NRC 2015-0004, LAR 266 to Revise Technical Specifications to Adopt TSTF-51 0, Revision 2, Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection, Using the Consolidated Line Item Improvement Process

LAR 266 to Revise Technical Specifications to Adopt TSTF-51 0, Revision 2, Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection, Using the Consolidated Line Item Improvement Process

ML15086A378
Person / Time
Site:	Point Beach
Issue date:	03/27/2015
From:	Mccartney E Point Beach
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
NRC 2015-0004, TSTF-510, Rev 2
Download: ML15086A378 (30)

Text

March 27, 2015 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Point Beach Nuclear Plant, Units 1 and 2 Docket 50-266 and 50-301 Renewed License Nos. DPR-24 and DPR-27 NRC 2015-0004 10 CFR 50.90 License Amendment Request 266 to Revise Technical Specifications to Adopt TSTF-51 0, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection," Using The Consolidated Line Item Improvement Process Pursuant to 10 CFR 50.90, NextEra Energy Point Beach, LLC (NextEra) is submitting a request for an amendment to the Technical Specifications (TS) for Point Beach Nuclear Plant (PBNP) Units 1 and 2.

The proposed amendment would modify TS requirements regarding steam generator tube inspections and reporting as described in TSTF-51 0, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection." provides a description and assessment of the proposed changes, the requested confirmation of applicability, and plant-specific verifications. Attachment 2 provides the existing TS pages marked up to show the proposed changes. Attachment 3 provides revised (clean) TS pages. Attachment 4 provides existing TS Bases pages marked up to show the proposed changes.

Approval of the proposed amendment is requested by March 2016. Once approved, the amendment shall be implemented within 60 days.

In accordance with 10 CFR 50.91, a copy of this application, with attachments, is being provided to the designated Wisconsin Official.

If you have any questions please contact Mr. Michael Millen, Licensing Manager, at 920/755-7845.

NextEra Energy Point Beach, LLC, 6610 Nuclear Road, Two Rivers, WI 54241

I declare under penalty of perjury that the foregoing is true and correct.

Executed on March 27, 2015 Very truly yours, NextEra Energy Point Beach, LLC

~VVlG~

Eric McCartney Site Vice President Attachments: 1.

2.

3.

4.

Description and Assessment Proposed Technical Specification Changes (Mark-Up)

Revised Technical Specification Pages Proposed Technical Specification Bases Changes (Mark-Up) cc:

Administrator, Region Ill, USNRC Project Manager, Point Beach Nuclear Plant, USNRC Resident Inspector, Point Beach Nuclear Plant, USNRC PSCW

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ATTACHMENT 1 NEXTERA ENERGY POINT BEACH, LLC POINT BEACH NUCLEAR PLANT, UNITS 1 AND 2 LICENSE AMENDMENT REQUEST 266 ADOPTION OF TSTF"510, REVISION 2, HREVISION TO STEAM GENERATOR PROGRAM INSPECTION FREQUENCIES AND TUBE SAMPLE SELECTION" DESCRIPTION AND ASSESSMENT

2.0 ASSESSMENT

2.1 APPLICABILITY OF PUBLISHED SAFETY EVALUATION 2.2 OPTIONAL CHANGES AND VARIATIONS 3.0 REGULATORYANALYSIS 3.1 NO SIGNIFICANT HAZARDS CONSIDERATION DETERMINATION 4.0 ENVIRONMENTAL EVALUATION 3 pages follow

1.0 DESCRIPTION

The proposed change revises Specification 5.5.8, "Steam Generator (SG) Program" and 5.6.8, "Steam Generator Tube Inspection Report." The proposed changes are needed to address implementation issues associated with the inspection periods, and address other administrative changes and clarifications.

The proposed amendment is consistent with TSTF-51 0, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection."

2.0 ASSESSMENT

2.1 Applicability of Published Safety Evaluation NextEra Energy Point Beach, LLC (NextEra) has reviewed TSTF-51 0, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection," and the model safety evaluation as part of.the Federal Register Notice of Availability dated October 27, 2011 (76 FR 66763). NextEra has concluded that the justifications presented in TSTF-510 and the model safety evaluation prepared by the NRC staff are applicable to Point Beach Nuclear Plant (PBNP) Units 1 and 2 and justify this amendment for the incorporation of the changes to the PBNP Units 1 and 2 TS.

2.2 Optional Changes and Variations NextEra is not proposing any variations or deviations from the TS changes described in the TSTF-510, Revision 2, or the applicable parts of the NRC staff's model safety evaluation as part of the Federal Register Notice of Availability dated October 27, 2011 (76 FR 66763).

PBNP Units 1 and 2 TS utilize different numbering than the Standard Technical Specifications on which TSTF-510 was based. Specific differences are:

TSTF-510 TS 5.5.9 corresponds to PBNP Units 1 and 2 TS 5.5.8 TSTF-510 TS 5.6.7 corresponds to PBNP Units 1 and 2 TS 5.6.8 In addition, the proposed change corrects an administrative inconsistency in TSTF-51 o, Paragraph d.2 of the Steam Generator Tube Inspection Program. In Section 2.0, "Proposed Change," TSTF-510 states that references to "tube repair criteria" in Paragraph dare revised to "tube plugging [or repair] criteria." However, in the following sentence in Paragraph d.2, this change was inadvertently omitted, "If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube repair criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated" (Emphasis added).

NextEra does not have an approved tube repair criteria. Therefore, the sentence is revised to state "tube plugging criteria" and the expired tube repair criteria for Unit 1 Refueling Outage 31 and the subsequent operating cycle is deleted.

Page 1 of 3

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3.0 REGULATORY ANALYSIS

3.1 NO SIGNIFICANT HAZARDS CONSIDERATION DETERMINATION PBNP Units 1 and 2 requests adoption of an approved change to the standard technical specifications (STS) into the plant specific technical specifications (TS), to revise the Specification 5.5.8, "Steam Generator (SG) Program," 5.6.8, "Steam Generator Tube Inspection Report," and LCO 3.4.17, "Steam Generator (SG) Tube Integrity/' to address inspection periods and other administrative changes and clarifications.

As required by 10 CFR 50.91{a), an analysis of the issue of no significant hazards consideration is presented below:

1. Does the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No The proposed change revises the Steam Generator (SG) Program to modify the frequency of verification of SG tube integrity and SG tube sample selection. A steam generator tube rupture (SGTR) event is one of the design basis accidents that are analyzed as part of a plant's licensing basis. The proposed SG tube inspection frequency and sample selection criteria will continue to ensure that the SG tubes are inspected such that the probability of a SGTR is not increased. The consequences of a SGTR are bounded by the conservative assumptions in the design basis accident analysis. The proposed change will not cause the consequences of a SGTR to exceed those assumptions. Therefore, it is concluded that this change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2. Does the proposed change create the possibility of a new or different kind of accident from any accident previously evaluated?

Response: No The proposed changes to the Steam Generator Program will not introduce any adverse changes to the plant design basis or postulated accidents resulting from potential tube degradation. The proposed change does not affect the design of the SGs or their method of operation. In addition, the proposed change does not impact any other plant system or component.

Therefore, it is concluded that this change does not create the possibility of a new or different kind of accident from any accident previously evaluated.

3, Does the proposed change involve a significant reduction in a margin of safety?

Response: No The SG tubes in pressurized water reactors are an integral part of the reactor coolant pressure boundary and, as such, are relied upon to maintain the primary system's pressure and inventory. As part of the reactor coolant pressure boundary, the SG tubes Page 2 of 3

are unique in that they are also relied upon as a heat transfer surface between the primary and secondary systems such that residual heat can be removed from the primary system. In addition, the SG tubes also isolate the radioactive fission products in the primary coolant from the secondary system. In summary, the safety function of a SG is maintained by ensuring the integrity of its tubes.

Steam generator tube integrity is a function of the design, environment, and the physical condition of the tube. The proposed change does not affect tube design or operating environment. The proposed change will continue to require monitoring of the physical condition of the SG tubes such that there will not be a reduction in the margin of safety compared to the current requirements.

Therefore, it is concluded that the proposed change does not involve a significant reduction in a margin of safety.

Based on the above, NextEra concludes that the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and, accordingly, a finding of 11no significant hazards consideration" is justified.

4.0 ENVIRONMENTAL EVALUATION The proposed change would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR Part 20, or would change an inspection or surveillance requirement. However, the proposed change does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluent that may be released offsite, or (iii) result in a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9),

Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment needs be prepared in connection with the proposed change.

Page 3 of 3

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.. o "' 0 o ooo o oo o 00 0.... 0 000 0 000 0 0 0000...,, 0 "o oooo OOOOOOOo 0 00.. 0 ATTACHMENT 2 NEXTERA ENERGY POINT BEACH, LLC POINT BEACH NUCLEAR PLANT, UNITS 1 AND 2 UCENSE AMENDMENT REQUEST 266 ADOPTION OF TSTF-510, REVISION 2, "REVISION TO STEAM GENERATOR PROGRAM INSPECTION FREQUENCIES AND TUBE SAMPLE SELECTION" PROPOSED TECHNICAL SPECIFICATION CHANGES (MARKUP COPY) 1 0 pages follow

3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam GenerC~tor (SiG) Twb.E? lntE?grity LCO 3.4.17 SG tui:Je integrity shall be maintained.

SG Tube integrity 3.4.17 All 8{3 t!-lbes satisfying the tube ~* iteria.shall be plugged in acc;prqance with the Steam Generator.. ram.

APPUCABILJTY:

MODEs 1, 2, 3i and 4.

AC1IONS

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Separflt!3 Condition entry Is allowed for each SG lube;

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CONDITION A one or more.SG tube$.

.s5=1lisfying the tube ffil3atF criter!C1 i'\\nd nptplugged ln aeicordarioe wlth the steam 'Ge*neratbr

Program, AND A.2 V~dfy tube (nt~grity bf the

affected tube(s) is*

maihtained until the next refueling outage or SG ttibe inspection.

PIL!g tt)e 9ftected twb.e( s) 1n

~oc:ordance with thE! :St(:)am Generator Progtaln.

COMPLETioN TIME 1 days Prior to.entering Mobs 4 following the 11E:Jxt rMuf>Unil qu{ag~

• or SG tube inspection B.

Req~ired Action and B, 1 BE:J. In Mo.bE 3.

6hows

~.ssocigte<;l 09fi1Pletion Time.ofOongition A not AND met.

.bR SGtub!3 iiJtegrity not maintained.

• Point Beach Be in MODE5.

36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> 3.4.17*1 Unit 1. -Amendment No. m Unit 2.. Amendment No.~

Revised hy IQft~wdatec:J :Septemser 18; 2006

SURVEILLANCE REQUIREMENTS SR 3.4.17.1 SURVEILLANCE Verify SG tube integrity in accordance with the Steam Generator Program.

$R 3.4.17,2 Verify that each ih_speoted SG tube that satisfies the tt)be t'Bj3aif crtfE:Jrla is pJqgQed ih aqcbrdCinC~ With the

/Generator Pro~ram.

I fP1Uggin0j SG Tube Integrity 3.4. 17 FREQUENCY In accordance with the Steam Generator Prqgram Prior to.entering MODE 4 folfowil')g a SG tube inspeetion Po1ht Beach 3.4.17-2 Unit 1 -Amendment No;~

Unit 2 *- Aim3hdnierit No. ~

• Rqyised py lpttor auted Sept<mWer.1 S, 2006

Programs and Manuals

_5.5 5.{3 Program~ and Mclnllals 5.5,8 steam Generator (SG) Program Point Beach A Steam Generator Prograrn.shall be established and implemented to ensure thC!t SG lllbe integcity i~ maintained. In flddition, the Steam Generator Program shall lnducle the folloWing~loos:

a.

Provisiohs for.condition monitoring assessments. Condition monitoring assessment mecli!S an. evalu;;~.ti<:>n Qf the lias found" con~iUon of the tubing With tt:ispe*ct to fhe performance cdteria for structural inJegrity cHltJ C\\CGkle11t induced leakage. The "as found" condition refers to the condition of the tubing dUring an SG'ihspection outage, as determined from the inser\\tice inspection re$.q1Js Qf py.other meflnS, prlgr to the Plllggipg of tubes.

Condition monitoring assessments shall be condt,~cted dl;lrh1g each outage during which the SG tubes are inspected or plugged to confirm thf!t the perforinanc_e.criteda are Beirig met.

b.

Performanc~ cri~E?riEl for s~ twbe in,t'1;1grity,.$G t\\JPl inlemity shall 9e m111hta!oecl by ni~<?tin(:l the performance criteria f9r)ube structural integrity, accident induced l~akagei ~nd operatitmal LEAKAGE.

L Str~ctllral 'integrity perl'onm~no~ criterion: All.in~service steqm generator tubes shaH r~taJn struchJr<ll integrity over tb~ tun rqnge 9f normai op$rating conditions (including Startup, 6petatfon in the power range, hot standby, and bbbl doww,a'l~ all antiCipated transients inc!pdeq in the pe$ign speCificatlorytana design basis ac:;cidel]ts.. TNs Includes ret~hiing ~i ~af!3tY factor of 3.0 against burst under notfill:11 steady state full poWer operation pdmary-to-secblidary pressure differential' and a safety *factor of 1 A against burst applied to, the

• desfgn basis ~<::oldl!l( prlmary".to-s~c:;90cl9ry pres§yre differenti?ls.

AP.~rt from the ;;~p:ove (¢quirements, a~:cHtloni;~! 16.a~ing qqnditlons asso_ciated With the design basis $ccide.i1ts, or cortibii1~iioh :of ac.cidents in accordance with the desigh arid licensitig basis;.shall also be evaiuated :to det~rrnln~ If th.e ~s~o9i?t.edjo_Rcfs c;on,tripyt~

significantly to burst or collapse, In the as$e$sntemt <;>f t~be integrity, those loads that do significantly affect but§t or poil~ps_e sht;!ll b.e determined and assessed in combination with the loads aUeto prf3ssure wHh a safety factor of 1 ;2 on the go[lbine<;l RrimCJrY loqgs qlld 1 :0 on <p<ial secondary loads.

2.

Accident induced leakage performance ~criterion: The prirhary to

$~ec9_ndary gcddent Tnduc.ed lrakag~ rat~R fgr any qesign b~sis gc;:ckl.etif. 'qther than a. $G tube rupture, sh<ill not !3><Ceed the leakage r.ate asswned in the a'ccident analysis in terms of total leakage rate Unit 1 - Amendment No. m.

0nli 2 ~.A.m~nd~1~nt No. m

Programs.and Manuals 5,5 5.5 Programs and Manuals

$i5.8 Steam Generator (SG) Program (continued)

PoiriJ Beach fat all SGs and leakage rate for an iriqividual SG.

Le~~age !s not fo exceea 500 gallons per day per SG,

3.

The operationaJ LEAKAGE performance criterion is ~pecjfied in Leo 3.4.13, "RCS Operatiomil LEAKAGE."

c.

Provisions for s(3 tube ~

criteria. Tubes found by inservice hispectiOn to contaill flaW$ With a depth al to or exceeding 40% of the r)Qm1nal tube WF111 thickness snail. be plu~ged.

plpgging The fQIJovAng alternate tube repair criteria shall be.applied as a'ri altematiVS to-the 40% depth based criteria:

1. For Unit 1 Refueling Outage 31 and the subsequent operating-GYGJe, tube$i.~.iith flav/s having a circumferential component less than or eq-ual to 203 d89r9es.fo.blnd in the portion of the tube below 17 inches from the top 9f the tubesheetana.above 1 inch frohi the bottom of th~

tubesheet do not reqbllre plugging. *TiJbeswithfla*tis having a circumferential component greater than 203 deg113~s foblnd in the portion of the tube beloW 17 inches froi11 the top of th~ tubesheet and above 1 inch from the bottom of the tubesheet shall be removed from

.s~tvic;~.

Tubes v.iith saPAS.e induced flaWs located *vVithin the region *from the4Gp ofth~ t~o~p~sheetto 17 inches.below the tOp c# the tubesheet shall be l"$mQ'/$'d from service, tube§i w~?Jfce. induced axial. cracks found iii the portioa-Qf tbe typ~ belo'N 17 inches-from the tQp-:c;>f the tubeSheet

~lugging

. '.~lheh' more than bne fiavl vvith circumferential botrip6nsnts is found hi th:e portion of the tblbe belo\\6.' 17 inches from the top of the*tubesheet and ab01.ie 1 ihch from the bOttom of the tubesheet vvith the total of tl:!e circumferE3ntiafcompooents greater thah203 degfees and an ~xial

~$pataiiori

• dista-ncB-Gf-!~s 'than *1 inch, then:the tube shaWbe* r.effiG\\JeG trom service. VI/hen the circumferential pomponents of each-otthe flav.;s are added, it is acceptable to coblnt tlie '9'/~rlapped pqrtions only

0!1,Q(3-.In the total of circumferential components.

Unit 1 -Amendment No. m Unit 2 N Arhenahieht No. *2-2 Programs and Manuals 5.5 5.5 Programs and Manuals VVheRone or more fl~~~i::mants ar-8--fGYHG-ih

~rtlon pf fhe t~l:le wjthin 1 inRh from the bottom~e tubeshoot;.

an~the totf!ll of tbEl.clrcum~ranti~l compGF!e~Bdjn the.tuf)e exceeds 94 degrees; then tha tube shall be remO'i~d from ser.tlc~

l/1/hen *one or more flaws with circumferential components are found in the portion.of the tube~tlithin 1 inch from the bottom of the tubesheet and Within 1 i_nch e~xial sepC~ration distance of a fla>.*l abGV~ch from the hotton1 of the tubashaet; and the total. of the circumferential compolier\\ts found. ih the tube excee9-M-degre.es, then theitilbe shall be removed fro.rn~eyy)ge; When~he circumferential*compen~f

. each oHh~ flaws an~ added, itis ~ccept?tble to C<_n~(lt the o~R-apped PGrtions on.ly once in the totai-Gf circutnferaniial cbmponants.

+his alternate tubtH9peiir criteria fs not applicable-to the tube at ro'l'l 38 column 69 in the A steam generator, which is not expanded the full l:enQtl:l 'of the tube sheet.

d.

Provisions for SG tupe ins.P~PtlQQS, Periodic SG tu_be inspections :shall be.

performed. The number an9 portions.of the tubes inspected and methods ofinspectibli snail be perfor.rr!ed with the objective of detecting flaws of any type (e.g.i volumetric flaws, axial and circumferential <ki:icks) that may be.

~~...-resent along the !E:)_ngth Qf the tp[3e,, frotn the, tube"to~tubesheetweld at the L--'----l tube 1n

• * -~'-to'"t besheet weld !:It the tl.lbe outlet; and that may satisfy the 'qppJicable tu t:epaH: criteria.* The tubel'-to-tubesheet weld is not part of the "tube. In addition to meeting the requirements of d.1, d2, and d~3 b:e!ow, the inspection spope., ihspection methogs, and inspection intervals shctll be.such *as to ehs.ure th.at SG tube integrity is maintained untn the next sG. inspection..An as!>essm~tit of degradation §..hall be pelformed to determine the type and location of flaws to whic

'e tubes may be susc?pUble and, pasE;tcl Pl"l thil3 assessment, to deter

• e which inspection Point Seach methods ne~d to b~ ~rnployed and at what location,

'~-s~e*ssment

1.

Inspect 100% of the tubes ih each SG during the first refueling outage following SG repla~~nieht Unit 1.;; Ame.nd.ment No; ~

Unit ?., Amen~m~nt Nq, ~*

Programs ahd Manuals 5.5 5,5 ProgralJis ~mq Manuals affecte.d and poteiltialty affected

2.

3, pnsr 1 1

. 'V

()

i. Unit 1.(alloy GOO ThermallY Treated tubes): mspeGt-4-00%~

tubes at sequential periods of 120, 90, and, thereafter, 60 effective

~~months. The first sequential p900G-shall-be-wnsklered to begin after the first inservica inspactioo of the SGs.. In additkm, inspect 50%. of the h.ibes by the refueling outage nearesl {1-u~

~@oinl ofthe period a_nd the re~~o%.0y the*rt:itUeJiflg ouiage n$~J(~stlhe ~nd_oHhe period. No SG shall operate for more than 48 effecti\\ie fUfl poiNer months or two refueling outages tv\\'hichever is less) without beiflg-jnspected-jlnsert2l ii, Un.it 2 (alloy 690 ThE3rm911Y Tr~atedtubes}: Inspect 100% o~

tLtb.e.s ~f s~qui;lntial periods of 144, 108,*72, ahd, thernaftar; 60 Mffictil;e full pol,,,cer months. The first sequential period shall be

.-Gohsi<:lsradto begin after the ~rst inssrvlca.-l8spactlon of the SGs; In addiiion, inspect.50% of the tubes by ths refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the and of the period. No SG shall operata tor more than 72 effective full -po*Nsr months_or thres refueling outage~ (*NI:!ichever is 1ess) Without being inspected.

results 1n more frequent rnspectrons If cr Indications qrt3.f()(Jnd In qny 9G tub eh' fflE} n~~.tlnspegti<;>n for e9c SC3 for the degradation mech

• m that GEl used the.crack Indication ~hc:JII not exceed 24 e f ve fUll poWer mohths orohe refueling outage (wliicheverr *

). If definitive inforrna~io!J, su_ch as from examination of.a puU~d tube,.diagnostic non-destructive testing, or ~nglh$~rihg E;iV9!0~Uon indioates that a crack-like indication is not associated. With~ crack(s), then th.e iri'dication need not be treated as a crack; e,

Provisions formonito.fing operatipnal primary to secondary LEAKAGE.

Point Beach

.5.5-.9 Unit -~,. Arnendment No. m Unit 2 -AtrlE?t1c;lrn§nt No. m

• • • • ~*****--*.. ***....................................................

~..................................................................................................................................... ~

INSERT 1 After the first refueling outage following SG installation, inspect each SG at least every 48 effective full power months or at least every other refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, and c below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 120 effective full power months. This constitutes the first inspection period; b)

During the next 96 effective full power months, inspect 1 00% of the tubes.

This constitutes the second inspection period; and c)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the third and subsequent inspection periods.

INSERT 2 After the first refueling outage following SG installation, inspect each SG at least every 72 effective full power months or at least every third refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b)

During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c)

During the next 96 effective full power months, inspect 100% of the tubes.

This constitutes the third inspection period; and d)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

Repc;>rting Requirements 5.6 5.6 Reporting Re*quirernents 5.6.6 PAM Report Wherl ~ report is required by Condition B or F of LCO 3.3.3, i*f:>ost AcCident Monitoring (PAM) instrumenfation, 11 _a rE)port sbflll be submitted within tlie following '14 days. The report s-hall outline the prepii:lnne~ c;tltern~te methoq of monitoring, the cause of the ihoperability! and the plan$ and s.chedule for r~stor1ng the instr.umentafion c:hannels of the Function to OPI::RABLE status. -

5.6. 7 Tendon Survelilance Report ApnormGII oonditJons obsE)rved during testing Will be.evaluated to detetmiM the eff(;)ot of s.uch condltlons on oonJainment structural integrity. This

~valuation should be completed Within 30 dayp of the iden_Uf(cafiol! of the condition. Any Qc>ndition which is determined in this eValuaUo.h to haVe ~

significant adverse effect on *cqnt~inment struotwClJ Integrity will be c_onsidered an abnormal Cle_f}radation of the oontainh1enf strl!ch,tre, Any abnormfll degradation of the contaJnmE)nt. structure icientified durihg the engineering evaluation of abnorina'i condition$ shall b~ reported to the NL!ciear Regqlaipry Commission pursuant to th.e requirement's of 10 GFR 50.4 Withih thirty days of that determination: Other conditions that ind_icate possible effects oh the integrity of two o.r more tend~ns sha_H be reportable in the J3~m~ manner. Such reports shall.ihollide a description of the tendon.oondition, the pondition of the concrete (t?~Pec.:ially at tendon anchorqges), the inspection procedure and the oorre:ctiv~ aption taken.

5.6.8 Steam Generator Tube Inspection Report Point Beach A r~pp_rt ~hCo~ll be s~t~mitted Within 180 days after the initiai entry in.to M.ObE 4 folloWhlg opriip!etion of an inspectioo performed ii1 accordanceWith the Spedflcatioli 5.5.81 Steam Generator (8(3) Program, The report shaH inclUde:

l'l*

b.

c.

d The soope of inspections peifo'n'ned bti each SGt

-,ii;ct~egradation m~qhahisms fotmd; Nondestructive examit1atio.n techniqUes Ufilizeq for e;;~¢h d~grad~tion m,echc:u1ism, l6.cation, orientation (if Hne.ar), ~n~ iYleiil~ured s1zes (if avaHabl,e) *oLservice induced indiCatiohS1

'5.6,.6 Unit 1.. Aitfenoment No. 22.~

Unit 2 - Amehdl'lie.nt No. *M

5,9 Reporting Requirements R~porHng R.eqqiremE:Jnts 5.6 r-----~

and th) effective plugg!ng percent0ge in e,ach.stea111 gener;:Jtor,

e.

Number of tUbes plugged during the inspection outa

~. degradation mechanism,

• ~

f.

+Gtal humber andpercentage Q{tubes plugged to date,

g.

The results of condition monitoring, inCluding the results of tqqe pulls ~nd (n-situ testing~flO The affective plup~ntag~ f{)f ~J4>>.Y9WBfH!t8~ch SG...

5.6.8 Steam Generator Tube Inspection Report< continued)

POint s~aoh t;

FolloWing compllc00ii ofan 'inspaciion parfo~i:l in Uhit 1 Ref~

OtjJaga31 *(anfl any inspections pa*rrormad in the subsaquantopamtmg.

cycl~)l tha nlllrl~~r.*of, indications =and losatioh I sii9; ori@.htatior+,-wl:iath>>:.

initiamd on primary or,secondary side 'for a~ch service indYGed flaw i.VIthin tlie thickm~ss oftha tubashaat, and the total-of-the circumfarantial compGnants and-any Circumferential Q.VgJ:Jap below 17 ir:~chas frorn the top of the tt1beshaat as determined in accordance with TS 55.8,

j.

• Fdllbi,Alir)g compl~tioh otah inspection paifortnad ih Urnt 1 Rafualli:lg O'ut~ga 31 (ahd any iiispeu;tibns performed in the subsaquBAt

~4H9-GYv!e); the primary to secondary LEAKAGE rata o~ooAIOO bi each steam gan~rator (If iHs not r,rao,ficallo assign" leakage to an ii:JdividuaiSG, the entire primary ta. ~econdary kEZAJ<:.A;(]E silo~

GGi:l~tivaly assumed to ba from one steam generator) durin~

~Ia preceding the inspection which is the subject of the report,

~n<il kT*

Follo\\Aiin~l~.t\\,.Qf an ih~\\P~otion-psrf(jwne~ in Unit *1 Ra(uOOng.*

Ot~tlilga 31 (and.an~,(ihspadioi1s petfoonad-iA-tl:la subsequent QP~ratlng Mc:;laJ, tha c~)ca1atad accident laaka?Je rat@ fiom-U:la poitJQIJ of thetuba'~elow 17 incha~drorn Jhe. tq~~t.Jo~

lh"e most limiting accident in the most limiting steam g.@B~~

p;6-7 Unit 1 - Arnehdiheht Nd. ~4)

Unif 2 "Amendment No. 634

ATTACHMENT 3 NEXTERA ENERGY POINT BEACH, LLC POINT BEACH NUCLEAR PLANT, UNITS 1 AND 2 UCENSEAMENDMENTREQUEST266 ADOPTION OF TSTF-510, REVISION 2, "REVISION TO STEAM GENERATOR PROGRAM INSPECTION FREQUENCIES AND TUBE SAMPLE SELECTION" REVISED TECHNICAL SPECIFICATION PAGES 8 pages follow

Programs and Manuals 5.5 5.5 Programs *and Manuals 5.5.8 Steam Generator (SG) Program Point Beach A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following:

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes.

Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged to confirm that the performance criteria are being met.

b.

Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1.

Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), and all anticipated transients included in the design specification, and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary~to~secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary~to~secondary pressure differentials.

Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate 5.5-7 Unit 1 - Amendment No.

Unit 2 -Amendment No.

~**.............................................................................................................................................................................................................................................................................

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Program (continued)

Point Beach for all SGs and leakage rate for an individual SG.

Leakage is not to exceed 500 gallons per day per SG.

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c.

Provisions for SG tube plugging criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging criteria. Tlye tube~to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d. 1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what location.

1.

Inspect 1 00% of the tubes in each SG during the first refueling outage following SG installation.

2. i. Unit 1 (alloy 600 Thermally Treated tubes): After the first refueling outage following SG installation, inspect each SG at least every 48 effective full power months or at least every other refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, and c below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable Unit 1 - Amendment No.

Unit 2-Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals Point Beach tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period.

Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage In an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a)

After the first refueling outage following SG installation, inspect 1 00% of the tubes during the next 120 effective full power months. This constitutes the first inspection period; b)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; and c)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the third and subsequent inspection periods.

ii. Unit 2 (alloy 690 Thermally Treated tubes): After the first refueling outage following SG installation, inspect each SG at least every 72 effective full power months or at least every third refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations 5.5-8a Unit 1 -Amendment No.

Unit 2 - Amendment No.

~-.. ------*-----**--***-*--**-*------*-* ***---******--*****---~***-**-******----

• • • -****--*--**--------~-*-**-***-*****---------~*--**--*--*--***---*****--*-**--***--------*.. *----*-----*---*---------------*--*---**-----*-------------~------..... -----**-*-**............ _...........,.... -

Programs and Manuals 5.5 5.5 Programs and Manuals Point Beach inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no Jess than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a) After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months.

This constitutes the first inspection period; b) During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c) During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d) During the remaining life of the SGs, inspect 1 00% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

3.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever results in more frequent inspections). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

5.5-9 Unit 1 - Amendment No.

Unit 2 -Amendment No.

3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained.

SG Tube Integrity 3.4.17 All SG tubes satisfying the tube plugging criteria shall be plugged in accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS

---

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

Separate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION A One or more SG tubes A.1 Verify tube integrity of the satisfying the tube affected tube(s) is plugging criteria and not maintained until the next plugged in accordance refueling outage or SG with the Steam tube inspection.

Generator Program.

AND A.2 Plug the affected tube(s) in accordance with the Steam Generator Program.

B. Required Action and B.1 Be in MODE 3.

associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5.

OR SG tube integrity not maintained.

Point Beach 3.4.17-1 COMPLETION TIME 7 days Prior to entering MODE 4 following the next refueling outage or SG tube inspection 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours Unit 1 ~Amendment No.

Unit 2 - Amendment No.

~** __,,,. *-***........ *-****. _..,.................................................................................................... -... -............................ _.............................................. _................................................................................,.,_............ -........ _..

SG Tube Integrity 3.4.17 SURVEILLANCE REQUIREMENTS SR 3.4.17.1 SR 3.4.17.2 Point Beach SURVEILLANCE Verify SG tube integrity in accordance with the Steam Generator Program.

Verify that each inspected SG tube that satisfies the tube plugging criteria is plugged in accordance with the Steam Generator Program.

FREQUENCY In accordance*

with the Steam Generator Program Prior to entering MODE 4 following a SG tube inspection 3.4.17-2 Unit 1 -Amendment No.

Unit 2 -Amendment No.

......... '"'..................................................................... '............................................................. *****~*..................................................................................................................................................................................................

'"' ""..,,,.,.. o,,,,.,,.,.,,,,,, """,,..,,,_ "'

oooo '''"'""'"' "'""0*

-o*.,.,,.,_,..,

''"""-*"'"'-""'"""'"-"'H Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.6 PAM Report When a report is required by Condition B or F of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6. 7 Tendon Surveillance Report Abnormal conditions observed during testing will be evaluated to determine the effect of such conditions on containment structural integrity. This evaluation should be completed within 30 days of the identification of the condition. Any condition which is determined in this evaluation to have a significant adverse effect on containment structural integrity will be considered an abnormal degradation of the containment structure.

Any abnormal degradation of the containment structure identified during the engineering evaluation of abnormal conditions shall be reported to the Nuclear Regulatory Commission pursuant to the requirements of 10 CFR 50.4 within thirty days of that determination. Other conditions that indicate possible effects on the integrity of two or more tendons shall be reportable in the same manner. Such reports shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedure and the corrective action taken.

5.6.8 Steam Generator Tube Inspection Report Point Beach A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.8, Steam Generator (SG) Program. The report shall include:

a.

The scope of inspections performed on each SG,

b.

Degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

Location, orientation (if linear), and measured sizes (if available) of service induced indications, 5.6-6 Unit 1 -Amendment No.

Unit 2-Amendment No.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.8 Steam Generator Tube Inspection Report (continued)

Point Beach

e.

Number of tubes plugged during the inspection outage for each degradation mechanism,

f.

The number and percentage of tubes plugged to date, and the effective I

plugging percentage in each steam generator,

g.

The results of condition monitoring, including the results of tube pulls and 1

in-situ testing.

5.6-7 Unit 1 -Amendment No.

Unit 2-Amendment No.

ATTACHMENT 4 NEXTERA ENERGY POINT BEACH, LLC POINT BEACH NUCLEAR PLANT, UNITS 1 AND 2 LICENSE AMENDMENT REQUEST 266 ADOPTION OF TSTF"510, REVISION 2, "REVISION TO STEAM GENERATOR PROGRAM INSPECTION FREQUENCIES AND TUBE SAMPLE SELECTION" PROPOSED TECHNICAL SPECIFICATION BASES CHANGES (MARKUP COPY FOR INFORMATION ONLY) 3 pages follow

aASES APPLICABLE SAFETY ANALYSES LCO Point Beach SG Tobe Integrity 8 3.4,17 The st~am generator tube rupture (SGTR) accident is the.limiting design basis eVent for SG tubes ahd avoidihg ah SGTR is the basis for this SpecificCition, The analysis of a SGTR event as$Umes a bounding primary tc).se,cond§ry LEAI<AG~ rate gree1ter thi;in or equal hJ $ql,.l~1 to th~

pperalional LEAi\\AGE rate ihnits ih 1-.00 $.4.13, *~Res Operational LEAKAGE," plus the leakage rate associatedviiith a double-enCied rupture of a single 'tube. The accident analysis for a SGTR assumes fhe conti:ll1llhated secondary fluid.is rele.asecl fo the atmosphere via safetY valves.

The analysis.for' design basis accidents and transients other than a SGTR

~~S!.)IJle the Scp fU.be~ retC\\ill thetr strudur~l integfity (i.e., they are as~Ljtne~ !iot to rupture.) ln. the$~ ani:jlyses, th$ steii:lm,d)scharg$ to the attrrosphere is based oh the total primary to secondary LEAKAGE from all SGs of 500 gallons per day or is assurned to increase to 500 gallons per day e~s a res!Jlt of acqJdenfinduced cgndifions. For accidents that do nof involve fuel damage, the primary coolant activity level of DOSE EQLii'VALENt 1-131 is as.$lJnied to I:Je equal to the LCb 3.4. 16, "Res Specific Activity," limits. For accidents that assume fuel damage, the primary coolant activity is a function of the amount of activity released fr(Jm the darn?geq fuel. The qose consequences ofthei?e e.v~}lts cjre Within the limits pf (3DC 19 I Ref. 2), alicl1 0 CFR 50.67 (Ref. 3) dose guideline limit.

$t~arrr.:fJenerf:~(.or tube iptegrity ~fl~isfie~ ¢riteriqn,2 ;of to GPR50,$6(c)(2)(ii).

The LCO reqljirE)s th.at SG t1,1pe integrity be 11')aintaineg, ThE:J LC(.) also re:),ql.lires ll-Jat all $G tu.bes thqt.saHsfy fh.~J~p~ir:o* _titer! a be pll,!Qge(j in

(;ICGQtdance With the st'eam G~rwr~tor Program:: r. '...

p uggrng Dlitirig ah SG insliei::tioh, C! ~

e'tube at satisfies the.Steam Gener9lor Progtam ~

c iteria is remov ** from service l?y plugging. lf a fybe W~s defetm!ned to satisfy the~ criteria but Was 'ri.ot plugged, the tUbe hiay still have tube lntewity.

• In thSJ ~Qntext ~f fhi$ $PE,JPiJJca_tiq!\\ §ln SG t1,1!2e is defihe<;i ~sthe entire length Qflhe.ft.li:Jt;J_, irw!u<;llM t!w iqpe w~l!, between the tqbe-to-tt,ibesheef weld adhetub(=i inletflndthetu.b.t?.. to*Hibe.sheet weld at the. tUbe outlet.

The tUbe~to*tubesheet weld is riot considered part ofthe lube.

A_~~ !Yb.~ h~l3 f!.l!?1:l int~grf{y when 1! {?gtJ$fi.e:s lhe $gi R!?rf9rm~nc¢ ~dterfq.

The. $.G p~rfotmahce cdt~d~ at~ d~fiMCl in.$pedfication $.5Jt ii$tearh Generator Program," and describe acceptable SG tube perfdtiiianbe.

Unit 1 -Amendment No;.240 lii1Jt2-Ain~ndrrt~hiNo. @44.

BASE:S LCO (coniimiec!)

APPLICABILITY ACTIONS SGTube Integrity 8 3.4.17 primary to secondary LEAKAGE indUced during the accident. The operational LEAKAGE performance crjtf'}rion provjdes an ob.8eJYab!e ind!ca!!~m of$~ tube cqnditiorw d.uripg piEjnt op(3rf:ltion. The limit on gpetfJtional LEAKAGE is contained in LCO 3.4.13, "RCS. open:~tiohal LEAKAGE. arid limits primary to secondary LEAKAGE through ahS' one SG to 150 gallons per day. This limitis based on the f:lssuwpUon tn?t.f;l

ingle orack le.f

lk

ihg this at)lount woukl not propagl;ltE

> to a B.GTR tinder the stress qpndition.s 9f a L.OCA.or a m~ln steam line bteak Jf this am6uht of LEAkAGE i.s due to more than one crack, the cracks are Very small, ahd the. aboVe.assumption is conservative.

Steam geher!'!tor twl:le integrity is thl;lllenged.When the pressurt3 diff~reriti~d across the tube.s is large. Large differentii:ll pressures across S.G tubes can only be experienced in MODE 1. ~; 3, or 4; RCS cgnditions are far I$$$ ch<;~Henglhg in MOPES 5 1:1hd 6 than during MODES 1., 2, 3, and 4. In MODE.S 5 and 6, primary lo sEicohaarY differential pressure is low, resulting in lower stresses am:l reduce.d.

pgtentlaJ tor L,_EAf<A(3E.

The ACTIONS.are modified oy a Note clarifyiqg that the Con~itions may b~ !?ntered in~ep~ngemt[y fGr e9ch SG fube. This is l;lcceptable be.oaqs~

~he Required Act.ions provide appropriate :<;:ompensatory :adjons for e§Ph aH~cted SG tube. Complying with the Required Actions titay allow for

.cbhtih'Lied Operation, ahd subsequent affected SG tUbes are:gciverned by subsequent Condition entry and application of f,lssoc;:i9ted Hequired Aotlgns.

. A.1 andA2

¢qnditic>n A 9pplies Jf.it is*dis.cqyereg the.. one or rn SG tubes.

eX~mined in an inservice inspeotio:n $a 'sfy the tube ~

criteria but were not plugged in accordance with e Steam Generator Prograhi as recfuiretlby SR 3.4.172. Afi e\\lafua

• n of SG tube integrily of the

~ffegfecl tu!;>e{?) !UU${ l?.e !Jl!=lcle.* $t am generator tube integrl1Y. is based O)l tneeting ~l)e $(3 pe.ffotJtl!

it1Ce

.*teria described in the Steam*

G~nl;irat6r'Progrgrn. Th~ $~0 mpaiJ: criteria define limits on SG tube degradation lhat alloW fot HaW groWth between inspections -While still providing assurance :that the SG performance cri.tefi~ w!Jt cqnJLOI,le to be met (t'l *9r9ed9 9eterming if a ~(,3* t!-lJ?,~ fhat should have b.l?eO pTugm~c!

has tub$ integrity; ~ll ev~lllation must be completed that demonstrate.s that the SG performance criteria Will continue to be met until tlie next fefu.eling outage or SG tube inspection. The tube integrity determination

'1~<~.4. ft-4 uJ;it 1 -Amt:1ntlment No. m Unit 2 '-Amendment No. ~

BA$E:$

SURVEILLANCE REQUIREMENTS

( continuE?d) lfcracl<indications are foUnd in any SG tune, tllr:i HlElXimum Inspection interval for all affected and potentially E!ffect~d SGs i~

restricted by Specification 5.5.8 untl.l subs.equent i'nspections support extending the inspection jnterv9l.

• Pain~ 13ea,ch SG Tub~ integrity

.8 3.4.17 The Steam GeQ.er(3.tqr Program determines the scope orthe inspection and the methods use o determine Whether the tubes contain flaws

~ati~fyh1g th3 t0be -~criteria; Inspection scope (i.e~~ which tubei> or

~rEjas* of tubirig within the SG are to be ins!Je9ted) it? a funqtlon ofexisting and potential ~egradation locations. Th~ St\\'3~n1 Generator Program also specifiE:Js the. inspection methods to be used to find potential degradation.

lnspectio.n methods are a fLfnction of degradation morphQiogyi non-destructive examiliatidri (NDE) technique capabll,itie~.,and Inspection locations.

he $je~m G.erwrator Ptogr~m defines the Frequency onm 3.4.17.1.

T Frequef1py Is determined by th*e operational assessmE:Jnt and other limit.. the SG. examination guidelines (Ref; 6). The $*~!;lam G.enerator Progra uses infqrmation on i;:l,xisting degrad~tion$ ~rid growth rates to d~termin~ n inspection Frequency that provides reasonable assurance that the tubin will meet the SG performance criteria a{ the next, s¢heduled insp tion. lti.addition, Specification 5,$..8 cohJciins prescriptive requir 1e1its concerning inspection intervals to provide added assurance tha e SG performance criteria will be met between sched4i~d inspections.

SR 3.4:17.2 byring al) sc;i [fl e,u I any in cted tube that satisfies the Stearn

(:?enercih?r pr

• ra

~criteria is re

• ed from serviqe. b,y,plwgging, The tube.~ cf' eria delineated ih $pecific *

• 5,5:8 are intended to ensure that tube. accepted for contill.L!eQ service $a *

. the SG performance _cri eria With allowance for error in the flaW Sl.

rne<;~s_urement. nd for future flaw groWth. In additii:Jrt; the tube~H:

cdti3fia, in co unction witH other elements 9r the $tE?arn G.i?nerator Program, eh ure that tile $G performance crited~ wifi ¢9htinue to be met until the n~ t lnspeqtion pf lhe subject tube(s). Refetehce 1 proVides guidance.* r performing operational assessments t6 verify that the tljbes re,rnainin in servic.e will continue to n1eet the SG p~rfgrmCJnce.c:[iterl~.

Tne H,quency of prigrto ente~Jng MODI; 4 foiloWlng a 'SG irispectlorr 11:1~\\.!

that the $i,nyei.Jlat;~~ fias been completed and all Wbes meet!ng t,h!;3 -~

criteria are plugged prior to sUbjecting the.SG !YP~~* to s(9Dif1c~nt primary to secondary pressure gifferE3riti~l..

B 3.4.17*6 Unit 1 ~Amendment No.i2;t3, Ullit 2 - AmendhEint No~ m

.*..,. ~..

.