Latest revision as of 22:47, 10 December 2024

Text

Proposed Tech Specs Sections 3.1,3.2,3.4,3.5 & 5.0 Re Reactivity Control Sys,Power Distribution Sys,Rcs,Eccs & Administrative Control,Respectively
	ML20154S290
Person / Time
Site:	Comanche Peak
Issue date:	10/14/1998
From:	; TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To:	;
Shared Package
ML20154S259	List: ML20154S290; TXX-9822, Submits follow-up Items Re Proposed Conversion to Improved Tech Specs Sections 3.1,3.2,3.4,3.5 & 5.0;
References
	NUDOCS 9810270366
	Download: ML20154S290 (39)
	v • d • e

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REACTIVITY CONTROL SYSTEMS POSITION INDICATION SYSTEMS OPERATING LIMITING CONDITION FOR OPERATION 3.1.3.2 The Digital Rod Position Indication System and the Demand Position Indication System shall be OPERABLE :nd cap;ble of deter;;;ining the control rod I1

183' po;ition;.;ithin i 12 steps.

APPLICABILITY: MODES 1 and 2.

ACTION:?

a.

With a maximum of one digital rod position indicator per bank group E* "

inoperable for"onelorimore groups;either:

1.

Determine the position of the nonindicating rodM indirectly by the movable incore detectors at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and I

i x;diotely withinl41 hours after any motion of the nonindicating rod which exceeds 24 steps in one direction since the last determination of the rod's position, or 2.

Reduce THERMAL POWER to less than 50% of RATED THERMAL POWER within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ;iorp Be in Mode 131withinjtheinextL6 hours.

! 2*C "

(K9) a 1

. New) W1th moreithan;one DigitaljRod: Position System!1ndicator;per; group

(

g inoperablelcomply withl ACTION 2a"LaboveTand;either; EI N 1A 1

,acegthe.controllrodslunder manualicontrollismediately1 e

itor'and Record RCS'T,/every; hour? and6estore'the 13 08 LS 0 3.1 20 digitairoa.pos1 tion 3nalcatorstourtMABLEistatusw1_th.in.24 1

z hoursisuchlthatla; maximum:of;one,digitallrod-position i nd i catorlperJ group ;i siinoperable / ~ or 2

BeinMode;31withinJhenext;67; hours.:

Separate;Actionientryjis! allowed for;each;inoperableirod position; indicator I

andleach demand"positionLindicator i

~

9810270366 981023 PDR ADOCK 05000445 P

PDR CPSES Mark-up of CTS - 3N.1 3N 1-17 10/1498

CONVERSION COMPARIS0N TABLE - CURRENT TS 3/4.1 Pfa]e 7 of 9 TECH SPEC CHANGE APPLICABILITY NUMBER DESCRIPTION DIABLO CANYON COMANCHE PEAK WOLF CREEK CALLAWAY 12-22 This change provides a new ACTION in the event the allowed outage times Yes Yes Yes Yes H

are not met for the rod misalignment actions. Prior to this change.

LCO 3.0.3 would have been entered allowing for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months prior to placing the plant in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . This change is more restrictive in that the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months time frame is eliminated.

13-01 The specific operabii..y attributes of the DRPI system would be moved to Yes Yes Yes Yes LG the Bases.

13-02 The requirement for inoperable digital rod position indication is changed Yes Yes Yes Yes LS-15 from "with a maximum of one per bank

to "one per group for one or more groups".

13-03 A 4-hour Completion Time is specified to verify rod position after Yes Yes Yes Yes LS-12 movement of a rod with inoperable indicators more than 24 steps in one direction.

13-04 A requirement would be added to bring the plant to MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Yes Yes Yes Yes M

if the required actions and completion times were not met.

13-05 The proposed change would retain an action statement, currently in the No. See CN No. See CN Yes Yes A

plant TS. that permits continued POWER OPERATION with more than one 13-08-LS-20.

13-08 LS-20.

digital rod position indicator per group inoperable.

13-06 The change would allow separate condition entry for each inoperable DRPI No. See CN No. See CN Yes Yes t

A or each demand indicator.

13-08-LS-20.

13-07 The proposed modifications to the SR would verify agreement between Yes Yes Yes Yes l

M digital and demand indicator systems prior to criticality after each removal of the reactor vessel head instead of every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The Frequency change is based on traveler TSTF-89.

13-08 Adds provision. from Callaway's current specifications as revised which.

Yes Yes No. Already in No. Already LS-20 under certain conditions, would allow continued operation with more than current TS.

in current one inoperable DRPI per group. ;;nu u con;istcnt with ;;;. 2M. Web 3 TS.

u.

~

n 3.1 0%

Q-3.1-20 b

CPSES Conversi>n Comparison Table - CTS 3M.]

10H488

l TSTF-142 Not-Incorporated 3;1 22'NA NRC; approved;; Traveler issuce

,g.3,1.co3 aftcr cut-off date.

4.

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m,u E_n_.w_ _ y_v_ _ u. _2 i

i wu

( p.3.1 002

(

rc-re n u j d E. ?,. bD

(

1 3.1 005 k

-( 3.1 20 W0G 105 Incorporated 3.1 16

Rod Position Indication 3.1.3 3:177 3.1-9 /

3.1 REACTIVITY CONTROL SYSTEMS 3-h8-31.7 Rod Position Indication LC0 34-8-3 1'.7 The EDigital-} Rod Position Indication (ED}RPI) System and the B-PS Demand Position Indication System shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2.

ACTIONS

..................................... NOTE j

Separate Condition entry is allowed for each inoperable rod position indicator 3-H ED pcr group and each demand position indicator per bank.

0 3.1 20

}

CONDITION REQUIRED ACTION COMPLETION TIME A.

One ED}RPI per group A.1 Verify the position of the Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

-:- B-PS,

inoperable for one or rods with inoperable i 3.1-12' more groups, position indicators indirectly by using movable incore detectors.

DB A.2 Reduce THERMAL PCdER to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months s 50% RTP.

CPSESMark-up ofNUREG-1431 - ITS3.1 3.1-18 10/14/98

Rod Position Indication 3.1.8 3.1.7

-3.1-9 CONDITION REQUIRED ACTION COMPLETION TIME B; More than one DRPI per d P1_ac_elthe: control rods Immediatel'y group; inoperable.!

underimanua12 control 3,1,7 Q 3.1 20 AND

\\

B.2 Monitor and Record'RCS,T.,,

Once.per;1 hourj 8 13 l

yerify the' position of Once:per,8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months the'. rods with inoperable position indicators; indirectly 3.1-12; byfusing movable,incore detectors; bNQ j B.

Restore. inoperable 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months position l indicators to OPERABLE' status such that'a' maximum'of'one DRPIjper group [is inoperable.

ED BC. One or more rods with BC.1 Verify the position of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable position the rods with 8

indicators DRPIs have inoperable position 3.1-17 been moved in excess of indicators indirectly 3.1 24 steps in one by using movable incore direction since the last detectors.

determination of the rod's position.

08 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months BC.2 Reduce THERHAL POWER to s 50% RTP.

CPSESMark-up ofNUREG-1431 - ITS3.1 3.1-19 WW98

Rod Position Indication B a-1-8 3;1.7 BASES full power operation, since the probability of simultaneously having a rod significantly out of position and an event sensitive to that rod position is small.

eu2 Reduction of THERMAL POWER to s 50% RTP puts the core into a condition where rod position is not significantly affecting core peaking factors (Ref. 3ll2).

The allowed Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is reasonable, based on operating experience, for reducing power to s 50% RTP from full power conditions without challenging plant systems and allowing for rod position determination by Required Action A.1 above.

B:1-:~'B;2 and-823'and B:4 0 3.1.G 1 When more than:one DRPI perfgroupifail E additional [ actions are necessary(tolensureLthat1 acceptable: power distribution limits are;maintainedJ;.m_inimumlSOM]1s1maintainedEand:the potential effects"of rod'aisalignment' on atenciatad accidaa+===1ye-c are li

... _ acingithe, Rod Control: System (in' manual =meene-e J nplanned rod. notion 1will not occurUTogetherfith:the indirect o

puunon. wm mnauen, avail.able; via movable incorel detectors will ' minimize the'notaa+4-' ~'r-* =4 e=14annant?

0-3.1 20 The immediate; Completion.2. Time ifor, pl acing : theLRod(Control Systemfin manual reflects;the urgency with'which unplanned rod motion;must,beLprevented'while)1n'this Condition,L.Monitori.

and recordingfeacto.ricoolant;Tghelpmassure;thatisignif1 cant i

i changesjin poweridistributionfandlSDMfarel avoided; j;The:once per nourTComp1.etion1 Time 11slacceptable;because'on1y_ minor fluctuationsjin:RCSitemperature.;areLexpected[atisteady state t: operating; conditions; The: position ofithe;rodsimay:beldetermined1 indirectly byluse of the1 movable;incore detector _s. jThe Required 7 Action;may. also be satisfied byl ensuring.at:least'onceiperf8 hours;that F{ satisfies LC0l 3 ; 2 ;'1, ; F4H ; sati sfies : LC013 : 2. 2,Tand SHUTDOWN LMARGIN i s;withi n thejlimits;providedlin the1COLRC provided the,nonindicating. rods have.:not been movedi';;; Verification of;RCCA:positionfonce);per 8' hours (is adequate;forfallowing continuedifull; power. operation for;a limited,724 hour0.00838 days 0.201 hours 0.0012 weeks 2.75482e-4 months ; period,isince:the!probabilityjof simultaneously having;alrod,s_ignificantly,out: of' position..and'an event; sensitive;tol.that rod;positioniis:small'. ;The,24-hour Compl_etion; Time provides;sufficientitime;toitroubleshoot and restoreithe DRPIisystem to operation 1while avoiding the plant challengesiassociated;withia:' shutdown.without;fullLrod position indicationi(RefL4);

CPSESMark-up ofNUREG-1431 Pases - ITS3.1 B 3.1-47 10/14/98

CHANGE NUMBER JUSTIFICATION 3.1 6 ITS LC0 3.1.4 would be split into two separate statements to clarify that the alignment limit is separate from OPERABILITY of the control rod. The CONDITION A wording is broadened from "untrippable" to " inoperable" to ensure the CONDITION encompasses all causes of inoperability. Previous wording was ambiguous for rods that, for instance, had slow drop times but were still trippable. These slow rods are inoperable rods, and the change clarifies the appropriate ACTIONS. The Bases are changed to reflect the changes to the LC0 and CONDITION A.

These changes are based on traveler TSTF-107.

3.1 7 This change to the ISTS would incorporate, into ITS LC0 3.1.7, an Action Statement that was previously approved as part of the Callaway and Wolf Creek licensing basi @_

.o.3.1 20 Cravised in Lnciswrc c. 3rhe Action dLatement would permit 7

continuea FUWER OPERATION for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months with more than I

one Digital Rod Position Indicator per rod group inoperable. Th Action Statement specifies additional required actions beyond those applicable to the condition of one DRPI per group

)

inoperable. The Bases for this change also would be incorocrated into the Bases for the olant TTc Esc

)

wanges are consistent with traveler TSTE234 WOC 73. Rcv.

E 315 1.

The Note undcr the ACTIONS is changcd to bc consistent j

W the new Required Action 1

/

3.18 The Frequency for ITS SR 3.1.7.1 for comparing DRPI and group demand position would be changed from 18 Honths to "Once prior to criticality after each removal of the reactor vessel head." This change makes it clear that the surveillance must be performed each time the head is removed and that it is not tied to an absolute time interval. This change is based on traveler TSTF 89.

3.1 9 This change would eliminate ISTS 3.1.2 because the SDM requirements for MODE 5 have been incorporated into Specification 3.1.1 in accordance with TSTF 136. Traveler TSTF-9. Rev. 1. relocated values for SDM to the COLR which TR 3.1 006 removed the only difference between ISTS LC0 3.1.1 and ITST LC0 3.1.2.

Differences above and below 200'F will be addressed in the COLR.

Subsequent sections have been re-numbered.

3.1 10 Several surveillances (e.g., rod position deviation monitor TR 3.1 004 and rod insertion limit monitor in this section) contain actions in the form of increased surveillance frequency to be performed in the event of inoperable alarms. These actions are moved from the TS to licensee controlled documents since the alarms do not themselves directly relate to the limits. This detail is not required to be in the TS to provide adequate protection of the public health and safety.

Therefore, moving this detail is acceptable and is consistent with traveler TSTF-110. Rev. 1.

CPSES Differencesfrom NUREG-1431 -ITS 3.1 2

10/14/98

CONVERSION COMPARISON TABLE FOR DIFFERENCES FROM NUREG-1431 SECTION 3.1 Page 1 of 3

TECH SPEC CHANGE APPLICABILITY NUMBER DESCRIPTION DIABLO CANYON COMANCHE PEAK WOLF CREEK CALLAWAY 3.1-1 In accordance witt. industry traveler TSTF.9 Rev-1, this change would Yes Yes Yes Yes relocate the specified limits for SDM from several TS to the COLR.

TR-3.1-0C6l 3.1-2 Changcs thc Notc to 5", 3.1.2.1. which dccis wit' vcrifying corc rca ti.ity Ves NA Ves NA Ne-witP'- I':'t;. to statc that thc normalicatica of rcdicted rcacti.ity Mairtaining valucs to coric;r,~nd to sc;;urcd.; luc; ;hal' b-donc prior to cxcccding ;

ETS No--

fucl burnup of 50 CF"O aftcr cach rcfuci'ng.".at-used.~

wording.FA Mentt ain'ng ISTS wording.PA 3.1-3 Wolf Crcck ITS LC0 0.1.C Cc@ircd Action C.1 is c.ucd fica "Oc 17 "00C NeNA NeNA VesNA NeNA 3." to "Sc 7 um0E 2 with y - 1.0." Nat ~used 4

0-3.1-23 3.1-4 In accordance with industry traveler TSTF-13 Rev-1. ISTS SR 3.1.4.2. which Yes Yes Yes Yes requires verifying MTC within the 300 ppm boron limit. is deleted and the Note in that SR is moved to the SR that requires the lower MTC limit to be verified. The deleted SR is not a requirement separate from the lower MTC TR-3.1-005 l l verification SR, but is essentially a clarification of when the SR for the l

lower MTC limit should be performed.

3.1-5 Per current TS [3.1.3.1]. the words "with all" are removed from the LC0 for Yes Yes Yes Yes control rod alignment limits. This ensures that the number of channels of DRPI required to be OPERABLE will not be misconstrued.

3.1-6 In accordance with traveler TSTF-107, the change provides additional Yes Yes Yes Yes clarification that the alignment limits in the LCO are separate from the OPERABILITY of a control rod.

3.1-7 An Action Statement that was previously approved as part of the current Yes Yes Yes licensing basic ne r=11=av and Wolf Creek would be added to improved 0-3.1-23 E

~

TS 3.1.6 revi;;d '- CncicsurcD The Action Statement would permit operation for up to a nuus a mm Jre than one ul9naRuu Tua m vo Indicator per group inoperable.

CPSES Conversion Comparison Table - ITS 3.1 10/w98

ADDITIONAL INFORMATION COVER SHEET ADDITIONAL INFORMATION NO: Q3.2-3 APPLICABILITY: CA, CP, DC, WC REQUEST:

ITS 3.2.1 Heat Flux Hot Channel Factor CTS 3/4.2.2 Heat Flux Hot Channel Factor (All FLOG Plants)

DOC 02-06-A JFD 3.2-12 ITS SR 3.2.1.1 & 3.2.1.2 Frequency Comment: The ITS SR frequency has been changed from the STS frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . This is based upon the incorrect justification that the CTS would allow 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months based upon ITS SR 3.0.3, since the CTS does not specify a frequency. Adopt the STS SR frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

FLOG Response (original): The change descriptions (DOC 2-06-A & JFD 3.2-12) will be revised to provide a basis for the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months that is predicated on the time required to perform the surveillance. DOC 2-06-A is also been revised to be DOC 2-06-M because this change is more restrictive than the CTS.

Callaway and Wolf Creek are incorporating this change (DOC 02-06-A, JFD 3.2-12) in lieu of maintaining CTS which did not specify any completion time. DOC 02-13-LG (applicable to Callaway only) and JFD 3.2-17 are no longer used.

FLOG Response (supplement): As discussed in a telecon with the NRC staff on October 1, 1998, additional justification for the basis for the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months surveillance frequency has been added to JFD 3.2-12.

Additionally, this item is related to Comment Number O 3.2-7 for Callaway and Wolf Creek. No additional response is required for Comment Number O 3.2-7.

ATTACHED PAGES:

Encl 6A 3

i' CHANGE NUMBER JUSTIFICATION f

Condition D, the breakpoints for the applicability of the surveillances in the notes in improved TS SR 3.2.4.1 and 4

SR 3.2.4.2 are modified to be applicable at less than or equal to 75% RTP, and greater than 75% RTP, respectively. This is an i

administrative change that retains current TS requirements.

3.2 10 Consistent with TSTF-110, this change moves requirements for increased surveillance frequencies in the event of inoperable i

alarms to licensee controlled documents. This change is acceptable because it removes requirements regarding alarms and alarm responses that are not necessary to be in the TS to protect

}

public health and safety.

3.2 11 This change, applicable to LCO 3.2.3, Axial Flux Difference (Constant Axial Offset Control plants only), collects 3 LC0 Notes 1

and one Applicability Note into " Notes" list under the LCO.

The revised presentation enhances clarity and usability. The Applicability Note is inappropriately located since it takes exception to the LCO requirement. The Note is moved to the LC0 Notes. This change is consistent with traveler TSTF 164.

3.2 12 Consistent with currcat Technical Specifications, The 0 3.2 3 i

required time for completion of a flux map for determination of the heat flux hot channel factor is changed from 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months i

to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after achieving equilibrium conditions. The proposed change affects SR 3.2.1.1 and SR 3.2.2.13.2;1:2. Aiflux. sap.is taken afterf a;powerfleveLincrease greater;than'a:specified amount totverify F{1slwithin 11mits.and to" provide assuranceithat Fa; i

will; remain within11.imits:unt113the1nextirequired;fiax map ;is takenl Based'on;plantfexpetienceEthelflux: maps 1takenjduring' power l

ascension provideia,highLdegree_ of confidence thathFalw1.1.libe withinglimitsfat1the next:powerplateau; Asisuch,lthe exactitime m

periodallowediforperformance;of~the] surveillance 7afterreaching

}

equilibriun gi s; notr a isigni ficant; safetylconsideration;JThe proposed time (24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ) is a reasonable time period for obtaining and : eval uating la fl ux1mapj and i then;completi.ng : the: procedural isteps associated;with:thisjsurveillance? "FurtherCthe 24; hour time periodiprovides' aireasonab.le]imit on;the lengthlof time:thatithe plant;can; operate;in;an: unconfirmed: condition l the completion of the surveillancc and docs act allow for plant operation in an uncertain condition for a protracted tiac period. This change is ccasistent with thc the Technical Specif'catica requirc; cats of speeWication 3.0.4 'and associated Bases) that allow 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months fee the cc;pletion of a survciliencc after prerequisiteplent conditicas arc attained and for which an cxception to

___an_u_

, n

....___..am vic 7.v.7 Fr u J f3 VW 3MUU.

CPSES Differencesfrom NUREG-1431 - its.s.z 4

1

ADDITIONAL INFORMATION COVER SHEET ADDITIONAL INFORMATION NO: Q3.5.5-1 APPLICABILITY: CP, DC REQUEST:

Section 3.4 DOC 6-21 LS-35

)

Section 3.5 JFD 3.5-4 CTS 3.4.5.2 Action b (CP)

CTS 3.4.6.2 Action b (DC)

ITS 3.5.5 Action A This change is a change to both the CTS and the STS and is beyond the scope of the conversion review and is generic. DOC 6-21 states that this change is consistent with WOG-84.

Comment: Please provide the current status of WOG-84. If WOG-84 is not approved by the TSTF, then this change should be withdrawn from the conversion submittal at the time of the TSTF rejection. If WOG-84 has not been acted on by the TSTF, or is approved by the TSTF, but not approved by the NRC by the time the draft safety evaluation is being prepared, then it should be withdrawn from the conversion submittal at that time. This change will not be reviewed on a plant-specific basis.

FLOG Response (original):

DCPP and CPSES desire to continue to pursue the revisions proposed by this change. WOG-84 is now TSTF-236 which was approved by the TSTF on February 5,1998.

J FLOG Response (revised): Per discussions with the NRC, since TSTF-236 has not been approved, the extension in seal water injection flow AOT from 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months associated with the TSTF will be withdrawn.

ATTACHED PAGES:

CTS 3/4.4 0 Enci2 3/4 4-15 Enci 3A 12 and 13 Enci 3B 8

Enci 4 1,66 and 67 ITS 3.5 1 EnciSA Traveler Status sheet,3.5-12 Enci 5B B 3.5-33 Encl 6A 1

Encl 6B 1

REACTOR G00LANT SYSTEM OPERATIONAL LEAKAGE LIMITING CONDITION FOR OPERATION ACTION (Continued)

O f(b.fcont.) With RCP' seal injection flow greater than the above limitmicrify j

_,,% w... m. r w s. singje 0"L"ma _;,

m......ng train ig mLs C

="mleyithin 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months onsieuuce um nuw rate To witmn. ilmits within g72 4ours or oc m at.least H0T STANDBY within the next 6 6-M-Es hours.anTin HOTsSHUTDOWN within the following 6-hours.-

0 3.5.5 1 c.

With any Reactor Coolant System Pressure Isolation Valve leakage greater than the above limit, isolate the high pressure portion of 611-LS the affected system from the low pressure portion within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months by use of at least two one closed manual, ee deactivated automatic valves. or check valve % and'within:72 hours'by.the use of a second closed manual, deactivated automatic, or check valve #: or be in at 6 30 A least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN 0 3.4.14 3 within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .*** ##

(New) With the.RHR suction isolation valve interlock function 6 29 LS 0 3.4.14 3 inoperable, isolate the affected-penetration by use:of one closed manual or deactivated automatic. valve within.4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

522-M.

SURVEILLANCE REQUIREMENTS 4.4.5.2.1 Reactor Coolant System leakages shall be demonstrated to be within each of the above limits by:

c.

tionitoring the Reactor Cociant System Leckage Octcction System sis-Ls required by Specification 3.4.5.1 at least once pcr 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

b.

Heasurement of the CONTROLLED LEAKAGE to the reactor coolant pump sin seals when the Reactor Coolant System pressure is 2235 20 psig at least once per 31 days with che modulating valve fully open. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4:

c.

Performance of a Reactor Coolant System water inventory balance at least within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving steady state operation

and at least j

once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months thereafter during steady state operation, except 1

that nc more than 05 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months shall clapsc betucca any two succcasive 515-Ls inventory balances. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4: and GIGLS J

d.

tionitoring the Reactor ll cad Flangc Leakoff System at least once per g7,w 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months se i

H 2-M T

being changed by less than 51/houer EEchvalveusedtosatisfythisactionmusthavebeenverifiedtomeet 6 30 A 0 3.4.14 3 surveillance requirement;4.4,5.2.2.

Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV; 6 29 L5 Separate Condition entry is allowed sfor each.PIV flow path.

0-3.4.14 3 1

J CPSES Mark-up of CTS 3N.4 3M 415 10/14/98 s

I

REACTOR COOLANT SYSTEM OPERATIONAL LEAKAGE LIMITING CONDITION FOR OPERATION ACTION (Continued)

'l(b.1 cont.) With RCP= seal injection flow greater than the above limituacrify

^^

a; train i g}

y.. m.m m 3;ng;e u;'L; m u..;;.... m C.

d ' nle within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months creieauce me n uw rate to witnin nmits within J70 4ours.or ue in at'.least HOT STANDBY within-the next 6 6-e H s hours ant in HOT SHlffDOWh within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

0 3.5.5 1 c.

With any Reactor Coolant System Pressure Isolation Valve leakage greater than the above limit, isolate the high pressure portion of 511-ts the affected system from the low pressure portion within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months by 512e use of at least two one closed manual; er deactivated automatic vehes, or. check valve" and within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months by the use of'a'second closed manual,-~ deactivated automatic, or check valve #: or be in at 6 30 A least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN 0 3.4.14 3 within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .*** ##

(New) With the RHR suction isolation valve interlock function 6-29 LS 0 3.4.14 3 inoperable, isolate:the affected penetration by use of one closed manual orl deactivated automatic valve within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

6-22-M SURVEILLANCE REQUIREMENTS 4.4.5.2.1 Reactor Coolant System leakages shall be demonstrated to be within each of the above limits by:

a.

tionitoring the Reactor Cocicat Systc= Leakage Detection System 613-ts i

required by Specification 3.4.5.1 at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; b.

Measurement of the CONTROLLED LEAXAGE to the reactor coolant pump 6-14-A seals when the Reactor Coolant System pressure is 2235 i 20 psig at least once per 31 days with the modulating valve fully open. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4:

c.

Performance of a Reactor Coolant System water inventory balance at least within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving steady state operation

and at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months thereafter during steady state operation, except that-r.c more than OS hours ; hall clapse betucen any two successive 15 1s inventory balances. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4: and 6-16 IS i

d.

,ynyc]ng the Reactor ll cad Flangc Lcakoff System at least once per 6-i7-Lo

,.-,a.

6-12-M T

being changed by less than ST/houe-EEchvalveusedtosatisfy'.this-actionmusthavebeenverifiedtomeet N

6-30 A surveillance requirement:4 4.5.2.2

~

0 3.4.14-3 Enter l applicable Conditions;and Required Actions for systems made inoperable by an inoperable PIV.'

6 29 Ls Separate' Condition entry is allowed for. each PIV. flow path.

o.3.4.14 3 CPSES Mark-up of CTS 3N.4 JN 415 10/14/93

CHANGE NUMBER EllC DESCRIPTION leakage is determined by performance of a RCS water inventory balance. The initial inventory balance is required within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months following RCS steady state operation and every 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months thereafter. Flange leakoff does not provide an indicator of pressure boundary integrity and consequently the removal of the monitoring does not involve the probability of loss of RCS water inventory.

6-17 LG The definition of steady state is moved to a the Bases.

Moving this information to the Bases is consistent with the NUREG-1431 philosophy of moving clarifying information and descriptive details out of the TS to the Bases.

6 18 LS-15 This change in conformance with NUREG-1431. Rev. 1, relaxes the requirement for PIV testing following operation in H0DE 5.

The previous requirement sas testing following 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months in H0DE 5 which is being ant.nded to 7 days in MODE 5.

This is acceptable on the basis that the additional time in H0DE 5 will have little or no impact on the pressure retaining

)

capability of the isolation valves while it may reduce the amount of leak testing required as the result of an 1

unplanned shutdown.

6 19 TR 3 This change in conformance with NUREG-1431 Rev. 1, removes the specific requirement for performing the PIV surveillance prior to returning a valve to service following maintenance, j

repair or replacement. Explicit post-maintenance TS surveillances requirements have been deleted because these requirements are adequately addressed by administrative post maintenance programs.

6 20 A

Consistent with NUREG 1431. IST requirements are moved to ITS 5.5.8.

m 6 21 This change inc cases the RCP scal injectica fl w o.3.5.5 1 l Completion Time from 4 to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ., with a ncw added verification that at icast 100% of-the assumed charging ficw romains availabic. The B;;cs for the scal injectica ficw limit relates to casuring adequate charging ficw during post LOCA injection. Thc rcvised Actions continue to assure this basis is adequately addressed by providing an ECCS like Rcquired Action. ITS Specification 3.S.2 alicws a 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time for onc crc =cre EEGS subsystcas incperabic if at least 100% of the assumed ECCS How is availabic. The scal injection ficw Actions have bcca ;cdified 30 that if the CPSES Description of Changes to Cis.w.4 il 10/11/98

CHANGE NUMBER ESJ1C DESCRIPTION N

rc::ining charging ficw (with some inoperability ift 0 3.5.5 1 i

the charging system) is greater than cr equal to 100%

of the assumed post LOCA charging ficw. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is alicwcd to restorc Operability. This change is consistent with travelcr 'E S4. Not used 6 22 H

This change adds a new ACTION to isolate the affected RHR 1

penetration within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months if the RHR suction isolation valve interlock function is inoperable. The function of the RHR suction valve interlock is to protect the RHR system from an intersystem LOCA by preventing the RCS hot leg suction isolation valves from inadvertently opening when the RCS pressure exceeds the interlock setpoint. Upon failure rf the interlock, the current TS permits continued operation for 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for restoration of the affected subsystem. The improved TS requires action within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to isolate U1e affected RHR subsystem. Thus the new ACTION decreases the probability of an intersystem LOCA upon the failure of the interlock. This is a more restrictive change and the new ACTION is in LCO 3.4.14 Condition C of the improved TS.

6 23 LS-25 Not Applicable to CPSES. See Conversion Comparison Table (enclosure 38).

6 24 H

Not Applicable to CPSES. See Conversion Comparison Table (enclosure 38).

6 25 LS-26 Not Applicable to CPSES. See Conversion Comparison Table (enclosure 38).

6-26 LS-30 Not Applicable to CPSES. See Conversion Comparison Table (enclosure 3B).

6 27 A

Not Applicable to CPSES. See Conversion Comparison Table (enclosure 3B).

6 28 LG Not Applicable to CPSES. See Conversion Comparison Table (enclosure 3B).

6i29 LS-38 Consistent with NUREG 1431,' separate. Condition entry is allowed for each flow path.with; excessive leakage from RCS;PIVs. l Al though this L speci fication ' provides 0 3.4.14 3 allimition allowable lPIVLleakage. rate,, _its' main purpose is;to prevent overpressure;; failure of'the low pressure' portions' of connecting ' systems.' ;The. leakage limit is an; indication that the PIVs between the.RCS and the connecting systems'are degradedLor~ degrading.. Each flow CPSES Description of Changes to CTS 3N.4 13 10/11/98

CONVERSION COMPARISON TABLE - CURRENT TS 3/4.4 r;ge s <f13 TECH SPEC CHANGE APPLICABILITY N'JMBER DESCRIPTION DIABLO CANYON C0HANCHE PEAK WOLF CREEK CALLAWAY 6-16 This change removes the requirement for monitoring the Yes Yes Yes Yes LS-14 reactor head flange leakoff system.

6-17 The definition of steady state is moved to Bases.

Yes -

Yes No - WCGS does not No - Callaway does LG have this not have this definition.

definition.

6-18 This change relaxes the requirement for PIV testing No - Not part of Yes Yes No - already in LS-15 following operation in MODE 5.

The previous requirement was current DCPP TS.

current TS per testing following 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months in MODE 5 which is revised to 7 Amendment 105.

days in MODE 5.

6-19 This change removes the specific requirement for performing Yes Yes Yes Yes TR-3 the PIV surveillance prior to returning a valve to service following maintenance, repair or replacement.

6-20 IST requirements are moved to Section 5 of the improved TS.

Yes Yes No - WCGS does not No - Callaway does A

have this not have this requireme_nt recuirement.

'6-21 Tk; chcngc incrcoscs th PsCP scci 'njcction 'lc.; Cc;piction YesNA VesNA fic Scc C! C 2C LC t:c Scc Ct C 20

\\

ES -35

" ;c 'rc; ' to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ..;ith a ncu cddcd.crification NA NA T

cc;t 1000 cf thc cs;umcd charging '!cu rc;;in:

0-3.5.5-1

)

u.u...,m.

~

6-22 This change adds a new ACTION to isolate the affected RHR No - Not part of Yes Yes Yes H

penetration within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months if the RHR suction isolation current DCPP TS.

valve interlock function is inoperable.

6-23 The leakage detection system specification is revised such Yes No - The non-Yes Yes LS-25 that the provisions of 3.0.4 are not applicable.' and.two applicability of monitoring systems can be inoperable without. invoking LCO 3.0.4 is already 0-3.4.15-1 3.0.3.

part of the current TS.

6-24 Revises ACTION to require going to COLD SHUTDOWN rather than No - Not part of No - The 600 psig Yes Yes M

HOT SHUTDOWN with an RCS pressure less than 600 psig.

current DCPP TS.

action is not part of the current TS.

CrSES Conversion Comparison Table - CTS 3N..t 10/w98

N0 SIGNIFICANT HAZARDS CONSIDERATIONS (NSHC)

CONTENTS I.

Organization........................................ 2 II.

Description of NSHC Eval uations...................... 3 III.

Generic No Significant Hazards Considerations "A"

Admi ni strative Changes......................... 5 "R"

Relocated Technical Specifications............. 7 "LG" Less Restrictive (Moving Information Out of the Technical Speci fications).................. 10 "H"

More Restrictive Requirements................. 12 I

IV.

Specific No Significant Hazards Considerations "LS" LS 1...................

............................ 15 l

LS 2........................

....................... 17 LS 3................................................

19 LS 4................................................ 21 LS-5................................................ 23 LS 6................................................ 25 LS 7......................................... Not Appl i cabl e LS-8................................................27 LS 9....................................

........... 29 LS - 10............................................... 31 LS 11............................................... 3 3 L S 12............................................... 3 5 LS 13............................................... 3 7 LS 14............................................... 3 9 LS 15............................................... 41 LS 16............................................... 4 3 LS 17............................................... 4 5 LS-18............................................... 47 t

LS 19............................................... 49 LS 20............................................... 51 LS 21............................................... 53 LS 22........................................ Not Appl i cabl e LS 23...............................................

55 LS 24........................................ Not Appl i cabl e LS 2 5........................................ N ot Appl i cabl e LS 26........................................ Not Appl i cabl e LS 27........................................ Not Appl i cabl e LS-28...............................................

57 LS-29............................................... 59 LS 3 0........................................ Not Appl i cabl e LS - 31............................................... 61 LS 32........................................ Not Appl i cabl e LS -3 3........................................ Not Appl i cabl e LS 34.......

... 64 ^

LS35......................................CNotused66 LS - 3 6.............................................. 68 0 3.5.5 1 LS 3 7........................................... 7 0 LS 38.l..f....l:..............f.:...;..,......._........

72 V.

Recurring No Significant Hazards Considerations "TR" 0 3.4.14-3 TR 2............................................... 724_

TR 3................................................ 746 CPSES No SignifIcant Ha:ards Consideradon - CTS 3N.4 1 10/1488

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CPSES No Significant Ha:ards Consideration - CTS 3N.4 66 10/14/98

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is s wuii k iivuui uJ uviiJ i vui u b i vi, a i i ru i i s 3 iJ suJ4ii su CPSES No Significant Ha:ards Consideration - CTS 3N.4 67 10!!4/98 1

i i

INDUSTRY TRAVELERS APPLICABLE TO SECTION 3.5 TRAVELER #

STATUS DIFFERENCE #

COMMENTS TSTF 90, Rev 1 Incorporated 3.5 6 Approved by the NRCI TR 3.5 001 TSTF-117 Incorporated 3.5 1 Approved by the NRC?

TR 3.5 001 TSTF-153 Incorporated 3.5 8 Approved'by.the NRCI TR 3.5 001 T&TF--155 NA Not NP,C CppicVed G^

TR-3.5 001

.crporated of traveler cut-cff date-

~ d TF 235 Incorpc ated 3-5-4 DCPP and CPSCS caly '

Q 3.5.5-1

Seal Injection Flow 3.5.5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.5 Seal Injection Flow Bi LC0 3.5.5 Reactor coolant pump seal injection flow shall be s 40 gpm with RCS centrifugal charging pump dischargc hc;dcr pressure 2--2400 2215 psig and.12255 psig and the charging flow control valve

'3'5-5' full open.

APPLICABILITY:

H0 DES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

[1,..1"crifyL100!J10w A.

Seal injection flow not theur3 3.5 4 within limit.

quivels;; t

single 0 3.5.5 1 OPE" Z E ECCS;;herging treinLir;;;il;bl;j m

A;l N

Adjust manual seal 3.5 4 injection throttle ours 0 3.5.5 1 valves to give a flow within limit with eentf4 fugal charging

3.5-5?

pump-discharge header RCS pressure B'

2 2400 2215 psig and;5 22551psig and the charging flow control valve full open.

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.

M B.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months CPSES Mark-up ofNUREG-1431 -ITS 3.S 3.5-12 10/14/98

Seal Injection Flow B 3.5.5 BASES APPLICABILITY In MODES 1, 2, and 3, the seal injection flow limit is dictated by ECCS flow requirements, which are specified for MODES 1, 2, 3.

and 4. The seal injection flow limit is not applicable for MODE 4 and lower, however, because high seal injection flow is less 1

critical as a result of the lower initial RCS pressure and decay heat removal requirements in these MODES. Therefore, RCP seal injection flow must be limited in MODES 1, 2, and 3 to ensure adequate ECCS performance.

Q-3.5.5 1 ACTIONS A.15 nd A.2 7

With the seal injection flow exceeding its limit, the amount of charging flow available to the RCS may be reduced. Under this Condition. action must be taken to restore the flow to below limitJcquired Actica A.1_casurcs that within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thc7 remcining l vail;bic ECCS ch ging 'icw 'without;;3su;;;ing on j additional ~singic,failurcijs 2.100! c' the ;ssu;;;c post Ly cher-ing f.lcw., P; quired Act'n-12 thcn ellows/he operator has has fiours from the time the flow is known tn be above the 1

' t still 1 % inc 100% of thc'essuncd pcst LOCA ECL

~

.c..rcinc44ew-fo correctly position the manual valves and thus be in compliance with the accident analysis. The Completion Time minimizes the potential exposure of the plant to a LOCA with insufficient injection flow and provides a reasonable time to restore seal injection flow within limits This time is A 4 stent conservative _eenscasd7 espect to respeet-te-the Completion '

Times for cac train of EC-. of other ECCS LCOs; it is based on

)

operatingexperience$ndissufficientfortakingcorrect4ve

(

cctions by operations personnel. of other ECCS LCOs: it is. based on

,,)

operating experience and is sufficient for taking corrective hetionsbyoperations. personnel.

B.1 and B.2 When the Required Actions cannot be completed within the required 4

Completion Time, a controlled shutdown must be initiated. The Completion Time of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for reaching MODE 3 from MODE 1 is a reasonable time for a controlled shutdown, based on operating experience and normal cooldown rates, and does not challenge plant safety systems or operators. Continuing the plant shutdown begun in Required Action B.1, an additional 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is a reasonable time, based on operating experience and normal cooldown rates, to reach MODE 4, where this LC0 is no longer applicable.

(continued)

CPSES Mark-up ofNUREG-1431 Bases -ITS 3.5 B 3.S-33 10/14/98 4

4 JUSTIFICATION FOR DIFFERENCES FROM NUREG-1431 NUREG-1431 Section 3.5 f

This enclosure contains a brief discussion / justification for each marked up technical change to NUREG 1431. Revision 1, to make them plant-specific or to incorporate generic changes resulting from the Industry /NRC generic change process.

The change numbers are referenced directly from the NUREG 1431 mark-ups.

For enclosures 3A, 3B, 4, 6A and 6B, text in brackets "[ ]" indicates the information is plant specific and is not common to all the Joint Licensing Subcommittee (JLS) plants. Empty brackets indicate that other JLS plants may have plant specific information in that location.

CHANGE NUMBER JUSTIFICATION 3.5 1 Replaces reference to the " pressurizer pressure" with a reference to the "RCS pressure" in the APPLICABILITY, Required Action C.2, and SR 3.5.1.5.

Required Action C.2 requires reducing pressurizer pressure to less than 1000 psig. However, pressurizer pressure instrumentation does not have the range to read that pressure. Consequently RCS pressure instrumentation is used. For the purposes of this LCO, the use of RCS pressure is equivalent. This is consistent with traveler TSTF-117.

3.5 2 Not Applicable to CPSES. See Conversion Comparison Table (enclosure 68).

3.5 3 Adds the word " mechanical" with regard to throttle valve position stop consistent with current TS. These valves have mechanical stops that maintain the valves in position for proper ECCS performance.

3.54 This change increases the RCP scal injc; tion ficw 3

Completion Tim frc; 4 to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ., with a acw added 0 3.5.5 1

\\

verification that at icast 100t of the assumed charging 1

i flow rc;; ins available. Thc Sascs for scal injection flow

'" M 001 rciate the limit to cr.suring adequate charging flu dueig 1

post-LOCA injection. The revised Actions continue to assure this basis is adcquately addressed by providing an ECCS-like Required Action. ITS Specification 3.5.2 allows a 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time for onc crc ; crc ECCS subsystems inoperabic if at least 100t of the assumed ECCS flow is availabic. The scal injection ficw Actions have been modif4ed so that-4f-tite remaining charging flow Mth some inoperability in the chargig system) is greeter than or equal to 100t of the assuccd post-LOCA charging ficw, 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is alicwed to restore Operability. This

^'an c is consistent with trevelcr TSTE 230 WOC S4. Not used 3.5 5 Deleted reference to centrifugal charging pump (CCP) discharge header pressure from the LC0 and ACTION A to reflect CTS

[3.4,5.2]. A description is added to the Bases which provides the methodology for adjusting the seal injection throttle valves consistent with plant specific analyses.

CPSESDifferencesJrom NUREG-1431 -ITS3.5 1

10/14/98

CONVERSION COMPARISON TABLE FOR DIFFERENCES FROM NUREG-1431, SECTION 3.5 Page 1 of 1 TECH SPEC CHANGE APPLICABILITY NUMBER DESCRIPTION DIABLO CANYON COMANCHE PEAK WOLF CREEK CALLAWAY 3.5-1 Replaced ' pressurizer pressure" with "RCS pressure."

Yes Yes Yes Yes 3.5-2 The Completion Time of LCO 3.5.1. CONDITION B is changed No - Not part of No - Not part of Yes - License Yes - Current TS from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to reflect the current TS.

current TS current TS Amendment perding.

per OL Amendment No. 91.

3.5-3 Adds the word " mechanical" with regard to throttle valve Yes Yes Yes Yes position stop consistent with the current TS.

[Tisc'rc-4to72 hour;.bngc'ncrcascsthe"C";calinjcctionficwCoplctica Ves NA Ves-NA No LCO 3.5.5 i:

Nc LC 3.5-4

(

with a ncw addcd vcrication that not ; plicabicz act ;pplicabic.

at icast 1000 of thc as:u cd charging ficw rcasins NA NA cv;ilabic. ".ot t: sed 0.3.5.E -1 E J

~

3.5-5 Deleted reference to centrifugal charging pump discharge Yes Yes No - Not part of No - Not part of header pressure to reflect current TS.

current TS current TS 3.5-6 SR 3.5.3.1 Note is moved to the LCO per traveler TSTF-90.

Yes Yes Yes Yes 3.5-7 Not used N/A N/A N/A N/A 3.5-8 Moves the Notes from the " APPLICABILITY" to the "LC0".

Also No - Not part of Yes Yes Yes revises the wording in Note 2 from " declared inoperable" to current TS.

L "made incapable of injecting".

3.5-9 The seal injection / return valves (BGV0198-BGV0202) are No - Not part of N3 - Not part of Yes Yes included in ITS SR 3.5.2.7 since they are included in CTS current TS.

current TS.

4.5.2.g.2).

CPSES Conversion Comparison Table -ITS3.5 10/14/98

ADDITIONAL INFORMATION COVER SHEET ADDITIONAL INFORMATION NO: CA-3.5-001

PPLICABILITY: CA, CP, DC, WC REQUEST (new for CPSES): The following Licensee initiated change was submitted by all the FLOG plants except CPSES as part of the response to the RAI on Section 3.5. CPSES has reconsider.

its position and has determined that CA-3.5-001 applies to CPSES. However, it has been enodified to be consistent with the CPSES licensing basis.

REQUEST (modified version of what was submitted by CA, DC and WC): Revise the ITS 3.5.1 Bases to address Westinghouse NSAL 97-003 with regard to the relationship of permissive P-11 to the accumulator isolation valves. The discussion of P-11 is not relevant to this LCO which is applicable above 1000 psig. L'or is the IEEE 279-1971 " operating bypass" discussion relevant or correct per the current applicability of TS 3.5.1.

The TS LCO applicability is in MODE 3 above 1000 psig for small Break LOCA whereas the P-11 interlock 1

and SI signal are for Large Break LOCA in MODES 1 and 2 above approximately 2000 psig.

ATTACHED PAGES:

Enci5B B 3.5-1, B 3.5-2, B 3.5-5, B 3.5-8, and B 3.5-9 i

4 4

i

Accumulators B 3.5.1 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)

B 3.5.1 Accumulators BASES BACKGROUND The functions of the ECCS accumulators are to supply water to the reactor vessel during the blowdown phase of a loss of coolant accident (LOCA), to provide inventory to help accomplish the refill phase that follows thereafter, and to provide Reactor Coolant System (RCS) makeup for a small break LOCA.

The blowdown phase of a large break LOCA is the initial period of the transient during which the RCS departs from equilibrium conditions, and heat from fission product decay, hot internals, and the vessel continues to be transferred to the reactor coolant. The blowdown phase of the transient ends when the RCS pressure falls to a value approaching that of the containment atmosphere.

In the refill phase of a LOCA, which immediately follows the blowdown phase, reactor coolant inventory has vacated the core through steam flashing and ejection out through the break. The core is essentially in adiabatic heatup. The balance of accumulator inventory is then available to help fill voids in the lower plenum and reactor vessel downcomer so as to establish a recovery level at the bottcm of the core and ongoing reflood of the core with the addition of safety injection (SI) water.

The accumulators are pressure vessels partially filled with borated water and pressurized with nitrogen gas. The accumulators are passive components, since no operator or control actions are required in order for them to perform their function.

Internal accumulator tank pressure is sufficient to discharge the accumulator contents to the RCS. if RCS pressure decreases below the accumulator pressure.

Each accumulator is piped into an RCS cold leg via an accumulator line and is isolated from the RCS by a motor operated isolation valve and two check valves in segies /The actcr operatec

% m on va;ves arc inter ccked by I 11 with the pressuricee pressure acasurement channcis to casurc that the valves will automatically open as RCS pressure increases to obcyc the CA-3.5 001 permissive circuit I 11 sctpoint cad'the mein control.bcord switch js,in the "eut;" position. [Ref. C]

CPSESMark-up ofNUREG-1431 Bases -ITS 3.5 B 3.5-1 10/14/98

Accumulators B 3.5.1

)

i BASES f

i BACKGROUND This interlock also prcvants inadvcrtcat closure of the I

(continued) valvcs during normal opcration prior to an accident. The valvcs will automatically open, howcycr. as a result of an SI signal. Thesc features casure that the valvas acct the CA3.5001l rcquirements of the Institute of Electrical and Electronic Enginccrs (IEEE) Standard 2701071 (ibf.1) for "cpcrating bypasses" and that the accumulators will be availabic for injection without reliance on operator action.

The motor (operatediisolation valves are; required:to be:open with power. removed in MODEL3'above 1000'psig.toisatisfy.BTP:ICSBi18

)

[Ref.s.1::Landf6];forf smalllbreak. LOCAs :They are required to be 1

open with^ power l removed 11n.M00ES 1.and.2iforal.arge. break LOCA'-

The accumulator size, water volume, and nitrogen cover pressure are selected so that three of the four accumulators are j

sufficient to partially cover the core before significant clad melting or zirconium water reaction can occur following a LOCA.

The need to ensure that three accumulators are adequate for this function is consistent with the LOCA assumption that the entire contents of one accumulator will be lost via the RCS pipe break during the blowdown phase of the LOCA.

i APPLICABLE The accumulators are assumed OPERABLE in both the large and SAFETY ANALYSES small break LOCA analyses at full power (Ref. 2). These are the Design Basis Accidents (DBAs) that establish the acceptance limits for the accumulators. Reference to the analyses for these DBAs is used to assess changes in the accumulators as they relate to the acceptance limits.

In performing the LOCA calculations, conservative assumptions are made concerning the availability of ECCS flow. In the early stages of a LOCA, with or without a loss of offsite power, the accumulators provide the sole source of makeup water to the RCS.

The assumption of loss of offsite power is required by regulations and conservatively imposes a delay wherein the ECCS l

pumps cannot deliver flow until the emergency diesel generators start, come to rated speed, and go through their timed loading sequence. In cold leg break scenarios, the entire contents of one accumulator are assumed to be lost through the break.

The limiting large break LOCA is a double ended guillotine break at the discharge of the reactor coolant pump. During this event, the accumulators discharge to the RCS as soon as RCS pressure I

decreases to below accumulator pressure.

1 1

4 CP3ES Mark-up ofNUREG-1131 Bases -ITS 3.5 B 3.5-2 10/14/98 i

l

Accumulators B 3.5.1 BASES APPLICABLE The effects on containment mass and energy releases from the SAFETY ANALYSES accumulators are accounted for in the appropriate analyses (Continued)

(Refs. 2 and 4).

CA-3.5 002 The accumulators satisfy Criterion 2 and 3 of 10CFR50.36(c)(')(11), the NRC Policy State: cat 2

LC0 The LCO establishes the minimum conditions required to ensure that the accumulators are available to accomplish their core cooling safety function following a LOCA. Four accumulators are required to ensure that 100% of the contents of three of the accumulators will reach the core during a LOCA. This is consistent with the assumption that the contents of one accumulator spill through the break. If less than three accumulators are injected during the blowdown phase of a LOCA, the ECCS acceptance criteria of 10 CFR 50.46 (Ref. 3) could be violated.

For an accumulator to be considered OPERABLE, the isolation valve must be fully open, power removed above a nominal RCS. pressure of E20003-1000 psig, and the limits established in the SRs for contained volume, boron concentration, and nitrogen cover pressure must be met.

APPLICABILITY In MODES 1 and 2 and in MODE 3 with RCS pressure > 1000 psig, the accumulator OPERABILITY requirements are based on full power operation. Although cooling requirements decrease as power decreases, the accumulators are still required to provide core cooling as long as elevated RCS pressures and temperatures exist.

This LC0 is only applicable at pressures > 1000 psig. At pressures s 1000 psig, the rate of RCS alowdown is such that the ECCS pumps can provide adequate injection to ensure that peak clad temperature remains below the 10 CFR 50.46 (Ref. 3) limit of 2200 F.

In MODE 3, witi, RCS pressure s 1000 psig, and in MODES 4, 5. and 6.

the accumulator motor operated isolation valves are cln*

to k nlate the accumulators from the RCS d ecumulator CA 3.5 001 isolation...is, only required when the. accumulator pressure.is greater than or; equal to 'the. maximum RCS pressure for. the existing RCS: cold leg;temoarature,' as allowed by the P/T curves orovided 1n the PTLR. Tffis allows KR C0010own and depressurizauun.oa]vut discharging the accumulators into the R or requiring depressurization of the accumulators.

(continued)

CPSES Mark-up ofNUREG-1431 Bases - ITS 3.S B 3.5-S 10/14/98

Accumulators B 3.5.1 BASES the concentration can be changed. The 31 day Frequency is adequate to identify changes that could occur from mechanisms such as stratification or inleakage. Sampling the affected accumulator within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a It (101Lgallon)(volume increase (101 gallons) will identiff whether inleakage has caused a reduction in boron concentration to below the required limit. It is not necessary to verify boron concentration if the added water inventory is from tLe refueling water storage tank (RWST), andythe RWST hasinot;been. diluted;since.. verifying that.its: boron concentration satisfies:SR 3;5.~4'.3.fbecause the water contained in the RWST is nominally within the accumulator boron concentration requirements. This is consistent with the recommendation of NUREG-1366 (Ref. 5).

SR 3.5.1.5 Verification every 31 days that power is removed from each accumulator isolation valve operator when the-pecssuricer RCS pressure is > 2000 1000 psig ensures that an active failure could not result in the undetected closure of an accumulator motor operated isolation valve. If this were to occur, only two j

accumulators would be available for injection given a single failure coincident with a LOCA. Since power is removed under administrative control, the 31 day Frequency will provide adequate assurance that power is removed.

This SR allows power to be supplied to the motor operated isolation valves when prcssuriccr RCS pressure is 5 2000 1000 psig.-thus allowing operational flexibility by avoiding unaccessary delays to manipulate the brcakers during plant startups or shutdcWns. Even with poucr supplied to the valves, inadvertent closurc is prevented by the RCS pressure interlock associated with the valves.

^uld closure of a valvc occur 1:t-spite of the interic CA 3.5 001 tk SI signal provided to the valves would open a closed l

valve in the cycat of a LOCA.

i (continued)

CPSES Mark-up ofNUREG-1431 Bases - IIS 3.S B 3.S-8 10/14/98 s

Accumulators B 3.5.1 BASES n

REFERENCES 1.

IEEE St=dard 279 1971. BTP:ICSB;18 :(Rev!l'2,l July 198

[ Application'of theisinglel.fa11ure criterion;to manual y trolled' electrically operated; valves; 2.

FSAR, Chapter E6}.

CA 3.5 001

~

3.

10 CFR 50.46.

4.

FSAR, Citapter E153, 5.

NUREG 1366, February 1990.

i N

JL*.".) ;cti = ]. A CPSES Mark-up ofNUREG-1431 Bases -ITS 3.5 B 3.5-9 10/14/98

ADDITIONAL INFORMATION COVER SHEET ADDITIONAL INFORMATION NO: CA-3.5-002 APPLICABILITY: CA, CP, DC, WC REQUEST (original):

Revise ITS 3.5.4 Bases to indicate that the RWST LCO, by virtue of its temperature, volume, and boron concentration limits, also satisfies Criterion 2 (initial conditions of accident analyses).

REQUEST (revised): Revise various additional ITS Bases regarding the correct application of Criterion 2 of 10CFR50.36(c)(2)(ii). These changes are consistent with the attachment to a May 9,1988 letter from T. E, Murley (N RC) to R. A. Newton (WOG) entitled "NRC Staff Review of NSSS Vendor Owners Groups' Application of the Cor-an's Interim Policy Statement Criteria to Standard Technical Specifications."

1. Revise ITS 3.5.1 Bases to indicate that the Accumulators LCO, by virtue of its pressure, volume, and boron concentration limits, also satisfies Criterion 2 (initial conditions of accident analyses),

2. Revise ITS 3.5.4 Bases to indicate that the RWST LCO, by virtue of its temperature, volume, and boron concentration limits, also satisfies Criterion 2 (initial conditions of accident analyses),

3. Revise ITS 3.6.7 Bases to indicate that the Recirculation Fluid pH Control (RFPC) System, by virtue of its TSP-C depth limit which ensures a minimum equilibrium sump pH of 7.1, also satisfies Criterion 2 (initial conditions of accident analyses). (Callaway only)

4. Revise ITS 3.7.6 Bases to indicate that the CST (and FWST for DCPP) LCO, by virtue of its water volume limit, also satisfies Criterion 2 (initial conditions of accident analyses).

ATTACHED PAGES: 1, CTS 3/4.5 - ITS 3.5 Enci5B B 3.5-5 and B 3.5-28 3, CTS 3/4 7 - ITS 3.7 Enci5B B 3.7-36

Accumulators B 3.5.1 BASES APPLICABLE The effects on containment mass and energy releases from the SAFETY ANALYSES accumulators are accounted for in the appropriate analyses (Continued)

(Refs. 2 and 4).

CA 3.5 002 The accumulators satisfy 6 terion Criteria:2[and 3 of 10CFR50.3.6(c)(2)(ii). the NRC Policy Stat = n:

LC0 The LC0 establishes the minimum conditions required to ensure that the accumulators are available to accomplish their core cooling safety function following a LOCA. Four accumulators are required to ensure that 100% of the contents of three of the accumulators will reach the core during a LOCA. This is consistent with the

{

assumption that the contents of one accumulator spill through the j

break. If less than three accumulators are injected during the blowdown phase of a LOCA, the ECCS acceptance criteria of 10 CFR 50.46 (Ref. 3) could be violated.

For an accumulator to be considered OPERABLE, the isolation valve must be fully open, power removed above a nominaliRCS pressure of E20003-1000 psig, and the limits established in the SRs for contained volume, boron concentration, and nitrogen cover pressure must be met.

)

APPLICABILITY In MODES 1 and 2, and in MODE 3 with RCS pressure > 1000 psig, the accumulat0r OPERABILITY requirements are based on full power operation. Although cooling requirements decrease as power decreases, the accumulators are still required to provide core i

cooling as long as elevated RCS pressures and temperatures exist.

J This LC0 is only applicable at pressures > 1000 psig. At pressures s 1000 psig, the rate of RCS blowdown is such that the ECCS pumps can provide adequate injection to ensure that peak clad temperature remains below the 10 CFR 50.46 (Ref. 3) limit of 2200 F.

In MODE 3, with RCS pressure s 1000 psig, and in MODES 4, 5, and 6, the accumulator motor operated isolation valves are closed to isolate the accumulators from the RCS. [ Accumulator CA-3.5 001 isolation is;only required whenithe accumulator pressure is greater" than;oriequal, to; the maximum RCS; pressure 1 for = the existing.RCS:coldL1egLtemperature. asfallowedlby;the P/T curves provided in;the PTLR.. This allows RCS cooldown and depressurization without discharging the accumulators into the RCS or requiring depressurization of the accumulators.

(continued) j CPSES Mark-up ofNUREG-1431 Bases - ITS 3.S B 3.5-5 10/14/98

RWST B 3.S.4 BASES temperature. The upper temperature limit of {-10G} 120 F is used in the small break LOCA analysis and containment OPERASILI"I analysis.

Exceeding this temperature will result in a higher peak clad SAFETY iemperature, because there is less heat transfer from the core to che injected water for the small break LOCA and higher containment pressures due to reduced containment spray cooling capacity. For the containment response following an MSLB, the lower limit on boron concentration and the upper limit on RWST water temperature are used to maximize the total energy release to containment.

The RWST satisfies Criteri 3 of

~

CA 3.5 002 10CFR50~.36(c)(2)(11); the NRC..

,y Statement LC0 The RWST ensures that an adequate supply of borated water is available to cool and depressurize the containment in the event of a Design Basis Accident (DBA), to cool and cover the core in the event of a LOCA, to maintain the reactor subcritical following a DBA, and to ensure adequate level in the containment sump to support ECCS and Containment Spray System pump operation in the recirculation mode.

To be considered OPERABLE, the RWST must meet the water volume, boron concentration, and temperature limits estchlished in the SRs.

APPLICABILITY In H0 DES 1, 2, 3, and 4. RWST OPERABILITY requirements are dictated by ECCS and Containment Spray System OPERABILITY requirements.

Since both the ECCS and the Containment Spray System must be OPERABLE in H0 DES 1, 2, 3 and 4, the RWST must also be OPERABLE to support their operation. Core cooling requirements in H00E 5 are addressed by LC0 3.4.7, "RCS Loops-H0DE 5. Loops Filled," and LCO 3.4.8, "RCS Loops-H0DE 5, Loops Not Filled." H0DE 6 core cooling requirements are addressed by LC0 3.9.5, " Residual Heat Removal (RHR) and Coolant Circulation-High Water Level," and LC0 3.9.6, " Residual Heat Removal (RHR) and Coolant Circulation-Low Water Level."

l ACTIONS

/L1 With RWST boron concentration or borated water temperature not within limits, they must be returned to within limits within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . Under these conditions neither the ECCS nor the Containment Spray System can perform its design function.

CPSES Mark-up ofNUREG-1431 Bases -ITS 3.S B 33-28 10/14/98

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TheCSTsatisfiesCriteria-en(i).and) oft'c""C"clicy g.3,5 002 State; nt. 10CFR50.36(c)(2)(i LC0 To satisfy accident analysis assumptions, the CST must contain sufficient cooling water to remove decay heat for [30 minutes]

following a reactor trip from 102% RTP, and then to cool down the RCS to RHR entry conditions, assuming a coincident loss of offsite power and the most adverse single activejfailure. In doing this, it must retain sufficient water to ensure adequate net positive suction head for the AFW pumps during cooldown-es

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level of 53Lis as m u.uuu yu s, wi s y,

vuo i v se uu Um ou 3 ~ su sily indicated.on the main control: board 3and;is based'onia; required volume;of:249,100; gallons L(includes: allowances for;unasable volume andrinstrument uncertainties).;:This; volume;is sufficient to~ hold the unit in CPSESMarkup ofNUREG-1431 Bases -ITS3.7 B 3.7-36 10/14/98

ADDITIONAL INFORMATION COVER SHEET ADDITIONAL INFORMATION NO: CP-3.5-003 APPLICABILITY: CP REQUEST (new): This licensee initiated change corrects two editorial errors in conjunction with the response to Comment Number Q 3.5.1-1.

(1) ITS SR 3.5.1.2 - the "6579 gallons" should have been "6597 gallons".

(2) The ITS Bases discussion of level instrument error was deleted from the Applicable Safety Analyses section and was supposed to be relocated to the Bases discussion of SR 3.5.1.2 and SR 3.5.1.3. It was inadvertently not added to the SR section at that time and is now being added.

ATTACHED PAGES:

EnctSA 3.5-2 Enci 58 B 3.5-7 4

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months fully open.

SR 3.5.1.2 Verify borated water volume in each accumulator 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is 2 7853 galicas 394 119l gallons;and 0 3.5.1 1 s 8171 gallenr 01* 597 gallons l c

CP 3.5 003 S'i 3.5.1.3 Verify nitrogen cover pressure in each 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months B-PS-accumulator is 2 385 623 psig and s 461 644

psig, l

I CPSES Mark-up ofNUREG-1431 -ITS 3.5 3.5-2 10/1488

Accumulators B 3.5.1 BASES reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

(Ll If more than one accumulator is inoperable, the plant is in a l

condition outside the accident analyses: therefore, LC0 3.0.3 must be entered immediately.

SURVEILLANCE SR 3.5.1.1 REQUIREMENTS Each accumulator valve should be verified to be fully open every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . This verification ensures that the accumulators are available for injection and ensures timely discovery if a valve should be less than fully open. If an isolation valve is not fully open, the rate of injection to the RCS would be reduced. Although a motor operated valve position should not change.ith power re nved, a closed valve could result in not meeting accident analyses assumptions. This Frequency is considered reasonable in view of other administrative controls that ensure a mispositioned isolation valve is unlikely.

SR 3.5.1.2 and SR 3.5.1.3 Every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , borated water volume and nitrogen cover pressure are verified for each accumulator. This Frequency is sufficient to ensure adequate injection during a LOCA. Because of the static design of the accumulator, a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency usually allows the operator to identify changes before limits are reached. Operating experience has shown this frequency to be appropriate for early detection and correction of off normal trends.

Each accumulator;1siequipped with two3evelsanditwo pressure channels..loneichannellof;eachlisidesignatedithe; primary channel and usedlfor;thinsurveillance except1when declared inoperable 6 The~second channelD.is'_used.to;performichannel checksland'as backup to:the primaryfchannell iSurveillances?are routinely l performed;on both1 channels!

ontrol; Board >1ndication may-_beiused!infthe surveillanceslo '

t co.3.5.co3 thejreqairedLindicated1Wat.erlvolumeuTo; allow forf a 5%

c' jnstrumentiinaccuracy;and;a 1* tank toleranceJcontroliroom indicatedJ val ues :ofc 39tiand ;61*l are _ conservative; and : may bel used ;in surve111anceR0therf meansiofLsurveillance,which consider measurement uncertainty mayfalso be usedl

~

CPSES Mark-up ofNUREG-1431 Bases -ITS 3.S B 3.5-7 10/14/98

ADDITIONAL INFORMATION COVER SHEET j

ADDITIONAL INFORMATION NO: NR-5 0-001 APPLICABILITY: CA, CP, DC, WC REQUEST:

The NRC requested the following:

l For the following plants (and CTS sections), the applications identify the CTS requirements are being relocated to the FSAR: CW (6.2.3, ISEG; 6.5, review and audit; 6.10.1, record retention);

CP (none); DC (6.10.1, record retention); and WC (6.2.3, ISEG; 6.5, review and audit; 6.8.2/3, procedure changes; 6.10.1, record retention). We discussed relocations to the QA plan with Ray Smith (OA branch) several weeks ago. The staff needs to have the licensees identify that these

)

requirements are going to the QA plan and thus controlled by 50.54(a). The DOCS for relocating the above CTS sections are 1-4-LG and 3-9-LG. These DOCS only state the relocation is to the FSAR. The relocation should be to the QA plan.

FLOG RESPONSE: Enclosures 3A and 3B have been updated to reflect the location of the subject relocated items.

ATTACHED PAGES:

Enci 3A 6

Enci 3B 7

(

I a

d 4

4 4

1 J

w

CHANGE H M EB H21C DESCRIPTION 03 08 A

CTS Specifications [6.9.1.5, 6.9.1.6 and 6.9.2] are revised to delete the reference to submittal location for the monthly report, core operating limits report and special reports. The requirements related to report t]bmittal are contained in 10 CFR. Since conformance to 10 CFR is a condition of the license, specific identification of this requirement in the TS would be duplicative and is not necessary. Since the plant requirements remain the same, the change is considered an administrative change. This change is consistent with NUREG 1431. Rev. 1.

03 09 LG The record retention requirements are moved to a icinsee controlled document tnc :5AR and impic:c5EI?h, w ced = nne removal of this detail from the ud is consistent with NUREG-;431. The requirement for retention of records related to activities affecting quality is contained in 10 CFR 50, Appendix B, Criteria XVII and other sections of 10 CFR 50 that are applicable to the plant (i.e., 50.71, etc.). Post completion review of records does not directly assure operation of the facility in a safe manner, as the activities described in the documents have already been performed. By retaini these requirements in aflicensee g i o,,,

r muu, m

..,m controlled documents, any changes in theseTecord retention requirements will b adequately controlled under the provisions of 10CFR50.

_a nd the applicable regulations.

03 10 LG Not applicable to CPSES. See conversion comparison table (enclosure 38).

/,3 11 A

The liigh Radiation Arca is revised to be consistent with 0 5.2 1 NUREC 1431 and the new " art 20 require;cnts. Changes are non-technical to add clarification and conform with N'JREC-1431 and RC 0.38. CTS 6.12,;which provides high radiation; area' ace.ess.controlialternativesipursuant.to 10 CFR:20.203(c)(2)fnasbeen' revised;as,a_ result;of_the changeLto10CFR20fandtheguidancelinLRegulatoryGuide 8.3;8: XSince the plantfequirements: remain the'same; except as 1dentified;in: specific Description'of Changes, the change is. considered; administrative. This change is consistent with NUREG)1431:as modified by TSTF 258.'

03 12 LG Not applicable to CPSES. See conversion comparison table (enclosure 3B).

03 13 M

The following report [ ] will be added to the ITS Administrative Controls section: " Reactor Coolant System (RCS) Pressure and Temperature Limits Report (PTLR)" [ ]

CPSES Description of Changes to CTS 6.0 6

10/11/98

l CONVERSION COMPARIS0N TABLE - CURRENT TS 6.0 Page 7 of 8 TECH SPEC CHANGE APPLICABILITY NUMBER DESCRIPTION DIABLO CANYON COMANCHE PEAK WOLF CRER CALLAWAY 03-08 CTS Specification [6.9.1.5. 6.9.1.6 and 6.9.21 are revised Yes Yes Yes Yes A

to delete the reference to submittal location for the monthly report, core operating limits report and special reports.

N 03-09 The record retention renuirements are moved licensee

- QA plan in Yes - QA plan in Yes - QA plan in Yes - QA plin in LG 411ed document thc FS*;l c ;d -Hca at;ng proccdurcs.

hapter 17.of FSAR Chapter 17 of FSAR Chapter 17 of tJSAR Chapter 17 of FSAR lhe requirement for retenu on of records related to-1 activities affecting quality is contained in 10 CFR 50.

Appendix B. Criteria XVII and other sections of 10 CFR 50 lNR-5.0-00L l

that are applicable to the plant (i.e.

50.71. etc.).

03-10 The Radiation Protection Program is moved to the FSAR.

Yes No - Deleted from Yes Yes LG This program requires procedures to be prepared for move to FSAR CTS per Amendment move to USAR move to FSAR personnel radiation protection consistent with 10 CFR Part 50/36

20. Periodic review of these procedures is required by 10 CFR 20.1101(c).

03-11 The High Radiation Area section is revised to be consistent Yes Yes Yes Yes A

with the new Part 20 requirements. Changes are non-technical to add clarification.

03-12 The Process Control Program (PCP) section is proposed to be Yes No Yes Yes LG moved outside the CTS. The PCP implements the requirements move to FSAR Deleted from CTS move to USAR move te FSAR of 10 CFR 20. 10 CFR 61. and 10 CFR 71.

per Amendment 50/36 03 13 The following report [s] have been added to the ITS:

Yes Yes Yes Yes M

" Reactor Coolant System (RCS) Pressure and Temperature Limits Report (PTLR)"[ ].

03-14 Shutdown margin values would be moved to COLR per traveler Yes No Yes Yes M

TSTF-9. In addition, moderator temperature coefficient Already part of CTS limits would also be moved to the COLR.

03-15 Adds refueling boron concentration limits to COLR.

Yes Yes No Yes M

Already in CTS CPSES Conversion Comparison Table - CTS 6.0 10/w98

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