Text

Issuance of Amendments Regarding Relocation of Specific Surveillance Frequency Requirements
	ML11167A226
Person / Time
Site:	Farley
Issue date:	07/18/2011
From:	Martin R; Plant Licensing Branch II
To:	Ajluni M; Southern Nuclear Operating Co
	Martin R, NRR/DORL/2-1, 415-1493
References
	TAC ME5055, TAC ME5056
	Download: ML11167A226 (141)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 July 18, 2011 Mr. M. J. Ajluni Nuclear Licensing Director Southern Nuclear Operating Company, Inc.

40 Inverness Center Parkway Post Office Box 1295, Bin - 038 Birmingham, AL 35201-1295

SUBJECT:

JOSEPH M. FARLEY NUCLEAR PLANT, UNITS 1 AND 2, ISSUANCE OF AMENDMENTS REGARDING RELOCATION OF SPECIFIC SURVEILLANCE FREQUENCY REQUIREMENTS (TAC NOS. ME5055 AND ME5056)

Dear Mr. Ajluni:

The Nuclear Regulatory Commission (NRC) has issued the enclosed Amendment No. 185 to Renewed Facility Operating License No. NPF-2 and Amendment No. 180 to Renewed Facility Operating License No. NPF-8 for the Joseph M. Farley Nuclear Plant, Units 1 and 2, respectively.

The amendments consists of changes to the Technical Specifications (TSs) in response to your application dated October 29,2010, as supplemented on February 21,2011.

The amendments revise the TSs to reflect the adoption of the NRC-approved TS Task Force (TSTF) traveler TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control- RITSTF [Risk-Informed TSTF] Initiative 5b." Most periodiC frequencies of TS surveillances are accordingly relocated to a licensee-controlled Surveillance Frequency Control Program (SFCP), and requirements for the new program are provided in the TS Administrative Controls section.

M. Ajluni -2 A copy of the related Safety Evaluation is also enclosed. A Notice of Issuance will be included in the Commission's biweekly Federal Register notice.

Sincerely,

(] k-m ~r-v' f~bert E. Martin, Senior Project Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-348 and 50-364

Enclosures:

1. Amendment No. 185 to NPF-2

2. Amendment No. 180 to NPF-8

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

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 SOUTHERN NUCLEAR OPERATING COMPANY, INC.

ALABAMA POWER COMPANY DOCKET NO. 50-348 JOSEPH M. FARLEY NUCLEAR PLANT, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 185 Renewed License No. NPF-2

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

A. The application for amendment by Southern Nuclear Operating Company, Inc.

(Southern Nuclear), dated October 29, 2010, as supplemented on February 21, 2011, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this license 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.

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

(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 185 , are hereby incorporated in the renewed license.

Southem Nuclear shall operate the facility in accordance with the Technical Specifications.

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

FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance: July 18, 2011

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SOUTHERN NUCLEAR OPERATING COMPANY, INC.

ALABAMA POWER COMPANY DOCKET NO. 50-364 JOSEPH M. FARLEY NUCLEAR PLANT, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 180 Renewed License No. NPF-8

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

A. The application for amendment by Southern Nuclear Operating Company, Inc.

(Southern Nuclear), dated October 29, 2010, as supplemented on February 21, 2011, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this license amendment will not be inimical to the common defense and security or to the health and safety of the public; and The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

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2. Accordingly, the license is amended by changes to the Technical Specifications, as indicated in the attachment to this license amendment; and paragraph 2.C.(2) of Renewed Facility Operating license No. NPF-8 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 180 , are hereby incorporated in the renewed license.

Southern Nuclear shall operate the facility in accordance with the Technical Specifications.

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

FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant licensing Branch 11-1 Division of Operating Reactor licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance: July 18, 2011

ATTACHMENT TO LICENSE AMENDMENT NO. 185 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-2 DOCKET NO. 50-348 AND ATTACHMENT TO LICENSE AMENDMENT NO. 180 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-8 DOCKET NO. 50-364 Replace the following pages of the Renewed Facility Operating Licenses and the Appendix A Technical Specifications (TSs) with the enclosed pages. The revised pages are identified by amendment number and contain vertical lines indicating the areas of change.

Remove Pages Insert Pages License License License No. NPF-2, page 4 License No. NPF-2, page 4 License No. NPF-8, page 3 License No. NPF-8, page 3 TSs TSs 1.1-6 1.1-6 3.1.1-1 3.1.1-1 3.1.2-2 3.1.2-2 3.1.4-3 3.1.4-3 3.1.5-2 3.1.5-2 3.1.6-3 3.1.6-3 3.1.8-2 3.1.8-2 3.2.1-3 3.2.1-3 3.2.1-5 3.2.1-5 3.2.2-3 3.2.2-3 3.2.3-1 3.2.3-1 3.2.4-4 3.2.4-4 3.3.1-9 3.3.1-9 3.3.1-10 3.3.1-10 3.3.1-11 3.3.1-11 3.3.1-12 3.3.1-12 3.3.1-13 3.3.1-13 3.3.2-6 3.3.2-6 3.3.2-7 3.3.2-7 3.3.2-8 3.3.2-8 3.3.2-9 3.3.2-9 3.3.2-10 3.3.2-10 3.3.2-11 3.3.2-11 3.3.2-12 3.3.2-12 3.3.3-2 3.3.3-2

- 2 Remove Pages Insert Pages TSs TSs 3.3.4-2 3.3.4-2 3.3.5-2 3.3.5-2 3.3.5-3 3.3.5-3 3.3.6-3 3.3.6-3 3.3.6-4 3.3.6-4 3.3.6-5 3.3.6-5 3.3.7-2 3.3.7-2 3.3.7-3 3.3.7-3 3.3.8-3 3.3.8-3 3.3.8-4 3.3.8-4 3.3.8-5 3.3.8-5 3.4.1-2 3.4.1-2 3.4.3-2 3.4.3-2 3.4.4-1 3.4.4-1 3.4.5-2 3.4.5-2 3.4.6-2 3.4.6-2 3.4.7-2 3.4.7-2 3.4.7-3 3.4.7-3 3.4.8-2 3.4.8-2 3.4.9-2 3.4.9-2 3.4.11-3 3.4.11-3 3.4.11-4 3.4.11-4 3.4.12-3 3.4.12-3 3.4.12-4 3.4.12-4 3.4.13-2 3.4.13-2 3.4.14-3 3.4.14-3 3.4.14-4 3.4.14-4 3.4.15-3 3.4.15-3 3.4.16-2 3.4.16-2 3.4.16-3 3.4.16-3 3.5.1-2 3.5.1-2 3.5.2-2 3.5.2-2 3.5.2-3 3.5.2-3 3.5.3-3 3.5.3-3 3.5.4-2 3.5.4-2 3.5.5-2 3.5.5-2 3.5.6-1 3.5.6-1 3.6.2-5 3.6.2-5 3.6.3-5 3.6.3-5 3.6.3-6 3.6.3-6 3.6.4-1 3.6.4-1 3.6.5-1 3.6.5-1 3.6.6-2 3.6.6-2 3.6.6-3 3.6.6-3 3.6.8-2 3.6.8-2 3.6.9-1 3.6.9-1

- 3 Remove Pages Insert Pages TSs TSs 3.7.4-2 3.7.4-2 3.7.5-2 3.7.5-2 3.7.5-3 3.7.5-3 3.7.6-1 3.7.6-1 3.7.7-2 3.7.7-2 3.7.8-2 3.7.8-2 3.7.9-1 3.7.9-1 3.7.10-3 3.7.10-3 3.7.11-2 3.7.11-2 3.7.12-2 3.7.12-2 3.7.13-1 3.7.13-1 3.7.14-1 3.7.14-1 3.7.16-1 3.7.16-1 3.7.17-2 3.7.17-2 3.7.19-2 3.7.19-2 3.8.1-6 3.8.1-6 3.8.1-7 3.8.1-7 3.8.1-8 3.8.1-8 3.8.1-9 3.8.1-9 3.8.1-10 3.8.1-10 3.8.1-11 3.8.1-11 3.8.1-12 3.8.1-12 3.8.1-13 3.8.1-13 3.8.1-14 3.8.1-14 3.8.3-2 3.8.3-2 3.8.3-3 3.8.3-3 3.8.4-2 3.8.4-2 3.8.4-3 3.8.4-3 3.8.4-4 3.8.4-4 3.8.6-2 3.8.6-2 3.8.6-3 3.8.6-3 3.8.7-2 3.8.7-2 3.8.8-2 3.8.8-2 3.8.9-2 3.8.9-2 3.8.10-2 3.8.10-2 3.9.1-1 3.9.1-1 3.9.2-2 3.9.2-2 3.9.3-2 3.9.3-2 3.9.4-2 3.9.4-2 3.9.5-3 3.9.5-3 3.9.6-1 3.9.6-1 5.5-15 5.5-15 5.5-16 5.5-16

-4 (2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 185 , are hereby incorporated in the renewed license.

Southern Nuclear shall operate the facility in accordance with the Technical Specifications.

(3) Additional Conditions The matters specified in the following conditions shall be completed to the satisfaction of the Commission within the stated time periods following the issuance of the renewed license or within the operational restrictions indicated. The removal of these conditions shall be made by an amendment to the renewed license supported by a favorable evaluation by the Commission.

a. Southern Nuclear shall not operate the reactor in Operational Modes 1 and 2 with less than three reactor coolant pumps in operation.

b. Deleted per Amendment 13

c. Deleted per Amendment 2

d. Deleted per Amendment 2

e. Deleted per Amendment 152 Deleted per Amendment 2

f. Deleted per Amendment 158

g. Southern Nuclear shall maintain a secondary water chemistry monitoring program to inhibit steam generator tube degradation.

This program shall include:

1) Identification of a sampling schedule for the critical parameters and control points for these parameters;

2) Identification of the procedures used to quantify parameters that are critical to control points;

3) Identification of process sampling points;

4) A procedure for the recording and management of data; Farley - Unit 1 Renewed License No. NPF-2 Amendment No. 185

- 3 (2) Alabama Power Company, pursuant to Section 103 of the Act and 10 CFR Part 50, "Licensing of Production and Utilization Facilities," to possess but not operate the facility at the designated location in Houston County, Alabama in accordance with the procedures and limitations set forth in this renewed license.

(3) Southern Nuclear, pursuant to the Act and 10 CFR Part 70, to receive, possess and use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Final Safety Analysis Report, as supplemented and amended; (4) Southern Nuclear, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess, and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (5) Southern Nuclear, 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 (6) Southern Nuclear, 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 the facility.

C. This renewed 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 Southern Nuclear is authorized to operate the facility at reactor core power levels not in excess of 2775 megawatts thermal.

(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 100, are hereby incorporated in the renewed license.

Southern Nuclear shall operate the facility in accordance with the Technical Specifications.

Farley - Unit 2 Renewed License No. NPF-8 Amendment No. 180

Definitions 1.1 1.1 Definitions SHUTDOWN MARGIN (80M)

(continued) b. In MODES 1 and 2, the fuel and moderator temperatures are changed to the hot zero power temperatures.

SLAVE AELAYTE8T A SLAVE RELAY TEST shall consist of energizing each slave relay and verifying the OPERABILITY of each slave relay. The SLAVE RELAY TEST shall include, as a minimum, a continuity check of associated testable actuation devices.

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

TRIP ACTUATING DEVICE A T ADOT shall consist of operating the trip actuating device OPERATIONAL TEST and verifying the OPERABILITY of required alarm, interlock, (TADOT) and trip functions. The T ADOT sh911 include adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy.

Farley Units 1 and 2 1.1-6 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)

LCO 3.1.1 SDM shall be within the limits provided in the COLR.

APPLICABILITY: MODE 2 with *keff < 1.0, MODES 3,4, and 5.

ACTIONS

. CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore Immediately SDM to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. In accordance with the Surveillance Frequency Control Program Farley Units 1 & 2 3.1.1-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 -----NOTE The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel bumup of 60 effective fun power days (EFPD) after each fuel loading.

Verify measured core reactivity is within +/- 1% 6.kIk of Once, prior to predicted values. entering MODE 1 after each refueling

-NOTE Only required after 60 EFPD In accordance with the Surveillance Frequency Control Program, Farley Units 1 and 2 , 3.1.2-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Rod Group Alignment Limits

. 3.1.4 ACTIONS CONDITION REQUIRED ACTION . COMPLETION TIME D. More than one rod not D.1.1 Verify SDM to be within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within alignment limit. . the limits provided in the COLR.

D.1.2 Initiate boration to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore required SDM to within limit.

AND D.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILlANCE REQLIIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment limit. In accordance with the Surveillance Frequency Control

~rogram SR 3.1.4.2 Verify rod freedom of movement (trippability) by In accordance with moving each rod not fully inserted in the core the Surveillance

~ 10 steps in either direction. . Frequency Control Program SR 3.1.4.3 Verify rod drop time of each rod, from the fully Prior to reactor withdrawn position, is:$; 2.7 seconds from the criticality after beginning of decay of stationary gripper coil voltage. each removal of to dashpot entry. with: the reactor head

b. All reactor coolant pumps operating.

Far1ey Units 1 and 2 3.1.4-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY*

SR 3.1.5.1 Verify each shutdown bank is within the limits In accordance with specified in the COLR. the Surveillance Frequency Control Program Farley U~its 1 and 2 3.1.5--2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.2 Verify each control bank insertion is within the limits In accordance with specified in the COLR. the Surveillance Frequency Control Program SR 3.1.6.3 Verify sequence and overlap limits specified in the In accordance with COLR are met for control banks not fully withdrawn the Surveillance from the core. Frequency Control Program Farley Units 1 and 2 3.1.6-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

PHYSICS TESTS Exceptions-MODE 2 3.1.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. RCS lowest loop average C.1 Restore RCS lowest 15 minutes temperature not within loop average limit. temperature to within limit.

I D. Required ,Action and 0.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Perform a CHANNEL OPERATION TEST on Prior to initiation of power range and intermediate range channels per PHYSICS TESTS SR 3.3.1.7, SR 3.3.1.8, and Table 3.3.1-1.

SR 3.1.8.2 Verify the RCS lowest loop average temperature is In accordance with the

~ 531°F. Surveillance

. Frequency Control

Program SR 3.1.8.3 Verify THERMAL POWER is s 5% RTP. In accordance with the Surveillance Frequency Control Program SR 3.1.8.4 Verify SDM to be within the limits provided in the In accordance with the COLR. Surveillance Frequency Control Program Farley Units 1 and 2 3.1.8-2 Amendment No. 185(Unit 1}

Amendment No. 180(Unit 2}

Fo(Z) 3.2.1 SURVEILLANCE REQUIREMENTS NOTE------

During power escalation at the beginning of each cycle, THERMAl.. POWER maybe increased until an equilibrium power level has been achieved, at which a power distribution map is obtained SURVEILlANCE FREQUENCY SR 3.2.1.1 Verify Fa(Z) is within steady state limit. Once after each '

refueling prior to THERMAl.. POWER exceeding 75% RTP Once after achieving equilibrium conditions after exceeding. by

~ 20% RTP, the THERMAl.. POWER at which Fa(Z) was last verified In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.2.1-3 Amendment No. 185 {Unit 1}

Amendment No. 180 (Unit 2)

FQ(Z}

3.2.1 SURVEILLANCE REQUIREMENTS SURVEILlANCE FREQUENCY SR 3.2.1.2 (continued) Once after achieving equilibrium conditions after exceeding, by

~ 20% RTP, the THERMAL POWER at which Fa(Z) was last verified In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.2.1-5 . Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREqUENCY SR '3.2.2.1 Verify ~ is within limits specified in the COLR. Once after each refueling prior to THERMAL.

POWER exceeding 75%RTP In accordance with the Surveillance Frequency Control Program '

Farley Units 1 and 2 3.2.2-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD)

LCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified in the COLR.

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

The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits.

APPLICABILITY: MODE 1 with THERMAL POWER;;:: 50% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.1 Reduce THERMAL 30 minutes POWER to < 50% RTP.

SURVEILLANCE REQUIREMENTS SURVEIlLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore In accordance with channel. the Surveillance Frequency Control Program Farley Units 1 and 2 3.2.3-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 *---NOTES

1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER s 75% RTP, the remaining three power range channels can be used for calculating QPTR.

2. SR 3.2.4.2 may be performed in lieu of this SUrveillance.

Verify QPTR is within limit by calculation. In accordance with the SUrveillance Frequency Control Program SR 3.2.4.2 --------- ---~OTE~--------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after input from one or more Power Range Neutron Flux .

channels are inoperable with THERMAL POWER

> 75% RTP.

Confirm that the normalized symmetric power In accordance with distribution is consistent with QPTR. the Surveillance Frequency Control Program Farley Units 1 and 2 3.2.4-4 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS NOTE--------------

Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.

SURVEILLANCE FREQUENCY SR 3.3.1.1 -----*------NOTE---------

Not required to be performed for sou rce range instrumentation until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is < P-6.

Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 ---*-----NOTES---*----

1. Adjust NIS channel if calorimetric calculated power exceeds NIS indicated power by more than +2% RTP.

2. Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is ~ 15% RTP.

Compare results of calorimetric heat balance In accordanCe with calculation to Nuclear Instrumentation System (NIS) the Surveillance channel output. Frequency Control Program SR 3.3.1.3 --------------INOTES~-----------

1. Adjust NIS channel if absolute difference Is

~3%.

2. Not required to be performed until 7 days after THERMAL POWER is ~ 50% RTP.

3. Performance of SR 3.3.1.9 satisfies this SR.

Compare results of the incore detector In accordance with measurements to NIS AFD. the Surveillance Frequency Control Program Far1ey Units 1 and 2 3.3.1-9 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RTS Instrumentation 3.3.1 SURVEI LLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.4 ------NOTE-------

This Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.6 Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.7 -----NOTE-------------

Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3.

Perform COT. In accordance with the' Surveillance Frequency Control Program Farley Units 1 and 2 3.3.1-10 Amendment No. 185 (Unit'1)

Amendment No. 180 (Unit 2)

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILlANCE FREQUENCY SR 3.3.1.8 -------------!NOTE--~---------

This Surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions.

Perform COT. --NOTE-Only required when not performed in accordance with the Surveillance Frequency Control Program Prior to reactor startup Four hours after reducing power below P-6 for source range instrumentation Twelve hours after reducing power below P-10 for power range and intermediate range instrumentation In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.1-11 Amendment No. 185 (Unit 1)

Amendment No.' 180 (Unit 2)

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.9 --------------NOTES-------------

1. Neutron detectors are excluded from the calibration.

2. Not required to be performed until 7 days after THERMAL POWER is ~ 50% RTP.

Calibrate excore channels to agree with incore In accordance with detector measurements. the SUnieillance Frequency Control Program SR 3.3.1.10 --------------NOTES------------

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. This Surveillance shall indude verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. In acCordance with the Surveillance Frequency Control Program SR 3:3.1.11 Perform COT. In accordance with the Surveillance Fr:equency Control Progr:a m AMQ

--NOTE-Only required when not performed in accordance with the Surveillance Frequency Control Program.

(continued)

FaneyUnits 1 and 2 3.3.1-12 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.11 (continued) Prior to reactor startup SR 3.3.1.12 ---------------NOTE-------------*--

Verification of setpoint Is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.13 ------------.-.NOTE----------------

Verification of setpoint is not required.

Perform TADOT. Prior to exceeding the P-9 interlock whenever the unit has been in MODE 3, if not performed within the previous 31 days SR 3.3.1.14 --------------NOTE------------

Neutron detectors are excluded from response time testing_

Verify RTS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.1-13 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

ESFAS Instrumentation 3.3.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME L (continued) L2 ----NOTE--

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for Surveillance testing, provided the other train is OPERABLE.

Restore train to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

OR \

L.3.1 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months AND L3.2 Be in MODE 5 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months SURVEILLANCE REQUIREMENTS

INOTE--------------*---------

Refer to trable 3.3.2-1 to determine which SRs apply for each ESFAS Function.

SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR3.3.2.3 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.2-6 Amendment No. 185 (Unit 1)

'Amendment No. 180 (Unit 2)

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.4 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.5 Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.6 NOTE Verification of setpoint not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.7 NOTE This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.2.8 Perform SLAVE RELAY TEST In accordance with the Surveillance Frequency Control Program SR 3.3.2.9 NOTE Not required to be performed for the turbine driven AFW pump untR 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SG pressure is

1005 psig.

Verify ESFAS RESPONSE TIMES are within limit. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.2-7 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS SR 3.3.2.10 --------------NOTE-----, -------- ---NOTE-Verification of setpointnot required. Only required when not performed within previous 92 days.

Perform TADOT. Prior to reactor startup Farley Units 1 and 2 3.3.2-8 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 4)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MQOESOR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDmONS REQUIREMENTS VAlUE SETPOINT

1. Safety Injedlon

a. Manual Initiation 1,2,3,4 2 B SR 3,3.2.6 NA NA

b. Aulomallc 1.2,3.4 2lrains C SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.8 Relays

c. Containmenl 1.2,3 3 D SR 3.3.2.1 S4.5ps1g S4.0pslg PressmI- SR 3.3.2.4 High 1 SR 3.3.2.7 SR 3.3.2.9

d. Pressuri~ 1.2.3<a) 3 0 SR 3.3.2.t 2: 1847 psig 2: 1850 pslg PressUR! -Low SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9

e. Steam Une Presswe (1) Low 1.2.3(b) 1 persteam D SR 3.3.2.1 ;;: S7S(c) psig ~ 585(C) psig line SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 (2) High 1.2.3 3 per steam D SR 3.3.2.1 S 112psig S 100 psig Differential line SR 3,3.2.4.

PresSUR! SR 3.3.2.7 Between SR 3.3.2.9 Steam lines (a) Above the P-l1 (Pressurizer Pressure) inleriock.

(b) Abowlhe P-12 (T8\III- Low Low) inleflock.

(e) TlIne conslants used In !he leadllag conlroller are I * ., 50 seconds and t2 S 5 seconds.

Farley Units 1 and 2 3.3.2-9 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

I

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 4)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT

2. Containment Spray

a. Manual Initiation 1,2.3,4 2 B SR 3.3.2.6 NA NA

b. Automatic Actuation 1,2,3,4 2 trains C SR 3.3.2.2 NA NA Logic and Actuation SR 3.3.2.3 Relays SR 3.3.2.8

e. Containment 1.2,3 4 E SR 33.2.1 S28.3psig s27 psig Pressure SR 3.3.2.4 High 3 SR 3.3.2.7 SR 3.3.2.9

3. Conlainmenllsolation

a. Phase A lsoIalion (1) Manual 1.2,3,4 2 B SR 3.3.2.6 NA NA Inltialion (2) Automatic 1.2.3,4 2 trains C SR 3.3.2.2 NA NA ActuatiOn Logic SR 3.3.2.3 and Actualion SR 3.3.2.8 Relays (3) Safety Injection Refer to Function 1 (Safety Injection) for all initiatiOn functions and requirements.

b. Phase B Isolation (1) Manual 1,2,3,4 2 B SR 3.3.2.6 NA NA Initiation (2) Automatic 1,2,3.4 2lralns C SR. 3.3.22 NA NA Aduation Logic: SR 33.2.3 and Aduation SR 3.3.2.8 Relays (3) Containment 1.2,3 4 E SR 3.3.2.1 s28.3psig S27psig Pressure SR 3.3.2.4 H'l!)h-3 SR 3.3.2.7 SR 3.3.2.9 Farley Units 1 and 2 3.3.2-10 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

I

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 4)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MOOESOR OTHER SPECIFIED REQUIRED SURVEilLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT

4. Swam Une Isolation 1 persteam

a. Manuallniliation 1,21d ).3(d) line F SR 3.3.2.6 NA NA

b. Automatic 1,2(d).3<d) 2 trains G SR 3.3.2.2 NA NA Actualion logic SR 3.3.2.3 and Actuation SR 3.3.2.8 Relays

c. Containment 1,2(d). 3(d) 3 0 SR 3.3.2.1 :s: 17.5 psig :s: 16.2 pslg Pressure* High 2 SR 3.3.2.4 SR 3.3.2.1 SR 3.3.2.9

d. SleamUne 1.21d).3(b)(d) 1 persleam D SR 3.3.2.1 ~ 51stc ) pslg ~585(c) psig Pressure Low line SR 3.3.2.4 SR 3.3.2.1 SR 3.3.2.9

e. High Steam Flow 1.2(d).3(d) 2persleam 0 SR 3.3.2.1 (e) (I) inTwoSleam line SR 3.3.2.4 Lines SR 3.3.2.1 Coincident with 1.:z(d).3(d) 1 per loop 0 SR 3.3.2.1 ~542.6*F <i!543'F TlW9 -low Low SR 3.3.2.4 SR 3.3.2.1 (b) Above the P-12 (Tavg' low low) interlock.

(e) TIme constants used in the leadllag controller are II <! 50 seconds and 12 :s: 5 seoonds.

(d) Except when one MSlV is closed in each steam line.

(e) less than 01" equal 10 a function defined asl!.P corresponding to 40.3% full steam flow below 20% load, l!.P increasing lineady from 40.3% fuU Sleam flow al 20% toad 10 110.3% fuR steam flow at 100% load.

(I) less tl1an 01" equal 10 a function defined as l!.P corresponding 10 40% full steam flow between 0% and 20% load and tIIen II l!.P Increasing linearly from 40% steam flow at 20% load to 110% fuM steam flow at 100% load.

Farley Units 1 and 2 3.3.2-11 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

I

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 4)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MOOESOR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDrTlONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT

5. Turbine Trip and Feedwater Isolation

. a. Automatic Actuation 1.2 2 trains H SR 3.3.2.2 NA NA Logic and Actuation SR 3.3.2.3 Relays SR 3.3.2.8

b. SG Waler Level 1,2 3perSG SR 3.3.2.1 s82.4% s82%

High High (P*1") SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9

c. Sarely Injection Rerer to FUfICIion 1 (Safety I~) for all initiation functions and requirements.

6. AUJlilary Feedwater 1.2.3 2lrains G SR 3.3.2.2 NA NA

a. Automatic Actuation SR 3.3.2.3 Logic and Actuation SR 3.3.2.8 Relays

b. SG Water Level* 1,2.3 3perSG o SR 3.3.2.1 ~27.6%

low low SR 3.3.2.4 SR 3.3.2.1 SR 3.3.2.9(v1

c. Safety Injection Refer to Function 1 (Safely Injedion) for aft initiation fundions and requirements.

d. Undervoltage 1.2 3 SR 3.3.2.5 Reaclor Coolant SR 3.3.2.7 Pump SR 3.3.2.9

e. Trip of all Main 2 per pump J SR 3.3.2.10 NA fIlA Feedwater Pumps

7. ESFAS Intenocks 1,2,3 21ra1ns L SR 3.3.2.2 NA

a. Automatic Actuation Logic and Actuation SR 3.3.2.3 Relays SR 3.3.2.8

b. Reactor Trip. P-4 1.2.3 1 per train, 2 C SR 3.3.2.6 NA fIlA trains 1,2.3 3 K SR 3.:12.4 S 2003 psig S 2000 psig SR 3.3.2.7

d. Tavg*LowLow.P.12 1,2.3 1 per loop K SR 3.3.2.4 ?: 542.6"F l1:543*F (OecteaSing)

SR 3.:12.7 s 545.4"F s 545"F (Increasing)

(g) Applicable i) MOAFW pumps only.

FaJley Units 1 and 2 3.3.2-12 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

PAM Instrumentation 3.3.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action an~ D.l Enter the Condition Immediately associated Completion referenced in Time of Condition C Table 3.3.3-1 for the not met. channel.

E. As required by Required E.1 Bein MODE 3. 6'hours Action D.l and referenced in AND Table 3.3.3-1.

E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. As required by Required F.l Initiate action in Immediately Action 0.1 and accordance with referenced in Specification 5.6.B.

Table 3.3.3-1.

SURVEILlANCE REQUIREMENTS

~NOTE-------~,--------*------------

SR 3.3.3.1 and SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized. the Surveillance Frequency Control Program SR 3.3.3.2 Perform CHANNEL CAUBRATION. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.3-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Remote Shutdown System 3.3.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Submit a report to the 14 days associated Completion NRC outlining the Time not met for Source preplanned alternate Range Neutron Flux method of ensuring the function. reactor remains shutdown in the event of a control room evacuation. the cause of the inoperability.

and the plans and schedule for restoring the Source Range Neutron Aux monitor to .

OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required In accordance with monitoring instrumentation channel that is normally' the Surveillance energized. Frequency Control Program SR 3.3.4.2 Verify each required control circuit and transfer In accordance with switch is capable of performing the intended function. the Surveillance Frequency Control Program SR 3.3.4.3 ---------------NOTE----*---------*-

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for each required In accordance with monitoring instrumentation channel. the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.4-2 Amendment No. -185 (Unit 1)

Amendment No. 180 (Unit 2)

LOP DG Start Instrumentation 3.3.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. ---NOTE-- 0.1 Verify voltage on Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Only applicable to associated bus is ;::: 3850 Function 3 . volts.

One Alarm Function channel inoperable on one or more trains.

E. Required Action and E.1 Restore bus voltage to ;::: 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion 3850 volts.

Time of Condition D not met.

F. Required Action and F.1 Bein MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition E AND not met.

F.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 ------------NOTES~-------------

1. TADOT shall exclude actuation of the final trip actuation relay for LOP Functions 1 and 2.

2. Setpoint verification not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.5-2 . Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

LOP DG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.2 ,------------NOTE------------

CHANNEL CALIBRATION shall exclude actuation of the final trip actuation relay for Functions 1 and 2.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3 *----Notel-*- - - - - -

Response time testing shall include actuation of the final trip actuation relay.

Verify ESF RESPONSE TIME within limit. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.5-3 Amendment No, 185 (Unit 1)

Amendment No, 180 (Unit 2)

Containment Purge and Exhaust Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS

NOTE .

Refer to Table 3.3.6*1 to determine which SRs apply for each Containment Purge and Exhaust Isolation Function.

SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2 Perform ACTUATION LOGIC TEST. In accordance with the SUrveillance Frequency Control Program SR 3.3.6.3 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.6.5 Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.6 NOTE*

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.6-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Containment Purge and Exhaust Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS SR 3.3.6.7 Perfonn CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.8 Verify ESF RESPONSE TIME within limit. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.6-4 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit2)

Containment Purge and Exhaust Isolation Instrumentation 3.3.6 Table 3.3.6-1 (page 1 of 1)

Containment Purge and Exhaust Isolation Instrumentation FUNCTION APPliCABLE REQUIRED SURVEILlANCE TRIP SETPOINT MODES OR OTHER CHANNELS REQUIREMENTS SPECIFIED CONDITIONS

1. ManuallnltJalion 1.2,3.4. (a), (b) 2 SR 3.3,6.6 ItA

2. AutomatJc Actuation Logic 1.2,3.4 2 trains SR 3.3.6.2 NA and Actuation Relays SR 3.3.6.3 SR 3.3.6.5 SR 3.3.6.8

3. Containment Radiation 1.2,3,4 1 SR3.3.6.1 2 S 2.27 X 10- pCilcc Gaseous (R-24A. 8) (a). (b) 2 SR3.3.6.4 (e)(d)

SR3.l.6.7 S 4.54 X 10'3 pCllcc

<<:)(e) s 2.21 X 10-3 pCilcc (e){t)

4. Containment Isolation Refer 10 LCO 3.3.2. "ESFAS Insfl\lmenlalion,* Function 3.s., for aU inltialion runclions and Phase A requirements.

(a) Dlmg COREALTERATJONS, (b) During movement of irradiated ruel assemblies within containment.

(e) Above background with noftow.

(d) With mini-putge in operation.

(e) With slow speed main pI.Ilg6 in operation.

(f) With fast speed main purge In operation.

Farley Units 1 and 2 3.3.6-5 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

CREFS Actuation Instrumentation 3.3.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Place both CREFS trains Immediately in emergency recirculation mode.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A AND or B not met in MODE 1, 2,3,or4. C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and 0.1 Suspend CORE Immediately associated Completion ALTERATIONS.

Time for Condition A or B not met during AND movement of irradiated fuel assemblies or 0.2 Suspend movement of Immediately during CORE irradiated fuel assemblies.

ALTERATIONS.

SlJRVEILLANCE REQUIREMENTS

*-----NOTE---------------------------

Refer to Table 3.3.7-1 to detennine which SRs apply for each CREFS Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.2 Perform COT. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

CREFS Actuation Instrumentation 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.3 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.7.4 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR '3.3.7.5 Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.7.6 -------------NOTE--------------*-

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.7.7 Perform CHANNEL CALIBRATION. In accordance with the SUrveillance Frequency Control Program Farley Units 1 and 2 3.3.7-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

PRF Actuation Instrumentation 3.3.8 SURVEILLANCE REQUIREMENTS

NOTE-Refer to Table 3.3.8-1 to determine which SRs apply for each PRF Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.8.2 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.8.3 Perform ACTUATION LOGIC TEST. In accordance with the SUrveillance Frequency Control Program SR 3.3.8.4 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.5 Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.6 NOTE Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.8-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

PRF Actuation Instrumentation 3.3.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.7 Perform CHANNEL CALIBRATION. In acrordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.8-4 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

PRF Actuation Instrumentation 3.3.8 Table 3.3.8-1 (page 1 of 1)

PRF Actuation Instrumentation I

FUNCTION APPLICABLE REQUIRED SURVEILLANCE TRIP SETPOINT I MODes OR OTHER CHANNELS REQUIREMENTS SPECIFIED CONDITIONS

1. Manual Initiation 1,2.3.4. (a) 2 trains SR 3.3.8.6 NA

2. Automatic Actuation Logic 1,2,3.4 2 trains SR 3.3.8.3 NA and Actuation Relays SR 3.3.8.4 SR 3.3.8.5

3. Spent Fuel Pool Room (a) 2 SR3.3.8.1 S 8.73 x 10-3 l/CiIcc (b) .

Radiation Gaseous SR3.3.B.2 (R-25A, B) SR3.3.8.7

4. Spent Fuel Pool Room (a) SR3.3.8.6 NA Ventilation Differential SR3.3.8]

Pressure (PDSL-3989A and B)

5. Containment Isolation - Refer to lCO 3.3.2. "ESFAS Instrumentation" Function 3.b, for al initiatioo Functions and PhaseB requirements.

(a) During movement of Irradiated fuel assemblies in the spent fuel pool room.

(b) Above background with no ftow.

Farley Units 1 and 2 3.3.8-5 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS Pressure, Temperature. and Flow ONB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is within the limit In accordance with specified in the COLR. the Surveillance Frequency Control Program SR 3.4.1.2 Verify RCS average temperature is within the limit In accordance with specified in the COLR. the Surveillance Frequency Control Program SR 3.4.1.3 Verify RCS total flow rate is within the limits. In accordance with the Surveillance Frequency Control Program SR 3.4.1.4 -------------NOTE----------

Not required to, be performed until 7 days after

~90% RTP.

Verify by measurement that RCS total flow rate is In accordance with within the limits. the Surveillance Frequency Control Program Farley Units 1 and 2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS PIT Limits 3.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. -----NOTE--- C.1 Initiate action to restore Immediately Required Action C.2 shall parameter(s) to within be completed whenever limits.

this Condition is entered.

AND Requirements of LeO not C.2 Determine RCS is Prior to entering met any time in other acceptable for continued MODE 4 than MODE 1, 2, 3, or 4. operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 --------INOTE Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.

Verify RCS pressure, RCS temperature, and ReS In accordance with heatup and cooldown rates are within the limits the Surveillance specified in the PTLR. Frequency Control Program Farley Units 1 and 2 3.4.3-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LCO 3.4.4 Three RCS loops shall be OPERABLE and in operation.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO not A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.4-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS Loops - MODE 3 3.4.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. One required RCS loop C.1 Restore required RCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not in operation, and loop to operation.

reactor trip breakers closed and Rod Control OR System capable of rod withdrawal. C.2 De-energize all control 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months rod drive mechanisms (CRDMs).

O. Two required RCS loops 0.1 De-energize all CRDMs. Immediately inoperable.

AND

-- OR 0.2 Suspend all operations Immediately No RCS loop in involving a reduction of operation. RCS boron concentration.

AND D.3 Initiate action to restore Immediately one RCS loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are In operation. In accordance with the Surveillance Frequency Control Program SR 3.4.5.2 Verify steam generator secondary side water levels In accordance with are <!: 30% (narrow range) for required RCS loops. the Surveillance Frequency Control Program SR 3.4.5.3 Verify correct breaker alignment and indicated power In accordance with are available to the required pump that is not in the Surveillance operation. Frequency Control Program Farley Units 1 and 2 3.4.5-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.6.2 Verify SG secondary side water levels are G!: 75% In accordance (wide range) for required RCS loops. with the Surveillance Frequency Control Program SR 3.4.6.3 Verify correct breaker alignment and indicated power In accordance are available to the required pump that is not in . with the operation. Surveillance Frequency Control Program Farley Units 1 and 2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS l-oops - MODE 5, Loops Filled

3.4.7 APPLICABILITY

MODE 5 with RCS loops filled.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.7.2 Verify SG secondary side water level is 2: 75% (wide In accordance range) in required SGs. With the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.7-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS Loops - MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.3 Verify correct breaker alignment and indicated power In accordance with are available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program Farley Units 1 and 2 3.4.7-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS Loops-MODE 5,Loops Not Filled 3.4.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops B.1 Suspend all operations Immediately inoperable. involving reduction in RCS boron concentration.

No RHR loop in operation. B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILlANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and indicated power In accordance with are available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program Farley Units 1 and 2 3.4.8-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Pressurizer 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is S 63.5% indicated. In accordance with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of each required group of pressurizer In accordance with heaters is ~ 125 kW. the Surveillance Frequency Control Program SR3.4.9.3 Verify required pressurizer heaters are capable of In accordance with being powered from an emergency power supply. the Surveillance Frequency Control Program Far1ey Units 1 and 2 3.4.9--2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Pressurizer PORVs 3.4.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. More than one block valve F.1 Place associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. PORVs in manual control.

AND F.2 Restore one block valve 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to OPERABLE status.

AND F.3 Restore remaining 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months block valve to OPERABLE status.

G. Required Action and G.1 Be In MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition F not AND met.

G.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 --------*------NOTES---

1. Not required to be met with block valve closed in accordance with the Required Action of Condition B or E.

2. Not required to be performed prior to entry into MODE 3.

3. Not required to be performed for Unit 2 for the remainder of operating cycle 16 for block valve Q2B31 MOV8000B.

Perform a complete cycle of each block valve. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.11-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.2 ----.----------------.-----NOTE----.-------------------------

Not required to be performed prior to entry into MODE 3.

In accordance with Perform a complete cycle of each PORV during the Surveillance MODE30r4. Frequency Control Program SR 3.4.11.3 Perfonn a complete cycle of each POAV using the backup PORV control system. In accordance with

. the Surveillance

! Frequency Control Program SA 3.4.11.4 ---------------------NOTE---------------------------

Required to be performed only for Unit 2 for the remainder of operating cycle 16.

Check power available to the Unit Two PORV block 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months valve O2B31 MOV8000B.

Farley Units 1 and 2 3.4.11-4 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

LTOP System 3.4.12 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One required RHR relief 0.1 Reduce pressurizer level 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months valve inoperable. to S; 30% (cold calibrated).

AND 0.2 Assign a dedicated 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months operator for RCS pressure monitoring and control.

AND 0.3 Restore required RHR 1 days relief valve to OPERABLE status.

E. Two required RHR relief E.1 Depressurize RCS and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months valves inoperable. establish RCS vent of 2: 2.85 square inches.

OR Required Action and associated Completion TIme of Condition A, C.

or D not met.

OR i

LTOP System inoperable for any reason other than Condition A. B. C. or D.

Farfey Units 1 and 2 3.4.12-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of one charging pump is In accordance with capable of injecting into the RCS. the Surveillance Frequency Control Program SR 3.4.12.2 Verify each accumulator is isolated. In accordance with the Surveillance Frequency Control

. Program SR 3.4.12.3 Verify RHR suction isolation valves are open for each In accordance with required RHR suction relief valve. the Surveillance Frequency Control Program SR 3.4.12.4 ----------NOTE--------------

Only required to be performed when complying with LCO 3.4.12.b ..

Verify RCS vent ~ 2.85 square inches open. In accordance with the Surveillance Frequency Control Program SR 3.4.12.5 Verify each required RHR suction relief valve In accordance with setpoint. the Inservlce Testing Program In accordance with i the Surveillance

Frequency Control I Program Farley Units 1 and 2 3.4.12-4 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 NOTES-- --NOTE-

1. Not required to be perfonned in MODE 3 or 4 Only required to until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation. be perfonned during steady

2. Not applicable to primary to secondary LEAKAGE. state operation Verify RCS operational LEAKAGE is within limits by In accordance performance of RCS water inventory balance. with the Surveillance Frequency Control Program SR 3.4.13.2 --NOTE Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Verify primary to secondary LEAKAGE is S 150 In accordance gallons per day through anyone SG. with the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.13-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 --NOTE8----

1. Not required to be Performed in MODES 3 and 4.

2. Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.

3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once If a repetitive testing loop cannot be avoided.

Verify leakage from each RCS PIV is equivalent to 18 months, prior S 0.5 gpm per nominal inch of valve size up to a to entering maximum of 5 gpm at an RCS pressure;<; 2215 psig MODE 2 and S 2255 psig.

Following valve '

actuation due to automatic or manual action or flow through the valve (except for RCS PIVs located in the RHR flow path)

SR 3.4.14.2 NOTE------

Not required to be met when the RHR System valves are required open in accordance with SR 3.4.12.3.

Verify RHR System autoclosure interlock In accordance with causes the valves to close automatically the Surveillance with a simulated or actual RCS pressure Frequency Control signal ~ 700 psig and s 750 psig. Program Fartey Units 1 and 2 3.4.14-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SR 3.4.14.3 - - - - - - - NOTE---

Not required to be met when the RHR System valves valves are required open in accordance with SR 3.4.12.3.

Verify RHR System open permissive interlock In accordance with prevents the valves from being opened with a the Surveillance simulated or actual RCS pressure signal Frequency Control

~ 295 psig and ;f 415 psig. Program Farley Units 1 and 2 3.4.14-4 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVeiLLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEl CHECK of the required In accordance with containment atmosphere radioactivity monitor. the Surveillance Frequency Control Program SR 3.4.15.2 Perform COT of the required containment In accordance with atmosphere radioactivity monitor. the Surveillance .

i Frequency Control

. Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required In accordance with containment atmosphere radioactMty monitor. the Surveillance Frequency Control Program SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required In accordance with containment air cooler condensate level monitor. the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.15-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS Specific Activity 3.4.16 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Tavg < SOO°F.

Time of Condition A not met.

OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.16-1.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific activity In accordance with

100/E tJCi/gm. the Surveillance Frequency Control Program SR 3.4.16.2 NOTE Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 In accordance with specific activity ::; O.S tJCi/gm. the Surveillance Frequency Control Program

! Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL

POWER change I of~15% RTP

~it~in a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months pened Farley Units 1 and 2 3.4.16-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RCS Specific Activity 3.4.16 SURVIELLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.3 NOTE--*

Not required to be performed until 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for ~ 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Determine £ from a sample taken In MODE 1 after a In accordance with minimum of 2 effective full power days and 20 days the Surveillance of MODE 1 operation have elapsed since the reactor Frequency Control was last subcritical for;;: 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . Program Farley Units 1 and 2 3.4.16-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully open. In accordance with the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each accumulator is In accordance with

~ 7555 gallons (31.4%) and S 7780 gallons (58.4%). the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each accumulator is In accordance with

~ 601 psig and :s 649 psig. the Surveillance Frequency Control Program SR 3.5.1.4 Verify boron concentration in each accumulator is In accordance with

~ 2200 ppm and S 2500 ppm. the Surveillance Frequency Control Program AND

--NOTE-Only required to be perfonned for affected accumulators Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of ~ 12%

level, Indicated, that is not the result of addition from the refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator In accordance with isolation valve operator when RCS pressure is the Surveillance

~ 2000 psig. Frequency Control Program Farley Units 1 and 2 3.5.1-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 --------NOTE-*---,------

Only required to be performed for valves 8132A and 81326 when Centrifugal Charging Pump A is inoperable.

Verify the foilowing valves are in the listed position In accordance with with power to the valve operator removed. the Surveillance Frequency Control Number Position Function Program 8884,8886 Closed Centrifugal Charging Pump to RCS Hot Leg 8132A,81326 Open Centrifugal Charging Pump discharge isolation 8889 Closed RHR to RCS Hot Leg Injection SR 3.5.2.2 Verify each ECCS manual, power operated, and In accordance with automatic valve in the flow path. that is not locked, the Surveillance sealed. or otherwise secured in position, is in the Frequency Control correct position. Program SR 3.5.2.3 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required the Inservice developed head. Testing Program SR 3.5.2.4 Verify each ECCS automatic valve in the flow path In accordance with that is not locked, sealed. or otherwise secured in the Surveillance position. actuates to the correct position on an actual Frequency Control or simulated actuation Signal. . Program Farley Units 1 and 2 3.5.2-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each ECCS pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3,5.2.6 Verify. for each ECCS throttle valve listed below. In accordance with each position stop is in the correct position. the Surveillance Frequency Control Valve Number Program CVC-V-8991 AlBIC CVC-V-8989 AJB/C CVC-V-8996 AJB/C CVC-V-8994 AlBIC RHR-HV 603 AlB SR 3.5.2.7 Verify. by visual inspection. each ECCS train. In accordance with containment sump suction inlet is not restricted by the Surveillance debris and the suction inlet trash racks, screens, and Frequency Control inner cages are properly installed and show no Program evidence of structural distress or abnormal corrosion.

Farley Units 1 and 2 3.5.2-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

ECCS - Shutdown 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.2 Verify the following valves are in the listed position* In accordance with with power to the valve operator removed. the Surveillance Frequency Control Number Position Function Program 8706A, Closed RHR pump discharge 87068 to centrifllgal charging pump suction 8884, Closed Centrifugal charging 8886 pump discharge to RCS hot legs Farley Units 1 and 2 3.5.3-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 - - --------NOTE----

Only required to be performed when ambient air temperature is < 35°F.

Verify RWST borated water temperature is ~ 35°F. fn accordance with the Surveillance Frequency Control Program SR 3.5.4.2 Verify RWST borated water volume is ~ 471,000 In accordance with gallons. the Surveillance Frequency Control Program SR 3.5.4.3 Verify RWST boron concentration is ~ 2300 ppm and In accordance with

s 2500 ppm. the Surveillance Frequency Control Program Farley Units 1 and 2 3.5.4-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SU RVEILLANCE FREQUENCY SR 3.5.5.1 -----NOTE Not required to be perfonned until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the Reactor Coolant System pressure stabilizes at

~ 2215 psig and S 2255 psig.

Verify manual seal injection throttle valves are In accordance with adjusted to give a flow within the limits of Figure the Surveillance 3.5.5-1 wilt! the seal water injection flow control Frequency Control valve full open. Program Farley Units 1 and 2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

ECCS Recirculation Fluid pH Control System 3.5.6 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.6 ECCS Recirculation Fluid pH Control System LCO 3.5.6 The ECCS Recirculation Fluid pH Control System shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ECCS Recirculation Fluid A.1 Restore system to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pH Control System OPERABLE status.

inoperable.

B. Required Action and B.1 Be in MODE3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Se in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.6.1 Perform a visual inspection of the ECCS In accordance with Recirculation Fluid pH Control System and verify the the Surveillance following: Frequency Control Program

a. Three (3) storage baskets are in place, and

b. Have maintained their integrity, and

c. Each basket is filled with trisodium phosphate compound such that the level is between the indicated fill marks on the baskets.

Farley Units 1 and 2 3.5.6-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 NOTES - - - - -

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

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.

Perform required air lock leakage rate testing in In accordance with accordance with the Containment leakage Rate the Containment Testing Program. Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened at In accordance with a time. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.2-5 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A. B. AND C. or 0 not met.

E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. One or more penetration F.1 Reduce leakage to within Prior to entering flow paths containing limit. MODE 4 from MODE containment purge 5 if the existing valves, with penetration leakage is determined leakage not within the during quarterly penetration limits. testing per SR 3.6.3.5 OR Prior to entering MODE 4 if excess leakage is determined during MODE 5 per SR3.6.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.3.1 Verify each 48 inch purge valve is sealed closed, In accordance with except for one purge valve in a penetration flow path the Surveillance while in Condition 0 of this LCO. Frequency Control Program SR 3.6.3.2 ------------NOTE Valves and blind flanges in high radiation areas may be verified by use of administrative controls.

Verify each containment isolation manual valve and In accordance with blind flange that is located outside containment and the Surveillance not locked. sealed. or otherwise secured and Frequency Control required to be closed during accident conditions is Program closed. except for containment isolation valves that are open under administrative controls.

Farley Units 1 and 2 3.6.3-5 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.3 -*-----------NOTE8--------------

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

2. The blind flange on the fuel transfer canal flange is omy required to be verified closed after each draining of the canal.

Verify each containment isolation manual valve and Prior to entering blind flange that is located inside containment and MODE4from .

not locked, sealed, or otherwise secured and MODE 5 if not required to be closed during accident conditions is perfonned within closed, except for containment isolation valves that the previous.

are open under administrative controls. 92 days SR 3.6.3.4 Verify the isolation time of each power operated or In accordance with automatic containment Isolation valve in the 1ST the 'nservice .

Program is within limits. Testing Program SR 3.6.3.5 Perform leakage rate testing for containment In accordance with penetrations containing containment purge valves the SUlveillance with resilient seals. Frequency Control Program AND Within 92 days after opening the valv~

SR 3.6.3.6 Verify each automatic containment isolation valve In accordance with that is not locked, sealed or otherwise secured in the Surveillance pOSition, actuates to the isolation position on an Frequency Control actual or simulated actuation signa1. Program Farley Units 1.aOO 2 3.6.3-6 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be ~ -1.5 psig and ~ +3.0 psig.

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

ACTIONS CONDITION . REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not within limits. pressure to within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met AND B.2 Be in MODES. 361:10urs SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.4-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Containment Air Temperature 3.6.5 3.6 CONTAI NMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be ~ 120°F.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average air A.1 Restore containment ! 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature not within average air temperature limit. to within limit B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODES. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is within In accordance with limit. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.5~1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Containment Spray and Cooling Systems 3.6.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two containment cooling D.1 Restore one containment 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trains inoperable. cooling train to OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition C or D AND not met.

E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. Two containment spray F.1 Enter LCO 3.0.3. Immediately trains inoperable.

OR Any combination of three or more trains inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power In accordance with operated, and automatic valve in the flow path that is the" Surveillance not locked. sealed, or othelWise secured in position is Frequency Control in the correct position. Program SR 3.6.6.2 Operate each required containment cooling train fan In accordance with unit for ~ 15 minutes. the Surveillance Frequency Control Program SR 3.6.6.3 Verify each containment cooling train cooling water In accordance with flow rate is ~ 1600 gpm. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.6-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.4 Verify each containment spray pump's developed In accordance with head at the flow test point is greater than or equal to the Inservlce the required developed head. Testing Program SR 3.6.6.5 Verify each automatic containment spray valve in the In accordance with flow path that is not locked, sealed, or otherwise the Surveillance secured in position, actuates to the correct position Frequency Control on an actual or simulated actuation signal. Program SR 3.6.6.6 Verify each containment spray pump starts In accordance with automatically on an actual or simulated actuation the Surveillance signal. Frequency Control Program SR 3.6.6.7 Verify each containment cooling train starts In accordance with automatically on an actual or simulated actuation the Surveillance signal. Frequency Control Program SR 3.6.6.8 Verify each spray nozzle is unobstructed. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.6-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2) .

HMS 3.6.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Operate each HMS train for ~ 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3.6.8.2 Verify each HMS fan speed is ~ 1320 rpm. In accordance with the Surveillance Frequency Control Program SR 3.6.8.3 Verify each HMS train starts on an actual or In accordance with simulated actuation signal. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.8-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Reactor Cavity Hydrogen Dilution System 3.6.9 3.6 CONTAINMENT SYSTEMS 3.6.9 Reactor Cavity Hydrogen Dilution System LCO 3.6.9 Two Reactor Cavity Hydrogen Dilution trains shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Reactor Cavity A;1 Restore the train to 30 days Hydrogen Dilution train OPERABLE status.

inoperable.

B. Required Action and B.1 Bein MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Operate each Reactor Cavity Hydrogen DilUtion train In accordance with for;?:: 15 minutes. the Surveillance Frequency Control Program SR 3.6.9.2 Verify each Reactor Cavity Hydrogen Dilution train In accordance with starts on an actual or simulated actuation signal. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.9-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

ARVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ARV. In accordance with the Surveillance Frequency Control Program SR 3.7.4.2 Verify one complete cycle of at least one manual In accordance with isolation valve in each ARV Line. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.4-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AFW System 3.7.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Three AFW trains D.1 -----NOTE--

inoperable. LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.

Initiate adion to restore Immediately one AFW train to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 ------------INOTE-----------

Not required to be performed for the AFW flow control valves when S 10% RTP or when the AFW system is not in automatic control.

0_.__-

Verify each AFW manual, power operated, and In accordance automatic valve in each water flow path. and in both with the steam supply now paths to the steam turbine driven Surveillance pump. that is not locked, sealed. or otherwise Frequency secured in position. is in the correct position. Control Program Farley Units 1 and 2 3.7.&-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AFWSystem 3.7.5 SURVEILLANCE REQUIREME_.N.T.S_

~-------------

SURVEILLANCE FREQUENCY SR 3.7.5.2 ---------*-----NOTE---------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after ~ 1005 psig in the steam generator.

Verify the developed head of each AFW pump at the In accordance flow test point is greater than or equal to the required with the Inservice developed head. Testing Program.

SR 3.7.5.3 Verify each AFW automatic valve that is not lOCked, In accordance sealed, or otherwise secured in position. actuates to with the the correct position on an actual or simulated Surveillance actuation signal. Frequency Control Program SR 3.7.5.4 -------------NOTE---------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after ~ 1005 psig in the steam generator.

Verify each AFW pump starts automatically on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.7.5.5 Verify the turbine driven AFW pump steam admission In accordance valves open when air is supplied from their respective with the air accumulators. Surveillance Frequency Control Program Farley Units 1 and 2 3.7.5-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

CST 3.1-6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)

LCO 3.7.6 The CSTshaU be OPERABLE.

APPLICABILITY: MODES 1.2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CST inoperable. A.1 Verify by administrative 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months means OPERABILITY of backup water supply. AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND A.2 Restore CST to 7 days OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEIlLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST level is ~ 150,000 gal. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.6--1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

CCWSystem 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 NOTE---------

Isolation of CCW flow to individual components does not render the CCW System inoperable.

Verify each accessible CCW manual, power In accordance with operated, and automatic valve in the flow path the Surveillance servicing safety related equipment, that is not locked, Frequency Control sealed. or otherwise secured in' position. is in the Program correct position.

SR 3.7.7.2 Verify each CCW automatic valve in the flow path In accordance with that is not locked. sealed. or otherwise secured in the Surveillance position. actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program SR 3.7.7.3 Verify each CCW pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.7-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

SWS 3.7.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TiME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or B AND not met.

C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 ----------------INOTE.----------------*

Isolation of SWS flow to individual components does not render the SWS inoperable.

Verify each accessible SWS manual, power In accordance with operated, and automatic valve in the flow path the Surveillance servicing safety related equipment, that is not locked, Frequency Control sealed, or otherwise secured in position. is in the Program correct position.

SR 3.7.8.2 Verify each SWS automatic valve in the flow path that In accordance with is not locked. sealed. or otherwise secured in the Surveillance position, actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program SR 3.7.8.3 Verify each SWS pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3.7.8.4 Verify the integrity of the SWS buried piping by visual In accordance with inspection of the ground area. the Surveillance I Frequency Control Program Fartey Units 1 and 2 3.7.8-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)

LCO 3.7.9 The UHS (Service Water Pond) shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. UHS water level or A.1 Be in MODE 4. 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months temperature not within the required limit(s). AND A.2 Be in MODE 5. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7:9.1 Verify water level of UHS is /!: 184 ft In accordance with mean sea level. the Surveillance Frequency Control Program SR3.7.9.2 Verify water temperature of :<; 95"F at the discharge In accordance with of the Service Water Pumps the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.9-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Control Room 3.7.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Suspend CORE Immediately associated Completion ALTERATIONS.

Time of Condition B not met during movement of AND irradiated fuel assemblies or during CORE E.2 Suspend movement of Immediately ALTERATIONS. irradiated fuel assemb6es.

Two CREFS trains inoperable during movement of irradiated fuel assemblies or during CORE ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each CREFS Pressurization train with the In accordance with heaters operating and each CREFS Recirculation and the Surveillance Filtration train for ~ 15 minutes. Frequency Control Program SR 3.7.10.2 Perform required CREFS filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). VFTP SR 3.7.10.3 -------------NOTE--------------

Not required to be performed in MODES 5 and 6.

In accordance with Verify each CREFS train actuates on an actual or the Surveillance simulated actuation signal.

Frequency Control Program Farley Units 1 and 2 3.7.10-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

CRACS 3.7.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two CRACS trains 0.1 Suspend CORE Immediately inoperable during ALTERATIONS.

movement of irradiated fuel assemblies or during AND CORE ALTERATIONS.

0.2 Suspend movement of Immediately irradiated fuel assemblies.

E. Two CRACS trains E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3,or4. .

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify each CRACS train has the capability to In accordance with remove the assumed heat load. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.11-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

PRF 3.7.12 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Two PRF trains inoperable E.1 Suspend movement of Immediately during movement of irradiated fuel irradiated fuel assemblies assemblies in the SFPR.

in the SFPR.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 - NOTE-Only required to be performed during movement of irradiated fuel assemblies in tfle SFPR.

Verify two PRF trains aligned to the SFPR. In accordance with the Surveillance Frequency Control Program SR 3.7.12.2 Operate each PRF train for 2: 15 minutes In the In accordance with applicable mode of operation (post LOCA and/or . the Surveillance refueling accident). Frequency Control Program SR 3.7.12.3 Perform required PRF filter testing in accordance with In accordance with the Ventilation Filter Testing Program (VFTP). theVFTP SR 3.7.12.4 Verify each PRF train actuates and the normal spent In accordance with fuel pool room ventilation system isolates on an the Surveillance actual or simulated actuation signal. Frequency Control Program SR 3.7.12.5 Verify one PRF train can maintain a pressure In accordance with

~ -0.125 inches water gauge with respect to adjacent the Surveillance areas during the post LOCA mode of operation at a Frequency Control flow rate ~ 5500 cfm. Program SR 3.7.12.6 Verify one PRF train can maintain a slightly negative In accordance with pressure with respect to adjacent areas during the the 'Surveillance fuel handling accident mode of operation at a flow Frequency Control rate ~ 5500 cfm. Program Farley Units 1 and 2 3.7.12-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Fuel Storage Pool Water Level 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Fuel Storage Pool Water Level LCO 3.7.13 The fuel storage pool water level shall be 2:: 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY: During movement of irradiated fuel assemblies in the fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool water A.1 ---NOTE--

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies In the fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Verify the fuel storage pool water level is 2:: 23 ft In accordance with above the top of the irradiated fuel assemblies seated the Surveillance in the storage racks. Frequency Control Program Farley Units 1 and 2 3.7.13-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Fuel Storage Pool Boron Concentration 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Fuel Storage Pool Boron Concentration LCO 3.7.14 The fuel storage pool boron concentration shall be ~ 2000 ppm.

APPLICABILITY: When fuel assemblies are stored in the fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool boron ---------NOTE--------

concentration not within LCO 3.0.3 is not applicable.

limit.

A.1 Suspend movement of fuel Immediately assemblies in the fuel storage pool.

AND A.2 Initiate action to restore Immediately fuel storage pool boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the fuel storage pool boron concentration is In accordance with within limit. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.14-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Secondary Specific Activity 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Secondary Specific Activity LCO 3.7.16 The specific activity of the secondary coolant shall be s; 0.10 IJCilgm DOSE EQUIVALENT 1~131.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not within A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months limit.

AND A,2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the specific activity of the secondary coolant is In accordance with s; 0.10 J.lCi/gm DOSE EQUIVALENT 1-131. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.16-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Cask Storage Area Boron Concentration Cask Loading Operations 3.7.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify the cask storage area boron concentration is Once within 4 within limit. hours prior to entering the Applicability of this LCO.

In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.17-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

ESF Room Coolers 3.7.19 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.19.1 Verify each ESF Room Cooler system manual valve In accordance with servicing safety-related equipment that is not locked, the Surveillance sealed, or otherwise secured in position, is in the

Frequency Control correct position.

Program SR 3.7.19.2 Verify each ESF Room Cooler fan starts In accordance with automatically on an actual or simulated actuation the Surveillance signal. Frequency Control Program Farley Units 1 and 2 3.7.19-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power i In accordance with availability for each required offsite circuit. the Surveillance Frequency Control Program SR 3.8.1.2 ---NOTES;-----

1. Performance of SR 3.8.1.6 satisfies this SR.

2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

3. A modified OG 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 3.8.1.6 must be met.

Verify each DG starts from standby conditions and In accordance with achieves steady state voltage ~ 3740 V and the Surveillance S 4580 V, and frequency ~ 58.8 Hz and S 61.2 Hz. Frequency Control Program Farley Units 1 and 2 3.8.1-6 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUREMENTS 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 3.8.1.6.

Verify each DG is synchronized and loaded and In accordance with operates for ~ 60 minutes at a load ~ 2700 kW and the Surveillance S 2850 kW for the 2850 kW DG and ~ 3875 kW and Frequency Control S' 4075 kW for the 4075 kW DGs. Program SR 3.8.1.4 Verify each day tank contains ~ 900 gal of fuel oil for In accordance with the 4075 kW DGs and 700 gal of fuel oil for the the Surveillance 2850kW DG. Frequency Control Program SR 3.8.1.5 Verify the fuel oil transfer system operates to transfer In accordance with fuel oil from storage tank to the day tank. the Surveillance Frequency Control Program SR 3.8.1.6 --NOTE All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby condition and In accordance with achieves in :5; 12 seconds. voltage ~ 3952 V and the Surveillance frequency ~ 60 Hz. Frequency Control Program Farley Units 1 and 2 3.8.1-7 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.7 ---*---NOTE This Surveillance shall not be performed in MODE 1 or 2.

Verify manual transfer of AC power sources from the In accordance with normal offsite circuit to the alternate required offsite the Surveillance circuit. Frequency Control Program SR 3.8.1.8 Verify each DG rejects a load greater than or equal to In accordance with its associated single largest post-accident load, and: the SurveHlance Frequency Control

a. Following load rejection. the speed is:s; 75% of Program the difference between nominal speed and the overspeed trip setpoint; and

b. Following load rejection, the voltage is

~ 3740 V and :s; 4580 V.

Farley Units 1 and 2 3.8.1-8 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILlANCE FREQUENCY SR 3.8.1.9 NOTES

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

2. This Surveillance shall not be performed in MODE 1,2,3, or4.

Verify on an actual or simulated loss of offsite power In accordanc~ with signal: the Surveillance Frequency Control

a. De-energization of emergency buses; Program

b. Load shedding from emergency buses;

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in S 12 seconds,

2. energizes auto-connected shutdown loads through automatic load sequencer.

3. maintains steady state voltage

?: 3740 V and S 4580 V,

4. maintains steady state frequency

?: 58.8 Hz and S 61.2 Hz, and

5. supplies permanently connected and auto-connected shutdown loads for 2: 5 minutes.

Farley Units 1 and 2 3.8.1-9 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.10 --------------NOT&-------------

All DG starts may be preceded by prelube period.

Verify on an actual or simulated Engineered Safety In accordance with the Surveillance Feature (ESF) actuation signal each DG auto-starts Frequency Control from standby condition and:

Program

a. In :s; 12 seconds after auto-start and during tests, achieves voltage ~ 3952 V;

b. In:s; 12 seconds after auto-start and during tests, achieves frequency ~ 60 Hz;

c. Operates for ~ 5 minutes and maintains a steady state generator voltage and frequency of ~ 3740 V and :s; 4580 V and ~ 58.8 Hz and

S;61.2 Hz;

NOTE--------

SR 3.8.1.1 O.d and e shall not be performed in MODE 1 or2.

d. Permanently connected loads remain energized from the offsite power system; and

e. Emergency loads are energized from the offsite power system.

Farley Units 1 and 2 3.8.1-10 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 Verify each DG's automatic trips are bypassed on In accordance with actual or simulated loss of voltage signal on the the SurveHiance emergency bus andlor an actual or simulated ESF Frequency Control actuation signal except: Program

a. Engine overspeed;

b. Generator differential current; and C. low lube oil pressure.

SR 3.8.1.12 ---------------NOTE------------

Momentary transients below the minimum load specified do not invalidate this test.

Verify each DG operates for ~ 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: In accordance with the Surveillance

a. For ~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded ~ 4353 for the 4075 kW Frequency Control DGs and ~ 3100 kW for the 2850 kW 00; and Program

b. For the remaining hours of the test loaded

~ 4075 kW for the 4075 kW DGs and 2: 2850 kW for the 2850 kW DG.

Farley Units 1 and 2 3.8.1-11 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.13 --NOTES-

1. This Surveillance shall be performed within 10 minutes of shutting down the DG after the DG has operated;?: 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded;?: 4075 kW for the 4075 kW DGs and ~ 2850 kW for the 2850 kWDG.

Momentary transients below the minimum load specified do not invalidate this test.

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

Verify each DG starts and achieves, in:s; 12 seconds, In accordance with voltage;?: 3952 V and frequency ~ 60 Hz. the Surveillance Frequency Control Program SR 3.8.1.14 ------1NOTE-------

This Surveillance shall not be performed in MODE 1, 2, 3, or4.

Verify each DG: In accordance with the Surveillance

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

b. Transfers loads to offsite power source; and

c. Returns to ready-ta-Ioad operation.

Farley Units 1 and 2 3.8.1-12 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.15 Verify, with a DG operating in test mode and In accordance with connected to its bus, an actual or simulated ESF the Surveillance actuation signal overrides the test mode by returning Frequency Control DG to ready-to-Ioad operation. Program SR 3.8.1.16 Verify interval between each sequenced load block is In accordance with within +/- 10% of design interval or 0.5 seconds, the Surveillance whichever is greater, for each emergency load Frequency Control sequencer. Program SR 3.8.1.17 --------------NOTES--------*----

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

2. This Surveillance shall not be performed in MODE 1,2,3, or4.

Verify on an actual or simulated loss of offsile power In accordance with signal in conjunction with an actual or simulated ESF the Surveillance actuation signal: Frequency Control Program

a. De-energization of emergency buses;

b. Load shedding from emergency buses; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in ~ 12 seconds, (continued)

Farley Units 1 and 2 3.8.1-13 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.17 (continued)

2. energizes autcrconnected emergency loads through load sequencer,

3. achieves steady state voltage

~ 3740 V and ~ 4580 V,

4. achieves steady state frequency

~ 58.8 Hz and ~ 61.2 Hz, and

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

~5 minutes.

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

Testing of the shared Emergency Diesel Generator (EDG) set (EDG 1-2A or EDG 1C) on either unit may be used to satisfy this surveillance requirement for these EDGs for both units.

Verify each DG does not trip and voltage is In accordance with maintained ~ 4990 V and ~ 3330 V during and the Surveillance following a load rejection of ~ 1200 kW and ~ 2400 Frequency Control kW. Program SR 3.8.1.19 --------------NOTE:-------------

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

Verify when started simultaneously from standby In accordance with condition, each DG achieves, in ~ 12 seconds, the Surveillance voltage ~ 3952 V and frequency ~ 60 Hz. Frequency Control Program Farley Units 1 and 2 3.8.1-14 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with new 0.1 Restore stored fuel oil 30 days fuel oil properties not within properties to within limits. limits.

E. One or more DGs with the E.1 Restore at least one 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months required starting air starting air receiver receiver pressure < 350 pressure per affected psig and ~ 150 psig (for DG to ;;:: 350 psig (for DG DG 1-2A, lB, and 2B), or 1-2A, lB, and 2B) or

< 200 psig and ~ 90 psig ~ 200 pSig (for DG 1C).

(for DG lC).

F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

OR One or more DGs diesel fuel oil, lube oil, or starting

-air subsystem not within limits for reasons other than Condition A, B, C, D, or E.

-SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 verify each fuel oil storage tank contains;;:: 25,000 gal In accordance with of useable fuel. the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.3-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Diesel Fuel Oil. Lube Oil. and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.2 Verify lubricating oil inventory is 2: 238 gal (for In accordance with DG 1-2A, 1B, and 2B) or 2: 167 gal (for DG 1C). the Surveillance Frequency Control Program SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Dtesel Fuel Oil limits of, tile Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each DG has at least one air start receiver with In accordance with a pressure 2: 350 psig (for DG 1-2A, 1B, and 28) and the Surveillance 2: 200 psig (for DG 1C). Frequency Control Program Farley Units 1 and 2 3.8.3-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS .

SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is;?: 127.8 V on float In accordance charge. with the Surveillance Frequency Control Program SR 3.8.4.2 Verify no visible corrosion at battery terminals and In accordance connectors. with the Surveillance Frequency Control Program Verify posHo-post battery connection resistance of each cell-to-cell and terminal connection is S 150 microhms for the Auxiliary Building batteries and

$ 1500 microhms for the SWIS batteries.

SR 3.8.4.3 Verify battery cells, cell plates, and racks show no In accordance visual indication of physical damage or abnormal with the deterioration. Surveillance Frequency Control Program SR 3.8.4.4 Remove visible terminal corrosion, verify battery In accordance cell- to-cell and terminal connections are coated with with the anti--corrosion material. Surveillance Frequency Control Program SR 3.8.4.5 Verify post-to-post battery connection resistance of In accordance each cell-to-cell and terminal connection is. $ 150 with the microhms for the Auxiliary Building batteries and Surveillance

$ 1500 microhms for the SWIS batteries Frequency Control Program Farley Units 1 and 2 3.8.4-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.6 -----NOTE-This Surveillance may be performed in MODE 1, 2, 3, 4,5, or 6 provided spare or redundant charger(s) placed in service are within surveillance frequency to maintain DC subsystem(s) OPERABLE.

Verify each required Auxiliary Building battery In accordance with charger supplies ~ 536 amps at ~ 125 V for ~ 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the Surveillance and each required SWiS battery charger supplies Frequency Control

~ 3 amps at ~ 125 V for ~ 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . Program SR 3.8.4.7 NOTES--

1. The performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4. 7 once per 60 months.

2. The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test at any time.

3. This Surveillance shall not be performed for the Auxiliary Building batteries in MODE 1, 2, 3, or4.

Verify battery capacity is adequate to supply, and In accordance with maintain in OPERABLE status, the required the Surveillance emergency loads for the design load profile described Frequency Control in the Final Safety Analysis Report, Section 8.3.2. by Program subjecting the battery to a service test Fariey Units 1 and 2 3.8.4-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.8 NOTE This Surveillance shall not be performed for the Auxiliary Building batteries in MODE 1. 2, 3. or 4.

Verify battery capacity is ~ 80% of the manufacturer's In accordance with rating when subjected to a performance discharge the Surveillance test or a modified performance discharge test. Frequency Control Program AND 18 months when battery shows degradation or has reached 85% of expected life or 17 years.

whichever comes first Farley Units 1 and 2 3.8.4-4 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

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

of Condition A not met.

One or more required batteries with average electrolyte temperature of the representative cells

< GOOF for the Auxiliary Building batteries or < 35°F for the SWIS batteries.

OR One or more required batteries with one or more battery cell parameters not within Category C values.

---NOTE---

Battery terminal voltage of 127.8 volts as measured by SR 3.6.4.1 is equivalent to average cell float voltage of 2.13 volts per cell.

One or more required batteries with the average cell float voltage ~ 2.13 volts.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify battery cell parameters meet Table 3.6.6-1 In accordance with category A limits. the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.6-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Battery Cell Parameters 3.B.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 In accordance with Category B limits. the Surveillance Frequency Control Program Once within 7 days after a battery discharge

< 110 V Once within 7 days after a battery overcharge

> 150V SR 3.8.6.3 Verify average electrolyte temperature of In accordance with representative cells is ~ 60°F for the Auxiliary the Surveillance Building batteries and ~ 35°F for the SWIS batteries. Frequency Control Program Farley Units 1 and 2 3.8.6-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Inverters - Operating 3.B.7 ACTIONS CONDITION REQUIRED ACTION COMPlETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and In accordance with alignment to required AC vital buses. the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.7-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Inverters - Shutdown 3.B.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate action to restore Immediately .

required inverters to OPERABLE status.

SURVEILlANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, and In accordance with alignments to required AC vital buses. the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.8-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Distribution Systems - Operating 3.8.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and 0.1 Bein MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, or AND C not met.

0.2 Be in MODES. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. One Service Water Intake E.1 Declare the associated Immediately Structure (SWIS) DC Service Water train electrical power distribution inoperable.

subsystem inoperable.

F. Two trains with inoperable F.1 Enter LCO 3.0.3. Immediately distribution subsystems that result in a loss of safety function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to In accordance with required AC, DC, and AC vital bus electrical power the Surveillance distribution subsystems. Frequency Control Program Faney Units 1 and 2 3.8.9.02 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Distribution Systems - Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate actions to restore Immediately required AC. DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.

A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to In accordance with required AC, DC, and AC vital bus electrical power the Surveillance distribution subsystems. Frequency Control Program Farley Units 1 and 2 3.8.10-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System, the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration not A.1 Suspend CORE Immediately within limit. AlTERATIONS.

AND A.2 Suspend positive Immediately reactivity additions.

A.3 Initiate action to restore Immediately boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified In accordance with in COLR. the Surveillance Frequency Control Program Fartey Units 1 and 2 3.9.1-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.2.2 -~NOTE Neutron detectors are excluded from CHANNEL CAliBRATION.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.9.2-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Containment Penetrations 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Venfy each required containment penetration is in the In accordance required status. with the Surveillance Frequency Control Program SR 3.9.3.2 Verify each required containment purge and exhaust In accordance valve actuates to the isolation position on an actual or with the simulated actuation signat Surveillance Frequency Control Program SR 3.9.3.3 ---------NOTE------ In accordance Only required for an open equipment hatch. with the Surveillance Frequency Control Verify the capability to install the equipment Program hatch.

Farley Units 1 and 2 3.9.3-2 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

RHR and Coolant Circulation - High Water Level 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Close equipment hatch 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and secure with four bolts.

AND A.S Close one door in each 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months airlock.

AND A.6.1 Close each penetration 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent OR A.6.2 Verify each penetration is 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months capable of being closed by an OPERABLE Containment Purge and exhaust Isolation System.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one RHR loop is in operation and circulating In accordance with reactor coolant at a flow rate of ~ 3000 gpm. the Surveillance Frequency Control Program Farley Units 1 and 2 3.9.4-2 Amendment No. 185 {Unit 1)

Amendment No. 180 {Unit 2)

RHR and Coolant Circulation - Low Water Level 3.9.5 SURVEILlANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating In accordance with reactor coolant at a flow rate of ~ 3000 gpm. the Surveillance Frequency Control Program SR 3.9.5.2 Verify correct breaker alignment and indicated power In accordance with available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program Fartey Units 1 and 2 3.9.5-3 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Refueling Cavity Water Level 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Refueling Cavity Water Level LCO 3.9.6 Refueling cavity water level shall be maintained ~ 23 ft above the top of reactor vessel flange.

APPLICABILITY: During CORE ALTERATIONS, except during latching and unlatching of control rod drive shafts, During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water level A.1 Suspend CORE Immediately not within limit. AlTERATIONS.

A.2 Suspend movement of Immediately irradiated fuel assemblies ,within containment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6,1 Verify refueling cavity water level is ~ 23 ft above the In accordance with top of reactor vessel flange. the Surveillance Frequency Control Program Farley Units 1 and 2 3.9.6-1 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.18 Control Room Integrity Program (CRIP) (continued)

A CRIP shall be established to implement the following:

a. Demonstrate. using Regulatory Guide (RG) 1.197 and ASTM E741. that CRE in leakage is less than the below values. The values listed below do not include 10 am assumed in accident analysis for ingress' egress.

i) 43 am when the control room ventilation systems are aligned in the emergency recirculation mode of operation, Ii) 600 am when the control room ventilation systems are aligned in the isolation mode of operation. and iii) 2,340 am when the control room ventilation systems are aligned in the normal mode of operation;

b. Demonstrate that the leakage characteristics of the CRE will not result in simultaneous loss of reactor control capability from the control room and the hot shutdown panels;

c. Maintain aCRE conflQuration control and a design and licensing bases control program and a preventative maintenance program. As a minimum.

the CRE configuration control program will determine whether the i} CRE differential pressure relative to adjacent areas and ii) the control room ventilation system flow rates, as determined in accordance with ASME N510-1989 or ASTM E2029-99. are consistent with the values measured at the time the ASTM E741 test was performed. If item i or Ii has changed.

determine how this change has affected the inleakage characteristics of the CRE. If there has been degradation in the inleakage characteristics of the CRE since the E741 test. then a determination should be made whether the licensing basis analyses remain valid. If the licensing basis analyses remain valid. the CRE remains OPERABLE.

d. Test the eRE in accordance with the testing methods and at the frequencies specified in RG 1.197. Revision 0, May 2003.

The prOVisions of SR 3.0.2 are applicable to the control room inleakage testing frequencies.

5.5.19 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance ReqUirements specified in the Technical Specifications (continued )

Farley Units 1 and 2 5.5-15 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.19 Surveillance Frequency Control Program (continued) 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.

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.

Farley Units 1 and 2 5.5-16 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 185 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-2 AND AMENDMENT NO. 180 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-8 SOUTHERN NUCLEAR OPERATING COMPANY, INC.

JOSEPH M. FARLEY NUCLEAR PLANT, UNITS 1 AND 2 DOCKET NOS. 50-348 AND 50-364

1.0 INTRODUCTION

By letter dated October 29, 2010 (Reference 10), as supplemented February 21, 2011 (Reference 12), the Southern Nuclear Operating Company, Inc. (SNC) submitted a request for changes to the Joseph M. Farley Nuclear Plant (FNP), Units 1 and 2, Technical Specifications (TSs). The requested changes reflect the adoption of Nuclear Regulatory Commission (NRC)-approved TS Task Force (TSTF) traveler TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control- RITSTF [Risk-Informed TSTF] Initiative 5b" (Reference 1). 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 TSs. All surveillance frequencies can be relocated except:

Frequencies that reference other approved programs for the specific interval (such as the Inservice 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 ;2 95% RTP [Rated Thermal Power]"); and

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").

-2 The definition of "Staggered Test Basis" in TS Section 1.1, "Definitions," is deleted. SNC adopts TSTF-425 and no longer uses this defined term in the TS and proposed removing it from Section 1.1.

A new program is added to the Administrative Controls in TS Section 5 as TS 5.5.19. The new program is called the SFCP and describes the requirements for the program to control changes to the relocated surveillance frequencies. The proposed licensee changes to the Administrative Controls of the TSs 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 (Reference 2), as the basis for making any changes to the surveillance frequencies once they are relocated out of the TSs.

In a letter dated September 19,2007 (Reference 9), the NRC staff approved NEI 04-10, Revision 1, as acceptable for referencing by licensees proposing to amend their TSs to establish a SFCP, to the extent specified and under the limitations delineated in NEI 04-10, and the NRC staff's safety evaluation (SE) providing the basis for its acceptance of NEI 04-10.

The NRC staff issued a Notice of Availability for TSTF-425, Revision 3, in the Federal Register on July 6, 2009 (74 FR 31996). The notice included a model SE. In its application dated October 29, 2010, the licensee stated that "SNC has concluded that the justifications presented in the TSTF and the SE, prepared by the NRC staff, are applicable to Units 1 and 2 of FNP." The SE that follows is based, in large part, on the model SE for TSTF-425.

The February 21, 2011, letter provided clarifying information that did not change the October 29, 2010, application and the initial proposed no significant hazards consideration determination.

2.0 REGULATORY EVALUATION

In the "Final Policy Statement on Technical Specifications Improvements for Nuclear Power Reactors," published in the Federal Register on July 22,1993 (58 FR 39132) the NRC addressed the use of Probabilistic Safety Analysis (PSA, currently referred to as Probabilistic Risk Assessment (PRA>> in determining the content of the TSs. On page 39135 of this Federal Register (FR) publication, the Commission states, in part, that:

The Commission believes that it would be inappropriate at this time to allow requirements which meet one or more of the first three criteria [in Title 10 of the code of Federal Regulations (10 CFR), Section 50. 36(c)(2)(ii)] 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 of determining the degree of regulatory conservatism that may be warranted for particular decisions. This

- 3 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 Technical Specifications, new requirements, and industry proposals for risk-based Technical Specification changes.

Approximately two years later, the NRC provided additional detail conceming the use of PRA in the "Use of Probabilistic Risk Assessment Methods in Nuclear Regulatory Activities; Final Policy Statement," published in the Federal Register on August 16, 1995 (60 FR 42622). On page 42627 of this FR publication, the Commission states, in part, that:

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.

On pages 42628 and 42629 of the FR publication, the Commission provided its policy on use of PRA which states:

Although PRA methods and infol111ation 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 PRAIstatistics 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 tel111s of methods and data. Implementation of the policy statement will improve the regulatory process in three areas: Foremost, through safety decision making 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

-4 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 staffpractices. Where appropriate, PRA should be used to 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.

The Commission's regulatory requirements related to the content of the TSs are set forth in Title 10 of the Code of Federal Regulations (10 CFR) Part 50.36, "Technical specifications." This regulation requires that the TSs include items in the following five specific categories: (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. The regulation does not specify the particular requirements within the categories to be included in a plant's TSs.

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 limiting conditions for operation will be met." To meet this requirement, the surveillance requirement must specify an adequate test, calibration, or inspection, and an appropriate frequency of performance. The licensee has proposed to implement changes to surveillance frequencies in the SFCP using the methodology in NEI 04-10, which includes qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, recommended monitoring of structures, systems, and components (SSCs), and documentation of the evaluation. 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 process.

The licensee's SFCP is intended to ensure 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 Appendix B to 10 CFR Part 50, require licensee monitoring of surveillance test failures and implementation of 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

- 5 reduced testing does not adversely impact the SSCs. These requirements, and the monitoring required by NEI 04-10, are intended to 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" (Reference 5),

describes a risk-informed approach, acceptable to the NRC, for assessing the nature and impact of proposed licensing-basis changes by considering engineering issues and applying risk insights.

This regulatory guide also provides risk acceptance guidelines for evaluating the results of such evaluations.

RG 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications" (Reference 3), describes an acceptable risk-informed approach specifically for assessing proposed TS changes.

RG 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities" (Reference 4), 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 of TSTF-425 for FNP provides for administrative relocation of applicable surveillance frequencies, and provides for the addition of the SFCP to the Administrative Controls section 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 consistent with the guidance provided in RG 1.174 and RG 1.177.

3.1 RG 1.177 Five Key Safety Principles RG 1.177 identifies five key safety principles required for risk-informed changes to the TSs. Each of these principles is addressed by the industry methodology document, NEI 04-10, and is evaluated below in SE Sections 3.1.1 through 3.1.5 with respect to the proposed amendment.

3.1.1 The Proposed Change Meets Current Regulations Paragraph (c)(3) in 10 CFR 50.36 requires that TSs include surveillance requirements which 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 proposed amendment would relocate most periodic surveillance requirement frequencies, currently shown in the FNP TSs, to a licensee-controlled program (i.e., the SFCP). The surveillance requirements themselves would remain in the TSs, as required by 10 CFR 50.36 (c)(3). The reqUirements for the SFCP would be

- 6 added to new TS 5.5.19. In accordance with TS 5.5.19, any changes to the surveillance requirement frequencies would be made in accordance with NEI 04-10, Revision 1. By letter dated September 19,2007 (Reference 9), the NRC staff found that the methodology in NEI 04-10, Revision 1, met NRC regulations, specifically 10 CFR 50.36 (c)(3), and was an acceptable program for controlling changes to surveillance requirement frequencies.

Based on the above considerations, the NRC staff concludes that the proposed change is consistent with the requirements in 10 CFR 50.36 (c)(3). Therefore, the proposed change meets the first key safety principle of RG 1.177.

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 met 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).

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.

TSTF-425 requires the application of NEI 04-10 for any changes to surveillance requirement 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 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. The NRC staff concludes that both the quantitative risk analysis and the qualitative considerations assure that a reasonable balance of defense-in-depth is maintained. Therefore, the proposed change meets the second key safety principle of RG 1.177.

-7 3.1.3 The Proposed Change Maintains Sufficient Safety Margins The engineering evaluation that will be conducted by the licensee under the SFCP, when surveillance requirement frequencies are revised, will assess the impact of the proposed frequency change in accordance with the principle that sufficient safety margins are maintained.

The guidelines used for making that assessment will include ensuring the proposed surveillance test frequency change is not in conflict 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 Final Safety Analysis Report and Bases to the TSs), since these are not affected by changes to the surveillance requirement frequencies.

Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis.

Based on the above considerations, the NRC staff concludes that there is reasonable assurance that safety margins will be maintained through the use of the SFCP methodology. Therefore, the proposed change meets the third key safety principle of RG 1.177.

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 RG 1.177 provides a framework for risk evaluation of proposed changes 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 FNP 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 FNP PRA technical adequacy. RG 1.200 is NRC's developed regulatory guidance whiCh, in revision 1, endorsed with comments and qualifications the use of the American Society of Mechanical Engineers (ASME) RA-Sb-2005, "Addenda to ASME RA-S-2002 Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications," (Reference 6), NEI 00-02, "PRA Peer Review Process Guidelines," (Reference 7),

and NEI 05-04, "Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard" (Reference 8). 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 requirement frequencies of SSCs, using plant-specific data and models. Capability category II of ASME RA-Sb-2005 was

-8 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 by the use of sensitivity studies where appropriate. The NRC staff notes that in revision 2, RG 1.200 endorsed with comments and qualifications an updated combined standard which includes requirements for fire, seismic, and other external events PRA models. The existing internal events standard was subsumed into the combined standard, but the technical requirements are essentially unchanged. Since NEI 04-10 specifically identified the use of RG 1.200 Revision 1 to assess the internal events standard, the licensee's approach is reasonable and consistent with the approved methodology.

In March 2010, a peer review of the FNP internal events PRA model was conducted using the ASME/American Nuclear Society (ANS) Combined PRA Standard (Reference 11). The staff reviewed the licensee's assessment of the identified deficiencies (Table 2 of Enclosure 2 of the license amendment request) and resolution or disposition of the items for this application. The staff assessment is provided below.

IE-A5-01: A systematic review of plant systems for potential initiating events was not conducted.

The licensee identified that such a review has now been completed and documented, and the finding is considered closed pending completion of documentation.

IE-A9-01: A plant-specific review of potential precursor events has not been performed. The licensee conducted a search of its plant-specific data for signi'f!cant (non-scram) events, and concluded that there were no new initiating event precursors. The finding is considered closed pending completion of documentation.

IE-B1-01: The grouping of initiating events requires additional documentation for clarity and traceability. The licensee has included additional information in the Initiating Events documentation, and the finding is considered closed pending completion of documentation.

IE-C5-01: The initiating events frequencies are not weighted by the fraction of time the plant is at power. The licensee identified that this has been done as part of the model quantification, and the finding is considered closed pending completion of documentation.

AS-C2-02: The level of documentation for accident sequence descriptions requires improvement.

The licensee identified changes made to the documentation to address this finding, which is considered closed.

SY-A9-01: System boundary definitions do not match fault trees. The licensee identified a review and modification of system documentation to correct this finding, which is considered closed pending completion of documentation.

SY-C1-01: System notebook documentation on test and maintenance was found to have dated references. The licensee identified this as a documentation only issue, and has corrected the references. The finding is considered closed pending completion of documentation.

HR-02-01 and HR-02-02: The detailed human failure event assessments and screening for pre-initiator events were found to be deficient. The licensee resolved these issues by verifying the approaches used and confirming their applicability by detailed analysis or screening values. The finding is considered closed pending completion of documentation.

- 9 HR-G1-01: Important human reliability events were not evaluated in detail. The licensee has developed detailed evaluations, and the finding is considered closed pending completion of documentation.

HR-G7-01 and HR-G7-02: The human action dependency analysis is not consistent with the values applied during quantification, and the top combinations are not addressed. A revised dependency analysis was conducted and incorporated into the model quantification. The finding is considered closed pending completion of documentation.

HR-13-01: Sources of uncertainty are not included in the human reliability analysis documentation.

A document has been created to address uncertainty, and the finding is considered closed pending completion of documentation.

IFEV-83-01: The flooding analysis indicates that sources of uncertainty were not documented because of the low contribution to CDF and LERF from flooding. A discussion of uncertainty was incorporated into the flooding notebook and the licensee considers this finding closed pending completion of documentation.

IFPP-82-02 and IFPP-82-03: The internal flooding partitioning study does not provide the basis for elimination of areas for further analysis. The licensee identified that the basis for screening areas and building has been incorporated into the documentation, and these findings are considered closed pending completion of documentation.

IFQU-A7-01: Quantification of internal flooding does not include uncertainties or a dependency analysis. These analyses were conducted and the finding is considered closed pending completion of documentation.

IFSN-A4-0 1: While the documentation provides extensive discussion of drains as propagation paths, there is not explicit estimation of drain capacities. The licensee identified that new text regarding drain capacities has been added, and the finding is considered closed pending completion of documentation.

IFSN-83-01: There is no discussion about uncertainty. The licensee identified new text regarding uncertainty and assumptions in the internal flooding documentation. The finding is considered closed pending completion of documentation.

QU-F1-01: Mutually exclusive logic was not documented in the quantification notebook. The licensee updated the reference and the finding is considered closed pending completion of documentation.

MU-84-01: A procedural requirement for peer reviews for upgrades needs to be added. The licensee identified procedure revisions which are in progress. This deficiency requires an administrative change to assure future upgrades receive appropriate peer reviews, and has no impact on the quantitative risk calculations which are performed for surveillance frequency change evaluations.

In addition to the above findings from the peer review, the licensee also identified four supporting requirements of the internal events standard, related to the LERF model, which were found to

-10 satisfy capability category I only, but no findings were issued. These four requirements were further evaluated by the licensee and dispositioned as conservatisms in the calculation of LERF.

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 the identified deficiencies, 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 does not maintain a fire PRA model, but uses an existing fire PRA, which was completed for the Individual Plant Examination of External Events (lPEEE). Similarly, the IPEEE seismic margins analysis will be used to provide seismic insights. Other external hazards were assessed as insignificant during the IPEEE assessment. Therefore, the risk contribution from these sources will be assessed either qualitatively or by bounding analyses for evaluation of surveillance frequency changes.

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.

The licensee will perform quantitative evaluations of the impact of selected testing strategy (Le.,

staggered testing or sequential testing) consistent with the guidance of NUREG/CR-6141 and NUREG/CR-5497, as discussed in NEI 04-10.

Thus, through the application of NEI 04-10 the FNP 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.

- 11 3.1.4.4 Assumptions for Time-Related Failure Contributions The failure probabilities of SSCs modeled in the FNP 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 regard 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 its approach is consistent with Regulatory Position 2.3.4 of RG 1.177.

3.1.4.S Sensitivity and Uncertainty Analyses NEI 04-10 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 II of ASME PRA Standard ASME RA-Sb-200S. 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.S of RG 1.177.

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 criteria 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,

- 12 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-5 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-5 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 the licensee includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (less than 5E-8 CDF and 5E-9 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 NRC concludes that 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 change satisfies the fourth key safety principle of RG 1.177 by assuring that any increase in risk is small and consistent with the intent of the Commission's Safety Goal Policy Statement.

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 NRC staff concludes that 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. Therefore, the proposed change meets the fifth key safety principle of RG 1.177.

~ 13 3.2 Addition of Surveillance Frequency Control Program to Administrative Controls The proposed amendment would add the SFCP into the Administrative Controls section of the FNP TSs. Specifically, new TS 5.5.19, "Surveillance Frequency Control Program," would read as follows:

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 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 NRC staff concludes that the proposed addition to the Administrative Controls section of the TSs adequately identifies the scope of the SFCP and defines the methodology to be used in a revision of surveillance frequencies. Therefore, the proposed TS change is acceptable.

3.3 TS Bases Changes The SNC application dated October 29, 2010, provided proposed changes to the TS Bases to be implemented with the associated TS changes. These pages were provided for information only and will be revised in accordance with the FNP TS Bases Control Program.

3.4 Technical Evaluation Conclusion The NRC staff has reviewed the licensee's proposed relocation of some surveillance frequencies to a new licensee-controlled program, the SFCP, and its proposal to control changes to surveillance frequencies in accordance with the new program. Based on the above considerations, the NRC staff concludes that the proposed amendment is acceptable.

4.0 STATE CONSULTATION

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

5.0 ENVIRONMENTAL CONSIDERATION

The amendments change a requirement with respect to installation or use of a facility component located within the restricted area as defined in 10 CFR Part 20 and changes surveillance requirements. The NRC staff has determined that the amendments involve no significant increase

- 14 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 77915]. Accordingly, the amendments meet 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 Commission has concluded, based on the considerations discussed above, that (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendments will not be inimical to the common defense and security or to the health and safety of the public.

7.0 REFERENCES

1. TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative 5b," March 18, 2009 (ADAMS Accession No. ML090850642).

2. NEI 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5B, Risk-Informed Method for Control of Surveillance Frequencies," April 2007 (ADAMS Accession No. ML071360456).

3. Regulatory Guide 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking:

Technical Specifications," August 1998 (ADAMS Accession No. ML003740176).

4. Regulatory Guide 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," Revision 1, January 2007 (ADAMS Accession No. ML070240001).

5. Regulatory Guide 1.174, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant- Specific Changes to the Licensing Basis," NRC, Revision 1, November 2002 (ADAMS Accession No. ML023240437).

6. ASME PRA Standard ASME RA-Sb--2005, Addenda to ASME RA-S-2002, "Standard for Probabilistic Risk Assessment for Nuclear Power Plant Application."

7. NEI 00-02, Revision 1 "Probabilistic Risk Assessment (PRA) Peer Review Process Guidance, Revision 1, May 2006 (ADAMS Accession No. ML061510621).

8. NEI 05-04, "Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard", Revision 0, August 2006.

9. Letter, H. K. Nieh to B. Bradley, Final Safety Evaluation for Nuclear Energy Institute (NEI)

Topical Report (TR) 04-10, Revision 1, "Risk-Informed Technical Specification Initiative 5B,

- 15 Risk-Informed Method for Control of Surveillance Frequencies, (TAC No. MD6111),"

September 19, 2007 (ADAMS Accession No. ML072570267).

10. M. J. Ajluni to U. S. NRC, "License Amendment Request for Adoption of TSTF-425-A, Rev. 3, Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program Using the Consolidated Line Item Improvement Process," October 29,2010 (ADAMS Accession No. ML103140605).

11. ASME/ANS RA-Sa-2009, Addenda to ASME/ANS RA-S-2008, "Standard for Level 1 I Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications," February 2009.

12. M. J. Ajluni to U. S. NRC, "Supplement to License Amendment Request for Joseph M.

Farley Nuclear Plant and Edwin I. Hatch Nuclear Plant to Implement Technical Specification Task Force 425-A, Revision 3," February 21,2011 (ADAMS Accession No. ML110530184).

Principal Contributor: Andrew Howe, NRRlDRA Date: July 18, 2011

'.. ML11167A226 OFFICE NRRlLPL2-1/PM NRRlLPL2-1/LA OGC NRRlITSB/BC NRRlLPL2-1/BC NRR/LPL2-1/PM MO'Brien RElliot GKulesa NAME RMartin (ABaxter for) RHarper (PBoyle for) RMartin DATE 07/14/11 6129111 07/12/11 07/07/11 07/14/11 07/14/11

v t e Letter Sequence Approval
TAC:ME5055, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed) TAC:ME5056, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed)
Initiation Request Acceptance... Supplement Administration Questions Answers Results Approval Other:
MONTHYEAR2011-02-21 [Table View]

ML11167A226

Text

SUBJECT:

Dear Mr. Ajluni:

Enclosures:

Attachment:

Attachment:

3.4.7 APPLICABILITY

1.0 INTRODUCTION

2.0 REGULATORY EVALUATION

3.0 TECHNICAL EVALUATION

4.0 STATE CONSULTATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 CONCLUSION

7.0 REFERENCES

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