Text

Issuance of Amendments Regarding (TAC Nos. ME3724 and ME3725)
	ML110680357
Person / Time
Site:	Mcguire, McGuire
Issue date:	03/29/2011
From:	Jacqueline Thompson; Plant Licensing Branch 1
To:	Repko R; Duke Energy Carolinas
	Thompson, Jon 415-1119
References
	TAC ME3724, TAC ME3725
	Download: ML110680357 (142)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 March 29, 2011 Mr. Regis T. Repko Vice President McGuire Nuclear Station Duke Energy Carolinas, llC 12700 Hagers Ferry Road Huntersville, NC 28078

SUBJECT:

MCGUIRE NUCLEAR STATION, UNITS 1 AND 2, ISSUANCE OF AMENDMENTS REGARDING REVISION OF THE TECHNICAL SPECIFICATIONS TO RELOCATE SPECIFIC SURVEilLANCE FREQUENCIES TO A LICENSEE-CONTROllED PROGRAM USING A RISK-INFORMED JUSTIFICATION (TSTF-425) (TAC NOS. ME3724 AND ME3725)

Dear Mr. Repko:

The Nuclear Regulatory Commission has issued the enclosed Amendment No. 261 to Renewed Facility Operating License NPF-9 and Amendment No. 241 to Renewed Facility Operating License NPF-17 for the McGuire Nuclear Station, Units 1 and 2. The amendments consist of changes to the Technical Specifications (TSs) in response to your application dated March 24. 2010, as supplemented by letters dated November 18, 2010, and March 2, 2011.

The amendments revise the TSs by relocating specific surveillance frequencies to a licensee-controlled document using a risk-informed justification.

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.

If you have any questions, please call me at 301-415-1119.

Sincerely, Jon Thompson, Project Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-369 and 50-370

Enclosures:

1. Amendment No. 261 to NPF-9

2. Amendment No. 241 to NPF-17

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

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-369 MCGUIRE NUCLEAR STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 261 Renewed License No. NPF-9

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

A. The application for amendment to the McGuire Nuclear Station, Unit 1 (the facility),

Renewed Facility Operating License No. NPF-9, filed by the Duke Energy Carolinas, LLC (licensee), dated March 24,2010, as supplemented by letters dated November 18, 2010, and March 2, 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 as 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 set forth in 10 CFR Chapter I; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

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2. Accordingly, the license is hereby amended by page 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-9 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 261 , are hereby incorporated into this renewed operating license. The licensee 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 90 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 License No. NPF-9 and the Technical Specifications Date of Issuance: March 29, 2011

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-370 MCGUIRE NUCLEAR STATION, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 241 Renewed License No. NPF-17

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

A. The application for amendment to the McGuire Nuclear Station, Unit 2 (the facility),

Renewed Facility Operating License No. NPF-17, filed by the Duke Energy Carolinas, LLC (the licensee), dated March 24, 2010. as supplemented by letters dated November 18. 2010. and March 2. 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 as 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 Oi) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

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2. Accordingly, the license is hereby amended by page 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-17 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 241 ,are hereby incorporated into this renewed operating license. The licensee 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 90 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 License No. NPF-17 and the Technical Specifications Date of Issuance: t~arch 29, 2011

ATTACHMENT TO LICENSE AMENDMENT NO. 261 RENEWED FACILITY OPERATING LICENSE NO. NPF-9 DOCKET NO. 50-369 AND LICENSE AMENDMENT NO. 241 RENEWED FACILITY OPERATING LICENSE NO. NPF-17 DOCKET NO. 50-370 Replace the following pages of the Renewed Facility Operating Licenses and the Appendix A Technical Specifications (TSs) with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Pages Insert Pages Licenses Licenses NPF-9, page 3 NPF-9, page 3 NPF-17, page 3 NPF-17, 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 3.1.4-4 3.1.4-4 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 3.2.1-4 3.2.1-4 3.2.1-5 3.2.1-5 3.2.2-3 3.2.2-3 3.2.2-4 3.2.2-4 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

-2 Remove Pages Insert Pages 3.3.1-11 3.3.1-11 3.3.1-12 3.3.1-12 3.3.1-13 3.3.1-13 3.3.2-8 3.3.2-8 3.3.2-9 3.3.2-9 3.3.3-3 3.3.3-3 3.3.4.2 3.3.4.2 3.3.5-2 3.3.5-2 3.4.1-3 3.4.1-3 3.4.3-2 3.4.3-2 3.4.4-1 3.4.4-1 3.4.5-3 3.4.5-3 3.4.6-2 3.4.6-2 3.4.7-3 3.4.7-3 3.4.8-2 3.4.8-2 3.4.9-2 3.4.9-2 3.4.11-4 3.4.11-4 3.4.12-5 3.4.12-5 3.4.12-6 3.4.12-6 3.4.13-2 3.4.13-2 3.4.14-3 3.4.14-3 3.4.14-4 3.4.14-4 3.4.15-4 3.4.15-4 3.4.16-2 3.4.16-2 3.4.16-3 3.4.16-3 3.4.17-1 3.4.17-1 3.5.1-2 3.5.1-2 3.5.2-2 3.5.2-2 3.5.2-3 3.5.2-3 3.5.4-2 3.5.4-2 3.5.5-2 3.5.5-2 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 3.6.5-2 3.6.5-2 3.6.6-1 3.6.6-1

- 3 Remove Pages Insert Pages 3.6.6-2 3.6.6-2 3.6.8-2 3.6.8-2 3.6.9-2 3.6.9-2 3.6.10-2 3.6.10-2 3.6.11-1 3.6.11-1 3.6.11-2 3.6.11-2 3.6.12-1 3.6.12-1 3.6.12-2 3.6.12-2 3.6.12-3 3.6.12-3 3.6.13-2 3.6.13-2 3.6.13-3 3.6.13-3 3.6.14-2 3.6.14-2 3.6.14-3 3.6.14-3 3.6.15-2 3.6.15-2 3.6.16-1 3.6.16-1 3.6.16-2 3.6.16-2 3.7.4-2 3.7.4-2 3.7.5-3 3.7.5-3 3.7.5-4 3.7.5-4 3.7.6-2 3.7.6-2 3.7.7-2 3.7.7-2 3.7.8-1 3.7.8-1 3.7.8-2 3.7.8-2 3.7.9-3 3.7.9-3 3.7.10-2 3.7.10-2 3.7.11-2 3.7.11-2 3.7.12-1 3.7.12-1 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 3.8.1-5 3.8.1-5 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

-4 Remove Pages Insert Pages 3.8.1-11 3,8.1-11 3.8.1-12 3.8.1-12 3.8.1-13 3.8.1-13 3.8.1-14 3.8.1-14 3.8.1-15 3.8.1-15 3,8.3-3 3.8.3-3 3.8.4-2 3.8.4-2 3.8.4-3 3.8.4-3 3.8.6-2 3.8,6-2 3.8.6-3 3.8.6-3 3.8.7-1 3.8.7-1 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 3.9.2-1 3.9.2-1 3.9.3-2 3.9.3-2 3.9.4-2 3.9.4-2 3.9.5-2 3.9.5-2 3.9.6-2 3.9.6-2 3.9.7-1 3.9.7-1 5.5-15 5.5-15 5.5-16

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. (4; Pursuant to the Act and 1D CFR Part5 30. 4D and 71>. " l'VCeiYe*. PONess and U50 In amounts as requlnld I1Irt byPlOducl, source Of spedllll'll..lC:t8ar rna",".' without I'8s*1Ion to chernlcel or physical form, tot sampllt lnalysis or InItrum.nt callbrltlOn or associated wtth rBdloactMJ appaI'8U or components; (5) PUI'Iuant to the Act and 10 CFR Par1s 30,40 and 70. to PQllOIs. but not nparat** such bypoducts and IIt*lal ru;;lear IT8Ierials as may be produced by the operalbn of McGUre Nuclear Slalion, Unit& rand 2' and'

* ' I (8) Pursuant to the Act and 10 CFR Parts JOand 40: to receMt, po$ses~ and procell for relene or traMfer IUC:h byproduct malenal n may be Produced by the Duke Training IflCf TechnolDVy Center.

C. Thl$ renewed operating liceose shell be deemed'to contain and is sub)ect to. the ,

condltJonl specified In the Commlsslon'l regulltlons set fof1h In 10 CFR Chapter I and II aubjec t to all applcable provisions of the Act and to the Nlel.

or regula1lons, and ordlm of the Commlallon now hereafter i1 effect; and Is

~ject to the addillonal concIltJons'lJ)edned or incorporailltd below:

(1 ) Maximum power Level The licensee Is authoriDtd to opef8ta the facinly at a reaGtor core full

$Ieady atate power level of 3411 meg8WItll thermll (100%).

(2) Tect1ngl Spec~'9!tions The Technlc;al SfW'lCltlcations contained in Appendlx'A, as revIsed throublh Amendment No. 261

are hereby tneorporated Into this reneMd operating bnse. Ttle Ilcensoe shall ()I:)erate !he ,&cUhy In accordanee with the Technical Spe<;lftcatlcos.

(3) !.Jgtod Final Safety AnalYSis Report

,The Updated Final Safety Al"IIIlyIl. Report supplement eubmitted ~u.nt to 10 CFR 54.21(d). 1$ ",vISed on OoQombor 1U, 2002, dlhtcr1bn cert.ltln futuro actlvitiaalo be completed before tna pertod ofax1endecJ QPe.-.tkln.

Duke shull complete the" ~Iv._ no lator 'han Juno 12, 2021. and aMI notify the NRC In wrtllng wl"te" Implementation of these ect/vltiells complole and can be verilled by N~C inspucUon.

The Updated Final Safety Analysls'Ropon supP'ement III reviled On December 18,2002, described above, IShall boo included In the next scheduled upda1e to the Updated Final Safety Analysla Repot1 required by 10 CFR ~.71{e)(4). following issuance of thl$ renewed ooerallng Dcense.

Until thai update Is complete, Duke may make cI'w.I~ 1.0 the prggrams dellcribed in such aupt:Jlement wtthout prior Commission approve!, provided thaI Duke evalUEJtes each such change pursuant to the oitena set forth In 10 eFR 50.59 aiid olhcrwlGo compli03 witllhe l'e(lulramonlD In thO!

sectiOn.

Renewed Llcenae No. NPF-9 Amendment No. 261

(4) Pur:auant 10 the Act and 10 CFR Parta 30,40 and 7~,.IO ftICOIve, ponesll and ule In amoun.. al required' any byproduct, 'Ollrce or IIP'IC'al nucllrer matertel withOut rettrtctIon to chemteal or phyak:aJ farm, for umpre .nalYlllI or Il"IIlrUment celHaUon or assocl8ted wtth radioactlve 8J)PIl'ltus or components; (5) P\nuant to the Act and 10 CF'R FJ.m 30, 40 and 70, to pos.... but riot sapllTate, such byproducts anltIJpeclal nuelear materlall as lJ&f be produced by tho operation of McGuire Nuolear Station, Unita , and 2: Ind, (6) Pursuant to the Act and 10 CFR1'at'I:I 30 and 40, to receive, poss8lsand pl'OCeSl for release or transfer such byproduct materie, 81 may be prodUced by the Duke Tl'llning .ncr Technology Center.

C. This renewed operltl"9 lICenSe shaU be deemed to contain and Is subject to the condltlonl Ipec:lfled In 1M Commlllilon'a regulatlonl leI for1h h 10 CFR Chapter I and IllUbject to 811 applicable provlslonl of tho Act and to tho rvkn, regulatIOns, and orders of the COmmission now or hereafter In err8Ct; Ind Is lubJect to the addlUonal ealdltlons Ipeeifiod or Incorporated below:

(1 ) M,xi,wum PO'tIISZ[ Level The licensee Is authorized to optJrute the facitity at a redr core full steady stale power tevel of 3411 megawaftS thermal (100%).

(2) Ieclmleal SpplcaVOO8

. The Toc:hnlc:al SPAdl\r.aVOns (X)ntained In Appendix A, as revised through AlMndment No. 241, !Ire hereby Incorpora ted Into this nJneMJd operattng license. ,I ne licensee lhall Operate the fBcflty In accordance with the Technical ~pecW'lC8t1o.nS. .

(3) Updated Final ~fety Ana"",', Repor1 The Updat~ Final Safety.AnaIysI. Report $upplemenl aubrnlned pUrsuant to 10 CFR 54.21(d), liS revb~ on December U~,2002, de'Otibn certain future actMilelt to be completed bofo.., Yle period Of ~nded CIPtInttion.

Duke ,han comptatelheaa actlvllles no late( than MarCh 3.2023. and shall notIfy the NRC 10 wrIting wlwn imphrmentatlon 01 ct.... actlvltle. i.

ccmplete and can be verlllvd P)I NRC InlJpectlon.

TN Updated Flnel ~afety Anal)'lr. Repon lupplement a, revl.od On December 18, 2002. described 4ibow, .".n be Included In tt. neXf scheduled updare to the Updated Fi1u/ Sefely Ana~is Repor1lVqullVd by 10 CFR 50.11(eX4), following lI,uan<:e of this rvnowed op8l'lllng lICente.

Until tl"iet update Is complete, Duke may make chlnges to 1M prggralTll described In suCh lIuppiement without prior Commlaalo'n approval, provided that Duke evalvlltes eaen ItJch chenge pursuant to 1he criteria let for1h In 10 CFR 50,59, and otherwls. Compile, with the requlremen15 in that section.

Re"j,wed lk::onse Nc. NPF.11

. AmvndmentNo.241

Definitions 1.1 1.1 Definitions (continued)

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

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

McGuire Units 1 and 2 Amendment Nos. 261, 241

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

LCO 3.1.1 SDM shall be within the limit specified in the COLR.

APPLICABILITY: MODE 2 with kef!" < 1.0, MODES 3, 4, and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore 15 minutes SDM to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM is within the limit specified in the COLR. In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.1.1-1 Amendment Nos. 261, 241

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 burnup of 60 effective full power days (EFPD) after each fuel loading.

Verify measured core reactivity is within +/- 1% Aklk of Once prior to predicted values. entering MODE 1 after each refueling In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.1.2-2 Amendment Nos. 261, 241

Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

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 B not met.

D. More than one rod not 0.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within alignment limit. limit specified in the COLR.

OR 0.1.2 Initiate boration to restore required SDM to within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months limit.

AND 0.2 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment limit. In accordance with the Surveillance Frequency Control Program Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod position deviation monitor is inoperable (continued)

McGuire Units 1 and 2 3.1.4-3 Amendment Nos. 261, 241

Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY In accordance with SR 3.1.4.2 Verify rod freedom of movement (trippability) by moving the Surveillance each rod not fully inserted in the core?: 10 steps in either Frequency Control direction. Program SR 3.1.4.3 Verify rod drop time of each rod, from the fully withdrawn Prior to reactor position, is ~ 2.2 seconds from the beginning of decay of criticality after stationary gripper coil voltage to dashpot entry, with: each removal of the reactor head

a. TaY9?: 551"F; and

b. All reactor coolant pumps operating.

McGuire Units 1 and 2 3.1.4-4 Amendment Nos. 261, 241

Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the limits specified in In accordance with the COLR. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.1.5-2 Amendment Nos. 261, 241

Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.6.2 Verify each control bank insertion is within the limits In accordance with specified in the COLR. the SUlveiliance Frequency Control Program Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod insertion limit monitor is inoperable SR 3.1.6.3 Verify sequence and overlap limits specified in the COLR In accordance with are met for control banks not fully withdrawn from the the Surveillance core. Frequency Control Program McGuire Units 1 and 2 3.1.6-3 Amendment Nos. 261, 241

PHYSICS TESTS Exceptions 3.1.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME 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 OPERATIONAL TEST on power Prior to initiation of range and intermediate range channels per SR 3.3.1.7, PHYSICS TESTS 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

~541°F. the Surveillance Frequency Control Program SR 3.1.8.3 Verify THERMAL POWER is ~ 5% RTP. In accordance with the Surveillance Frequency Control Program SR 3.1.8.4 Verify SDM is within the limit specified in the COLR. In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.1.8-2 Amendment Nos. 261, 241

FQ(X,Y,Z) 3.2.1 SURVEILLANCE REQUIREMENTS

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

During power escalation at the beginning of each cycle, THERMAL POWER may be 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 F~(X, Y,Z) is within steady state limit. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by

.:::.10% RTP, the THERMAL POWER at which FMO(X,Y,Z) was last verified In accordance with the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.2.1-3 Amendment Nos. 261, 241

FQ(X,Y,Z) 3.2.1 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.2.1.2 ------------------------NOTE-------------------------------

1. Extrapolate FMO(X,Y,Z) using at least two measurements to 31 EFPD beyond the most recent measurement. If F~(X,Y,Z) is within limits and the 31 EFPD extrapolation indicates:

F't(X,Y,Z)EXTRAPOLATED > F~(X,y.Z)OP EXTRAPOLATED, and EMdX,Y.Z)e.)(TRAPOLATED > EMo(X,Y,Z)

F~(X,y,Z)OPEXTRAPOlATED F~(X,Y,Z)OP then:

a. Increase F~(X,Y,Z) by the appropriate factor specified in the COLR and reverify FMO(X,Y,Z) .s F~(X,Y,Z)oP; or

b. Repeat SR 3.2.1.2 prior to the time at which F~(X,y,Z).s Fil(X,Y,Z)oP is extrapolated to not be met.

2. Extrapolation of FMO(X,Y,Z) is not required for the initial flux map taken after reaching equilibrium conditions.

Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving i.

equilibrium conditions !

after exceeding, by.:::.

10% RTP, the THERMAL POWER at which F't{X,Y,Z) was fast verified In accordance with the Surveillance Frequency Control Pro ram (continued)

McGuire Units 1 and 2 3.2.1-4 Amendment Nos. 261, 241

FQ(X,Y,Z) 3.2.1 SURVEILLANCE FREQUENCY SR 3.2.1.3 ---------------------------NOTES------------------------

i. Extrapolate F~(X,Y,Z) using at least two measurements to 31 EFPD beyond the most recent measurement. If F~(X,Y,Z} is within limits and the 31 EFPD extrapolation indicates:

F~(X, Y,Z}EXTRAPOLATED .? F~(X. Y,Z}RPSEXTRAPOLATED, and E~(X,y,ZlExTRAPOLATED > E~(X,Y,Z)

F~(X,y,Z}RPSEXTRAPOLATED F~(X. Y,ztPs then:

a. Increase FMo(X,Y,Z) by the appropriate factor specified in the COLR and reverify F~(X,y.Z) ~ F~(X,Y,Z)RPS; or

b. Repeat SR 3.2.1.3 prior to the time at which FMQ(X,Y,Z) ~ F~(X,y,Z)RPS is extrapolated to not be met.

2. Extrapolation of F~(X,Y.Z) is not required for the initial flux map taken after reaching equilibrium conditions.

Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by .?

10% RTP, the THERMAL POWER at which F~(X,Y,Z} was last verified In accordance with the Surveillance Frequency Control Pr ram McGuire Units 1 and 2 3.2.1-5 Amendment Nos. 261, 241

F"H(X,Y) 3.2.2 SURVEILLANCE REQUIREMENTS

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

During power escalation at the beginning of each cycle. THERMAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained.

SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify F~H(X, Y) is within steady state limit. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by ~

10% RTP, the THERMAL POWER at which FMt,H(X,Y) was last verified In accordance with the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.2.2-3 Amendment Nos. 261, 241

F6H (X,Y) 3.2.2 SURVEILLANCE FREQUENCY SR 3.2.2.2 -----------------------------NOTE S-----------------------------

1. Extrapolate F~H(X, Y) using at least two measurements to 31 EFPD beyond the most recent measurement. If F~H(X,Y) is within limits and the 31 EFPD extrapolation indicates:

and EM6~EXTRAPOLATED > EM6~

F~H(X,Y)SURVEXTRAPOLATED F~H(X,y)SURV then:

a. Increase F~H (X,Y) by the appropriate factor specified in the COLR and reverify FM6H (X,Y).;s, F~H (X,y)SURV; or

b. Repeat SR 3.2.2.2 prior to the time at which FM6H (X, Y) .;s, F~H (X, y)SURV is extrapolated to not be met.

2. Extrapolation of F~H (X,Y) is not required for the initial flux map taken after reaching equilibrium conditions.

Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equilibrium conditions after exceeding, by ~

10% RTP, the THERMAL POWER at which F~H (X, Y) was last verified In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.2.2-4 Amendment Nos. 261, 241

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 Once with in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and every 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months thereafter with the AFD monitor alarm inoperable McGuire Units 1 and 2 3.2.3-1 Amendment Nos. 261, 241

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4. 1 ---------------------------NaTES----------------------------

1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER

<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 Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter with the QPTR alarm inoperable SR 3.2.4.2 ------------------------NaTES-----------------------------

Only required to be performed if input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER> 75% RTP.

Verify QPTR is within limit using the movable incore In accordance with detectors. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.2.4-4 Amendment Nos. 261, 241

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

1. Adjust NIS channel if absolute difference is > 2%

RTP.

2. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER is 2: 15% RTP.

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

1. Adjust NIS channel if absolute difference is > 3%

AFD.

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 2: 15% RTP.

Compare results of the incore detector measurements to In accordance with NISAFD. the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.3.1-9 Amend ment Nos. 261, 241

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS continued)

SURVEILLANCE FREQUENCY SR 3.3.1.4 -----------------------NOTES------------------------------

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 Pro ram SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control i Pro ram SR 3.3.1.6 ------------------------NOTES--------------------

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 ~ 75% RTP.

Calibrate excore channels to agree with incore detector In accordance with measurements. the Surveillance Frequency Control Pro ram SR 3.3.1.7 ------------.:.--NOTES-----------------------

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 Pro ram (continued)

McGuire Units 1 and 2 3.3.1-10 Amendment Nos. 261, 241

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS continued)

SURVEILLANCE FREQUENCY SR 3.3.1.8 -----------------------NOTES-----------------------------

This Surveillance shall include verification that interlocks P-6 (for the Intermediate Range channels) and P-10 (for the Power Range channels) are in their required state for existing unit conditions.

Perform COT. --------NOTE-----

Only required when not performed within the Frequency specified in the Surveillance Frequency Control Program or previous 184 days Prior to reactor startup Four hours after reducing power below P-10 for power and intermediate range instrumentation Four hours after reducing power below P-6 for source range instrumentation In accordance with the Surveillance Frequency Control Pro ram (continued)

McGuire Units 1 and 2 3.3.1-11 Amendment Nos. 261, 241

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.9 -----------------------NOTES-----------------------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1 0 ---------------------------NOTES-------------------------------

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 3.3.1.11 -----------------------NOTES--------------------------

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. Power Range Neutron Flux high voltage detector saturation curve verification is not required to be performed prior to entry into MODE 1 or 2.

3. Intermediate Range Neutron Flux detector plateau voltage verification is not required to be performed prior to entry into MODE 1 or 2.* In accordance with the Surveillance Frequency Control Perform CHANNEL CALIBRATION. Program SR 3.3.1.12 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program (continued)

This note applies to the Westinghouse-supplied compensated ion chamber neutron detectors. The compensated ion chamber neutron detectors are being replaced with Thermo Scientific-supplied fission chamber neutron detectors which do not require detector plateau voltage verification. Therefore, this note does not apply to the fission chamber neutron detectors.

McGuire Units 1 and 2 3.3.1-12 Amendment Nos. 261, 241

RTS Instrumentation 3.3.1 SURVEILLANCE FREQUENCY SR 3.3.1.13 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.14 --------------------------NOTES------------------------

Verification of setpoint is not required.

Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.15 ---------------------NOTES------------------ -----NOTE-----

Verification of setpoint is not required. Only required when not performed within previous 31 days Perform TADOT. Prior to reactor startup SR 3.3.1.16 -------------------------NOTES----------------------

Neutron detectors are excluded from response time testing.

Verify RTS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program SR 3.3.1.17 Verify RTS RESPONSE TIME for RTDs is within limits. In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.3.1-13 Amendment Nos. 261, 241

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.2.1 Periorm CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2 Periorm ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.3 Periorm COT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.4 Periorm MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.5 Periorm COT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.6 Periorm SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.7 ------------------------NOTE-----------------------

Verification of setpoint not required for manual initiation functions.

.-------------------------------~---------------

Periorm TADOT. In accordance with the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.3.2-8 Amendment Nos. 261, 241

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2. 8 -------------------------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. 3.2.9 ---------------------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 SG pressure is .::: 900 psig.

Verify ESFAS RESPONSE TIMES are within limit. In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.3.2-9 Amendment Nos. 261, 241

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

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

SR 3.3.3.1 and SR 3.3.3.3 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 Not Used Not Used SR 3.3.3.3 ------------------NOTE---------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.3.3-3 Amendment Nos. 261, 241

Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3 1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized. the Surveillance Frequency Control Program SR 3.3.4.2 Verify each required control circuit and transfer switch is In accordance with capable of performing the intended function. the Surveillance Frequency Control Program SR 3.3.4.3 Perform CHANNEL CALIBRATION for each required In accordance with instrumentation channel. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.3.4.2 Amendment Nos. 261, 241

LOP DG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2 -----------------------NOTE------------------------

A NOMINALTRIP SETPOINT associated with this SR shall be set within the channel's calibartion tolerance band.

Perform CHANNEL CALIBRATION with NOMINAL TRIP In accordance with SETPOINT and Allowable Value as follows: the Surveillance Frequency Control

a. Loss of voltage Allowable Value?: 3122 V (Unit Program

1) 3108 V (Unit 2) with a time delay of 8.5 +/- 0.5 second.

Loss of voltage NOMINAL TRIP SETPOINT 3174 V (Unit 1) 3157 V (Unit 2) +/- 45 V with a time delay of 8.5 +/- 0.5 second.

b. Degraded voltage Allowable Value> 3661 V (Unit

1) ?: 3685.5 V (Unit 2) with a time delay of:::: 11 seconds with SI and < 600 seconds without SI.

Degraded voltage NOMINAL TRIP SETPOINT 3678.5 V (Unit 1) 3703 V (Unit 2) with a time delay of:::: 11 seconds with SI and:::: 600 seconds without S\.

McGuire Units 1 and 2 3.3.5-2 Amendment Nos. 261, 241

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is within limits. In accordance with the Surveillance Frequency Control Program SR 3.4.1.2 Verify RCS average temperature is within limits. In accordance with the Surveillance Frequency Control Program SR 3.4.1.3 Verify RCS total flow rate is within limits. In accordance with the Surveillance Frequency Control Program SR 3.4.1.4 Perform CHANNEL CALIBRATION for each RCS total In accordance with flow indicator. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.4.1-3 Amendment Nos. 261, 241

RCS Pff Limits 3.4.3 ACTIONS (continued)

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

whenever this Condition is entered. AND C.2 Determine RCS is Prior to entering Requirements of LCO acceptable for continued MODE 4 not met any time in other operation.

than MODE 1,2,3, or 4.

,t* .

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ------------------NOTE-------------------

Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.

Verify RCS pressure, RCS temperature, and RCS heatup In accordance with and cooldown rates are within limits. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.4.3-2 Amendment Nos. 261, 241

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 Four RCS loops shall be OPERABLE and in operation.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months not 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 McGuire Units 1 and 2 3.4.4-1 Amendment Nos. 261, 241

RCS Loops - MODE 3 3.4.5 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 are In accordance with

~ 12% narrow range for required RCS loops. the Surveillance Frequency Control Pro~ram SR 3.4.5.3 Verify correct breaker alignment and indicated power are In accordance with available to the required pumps that are not in operation. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.4.5-3 Amendment Nos. 261, 241

RCS Loops - MODE 4 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One RHR loop B.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE.

AND ALL RCS loops inoperable.

C. Both required RCS or C.1 Suspend operations that Immediately RHR loops inoperable. would cause introduction of coolant into the RCS with OR boron concentration less than required to meet the No RCS or RHR loop in SDM of LCO 3.1.1 and operation. maintain Keff < 0.99, AND C.2 Initiate action to restore Immediately one loop to OPERABLE status and operation.

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 ~ 12% narrow In accordance with range for required RCS loops. the Surveillance Frequency Control

Program SR 3.4.6.3 Verify correct breaker alignment and indicated power are In accordance with available to the required pump that is not in operation. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.4.6-2 Amendment Nos. 261, 241

RCS Loops - MODE 5, Loops Filled 3.4.7 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.::: 12% narrow In accordance with range in required SGs. the Surveillance Frequency Control Program SR 3.4.7.3 Verify correct breaker alignment and indicated power are In accordance with available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program McGuire Units 1 and 2 3.4.7-3 Amendment Nos. 261, 241

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

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

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 are In accordance with available to the required RHR pump that is not in the Surveillance operation. Frequency Control Program McGuire Units 1 and 2 3.4.8-2 Amendment Nos. 261, 241

Pressurizer 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUEI\JCY SR 3.4.9.1 Verify pressurizer water level is < 92% (1600 fe). 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 .::: 150 kW. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.4.9-2 Amendment Nos. 261, 241

Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 --------------------------NOTE---------------------------------

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

Perform a complete cycle of each block valve. In accordance with the Surveillance Frequency Control Program SR 3.4.11.2 ---------------------------NOTE------------------------------

Required to be performed in MODE 3 or MODE 4 when the temperature of all RCS cold legs is > 300°F and the block valve closed.

,r'1 .

Perform a complete cycle of each PORV. In accordance with the Surveillance Frequency Control '. !

Program SR 3.4.11.3 Verify the nitrogen supply for each PORV is OPERABLE In accordance with by: the Surveillance Frequency Control

a. Manually transferring motive power from the air Program supply to the nitrogen supply,

b. Isolating and venting the air supply, and

c. Operating the PORV through one complete cycle.

McGuire Units 1 and 2 3.4.11-4 Amendment Nos. 261, 241

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of one centrifugal charging pump or In accordance with one safety injection pump is capable of injecting into the the Surveillance RCS. 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 when the In accordance with RHR suction relief valve is used for overpressure the Surveillance protection. 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.::: 2.75 square inches open. In accordance with the Surveillance Frequency Control Program SR 3.4.12.5 Verify PORV block valve is open for each required In accordance with PORV. the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.4.12-5 Amendment Nos. 261, 241

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12. 6 ----------------------NOTE----------------------------

Not required to be met until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing RCS cold leg temperature to ~ 300°F.

Perform a COT on each required PORV. excluding In accordance with actuation. the Surveillance Frequency Control Program SR 3.4.12.7 Perform CHANNEL CALIBRATION for each required In accordance with PORV actuation channel. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.4.12-6 Amendment Nos. 261! 241

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

Only required to

1. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after be performed establishment of steady state operation. during steady state operation

2. Not applicable to primary to secondary LEAKAGE.

Verify Res Operational LEAKAGE is within limits by In accordance with performance of RCS water inventory balance. ! the Surveillance I Frequency Control Pro ram 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 ~ 135 gallons In accordance with per day through anyone SG and ~ 389 gallons per day the Surveillance total through all SGs. Frequency Control Pro ram McGuire Units 1 and 2 3.4.13-2 Amendment Nos. 261, 241

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

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 ~ 0.5 In accordance with gpm per nominal inch of valve size up to a maximum of 5 the Inservice gpm at an RCS pressure ~ 2215 psig and ~ 2255 psig. Testing Program, and in accordance with the Surveillance Frequency Control Program Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to automatic or manual action or flow through the valve (continued)

McGuire Units 1 and 2 3.4.14-3 Amendment Nos. 261, 241

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS {continued}

SURVEILLANCE FREQUENCY SR 3.4.14.2 Verify RHR system interlock prevents the valves from In accordance with being opened with a simulated or actual RCS pressure the Surveillance signal?:: 425 pSig. Frequency Control Program McGuire Units 1 and 2 3.4.14-4 Amendment Nos. 261, 241

RCS Leakage Detection instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the containment In accordance with atmosphere particulate radioactivity monitor. the Surveillance Frequency Control Program SR 3.4.15.2 Perform COT of the containment atmosphere particulate In accordance with radioactivity monitor. the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the containment In accordance with floor and equipment sump level monitors. the Surveillance Frequency Control Program SR 3.4.15.4 Perform CHANNEL CALIBRATION of the containment In accordance with atmosphere particulate radioactivity monitor. the Surveillance Frequency Control Program SR 3.4.15.5 Perform CHANNEL CALIBRATION of the containment In accordance with ventilation unit condensate drain tank level monitor. the Surveillance Frequency Control Program SR 3.4.15.6 Perform CHANNEL CALI BRATION of the incore In accordance with instrument sump level alarm. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.4.15-4 Amendment Nos. 261, 241

RCS Specific Activity 3.4.16 ACTIONS (continued)

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 < 500°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 ~ 100iE In accordance with f,lCi/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 specific In accordance with activity ::: 1.0 jJCi/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 of.:::, 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period (continued)

McGuire Units 1 and 2 3.4.16-2 Amendment Nos. 261, 241

RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS continued)

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 Efrom a sample taken in MODE 1 after a In accordance with minimum of 2 effective full power days and 20 days of the Surveillance MODE 1 operation have elapsed since the reactor was Frequency Control last subcritical for.::: 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Program McGuire Units 1 and 2 3.4.16-3 Amendment Nos. 261, 241

/

RCS Loops - Test Exceptions 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 RCS Loops- Test Exceptions LCO 3.4.17 The requirements of LCO 3.4.4, "RCS Loops-IVIODES 1 and 2," may be suspended, with THERMAL POWER < P-7.

APPLICABILITY: MODES 1 and 2 during startup and PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A, THERMAL POWER ~ A,1 Open reactor trip breakers. Immediately P-7.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify THERMAL POWER is < P-7. In accordance with the Surveillance Frequency Control Program SR 3.4.17.2 Perform a COT for each power range neutron flux-low Prior to initiation of and intermediate range neutron flux channel and P-7. startup and PHYSICS TESTS McGuire Units 1 and 2 3.4.17-1 Amendment Nos. 261,241

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

.:: 6870 gallons and.::: 7342 gallons. the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each accumulator is In accordance with

.:: 585 psig and.::: 639 psig. the Surveillance Frequency Control Program SR 3.5.1.4 Verify boron concentration in each accumulator is within In accordance with the limits specified in the COLR. the Surveillance Frequency Control Program AND

NOTE-----"

Only required to be performed 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.:: 1%

of tank volume 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 isolation In accordance with valve operator when RCS pressure is > 1000 psig. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.5.1-2 Amendment Nos. 261, 241

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position with In accordance with power to the valve operator removed. the Surveillance Frequency Control Number Position Function Program NI162A Open SI Cold Leg Injection NI121A Closed SI Hot Leg Injection NI1528 Closed SI Hot Leg Injection NI1838 Closed RHR Hot Leg Injection NI173A Open RHR Cold Leg Injection NI1788 Open RHR Cold Leg Injection NI1008 Open SI Pump RWST Suction FW27A Open RHR/RWST Suction NI147A Open SIPump Mini-Flow 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 correct Frequency Control position. Program SR 3.5.2.3 Verify ECCS piping is full of water. In accordance with the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.5.2-2 Amendment Nos. 261, 241

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.4 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 3.5.2.5 Verify each ECCS automatic valve in the flow path that is In accordance with not locked, sealed, or otherwise secured in position, the Surveillance actuates to the correct position on an actual or simulated Frequency Control actuation signal. Program SR 3.5.2.6 Verify each ECCS pump starts automatically on an actual In accordance with or simulated actuation signal. the Surveillance Frequency Control Program SR 3.5.2.7 Verify, for each ECCS throttle valve listed below, each In accordance with position stop is in the correct position. the Surveillance Frequency Control Centrifugal Charging Safety Injection Program Pump Injection Throttle Pump Throttle Valve Number Valve Number NI480 NI488 NI481 NI489 NI482 NI490 NI483 NI491 SR 3.5.2.8 Verify, by visual inspection, that the ECCS containment In accordance with sump strainer assembly and the associated enclosure are the Surveillance not restricted by debris and show no evidence of structural Frequency Control distress or abnormal corrosion. Program McGuire Units 1 and 2 3.5.2-3 Amendment Nos. 261. 241

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify RWST borated water temperature is ~ 70°F and In accordance with

< 100°F. the Surveillance Frequency Control Program SR 3.5.4.2 Verify RWST borated water volume is > 372,100 gallons. In accordance with the Surveillance Frequency Control Program SR 3.5.4.3 Verify RWST boron concentration is within the limits In accordance with specified in the COLR. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.5.4-2 Amendment Nos. 261, 241

Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 --------------------------NOTE------------------------

Not required to be performed 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.::: 2255 psig.

Verify manual seal injection throttle valves are adjusted to In accordance with give a flow within limit with centrifugal charging pump the Surveillance operating and the charging flow control valve full open. Frequency Control Program McGuire Units 1 and 2 3.5.5-2 Amendment Nos. 261, 241

Containment Air Locks 3.6.2 ACTIONS (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 ------------------------------NOTE----------------------

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 Testing the Containment Program. Leakage Rate Testing Program.

SR 3.6.2.2 Perform a pressure test on each inflatable air lock door In accordance with seal and verify door seal leakage is < 15 sccm. the Surveillance Frequency Control ProQram SR 3.6.2.3 Verify only one door in the air lock can be opened at a In accordance with time. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.6.2-5 Amendment Nos. 261, 241

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each containment purge supply and exhaust valve In accordance with for the lower compartment, upper compartment, and the Surveillance incore instrument room is sealed closed, except for one Frequency Control purge valve in a penetration flow path while in Condition Program E of this LCO.

SR 3.6.3.2 Not Used.

SR 3.6.3.3 ---------------------NOTE------------------

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

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

(continued)

McGuire Units 1 and 2 3.6.3-5 Amendment Nos. 261, 241

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6. 3.4 ------------------------NOTE-------------------------

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

Verify each containment isolation manual valve and blind Prior to entering flange that is located inside containment or annulus and MODE 4 from not locked, sealed, or otherwise secured and required to MODE 5 if not be closed during accident conditions is closed, except for performed within containment isolation valves that are open under the previous administrative controls. 92 days SR 3.6.3.5 Verify the isolation time of automatic power operated In accordance with containment isolation valve is within limits. the Inservice Testing Program In accordance with SR 3.6.3.6 Perform leakage rate testing for containment purge lower the Containment and upper compartment and incore Instrument room Leakage Rate valves with resilient seals. Testing Program SR 3.6.3.7 Verify each automatic containment isolation valve that is In accordance with not locked, sealed or otherwise secured in position, the Surveillance actuates to the isolation position on an actual or Frequency control simulated actuation signal. Program (continued)

McGuire Units 1 and 2 3.6.3-6 Amendment Nos. 261. 241

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be 2: -0.3 psig and::::; +0.3 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 8.2 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 3.6.4.1 Verify containment pressure is within limits. In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.6.4-1 Amendment Nos. 261, 241

Containment Air Temperature 3.6.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment upper compartment average air In accordance with temperature is within limits. the Surveillance Frequency Control Program SR 3.6.5.2 Verify containment lower compartment average air In accordance with temperature is within limits. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.6.5-2 Amendment Nos. 261, 241

Containment Spray System 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray System LCO 3.6.6 Two containment spray trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One containment spray A.1 Restore containment spray 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train inoperable. train to OPERABLE status.

B. Required Action and 8.1 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 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power operated, In accordance with and automatic valve in the flow path that is not locked, the Surveillance sealed, or otherwise secured in position is in the correct Frequency Control position. Program

( continued)

McGuire Units 1 and 2 3.6.6-1 Amendment Nos. 261, 241

Containment Spray System 3.6.6 SURVEILLANCE FREQUENCY SR 3.6.6.2 Verify each containment spray pump's developed head at In accordance with the flow test point is greater than or equal to the required the Inservice developed head. Testing Program SR 3.6.6.3 Verify each automatic containment spray valve in the flow In accordance with path that is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual or Frequency Control simulated actuation signal. Program SR 3.6.6.4 Verify each containment spray pump starts automatically In accordance with on an actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3.6.6.5 Verify that each spray pump is de-energized and In accordance with prevented from starting upon receipt of a terminate signal the Surveillance and is allowed to start upon receipt of a start permissive Frequency Control from the Containment Pressure Control System (CPCS). Program SR 3.6.6.6 Verify that each spray pump discharge valve closes or is In accordance with prevented from opening upon receipt of a terminate the Surveillance signal and is allowed to open upon receipt of a start Frequency Control permissive from the Containment Pressure Control Program System (CPCS).

SR 3.6.6.7 Verify each spray nozzle is unobstructed. Following activities which could result in nozzle blockage McGuire Units 1 and 2 3.6.6-2 Amendment Nos. 261, 241

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Operate each HSS train for ~ 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3.6.8.2 Verify the fan motor current is :s; 21.5 amps when the fan In accordance with speed is ~ 3579 rpm and :s; 3619 rpm with the hydrogen the Surveillance skimmer fan operating and the motor operated suction Frequency Control valve closed.

Program SR 3.6.8.3 Verify the motor operated suction valve opens In accordance with automatically and the hydrogen skimmer fans receive a the Surveillance start permissive signal from the Containment Pressure Frequency Control Control System. Program SR 3.6.8.4 Verify each HSS train starts on an actual or simulated In accordance with actuation signal after a delay of~ 8 minutes and:s; 10 the Surveillance minutes. Frequency Control Program McGuire Units 1 and 2 3.6.8-2 Amendment Nos. 261, 241

HMS 3.6.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Energize each HMS train power supply breaker and In accordance with verify;;:: 34 ignitors are energized in each train. the Surveillance Frequency Control Program SR 3.6.9.2 Verify at least one hydrogen ignitor is OPERABLE in In accordance with each containment region. the Surveillance Frequency Control Program SR 3.6.9.3 Energize each hydrogen ignitor and verify temperature is In accordance with

1700°F. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.6.9-2 Amendment Nos. 261, 241

AVS 3.6.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.10.1 Operate each AVS train for ~ 10 continuous hours with In accordance with heaters operating. the Surveillance Frequency Control Program SR 3.6.10.2 Perform required AVS filter testing in accordance with the In accordance with Ventilation Filter Testing Program (VFTP). the VFTP SR 3.6.10.3 Verify each AVS train actuates on an actual or simulated In accordance with actuation signal. the Surveillance Frequency Control Program SR 3.6.10.4 Verify each AVS filter cooling bypass valve can be In accordance with opened. the Surveillance Frequency Control Program SR 3.6.10.5 Verify each AVS train flow rate is ~ 7200 cfm and 5: 8800 In accordance with cfm. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.6.10-2 Amendment Nos. 261, 241

ARS 3.6.11 3.6 CONTAINMENT SYSTEMS 3.6.11 Air Return System (ARS)

LCO 3.6.11 Two ARS trains shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A One ARS train A1 Restore ARS train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

8. Required Action and 8.1 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 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.11.1 Verify each ARS fan starts on an actual or simulated In accordance with actuation signal, after a delay of ~ 8 minutes and the Surveillance

~ 10 minutes, and operates for ~ 15 minutes. Frequency Control Program (continued)

McGuire Units 1 and 2 3.6.11-1 Amendment Nos. 261, 241

ARS 3.6.11 SURVEILLANCE FREQUENCY SR 3.6.11.2 Verify, with the ARS fan damper closed and with the In accordance with bypass dampers open, each ARS fan motor current is the Surveillance s 32.0 amps when the fan speed is ~ 840 rpm and s 900 Frequency Control rpm. Program SR 3.6.11.3 Verify, with the ARS fan not operating, each ARS motor In accordance with operated damper opens automatically on an actual or the Surveillance simulated actuation signal after a delay of ~ 9 seconds Frequency Control and s 11 seconds. Program SR 3.6.11.4 Verify the check damper is open with the air return fan In accordance with operating. the Surveillance Frequency Control Program SR 3.6.11.5 Verify the check damper is closed with the air return fan In accordance with not operating. the Surveillance Frequency Control Program SR 3.6.11.6 Verify that each ARS fan is de-energized or is prevented In accordance with from starting upon receipt of a terminate signal and is the Surveillance allowed to start upon receipt of a start permissive from Frequency Control the Containment Pressure Control System (CPCS). Program SR 3.6.11.7 Verify that ARS fan motor-operated damper is allowed to In accordance with open upon receipt of a start permissive from the the Surveillance Containment Pressure Control System (CPCS) and is Frequency Control prevented from opening in the absence of a start Program permissive.

McGuire Units 1 and 2 3.6.11-2 Amendment Nos. 261. 241

Ice Bed 3.6.12 3.6 CONTAINMENT SYSTEMS 3.6.12 Ice Bed LCO 3.6.12 The ice bed shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Ice bed inoperable. A.1 Restore ice bed to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months 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 8.2 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 3.6.12.1 Verify maximum ice bed temperature is s 27°F. In accordance with the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.6.12-1 Amendment No. 261, 241

Ice Bed 3.6.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.12.2 ---------------------NOTE--------------------------

The chemical analysis may be performed on either the liquid solution or on the resulting ice.

Verify, by chemical analysis, that ice added to the ice Each ice addition condenser meets the boron concentration and pH requirements of SR 3.6.12.7.

SR 3.6.12.3 Verify by visual inspection, accumulation of ice on In accordance with structural members comprising flow channels through the Surveillance the ice bed is ::: 15 percent blockage of the total flow Frequency Control area for each safety analysis section. Program SR 3.6.12.4 Verify total mass of stored ice is z 1,890,000 Ibs by In accordance with calculating the mass of stored ice, at a 95 percent the Surveillance confidence, in each of three Radial Zones as defined Frequency Control below, by selecting a random sample of z 30 ice baskets Program in each Radial Zone, and Verify:

1. Zone A (radial rows 8, 9), has a total mass of z 313,200 Ibs

2. Zone B (radial rows 4, 5, 6, 7), has a total mass of z 901,000 Ibs

3. Zone C (radial rows 1,2,3), has a total mass of z 675,800 Ibs (continued)

McGuire Units 1 and 2 3.6.12-2 Amendment No. 261, 241

Ice Bed 3.6.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.12.5 Verify that the ice mass of each basket sampled in SR In accordance with 3.6.12.4 is z 600 Ibs. the Surveillance Frequency Control Program SR 3.6.12.6 Visually inspect, for detrimental structural wear, cracks, In accordance with corrosion, or other damage, two ice baskets from each the Surveillance group of bays as defined below: Frequency Control Program

a. Group 1 - bays 1 through 8;

b. Group 2 - bays 9 through 16; and

c. Group 3 - bays 17 through 24.

SR 3.6.12. 7 -----------------NOTE---------------------------

The requirements of this SR are satisfied if the boron concentration and pH values obtained from averaging the individual sample results are within the limits specified below.

Verify, by chemical analysis of the stored ice in at least In accordance with one randomly selected ice basket from each ice the Surveillance condenser bay, that ice bed: Frequency Control Program

a. Boron concentration is .::: 1800 ppm and ~ 2330 ppm; and

b. pH is.::: 9.0 and ~ 9.5.

McGuire Units 1 and 2 3.6.12-3 Amendment No. 261, 241

Ice Condenser Doors 3.6.13 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Restore ice condenser door 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months associated Completion to OPERABLE status and Time of Condition B not closed position.

met.

D. Required Action and D.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 C AND not met.

D.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 3.6.13.1 Verify all lower inlet doors indicate closed by the Inlet In accordance with Door Position Monitoring System. the Surveillance Frequency Control Program SR 3.6.13.2 Verify, by visual inspection, each intermediate deck door In accordance with is closed and not impaired by ice, frost, or debris. the Surveillance Frequency Control Program SR 3.6.13.3 Verify, by visual inspection, each top deck door: In accordance with the Surveillance

a. Is in place; and Frequency Control Program

b. Has no condensation, frost, or ice formed on the door that would restrict its opening.

(continued)

McGuire Units 1 and 2 3.6.13-2 Amendment Nos. 261, 241

Ice Condenser Doors 3.6.13 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.13.4 Verify, by visual inspection. each lower inlet door is not In accordance impaired by ice. frost, or debris. with the Surveillance Frequency Control Program SR 3.6.13.5 Verify torque required to cause each lower inlet door to In accordance begin to open is $ 675 in-lb. and verify free movement of with the the door. Surveillance Frequency Control Program SR 3.6.13.6 (deleted)

SR 3.6.13.7 Verify for each intermediate deck door: In accordance with the

a. No visual evidence of structural deterioration; Surveillance Frequency

b. Free movement of the vent assemblies; and Control Program

c. Free movement of the door.

McGuire Units 1 and 2 3.6.13-3 Amendment Nos. 261, 241

Divider Barrier Integrity 3.6.14 SURVEILLANCE REQUIREMENTS SU RVEI LLANCE FREQUENCY SR 3.6.14.1 Verify, by visual inspection, all personnel access doors Prior to entering and equipment hatches between upper and lower MODE 4 from containment compartments are closed. MODES SR 3.6.14.2 Verify, by visual inspection, that the seals and sealing Prior to final surfaces of each personnel access door and equipment closure after each hatch have: opening

a. No detrimental misalignments; AND

b. No cracks or defects in the sealing surfaces; and ------NOTE----

Only required for

c. No apparent deterioration of the seal material. seals made of resilient materials In accordance with the Surveillance Frequency Control Program SR 3.6.14.3 Verify, by visual inspection, each personnel access door After each opening or equipment hatch that has been opened for personnel transit entry is closed.

SR 3.6.14.4 Remove two divider barrier seal test coupons and verify In accordance with both test coupons' tensile strength is ~ 39.7 psi. the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.6.14-2 Amendment Nos. 261, 241

Divider Barrier Integrity 3.6.14 SURVEILLANCE FREQUENCY SR 3.6.14.5 Visually inspect;? 95% of the divider barrier seal length, In accordance with and verify: the Surveillance Frequency Control

a. Seal and seal mounting bolts are properly Program installed; and .

b. Seal material shows no evidence of deterioration due to holes, ruptures, chemical attack, abrasion, radiation damage, or changes in physical appearance.

McGuire Units 1 and 2 3.6.14-3 Amendment Nos. 261. 241

Containment Recirculation Drains 3.6.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.15.1 Verify, by visual inspection, that: Prior to entering MODE 4 from

a. Each refueling canal drain valve is locked open; MODE 5 after each partial or

b. Each refueling canal drain is not obstructed by complete fill of the debris; and canal SR 3.6.15.2 Verify, by visual inspection, that no debris is present in In accordance with the upper compartment or refueling canal that could the Surveillance obstruct the refueling canal drain. Frequency Control Program SR 3.6.15.3 Verify for each ice condenser floor drain that the: In accordance with the Surveillance

a. Valve opening is not impaired by ice, frost, or Frequency Control debris; Program

b. Valve seat shows no evidence of damage;

c. Valve opening force is s 66 Ib; and

d. Drain line from the ice condenser floor to the lower compartment is unrestricted.

McGuire Units 1 and 2 3.6.15-2 Amendment Nos. 261, 241

Reactor Building 3.6.16 3.6 CONTAINMENT SYSTEMS 3.6.16 Reactor Building LCO 3.6.16 The reactor building shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor building A.1 Restore reactor building to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable. 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 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE EQUENCY SR 3.6.16.1 Verify the door in each access opening is closed, except In accordance with when the access opening is being used for normal transit the Surveillance entry and exit. Frequency Control Program (continued)

McGuire Units 1 and 2 3.6.16-1 Amendment Nos. 261, 241

Reactor Building 3.6.16 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.16.2 Verify each Annulus Ventilation System train produces a In accordance with pressure equal to or more negative than -0.5 inch water the Surveillance gauge in the annulus within 22 seconds after a start Frequency Control signal and -3.5 inches water gauge after 48 seconds. Program Verifying that upon reaching a negative pressure of -3.5 inches water gauge in the annulus, the system switches into its recirculation mode of operation and that the time required for the annulus pressure to increase to -0.5 inch water gauge is :;?; 278 seconds.

SR 3.6.16.3 Verify reactor building structural integrity by performing a In accordance with visual inspection of the exposed interior and exterior the Surveillance surfaces of the reactor building. Frequency Control Program McGuire Units 1 and 2 3.6.16-2 Amendment Nos. 261, 241

SG PORVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each SG PORV. In accordance with the Surveillance Frequency Control Program SR 3.7.4.2 Verify one complete cycle of each SG PORV block valve. In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.7.4-2 Amendment Nos. 261, 241

AFWSystem 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 ----------------------NOTE------------------------

Not applicable to automatic valves when THERMAL POWER is.::: 10% RTP.

Verify each AFW manual, power operated, and automatic In accordance valve in each water flow path, and in both steam supply with the flow paths to the steam turbine driven pump, that is not Surveillance locked, sealed, or otherwise secured in position, is in the Frequency correct position. Control Program 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 2 900 psig in the steam generator.

Verify the developed head of each AFW pump at the flow In accordance test point is greater than or equal to the required with the Inservice developed head. Testing Program SR 3.7.5.3 --------------------------NOTE---------------------

Not applicable in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW automatic valve that is not locked, In accordance sealed, or otherwise secured in position, actuates to the I with the correct position on an actual or simulated actuation

Surveillance signal. I Frequency

~ontrol Program (continued)

McGuire Units 1 and 2 3.7.5-3 Amendment Nos. 261, 241

AFWSystem 3.7.5 SURVEILLANCE* REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.5. 4 -------------------------NOTE-----------------------

1. 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 ~ 900 psig in the steam generator.

2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW pump starts automatically on an actual In accordance or simulated actuation signal. with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.7.5-4 Amendment Nos. 261, 241

CCW System 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 -------------------NOTE-------------------------

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

Verify each CCW manual, power operated, and In accordance with automatic valve in the flow path servicing safety related the Surveillance equipment, that is not locked, sealed, or otherwise Frequency Control secured in position, is in the correct position. Program SR 3.7.6.2 Verify each CCW automatic valve in the flow path In accordance with servicing safety related equipment, that is not locked, the Surveillance sealed, or otherwise secured in position, actuates to the Frequency Control correct position on an actual or simulated actuation Program signal.

SR 3.7.6.3 Verify each CCW pump starts automatically on an actual In accordance with or simulated actuation signal. the Surveillance Freq uency Control Program McGuire Units 1 and 2 3.7.6-2 Amendment Nos. 261, 241

NSWS 3.7.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

8. Required Action and 8.1 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 not AND 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 3.7.7.1 --------------------------NOTE------------------------

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

Verify each NSWS manual, power operated, and In accordance with automatic valve in the flow path servicing safety related the Surveillance equipment, that is not locked, sealed, or otherwise Frequency Control secured in position, is in the correct position. Program SR 3.7.7.2 Verify each NSWS automatic valve in the flow path In accordance with servicing safety related equipment, that is not locked, the Surveillance sealed, or otherwise secured in position, actuates to the Frequency Control correct position on an actual or simulated actuation Program signal.

SR 3.7.7.3 Verify each NSWS pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.7.7-2 Amendment Nos. 261, 241

SNSWP 3.7.8 SURVEILLANCE REQUIREMENTS (continued) 3.7 PLANT SYSTEMS 3.7.8 Standby Nuclear Service Water Pond (SNSWP)

LCO 3.7.8 The SNSWP shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SNSWP inoperable. A1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.7.8.1 Verify water level of SNSWP is;::: 739.5 ft mean sea In accordance with level. the Surveillance Frequency Control Program SR 3.7.8.2 ---------------NOTE-------------

Only required to be performed during the months of July, August, and September.

Verify average water temperature of SNSWP is s 82°F at In accordance with an elevation of 722 ft. in SNSWP. the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.7.8-1 Amendment Nos. 261, 241

SNSWP 3.7.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.8.3 Verify, by visual inspection, no abnormal degradation, In accordance with erosion, or excessive seepage of the SNSWP dam. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.7.8-2 Amendment Nos. 261, 241

CRAVS 3.7.9 CONDITION REQUIRED ACTION COMPLETION TIME I

G. One or more CRAVS G.1 Restore CRAVS train(s) 7 days train(s) heater heater to OPERABLE inoperable. status.

G.2 Initiate action in 7 days accordance with Specification 5.6.6.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Operate each CRAVS train for ~ 10 continuous hours In accordance with with the heaters operating. the Surveillance Frequency Control Program SR 3.7.9.2 Perform required CRAVS filter testing in accordance with In accordance with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.9.3 Verify each CRAVS train actuates on an actual or In accordance with simulated actuation signal. the Surveillance Frequency Control Program

. SR 3.7.9.4 Perform required CRE unfiltered air inleakage testing in In accordance with accordance with the Control Room Envelope Habitability the Control Room Program. Envelope Habitability Program McGuire Units 1 and 2 3.7.9-3 Amendment Nos. 261, 241

CRACWS 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two CRACWS trains D.1 Suspend CORE Immediately inoperable in MODE 5 ALTERATIONS.

or 6, or during movement of irradiated AND fuel assemblies, or during CORE D.2 Suspend movement of Immediately ALTERATIONS. irradiated fuel assemblies.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify the control room temperature is ~ gO°F. In accordance with the Surveillance Frequency Control Pro ram McGuire Units 1 and 2 3.7.10-2 Amendment Nos. 261, 241

ABFVES 3.7.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Operate each ABFVES for ~ 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3.7.11.2 Perform required ABFVES filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.11.3 Verify each ABFVES actuates on an actual or simulated In accordance with actuation signal. the Surveillance Frequency Control Program SR 3.7.11.4 Verify one ABFVES can maintain a pressure In accordance with s; -0.125 inches water gauge in the ECCS pump room the SUrveillance area relative to atmospheric pressure during the post Frequency Control accident mode of operation. Program McGuire Units 1 and 2 3.7.11-2 Amendment No. 261, 241

FHVES 3.7.12 3.7 PLANT SYSTEMS 3.7.12 Fuel Handling Ventilation Exhaust System (FHVES)

LCO 3.7.12 The FHVES shall be OPERABLE and in operation.

APPLICABILITY: During movement of irradiated fuel assemblies in the fuel building.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A FHVES inoperable. ------------NOTE------------

LCO 3.0.3 is not applicable.

A1 Suspend movement of Immediately irradiated fuel assemblies in the fuel building.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Verify FHVES in operation. In accordance with the Surveillance Frequency Control Program SR 3.7.12.2 Operate FHVES for ~ 15 minutes. Prior to movement of irradiated fuel assemblies (continued)

McGuire Units 1 and 2 3.7.12-1 Amendment Nos. 261, 241

FHVES 3.7.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.12.3 Perform required FHVES filter testing in accordance with In accordance with the Ventilation Filter Testing Program (VFTP). the VFrp SR 3.7.12.4 Verify FHVES can maintain an exhaust flow rate In accordance with

> 8000 cfm greater than the supply flow rate. the Surveillance Frequency Control Program SR 3.7.12.5 Verify each FHVES filter bypass damper can be closed. In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.7.12-2 Amendment Nos. 261, 241

Spent Fuel Pool Water Level 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Spent Fuel Pool Water Level lCO 3.7.13 The spent fuel pool water level shall be ~ 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel 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 spent fuel pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Verify the spent fuel pool water level is ~ 23 ft above the In accordance with top of the irradiated fuel assemblies seated in the storage the Surveillance racks. Frequency Control Program McGuire Units 1 and 2 3.7.13-1 Amendment Nos. 261, 241

Spent Fuel Pool Boron Concentration 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Spent Fuel Pool Boron Concentration LCO 3.7.14 The spent fuel pool boron concentration shall be within the limit specified in the COLR.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A Spent fuel pool boron ------------------NOTE------------------

concentration not within LCO 3.0.3 is not applicable.

limit.

A1 Suspend movement of fuel Immediately assemblies in the spent fuel pool.

A2 Initiate action to restore Immediately spent fuel pool boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the spent fuel pool boron concentration is within In accordance with limit. the Surveillance Frequency Control Pro ram McGuire Units 1 and 2 3.7.14-1 Amendment Nos. 261, 241

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 ~ 0.10 flCi/gm DOSE EQUIVALENT 1-131.

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

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

~ 0.10 flCi/gm DOSE EQU IVALENT 1-131. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.7.16-1 Amendment Nos. 261, 241

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

1. Performance of SR 3.8.1.7 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 DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.

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

Verify each DG starts from standby conditions and In accordance with achieves steady state voltage ~ 3740 V and:; 4580 V, the Surveillance and frequency ~ 58.8 Hz and:; 61.2 Hz. Frequency Control Program (continued)

McGuire Units 1 and 2 3.8.1-5 Amendment Nos. 261, 241

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------------------NOTES---------------------------

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

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

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

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

Verify each DG is synchronized and loaded and operates In accordance with for?: 60 minutes at a load?: 3600 kW and s 4000 kW. the Surveillance Frequency Control Program SR 3.8.1.4 Verify each day tank contains?: 39 inches of fuel oil. In accordance with the Surveillanoe Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water from each day In accordance with tank. the Surveillance Frequency Control Program SR 3.8.1.6 Verify the fuel oil transfer system operates to In accordance with automatically transfer fuel oil from storage tank to the day the Surveillanoe tank. Frequency Control Program (continued)

McGuire Units 1 and 2 3.8.1-6 Amendment Nos. 261, 241

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1. 7 -----------------------NOTES------------------------

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

Verify each DG starts from standby condition and In accordance with achieves in =:; 11 seconds voltage of ~ 3740 V and the Surveillance frequency of ~ 57 Hz and maintains steady state voltage Frequency Control

~ 3740 V and =:; 4580 V, and frequency ~ 58.8 Hz and Program

$ 61.2 Hz.

SR 3.8.1.8 ------------------------NOTES------------------------

This Surveillance shall not be performed in MODE 1 or 2.

Verify automatic and manual transfer of AC power In accordance with sources from the normal offsite circuit to each alternate the Surveillance offsite circuit. Frequency Control Program (continued)

McGuire Units 1 and 2 3.8.1-7 Amendment Nos. 261, 241

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9 Verify each DG, when connected to its bus in parallel with In accordance with offsite power and operating with maximum kVAR loading the Surveillance that offsite power conditions permit, rejects a load greater Frequency Control than or equal to its associated single largest post Program accident load, and:

a. Following load rejection, the frequency is::; 63 Hz;

b. Within 3 seconds following load rejection, the voltage is ~ 3740 V and::; 4580 V; and

c. Within 3 seconds following load rejection, the frequency is ~ 58.8 Hz and::; 61.2 Hz.

SR 3.8.1.10 Verify each DG does not trip and voltage is maintained In accordance with

4784 V during and following a load rejection of the Surveillance

~ 3600 kW and::; 4000 kW. Frequency Control Program (continued)

McGuire Units 1 and 2 3.8.1-8 Amendment Nos. 261, 241

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.8.1.11 ----------------------NOTES---------------------

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

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

Verify on an actual or simulated loss of offsite power In accordance 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 the emergency bus in

11 seconds,

2. energizes auto-connected blackout loads through automatic load sequencer,

3. maintains steady state voltage

?: 3740 V and::; 4580 V,

4. maintains steady state frequency

~ 58.8 Hz and::; 61.2 Hz, and

5. supplies auto-connected blackout loads for

~ 5 minutes.

(continued)

McGuire Units 1 and 2 3.8.1-9 Amendment Nos. 261, 241

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

Ali DG starts may be preceded by prelube period.

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

a. In s; 11 seconds after auto-start signal achieves voltage of ~ 3740 and during tests, achieves steady state voltage ~ 3740 V and s; 4580 V;

b. In s; 11 seconds after auto-start signal achieves frequency of ~ 57 Hz and during tests, achieves steady state frequency ~ 58.8 Hz and s; 61.2 Hz;

c. Operates for ~ 5 minutes; and

d. The emergency bus remains energized from the offsite power system.

(continued)

McGuire Units 1 and 2 3.8.1-10 Amendment Nos. 261, 241

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13 Verify each DG's non-emergency automatic trips are In accordance with bypassed on actual or simulated loss of voltage signal on the Surveillance the emergency bus concurrent with an actual or Frequency Control simulated ESF actuation signal. Program SR 3.8.1.14 --------------------NOTES--------------------

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

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

Verify each DG, when connected to its bus in parallel with In accordance with offsite power and operating with maximum kVAR loading the Surveillance that offsite power conditions permit, operates for Frequency Control

?: 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: Program

a. For?: 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded?: 4200 kW and::; 4400 kW; and

b. For the remaining hours of the test loaded

?: 3600 kW and::; 4000 kW.

(continued)

McGuire Units 1 and 2 3.8.1-11 Amendment Nos. 261, 241

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15 ---------------------NOTES--------------------

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated ~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded ~ 3600 kW and

4000 kW.

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

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

Verify each DG starts and achieves, in :::; 11 seconds, In accordance with voltage ~ 3740 V, and frequency ~ 57 Hz and maintains the Surveillance steady state voltage ~ 3740 V and:::; 4580 V and Frequency Control frequency ~ 58.8 Hz and:::; 61.2 Hz. Program SR 3.8.1.16 ------------------NOTES------------------------

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 standby operation.

(continued)

McGuire Units 1 and 2 3.8.1-12 Amendment Nos. 261, 241

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.17 ------------------------------NOTES-----------------------

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

Verify. with a DG operating in test mode and connected In accordance with to its bus, an actual or simulated ESF actuation signal the Surveillance overrides the test mode by: Frequency Control Program

a. Returning DG to standby operation; and

b. Automatically energizing the emergency load from offsite power.

SR 3.8.1.18 Verify interval between each sequenced load block is In accordance with within design interval for each automatic load sequencer. the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.8.1-13 Amendment Nos. 261, 241

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19 --------------------------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 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 the emergency bus in s; 11 seconds,

2. energizes auto-connected emergency loads through load sequencer,

3. achieves steady state voltage;;:: 3740 V and s;4580 V,

4. achieves steady state frequency;;:: 58.8 Hz and s; 61.2 Hz, and

5. supplies auto-connected emergency loads for;;:: 5 minutes.

(continued)

McGuire Units 1 and 2 3.8.1-14 Amendment Nos. 261, 241

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 --------------------------NOTES-------------------------

AI/ DG starts may be preceded by an engine pre lube period.

Verify when started simultaneously from standby In accordance with condition, each DG achieves, in :s; 11 seconds, voltage of the Surveillance

~ 3740 V and frequency of ~ 57 Hz and maintains steady Frequency Control state voltage ~ 3740 V and :s; 4580 V, and frequency Program

~ 58.8 Hz and :s; 61.2 Hz.

McGuire Units 1 and 2 3.8.1-15 Amendment Nos. 261, 241

Diesel Fuel Oil and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify the fuel oil storage system contains ~ 39,500 gal of In accordance with fuel for each DG. the Surveillance Frequency Control Program SR 3.8.3.2 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.3 Verify each DG air start receiver pressure is ~ 210 psig. In accordance with the Surveillance Frequency Control Pr~gram SR 3.8.3.4 Check for and remove accumulated water from the fuel In accordance with oil storage tank. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.8.3-3 Amendment Nos. 261, 241

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is :2: 125 V on float charge. In accordance with the Surveillance Frequency Control Program SR 3.8.4.2 Verify no visible corrosion at battery terminals and In accordance with connectors. the Surveillance Frequency Control OR Program Verify connection resistance of specific connection(s) meets Table 3.8.4-1 limit.

SR 3.8.4.3 Verify battery cells, cell plates, and racks show no visual In accordance with indication of physical damage or abnormal deterioration the Surveillance that could degrade battery performance. Frequency Control Program SR 3.8.4.4 Remove visible terminal corrosion, verify battery cell to In accordance with cell and terminal connections are clean and tight, and are the Surveillance coated with anti-corrosion material. Frequency Control Program SR 3.8.4.5 Verify all battery connection resistance values meet In accordance with Table 3.8.4-1 limits. the Surveillance Frequency Control Program SR 3.8.4.6 Verify each battery charger supplies:2: 400 amps at In accordance with

2: 125 V for:2: 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.8.4-2 Amendment Nos. 261, 241

DC Sources - Operating 3.8.4 SURVEILLANCE FREQUENCY S R 3.8.4. 7 ----------------------NOTE---------------------------

The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7.

Verify battery capacity is adequate to supply, and In accordance with maintain in OPERABLE status, the required emergency the Surveillance loads for the design duty cycle when subjected to a Frequency Control battery service test. Program SR 3.8.4.8 Verify battery capacity is ;::: 80% of the manufacturer's In accordance with rating when subjected to a performance discharge test or the Surveillance a modified performance discharge test. Frequency Control Program 12 months when battery shows degradation or has reached 85% of expected life with capacity <: 100%

of manufacturer's rating 24 months when battery has reached 85% of the expected life with capacity;:::

100% of manufacturer's rating McGuire Units 1 and 2 3.8.4-3 Amendment Nos. 261, 241

Battery Cell Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated battery Immediately associated Completion inoperable.

Time of Condition A not met.

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

< 60°F.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 In accordance with Category A limits. the Surveillance Frequency Control Program (continued)

McGuire Units 1 and 2 3.8.6-2 Amendment Nos. 261, 241

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

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

< 110V Once within 7 days after a battery overcharge

> 150V SR 3.8.6.3 Verify average electrolyte temperature of representative In accordance with cells is 260°F. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.8.6-3 Amendment Nos. 261, 241

Inverters Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters-Operating LCO 3.8.7 The four required Channels of inverters shall be OPERABLE.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A One inverter inoperable. A1 ------------NOTE----------

Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems - Operating" with any vital bus de-energized.

Restore inverter to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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 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, and alignment to required In accordance with AC vital buses. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.8.7-1 Amendment Nos. 261, 241

Inverters - Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or required boron concentration.

A.2.4 Initiate action to restore Immediately required inverters to OPERABLE status.

j' i

I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct voltage and alignments to required AC vital In accordance with buses. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.8.8-2 Amendment Nos. 261, 241

Distribution Systems - Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One channel of DC C.1 Restore DC channel of 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power electrical power distribution distribution subsystem subsystem to OPERABLE AND inoperable. status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO D. Required Action and D.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 0.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Two trains with E.1 Enter LCO 3.0.3. Immediately inoperable 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 AC, DC, In accordance with and AC vital bus electrical power distribution subsystems. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.8.9-2 Amendment Nos. 261, 241

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 Dec/are associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.

A.2.6 Declare affected Low Immediately Temperature Overpressure Protection (LTOP) feature(s) inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to required In accordance with AC, DC, and AC vital bus electrical power distribution the Surveillance subsystems. Frequency Control Program McGuire Units 1 and 2 3.8.10-2 Amendment Nos. 261, 241

Boron Conrentration 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.

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

Only applicable to the refueling canal and refueling cavity when connected to the RCS.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron conrentration not A.1 SusJ:end CORE Immediately within limit. ALTERATIONS.

A.2 SlJst::ald positive reactivity Immediately additions.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified in In accordanre with COLR. the Surveillanre Frequency Control Program McGuire Units 1 and 2 3.9.1-1 Amendment Nos. 261, 241

Unborated Water Source Isolation Valves 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Unborated Water Source Isolation Valves LCO 3.9.2 Each valve used to isolate unborated water sources shall be secured in the closed position.

APPLICABILITY: MODE 6.

ACTIONS

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

Separate Condition entry is allowed for each unborated water source isolation valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. ----------NOTE------- A.1 Suspend CORE Immediately Required Action A.3 ALTERATIONS.

must be completed whenever Condition A is AND entered.

A.2 Initiate actions to secure Immediately valve in closed position.

One or more valves not secured in closed AND position.

A.3 Perform SR 3.9.1.1. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water sources is In accordance with secured in the closed position. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.9.2-1 Amendment Nos. 261, 241

Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.3.2 ----------------------NOTE----------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program McGuire Units 1 and 2 3.9.3-2 Amendment Nos. 261, 241

Containment Penetrations 3.9.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify each required containment penetration is in the In accordance with required status. the Surveillance Frequency Control Program SR 3.9.4.2 Perform required Containment Purge Exhaust System In accordance with Testing in accordance with the Ventilation Filter Testing the VFTP Program (VFTP).

McGuire Units 1 and 2 3.9.4-2 Amendment Nos. 261, 241

RHR and Coolant Circulation - High Water Level 3.9.5 i'

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

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 2?: 1000 gpm and RCS the Surveillance temperature is s: 140°F. Frequency Control Program McGuire Units 1 and 2 3.9.5-2 Amendment Nos. 261, 241

RHR and Coolant Circulation - Low Water Level 3.9.6 CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Initiate action to restore Immediately one RHR loop to operation.

B.3 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating In accordance with reactor coolant at a flow rate of ~ 1000 gpm and RCS the Surveillance temperature is ~ 140°F. Frequency Control Program SR 3.9.6.2 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 McGuire Units 1 and 2 3.9.6-2 Amendment Nos. 261, 241

Refueling Cavity Water Level 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Cavity Water Level LCO 3.9.7 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 A,1 Suspend CORE Immediately level not within limit. AL TERATIONS.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling cavity water level is;:,>: 23 ft above the top In accordance with of reactor vessel flange. the Surveillance Frequency Control Program McGuire Units 1 and 2 3.9.7-1 Amendment Nos. 261, 241

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16 Control Room Envelope Habitability Program (continued)

b. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (H) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision O.

d. Measurement, at designated locations, of the CRE pressure relative to atmospheric pressure during the pressurization mode of operation by one train of the CRAVS, operating at a makeup flow rate of ~ 2200 cfm, at a Frequency of 18 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the periodic assessment of the CRE boundary in accordance with Regulatory Guide 1.197, Figure 1.

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.

The unfiltered air inleakage limit for radiological challenges is the inJeakage flow rate assumed in the licensing basis analyses of DBA consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

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

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

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

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

(continued)

McGuire Units 1 and 2 5.5-15 Amendment Nos. 261, 241

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.17 Surveillance Frequency Control Program (continued)

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.

(continued)

McGuire Units 1 and 2 5.5-16 Amendment Nos. 261, 241

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 261 TO RENEWED FACILITY OPERATING LICENSE NPF-9 AND AMENDMENT NO. 241 TO RENEWED FACILITY OPERATING LICENSE NPF-17 DUKE ENERGY CAROLINAS, LLC MCGUIRE NUCLEAR STATION, UNITS 1 AND 2 DOCKET NOS. 50-369 AND 50-370

1.0 INTRODUCTION

By application dated March 24, 2010 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML100890320), as supplemented by letters dated November 18, 2010 (ADAMS Accession No. ML103270658), and March 2, 2011 (ADAMS Accession No. ML110730171), Duke Energy Carolinas, LLC (Duke, the licensee), requested changes to the Technical Specifications (TSs) for the McGuire Nuclear Station, Units 1 and 2 (McGuire 1 and 2).

The supplements dated November 18, 2010, and March 2, 2011, provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the staff's original proposed no significant hazards consideration determination as published the Federal Register on November 16, 2010 (75 FR 70035).

The amendments would revise the TSs by relocating specific surveillance frequencies to a licensee-controlled document using a risk-informed justification. The proposed changes would revise the TSs by relocating specific surveillance frequency requirements to a licensee-controlled document using a risk-informed justification. The proposed changes adopt Nuclear Regulatory Commission (NRC, the Commission) staff-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);

-2

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").

A new program would be added to the Administrative Controls in TS Section 5.5.17. 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, Revision 1, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies," April 2007 (Reference 2), as the basis for making any changes to the surveillance frequencies once they are relocated out of the TSs.

By letter dated September 19,2007, (Reference 3), the NRC staff approved NEI 04-10, Revision 1, as acceptable for referencing by licensees proposing to amend their TSs to establish an SFCP. This acceptance was limited as specified in NEI 04-10, Revision 1, and Reference 3.

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 Safety Evaluation (SE). In its application dated March 24,2010, the licensee stated that "Duke Energy has concluded that the justifications presented in the TSTF proposal and the safety evaluation prepared by the NRC staff are applicable to McGuire Nuclear Station, Units 1 and 2, and justify this amendment to incorporate the changes to the McGuire Technical Specifications." The SE that follows is based, in large part, on the model SE for TSTF-425.

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 staff 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 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), Part 50, 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. * * *

-3 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 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 concerning 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 this Federal Register publication, the Commission provided its policy on use of PRA which states:

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

Implementation of the policy statement will improve the regulatory process in three areas:

Foremost, through safety 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:

-4 (1) The use of PRA technology should be increased in all regulatory matters to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach and supports the NRC's traditional defense-in-depth philosophy.

(2) PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where practical within the bounds of the state-of-the-art, to reduce unnecessary conservatism associated with current regulatory requirements, regulatory guides, license commitments, and staff practices. Where appropriate, PRA should be used to 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 10 CFR 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 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 program.

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

- 5 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 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 4),

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 RG 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 5), 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 6), 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 McGuire 1 and 2 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 will include surveillance requirements which are "requirements relating to test, calibration, or inspection to assure that necessary quality of

-6 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 McGuire 1 and 2 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 added to new TS Section 5.0. In accordance with TS Section 5.0, 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 3), 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 the CDF and the 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

-7 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.

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 McGuire 1 and 2's 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 McGuire 1 and 2's PRA technical adequacy. RG 1.200 is NRC's developed regulatory guidance which, in Revision 1, endorsed with comments and qualifications the use of "ASME [American Society of Mechanical Engineers] PRA Standard RA-Sb-2005, Addenda B to ASME RA-S-2002 Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications" (Reference 7), NEI 00-02, Revision 1, "Probabilistic Risk

-8 Assessment (PRA) Peer Review Process Guidance," (Reference 8), and NEI 05-04, "Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard" (Reference 9). 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 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 RG 1.200, Revision 2, 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.

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

Gap #1: Accident sequence notebooks and system model notebooks should document the phenomenological conditions created by the accident sequence progression. In response to the RAI, the licensee stated that for each surveillance frequency change evaluation, any phenomenological conditions created by the accident sequence progression will be identified, included and documented in the analysis.

Gap #2: Structure, systems and components (SSC) boundaries, SSC failure modes and success criteria definitions should be established for failure rates and common cause failure parameters.

In response to the RAI, the licensee stated that each surveillance frequency change evaluation will use definitions for SSC boundary, unavailability boundary, failure mode, and success criteria consistently across the systems and data analyses.

Gap #3: Data calculations should be revised to group standby and operating component data.

Group components by service condition to the extent supported by the data. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will include sensitivity studies to consider the impact of grouping data into operating vs. standby failure rates and by service condition.

Gap #4: As part of the Bayesian update process, checks are performed to assure that the posterior distribution is reasonable given the prior distribution and plant experience. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will verify that the Bayesian update process produces a reasonable posterior distribution.

Gap #5: Comparisons should be done of the component boundaries assumed for the generic common cause failure (CCF) estimates to those assumed in the PRA to ensure that these

-9 boundaries are consistent. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will ensure that CCF probabilities are consistent with component boundaries and plant experience.

Gap #6: Human reliability analysis should consider the potential for calibration errors. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will identify and consider the impact that equipment calibration errors could have on the results and conclusions.

Gap #7: Maintenance and calibration activities that could simultaneously affect equipment in either different trains of a redundant system or diverse systems should be identified. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will identify and consider the impact that equipment calibration errors could have on the results and conclusions.

Gap #8, #12: Mean values should be developed for pre- and post-initiator human error probabilities (HEPs). In response to the RAI, the licensee stated that each surveillance frequency change evaluation will use mean values for pre- and post-initiator HEPs.

Gap #9: When estimating HEPs, the impact of plant-specific and scenario-specific performance shaping factors should be considered and documented. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will use HEP values that have been quantified with consideration of plant-specific and scenario-specific performance shaping factors.

Gap #10, #11, #13: HRA documentation should be enhanced to include time available to complete actions, a review of Human Failure Events (HFEs) and their final HEPs relative to each other, and appropriate credit if given for operator recovery actions. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will use HEP events with time available inputs based on plant-specific thermal hydraulic analyses; post-initiator HEPs will be reviewed against each other to check their reasonableness given the scenario context, plant procedures, operating practices and experience; and operator actions will only be credited if they are feasible.

Gap #14: The licensee identified twelve initiating event gaps to the supporting requirements for capability category II of the PRA standard. In response to the RAI, the licensee confirmed that no technical issues were identified for any of these supporting requirements but there remained a need to enhance the documentation. The licensee stated that the McGuire 1 and 2 initiating events analysis is revised with each PRA update to ensure that it remains consistent with industry operating experience as well as current plant design, operation and experience. Furthermore, the licensee noted that a calculation was performed to address the initiating events supporting requirements. Each surveillance frequency change evaluation will review this calculation for potential impacts on the analysis. In addition, each surveillance frequency change will include a sensitivity analysis to determine the impact of the assumptions and sources of model uncertainty on the 5b analysis result.

Gap #15: Six internal flooding supporting requirements are not met in the McGuire 1and 2 PRA.

In response to the RAI, the licensee stated that a plan and schedule are in place for addressing

- 10 internal flood issues related to the PRA Standard for McGuire 1 and 2. In the interim, for each surveillance frequency change, all supporting requirements not meeting capability Category II will be evaluated with sensitivity studies.

Gap #16: In crediting HFEs that support the accident progression analysis, explicitly model reactor coolant system depressurization for smaliloss-of-coolant accidents (LOCAs) and perform the dependency analysis on the HEPs. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will include a sensitivity study to assess the importance of explicitly modeling ReS depressurization for small LOCAs.

Gap #17, #20, #23, #25, #29: Collectively, these gaps identify deficiencies in the documentation process that do not directly affect the technical adequacy of the PRA model.

Gap #18, #19: Enhancement to the uncertainty analysis by use of a documented, systematic process to identify significant assumptions is recommended. In response to the RAI, the licensee stated that use of this application will include a sensitivity analysiS for these gaps per NEI 04-10 if applicable to the specific surveillance test interval evaluation.

Gap #21: Documentation should include thermal hydraulic bases for all safety function success criteria for all initiating events. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will ensure that the success criteria address all initiators.

Gap #22: The acceptability of the results should be shown for the thermal hydraulic, structural, or other supporting engineering bases used to support the success criteria. In response to the RAI, the licensee stated that each surveillance frequency change evaluation will check and ensure the reasonableness and acceptability of the thermal hydraulic analyses result used to support the success criteria.

Gap #24, #27: System documentation should be enhanced to include an up-to-date system walkdown checklist and system engineer review for each system. In response to the RAI, the licensee stated that until each system notebook is updated, the impact of these gaps will be evaluated for each surveillance frequency change.

Gap #26: Quantitative evaluations should be provided for screening criteria associated with system unavailability and unreliability. In response to the RAI, the licensee stated that for each surveillance frequency change, the component and failure mode screening performed in the system analysis will be verified to meet the quantitative requirements provided in SY-A 14.

Gap #28: A consideration of potential sse failures due to adverse environmental conditions should be identified and documented. In response to the RAI, the licensee states that for each surveillance frequency change, potential SSC failures due to adverse environmental conditions will be identified, included and documented in the analysis.

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

- 11 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.

McGuire 1 and 2's PRA includes a plant-specific seismic analysis and fire model. The current McGuire 1 and 2 seismic PRA model of record utilizes Seismic Margins Methodology and was recently updated as part of a revision. The fire PRA model is integrated into the overall PRA model, therefore; quantitative fire risk insights can be obtained. Both seismic and fire models use the same analysis and methodology as described in the original Individual Plant Examination for External Events (IPEEE). Furthermore, the licensee is planning to perform a self-assessment against the supporting requirements for both fire and seismic events of ASME/ANS PRA standard RA-Sa-2009, Addendum A to RA-S-2008 for the McGuire 1 and 2 fire and seismic PRA. The licensee stated that any deviations from ASME Standard Capability Category II requirements for each application of initiative 5b will be addressed.

The McGuire 1 and 2 PRA does not include an approved quantitative shutdown PRA model, therefore; the licensee stated that it will either 1) utilize the plant shutdown safety assessment tool developed to support implementation of NUMARC 91-06 or 2) perform an alternate qualitative risk evaluation process to assess the proposed surveillance frequency change.

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 (i.e.,

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

- 12 Thus, through the application of NEI 04-10 the McGuire 1 and 2 PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency, and is consistent with Regulatory Position 2.3.3 of RG 1.177.

3.1.4.4 Assumptions for Time Related Failure Contributions The failure probabilities of SSCs modeled in the McGuire 1 and 2 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.

3.1.4.5 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-2005. Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies. Required monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented will also be performed. Thus, through the application of NEI 04-10, the licensee has appropriately considered the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations, and is consistent with Regulatory Position 2.3.5 of RG 1.177.

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

- 13 accordance with the TS SFCP. Each individual change to surveillance frequency must show a risk impact below 1E-6 per year for a change to the CDF, and below 1E-7 per year for a change to the 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, 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 a change to the CDF, and below 1E-6 per year for a change to the LERF, and the total CDF and the 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 "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).

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. NE104-10 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

- 14 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.

3.2 Addition of Surveillance Frequency Control Program to TS Section 5 The proposed amendment would add the SFCP into the Administrative Controls section of the McGuire 1 and 2 TSs. Specifically, new TS Section 5.5.17, "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 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 North Carolina State 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 the installation or use of facility components located within the restricted area as defined in 10 CFR Part 20 and change

- 15 surveillance requirements. The NRC staff has determined that the amendments involve no significant increase in the amounts and no significant change in the types of any effluents that may be released offsite and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission has previously issued a proposed finding that the amendments involve no significant hazards consideration, and there has been no public comment on such finding (75 FR 70035). The amendments also relate to changes in recordkeeping, reporting, or administrative procedures or requirements. Accordingly, the amendments meet the eligibility criteria for categorical exclusions set forth in 10 CFR 51.22(c)(9) and (c)(10). Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the 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. Letter, H. K. Nieh, NRC, to B. Bradley, NEI, "Final Safety Evaluation for Nuclear Energy Institute (NEI) Topical Report (TR) 04-10, Revision 1, 'Risk-Informed Technical Specification Initiative 5B, Risk-Informed Method for Control of Surveillance Frequencies' (TAC No. MD6111)," September 19, 2007 (ADAMS Accession No. ML072570267).

4. RG 1.174, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis," NRC, July 1998 (ADAMS Accession No. ML003740133).

5. RG 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," NRC, August 1998 (ADAMS Accession No. ML003740176).

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

7. ASME PRA Standard ASME RA-Sb-2005, "Addenda B to ASME RA-S-2002, 'Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications,'" ASME, New York, New York, December 30,2005.

- 16

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

9. NEI 05-04, Revision 0, "Process for Performing FOllow-On PRA Peer Reviews Using the ASME PRA Standard," NEI, Washington, DC, January 2005.

Principal Contributor: J. Patel Date: March 29, 2011

March 29, 2011 Mr. Regis T. Repko Vice President McGuire Nuclear Station Duke Energy Carolinas, LLC 12700 Hagers Ferry Road Huntersville, NC 28078 SUB~IECT: MCGUIRE NUCLEAR STATION, UNITS 1 AND 2, ISSUANCE OF AMENDMENTS REGARDING REVISION OF THE TECHNICAL SPECIFICATIONS TO RELOCATE SPECIFIC SURVEILLANCE FREQUENCIES TO A LICENSEE-CONTROLLED PROGRAM USING A RISK-INFORMED JUSTIFICATION (TSTF-425) (TAC NOS. ME3724 AND ME3725)

Dear Mr. Repko:

The Nuclear Regulatory Commission has issued the enclosed Amendment No. 261 to Renewed Facility Operating License NPF-9 and Amendment No. 241 to Renewed Facility Operating License NPF-17 for the McGuire Nuclear Station, Units 1 and 2. The amendments consist of changes to the Technical Specifications (TSs) in response to your application dated March 24, 2010, as supplemented by letters dated November 18, 2010, and March 2, 2011.

The amendments revise the TSs by relocating specific surveillance frequencies to a licensee-controlled document using a risk-informed justification.

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.

If you have any questions, please call me at 301-415-1119.

Sincerely, IRAJ Jon Thompson, Project Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-369 and 50-370

Enclosures:

1. Amendment No. 261 to NPF-9

2. Amendment No. 241 to NPF-17

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

Public LPL2-1 RlF RidsNrrPMMcGuire Resource (hard copy)

RidsAcrsAcnw_MailCTR Resource RidsNrrDirsltsb Resource RidsNrrLAMOBrien Resource (hard copy)

RidsNrrDraApla Resource RidsNrrDorlDpr Resource RidsNrrDorlLpl2-1 Resource RidsOgcRp Resource RidsRgn2MailCenter Resource J. Patel, NRR ADAMS Accession No ML110680357 *concurrence via memo dated 2123/11 ML110420327 OFFICE NRRlLPL2-1/PM NRRlLPL2-1/LA DIRSIITSB/BC DRAIAPLAlBC OGC NLO NRRlLPL2-1/BC NRRlLPL2-1/PM RElliott (w/commentsl NAME JThompson MO'Brien CSchulten for) DHarrison* DRoth GKulesa JThompson DATE 03/16/11 3116111 3/16/11 02/23/11 3123111 03/28/11 03/28/11 OFFICIAL RECORD COpy

v t e Letter Sequence Approval
TAC:ME3724, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed) TAC:ME3725, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed)
Initiation Request, Request, Request Acceptance... Supplement Administration Questions 21 October 2010 Answers 18 November 2010 Results Approval Other:
MONTHYEAR2010-11-18 [Table View]

ML110680357

Text

SUBJECT:

Dear Mr. Repko:

Enclosures:

Attachment:

Attachment:

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

Dear Mr. Repko:

Enclosures:

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