ON         COMPLETION TIME C. Required Division 3 DG C.1     Perform SR 3.8.1.1      1 hour inoperable.                    for OPERABLE required offsite circuit(s).      AND Once per One required Division                                    [[estimated NRC review hours::8 hours]] 1, 2, 0 r 3 DG                                          thereafter inoperable and the required opposite unit AND Division 2 DG inoperable.           C.2     Declare required        [[estimated NRC review hours::4 hours]] from feature(s), supported   discovery of by the inoperable       Condition C DG(s), inoperable       concurrent with when the redundant       inoperability required feature(s)     of redundant are inoperable.         required feature(s)
Declare required feature(s), supported by the inoperable DG(s), inoperable when the redundant required feature(s) are inoperable.
C.3.1   Determine OPERABLE      [[estimated NRC review hours::24 hours]] DG(s) are not inoperable due to common cause failure.
1 hour AND Once per 8 hours thereafter 4 hours from discovery of Condition C concurrent with inoperability of redundant required feature(s)
OR C.3.2    Perform SR 3.8.1.2       [[estimated NRC review hours::24 hours]] for OPERABLE DG(s).
C.3.1 OR C.3.2 Determine OPERABLE DG(s) are not inoperable due to common cause failure. Perform SR 3.8.1.2 for OPERABLE DG(s). 24 hours 24 hours C.4 Restore required DG(s) to OPERABLE status. 72 hours 17 days from discovery of failure to meet LCO 3.8.La or b (continued)
C.4     Restore required         [[estimated NRC review hours::72 hours]] DG(s) to OPERABLE status.
LaSalle 1 and 2 3.8.1-4 Amendment No. 194/181 AC Sources-Operating 3.8.1 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME F. Two required Division 1, 2, or 3 DGs inoperable. .DR Division 2 DG and the required opposite unit Division 2 DG inoperable.
17 days from discovery of failure to meet LCO 3.8.La or b (continued)
F.l Restore one required DG to OPERABLE status. 2 hours 72 hours if Division 3 DG is inoperable G. Required Action and associated Completion Time of Condition A, B, C, D, E, or F not met. G.l Be in MODE 3. 12 hours H. Three or more required AC sources inoperable.
LaSalle 1 and 2                   3.8.1-4               Amendment No. 194/181
H.l Enter LCO 3.0.3. Immediately LaSalle 1 and 2 3.8.1-6 Amendment  194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS ------------------------------------
 
NOTES -----------------------------------SR 3.8.1.1 through SR 3.8.1.20 are applicable only to the given unit's AC electrical power sources. 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 -------------------
AC Sources-Operating 3.8.1 ACTI ONS CONDITION             REQUIRED ACTION           COMPLETION TIME F. Two required Division   F.l  Restore one required    [[estimated NRC review hours::2 hours]] 1, 2, or 3 DGs               DG to OPERABLE inoperable.                 status.
NOTES------------------All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.
      .DR                                                   [[estimated NRC review hours::72 hours]] if Division 3 DG Division 2 DG and the                               is inoperable required opposite unit Division 2 DG inoperable.
When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met. 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)
G. Required Action and   G.l  Be in MODE 3.          [[estimated NRC review hours::12 hours]] associated Completion Time of Condition A, B, C, D, E, or F not met.
LaSalle 1 and 3.8.1-7 Amendment 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.3 -------------------
H. Three or more required H.l   Enter LCO 3.0.3.       Immediately AC sources inoperable.
NOTES ------------------
LaSalle 1 and 2                   3.8.1-6               Amendment  I~o. 194/181
: 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 loaded and operates for 60 minutes at load 2400 kW and s 2600 kW. and a 31 days SR 3.8.1.4 Verify each required day tank contains  250 gal of fuel oil for Divisions 1 and and 550 gal for Division 3. 2 31 days SR 3.8.1.5 Check for and remove accumulated each required day tank. water from 31 days SR 3.8.1.6 Veri fy each requi red fuel oi 1 transfer system operates to automatically transfer fuel oi 1 from storage tanks to the day tank. 92 days (continued)
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS
LaSalle 1 and 2 3.8.1-8 Amendment No. 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.7 -------------------
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOT ES - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
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.
: 1. All DG sta rts 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 condition and achieves:  
: 2.          SR 3.8.1.21 is applicable to the required opposite unit's DG.
: a. In s 13 seconds, voltage 4010 V and frequency 58.8 Hz; and b. Steady state voltage 4010 V and s 4310 V and frequency 58.8 Hz and s 61.2 Hz. 184 days SR 3.8.1.8 -------------------
SURVEI LLANCE                                                               FREQUENCY SR     3.8.1.1               Verify correct breaker alignment and                                                 7 days indicated power availability for each required offsite circuit.
NOTE -------------------
SR     3.8.1.2               - - - - - - - - - - - - - - - - - - - NOTE S- - - - - - - - - - - - - - - - - -
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.
: 1.        All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
Credit may be taken for unplanned events that satisfy this SR. Verify manual transfer of unit power supply from the normal offsite circuit to the alternate offsite circuit. 24 months (continued)
: 2.        A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.
LaSalle 1 and 2 3.8.1-9 Amendment 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SR 3.8.1.9 SURVEI LLANCE ------------------
When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.
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.
: 3.        A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.
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. FREQUENCY Verify each required DG rejects a load greater than or equal to its associated single largest post-accident load and following load rejection, the frequency  
Verify each required DG starts from standby                                           31 days conditions and achieves steady state voltage ~ 4010 V and ~ 4310 V and frequency
::; 66.7 Hz. is 24 months SR 3.8.1.10 ----------------- OTE S--------------------
                              ~ 58.8 Hz and ~ 61.2 Hz.
: 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.
(continued)
Credit may be taken for unplanned events that satisfy this SR. 2. A single test of the common OG at the specified Frequency will satisfy the Surveillance for both units. Verify each required DG does not trip and voltage is maintained::;
LaSalle 1 and 2                                                      3.8.1-7                                 Amendment         I~o. 194/181
5000 V during and following a load rejection of a load 2600 kW. 24 months (continued)
 
LaSalle 1 and 2 3.8.1-10 Amendment No. 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE 3.8.1.11 -------------------
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                         FREQUENCY SR 3.8.1.3   - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -
NOTES------------------All DG starts may be preceded by an engine prelube period. 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.
: 1.       DG loadings may include gradual loading as recommended by the manufacturer.
Credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated loss of offsite power signal: De-energization of emergency buses; Load shedding from emergency buses for Divisions 1 and 2 only; and DG auto-starts from standby condition and: energizes permanently connected loads in 13 seconds, energizes auto-connected shutdown loads, maintains steady state voltage Z 4010 V and 4310 V, maintains steady state frequency z 58.8 Hz and 61.2 Hz, and supplies permanently connected and auto-connected shutdown loads for z 5 minutes.
: 2.       Momentary transients outside the load range do not invalidate this test.
24 months (continued)
: 3.       This Surveillance shall be conducted on only one DG at a time.
LaSalle 1 and 3.8.1-11 Amendment No. 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.12 ------------------
: 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.
------------------All DG sta rts may be preceded by an engine prelube period. 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.
: 5.       A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.
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: In s 13 seconds after auto-start, achieves voltage 4010 V and frequency 58.8 Hz; Achieves steady state voltage 4010 V and s 4310 V and frequency 58.8 Hz and s 61.2 Hz; and Operates for  5 minutes. (continued)
Verify each required DG is synchronized and                                        31 days loaded and operates for ~ 60 minutes at a load ~ 2400 kW and s 2600 kW.
LaSalle 1 and 3.8.1-12 Amendment No. 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.13 -------------------
SR 3.8.1.4   Verify each required day tank contains                                             31 days
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.
                ~ 250 gal of fuel oil for Divisions 1 and 2 and ~ 550 gal for Division 3.
Credit may be taken for unplanned events that satisfy this SR. Verify each required DG's automatic trips are bypassed on an actual or simulated ECCS initiation signal except: a. Engine overspeed; and b. Generator differential current. 24 months (continued)
SR 3.8.1.5   Check for and remove accumulated water from                                        31 days each required day tank.
LaSalle 1 and 2 3.8.1-13 Amendment No. 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE SR SUR VEIL LA NC-------------------
SR 3.8.1.6   Veri fy each requi red fuel oi 1 transfer                                         92 days system operates to automatically transfer fuel oi 1 from storage tanks to the day tank.
NOTES ------------------Momentary transients outside the load and power factor ranges do not invalidate this test. This Surveillance shall not normally be performed in MODE 1 or 2 unless the other two DGs are OPERABLE.
(continued)
If either of the other two DGs becomes inoperable, this Surveillance shall be suspended.
LaSalle 1 and 2                                       3.8.1-8                               Amendment No. 194/181
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. 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. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units. Verify each required DG operating within the power factor limit operates for 24 hours: For 2 hours loaded 2860 kW; and For the remaining hours of the test loaded 2400 kW and 2600 kW.
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                           FREQUENCY SR 3.8.1.7   - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -
24 months (continued)
: 1.       All DG sta rts may be preceded by an engine prelube period.
LaSalle 1 and 3.8.1-14 Amendment 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE SURVEILLANCE FREQUENCY SR 3.8.1.15 -------------------
: 2.       A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.
NOTES ------------------
Verify each required DG starts from standby                                         184 days condition and achieves:
: 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 hours loaded 2400 kW and s 2600 kW. Momentary transients outside of load range do not invalidate this test. 2. All DG sta rts may be preceded by engine prelube period. an 3. A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units. Verify each achieves:
: a.       In s 13 seconds, voltage                     ~  4010 V and frequency ~ 58.8 Hz; and
required DG starts and 24 months a. In s 13 seconds, voltage frequency 58.8 Hz; and 4010 V and b. Steady state voltage s 4310 V and frequency and s 61.2 Hz. 4010 V and  58.8 Hz (continued)
: b.       Steady state voltage ~ 4010 V and s 4310 V and frequency ~ 58.8 Hz and s 61.2 Hz.
LaSalle 1 and 2 3.8.1-15 Amendment  194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR -------------------
SR 3.8.1.8   - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - -
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.
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.
Verify manual transfer of unit power supply                                         24 months from the normal offsite circuit to the alternate offsite circuit.
Credit may be taken for unplanned events that satisfy this SR. Verify each required DG: 24 months Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite powe r; Transfers loads to offsite power source; and Returns to ready-to-load operation. (continued)
(continued)
LaSalle 1 and 3.8.1-16 Amendment No. 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.17 -------------------
LaSalle 1 and 2                                       3.8.1-9                                 Amendment I~o. 194/181
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.
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE                                                          FREQUENCY SR 3.8.1.9     - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -
Credit may be taken for unplanned events that satisfy this SR. Verify, with a required DG operating in 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. 24 months SR 3.8.1.18 -------------------
: 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.
NOT E--------------------
Credit may be taken for unplanned events that satisfy this SR.
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.
: 2.       A single test of the common DG at the specified Frequency will satisfy the Surveillance for both units.
Credit may be taken for unplanned events that satisfy this SR. Veri fy i nterva 1 between each sequenced load block, for Division 1 and 2 DGs only, is 2 90% of the design interval for each time delay relay. 24 months (continued)
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
LaSalle 1 and 2 3.8.1-17 Amendment No. 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURV EI 3.8.1.19 -------------------
::; 66.7 Hz.
NOTES------------------All DG starts may be preceded by an engine prelube period. 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.
SR 3.8.1.10   - - - - - - - - - - - - - - - - - I~ OTE S- - - - - - - - - - - - - - - - - - - -
Credit may be taken for unplanned events that satisfy this SR. Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal: De-energization of emergency buses; Load shedding from emergency buses for Divisions 1 and 2 only; and DG auto-starts from standby condition and: energizes permanently connected loads in 13 seconds, energizes auto-connected emergency loads including through time delay relays, where applicable, maintains steady state voltage 4010 V and 4310 V, maintains steady state frequency 58.8 Hz and 61.2 Hz, and supplies permanently connected and auto-connected emergency loads for 5 minutes.
: 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.
24 months (continued)
Credit may be taken for unplanned events that satisfy this SR.
LaSalle 1 and 3.8.1-18 Amendment No. 194/181 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.20 -------------------
: 2.         A single test of the common OG at the specified Frequency will satisfy the Surveillance for both units.
NOTE -------------------
Verify each required DG does not trip and                                             24 months voltage is maintained::; 5000 V during and following a load rejection of a load
All DG starts may be preceded by an engine prelube period. Verify, when started simultaneously from standby condition, each required DG achieves, in 13 seconds, voltage 4010 V and frequency 58.8 Hz. 10 years SR 3.8.1.21 -------------------
                ~ 2600 kW.
NOT E--------------------
(continued)
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:
LaSalle 1 and 2                                       3.8.1-10                                 Amendment No. 194/181
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 the opposite unit's Specification 3.8.1, except SR 3.8.1.12, SR 3.8.1.13, SR 3.8.1.17, SR 3.8.1.18, SR 3.8.1.19, and SR 3.8.1.20, are applicable.
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                          FREQUENCY SR  3.8.1.11   - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -
In accordance with applicable SRs LaSalle 1 and 2 3.8.1-19 Amendment No. 194/181 Reporting Requirements 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued) The Rod Block Monitor Upscale Instrumentation Setpoint for the Rod Block Monitor-Upscale Function Allowable Value for Specification 3.3.2.1. The OPRM setpoints for the trip function for SR 3.3.1.3.3. 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: ANF-524(P)(A), "ANF Critical Power Methodology for Boiling Water Reactors." ANF-913(P)(A), "COTRANSA 2: A Computer Program for Boiling Water Reactor Transient Analysis." MF-CC-33(P)(A), "HUXY: A Generalized Il1ultirod Heatup Code with 10 CFR 50, Appendix K Heatup Option." XN-NF-80-19(P)(A), "Advanced Nuclear Fuel Methodology for Boiling Water Reactors." XN-NF-85-67(P)(A), "Generic Mechanical Design for Exxon Jet Pump BWR Reload Fuel." EMF-CC-074(P)(A), Volume 4 -"BWR Stability Analysis:
: 1.        All DG starts may be preceded by an engine prelube period.
Assessment of STAIF with input from MICROBURN-B2." XN-NF-81-58(P)(A), "RODEX2 Fuel Rod Thermal-Mechanical Response Evaluation Model." XN-NF-84-105(P)(A), "XCOBRA-T:
: 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.
A Computer Code for BWR Transient Thermal-Hydraulic Core Analysis." (continued)
Verify on an actual or simulated loss of                                           24 months offsite power signal:
LaSalle 1 and 2 Amendment No. 194/181 UNITED NUCLEAR REGULATORY WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 194 TO FACILITY OPERATING LICENSE NO. NPF-11 AND AMENDMENT NO. 181 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  
: 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 Z   4010 V and ~ 4310 V,
: 4.      maintains steady state frequency z 58.8 Hz and           ~ 61.2 Hz, and
: 5.      supplies permanently connected and auto-connected shutdown loads for z 5 minutes.
(continued)
LaSalle 1 and 2                                      3.8.1-11                               Amendment No. 194/181
 
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE                                                         FREQUENCY SR 3.8.1.12   - - - - - - - - - - - - - - - - - - -I~OTES - - - - - - - - - - - - - - - - - -
: 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 Emergency                                         24 months Core Cooling System (ECCS) initiation signal each required DG auto-starts from standby condition and:
: a.        In s 13 seconds after auto-start, achieves voltage ~ 4010 V and frequency ~ 58.8 Hz;
: b.      Achieves steady state voltage ~ 4010 V and s 4310 V and frequency ~ 58.8 Hz and s 61.2 Hz; and
: c.      Operates for             ~ 5 minutes.
(continued)
LaSalle 1 and 2                                      3.8.1-12                               Amendment No. 194/181
 
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. 194/181
 
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SUR VEIL LA NCE                                                      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
                ~ [[estimated NRC review hours::24 hours]]:
: a.        For   ~  [[estimated NRC review hours::2 hours]] loaded           ~  2860 kW; and
: b.        For the remaining hours of the test loaded ~ 2400 kW and ~ 2600 kW.
(continued)
LaSalle 1 and 2                                      3.8.1-14                               Amendment   I~o. 194/181
 
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                         FREQUENCY SR 3.8.1.15   - - - - - - - - - - - - - - - - - - -NOTES - - - - - - - - - - - - - - - - - -
: 1.       This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated ~ [[estimated NRC review hours::2 hours]] loaded ~ 2400 kW and s 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 s 13 seconds, voltage                   ~  4010 V and frequency ~ 58.8 Hz; and
: b.       Steady state voltage               ~  4010 V and s 4310 V and frequency                   ~  58.8 Hz and s 61.2 Hz.
(continued)
LaSalle 1 and 2                                     3.8.1-15                               Amendment  I~o. 194/181
 
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE                                                         FREQUENCY SR 3.8.1.16  - - - - - - - - - - - - - - - - - - - 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:                                                           24 months
: a.        Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite powe r;
: 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. 194/181
 
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE                                                           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   - - - - - - - - - - - - - - - - - - - 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.
Veri fy i nterva 1 between each sequenced load                                     24 months block, for Division 1 and 2 DGs only, is 2 90% of the design interval for each time delay relay.
(continued)
LaSalle 1 and 2                                       3.8.1-17                               Amendment No. 194/181
 
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURV EI LLANCE                                                        FREQUENCY SR  3.8.1.19   - - - - - - - - - - - - - - - - - - - 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 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. 194/181
 
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE                                                         FREQUENCY SR 3.8.1.20   - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - -
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 ~ 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. 194/181
 
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), "ANF Critical Power Methodology for Boiling Water Reactors."
: 2. ANF-913(P)(A), "COTRANSA 2: A Computer Program for Boiling Water Reactor Transient Analysis."
: 3. MF-CC-33(P)(A), "HUXY: A Generalized Il1ultirod 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 I~uclear 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. 194/181
 
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 194 TO FACILITY OPERATING LICENSE NO. NPF-11 AND AMENDMENT NO. 181 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==
==1.0 INTRODUCTION==


By letter to the U.S. Nuclear Regulatory Commission (NRC) dated September 11, 2008, (Agencywide Documents Access and lVIanagement 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).
By letter to the U.S. Nuclear Regulatory Commission (NRC) dated September 11, 2008, (Agencywide Documents Access and lVIanagement 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),
1.1 Proposed License Amendment The proposed TS changes would remove the TS that applied only during Unit 1 Refueling Outage 11, Unit2 Refueling Outage 11 and Unit 1 Refueling Outage 12 in TS 3.7.1, Residual Heat Removal (RHR)
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).
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.
1.1 Proposed License Amendment The proposed TS changes would remove the TS that applied only during Unit 1 Refueling Outage 11, Unit2 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."
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
Specifically, the proposed changes would remove the following notes, conditions, required actions and completion times as described below:
-4, 5, or defueled.
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.
: 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 B, Required Action B.1 and the associated completion time, a 6-day (for Division 2 CSCS valve maintenance) or 1 O-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.
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 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 B 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.
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.
: 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.
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. 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, B, 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. 
-


==2.0 REGULATORY EVALUATION==
                                                - 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 B, Required Action B.1 and the associated completion time, a 6-day (for Division 2 CSCS valve maintenance) or 1O-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 B 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 B 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, B, 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.


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:
                                                  - 3
(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 
-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-t\lF-524(P)(A), "At\lF 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 1 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 one-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==
==2.0       REGULATORY EVALUATION==


In accordance with the Commission's regulations, the Illinois State official was notified of the proposed issuance of the amendments.
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."
The State official had no comments.
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:
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.
* 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.
The amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9).
* 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.
In addition, the amendment changes are administrative.
* 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.
Accordingly, the amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(1 0). 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.
* 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.
-


==6.0 CONCLUSION==
==3.0       TECHNICAL EVALUATION==


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:
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
K. Bucholtz Date: August 28,2009 Mr. Charles G. Pardee August28,2009 President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 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:==
                                                    - 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.
The U.S. Nuclear Regulatory Commission (the Commission) has issued the enclosed Amendment No. 194 to Facility Operating License No. NPF-11 and Amendment No. 181 to Facility Operating License No. NPF-18 for the LaSalle County Station, Units 1 and 2, respectively.
Additionally, there is an administrative correction to TS Section 5.6.5, "Core Operating Limits Report." The topical report XN-t\lF-524(P)(A), "At\lF Critical Power Methodology for Boiling Water Reactors" referenced in TS 5.6.5 is being administratively changed to ANF-524(P)(A),
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).
"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 1 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 one-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)(1 0). 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.
 
                                            - 5
 
==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 28,2009
 
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.
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.
A copy of the Safety Evaluation is also enclosed. The Notice of Issuance will be included in the Commission's biweekly Federal Register notice.
The Notice of Issuance will be included in the Commission's biweekly Federal Register notice. Sincerely, IRA! 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  
Sincerely, IRA!
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:==
==Enclosures:==
: 1. Amendment No. 194 to NPF-11 2. Amendment No. 181 to NPF-18 3. Safety Evaluation cc w/encls: See next page DISTRIBUTION:
: 1. Amendment No. 194 to NPF-11
PUBLIC RidsNrrDorlDpr Resource RidsNrrPMLaSalle Resource RidsOgcRp Resource RidsNrrDirsltsb Resource RidsRgn3MailCenter Resource RidsNrrDorlLpl3-2 Resource RidsNrrLATHarris Resource LPL3-2 R/F RidsAcrsAcnw
: 2. Amendment No. 181 to NPF-18
_MailCTR Resource Amendment Accession No ML092040273 NRR-058 *Concurrence via memo dated OFFICE LPL3-2/PM LPL3-2/LA DIRSIITSB OGC(NLO) LPL3-2/BC NAME CGoodwin THarris RElliotl*
: 3. Safety Evaluation cc w/encls: See next page DISTRIBUTION:
LSubin SCampbell DATE 8/17/09 8/13/09 6 116/09 8/21/09 8/28/09 OFFICIAL RECORD COPY Mr. Charles G. Pardee September 3, 2009 President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 LASALLE COUNTY STATION, UNITS 1 AND 2 -CORRECTION LETrER FOR LICENSE AMENDMENT NOS. 193 AND 180 RE: DELETE OBSOLETE LICENSE CONDITIONS AND REVISE TECHNICAL SPECIFICATIONS (TAC NOS. MD9616 AND MD9617)
PUBLIC                         RidsNrrDorlDpr Resource           RidsNrrPMLaSalle Resource RidsOgcRp Resource             RidsNrrDirsltsb Resource         RidsRgn3MailCenter Resource RidsNrrDorlLpl3-2 Resource     RidsNrrLATHarris Resource         LPL3-2 R/F RidsAcrsAcnw_ MailCTR Resource Amendment Accession No ML092040273     NRR-058           *Concurrence via memo dated OFFICE       LPL3-2/PM     LPL3-2/LA         DIRSIITSB         OGC(NLO)       LPL3-2/BC NAME         CGoodwin       THarris           RElliotl*         LSubin         SCampbell DATE           8/17/09       8/13/09           6 116/09         8/21/09       8/28/09


==Dear Mr. Pardee:==
ML082550530), as supplemented by letter dated August 11, 2009 (ADAMS Accession No. ML092240199).
By letter dated August 27,2009 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML092040273), the Nuclear Regulatory Commission (NRC) staff issued Amendment Nos. 193 and 180 to Facility Operating License Nos. NPF-11 and NPF-18 for the LaSalle County Station, Units 1 and 2, respectively.
Administrative errors were identified in the amendments. The amendments were incorrectly dated. They should be dated for August 28,2009. It was also noted that the amendment numbers used were incorrect. The correct amendment numbers are 194 and 181 for LaSalle County Station, Units 1 and 2, respectively. Please replace the amendments dated August 27, 2009, with the enclosed amendments.
The amendments remove time, cycle, or modification-related items from the operating licenses and Technical Specifications in response to your application dated September 11, 2008 (ADAMS Accession No. ML082550530), as supplemented by letter dated August 11, 2009 (ADAMS Accession No. ML092240199).
Administrative errors were identified in the amendments.
The amendments were incorrectly dated. They should be dated for August 28,2009. It was also noted that the amendment numbers used were incorrect.
The correct amendment numbers are 194 and 181 for LaSalle County Station, Units 1 and 2, respectively.
Please replace the amendments dated August 27, 2009, with the enclosed amendments.
The incorrect information was editorial in nature. The corrections do not change the approval conveyed by the amendments, or the conclusions reached by the associated safety evaluation.
The incorrect information was editorial in nature. The corrections do not change the approval conveyed by the amendments, or the conclusions reached by the associated safety evaluation.
We regret any inconvenience this may have caused you. Sincerely, IRA! 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  
We regret any inconvenience this may have caused you.
Sincerely, IRA!
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


==Enclosure:==
==Enclosure:==


Amendments dated August 28, 2009 cc w/encl: Distribution via ListServ DISTRIBUTION:
Amendments dated August 28, 2009 cc w/encl: Distribution via ListServ DISTRIBUTION:
PUBLIC LPL3-2 R1F RidsNrrPMLaSalie Resource RidsOgcRp Resource RidsNrrDirsltsb Resource RidsRgn3MailCenter Resource RidsNrrDorlLpl3-2 Resource RidsNrrLATHarris Resource RidsNrrDorlDpr Resource RidsAcrsAcnw_MailCTR Resource ADAMS Accession No M092450404 NRR-106 OFFICE LPL3-2/PM LPL3-2/LA LPL3-2/BC NAME CGoodwin THarris SCampbell DATE 9/3/09 9/2/09 9/3/09 OFFICIAL RECORD COPY}}
PUBLIC           LPL3-2 R1F     RidsNrrPMLaSalie Resource RidsOgcRp Resource             RidsNrrDirsltsb Resource RidsRgn3MailCenter Resource     RidsNrrDorlLpl3-2 Resource RidsNrrLATHarris Resource       RidsNrrDorlDpr Resource RidsAcrsAcnw_MailCTR Resource ADAMS Accession No M092450404           NRR-106 OFFICE       LPL3-2/PM     LPL3-2/LA         LPL3-2/BC NAME         CGoodwin       THarris           SCampbell DATE         9/3/09         9/2/09             9/3/09}}

Latest revision as of 00:09, 22 March 2020

Correction Letter for License Amendment Nos. 193 and 180 Obsolete License Conditions and Revise Technical Specifications
ML092450404
Person / Time
Site: LaSalle  Constellation icon.png
Issue date: 09/03/2009
From: Goodwin C
Plant Licensing Branch III
To: Pardee C
Exelon Nuclear
Goodwin, Cameron S, NRR/DORL, 415-3719
References
TAC MD9616, TAC MD9617
Download: ML092450404 (48)
v • d • e


Text

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 September 3, 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 - CORRECTION LETTER FOR LICENSE AMENDMENT NOS. 193 AND 180 RE: DELETE OBSOLETE LICENSE CONDITIONS AND REVISE TECHNICAL SPECIFICATIONS (TAC NOS. MD9616 AND MD9617)

Dear Mr. Pardee:

By letter dated August 27, 2009 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML092040273), the Nuclear Regulatory Commission (NRC) staff issued Amendment Nos. 193 and 180 to Facility Operating License Nos. NPF-11 and NPF-18 for the LaSalle County Station, Units 1 and 2, respectively. The amendments remove time, cycle, or modification-related items from the operating licenses and Technical Specifications in response to your application dated September 11, 2008 (ADAMS Accession No. ML082550530), as supplemented by letter dated August 11, 2009 (ADAMS Accession No. ML092240199).

Administrative errors were identified in the amendments. The amendments were incorrectly dated. They should be dated for August 28, 2009. It was also noted that the amendment numbers used were incorrect. The correct amendment numbers are 194 and 181 for LaSalle County Station, Units 1 and 2, respectively. Please replace the amendments dated August 27, 2009, with the enclosed amendments.

The incorrect information was editorial in nature. The corrections do not change the approval conveyed by the amendments, or the conclusions reached by the associated safety evaluation.

We regret any inconvenience this may have caused you.

Sincerely, 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

Enclosure:

Amendments dated August 28, 2009 cc w/encl: Distribution via ListServ

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 August28,2009 Mr. Charles G. Pardee President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 SUB.JECT: 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. 194 to Facility Operating License No. NPF-11 and Amendment No. 181 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, a~tL<!VJ,J/;--~~~/~

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. 194 to NPF-11
2. Amendment No. 181 to NPF-18
3. Safety Evaluation cc wlencls: 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. 194 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. 194, 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.

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 28, 2009

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 EXELON GENERATION COMPANY, LLC DOCKET NO. 50-374 LASALLE COUNTY STATION, UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 181 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. 181, 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 NUCLEARc:4ULATORY COMMISSION s~m~~ell'~

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 28, 2009

ATTACHMENT TO LICENSE AMENDMENT NOS. 194 AND 181 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 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.19~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. I\JPF-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 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.

The Training and Qualification Plan and Safeguards Contingency Plan are Appendices to the Security Plan.

-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 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. 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.18~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 Speci'f!cations 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. I\IPF-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\ 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. t\lPF-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-1 013)
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.

ACTI ONS CONDITION REQU I RED ACTI ON CO~IPLETION TI~IE A. One RHRSW subsystem A.l - - - - - - 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. 194/181

RHRSW System 3.7.1 ACTIONS CONDITION REQU I RED ACTI ON COMP LETI Ol~ TIME B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 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 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> subsystem to OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> associated Completion Time of Condition C AND not met.

D.2 Be in 1"10DE 4. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.7.1.1 Verify 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. 194/181

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.

ACTI ONS

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

Separate Condition entry is allowed for each DGCW subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGCW A.1 Declare supported Immediately subsystems inoperable. component(s) inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Veri fy each DGCW subsystem manua 1, 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 3.7.2.2 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. 194/181

AC Sources-Operating 3.8.1 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME C. Required Division 3 DG C.1 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 hours0.333 days <br />0.0476 weeks <br />0.011 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 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> from feature(s), supported discovery of by the inoperable Condition C DG(s), inoperable concurrent with when the redundant inoperability required feature(s) of redundant are inoperable. required feature(s)

C.3.1 Determine OPERABLE 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> DG(s) are not inoperable due to common cause failure.

OR C.3.2 Perform SR 3.8.1.2 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> for OPERABLE DG(s).

C.4 Restore required 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> DG(s) to OPERABLE status.

17 days from discovery of failure to meet LCO 3.8.La or b (continued)

LaSalle 1 and 2 3.8.1-4 Amendment No. 194/181

AC Sources-Operating 3.8.1 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME F. Two required Division F.l Restore one required 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> 1, 2, or 3 DGs DG to OPERABLE inoperable. status.

.DR 72 hours3 days <br />0.429 weeks <br />0.0986 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 hours0.5 days <br />0.0714 weeks <br />0.0164 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 I~o. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOT ES - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

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 - - - - - - - - - - - - - - - - - - - NOTE S- - - - - - - - - - - - - - - - - -

1. All DG starts 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 I~o. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.3 - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -

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 s 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 Veri fy each requi red fuel oi 1 transfer 92 days system operates to automatically transfer fuel oi 1 from storage tanks to the day tank.

(continued)

LaSalle 1 and 2 3.8.1-8 Amendment No. 194/181

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

1. All DG sta rts 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 s 13 seconds, voltage ~ 4010 V and frequency ~ 58.8 Hz; and
b. Steady state voltage ~ 4010 V and s 4310 V and frequency ~ 58.8 Hz and s 61.2 Hz.

SR 3.8.1.8 - - - - - - - - - - - - - - - - - - - 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 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 I~o. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.9 - - - - - - - - - - - - - - - - - - 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 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 - - - - - - - - - - - - - - - - - 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 OG 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. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 - - - - - - - - - - - - - - - - - - - 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 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 Z 4010 V and ~ 4310 V,
4. maintains steady state frequency z 58.8 Hz and ~ 61.2 Hz, and
5. supplies permanently connected and auto-connected shutdown loads for z 5 minutes.

(continued)

LaSalle 1 and 2 3.8.1-11 Amendment No. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.12 - - - - - - - - - - - - - - - - - - -I~OTES - - - - - - - - - - - - - - - - - -

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 Emergency 24 months Core Cooling System (ECCS) initiation signal each required DG auto-starts from standby condition and:

a. In s 13 seconds after auto-start, achieves voltage ~ 4010 V and frequency ~ 58.8 Hz;
b. Achieves steady state voltage ~ 4010 V and s 4310 V and frequency ~ 58.8 Hz and s 61.2 Hz; and
c. Operates for ~ 5 minutes.

(continued)

LaSalle 1 and 2 3.8.1-12 Amendment No. 194/181

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. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SUR VEIL LA NCE 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

~ 24 hours1 days <br />0.143 weeks <br />0.0329 months <br />:

a. For ~ 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> loaded ~ 2860 kW; and
b. For the remaining hours of the test loaded ~ 2400 kW and ~ 2600 kW.

(continued)

LaSalle 1 and 2 3.8.1-14 Amendment I~o. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.15 - - - - - - - - - - - - - - - - - - -NOTES - - - - - - - - - - - - - - - - - -

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated ~ 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> loaded ~ 2400 kW and s 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 s 13 seconds, voltage ~ 4010 V and frequency ~ 58.8 Hz; and
b. Steady state voltage ~ 4010 V and s 4310 V and frequency ~ 58.8 Hz and s 61.2 Hz.

(continued)

LaSalle 1 and 2 3.8.1-15 Amendment I~o. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.16 - - - - - - - - - - - - - - - - - - - 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: 24 months

a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite powe r;
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. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE 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 - - - - - - - - - - - - - - - - - - - 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.

Veri fy i nterva 1 between each sequenced load 24 months block, for Division 1 and 2 DGs only, is 2 90% of the design interval for each time delay relay.

(continued)

LaSalle 1 and 2 3.8.1-17 Amendment No. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURV EI LLANCE FREQUENCY SR 3.8.1.19 - - - - - - - - - - - - - - - - - - - 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 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. 194/181

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.20 - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - -

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 ~ 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. 194/181

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), "ANF Critical Power Methodology for Boiling Water Reactors."
2. ANF-913(P)(A), "COTRANSA 2: A Computer Program for Boiling Water Reactor Transient Analysis."
3. MF-CC-33(P)(A), "HUXY: A Generalized Il1ultirod 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 I~uclear 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. 194/181

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 194 TO FACILITY OPERATING LICENSE NO. NPF-11 AND AMENDMENT NO. 181 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 lVIanagement 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, Unit2 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 B, Required Action B.1 and the associated completion time, a 6-day (for Division 2 CSCS valve maintenance) or 1O-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 B 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 B 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, B, 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.

- 3

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-t\lF-524(P)(A), "At\lF 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 1 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 one-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)(1 0). 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 28,2009

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, IRA!

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. 194 to NPF-11
2. Amendment No. 181 to NPF-18
3. Safety Evaluation cc w/encls: See next page DISTRIBUTION:

PUBLIC RidsNrrDorlDpr Resource RidsNrrPMLaSalle Resource RidsOgcRp Resource RidsNrrDirsltsb Resource RidsRgn3MailCenter Resource RidsNrrDorlLpl3-2 Resource RidsNrrLATHarris Resource LPL3-2 R/F RidsAcrsAcnw_ MailCTR Resource Amendment Accession No ML092040273 NRR-058 *Concurrence via memo dated OFFICE LPL3-2/PM LPL3-2/LA DIRSIITSB OGC(NLO) LPL3-2/BC NAME CGoodwin THarris RElliotl* LSubin SCampbell DATE 8/17/09 8/13/09 6 116/09 8/21/09 8/28/09

ML082550530), as supplemented by letter dated August 11, 2009 (ADAMS Accession No. ML092240199).

Administrative errors were identified in the amendments. The amendments were incorrectly dated. They should be dated for August 28,2009. It was also noted that the amendment numbers used were incorrect. The correct amendment numbers are 194 and 181 for LaSalle County Station, Units 1 and 2, respectively. Please replace the amendments dated August 27, 2009, with the enclosed amendments.

The incorrect information was editorial in nature. The corrections do not change the approval conveyed by the amendments, or the conclusions reached by the associated safety evaluation.

We regret any inconvenience this may have caused you.

Sincerely, IRA!

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

Enclosure:

Amendments dated August 28, 2009 cc w/encl: Distribution via ListServ DISTRIBUTION:

PUBLIC LPL3-2 R1F RidsNrrPMLaSalie Resource RidsOgcRp Resource RidsNrrDirsltsb Resource RidsRgn3MailCenter Resource RidsNrrDorlLpl3-2 Resource RidsNrrLATHarris Resource RidsNrrDorlDpr Resource RidsAcrsAcnw_MailCTR Resource ADAMS Accession No M092450404 NRR-106 OFFICE LPL3-2/PM LPL3-2/LA LPL3-2/BC NAME CGoodwin THarris SCampbell DATE 9/3/09 9/2/09 9/3/09

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