Text

Issuance of Amendments Regarding risk-informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program
	ML110200143
Person / Time
Site:	LaSalle
Issue date:	02/24/2011
From:	Ellen Brown; Plant Licensing Branch III
To:	Pacilio M; Exelon Nuclear
	Brown Eva, NRR/DORL, 415-2315
References
	TAC ME3363, TAC ME3364
	Download: ML110200143 (167)
	v • d • e

,fJ 10 UNITED STATES

.... NUCLEAR REGULATORY COMMISSION

<II WASHINGTON, D.C. 20555-0001

~ r;;

~ ~

"'" ~o February 24, 2011

- it11~Michael J. Pacilio President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 SLlB,JECT: LASALLE COUNTY STATION, UNITS 1 AND 2 -ISSUANCE OF AMENDMENTS REGARDING RISK-INFORMED JUSTIFICATION FOR THE RELOCATION OF SPECIFIC SURVEILLANCE FREQUENCY REQUIREMENTS TO A LICENSEE-CONTROLLED PROGRAM (TAC NOS. ME3363 AND ME3364)

Dear Mr. Pacilio:

The U.S. Nuclear Regulatory Commission (the Commission) has issued the enclosed Amendment No. 200 to Facility Operating License No. NPF-11 and Amendment No. 187 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 February 15, 2010 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML100480009), as supplemented by letters dated April 26, June 23, and August 3, 2010 (ADAMS Accession Nos. ML101160374, ML101750102, and ML110390169, respectively).

The requested change is the adoption of Nuclear Regulatory Commission-approved Technical Specification Task Force (TSTF-425), Revision 3, "Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative 5b." When implemented, TSTF-425 relocates most periodic frequencies of Technical Specification (TS) surveillances to a licensee-controlled program, the Surveillance Frequency Control Program, and provides requirements for the new program in the Administrative Controls section of the TS.

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!

Eva Brown, Senior 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. 200 to NPF-11

2. Amendment No. 187 to NPF-18

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

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. 200 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 February 15, 2010, as supplemented by letters dated April 26, June 23, and August 3, 2010, 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. 200 , 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 120 days of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Robert D. Carlson, 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: February 24, 2011

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. 187 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 February 15, 2010, as supplemented by letters dated April 26, June 23, and August 3, 2010, 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. 187 ,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 120 days of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Robert D. Carlson, 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: February 24, 2011

ATTACHMENT TO LICENSE AMENDMENT NOS. 200 AND 187 FACILITY OPERATING LICENSE NOS. NPF-11 AND NPF-18 DOCKET NOS. 50-373 AND 50-374 Replace the following pages of the Facility Operating Licenses and Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert License NPF-11 License NPF-11 Page 3 Page 3 License NPF-18 License NPF-18 Page 3 Page 3 TSs TSs 3.1.3-4 3.1.3-4 3.1.4-2 3.1.4-2 3.1.5-3 3.1.5-3 3.1.6-2 3.1.6-2 3.1.7-1 3.1.7-1 3.1.7-2 3.1.7-2 3.1.7-3 3.1.7-3 3.1.7-4 3.1.7-4 3.1.7-5 3.1.7-5

3.1.7-6 3.1.8-2 3.1.8-2 3.2.1-1 3.2.1-1 3.2.2-1 3.2.2-1 3.2.3-1 3.2.3-1 3.3.1.1-3 3.3.1.1-3 3.3.1.1-4 3.3.1.1-4 3.3.1.1-5 3.3.1.1-5 3.3.1.1-6 3.3.1.1-6 3.3.1.1-7 3.3.1.1-7 3.3.1.1-8 3.3.1.1-8 3.3.1.1-9 3.3.1.1-9

3.3.1.1-10 3.3.1.2-3 3.3.1.2-3 3.3.1.2-4 3.3.1.2-4 3.3.1.2-5 3.3.1.2-5 3.3.1.3-3 3.3.1.3-3

3.3.1.3-4 3.3.2.1-3 3.3.2.1-3 3.3.2.1-4 3.3.2.1-4 3.3.2.1-5 3.3.2.1-5

-2 Remove Insert TSs TSs 3.3.2.2-2 3.3.2.2-2 3.3.2.2-3 3.3.2.2-3 3.3.3.1-3 3.3.3.1-3 3.3.3.2-2 3.3.3.2-2 3.3.4.1-3 3.3.4.1-3 3.3.4.1-4 3.3.4.1-4 3.3.4.2-3 3.3.4.2-3 3.3.5.1-7 3.3.5.1-7 3.3.5.1-8 3.3.5.1-8 3.3.5.1-9 3.3.5.1-9 3.3.5.1-10 3.3.5.1-10 3.3.5.1-11 3.3.5.1-11 3.3.5.1-12 3.3.5.2-3 3.3.5.2-3 3.3.6.1-4 3.3.6.1-4 3.3.6.1-5 3.3.6.1-5 3.3.6.2-3 3.3.6.2-3 3.3.7.1-2 3.3.7.1-2 3.3.7.1-3 3.3.8.1-2 3.3.8.1-2 3.3.8.2-4 3.3.8.2-4 3.4.1-3 3.4.1-3 3.4.2-1 3.4.2-1 3.4.2-2 3.4.2-2 3.4.3-2 3.4.3-2 3.4.5-2 3.4.5-2 3.4.7-3 3.4.7-3 3.4.8-2 3.4.8-2 3.4.9-3 3.4.9-3 3.4.10-2 3.4.10-2 3.4.11-3 3.4.11-3 3.4.11-4 3.4.11-4 3.4.11-5 3.4.11-5 3.4.12-1 3.4.12-1 3.5.1-4 3.5.1-4 3.5.1-5 3.5.1-5 3.5.2-3 3.5.2-3 3.5.2-4 3.5.2-4 3.5.3-2 3.5.3-2 3.5.3-3 3.5.3-3 3.6.1.1-3 3.6.1.1-3 3.6.1.1-4 3.6.1.1-4 3.6.1.2-4 3.6.1.2-4 3.6.1.3-6 3.6.1.3-6 3.6.1.3-7 3.6.1.3-7

- 3 Remove TSs TSs 3.6.1.3-8 3.6.1.3-8 3.6.1.4-1 3.6.1.4-1 3.6.1.5-1 3.6.1.5-1 3.6.1.6-2 3.6.1.6-2 3.6.1.6-3 3.6.1.6-3 3.6.2.1-2 3.6.2.1-2 3.6.2.2-1 3.6.2.2-1 3.6.2.3-2 3.6.2.3-2 3.6.2.4-2 3.6.2.4-2 3.6.3.2-1 3.6.3.2-1 3.6.4.1-3 3.6.4.1-3 3.6.4.2-4 3.6.4.2-4 3.6.4.3-3 3.6.4.3-3 3.7.1-2 3.7.1-2 3.7.2-1 3.7.2-1 3.7.3-2 3.7.3-2 3.7.4-3 3.7.4-3 3.7.4-4 3.7.4-4 3.7.5-3 3.7.5-3 3.7.6-2 3.7.6-2 3.7.7-1 3.7.7-1 3.7.7-2 3.7.7-2 3.7.8-1 3.7.8-1 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 3.8.3-3 3.8.3-3 3.8.4-3 3.8.4-3 3.8.4-4 3.8.4-4 3.8.4-5 3.8.4-5 3.8.6-3 3.8.6-3 3.8.6-4 3.8.6-4 3.8.6-5

-4 Remove TSs TSs 3.8.7-3 3.8.7-3 3.8.8-2 3.8.8-2 3.9.1-2 3.9.1-2 3.9.2-1 3.9.2-1 3.9.2-2 3.9.2-2 3.9.3-1 3.9.3-1 3.9.5-1 3.9.5-1 3.9.6-1 3.9.6-1 3.9.7-1 3.9.7-1 3.9.8-3 3.9.8-3 3.9.9-3 3.9.9-3 3.10.1-2 3.10.1-2 3.10.2-3 3.10.2-3 3.10.3-3 3.10.3-3 3.10.3-4 3.10.3-4 3.10.4-2 3.10.4-2 3.10.4-3 3.10.4-3 3.10.5-2 3.10.5-2 3.10.7-3 3.10.7-3 3.10.7-4 3.10.7-4 5.5-15 5.5-15 5.5-16

3 (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 (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 No. 200 ,and the Environmental Protection Plan contained in Appendix S, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3) Conduct of Work Activities During Fuel Load and Initial Startup The licensee shall review by committee all Unit 1 Preoperational Testing and System Demonstration activities performed concurrently with Unit 1 initial fuel loading or with the Unit 1 Startup Test Program to assure that the activity will not affect the safe performance of the Unit 1 fuel loading or the portion of the Unit 1 Startup Program being performed. The review shall address, as a minimum, system interaction, span of control, staffing, security and health phYSiCS, with respect to performance of the activity concurrently with the Unit 1 fuel loading or the portion of the Unit 1 Startup Program being performed. The committee for the review shall be composed of at least three members, knowledgeable in the above areas, and who meet the qualifications for professional-technical personnel specified by Amendment No. 200

- 3 (5) Pursuant to the Act and 10 CFR Parts 30, 40, and 70 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). 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. 187 and the Environmental Protection Plan contained I

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) Conduct of Work Activities During Fuel Load and Initial Startup The licensee shall review by committee all Unit 2 Preoperational Testing and System Demonstration activities performed concurrently with Unit 2 initial fuel loading or with the Unit 2 Startup Test Program to assure that the activity will not affect the safe performance of the Unit 2 fuel loading or the portion of the Unit 2 Startup Program being performed. The review shall address, as a minimum, system interaction, span of control, staffing, security and health physics, with respect to performance of the activity concurrently with the Unit 2 fuel loading or the portion of the Unit 2 Startup Program being performed. The committee for the review shall be composed of at least three members, knowledgeable in the above areas, and who meet the qualifications for professional-technical personnel specified by section 4.4 of ANSI N18.7-1971. At least one of these three shall be a senior member of the Assistant Superintendent of Operation's staff.

Amendment No. 187

Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of each control rod. In accordance with the Surveillance Frequency Control Program SR 3.1.3.2 DELETED SR 3.1.3.3 ---NOTE- --- --- ---

Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RWM.

Insert each withdrawn control rod at least In accordance one notch. with the Surveillance Frequency Control Program SR 3.1.3.4 Veri fy each control rod scram time from In accordance fully withdrawn to notch position 05 is with

~ 7 seconds. SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 (continued)

LaSalle 1 and 2 3.1.3-4 Amendment No .200 / 187

Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.2 Verify. for a representative sample. each In accordance tested control rod scram time is within the with the limits of Table 3.1.4 1 with reactor steam Surveillance dome pressure ~ 800 psig. Frequency Control Program SR 3.1.4.3 Verify each affected control rod scram time Prior to is within the limits of Table 3.1.4-1 with declaring any reactor steam dome pressure. control rod OP ERAB LE afte r work on control rod or CRD tern that could affect scram time SR 3.1.4.4 Verify each affected control rod scram time Prior to is within the limits of Table 3.1.4 1 with exceeding reactor steam dome pressure ~ 800 psig. 40% RTP after fuel movement withi n the affected core cell Prior to exceeding 40% RTP after work on control rod or CRD System that coul d affect scram time LaSalle 1 and 2 3.1.4 2 Amendment No. 200 / 187

Control Rod Scram Accumul ators 3.1. 5 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Declare the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated control rod inoperable.

D. Required Action B.1 or D.1 ------NOTE- ---

C.1 and associated Not applicable if all Completion Time not inoperable control met. rod scram accumulators are associ ated with fully inserted control rods.

Place the reactor Immediately mode switch in the shutdown position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each control rod scram accumulator In accordance pressure is ~ 940 psig. with the Surveillance Frequency Control Program LaSall eland 2 3.1.5-3 Amendment No.200 1187

Rod Pattern Control 3.1. 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE B.1 - - NOTE - - - - -

control rods not in RWM may be bypassed compliance with the as allowed by analyzed rod position LCD 3.3.2. 1.

sequence.

Suspend withdrawal of Immediately control rods.

B.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Ve r if y all 0 PERA BLE con t r 0 1 rod s com ply In accordance with the analyzed rod position sequence. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.1.6-2 Amendment No .200 / 187

SLC System 3.1. 7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) System LCO 3.1. 7 Two SLC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SLC subsystem A.l Restore SLC subsystem 7 days inoperable. to OPERABLE status.

B. Two SLC subsystems B.1 Restore one SLC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable. subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Ti me not met.

C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.1.7.1 Verify available volume of sodium In accordance pentaborate solution is within the limits with the of Figure 3.1.7 1. Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.1.7 1 Amendment No .200 / 187

SLC System 3.1. 7 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.1.7.2 Verify temperature of sodium penta borate In accordance solution is within the limits of with the Figure 3.1.72. Surveillance Frequency Control Program SR 3.1.7.3 Verify temperature of pump suction piping In accordance up to the storage tank outlet valves is with the

68°F. Surveillance Frequency Control Program SR 3.1.7.4 Verify continuity of explosive charge. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.1.7-2 Amendment No. 200 / 187

SLC System 3.1. 7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.5 Verify the concentration of sodium In accordance penta borate in solution is within the with the limits of Figure 3.1.7 1. Surveillance Frequency Contro 1 Program Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after water or sodium penta borate is added to solution Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after solution temperature is restored within the 1 i mits of Figure 3.1.7-2 SR 3.1.7.6 Verify each SLC subsystem manual, power In accordance operated, and automatic valve in the flow with the path that is not locked, sealed, or Surveillance otherwise secured in position is in the Frequency correct position, or can be aligned to the Control Program correct position.

SR 3.1.7.7 Verify each pump develops a flow rate In accordance

~ 41.2 gpm at a discharge pressure with the

~ 1220 psig. Inservice Testing Program (continued)

LaSalle 1 and 2 3.1.7-3 Amendment No. 200 / 187

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.l.7.8 Verify flow through one SLC subsystem from In accordance pump into reactor pressure vessel. with the Surveillance Frequency Control Program SR 3.l.7.9 Verify all heat traced plplng between In accordance storage tank and storage tank outlet valves with the is unblocked. Surveillance Frequency Control Program Once withi n 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after piping temperature is restored within the 1i mits of Figure 3.1.7 2 LaSalle 1 and 2 3.1.7 4 Amendment No. 200 I 187

SLC System 3.1. 7 5200

.0%, (13.8%,

Gal) 5150 Gal) 5100 5000 8 4900

~

~ 4800 f-<

t) U naccep tab Ie Z Operation 4700 4600 (13.4%, (13.8%,

4587 Gal) 4587 Gal) 4500 11 12 13 14 15 Concentration (% by weight)

Figure 3.1.7-1 (page 1 of 1)

Sodium Penta borate Solution Volume/Concentration Requirements LaSalle 1 and 2 3.1.7-5 Amendment NO.200 /187

SLC System 3.1. 7 150 140 130 120 Acceptable LL Operation o

110 (J)

L

l

~

rtl L

100 (J)

D E

(J) f-90 80 Unacceptable Operation 70 60 50 40 o 5 10 15 20 25 30 35 40 Concentration (% by weight)

Figure 3.1.7-2 (page 1 of 1)

Sodium Pentaborate Solution Temperature/Concentration Requirements LaSalle 1 and 2 3.1.7-6 Amendment NO'200 /187

SDV Vent and Drain Valves 3.1. 8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - - -

Not required to be met on vent and drain valves closed during performance of SR 3.1.8.2.

Verify each SDV vent and drain valve is In accordance open. with the Surveillance Frequency Control Program SR 3.1.8.2 Cycle each SDV vent and drain valve to the In accordance fully closed and fully open position. with the Surveillance Frequency Control Program SR 3.1.8.3 Verify each SDV vent and drain valve: In accordance with the

a. Closes in ~ 30 seconds after receipt Surveillance of an actua 1 or s i mul ated scram Frequency signal; and Control Program

b. Opens when the actual or simulated scram signal is reset.

LaSalle 1 and 2 3.1.8-2 Amendment I~o. 200 / 187

APLHGR 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)

LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY: THERMAL POWER ~ 25% RTP.

ACTIONS CONDITION REQUIRED ACTION I COMPLETION TIME A. Any APLHGR not within A.1 Restore APLHGR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. withi n 1 i mits.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all APLHGRs are less than or equal Once within to the limits specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

~ 25% RTP In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.2.1-1 Amendment No .200 I 187

MCPR 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)

LCD 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR.

APPLICABILITY: THERMAL POWER ~ 25% RTP.

ACTIONS CONDITION REQU I RED ACTI ON COMPLETI ON TIME A. Any MCPR not within A.l Restore MCPR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 1 imits. withi n 1 i mits.

B. Required Action and B.l Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal Once within to the limits specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

~ 25% RTP In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.2.2 1 Amendment No. 200/ 187

LHGR 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR)

LCO 3.2.3 All LHGRs shall be 1ess than or equal to the 1 imits specified in the COLR.

APPLICABILITY: THERMAL POWER ~ 25% RTP.

ACTIONS CONDITION REQUIRED ACT ION COMPLETION TIME A. Any LHGR not withi n A.1 Restore LHGR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. within limits.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEI LLMCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to Once within the limits specified in the COLR. 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s after 2: 25% RTP In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.2.3-1 Amendment No. 200 / 187

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS NOTES---

1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.2 ------------------NOTE-Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER ~ 25% RTP.

Verify the absolute difference between In accordance the average power range monitor (APRM) with the channels and the calculated power Surveillance

~ 2% RTP while operating at ~ 25% RTP. Frequency Control Program SR 3.3.1.1.3 Adjust the channel to conform to a In accordance calibrated flow signal. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.1.1-3 Amendment No. 200/ 187

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.4 ------------------NOTE Not required to be performed when entering MODE 2 from MODE 1 until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.6 Verify the source range monitor (SRM) and Prior to fully intermediate range monitor (IRM) channels withdrawing overlap. SRMs SR 3.3.1.1.7 NOTE------------------

Only required to be met during entry into MODE 2 from MODE 1.

Verify the IRM and APRM channels overlap. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.8 Calibrate the local power range monitors. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.1.1-4 Amendment No. 200 / 187

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.10 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.11 NOTES---- ---

1. Neutron detectors are excluded.

2. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.12 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)

LaSall eland 2 3.3.1.1-5 Amendment No. 2001 187

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.13 - ----- NOTES----

1. Neutron detectors are excluded.

2. For Function 1.a, not required to be performed when entering MODE 2 from MODE 1 until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.14 Verify the APRM Flow Biased Simulated In accordance Thermal Power-Upscale time constant is with the

~ 7 seconds. Surveillance Frequency Control Program SR 3.3.1.1.15 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.16 Verify Turbine Stop Valve-Closure and In accordance Turbine Control Valve Fast Closure, Trip with the Oil Pressure-Low Functions are not Surveillance bypassed when THERMAL POWER is ~ 25% RTP. Frequency Control Program (contlnued)

LaSalle 1 and 2 3.3.1.1-6 Amendment No. 200/ 187

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.17 ----NOTES

1. Neutron detectors are excluded.

2. For Function 9, the RPS RESPONSE TIME is measured from start of turbine control valve fast closure.

In accordance Verify the RPS RESPONSE TIME is within with the limits. Surveillance Frequency Control Program LaSalle 1 and 2 3.3.1.1 7 Amendment No. 200 I 187

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 1 of 3)

Reactor Protection System Instrumentation APPLICA3LE REQUIRED CONDITIONS MODES OR OTHER CHMNELS REFERENCED SPECIFIED PER TRIP FROM REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CDND IT IONS SYSTEM ACTION 0.1 REQUIREMENTS VALUE I. Intermediate Range Monitors

a. Neutron Fl uxHi gh 2 3 G SR 3.3.1.1.1 ::: 1231125 SR 3.3.1.1.4 divisions SR 3.3.1.1.6 of full SR 3.3.1.1.7 scale SR 3.3.1.1.13 SR 3.3.1.1.15 H SR 3.3.1.1.1 ::: 1231125 SR 3.3.1.1.5 divisions SR 3.3.1.1.13 of full SR 3.3.1.1.15 scale

b. Inop 2 3 G SR 3.3.1.1.4 NA SR 3.3.1.1.15 3 H SR 3.3.1.1.5 NA SR 3.3.1.1.15

2. Average Power Range Monitors

a. Neutron Flux-High, 2 2 G SR 3.3.1.1.1 s: 20% RTP Setdown SR 3.3.1.1.4 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.11 SR 3.3.1.1.15

b. Flow 3iased Simulated 2 SR 3.3.1.1.1 s: 0.61 W +

Therma 1 Power-Upsca 1e SR 3.3.1.1.2 68.2% RTP SR 3.3.1.1.3 and SR 3.3.1.1.8 s: 115.5%

SR 3.3.1.1.9 RTPtrl)

SR 3.3.1.1.11("

SR 3.3.1.1.14 SR 3.3.1.1.15

c. Fixed Neutron 2 SR 3.3.1.1.1 ::: 120% RTP Flux-High SR 3.3.1.1.2 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.15 SR 3.3.1.1.17 (continued)

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Ib) If teas-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be eva1 ated to verify that it is functioning as required before returning the channel to service.

Ic) The nstrument channel nt shall be reset to a value that is within the as left tolerance around the nominal trip setpoint ( ) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the NTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (field setting) to confirm channel performance. The NTSP and the methodologies used to determine the as-found and the as-left tolerances are specified in the Technical Requirements Manual.

(d) Allowable Value is 0.54 W+ 55.91 RTP and::: 112.31 RTP when reset for single loop operation per LCD 3.4.1, "Recirculation Loops Operating."

LaSalle 1 and 2 3.3,1.1-8 Amendment No. 200 1 187

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 2 of 3)

Reactor Protection System Instrumentation APPLICA3LE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANN ELS FROM SPECIFIED PER TRIP REQUIRED SURVEI LLANCE ALLOWAB LE FUNCTION CONDITIONS SYSTEM ACTION 0.1 REQU IREMENTS VALUE

2. Average Power Range f1onitors (continued)

d. lnop 1,2 2 G SR 3.3.l.l.8 NA SR 3.3.l.1.9 SR 3.3.l.1.15

3. Reactor Vessel Steam Dome 1,2 2 G SR 3.3.1.1.9 ,; 1059.0 psig Pressure-High SR 3.3.1.1.10 SR 3.3.1.1.15

4. Reactor Vessel Water 1,2 2 G SR 3.3.1.l.1 ~ 11.0 inches Leve I -Low, Level 3 SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.17

5. Main Steam Isolation 8 F SR 3.3.l.l.9 ,; 13.7% closed Valve-Closure SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.17

6. Drywell Pressure High 1,2 G SR 3.3.1.1.9 ,; 1.93 psig SR 3.3.1.1.13 SR 3.3.1.1.15

7. Scram Discharge Volume Water Level-High

a. Trans~itter/Trip Unit 1,2 G SR 3.3.1.l.9 ,; 767 ft SR 3.3.1.1.13 8.55 inches SR 3.3.1.1.15 elevation 5'" 2 H SR 3.3.1.1.9 ,; 767 ft SR 3.3.1.1.13 8.55 inches SR 3.3.1.1.15 elevation (continued)

(a) With any control rod withdrawn from a core cell containing one or ~ore fuel asse~blies.

LaSalle 1 and 2 3.3.1.1 9 Amendment No. 200 I 187

RPS Instrumentation 3.3.l.1 Table 3.3.1.1 1 (page 3 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVE[lLA~CE ALLO'IlA3LE FUNCT ION CONDITIONS SYSTE~l ACTION D. 1 REQU I RE~lE NTS VALUE

7. Scram Discharge Volume Water Level-High (continued)

b. Float Switch 1,2 2 G SR 3.3.1.1.9 ;; 767 ft SR 3.3.1.1.13 8.55 inches SR 3.3.1.1.15 elevation SUd 2 H SR 3.3.1.1 9 ;; 767 ft SR 3.3.1.1.13 8.55 inches SR 3.3.1.1.15 elevation

8. Turbine Stop Valve ::, 25% RTP 4 SR 3.3.1.1.9 ;; 8.9% closed Closure SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.16 SR 3.3.1.1.17

9. Turbine Control Valve ::, 25% RTP SR 3.3.1.1.9 ::, 425.5 psig Fast Closure, Tri p Oi 1 SR 3.3.1.1.13 Pressure-Low SR 3.3 1.1.15 SR 3.3 1.1.16 SR 3.3.~.1.17

10. Reactor Mode 1,2 2 G SR .1.1.12 NA SWitch-Shutdown Positi on SR 3.3.1.1.15 5(a) H SR 3. .1.1.12 NA SR 3.3.1.1.15

11. Manual Scram ,2 G SR 3. .1.1.5 ~;A SR 3.3.1.1.15 5'" 2 SR 3.3.1.1.5 NA SR 3.3.1.1.15 (a) WiUI any control rod witndrawn from a core cell containing one or more fuel assemblies.

LaSalle 1 and 2 3.3.1.1-10 Amendment No. 200 187

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS

- - - - - - NOTE -

Refer to Table 3.3.1.2 1 to determine which SRs apply for each applicable MODE or other specified condition.

SURV EI LLANC E FREQUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Cont ro 1 Program SR 3.3.1.2.2 NOTES-----

1. Only required to be met during CORE ALT ERA TI 0 NS.

2. One SRM may be used to satisfy more than one of the following.

Verify an OPERABLE SRM detector is In accordance located in: with the Surveillance

a. The fueled region; Frequency Control Program

b. The core quadrant where CORE ALTERATIONS are being performed when the associated SRM is included in the fueled region; and

c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.

SR 3.3.1.2.3 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.1.2-3 Amendment No. 200/ 187

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.2.4 - - - - - - - - - - - - - NOTE Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.

Veri count rate is: In accordance with the

a. ~ 3.0 cps; or Surveillance uency

b. ~ 0.7 cps with a signal to noise Control Program ratio ~ 20:1.

SR 3.3.1.2.5 ----------NOTE--

The determination of signal to noise ratio is not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.

Perform CHANNEL FUNCTIONAL TEST and In accordance determination of signal to noise ratio. with the Surveillance Frequency Control Program SR 3.3.1.2.6 ------- ---------NOTE--

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL FUNCTIONAL TEST and In accordance determination of signal to noise ratio. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.1.2 4 Amendment No.200 / 187

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.2.7 ------ ------- NOTES-------

1. Neutron detectors are excluded.

2. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.1.2 5 Amendment No. 200 1 187

OPRM Instrumentation 3.3.1.3 SURVEILLANCE REQUIREMENTS

NOTE--

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the OPRM maintains trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.3.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.3.2 Calibrate the local power range monitors. In accordance with the Surveillance Frequency Control Program SR 3.3.1.3.3 NOTE- - - - - - -

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. The setpoints In accordance for the trip function shall be as specified with the in the COLR. Surveillance Frequency Control Program SR 3.3.1.3.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.1.3 3 Amendment NO.200 / 187

OPRM Instrumentation 3.3.1.3 SURVEILLANCE R IREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.3.5 Verify OPRM is not bypassed when THERMAL In accordance POWER is ~ 28.1% RTP and recirculation with the drive flow is < 60% of rated recirculation Surveillance drive flow. Frequency Control Program SR 3.3.1.3.6 NOTE----------

Neutron detectors are excluded.

Verify the RPS RESPONSE TIME is within In accordance limits. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.1.3-4 Amendment No. 200/ 187

Control Rod Block Instrumentation 3.3.2.1 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME E. One or more Reactor E.1 Suspend control rod Immediately Mode Switch-Shutdown withdrawal.

Position channels inoperable.

E.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assembl i es.

SURVEILLANCE REQUIREMENTS NOTES

1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.

2. When an RBM channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.2.1 3 Amendment No. 200/ 187

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.1.2 ---NOTE Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn at

~ 10% RTP in MODE 2.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.3 --NOTE---

Not requi red to be performed unti 1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is ~ 10% RTP in MODE 1.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.4 NOTE------

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.2.1 4 Amendment No. 200 I 187

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE ! FREQUENCY SR 3.3.2.1.5 NOTE----------

Neutron detectors are excluded.

Verify the RBM is not bypassed when In accordance THERMAL POWER is ~ 30% RTP and a with the peripheral control rod is not selected. Surveillance Frequency Control Program SR 3.3.2.1.6 Verify the RWM is not bypassed when In accordance THERMAL POWER is s 10% RTP. with the Surveillance Frequency Control Program SR 3.3.2.1.7 ----------------- NOTE------------- ---

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.8 Verify control rod sequences input to the Prior to RWM are in conformance with analyzed rod decl aring RWM position sequence. OPERABLE following 1 oadi ng of sequence into RWM SR 3.3.2.1.9 Verify the bypassing and position of Prior to and control rods required to be bypassed in during the RWM by a second licensed operator or movement of other qualified member of the technical control rods staff. bypassed in RWM LaSalle 1 and 2 3.3.2.1 5 Amendment No.200 / 187

Feedwater System and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 ACTIONS CONDITION REQUI RED ACTION COMPLETION TIME C. Required Action and C.1 ----NOTE-associated Completion Only applicable if Ti me not met. inoperable channel is the result of an inoperable motor driven feedwater pump breaker or feedwater turbine stop valve.

Remove affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months feedwater pump(s) from service C.2 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to < 25% RTP.

SURVEILLANCE REQUIREMENTS

- NOTE - - - - - - - -

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided feedwater system and main turbine high water level trip capability is maintained.

SURVEILLANCE FREQUENCY SR 3.3.2.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.2.2-2 Amendment No. 2001 187

Feedwater System and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2.3 Perform CHANNEL CALIBRATION. The In accordance Allowable Value shall be s 59.5 inches. with the Surveillance uency Control Program SR 3.3.2.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, In accordance including breaker and valve actuation. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.2.2-3 Amendment No.2001 187

PAM Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS NOTES

1. These SRs apply to each Function in Table 3.3.3.1 1.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the other required channel in the associated Function is OPERABLE.

SURVEI LLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Contro 1 Program SR 3.3.3.1.2 (Deleted)

SR 3.3.3.1.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.3.1-3 Amendment No.2001 187

Remote Shutdown Monitoring System 3.3.3.2 SURVEILLANCE REQUIREMENTS NOTE When an instrumentation channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Perform CHANNEL CHECK for each required In accordance instrumentation channel that is normally with the energized. Surveillance Frequency Control Program SR 3.3.3.2.2 Perform CHANNEL CALIBRATION for each In accordance required instrumentation channel. with the Surveillance uency Control Program LaSalle 1 and 2 3.3.3.2 2 Amendment No .200 / 187

EOC RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS

NOTE When a channel is placed in an inoperable status solely for performance of required Surveillances. entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains EOC-RPT trip capability.

SURVEI LLANCE FREQUENCY SR 3.3.4.1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.4.1.2 Perform CHANNEL CALIBRATION. The In accordance Allowable Values shall be: with the Surveillance

a. TSV-Closure: ~ 8.9% closed; and uency Control Program

b. TCV Fast Closure, Trip Oil Pressure-Low: ~ 425.5 psig.

SR 3.3.4.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST, In accordance including breaker actuation. with the Surveillance Frequency Control Program SR 3.3.4.1.4 Verify TSV-Closure and TCV Fast Closure, In accordance Trip Oil Pressure-Low Functions are not with the bypassed when THERMAL POWER is ~ 25% RTP. Surveillance Frequency Control Program (continued)

LaSall eland 2 3.3.4.1 3 Amendment No. 200/187

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.l.5 - - - - - - - - - - - - - - - - - - NOTE Breaker arc suppression time may be assumed from the most recent performance of SR 3.3.4.l.6.

Verify the EOC-RPT SYSTEM RESPONSE TIME In accordance is within limits. with the Surveillance Frequency Control Program SR 3.3.4.1.6 Determine RPT breaker arc suppression In accordance time. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.4.1 4 Amendment No .200 I 187

ATWS RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS

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

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains ATWS-RPT trip capability.

SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.3 Perform CHANNEL CALIBRATION. The In accordance Allowable Values shall be: with the Surveillance

a. Reactor Vessel Water Level-Low Low, Frequency Level 2: ~ 54 inches; and Control Program

b. Reactor Steam Dome Pressure-High:

s 1147 psig.

SR 3.3.4.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, In accordance including breaker actuation. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.4.2-3 Amendment No.200 / 187

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS NOT ES- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 3.c, 3.d, 3.e, and 3.f; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions other than 3.c, 3.d, 3.e, and 3.f, provided the associated Function or the redundant Function maintains ECCS initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.l.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.l.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.l.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.l.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.5.1-7 Amendment No. 200/ 187

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.3.5.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.6 Verify ECCS RESPONSE TIME is within In accordance limits. with the Survei 11 ance Frequency Control Program LaSalle 1 and 2 3.3.5.1 8 Amendment No. 2001 187

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 4)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTI ON CONDITIONS FUNCTION ACTION A.l REQU I REMENTS VALUE

1. Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS)

Subsystems

a. Reactor Vessel Water 1.2.3. 2(0) B SR 3.3.5.1.1 ;:> -147.0 Level-Low Low Low, SR 3.3.5.1.2 inches Leve I 1 SR 3 . . 5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Drywell Pressure-High 1.2,3 2\b) SR 3.3.5.1.2 ,,1.77psig SR 3.3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.6

c. LPCI Pump A 1,2,3. C SR 3.3.5.1.2 " 5.5 seconds Start-Time Delay SR 3.3 . . 1.4 Relay SR 3.3.5.1.5

d. Reactor Steam 1.2.3 2 SR 3.3.5.1.2 490 Dsig and Dome Pressure-Low SR 3.3.5.1.4 " 522 psig (Injection Permissive) SR 3.3.5.1.5 SR 3.3.5.1.6 2 SR 3.3.5.1.2 ;:> 490 psig and SR 3.3.5.1.4 " 522 psig SR 3.3.5.1.5 SR 3.3.5.1.6

e. LPCS Pump Discharge 1.2,3, SR 3.3.5.1.2 ;:> 1240 gpm and Fl ow~Low (Bypa ss) SR 3.3.5.1.3 " 1835 gpm SR 3.3.5.1.5

f. LPCI Pump A Discharge 1,2,3. SR 3.3.5.1.2 ;:> 1330 gpm and Flow-Low (Bypass) SR 3.3.5.1.3 " 2144 gpm SR 3.3.5.1.5

g. LPCS and LPCI A 1,2,3 1 per valve D SR 3.3.5.1.2 :> 490 psig and Injection Line SR 3.3.5.1.4 " 522 pSig Pressure-Low SR 3.3.5.1.5 (Injection Permissive) SR 3.3.5.1.6 1 per valve 3 SR 3.3.5.1.2 ;:> 490 psig and SR 3.3.5.1.4 522 psig SR 3.3.5.1.5 SR 3.3.5.1.6

h. Manual Initiation 1. 2,3, c SR 3.3.5.1.5 (cont;nued)

(al When associated EeCS subsystem(s) are required to be OPEQABLE per LCD 3.5.2, "EeCS-Shutdown."

(b) Also required to initiate the associated diesel generator (DG).

LaSalle 1 and 2 3.3.5.1-9 Amendment No.200 / 187

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1*1 (page 2 of 4)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FRO!'

SPEcrcIED CHANNELS PER REQUIRED SURVEI LLANCE ALLOWABLE FUNCTION CONDIT IONS FUNCT:ON ACT ION A. 1 REQUIREMENTS VALUE

2. LPCI 3 and LPCI C Suo systems

a. Reactor Vessel Water 1.2,3, SR 3.3.5.1.1 :? -147.0 Level Low Low Low, SR 3.3.5.1.2 inches Leve I 1 SR 3.3,5.1.4 SR 3.3.5.1.5 SR 3.3.5 1.6

b. Drywell Pressure-High 1.2,3 2'" SR 3.3.5.1.2 1. 77 pSig SR 3,3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.6

c. LPCl Pump B 1.2,3, c SR 3.3.5.1.2 $ 5.5 seconds Start-Time Delay SR 3.3.5.1.4 Relay SR 3.3,5.1.5

d. Reactor Steam Dome 1.2.3 SR 3.3.5.1.2 :? 490 psig and Pressure-LoVi SR 3.3.5.1.4 $ 522 pS i 9 (Injection Permissive) SR 3.3.5.1.5 SR 3.3.5.1.6 2 SR 3.3.5.1.2 :? 490 psig and SR 3.3.5.1.4 $ 522 psig SR 3.3.5 1.5 SR 3.3.5.1.6

e. LPCI Pump Band LPCI 1,2,3, 1 per' pump SR 3.3.5.1.2 :? 1330 gpm and Pump C Discharge SR 3.3.5.1.3 $ 2144 gpm Flow-Low (Bypass) SR 3.3.5.1.5

f. LPCI 8 and LPCI 1.2.3 1 per valve o SR 3.3.5.1.2 :? 490 psig and Injection Line SR 3.3.5.1.4 $ 522 psig Pressure-Low SR 3.3.5.1.5 (Injection Permissive) SR 3.3.5.1.6 4(') ,5") 1 per val ve 8 SR 3.3.5.1.2 :? 490 psig and SR 3.3.5.1.4 $ 522 psig SR 3.3.5,1.5 SR 3.3.5.1.6

g. Manual Initiation 1,2.3, c SR 3.3.5.1.5 NA (continued)

(a) When associated ECCS subsystem(s) are required to be OPERA3LE per LCD 3.5.2.

(bl Also required to initiate the associated DG.

LaSalle 1 and 2 3.3.5.1 10 Amendment No.200 / 187

ECCS Instrumentation 3.3.5.1 Table 3 3.5.1 1 (page 3 of 4)

Emergency Core Cooling Syste~ :nstrumentation APPLICABLE CONDITIONS r1CDES OR REFERENCED O,HER REQUIREC FROM SPECIFIED CHMNELS PER REQUIRED SURVE I LLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A. 1 REQUIREMENTS VALUE

3. High Pressure Core Spray (HPCS) 5ysten'

a. Reactor Vessel Water 1,2,3, SR 3.3.5.1.1 " -83 inches Level-Low Low, SR 3.3.5.1.2 Leve 1 2 SR 3.3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Drywel I Pressure-High 1,2,3 SR 3.3.5.1.2 <; 1. 77 psig SR 3.3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.6

c. Reactor Vessel Water 1,2,3, c SR 3.3.5.1.1 " 66.5 inches Level-High, Level 8 SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5

d. Discharge 1,2, o SR 3.3.5.1.2 13.2 pSig gh SR 3.3.5.1.4 (Bypass) SR 3.3.5.1.5

e. HPCS System Flow 1,2,3, C SR 3.3.5.1.2 2 1380 gpm and Rate-Low (Bypass) SR 3.3.5.1.3 <; 2194 gpm SR 3.3.5.1.5

f. ~lanual ,nitiation 1,2,3, C SR 3.3.5.1.5 NA

4. Automatic System (ADS

a. Reactor Vessel Water SR 3.3.5.1.1 > 147.0 Level-Low Low Low, SR 3.3.5.1.2 inches Leve I 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure-High E SR 3.3.5.1.2 ,,;1.77 psig SR 3.3.5.1.4 SR 3.3.5.1.5

c. ADS Initiation Timer F SR 3.3.5.1.2 " ::8 seconds SR 3.3.5.1.4 SR 3.3.5.1.5 (conti nued)

(0) When associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2.

(bl Also required to initiate the associated CG.

(c) With reactor steam dome pressure> 150 psig.

LaSalle 1 and 2 3.3.5.1-11 Amendment No. 200' 187

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1*1 (page 4 of 4)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEI LLANC E ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.l REQUIREMENTS VALUE

4. ADS Tri p System A (continued)

d. Reactor Vessel Water 1,2 (rl ,3(c) SR 3.3.5.1.1 Leve l-Low. Level 3 SR 3.3.5.1.2 " 11.0 inches (Confi rmatory) SR 3.3.5.1.4 SR 3.3.5.1.5

e. LPCS Pump Discharge 1,2 (el ,3(c) SR 3.3.5.1.2 " 131.2 psig Pressure-High SR 3.3.5.1.4 and SR 3.3.5.1.5 271.0 psig

f. LPCI Pump A Discharge 1 ,2 (e) ,3(c) SR Pressure-High SR 3.3.5.1.2 3.3.5.1.4 "and105.0 psig SR 3.3.5.1.5

" 128.6 ps i g

g. ADS Drywell Pressure 1.2 Ic}.3 Ic ) SR 3.3.5.1.2 Bypass Timer SR 3.3.5.1.4 " 598 seconds SR 3.3.5.1.5

h. Manual Initiation 1. 21e) .3Ie) SR 3.3.5.1.5 NA

5. ADS Trip System B

a. Reactor Vessel Water 1 ,2 (e) ,3(C) SR 3.3.5.1.1 " -147.0 Level-Low Low Low. SR 3.3.5.1.2 inches Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5 SR

b. Drywell Pressure-High 1 ,2 (el ,3(C)

SR 3.3.5.1.2 3.3.5.1.4 " 1.77 psig SR 3.3.5.1.5 1.2 Ie) .3Ie)

c. ADS Initiation Timer SR SR 3.3.5.1.2 3.3.5.1.4 " 118 seconds SR 3.3.5.1.5 1 .2 Ie) .3Ie) SR 3.3.5.1.1 inches

d. Reactor Vessel Water Level-Low. Level 3 SR 3.3.5.1.2 " 11.0 (Confirmatory) SR 3.3.5.1.4 SR 3.3.5.1.5

e. LPCI Pumps B & C 1 ,2{c) ,3(c) 2 per pump SR 3.3.5.1.2 " 105.0 psig Discharge SR 3.3.5.1.4 and Pressure-High SR 3.3.5.1.5 128.6 psig

1. 2{c) SR 3.3.5.1.2 seconds

f. ADS Drywell Pressure Bypass Timer

,3(c)

SR 3.3.5.1.4 " 598 SR 3.3.5.1.5

g. Manual Initiation 1.2(c) .3(c) SR 3.3.5.1.5 NA (c) With reactor steam dome pressure> 150 psig.

LaSalle 1 and 2 3.3.5.1-12 Amendment No. 200/ 187

RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS NOTES -----

1. Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 2 and 4; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 1 and 3 provided the associated Function maintains RCIC initiation capability.

SURVEI LLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.5.2-3 Amendment No .200 / 187

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIOI~S CONDITION REQUIRED ACTION COMPLETION TIME J. As required by J.1 Initiate action to Immediately Required Action C.1 restore channel to and referenced in OPERABLE status.

Table 3.3.6.1 1.

J.2 Initiate action to Immediately isolate the Residual Heat Removal (RHR)

Shutdown Cooling (SDC) System.

SURVEILLANCE REQUIREMENTS

NOTES ---------

1. Refer to Table 3.3.6.1 1 to determine which SRs apply for each Primary Containment Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.6.1 4 Amendment No. 200/ 187

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.6 Verify the ISOLATION SYSTEM RESPONSE TIME In accordance of the Main Steam Isolation Valves is with the within limits. Surveillance Frequency Control Program LaSalle 1 and 2 3.3.6.1-5 Amendment No. 200 I 187

Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS

--NOTES --

1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains isolation capability.

SURV EI LLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program LaSall eland 2 3.3.6.2 3 Amendment No.200 I 187

CRAF System Instrumentation 3.3.7.1 ACTIONS CONDITION REQU I RED ACTION COMPLETION TIME B. Required Action and B.1 Place the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion CRAF subsystem in the Time not met. pressurizaton mode of operation.

B.2 Declare associated 1 hour CRAF subsystem inoperable.

SURVEILLANCE REQUIREMENTS

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOTE When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains CRAF subsystem initiation capability.

SURV EI LLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.3.7.1 2 Amendment No. 200 / 187

CRAF System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1.3 Perform CHANNEL CALIBRATION. The In accordance Allowable Value shall be ~ 11.0 mR/hr. with the Surveillance Frequency Control Program SR 3.3.7.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.7.1-3 Amendment No *200 I 187

LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months provided the associated Function maintains LOP initiation capability.

SURV EILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.2 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.3 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.8.1-2 Amendment No.200 / 187

RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 NOTE------------------

Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for ~ 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The In accordance Allowable Values shall be: with the Surveillance

a. Overvoltage s 131.4 V (with time Frequency delay set to s 3.92 seconds). Control Program

b. Undervoltage ~ 108.7 V (with time delay set to s 3.92 seconds).

c. Underfrequency ~ 57.3 Hz (with time delay set to s 3.92 seconds)

SR 3.3.8.2.3 Perform a system functional test. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.3.8.2-4 Amendment No.200 / 187

Recirculation Loops Operating 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - -

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after both recirculation loops are in operation.

Verify recirculation loop jet pump flow In accordance mismatch with both recirculation loops in with the operation is: Surveillance Frequency

a. ~ 10% of rated core flow when Control Program operating at < 70% of rated core flow; and

b. ~ 5% of rated core flow when operating at ~ 70% of rated core flow.

LaSalle 1 and 2 3.4.1 3 Amendment No. 200/ 187

FCVs 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Flow Control Valves (FCVs)

LCO 3.4.2 A recirculation loop FCV shall be OPERABLE in each operating recirculation loop.

APPLICABILITY: MODES 1 and 2.

ACTIONS

--NOTE Separate Condition entry is allowed for each FCV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Lock up the FCV. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months FCVs inoperable.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.2.1 Verify each FCV fails "as is" on loss of In accordance hydraulic pressure at the hydraulic unit. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.4.2-1 Amendment No.200 I 187

FCVs 3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.2 Verify average rate of each FCV movement In accordance is: with the Surveillance

a. ~ 11% of stroke per second for Frequency open i ng; and Control Program

b. ~ 11% of stroke per second for closing.

LaSalle 1 and 2 3.4.2-2 Amendment NO.200 / 187

Jet Pumps 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 - - - - - - NOTES - - - -

1. Not required to be performed until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after associated recirculation loop is in operation.

2. Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after> 25% RTP.

Verify at least two of the following In accordance criteria (a, b, and c) are satisfied for with the each operating recirculation loop: Surveillance Frequency

a. Recirculation loop drive flow versus Control Program flow control valve position differs by

~ 10% from established patterns.

b. Indicated total core flow versus calculated total core flow differs by

~ 10% from established patterns.

c. Each jet pump diffuser to lower plenum differential pressure differs by ~ 20%

from established patterns.

LaSalle 1 and 2 3.4.3-2 Amendment No. 200 I 187

RCS Ope rat i ona 1 LEAKAGE 3.4.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Verify source of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months unidentified LEAKAGE increase is not intergranular stress corrosion cracking susceptible material.

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

C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months

.QR Pressure boundary LEAKAGE exists.

SURVEI LLANCE FREQUENCY SR 3.4.5.1 Verify RCS unidentified and total LEAKAGE In accordance and unidentified LEAKAGE increase are with the within limits. Surveillance Frequency Control Program LaSalle 1 and 2 3.4.5-2 Amendment No. 2001 187

RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS NOTE-------------

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the other required leakage detection instrumentation is OPERABLE.

SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywell In accordance atmospheric monitoring system. with the Surveillance Frequency Control Program SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of required In accordance leakage detection instrumentation. with the Surveillance Frequency Control Program SR 3.4.7.3 Perform CHANNEL CALIBRATION of required In accordance 1ea kage detection instrumentation. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.7-3 Amendment NO*200 / 187

RCS Specific Activity 3.4.8 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME B. (continued) B.2.2.1 Be in M8DE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months B.2.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 -NOTE-----

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT In accordance I 131 specific activity is ~ 0.2 ~Ci/gm. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.8-2 Amendment No. 200 / 187

RHR Shutdown Cooling System-Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 --NOTE Not required to be met until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reactor vessel pressure is less than the RHR cut in permissive pressure.

Verify one RHR shutdown cooling subsystem In accordance or recirculation pump is operating. with the Surveillance Frequency Control Program La Sa 11 e 1 and 2 3.4.9-3 Amendment No.200 /187

RHR Shutdown Cooling System-Cold Shutdown 3.4.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR shutdown B.1 Veri fy reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from cooling subsystem in coolant circulating discovery of no operation. by an alternate reactor coolant method. circulation AND No recirculation pump in operation. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter B.2 Monitor reactor Once per hour coolant temperature and pressure.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify one RHR shutdown cooling subsystem In accordance or recirculation pump is operating. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.10-2 Amendment No. 200 /187

RCS PIT Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURV EI LLANCE FREQUENCY SR 3.4.11.1 -------NOTE-----

Only required to be performed during RCS heatup and cool down operations, and RCS inservice leak and hydrostatic testing.

Verify: In accordance with the

a. RCS pressure and RCS temperature are Surveillance within the applicable limits specified Frequency in Figures 3.4.11 1, 3.4.11 2, Cont ro 1 Prog ram 3.4.11-3 for Unit 1 up to 20 EFPY, and Figures 3.4.11-4, 3.4.11-5, and 3.4.11-6 for Unit 2 up to 20 EFPY;

b. RCS heatup and cooldown rates are

~ 100°F in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period; and

c. RCS temperature change during system leakage and hydrostatic testing is

~ 20°F in anyone hour period when the RCS pressure and RCS temperature are not within the limits of Figure 3.4.11-2 for Unit 1 up to 20 EFPY and Figure 3.4.11-5 for Unit 2 up to 20 EFPY.

SR 3.4.11.2 Verify RCS pressure and RCS temperature are Once within within the criticality limits specified in 15 minutes Figure 3.4.11 3 for Unit 1 up to 20 EFPY prior to and Figure 3.4.11-6 for Unit 2 up to 20 control rod EFPY. wi thdrawal for the purpose of achieving criticality (continued)

LaSalle 1 and 2 3.4.11-3 Amendment No.200 I 187

RCS PIT Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.11.3 - --- ----NOTE-Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump startup.

Verify the difference between the bottom Once withi n head coolant temperature and the reactor 15 minutes pressure vessel (RPV) coolant temperature prior to each is::; 145°F. startup of a recirculation pump SR 3.4.11.4 --- --- --- ---NOTE- --- --- --- -

Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump startup.

Verify the difference between the reactor Once within coolant temperature in the recirculation 15 minutes loop to be started and the RPV coolant prior to each temperature is ::; 50°F. startup of a recirculation pump SR 3.4.11.5 --- --------- -NOTE--

Only required to be performed when tensioning the reactor vessel head bolting studs.

Verify reactor vessel flange and head In accordance flange temperatures are ~ 72°F for Unit 1 with the and ~ 86°F for Unit 2. Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.4.11-4 Amendment No. 200 I 187

RCS PIT Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.6 ------NOTE-Not required to be performed until 30 minutes after RCS temperature ~ 77°F for Unit 1 and ~ 91°F for Unit 2 in MODE 4.

Verify reactor vessel flange and head In accordance flange temperatures are ~ 72°F for Unit 1 with the and ~ 86°F for Unit 2. Surveillance Frequency Control Program SR 3.4.11.7 - - - - - -NOTE- - -

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after RCS temperature ~ 92°F for Unit 1 and

~ 106°F for Unit 2 in MODE 4.

Verify reactor vessel flange and head In accordance flange temperatures are ~ 72°F for Unit 1 with the and ~ 86°F for Unit 2. Surveillance Frequency Control Program LaSalle 1 and 2 3.4.11 5 Amendment No. 200 / 187

Reactor Steam Dome Pressure 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure LCO 3.4.12 The reactor steam dome pressure shall be ~ 1020 psig.

APPLICABILITY: MODES 1 and 2.

ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome A.1 Restore reactor steam 15 minutes pressure not within dome pressure to 1 i mit . within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify reactor steam dome pressure is In accordance

~ 1020 psig. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.4.12 1 Amendment No .200 I 187

ECCS-Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1. 1 Verify, for each ECCS injection/spray In accordance subsystem, the piping is filled with water with the from the pump discharge valve to the Surveillance injection valve. Frequency Control Program SR 3.5.1.2 Verify each ECCS injection/spray subsystem In accordance manual, power operated, and automatic valve with the in the flow path, that is not locked, Surveillance sealed, or otherwise secured in position, Frequency is in the correct position. Control Program SR 3.5.1.3 Verify ADS accumulator supply header In accordance pressure is ~ 150 psig. with the Surveillance Frequency Control Program SR 3.5.1.4 Verify ADS accumulator backup compressed In accordance gas system bottle pressure is ~ 500 psig. with the Surveillance Frequency Contra 1 Program Verify ADS accumulator reserve bottle pressure is ~ 1100 psig.

SR 3.5.1.5 Verify each ECCS pump develops the In accordance specified flow rate against the specified with the test line pressure. Inservice Testing Program TEST LINE SYSTEM FLOW RATE PRESSURE LPCS ~ 6350 gpm ~ 290 psig LPCI ;:;. 7200 gpm ~ 130 psig HPCS (Unit 1) ~ 6250 gpm ~ 370 psig HPCS ( Unit 2 ) ~ 6200 gpm ~ 330 psig (continued)

LaSalle 1 and 2 3.5.1-4 Amendment No.2DD / 187

ECCS-Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.6 NOTE Vessel injection/spray may be excluded.

Verify each ECCS injection/spray subsystem In accordance actuates on an actual or simulated with the automatic initiation signal. Surveillance Frequency Control Program SR 3.5.1.7 ----------- NOTE Valve actuation may be excluded.

Verify the ADS actuates on an actual or In accordance simulated automatic initiation signal. with the Surveillance Frequency Control Program SR 3.5.1.8 NOTE-------------------

Valve actuation may be excluded.

Verify each required ADS valve actuator In accordance strokes when manually actuated. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.5.1 5 Amendment NO*200 / 187

ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify, for each required low pressure ECCS In accordance injection/spray subsystem, the suppression with the pool water level is ;:: -12 ft 7 in. Surveillance Frequency Control Program SR 3.5.2.2 Verify, for the required High Pressure Core In accordance Spray (HPCS) System, the suppression pool with the water level is ;:: -12 ft 7 in. Surveillance Frequency Control Program SR 3.5.2.3 Verify, for each required ECCS injection/ In accordance spray subsystem, the piping is filled with with the water from the pump discharge valve to the Surveillance injection valve. Frequency Control Program SR 3.5.2.4 Verify each required ECCS injection/spray In accordance subsystem manual, power operated, and with the automatic valve in the flow path, that s Surveillance not locked, sealed, or otherwise secured in Frequency position, is in the correct position. Control Program SR 3.5.2.5 Verify each required ECCS pump develops the In accordance specified flow rate against the specified with the test line pressure. Inservice Testing Program TEST LINE SYSTEM FLOW RATE PRESSURE LPCS ;:: 6350 gpm ;:: 290 psig LPCI ;:: 7200 gpm ;::: 130 psig HPCS ( Unit 1) ;:: 6250 gpm ;::: 370 psig HPCS ( Unit 2 ) ;:: 6200 gpm ;:: 330 psig (continued)

LaSalle 1 and 2 3.5.2 3 Amendment No. 200/ 187

ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.6 NOTE-Vessel injection/spray may be excluded.

Verify each required ECCS injection/spray In accordance subsystem actuates on an actual or with the simulated automatic initiation signal. Surveillance Frequency Control Program LaSalle 1 and 2 3.5.2 4 Amendment No. 200/ 187

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System plplng is filled In accordance with water from the pump discharge valve to with the the injection valve. Surveillance Frequency Control Program SR 3.5.3.2 Verify each RCIC System manual, power In accordance operated, and automatic valve in the flow with the path, that is not locked, sealed, or Surveillance otherwise secured in position, is in the Frequency correct position. Control Program SR 3.5.3.3 - - - - - - - - - - NOTE-Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with reactor pressure ~ 1020 psig In accordance and ~ 920 psig, the RCIC pump can develop a with the flow rate ~ 600 gpm against a system head Surveillance corresponding to reactor pressure. Frequency Control Program SR 3.5.3.4 ---------NOTE--

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with reactor pressure ~ 165 psig, In accordance the RCIC pump can develop a flow rate with the

~ 600 gpm against a system head Surveillance corresponding to reactor pressure. Frequency Control Program (continued)

LaSalle 1 and 2 3.5.3-2 Amendment No 200 / 187

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.5 NOTE - -

Vessel injection may be excluded.

Verify the RCIC System actuates on an In accordance actual or simulated automatic initiation with the signal. Surveillance Frequency Control Program LaSalle 1 and 2 3.5.3-3 Amendment No. 200 / 187

Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FR ENCY SR 3.6.1.1.3 Verify drywell-to-suppression chamber In accordance bypass leakage is ~ 10% of the acceptable with the A/Jk design val ue of 0.030 ft2 at an Surveillance initial differential pressure of Frequency

~ 1.5 psid. Control Program 48 months following a test with bypass leakage greater than the bypass leakage limit 24 months following 2 consecutive tests with bypass 1 eakage grater than the bypass 1eakage limit until 2 consecutive tests are less than or equal to the bypass leakage limit (continued)

LaSalle 1 and 2 3.6.1.1-3 Amendment No. 200 / 187

Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1.4 ------ NOTE -----------

Performance of SR 3.6.1.1.3 satisfies this surveillance.

Verify individual drywell to suppression In accordance chamber vacuum relief valve bypass leakage with the is ::: 1.2% of the acceptable A/Jk design Surveillance value of 0.030 ft2 at an initial Frequency differential pressure of ~ 1.5 psid. Control Program SR 3.6.1.1.5 -----------NOTE---

Performance of SR 3.6.1.1.3 satisfies this surveillance.

Verify total drywell-to suppression chamber In accordance vacuum relief valve bypass leakage is with the

3.0% of the acceptable AIJk des i gn value Surveillance of 0.030 ft2 at an initial differential Frequency pressure of ~ 1.5 psid. Control Program LaSalle 1 and 2 3.6.1.1-4 Amendment No. 200 I 187

Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.3 Restore air lock to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.1.2.1 - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - -

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock 1ea kage test.

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.1.

Perform required primary containment air In accordance lock leakage rate testing in accordance with the with the Primary Containment Leakage Rate Primary Testing Program. Containment Leakage Rate Testing Program SR 3.6.1.2.2 Verify only one door in the primary In accordance containment air lock can be opened at a with the time. Surveillance Frequency Control Program LaSall e 1 and 2 3.6.1.2-4 Amendment NO.200 / 187

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.1.3.1 - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - -

Not required to be met when the 8 inch and 26 inch primary containment purge valves are open for inerting, de inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open, provided the drywell purge valves and suppression chamber purge valves are not open simultaneously.

Verify each 8 inch and 26 inch primary In accordance containment purge valve is closed. with the Surveillance Frequency Control Program SR 3.6.1.3.2 - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - -

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.

2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation In accordance manual valve and blind flange that is with the located outside primary containment and Surveillance not locked, sealed, or otherwise secured Frequency and is required to be closed during Control Program accident conditions is closed.

(continued)

LaSalle 1 and 2 3.6.1.3-6 Amendment No.200/187

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.3 ------- -- NOTES--

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.

2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation Prior to manual valve and blind flange that is entering MODE 2 located inside primary containment and or 3 from not locked, sealed, or otherwise secured MODE 4 if and is required to be closed during primary accident conditions is closed. containment was de-inerted while in MODE 4, if not performed within the previous 92 days SR 3.6.1.3.4 Verify continuity of the traversing In accordance incore probe (TIP) shear isolation valve with the explosive charge. Surveillance Frequency Control Program SR 3.6.1.3.5 Verify the isolation time of each power In accordance operated, automatic PCIV, except MSIVs, with the is within limits. Inservice Testing Program (continued)

LaSalle 1 and 2 3.6.1.3-7 Amendment No. 200/187

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.6 Verify the isolation time of each MSIV is In accordance

~ 3 seconds and ~ 5 seconds. with the Inservice Testing Program SR 3.6.1.3.7 Verify each automatic PCIV actuates to In accordance the isolation position on an actual or with the simulated isolation signal. Surveillance Frequency Contro 1 Prog ram SR 3.6.1.3.8 Verify each reactor instrumentation line In accordance EFCV actuates to the isolation position with the on an actual or simulated instrument line Surveillance break signal. Frequency Control Program SR 3.6.1.3.9 Remove and test the explosive squib from In accordance each shear isolation valve of the TIP with the System. Surveillance Frequency Control Program SR 3.6.1.3.10 Verify leakage rate through anyone main In accordance steam line is ~ 200 scfh and through all with the four main steam lines is ~ 400 scfh when Primary tested at ~ 25.0 psig. Containment Leakage Rate Testing Program SR 3.6.1.3.11 Verify combined leakage rate through In accordance hydrostatically tested lines that with the penetrate the primary containment is Primary within limits. Containment Leakage Rate Testing Program LaSalle 1 and 2 3.6.1.3-8 Amendment No. 200/187

Drywell and Suppression Chamber Pressure 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Drywell and Suppression Chamber Pressure LCO 3.6.1.4 Drywell and suppression chamber pressure shall be

~ 0.5 psig and $ +0.75 psig.

APPLICABI LITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell or suppression A.l Restore drywell and 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months chamber pressure not suppression chamber within limits. pressure to within limits.

B. Required Action and B.l Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.1.4.1 Verify drywell and suppression chamber In accordance pressure is within limits. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.1.4 1 Amendment NO*200 /187

Drywell Air Temperature 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Drywell Air Temperature LCO 3.6.1.5 Drywell average ai r temperature shall be s 135°F.

APPLICABI LITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION ON TIME A. Drywell average air A.1 Restore drywell 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature not within average air 1 i mi t. temperature to within 1 i mit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Ti me not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify drywell average air temperature is In accordance within limit. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.1.5-1 Amendment No. 200 / 187

Suppression Chamber to Drywell Vacuum Breakers 3.6.1.6 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME E. Two or more E.1 Enter LCO 3.0.3. Immediately suppression chamber-to-drywell vacuum breakers

-inoperable.

SURVEILLANCE FREQUENCY SR 3.6.1.6.1 NOTES - - - - - - - - - - - -

1. Not required to be met for vacuum breakers that are open during Surveillances.

2. Not required to be met for vacuum breakers open when performing their intended function.

Verify each vacuum breaker is closed. In accordance with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.6.1.6-2 Amendment No. 200 / 187

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1. 6 . 2 Perform a functional test of each vacuum In accordance breaker. with the Surveillance Frequency Control Program Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after any discharge of steam to the suppression chamber from the safety/relief valves SR 3.6.1.6.3 Verify the opening setpoint of each In accordance vacuum breaker is ~ 0.5 psid. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.1.6-3 Amendment No. 200/ 187

Suppression Pool Average Temperature 3.6.2.1 ACTIONS C.

CONDITION Suppression pool C.1 REQUIRED ACTION Place the reactor e ON TIME Immediately average temperature mode switch in the

> 110°F but ~ 120°F. shutdown position.

AND C.2 Verify suppression Once per pool average 30 minutes temperature ~ 120°F.

Mill C.3 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Suppression pool D.1 Depressurize the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months average temperature reactor vessel to

> 120°F. < 200 psig.

AND D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1.1 Verify suppression pool average In accordance temperature is within the applicable with the limits. Surveillance Frequency Control Program 5 minutes when performing testing that adds heat to the suppression pool LaSalle 1 and 2 3.6.2. 2 Amendment No. 200 I 187

Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be;:::: 4.5 inches and s +3 inches.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water A.1 Restore suppression 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 1eve 1 not within pool water 1 evel to 1 i mits . withi n 1 i mits.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Ti me not met. AN..D.

B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is In accordance within limits. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.2.2-1 Amendment No. 200 I 187

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

SR 3.6.2.3.2 Verify each required RHR pump develops a In accordance flow rate 2 7200 gpm through the with the associated heat exchanger while operating Inservice in the suppression pool cooling mode. Testing Program LaSalle 1 and 2 3.6.2.3-2 Amendment No. 2001 187

RHR Suppress ion Pool Spray 3.6.2.4 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.2.4.1 Verify each RHR suppression pool spray In accordance subsystem manual and power operated valve with the in the flow path that is not locked, Surveillance sealed, or otherwise secured in position, Frequency is in the correct position or can be Control Program aligned to the correct position.

SR 3.6.2.4.2 Verify each required RHR pump develops a In accordance flow rate ~ 450 gpm through the spray with the sparger while operating in the Inservice suppression pool spray mode. Testing Program LaSall eland 2 3.6.2.4-2 Amendment No. 200 / 187

Primary Containment Oxygen Concentration 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 Primary Containment Oxygen Concentration LCO 3.6.3.2 The primary containment oxygen concentration shall be

< 4.0 volume percent.

APPLICABI LITY: MODE 1 during the time period:

a. From 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is > 15% RTP following sta rtup, to

b. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to reducing THERMAL POWER to < 15% RTP prior to the next scheduled reactor shutdown.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore oxygen 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months oxygen concentration concentration to not withi n 1 i mit. within 1 i mit.

B. Required Action and B.1 Reduce THERMAL POWER 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated Completion to ~ 15% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.3.2.1 Verify primary containment oxygen In accordance concentration is within limits. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.3.2-1 Amendment No.200 / 187

Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.4.1.1 Verify secondary containment vacuum is In accordance

~ 0.25 inch of vacuum water gauge. with the Surveillance Frequency Control Program SR 3.6.4.1.2 Verify one secondary containment access In accordance door in each access opening is closed. with the Surveillance Frequency Control Program SR 3.6.4.1.3 Verify the secondary containment can be In accordance drawn down to ~ 0.25 inch of vacuum water with the gauge in 900 seconds using one standby Surveillance gas treatment (SGT) subsystem. Frequency Control Program SR 3.6.4.1.4 Verify the secondary containment can be In accordance maintained ~ 0.25 inch of vacuum water with the gauge for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months using one SGT subsystem Surveillance at a flow rate ~ 4400 cfm. Frequency Control Program SR 3.6.4.1.5 Verify all secondary containment In accordance equipment hatches are closed and sealed. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.4.1 3 Amendment No. 200/187

SCIVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLMCE FREQUENCY SR 3.6.4.2.1 ------NOTES

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.

2. Not required to be met for SCIVs that are open under administrative controls.

Verify each secondary containment In accordance isolation manual valve and blind flange with the that is not locked, sealed or otherwise Surveillance secured in position and is required to be Frequency closed during accident conditions is Control Program closed.

SR 3.6.4.2.2 Verify the isolation time of each power In accordance operated, automatic SCIV is within with the limits. Surveillance Frequency Control Program SR 3.6.4.2.3 Verify each automatic SCIV actuates to In accordance the isolation position on an actual or with the simulated automatic isolation signal. Surveillance Frequency Control Program LaSalle 1 and 2 3.6.4.2 4 Amendment No .200 / 187

SGT System 3.6.4.3 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.2 Suspend CORE Immediately ALTERA TI 0 NS .

E.3 Initiate action to Immediately suspend OPDRVs.

SURVEI LLANCE REQU I REMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for In accordance

~ 10 continuous hours with heaters with the operating. Surveillance Frequency Control Program SR 3.6.4.3.2 Perform required SGT filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).

SR 3.6.4.3.3 Verify each SGT subsystem actuates on an In accordance actual or simulated initiation signal. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.6.4.3-3 Amendment No. 200/ 187

RHRSW System 3.7.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met.

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

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

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

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

D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1. 1 Verify each RHRSW manual, power operated, In accordance and automatic valve in the flow path, that with the is not locked, sealed, or otherwise secured Surveillance in position, is in the correct position or Frequency can be aligned to the correct position. Control Program LaSalle 1 and 2 3.7.1-2 Amendment No. 200 1 187

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.

APPLI CABI LITY: MODES 1, 2, and 3.

ACTIONS

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

Separate Condition entry is allowed for each DGCW subsystem.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Verify each DGCW subsystem manual, power In accordance operated, and automatic valve in the flow with the path, that is not locked, sealed, or Surveillance otherwise secured in position, is in the Frequency correct position. Control Program SR 3.7.2.2 Verify each DGCW pump starts automatically In accordance on each required actual or simulated with the initiation signal. Survei 11 ance Frequency Control Program LaSall e 1 and 2 3.7.2-1 Amendment No. 200/ 187

UHS 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify cooling water temperature supplied In accordance to the plant from the CSCS pond is with the S 101.25°F. Surveillance Frequency Control Program SR 3.7.3.2 Verify sediment level is s 1.5 ft in the In accordance intake flume and the CSCS pond. with the Surveillance Frequency Control Program SR 3.7.3.3 Verify CSCS pond bottom elevation is In accordance s 686.5 ft. with the Survei 11 ance Frequency Control Program LaSalle 1 and 2 3.7.3-2 Amendment No.200 / 187

CRAF System 3.7.4 ACTIONS CONDITION REQU I RED ACTION COMPLETION TIME F. Two CRAF subsystems - - - - - NOT E- - - - - - - - - -

inoperable during LCO 3.0.3 is not applicable.

movement of irradiated fuel assemblies in the secondary containment, F.1 Suspend movement of Immediately during CORE i rradi ated fuel ALTERATIONS, or during assemblies in the OPDRVs. secondary containment.

One or more CRAF subsystems i noperabl e F. 2 Suspend CORE Immediately due to inoperable CRE ALTERATIONS.

boundary during movement of irradiated AND fue 1 assemb 1 i es in the secondary containment, F.3 Initiate action to Immediately during CORE suspend OPDRVs.

ALTERATIONS, or during OPDRVS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Operate each CRAF subsystem for In accordance

~ 10 continuous hours with the heaters with the operating. Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.7.4 3 Amendment No200 I 187

CRAF System 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.2 Manually initiate flow through the CRAF In accordance recirculation filters for ~ 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months . with the Surveillance Frequency Control Program SR 3.7.4.3 Perform required CRAF filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).

SR 3.7.4.4 Verify each CRAF subsystem actuates on an In accordance actual or simulated initiation signal. with the Surveillance Frequency Control Program SR 3.7.4.5 Perform required CRE unfiltered air In accordance inleakage testing in accordance with the with the Control Room Envelope Habitability Program. Control Room Envelope Habitability Program LaSalle 1 and 2 3.7.4-4 Amendment No .200 / 187

Control Room Area Ventilation AC System 3.7.5 ACTIONS CONDITION REQU I RED ACTION COMPLETION TIME E. Required Action and --------- NOTE - ------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition B not met during movement of irradiated E.1 Suspend movement of Immediately fuel assemblies in the irradiated fuel secondary containment, assemblies in the during CORE secondary ALTERATIONS, or during containment.

OPDRVs.

E.2 Suspend CORE Immediately ALTE RATI aNS.

E.3 Initiate action to Immediately suspend OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Monitor control room and auxiliary electric In accordance equipment room temperatures. with the Surveillance Frequency Control Program SR 3.7.5.2 Verify correct breaker alignment and In accordance indicated power are available to the with the control room area ventilation AC Surveillance subsystems. Frequency Control Program LaSalle 1 and 2 3.7.5-3 Amendment No. 200/ 187

Main Condenser Offgas 3.7.6 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.7.6.1 NOTE Not required to be performed until 31 days after any main steam line not isolated and SJAE in operation.

Verify the gross gamma activity rate of the In accordance noble gases is s 340,000 ~Ci/second after with the decay of 30 minutes. Surveillance Frequency Control Program Once withi n 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after a

~ 50% increase in the nominal steady state fission gas rel ease after factoring out increases due to changes in THERMAL POWER 1eve 1 LaSalle 1 and 2 3.7.6-2 Amendment No.200 / 187

Main Turbine Bypass System 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Main Turbine Bypass System LCO 3.7.7 The Main Turbine Bypass System shall be OPERABLE.

LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPRl," limits for an inoperable Main Turbine Bypass System, as specified in the COLR, are made applicable.

APPLICABILITY: TH RMAL POWER ~ 25% RTP.

ACTIONS CONDITION REQU I RED ACTI ON N TIME A. Requirements of the A.1 Satisfy the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months LCO not met. requirements of the LCD.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify one complete cycle of each main In accordance turbine bypass valve. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.7.7-1 Amendment No. 200/ 187

Main Turbine Bypass System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.2 Perform a system functional test. In accordance with the Surveillance Frequency Control Program SR 3.7.7.3 Verify the TURBINE BYPASS SYSTEM RESPONSE In accordance TIME is within limits. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.7.7-2 Amendment No200 / 187

Spent Fuel Storage Pool Water Level 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Spent Fuel Storage Pool Water Level LCO 3.7.8 The spent fuel storage pool water 1evel shall be

~ 21 ft 4 inches over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks.

APPLICABI LITY: During movement of irradiated fuel assemblies in the spent fuel storage pool, During movement of new fuel assemblies in the spent fuel storage pool with irradiated fuel assemblies seated in the spent fuel storage pool.

ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. Spent fuel storage A.l NOTE -

pool water level not LCO 3.0.3 is not within limit. applicable.

Suspend movement of Immediately fuel assemblies in the spent fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 Verify the spent fuel storage pool water In accordance level is ~ 21 ft 4 inches over the top of with the irradiated fuel assemblies seated in the Surveillance spent fuel storage pool racks. Frequency Control Program LaSalle 1 and 2 3.7.8-1 Amendment No.200 / 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS

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

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

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

SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and In accordance indicated power availability for each with the required offsite circuit. Surveillance Frequency Control Program SR 3.8.1.2 -- ------ NOTES ------

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 In accordance conditions and achieves steady state with the voltage ~ 4010 V and ~ 4310 V and frequency Surveillance

~ 58.8 Hz and ~ 61.2 Hz. Frequency Control Program (continued)

LaSalle 1 and 2 3.8.1 7 Amendment No.200 I 187

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 In accordance loaded and operates for 2 60 minutes at a with the load 2 2400 kW and ~ 2600 kW. Surveillance Frequency Control Program SR 3.8.1.4 Verify each required day tank contains In accordance 2250 gal of fuel oil for Divisions 1 and 2 with the and 2 550 gal for Division 3. Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water from In accordance each required day tank. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.8.1-8 Amendment No. 200/ 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SU RVEI LLANC E FREQUENCY SR 3.8.1.6 Verify each required fuel oil transfer In accordance system operates to automatically transfer with the fuel oi 1 from storage tanks to the day Surveillance tank. Frequency Control Program SR 3.8.1.7 -------NOTES--------

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

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

Verify each required DG starts from standby In accordance condition and achieves: with the Surveillance

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

b. Steady state voltage ~ 4010 V and ~ 4310 V and frequency ~ 58.8 Hz and ~ 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 In accordance from the normal offsite circuit to the with the alternate offsite circuit. Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.8.1-9 Amendment No 200/ 187

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 r ects a load In accordance greater than or equal to its associated with the single largest post accident load and Surveillance following load rejection, the frequency is Frequency

$ 66.7 Hz. Control Program SR 3.8.1.10 ----NOTES---

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

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

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

Verify each required DG does not trip and In accordance voltage is maintained $ 5000 V during and with the following a load rejection of a load Surveillance

~ 2600 kW. Frequency Control Program (continued)

LaSalle 1 and 2 3.8.1-10 Amendment No. 2001 187

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 In accordance offsite power signal: with the Surveillance

a. De-energization of emergency buses; Frequency Control Program

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

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in ~ 13 seconds,

2. energizes auto-connected shutdown loads,

3. maintains steady state voltage

~ 4010 V and ~ 4310 V,

4. maintains steady state frequency

~ 58.8 Hz and ~ 61.2 Hz, and

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

~ 5 minutes.

(continued)

LaSalle 1 and 2 3.8.1-11 Amendment No 200 / 187

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

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

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

Verify on an actual or simulated Emergency In accordance Core Cooling System (ECCS) initiation with the signal each required DG auto-starts from Surveillance standby condition and: Frequency Control Program

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

b. Achieves steady state voltage ~ 10 V and ~ 4310 V and frequency ~ 58.8 Hz and ~ 61.2 Hz; and

c. Operates for ~ 5 minutes.

(continued)

LaSalle 1 and 2 3.8.1-12 Amendment No.200 I 187

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 In accordance are bypassed on an actual or simulated ECCS with the initiation signal except: Surveillance Frequency

a. Engine overspeed; and Control Program

b. Generator differential current.

(continued)

LaSalle 1 and 2 3.8.1-13 Amendment No.200 / 187

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

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

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

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

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

Verify each required DG operating within In accordance the power factor limit operates for with the 2 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: Surveillance Frequency

a. For 2 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2 2860 kW; and Control Program

b. For the remaining hours of the test loaded 2 2400 kW and ~ 2600 kW.

(continued)

LaSalle 1 and 2 3.8.1-14 Amendment No. 200 / 187

AC Source rating 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 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2 2400 kW and ~ 2600 kW.

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

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

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

Verify each required DG starts and In accordance achieves: with the Surveillance

a. In ~ 13 seconds, voltage 2 4010 V and Frequency frequency 2 58.8 Hz; and Control Program

b. Steady state voltage 2 4010 V and

~ 4310 V and frequency 2 58.8 Hz and ~ 61.2 Hz.

(continued)

LaSalle 1 and 2 3.8.1-15 Amendment No200 / 187

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: In accordance with the

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

b. Transfers loads to offsite power source; and

c. Returns to ready-to load operation.

(continued)

LaSalle 1 and 2 3.8.1-16 Amendment No. 200 1 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.17 ----- --NOTE-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 In accordance test mode and connected to its bus: with the Surveillance

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

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

SR 3.8.1.18 - -- NOTE-This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify interval between each sequenced load In accordance block, for Division 1 and 2 DGs only, is with the 2 90% of the design interval for each time Surveillance delay relay. Frequency Control Program (continued)

LaSalle 1 and 2 3.8.1 17 Amendment NO*200 /187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI 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 In accordance offsite power signal in conjunction with an with the actual or simulated ECCS initiation signal: Surveillance Frequency

a. De-energization of emergency buses; Control Program

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. 200 / 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.20 -NOTE All DG starts may be preceded by an engine prelube period.

Verify, when started simultaneously from In accordance standby condition, each required DG with the achieves, in ~ 13 seconds, voltage ~ 4010 V Surveillance and frequency ~ 58.8 Hz. Frequency Cont ro 1 Prog ram SR 3.8.1.21 -NOTE -

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.200 / 187

Diesel Fuel Oil and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify: In accordance with the

a. ~ a 7 day supply of fuel in the Surveillance combi ned fuel oi 1 storage tank and day Frequency tank for the Division 1 and Division 2 Control Program OGs and the opposite unit Division 2 DG.

b. ~ a 7 day supply of fuel in the combined fuel oil storage tank and day tank for the Division 3 DG.

SR 3.8.3.2 Veri fy fuel oil properties of new and In accordance stored fuel oil are tested in accordance with the Oi esel with, and maintained within the limits of, Fuel Oil the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.3 Verify each DG air start receiver pressure In accordance is ~ 200 psig. with the Surveillance Frequency Control Program SR 3.8.3.4 Check for and remove accumulated water from In accordance each fuel 0; 1 storage tank. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.8.3-3 Amendment NO*200 / 187

DC Sources-Operating 3.8.4 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.l Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Con dition A AND not met for the Division 1 or 2 125 F.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months VDC electrical power subsystem.

OR Required Action and associated Completion Time of Con dition E not met.

G. Required Action and G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Con dition B not met.

SURVEILLANCE REQUIREMENTS

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

I. SR 3.8.4.1 through SR 3.8.4.3 are applicable only to the given un t's DC electrical power sources.

2. SR 3.8.4.4 is applicable only to the opposite unit DC electrical power source.

SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is greater In accordance than or equal to the minimum established with the float voltage. Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.8.4-3 Amendment No.200 I 187

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.4.2 Verify each required battery charger In accordance supplies: with the Surveillance

a. ~ 200 amps at greater than or equal to Frequency the minimum established float voltage Control Program for ~ 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for the Division 1 and 2 125 V battery chargers;

b. ~ 50 amps at greater than or equal to the minimum established float voltage for ~ 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for the Division 3 125 V battery charger; and

c. ~ 200 amps at greater than or equal to the minimum established float voltage for ~ 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for the 250 V battery charger.

Verify each battery charger can recharge the battery to the fully charged state within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.

(continued)

LaSalle 1 and 2 3.8.4-4 Amendment No. 200 I 187

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.3 -NOTES

1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.

2. This Surveillance shall not normally be performed in MODE 1 or 2 for the 125 VDC batteries. 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 battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery In accordance service test. with the Surveillance Frequency Control Program SR 3.8.4.4 ---NOTE ------------

When the opposite unit is in MODE 4 or 5, or moving irradiated fuel in the secondary containment, the following opposite unit SRs are not required to be performed:

SR 3.8.4.2 and SR 3.8.4.3.

For the opposite unit Division 2 DC In accordance electrical power subsystem, the SRs of the with applicable opposite unit Specification 3.8.4 are SRs applicable.

LaSall eland 2 3.8.4-5 Amendment No 200 / 187

Battery Parameters 3.8.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Declare associated Immediately associated Completion battery inoperable.

Time of Condition A, B, C, D, or E not met.

One or more batteries with one or more battery cells float voltage < 2.07 V and float current> 2 amps.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - -

Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.

Verify battery float current is S 2 amps. In accordance with the Surveillance Frequency Control Program SR 3.8.6.2 Verify each battery pilot cell voltage is In accordance 2: 2.07 V. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.8.6-3 Amendment No. 200 / 187

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.3 Verify each battery connected cell In accordance electrolyte level is greater than or equal with the to minimum established design limits. Surveillance Frequency Control Program SR 3.8.6.4 Verify each battery pilot cell temperature In accordance is greater than or equal to minimum with the established design limits. Surveillance Frequency Control Program SR 3.8.6.5 Verify each battery connected cell voltage In accordance is ;?: 2.07 V. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.8.6-4 Amendment NO.200 I 187

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FR ENCY SR 3.8.6.6 - - - - - - - - NOTES - - - - - - - - - - - - -

1. This Surveillance shall not normally be performed in MODE 1 or 2 for the 125 VDC batteries. 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.

2. In MODE 1, 2 or 3, and the opposite unit In accordance in MODE 4 or 5, or moving irradiated with the fuel in the secondary containment, this Surveillance Surveillance is not required to be Frequency performed for the opposite unit Division Control Program 2 DC electrical power subsystem.

3. In MODE 4, 5 or during movement of irradiated fuel in the secondary 12 months when containment in Mode 4, 5 or defueled, battery shows this Surveillance is not required to be degradation or performed. has reached 85%

of expected life with Verify battery capacity is ~ 80% of the capacity manufacturer's rating when subjected to a < 100% of performance discharge test or a modified manufacturer's performance discharge test. rating 24 months when battery has reached 85% of the life with capacity

~ 100% of manufacturer's rating LaSalle 1 and 2 3.8.6-5 Amendment No. 200 / 187

Distribution Systems~Operating 3.8.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. One or both Division 3 F.l Declare associated Immediately AC or DC electrical supported features power distribution inoperable.

subsystems inoperable.

G. Division 1 250 V DC G.1 Declare associated Immediately electrical power supported features subsystem inoperable. inoperable.

H. Two or more electrical H.l Enter LCO 3.0.3. Immediately power distribution subsystems inoperable that, in combination, result in a loss of function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct breaker alignments and In accordance voltage to required AC and DC electrical with the power distribution subsystems. Surveillance Frequency Control Program LaSalle 1 and 2 3.8.7-3 Amendment No. 200 I 187

Distribution Systems-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.

A.2.4 Initiate actions to Immediately restore required AC and DC electrical power distribution subsystems to OPERABLE status.

A.2.S Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct breaker alignments and In accordance voltage to required AC and DC electrical with the power distribution subsystems. Surveillance Frequency Control Program LaSalle 1 and 2 3.8.8-2 Amendment N0200 / 187

Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of In accordance the following required refueling equipment with the interlock inputs: Surveillance Frequency

a. All rods-in, Control Program

b. Refuel platform position,

c. Refuel platform fuel grapple, fuel loaded,

d. Refuel platform frame mounted hoist, fuel-loaded,

e. Refuel platform trolley-mounted hoist, fuel loaded, and

f. Service platform hoist, fuel-loaded.

LaSall eland 2 3.9.1-2 Amendment No. 2001 187

Refuel Position One-Rod Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod Out Interlock LCD 3.9.2 The refuel position one-rod out interlock shall be OPERABLE.

APPLICABILITY: MODE 5 with the reactor mode switch in the refuel position and any control rod withdrawn.

ACTIONS CONDITION REQU I RED ACTION COMP LETI ON TI ME A. Refuel position one A.1 Suspend control rod Immediately rod out interlock withdrawal.

inoperable.

A.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in refuel In accordance position. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.9.2-1 Amendment No.2DD / 187

Refuel Position One Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.2 --NOTE Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.2-2 Amendment No. 200/ 187

Control Rod Position 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be full y inserted.

APPLICABI LITY: When loading fuel assemblies into the core.

ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. One or more control A.l Suspend loading fuel Immediately rods not fully assemblies into the inserted. core.

SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.3 1 Amendment No.200 / 187

Control Rod OPERABILITY-Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY-Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.

APPLICABI LITY: MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIlvlE A. One or more withdrawn A.l Initiate action to Immediately control rods fully insert inoperable. inoperable withdrawn control rods.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 - - - - - - - - - - NOTE - - -

Not required to be performed until 7 days after the control rod is withdrawn.

Insert each withdrawn control rod at least In accordance one notch. with the Surveillance Frequency Control Program SR 3.9.5.2 Verify each withdrawn control rod scram In accordance accumulator pressure is ~ 940 psig. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.5 1 Amendment No. 200 / 187

RPV Water Level-Irradiated Fuel 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level-Irradiated Fuel LCO 3.9.6 RPV water level shall be ~ 22 ft above the top of the RPV fl ange.

APPLICABI LITY: During movement of irradiated fuel assemblies within the RPV.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not A.l Suspend movement of Immediately within 1imit. i rradi ated fuel assemblies within the RPV.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify RPV water level is ~ 22 ft above the In accordance top of the RPV fl ange. wi th the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.6-1 Amendment No.200 I 187

RPV Water Level-New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel (RPV) Water Level-New Fuel or Control Rods LCO 3.9.7 RPV water 1evel shall be ~ 23 ft above the top of i rradi ated fuel assemblies seated within the RPV.

APPLICABI LITY: During movement of new fuel assemblies or handling of control rods within the RPV when irradiated fuel assemblies are seated within the RPV.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water 1evel not A.l Suspend movement of Immediately within limit. new fuel assemblies and handling of control rods within the RPV.

SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.9.7.1 Verify RPV water level is ~ 23 ft above the In accordance top of irradiated fuel assemblies seated with the withi n the RPV. Surveillance Frequency Control Program LaSalle 1 and 2 3.9.7-1 Amendment No.200 I 187

RHR-High Water Level 3.9.8 SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem In accordance is operating. with the Surveillance Frequency Control Program LaSall eland 2 3.9.8 3 Amendment No. 200 I 187

RHR-Low Water Level 3.9.9 SURVEILLANCE FREQUENCY SR 3.9.9.1 Verify one RHR shutdown cooling subsystem In accordance is operating. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.9.9-3 Amendment No .200 / 187

Reactor Mode Switch Interlock Testing 3.10.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

QR A.3.2 - - *NOTE---*

Only applicable in MODE 5.

Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the refuel position.

SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.10.1.1 Verify all control rods are fully inserted In accordance in core cells containing one or more fuel with the assemblies. Surveillance Frequency Control Program SR 3.10.1.2 Verify no CORE ALTERATIONS are in progress. In accordance with the Surveillance Frequency Control Program LaSalle 1 and 2 3.10.1 2 Amendment No.200 I 187

Single Control Rod Withdrawal-Hot Shutdown 3.10.2 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.10.2.1 Perform the applicable SRs for the required According to LCOs. the applicable SRs SR 3.10.2.2 ---- NOTE---

Not required to be met if SR 3.10.2.1 is satisfied for LCO 3.10.2.d.1 requirements.

Verify all control rods, other than the In accordance control rod being withdrawn, in a five by with the five array centered on the control rod Surveillance being withdrawn, are disarmed. Frequency Control Program SR 3.10.2.3 Verify all control rods, other than the In accordance control rod being withdrawn, are fully with the inserted. Surveillance Frequency Control Program LaSalle 1 and 2 3.10.2-3 Amendment No. 200 I 187

Single Control Rod Withdrawal-Cold Shutdown 3.10.3 CONDITION REQU I RED ACTI ON COMPLETION TIME B. One or more of the B.1 Suspend withdrawal of Immediately above requirements not the control rod and met with the affected removal of associated control rod not CRD.

insertable.

B.2.1 Initiate action to Immediately fully insert all control rods.

B.2.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the According to required LCOs. applicable SRs SR 3.10.3.2 NOTE-- -

Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.c.1 requirements.

Verify all control rods. other than the In accordance control rod being withdrawn. in a five by with the fi ve array centered on the control rod Surveillance being withdrawn, are disarmed. Frequency Control Program (continued)

LaSalle 1 and 2 3.10.3-3 Amendment No.200 ! 187

Single Control Rod Withdrawal~Cold Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.3 Veri fy all control rods, other than the In accordance control rod being withdrawn, are fully with the inserted. Surveillance Frequency Control Program SR 3.10.3.4 ---- ----------NOTE -----

Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.b.1 requirements.

Verify a control rod withdrawal block is In accordance inserted. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.10.3 4 Amendment No.2DD / 187

Single CRD Removal-Refueling 3.10.4 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. (continued) A.2.1 Initiate action to Immediately fully insert all control rods.

A.2.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.1 Verify all controls rods, other than the In accordance control rod withdrawn for the removal of with the the associated CRD, are fully inserted. Surveillance Frequency Control Program SR 3.10.4.2 Verify all control rods, other than the In accordance control rod withdrawn for the removal of with the the associated (RD, in a five by five array Surveillance centered on the control rod withdrawn for Frequency the removal of the associated CRD, are Control Program disarmed.

SR 3.10.4.3 Verify a control rod withdrawal block is In accordance inserted. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.10.4-2 Amendment No. 200/ 187

Single CRD Removal-Refueling 3.10.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 SR 3.10.4.5 Verify no other CORE ALTERATIONS are in In accordance progress. with the Surveillance Frequency Control Program LaSall eland 2 3.10.4-3 Amendment No. 200/ 187

Multiple Control Rod Withdrawal-Refueling 3.10.5 ACTIONS CONDITION REQU I RED ACTI ON COMPLETION TIME A. (continued) A.2.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify the four fuel assemblies are removed In accordance from core cells associated with each with the control rod or CRD removed. Surveillance Frequency Control Program SR 3.10.5.2 Verify all other control rods in core cells In accordance containing one or more fuel assemblies are with the fully inserted. Surveillance Frequency Control Program SR 3.10.5.3 Verify fuel assemblies are not being loaded In accordance into or shuffled within the reactor with the pressure vessel. Surveillance Frequency Control Program LaSalle 1 and 2 3.10.5 2 Amendment No. 200 / 187

SDM Test-Refueling 3.10.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.7.2 - -NOTE Not required to be met if SR 3.10.7.3 satisfied.

Perform the MODE 2 applicable SRs for According to LCO 3.3.2.1, Function 2 of Table the applicable 3.3.2.1 1. SRs SR 3.10.7.3 NOTE Not required to be met if SR 3.10.7.2 satisfied.

Verify movement of control rods is in During control compliance with the approved control rod rod movement sequence for the SDM test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.7.4 Verify no other CORE ALTERATIONS are in In accordance progress. with the Surveillance Frequency Control Program (continued)

LaSalle 1 and 2 3.10.7-3 Amendment No. 200 / 187

SOM Test-Refueling 3.10.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.7.5 Verify each withdrawn control rod does not Each time the go to the withdrawn overtravel position. control rod is withd rawn to "full out" position Prior to satisfying LCO 3.10.7.c requirement after work on contra 1 rod or CRD System that could affect coupling SR 3.10.7.6 Verify CRD charging water header pressure In accordance

~ 940 psig. with the Surveillance Frequency Control Program LaSalle 1 and 2 3.10.7-4 Amendment NO.200 / 187

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Control Room Envelope Habitability Program (continued)

d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one train of the CRAF System, operating at the flow rate required by the VFTP, at a Frequency of 24 months on a STAGGERED TEST BASIS.

The results shall be trended and used as part of the 24 month assessment of the CRE boundary.

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. Unfiltered air inleakge limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

5.5.16 This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.

(continued)

LaSalle 1 and 2 5.5 15 Amendment No. 200 / 187

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16 Surveillance Frequency Control Program (continued)

b. Changes to the "requencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04 10, "Risk Informed Method for Control of Surveillance Frequencies," Revision 1.

c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.

LaSalle 1 and 2 5.5-16 Amendment NO*200 / 187

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 200 TO FACILITY OPERATING LICENSE NO. NPF-11 AND AMENDMENT NO. 187 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 Nuclear Regulatory Commission (NRC, the Commission) dated February 15, 2010 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML100480009), as supplemented by letters dated April 26, 2010 (ADAMS Accession No. ML101160374), June 23,2010 (ADAMS Accession No. ML101750102), and August 3,2010 (ADAMS Accession No. ML110390169) Exelon Generation Company, LLC (the licensee),

requested changes to the technical specifications (TSs) for LaSalle County Station (LSCS),

Units 1 and 2. The April 26, June 23, and August 3, 2010, supplements, contained clarifying information and did not change the NRC staff's initial proposed 'finding of no significant hazards consideration published in the Federal Register (75 FR 20636, April 20, 2010).

The requested change is the adoption of NRC-approved Technical Specification Task Force (TSTF-425), Revision 3, "Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative 5b." When implemented, TSTF-425 relocates most periodic frequencies of TS surveillances to a licensee controlled program, the Surveillance Frequency Control Program (SFCP), and provides requirements for the new program in the Administrative Controls section of the TS. All surveillance frequencies can be relocated except:

Frequencies that reference other approved programs for the specific interval (such as the In-Service Testing Program or the Primary Containment Leakage Rate Testing Program);

Frequencies that are purely event-driven (e.g., "each time the control rod is withdrawn to the 'full out' position");

Frequencies that are event-driven, but have a time component for performing the surveillance on a one-time basis once the event occurs (e.g., "within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after thermal power reaching ~ 95% RTP"); and

2

Frequencies that are related to specific conditions (e.g., battery degradation, age and capacity) or conditions for the performance of a surveillance requirement (e.g., "drywell to suppression chamber differential pressure decrease.")

A new program is added to the Administrative Controls of TS Section 5 as 5.5.16 called the SFCP and describes the requirements for the program to control changes to the relocated surveillance frequencies. The TS Bases for each of the affected surveillance requirements are revised to state that the frequency is set in accordance with the SFCP. Some surveillance requirements Bases do not contain a discussion of the frequency. In these cases, the Bases describing the current frequency were added to maintain consistency with the Bases for similar surveillances. These instances are noted in the markup along with the source of the text. The proposed licensee changes to the Administrative Controls of the TS to incorporate the SFCP include a specific reference to Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical SpeCifications Initiative 5B, Risk-Informed Method for Control of Surveillance Frequencies," Revision 1, as the basis for making any changes to the surveillance frequencies once they are relocated out of the TS.

In a letter dated September 19, 2007, the NRC staff approved NEI 04-10, Revision 1, (ADAMS Accession No. ML072570267), as acceptable for referencing in licensing actions to the extent specified and under the limitations delineated in NEI 04-10, and the safety evaluation providing the basis for NRC acceptance of NEI 04-10.

2.0 REGULATORY EVALUATION

In the "Final Policy Statement on Technical Specifications Improvements for Nuclear Power Reactors," published in the Federal Register (58 FR 39132, July 22,1993), the NRC addressed the use of Probabilistic Safety Analysis <<PSA), currently referred to as Probabilistic Risk Assessment (PRA) in Standard Technical Specifications. In discussing the use of PSA in Nuclear Power Plant Technical Specifications, the Commission wrote in part:

The Commission believes that it would be inappropriate at this time to allow requirements which meet one or more of the first three criteria to be deleted from technical specifications based solely on PSA (Criterion 4). However, if the results of PSA indicate that technical specifications can be relaxed or removed, a deterministic review will be performed.

The Commission Policy in this regard is consistent with its Policy Statement on "Safety Goals for the Operation of Nuclear Power Plants," (51 FR 30028, published on August 21,1986). The Policy Statement on Safety Goals states in part, " ... [probabilistic] results ... should also be reasonably balanced and supported through use of deterministic arguments. In this way, judgments can be made ... about the degree of confidence to be given these [probabilistic]

estimates and assumptions. This is a key part of the process for determining the degree of regulatory conservatism that may be warranted for particular decisions.

This defense-in-depth approach is expected to continue to ensure the protection of public health and safety."

The Commission will continue to use PSA, consistent with its policy on Safety Goals, as a tool in evaluating specific line item improvements to TSs new

- 3 requirements, and industry proposals for risk-based Technical Specification change.

Approximately two years later, the NRC provided additional detail concerning the use of PRAs in the 'Use of Probabilistic Risk Assessment in Nuclear Regulatory Activities: Final Policy Statement," published in the Federal Register (60 FR 42622, August 16,1995). The Commission, in discussing the deterministic and probabilistic approach to regulation, and the Commission's extension and enhancement of traditional regulation, wrote in part:

PRA addresses a broad spectrum of initiating events by assessing the event frequency. Mitigating system reliability is then assessed, including the potential for multiple and common cause failures. The treatment therefore goes beyond the single-failure requirements in the deterministic approach. The probabilistic approach to regulation is, therefore, considered an extension and enhancement of traditional regulation by considering risk in a more coherent and complete manner.

The Commission provided its new policy, stating:

Although PRA methods and information have thus far been used successfully in nuclear regulatory activities, there have been concerns that PRA methods are not consistently applied throughout the agency, that sufficient agency PRNstatistics expertise is not available, and that the Commission is not deriving full benefit from the large agency and industry investment in the developed risk assessment methods. Therefore, the Commission believes that an overall policy on the use of PRA in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that promotes regulatory stability and efficiency. This policy statement sets forth the Commission's intention to encourage the use of PRA and to expand the scope of PRA applications in all nuclear regulatory matters to the extent supported by the state-of-the-art in terms of methods and data.

Implementation of the policy statement will improve the regulatory process in three areas: Foremost, through safety decisionmaking enhanced by the use of PRA insights; through more efficient use of agency resources; and through a reduction in unnecessary burdens on licensees.

Therefore, the Commission adopts the following policy statement regarding the expanded NRC use of PRA:

(1) The use of PRA technology should be increased in all regulatory matters to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach and supports the NRC's traditional defense-in-depth philosophy.

(2) PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where practical within the bounds of the state-of-the-art, to reduce unnecessary conservatism associated with current regulatory requirements, regulatory guides, license commitments, and staff practices. Where appropriate, PRA should be used to

-4 support the proposal for additional regulatory requirements in accordance with 10 CFR 50.109 (8ackfit Rule). Appropriate procedures for including PRA in the process for changing regulatory requirements should be developed and followed.

It is, of course, understood that the intent of this policy is that existing rules and regulations shall be complied with unless these rules and regulations are revised.

(3) PRA evaluations in support of regulatory decisions should be as realistic as practicable and appropriate supporting data should be publicly available for review.

(4) The Commission's safety goals for nuclear power plants and subsidiary numerical objectives are to be used with appropriate consideration of uncertainties in making regulatory judgments on the need for proposing and backfitting new generic requirements on nuclear power plant licensees.

In Title 10 of the Code of Federal Regulations (10 CFR) 50.36, the NRC established its regulatory requirements related to the content of TSs. Pursuant to 10 CFR 50.36, the TSs are required to 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 conditions for operation; (3) surveillance requirements; (4) design features; and (5) administrative controls.

As stated in 10 CFR 50.36( c)(3),

Surveillance requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the conditions for operation will be met.

These categories will remain in the TS. The new TS SFCP provides the necessary administrative controls to require that surveillances relocated to the SFCP are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Changes to surveillance frequencies in the SFCP are made using the methodology contained in NEI 04-10, including qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, and recommended monitoring of structures, systems, and components (SSCs), and required to be documented. Furthermore, changes to frequencies are subject to regulatory review and oversight of the SFCP implementation through the rigorous NRC review of safety-related SSC performance provided by the reactor oversight program.

Licensees are required by the TS to perform surveillance test, calibration, or inspection on specific safety-related system equipment (e.g., reactivity control, power distribution, electrical, and instrumentation) to verify system operability. Surveillance frequencies, currently identified in the TSs, are based primarily upon deterministic methods such as engineering judgment, operating experience, and manufacturer's recommendations. The licensee's use of NRC approved methodologies identified in NEI 04-10 provides a way to establish risk-informed surveillance frequencies that complement the deterministic approach and support the NRC's traditional defense-in-depth philosophy.

- 5 The licensee's SFCP ensures that surveillance requirements specified in the TSs are performed at intervals sufficient to assure the above regulatory requirements are met. Existing regulatory requirements, such as 10 CFR 50.65, "Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants," and 10 CFR Part 50, Appendix B, (Corrective Action Program), require licensee monitoring of surveillance test failures and implementing corrective actions to address such failures. One of these actions may be to consider increasing the frequency at which a surveillance test is performed. In addition, the SFCP implementation guidance in NEI 04-10 requires monitoring the performance of SSCs for which surveillance frequencies are decreased to assure reduced testing does not adversely impact the SSCs.

These requirements, and the monitoring required by NEI 04-10, ensure that surveillance frequencies are sufficient to assure that the requirements of 10 CFR 50.36 are satisfied and that any performance deficiencies will be identified and appropriate corrective actions taken.

Regulatory Guide (RG) 1.174, "An Approach for Using Probabilistic Risk Assessment in Risk Informed Decisions on Plant-Specific Changes to the Licensing Basis," describes a risk informed approach, acceptable to the NRC, for assessing the nature and impact of proposed permanent licensing-basis changes by considering engineering issues and applying risk inSights. This RG also provides risk acceptance guidelines for evaluating the results of such evaluations.

In RG 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," it describes an acceptable risk-informed approach specifically for assessing proposed permanent TS changes.

In RG 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," it describes an acceptable approach for determining whether the quality of the PRA, in total or the parts that are used to support an application, is sufficient to provide confidence in the results, such that the PRA can be used in regulatory decision making for light-water reactors.

3.0 TECHNICAL EVALUATION

The licensee's adoption ofTSTF-425 for LSCS provides for administrative relocation of applicable surveillance frequencies, and provides for the addition of the SFCP to the administrative controls of the TSs. TSTF-425 also requires the application of NEI 04-10 for any changes to surveillance frequencies within the SFCP. The licensee's application for the changes proposed in TSTF-425 included documentation regarding the PRA technical adequacy consistent with the requirements of RG 1.200. In accordance with NEI 04-10, PRA methods are used in combination with plant performance data and other considerations, to identify and justify modifications to the surveillance frequencies of equipment at nuclear power plants. This is in accordance with guidance provided in RG 1.174 and RG 1.177 in support of changes to surveillance test intervals.

3.1 RG 1.177 Five Key Safety Principles In RG 1.177, it identifies five key safety principles required for risk-informed changes to TSs.

Each of these principles is addressed by the industry methodology document, NEI 04-10.

-6 3.1.1 The Proposed Change Meets Current Regulations Section 50.36(c)(3) to 10 CFR provides that TSs will include surveillances which are "requirements relating to test, calibration, or inspection to assure that necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." NEI 04-10 provides guidance for relocating the surveillance frequencies from the TSs to a licensee-controlled program by providing an NRC-approved methodology for control of the surveillance frequencies. The surveillances themselves would remain in the TSs, as required by 10 CFR 50.36(c)(3).

This change is consistent with other NRC-approved TS changes in which the surveillance frequencies are relocated to licensee-controlled documents, such as surveillances performed in accordance with the In-service Testing Program or the Primary Containment Leakage Rate Testing Program. Thus, this proposed change meets the first key safety principle of RG 1.177 by complying with current regulations.

3.1.2 The Proposed Change Is Consistent With the Defense-in-Depth Philosophy Consistency with the defense-in-depth philosophy, the second key safety principle of RG 1.177, is maintained if:

A reasonable balance is preserved among prevention of core damage, prevention of containment failure, and consequence mitigation.

Over-reliance on programmatic activities to compensate for weaknesses in plant design is avoided.

System redundancy, independence, and diversity are preserved commensurate with the expected frequency, consequences of challenges to the system, and uncertainties (e.g.,

no risk outliers). Because the scope of the proposed methodology is limited to revision of surveillance frequencies, the redundancy, independence, and diversity of plant systems are not impacted.

Defenses against potential common-cause failures are preserved, and the potential for the introduction of new common-cause failure mechanisms is assessed.

Independence of barriers is not degraded.

Defenses against human errors are preserved.

The intent of the General Design Criteria in 10 CFR Part 50, Appendix A, is maintained.

In TSTF-425, it requires the application of NEI 04-10 for any changes to surveillance frequencies within the SFCP. NEI 04-10 uses both the core damage frequency (CDF) and the large early release frequency (LERF) metrics to evaluate the impact of proposed changes to surveillance frequencies. The guidance of RG 1.174 and RG 1.177 for changes to CDF and LERF is achieved by evaluation using a comprehensive risk analysis, which assesses the

-7 impact of proposed changes including contributions from human errors and common-cause failures.

Defense-in-depth is also included in the methodology explicitly as a qualitative consideration outside of the risk analysis, as is the potential impact on detection of component degradation that could lead to an increased likelihood of common-cause failures. Both the quantitative risk analysis and the qualitative considerations assure a reasonable balance of defense-in-depth is maintained to ensure protection of public health and safety, satisfying the second key safety principle of RG 1.177.

3.1.3 The Proposed Change Maintains Sufficient Safety Margins The engineering evaluation that will be conducted by the licensee under the SFCP when frequencies are revised will assess the impact of the proposed frequency change with the principle that sufficient safety margins are maintained. The guidelines used for making that assessment will include ensuring that the proposed surveillance test frequency change is not in con1'lict with approved industry codes and standards or adversely affects any assumptions or inputs to the safety analysis, or, if such inputs are affected, justification is provided to ensure sufficient safety margin will continue to exist.

The design, operation, testing methods, and acceptance criteria for SSCs, specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as described in the plant licensing basis (including the Updated Final Safety Analysis Report and Bases to TSs) since these are not affected by changes to the surveillance frequencies. Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis. Thus, safety margins are maintained by the proposed methodology, and the third key safety principle of RG 1.177 is satisfied.

3.1.4 When Proposed Changes Result in an Increase in Core Damage Frequency or Risk, the Increases Should Be Small and Consistent With the Intent of the Commission's Safety Goal Policy Statement A framework for evaluating the risk impact of proposed changes is provided in RG 1.177 to surveillance frequencies. This requires the identification of the risk contribution from impacted surveillances, determination of the risk impact from the change to the proposed surveillance frequency, and performance of sensitivity and uncertainty evaluations. TSTF-425 requires application of NEI 04-10 in the SFCP. NEI 04-10 satisfies the intent of RG 1.177 requirements for evaluating the change in risk and for assuring that such changes are small.

3.1.4.1 Quality of the PRA The quality of the LSCS PRA is compatible with the safety implications of the proposed TS change and the role the PRA plays in justifying the change. That is, the more the potential change in risk or the greater the uncertainty in that risk from the requested TS change, or both, the more rigor that must go into ensuring the quality of the PRA.

The licensee used RG 1.200 to address the technical adequacy of the LSCS PRA. RG 1.200 is NRC's developed regulatory guidance, which endorses with comments and qualifications the use of the American Society of Mechanical Engineers (ASME) RA-Sb-2005, "Addenda to

-8 ASME RA-S-2002 Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications," NEI 00-02, "PRA Peer Review Process Guidelines," and NEI 05-04, "Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard." The licensee has performed an assessment of the PRA models used to support the SFCP against the requirements of RG 1.200 to assure that the PRA models are capable of determining the change in risk due to changes to surveillance frequencies of SSCs, using plant-specific data and models. Capability Category II of ASME RA-St:r2005 is applied as the standard, and any identified deficiencies to those requirements are assessed further to determine any impacts to proposed decreases to surveillance frequencies, including the use of sensitivity studies where appropriate.

The NRC staff reviewed the licensee's assessment of the LSCS PRA and the remaining open deficiencies that do not conform to capability Category II of the ASME PRA standard (Table A.2 1 of Attachment 2 of the license amendment request). The NRC staff's assessment of these open "gaps," to assure that they may be addressed and dispositioned for each surveillance frequency evaluation per the NEI 04-10 methodology, is provided below.

Gap IE-A7: A review of plant-specific initiating event precursors has not been performed such that this supporting requirement is met only at capability Category I. The licensee stated this is a documentation issue, and that no additional initiating event categories would be identified by conducting any further precursor reviews. The NRC staff concurs that a review of such precursors is unlikely to identify new significant initiators for LSCS, and therefore, this deficiency can be addressed per the methodology of NEI 04-10.

Gap IE-D3, AS-C3, SC-C3, SY-C3, HR-13, DA-E3, IF-F3, QU-E2, QU-E4, QU-F4, LE-F3, LE-G4: Sources of model uncertainty and related assumptions have not been documented.

Each individual surveillance frequency evaluation will follow the guidance available in NUREG 1855, and therefore, the NRC staff concurs that this documentation issue can be addressed per the methodology of NEI 04-10.

Gap SC-B5: The supporting engineering bases for success criteria were not adequately verified for reasonableness and acceptability. The licensee identified this as a documentation issue since the success criteria calculations do include cross-comparisons of different thermal hydraulic codes. The NRC staff concurs that the licensee has performed adequate verification of its success criteria bases, and therefore, this deficiency can be addressed per the methodology of NEI 04-10.

Gap SY-A4: The systems analysis notebooks do not consistently document the performance of walk downs as required by this supporting requirement. The peer review team and the licensee disposition of this item indicate that such walk downs were conducted in the original development of the PRA models, but the documentation was not retained in the system notebooks. The NRC staff concurs that this deficiency is related to the system notebook documentation and not the technical adequacy of the system models, and can be addressed per the methodology of NEI 04-10.

Gaps HR-A 1, HR-A2, HR-B1: These supporting requirements address the identification of potential human error events by review of operational practices and procedures and applying appropriate screening criteria. The licensee identified these gaps as documentation issues based on the peer review team not identifying any events missing from the PRA model. The

-9 NRC staff concurs that these documentation deficiencies can be addressed per the methodology of NEI 04-10.

Gap HR-G6: A comparison of human error probabilities is required by the standard but there was no discussion in the analysis of this being performed. The licensee stated that such a reasonableness check was performed for LSCS PRA model and that this is a documentation issue. The NRC staff concurs that this deficiency is related to documentation and not the technical adequacy of the human reliability analysis and can be addressed per the methodology of NEI 04-10.

Gap DA-C8: The standby status probabilities are not always based on plant operational data as required to meet capability Category II. The system or train standby times are estimated based on the surveillance test intervals, which is identified as consistent with actual practice. The use of scheduled and prescribed surveillance tests as the basis for the number of standby hours is equal to or greater than the actual number of hours between tests. Unplanned tests are not credited in the number of standby hours between tests. This is conservative since it leads to a slightly higher failure rate than might be calculated from the use of the plant operating records number of standby hours. This difference does not significantly impact the risk profile. The use of the frequency of LSCS component surveillance tests are appropriate estimates for the system or train standby times because the surveillance tests are monitored in accordance with specific plant and corporate procedures. The NRC staff concurs with the licensee's disposition of this item, and it can be addressed per the methodology of NEI 04-10.

Gap DA-C10: A review of surveillance test procedures to determine which component failure modes are fully tested has not been completed. The number of plant-specific demands is based on the number of surveillance tests performed, which is conservative (Le., lower) with respect to the actual number of demands experienced. This approach captures the appropriate number of demands performed during each test (Le., reflects the number of demands within the test procedure if more than one). Unplanned tests are not included in the number of demands.

This is conservative since it leads to a slightly higher failure rate than might be calculated from the use of the actual demand count. Based on the Bayesian update process incorporated for calculating the LSCS component failure data, this difference does not significantly impact the risk profile. The NRC staff concurs with the licensee's disposition of this item, and it can be addressed per the methodology of NEI 04-10.

Gap IF-C3b: Flood barrier unavailability was identified as not being discussed, although the peer review team identified it as having minimal significance. The disposition of this deficiency stated that flood barrier unavailability was considered and included in the internal flood analysis, and therefore, is only a documentation issue. The NRC staff concurs that this documentation issue can be addressed per the methodology of NEI 04-10.

Gaps QU-D1 a, QU-D4: The review of cutsets was identified as insufficient based on the number of cutsets reviewed. The licensee stated that additional reviews of more cutsets are performed but are not documented, and therefore, is only a documentation issue. The NRC staff concurs that this documentation issue can be addressed per the methodology of NEI04-10.

10 Gaps QU-F3, QU-F6: These supporting requirements address documentation requirements for the model quantification which have no impact on the PRA model. The NRC staff concurs that this documentation issue can be addressed per the methodology of NEI 04-10.

Based on the licensee's assessment using the applicable PRA standard and RG 1.200, the level of PRA quality, combined with the proposed evaluation and disposition of gaps, is sufficient to support the evaluation of changes proposed to surveillance frequencies within the SFCP, and is consistent with Regulatory Position 2.3.1 of RG 1.177.

3.1.4.2 Scope of the PRA The licensee is required to evaluate each proposed change to a relocated surveillance frequency using the guidance contained in NEI 04-10 to determine its potential impact on risk, due to impacts from internal events, fires, seismic, other external events, and from shutdown conditions. Consideration is made of both CDF and LERF metrics. In cases where a PRA of sufficient scope or where quantitative risk models were unavailable, the licensee uses bounding analyses or other conservative quantitative evaluations. A qualitative screening analysis may be used when the surveillance frequency impact on plant risk is shown to be negligible or zero.

The licensee has developed a fire PRA model, which is an interim implementation of the methodology of NUREG/CR-6850 because not all tasks identified in this document are completely addressed. The licensee identified the incomplete tasks and characterized the limitations of its existing fire PRA model. For surveillance interval evaluations, the licensee intends to employ the fire PRA model to obtain quantitative insights when needed to supplement a qualitative or bounding assessment.

The individual plant examination of external events (IPEEE) seismic margins analysis will be used to provide seismic insights. Other external hazards were screened during the IPEEE assessment, and will therefore, be qualitatively assessed for this application.

The licensee's evaluation methodology is sufficient to ensure the scope of the risk contribution of each surveillance frequency change is properly identified for evaluation and is consistent with Regulatory Position 2.3.2 of RG 1.177.

3.1.4.3 PRA Modeling The licensee will determine whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA. Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out. The methodology adjusts the failure probability of the impacted SSCs, including any impacted common cause failure modes, based on the proposed change to the surveillance frequency. Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to the surveillance frequency. Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy consistent with guidance contained in RG 1.200, and by sensitivity studies identified in NEI 04-10.

11 The licensee will perform quantitative evaluations of the impact of the selected testing strategy (i.e., staggered testing or sequential testing) consistent with the guidance of NUREG/CR-8141 and NUREG/CR-5497, as discussed in NEI 04-10.

Thus, through the application of NEI 04-10, the lSCS PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency and is consistent with Regulatory Position 2.3.3 of RG 1.177.

3.1.4.4 Assumptions for Time-Related Failure Contributions The failure probabilities of SSCs modeled in the lSCS PRA include a standby time-related contribution and a cyclic demand-related contribution. NEI 04-10 criteria adjust the time-related failure contribution of SSCs affected by the proposed change to surveillance frequency. This is consistent with RG 1.177, Section 2.3.3, which permits separation of the failure rate contributions into demand and standby for evaluation of surveillance requirements. If the available data do not support distinguishing between the time-related failures and demand failures, then the change to surveillance frequency is conservatively assumed to impact the total failure probability of the SSC, including both standby and demand contributions. The SSC failure rate (per unit time) is assumed to be unaffected by the change in test frequency and will be confirmed by the required monitoring and feedback implemented after the change in surveillance frequency is implemented. The process requires consideration of qualitative sources of information with regards to potential impacts of test frequency on SSC performance, including industry and plant-specific operating experience, vendor recommendations, industry standards, and code-specified test intervals. Thus, the process is not reliant upon risk analyses as the sole basis for the proposed changes.

The potential beneficial risk impacts of reduced surveillance frequency, including reduced downtime, lesser potential for restoration errors, reduction of potential for test caused transients, and reduced test-caused wear of equipment, are identified qualitatively, but are conservatively not required to be quantitatively assessed. Thus, through the application of NEI 04-10, the licensee has employed reasonable assumptions with regard to extensions of surveillance test intervals, and is consistent with Regulatory Position 2.3.4 of RG 1.177.

3.1.4.5 Sensitivity and Uncertainty Analyses In NEI 04-10, it requires sensitivity studies to assess the impact of uncertainties from key assumptions of the PRA, uncertainty in the failure probabilities of the affected SSCs, impact to the frequency of initiating events, and of any identified deviations from capability Category" of ASME PRA Standard (ASME RA-Sb-2005) (Reference 4). Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies. Required monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented will also be performed. Thus, through the application of NEI 04-10, the licensee has appropriately considered the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations, and is consistent with Regulatory Position 2.3.5 of RG 1.177.

12 3.1.4.6 Acceptance Guidelines The licensee will quantitatively evaluate the change in total risk (including internal and external events contributions) in terms of CDF and LERF for both the individual risk impact of a proposed change in surveillance frequency and the cumulative impact from all individual changes to surveillance frequencies using the guidance contained in NRC approved NEI 04-10 in accordance with the TS SFCP. Each individual change to surveillance frequency must show a risk impact below 1E-6 per year for change to CDF, and below 1E-7 per year for change to LERF. These are consistent with the limits of RG 1.174 for very small changes in risk. Where the RG 1.174 limits are not met, the process either considers revised surveillance frequencies which are consistent with RG 1.174 or the process terminates without permitting the proposed changes. Where quantitative results are unavailable to permit comparison to acceptance guidelines, appropriate qualitative analyses are required to demonstrate that the associated risk impact of a proposed change to surveillance frequency is negligible or zero. Otherwise, bounding quantitative analyses are required which demonstrate the risk impact is at least one order of magnitude lower than the RG 1.174 acceptance guidelines for very small changes in risk. In addition to assessing each individual SSC surveillance frequency change, the cumulative impact of all changes must result in a risk impact below 1E-S per year for change to CDF, and below 1E-6 per year for change to LERF, and the total CDF and total LERF must be reasonably shown to be less than 1E-4 per year and 1E-S per year, respectively. These are consistent with the limits of RG 1.174 for acceptable changes in risk, as referenced by RG 1.177 for changes to surveillance frequencies. The NRC staff interprets this assessment of cumulative risk as a requirement to calculate the change in risk from a baseline model utilizing failure probabilities based on the surveillance frequencies prior to implementation of the SFCP, compared to a revised model with failure probabilities based on changed surveillance frequencies. The NRC staff further notes that Exelon includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (less than SE-8 per year CDF and SE-9 per year LERF) once the baseline PRA models are updated to include the effects of the revised surveillance frequencies.

The quantitative acceptance guidance of RG 1.174 is supplemented by qualitative information to evaluate the proposed changes to surveillance 'frequencies, including industry and plant-specific operating experience, vendor recommendations, industry standards, the results of sensitivity studies, and SSC performance data and test history.

The final acceptability of the proposed change is based on all of these considerations and not solely on the PRA results compared to numerical acceptance guidelines. Post implementation performance monitoring and feedback are also required to assure continued reliability of the components. The licensee's application of NEI 04-10 provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed changes to surveillance frequencies, consistent with Regulatory Position 2.4 of RG 1.177. Therefore, the proposed Exelon methodology satisfies the fourth key safety principle of RG 1.177 by assuring any increase in risk is small consistent with the intent of the Commission's Safety Goal Policy Statement.

- 13 3.1.5 The Impact of the Proposed Change Should Be Monitored Using Performance Measurement Strategies The licensee's adoption of TSTF-425 requires application of NEI 04-10 in the SFCP.

NEI 04-10 requires performance monitoring of SSCs whose surveillance frequency has been revised as part of a feedback process to assure that the change in test frequency has not resulted in degradation of equipment performance and operational safety. The monitoring and feedback includes consideration of maintenance rule monitoring of equipment performance. In the event of degradation of SSC performance, the surveillance frequency will be reassessed in accordance with the methodology, in addition to any corrective actions which may apply as part of the maintenance rule requirements. The performance monitoring and feedback specified in NEI 04-10 is sufficient to reasonably assure acceptable SSC performance and is consistent with Regulatory Position 3.2 of RG 1.177. Thus, the fifth key safety principle of RG 1.177 is satisfied.

3.2 Addition of Surveillance Frequency Control Program to Administrative Controls The licensee has included the SFCP and specific requirements into the Administrative Controls, TS Section 5.5.16, Surveillance Frequency Control Program, as follows:

This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the TSs are performed at intervals sufficient to assure that the associated limiting conditions for operation are met.

a. The Surveillance Frequency Control Program shall contain a list of Frequencies of the Surveillance Requirements for which the Frequency is controlled by the program.

b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.

c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.

The proposed program is consistent with the model application of TSTF-425, and is therefore acceptable.

The NRC staff has reviewed the licensee's proposed relocation of some surveillance frequencies to a licensee controlled document, and controlling changes to surveillance frequencies in accordance with a new program, the SFCP, identified in the administrative controls of TS. The SFCP and TS Section 5.5.16 references NEI 04-10, which provides a risk informed methodology using plant-specific risk insights and performance data to revise surveillance frequencies within the SFCP. This methodology supports relocating surveillance frequencies from TS to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10 which is specified in the Administrative Controls of the TSs.

14 The proposed licensee adoption of TSTF-425 and risk-informed methodology of NEI 04-10 as referenced in the Administrative Controls of TS, satisfies the key principles of risk-informed decision making applied to changes to TS as delineated in RG 1.177 and RG 1.174, in that:

The proposed change meets current regulations;

The proposed change is consistent with defense-in-depth philosophy;

The proposed change maintains sufficient safety margins;

Increases in risk resulting from the proposed change are small and consistent with the Commission's Safety Goal Policy Statement; and

The impact of the proposed change is monitored with performance measurement strategies.

Section to 50.36(c)(3) to 10 CFR states "Technical specifications will include items in the following categories: Surveillance Requirements. Surveillance Requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." The NRC staff finds that with the proposed relocation of surveillance frequencies to an owner-controlled document and administratively controlled in accordance with the TS SFCP, Exelon continues to meet the regulatory requirement of 10 CFR 50.36, and, specifically, 10 CFR 50.36(c)(3), surveillance requirements.

3.3 Technical Summary The NRC staff has reviewed the licensee's proposed relocation of some surveillance frequencies to a licensee-controlled document, and controlling changes to surveillance frequencies in accordance with a new program, the SFCP, identified in the administrative controls of TS. The SFCP and TS Section 5.5.16 references NEI 04-10, which provides a risk informed methodology using plant-specific risk inSights and performance data to revise surveillance frequencies within the SFCP. This methodology supports relocating surveillance frequencies from a TS to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10 which is specified in the Administrative Controls of the TS.

The proposed licensee adoption of TSTF-425 and risk-informed methodology of NEI 04-10 as referenced in the Administrative Controls of the TS, satisfies the key principles of risk-informed decision making applied to changes to TS as delineated in RG 1.177 and RG 1.174, in that:

The proposed change meets current regulations;

The proposed change is consistent with defense-in-depth philosophy;

The proposed change maintains sufficient safety margins;

15

Increases in risk resulting from the proposed change are small and consistent with the Commission's safety goal policy statement; and

The impact of the proposed change is monitored with performance measurement strategies.

4.0 STATE CONSULTAllON 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 amendments change surveillance requirements of the facilities components located within the restricted area as defined in 10 CFR Part 20 and surveillance requirements. The NRC staff has determined that the amendments involve no significant increase in the amounts and no significant change in the types of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission has previously issued a proposed finding that the amendments involve no significant hazards consideration, and there has been no public comment on such finding (75 FR 20636; April 20, 2010). Accordingly, the amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.

6.0 CONCLUSION

The NRC has concluded, on the basis of 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 NRC'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: Andrew Howe, NRR Date of issuance: February 24, 2011

February 24, 2011 Mr. Michael J. Pacilio President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville,IL 60555 SUB..IECT: LASALLE COUNTY STATION, UNITS 1 AND 2 -ISSUANCE OF AMENDMENTS REGARDING RISK-INFORMED JUSTIFICATION FOR THE RELOCATION OF SPECIFIC SURVEILLANCE FREQUENCY REQUIREMENTS TO A LICENSEE-CONTROLLED PROGRAM (TAC NOS. ME3363 AND ME3364)

Dear Mr. Pacilio:

The U.S. Nuclear Regulatory Commission (the Commission) has issued the enclosed Amendment No. 200 to Facility Operating License No. NPF-11 and Amendment No. 187 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 February 15,2010 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML100480009), as supplemented by letters dated April 26, June 23, and August 3,2010 (ADAMS Accession Nos. ML101160374, ML101750102, and ML110390169, respectively).

The requested change is the adoption of Nuclear Regulatory Commission-approved Technical Specification Task Force (TSTF-425), Revision 3, "Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative 5b." When implemented, TSTF-425 relocates most periodic frequencies of Technical Specification (TS) surveillances to a licensee-controlled program, the Surveillance Frequency Control Program, and provides requirements for the new program in the Administrative Controls section of the TS.

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!

Eva Brown, Senior 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. 200 to NPF-11

2. Amendment No. 187 to NPF-18

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

PUBLIC LPL3-2 RtF RidsNrrPMLaSalie Resource RidsOgcRp Resource RidsNrrDirsltsb Resource RidsRgn3MailCenter Resource RidsNrrDorlLpl3-2 Resource RidsNrrLASRohrer Resource RidsNrrDorlDpr Resource RidsAcrsAcnw MailCTR Resource Amendment Accession No. ML110200143 *b memo dated 7/26/10 LPL3-2/PM LPL3-2/LA APLAlBC OGC LPL3-21BC EBrown THarris/SRohrer w/comment DHarrison

DRoth NLO RCarlson 218/11 1/28/11 7/26/10 214/11 2124/11

v t e Letter Sequence Approval
TAC:ME3363, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed) TAC:ME3364, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed)
Initiation Request, Request, Request, Request Acceptance Administration Questions 26 May 2010 21 July 2010 Answers Results Approval, Approval Other:
MONTHYEAR2010-06-23 [Table View]

ML110200143

Text

Dear Mr. Pacilio:

Enclosures:

Attachment:

Attachment:

1.0 INTRODUCTION

2.0 REGULATORY EVALUATION

3.0 TECHNICAL EVALUATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 CONCLUSION

Dear Mr. Pacilio:

Enclosures:

Navigation menu

Search