Text

Forwards Matrix Identifying Items in TS Which Will Be Located to Other Licensee Controlled Documdnts,As Agreed in 941101 Meeting W/Nrc Re TS Change Request 93-16,dtd 940929.Response to RAI Re Improved TS Section 3.3 Also Encl
	ML20080T722
Person / Time
Site:	Peach Bottom
Issue date:	03/03/1995
From:	Hunger G; PECO ENERGY CO., (FORMERLY PHILADELPHIA ELECTRIC
To:	; NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
Shared Package
ML20080T725	List: ML20080T722; ML20080T739;
References
	NUDOCS 9503140085
	Download: ML20080T722 (52)
	v • d • e

{{#Wiki_filter:rn, ,mW x et. tion so,,.,i o i e M, c.?. * ,10CFR50.90: c a LPECO ENERGY-Efr!!=:"Le,, - "yr 965 Chesterbrook Boulevard -l Wayne, PA 19087-5691 ? i . March 3,1995 Docket Nos. 50-277-j 50-278. Ucense Nos. DPR-44 DPR i U. S. Nuclear Regulatory Commission Attn: Document Control Desk .l Washington, DC 20555

Subject:

Peach Bottom Atomic Power Station, Units 2 and 3 l Supplement 1 to TSCR 93-16 Conversion to improved Technical Specifications q

References:

(1) Letter from G. A. Hunger, Jr. (PECO Energy) to 8JSNRC - dated September 29,1994 ~ (2) Letter from J. W. Shea (USNRC) to G. A. Hunger, Jr. dated February 14,1995 l

Dear Sir:

In Reference (1), PECO Energy Company submitted Technical Specifications ~ Change Request (TSCR) 93-16, requesting changes to Appendix A of the Facility Operating Licenses for Peach Bottom Atomic Power Station (PBAPS), j Units 2 and 3. This TSCR proposed an overall conversion of the current PBAPS Technical Speedications (TS) to the improved Technical Speedications (ITS), as contained in NUREG 1433, " Standard Technical Specifications, General Electric Plants, BWR/4."

j in a meeting with the NRC on November 1,1994, PECO Energy agreed to j

submit a matrix which identifies the items in current TS which will be relocated to other licensee controlled documents, as part of the overall conversion to ITS. This matrix is included as Enclosure 1 to this letter. Included for each item in i this matrix is an identdication of the control which will be in place to' govern l subsequent changes to the relocated item. i 5 .l 140040 j 95o314ooB5 95o303 J 0 PDR ADoCK o5ooo277 e i P PDR I ] g l s 1

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March 3,1995.

P 2; 3 ii E Enclosure.2 to this letter provides PECO Energy's response to the NRC's request for additional irdunTetion regarding ITS Section 3.3 Instrurnentation. h . This request was transmitted by Reference (2). In the enclosure, each request t is restated followed by our response. ] 'If you have any questions, please contact us. ] . Very truly yours, t tr><..c.Frg p 64& G. A. Hunger, Jr., j Director - Licensing Affidavit, Enclosures 1 and 2 r cc: T. T. Martin, Administrator, Region I, USNRC .W. L Schmidt, USNRC Senior Resident inspector, PBAPS R. R. Janati, Commonwealth of Pennsylvania ~ 9 I I f 'l l l = l r

x t, COMMONWEALTH OF PENNSYLVANIA :

SS.

' COUNTY OF CHESTER ' i W. H. Smith, Ill, being first duly sworn, deposes and says: That he is Vice President of PECO Energy Company; the applicant herein; that he has read the attached Technical Specifications Change Request (TSCR 93-16, Supplement 1) for changes to the Peach Bottom Facility Operating Ucenses DPR-44 y and DPR-56, and knows the contents thereof; and that the statements and matters set forth therein are true and correct to the best of his knowledge, information and belief. o Iddl-Ald)P Vice President (/ 1 1 Subscribed and sworn to before me this $)2 ay d [2 of 1995. ,k se Mrn Nbtary'Publid j j Erfca A.R ulacar8ik

4 , (j '. 4 C r, ENCLOSURE 1 RELOCATED ITEMS MATRIX - _ - - _. _ _ ~ _.. - - - - _ _ - -. - - - - -

vi.- i ~* ENCLOSURE 1: RELOCATED ITEMS MATRIM (page 1 sf 15) ~.; ITS CTS Description Location Change Centrota 2.0-R, 1.1.A Details that establish when MCPR safety limit is violated. Procedures 10CFR50.59 2.0-R, 6.7.1.d Requirement to notify the NRS within 24 hours of a SL Proce&Jres 10CFR50.59 violation and stheit an LER to the NRS. 3.1.1-R, 4.3.A.1 Details of method used to verify the bOM with the highest Procedtsres 10CFt50.59 worth control ' rod. 3.1.2-R, 4.3.D Details of method usetJ to perform and the purposes of the seses seses control - reactivity anomalies surveillance. Program (5.5.10) l 3.1.3-R. 3.3.A.2.b; 3.3.8.1 Details for disarming CRDs. Bases - Bases controt l ' Program (5.5.10) 3.1.3-R, 3.3.B.2; 4.3.t.2 Requirement to have the control rod drive housing stepert - In - Prucedures 10CFR50.59 place for control rod operability. 3.1.7-R, 4.4.A.1 Requirement to verify the proper operation and setpoint of - the ' Procedures 10CFR50.59 SLC System retlef valves. 3.1.7-R, 4.4.A.2; 4.4.A.3 Details of the method of performing and an emptanetion of the Proce Aares 10CFR50.59 I surveillance test to verify flow through the SLC System from the ptmp into the RPV. 3.1.7-R, 4.4.5.4 Requirement to verify enrichment calculation results after an Procedures 10CFR50.59 addition to the SLC tank by aneIysis wIthin 30 days o' the addition. 3.1.7-R. 4.4.5.3 Detalts of testing the SLC ptmp loop (pimping solution to the Procedures 10CFR50.59 test tank). 3.1.8-R, 4.7.0.2.b Requirement for post maintenance testing of the SDV Vent and Procedures 10CFR50.59 ' ) Drain Valve. ] 3.1.8-R, 4.7.D.2.s . Requirement to record. delly the position of at teest ene other Procedures 10CFR50.59 volve in each line having an inoperable SDV Vent and drain Valve. 3.1.5-R, Tebte 3.7.1 Details relating to the design and operation of.the SDV Vent . Bases Bases Control-and Drain Vatwes. Program (5.5.10) y 3.2.1-R, 3.5.I Requirement regarding which limit - to select from the (DLR e&en ~ Procedures 10CFR50.59 timits are determined using hand calculation. 3.2.2-R. 4.5.K.2 . Recpsirement. for determining Tau (average scram time to the 20E Procedures 10CFR50.59 insertion position)- and the acceptance criteria.

ENCLOSURE 1: RELOCATED ITEMS MATRIX (page 2 sf '15) ' ITS CTS Description Location Change Controls 3.3.1.1-R, 2.1.A.1; Terms (S; W; and detta W) and definitions for the setting of UFSAR 10CFR50.59 Table 3.1.1 Note 12 the APRM flow biased simulated thernet power equation. 3.3.1.1-R, Figure 1.1-1 APRM Flow Blased Scram Relationship to Normat operating Procackares 10CFR50.59 Conditicos Figure. 3.3.1.1-R, 3.1.A; 4.1.A Response time testing surveillance and the acceptance Procedures 10CFR50.59 criteria. 3.3.1.1-R. Table 4.1-1 Item 1 Details of the performance of the Channel Functional Test for Procedures 10CFR50.59 the Mode Switch in Shutdown. 3.3.1.1-R, Table 3.1.1 Note 11 Requirement that an APRM will be considered Operable if there Bases Bases Control are at least 2 LPRM inputs per levet and at least 14 LPRM Program (5.5.10) Inputs of the normal complement. 3.3.1.1-R. Table 3.1.1 Number of Instrument Channels Provided by Design Cottan. Bases Bases Control Program (5.5.13) 3.3.1.1-R, Tabte 3.1.1 Note 6 Details of the MSIV Closure Function design which permits UFSAR 10CFR50.59 closure of any two lines without a scram being initiated. 3.3.1.1-R. Table 3.1.1 Note 5 & Details when the IRMs and APRM Downscate are automaticatty Procedures 10CFR50.59 10 bypassed. 3.3.1.1-R. Table 4.1.1 Note 6 Discussions / specifics (e.g.: ediat's required to be testad for UFSAR 10CFR50.59 each Function; egJipment required for the test; how to perform the test; etc.) concerning Surveittance Tests and the Grow Column both tables. 3.3.1.1-R. Table 4.1.1 Notes 2 Discussions /apecifics (e.g.; what's required to be tested for Procedures 10CFR50.59 4, & 5; each Function; egipment re@lred for the test; how to perform Tabte 4.1.2 Notes 1, the test; etc.) concerning Surveittance Tests and the Grow 2, 3, & 5 Coluun both tables. 3.3.1.1-R,. Table 4.1.1 Note 3 Requirement that functional tests shall be performed on part Procedures 10CFR50.59 of the system that is not required to be operable or are tripped prior to returning the system to operable status. 3.3.1.1-R,, Table 4.1.1 RPS Channet Test Switch; Requirement that a ftmettonal test be Procedures 10CFR50.59 performed after channet maintenance. 3.3.1.1-R,, Table 3.1.1 Trip Level Settings for the various Functions. Procedures 10CFR50.59 3.3.1.1-R,, 3.1.A.1 Note 2 System operationet ' details (when not to place in trip) Bases Bases Control Program (5.5.10)

i. _.3 EWCLOEURE.It RELOCATED ITEMR MATRIX (page 3 of 15) .J ITs cts Description Locetten Change Centrets 3.3.1.2-R, 3.10.5.1.e Requirement thet 3RMe he inserted to the normat operating Procabres - 10CFR50.59 tevet abring core etteratione. 3.3.1.2-R, 3.10.5.1.b Requirement that the 3RM minleum cessit rete daring Core Procedures 10CFR50.59 etterations sesst be achieved with ett rods fully inserted in the core. 3.3.2.1*R, 2.1.g; 3.2.C; Table safety Limits; LCOs; and st Recpairements for Red stock TRM . 10CFR50.59 3.2.C Wotes 16,8-fisictions ossociated with the AMees; IRMs; SRMs and scrum 10, & 15; discherse volume Levet. Tabte 4.2.C Note 2 q 3.3.2.1-R, Table 3.2.C musher of Instrument Channels Provided by Design. Beees seees Contret Proeram -(5.5.10) 3.3.2.1-R, Table 4.2.C; notes 4 Details regarding the performance of Rod Block Monitor Proembres 10CFR50.59' &6 surveltlance Tests. 3.3.2.1 R. 4.3.s.3.b.1.o; Details reteted to the performance of the Red Worth Minimizer Procedwes 10CFR50.59-4.3.3.3.b.1.b; Channet Functional Test. 4.3.3.3.b.1.c 3.3.2.1-R, Table 4.2.C Items 5 Regst rement for en Instrument Check of the RgM once per day. Procedures 10CFR50.59 ~ &6 3.3.3.1 R, Table 3.2.F; Table Requirements for the - following PAM Instrumentation: Rx Water flat 10CFR50.59 4.2.F Levet (WR) ; Drywell P; Dryuell T; suppression Cheeber Water j tevet (NR) ; CR Position; Neutron Monitoring; 3RV Position Indicati m; Mein stock Nigh Range Red Monitor; and Rn Bits 8 Roof Vent Ni@ Rarge ' Red Monitor. 3.3.3.1 R, Tabie 3.2.F Deteits of system Operability recpsirements and description ' of UFSAR '10CFR50.59 ~ the 'instruesnts. 3.3.3.1-R, Table 4.2 F; Note ** Details of the performance of surveittences. Precethres 10CFR50.59 & ***; 4.7. A.6.c 3.3.3.1 R. 4.7.A.6.c Requiream.. that the atmospheric enelyzing system be Procesbres . 10CFR50.59 functionetty tested one per operating cycle when the CAD i system is tested. 3.3.3.2-R, 3.11.C.1; 4.11.C.1 Requirement that the Emergency shutdeun Control Penets be Procedures 10 FR50.59 escured et ett times and thet this status be verified once per - G usek by visuet - Inspection. l 3.3.4.1-R, 3.2.G; 4.2.G; Table Respairement for the ATWs alternete rod insertion function. Tiet ' . 10CFR50.59 l 3.2.G; Tabte 4.2.G i r l i -.-- --. -......-..--.m+ m m .m.-,-. ., _ ~ ~ ~ .-r-...- ..,.-e_...-,..v-. ~.....,.. ~. - =...-.-- -. - - w e w~ w.%<-w..---.

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ENCLOOURE ~ 1: RELOCATED ITEBIS IIAT*IX (page 4 of 15) ' t j ITS cts ' Description - Loestlen - Change Centrots l 3.3.4.1 R, 3.2.G; Tabte 4.2.G Respairement thet the ATW5 Recirculation Pump Trip Ftanction - Proceeksres 10CMt50.59 - have menuet actustion. 4 3.3.4.1-R, 3.2.G Respairement that specifies the specific ATWs-RPT espelpment esses esses control l - thet needs to be Operstde in the Run stede; specificelty the Program (5.5.10). phrase "The outenstic actuation Logic; and actuation devices of." 3.3.4.1 R. Table 3.2.G Ihster of ' Instrissent Channets Provided by Design per Trip teses seees Contret system. Program (5.5.10) q t i 3.3.4.1-R. - Tebte 4.2.G mote 1 Table 4.2.G, note 1; Respairement that the ATWs-RPT instrissent UFSAR 10CFR50.59 j chamels - are the same ones used by the Core and Containment { Cooting ~ systems. 4 3.3.4.1-R, Tatde 4.2.G. Note 2 Respairement for e three month Logic system Functional Test on Processres 10CFR50.59 i the ATUS-RPT Function and Tatde 4.2.G; note 2; Respairement 1 that the recircutetten pneups nead not be tripped daring the Logic system Fisictional Test. i J; 3.3.4.1 R. 3.2.G mote 2 system operationet details (uhen not to ptoce in trip). seees seees Centret Progres-(5.5.10) 1 3.3.5.1-R, 2.1.1; 2.1.J; Table Tebte 3.2.s; '" Indicated Level"; Table 4.2.b; notes 3 & 4; Processres 10CFR50.59 ~i ? 3.2.8 Ilote 4 - details such as conversions; specific Instrisettons; etc. 3.3.5.1 R, Totde 3.2.s Trip Level setting 'colisun. Proceskares 10CFR50.59 -l 3.3.5.1 R, Tetde 3.2.5 Remarks - Colism; Detains of specific Infaisation ebeut the Bones Bones Centret Functions (e.g.; other Fisictions rosystred to inittete the Program (5.5.10) system;. the role of the Fastetton in initiating the item; 4 - etc.) i 3.3.5.1 R. Tatde 4.2.5 SR for the ses retlef volves bellous pressure suitches. Processres 10CFR50.59 3.3.5.1-R. Tatde 3.2.B; Tatde Respairements ' for the trip system bus peuer monitors; the core 7151 10CFR50.59 4.2.8 aprey sporger differentiet pressure-sanitor; the LPCI crees i connect peeftien Indieetion. I i 3.3.5.1-R, Table - 4.2.5; Note 7 Detalts about the instrisesnts; ' specifically. the roupstrement. UFSAR 10CFR50.59-that channets cenelet of analog trenmoitters; indicators and electronic trip units. 3.3.5.1-R. Tatde 4.2.5 LSFT for the area cooling for oefeguards systems. TIBI -10CFR50.59 3.3.5.1 R, Telde 3.2.s Rosysirement for a LPCI - Centainment ute Pressure Function. TIBt 10 Crit 50.59 m. m .m .. m-m .-..me.. .-......m--.-.~_m_..w-,......_.....,o..-a.em-...w.m.-----.. m...m... .-.m....-.m

ENCLOSURE 1: RELOCATED ITEMS MATRIX (page 5 of 15) ITS CTS Description Location Change Controts 3.3.5.2-R, 2.1.J; Table 3.2.8 Details which are procedural in nature (e.g.; conversions; UFSAR 10CFR50.59 specific instructions; etc.). 3.3.5.2-R, Table 4.2.5 Notes 3 Details which are procedurst in nature (e.g.; conversions; Procedures 10CFR50.59 &4 specific instructions; etc.). l 3.3.5.2-R. Table 3.2.8 Trip Levet Settings. Procedsres 10CFR50.59 3.3.5.2-R, Table 3.2.s; Table Details about instrtsments;- spectficalty; requirements that UFSAR -10CFR50.59 4.2.8 Note 7 chamels consists of anatog transmitters; indicators and electronic trip mits. 3.3.5.2-R. Tabte 3.2.s Reauirements for the RCIC Trip System bus power punitor. TRM 10CFR50.59 3.3.6.1-R, Table 3.2.s; Tabte Regst rement for a Reactor Low Pressure Function. TRM 10CFR50.59 4.2.8 Item 4 3.3.6.1-R, Table 3.2.A: Table Requirement for Number of Instrument Channels Provided By Bases Bases Control 3.2.s; Table 3.2.0 Design. Progros (5.5.10) 3.3.6.1-R, Tabte 3.2.0 Details relating to the design; plant operations; and TRM 10CFR50.59 maintenance of the PCI Instrumentation. 3.3.6.1-R, Table 4.1.2 Note 3; Details relating to the design; plant operations; and Procedsres 10CFR50.59 Tables 4.2.A. B, & D maintenance of the PCI Instrumentation. Notes 3, 4 4 3.3.6.1-R, Table 3.2.A Note 6; Details relating to the design; plant operations; and Bases Bases Control Table 3.2.8 Notes 2 maintenance of the FCI Instrtsnentation. Program (5.5.10)' &3 3.3.6.1-R, 2.1.C; 2.1.K; Tabte Details relating to the design; plant operations; and UFSAR 10CFR50.59 I 3.2.A Notes 3, 4, & maintenance of the PCI Instrumentation. 8; Table 3.2.8 Note 4; Tables 4.2.A, 8, & D Note 7 3.3.6.1-R. Table 3.2.s Setpoints for the NPCI and RCIC isolation on the steam line Procedsres 10CFR50.59 tow pressure f metion. 3.3.6.1-R, Table 3.2.A; Table Trip Levet Settings. Procedures 10CFR50.59 3.2.s; Table 3.2.0 3.3.6.1-R. Table 3.2.A Note 9 Compensatory actions associated with recovery of a toss of Bases Bases Contret ventitation in the MSL ttsinet. Program (5.5.10) 3.3.6.1-R, 3.2.A.1 Note 2; System operational details (then not to plant in trip) Bases Saaes Control 3.2.0.1.1 Note 2 Program (5.5.10)

ENCLOSURE 1: RELOCATED ITEMS MATRIX (page 6 of 15) IT5 CTS Description Location Change Controls 3.3.6.1-R. 3.2.A.2 Note 3; Requirements for Reactor Clearg System Righ Temperature TRM 10CFR50.59 Table 3.2.A Item 11; Function. Table 4.2.A Item 7 3.3.6.2-R, Table 3.2.D Trip Levet settings. Proce&rss 10CFR50.59 3.3.6.2-R, Tabte 3.2.0; Details relating to design and operation and items which are Proce&res 10CFR50.59 Table 4.2.A Note 4; procedural in nature (e.g.; specific Instructions; etc.). 4.2.D Note 4 3.3.6.2-R, 3.2.0.1 Note 2 system operational details (when not to place in trip) Bases Bases control Program (5.5.10) 3.3.7.1-R, Tabte 3.D.2 Trip levet settings. Proce&res 10CFR50.59 3.3.7.1-R, Table 3.2.D; Details about the instrument (msber of channels provided by seses teses controt 3.11.A.5; 3.11.A.5.b design; etc). Program (5.5.10) 3.3.7.1 R, Table 3.2.D; Requirements for trip ftmettons of the MCREV initiation TRM 10CFR50.59 3.11.A.5.a; instrumentation not associated with control room air intake 3.11.A.6; 4.11.A.4; radiation--high channels. 4.11.A.6 3.3. 7.1 - R. 4.11.A.5 Items which are procedural in nature (e.g., conversions, Procedures 10CFR50.59 specific instructions, etc.). 3.3.8.1-R, Table 3.2.8 Details which are procedurst in nature; specificatty; Procedures 10CFR50.59 instructions on where to test (voltage and time) the relays. 3.3.8.1-R, Table 3.2.s Trip Levet settings. Procedures 10CFR50.59 3.3.8.1-R, Table 3.2.B; Table Details on the instruments (e.g.; specific ftmettons they UFSAR 10CFR50.59 4.2.8 perform; etc.). 3.3.8.1-R. Table 3.2.s Trip Levet setting for the 4kV Emergency Bus Undervoltage Procedures 10CFR50.59 Relay. 3.3.8.2-R, 3.1.D.1 Details of what constitutes a trip train (an electric power Bases Bases control monitoring assenbty). Program (5.5.10) 3.3.8.2-R, 4.1.D.1; 4.1.D.2 Maximus setpoint for the imidervoltage and taiderfrequency Procedures 10CFR50.59 relays and minisua setpoint for the overvottage and underfrequency time delay relays. CTS 3/4.15-R, 3/4.15 seismic Monitoring Instrumentation. TRM 10CFR50.59

i jg s.. EuCLogumE It RELOCATED ITEtis Ig4TalR '.(page 7 of 15) 8.. ITS CTS Descriptten -Lecetion Change controte: 3.4.1-R, 3.6.F.1 Requirement that following one-pump eperation; the discherge Procedures 10CFR50.M : m - 4 vetve of the teu speed. pap any.not be opened untoss the speed' of the faster pump is less then 50E of its rated speed. a4 3.4.1-R, 4.6.F.1 Requirement to obtain baseline APIst and LMet neutron fleet Procedures - 10CFR50.59 noise date. 3.4.1 R, 3.6.F.4; 3.6.F.5.b Requirements to =leundletely inittete action.= geoes geoes Centret Program (5.5.10) .y 3.4.1 R. 3.6.F.5.b Details regarding the detenmination of LPIg4 neutron fleet notee Beses geoes Centret l Levels (which LPtots to use and their tocation). Program'(5.5.10)- 4 CTS 3.6.G-R, 3/4.6.G Requirement for structuret Integrity. TIst 10CFR50.59 3.4.2-R, - 3.6.E.2; 3.6.E.3; Detells on the Jet Puups reteted to systems (e.g. Indicated Procedures 10CFR50.59 3.6.E.4 core flow is the sum of the flow indication from each of the 20 Jet pneups). 3.4.2-R, 4.6.E.3 newirement to obtain besetine data respelred to ev-tunte Jet Processres - 10CFR50.59: ptmp Operabitity each operetIng cycte. 3.4.3-R, 4.6.D.2 Rowirement to disassemble and inspect one SRV every 24 Procedures -10CFR50.59 senths. 3.4.3-R, 4.6,0.3 Requirements for the Relief Velve Bettous instrumentatten Procesares 10CFR50.59 3.4.3-R, 4.6.D.4 Instructions on how.to verify..thet the relief velve is ~ Bones geoes Centret annuelty opened. - Program (5.5.10) 3.4.3-R. 4.6.D.3 Requirement to perform en inspection for teekage of the Procesares 10CFR50.59 - accumuletors and air piping. for the 3RVs once per operating - 4 cycle. 3.4.5-R, 4.6.C.1 Retyirement ' thet ECS teskage - shett be determined - my the - Processres 10CFit50.59 primary centeinment dryuett eusp collection and flow monitoring system. 3.4.5-R, ' 4.6.c.2 - Requirement that the Drywett _ __ _;t.. radioactivity. Levels ' Procesares 10CFit90.99 he monitored and recorded at toest once per day.~ 3.4.6-R, 3.6.B.1; 4.6.g.1; Requirements ' for reacter coetent and offges system esoples-Processres 10CFR50.99 febte I - essgeting eksring startup; fottowing significent a peuer. towel changes; and ' following - significent changes in offges radiation levels.

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LENCLCEURE' 1: RELOCATED 17B45 IIRTRIX - (pose 3 of 15) m ITS CTS Description Locetten' thanbe Centreta 3.4.9-R, 3.6.A.1; 3.6.A.2; Requirements for reactor cootent system pressure and PTLR 10CFR50.59 & PTLR 3.6.A.3; 3.6.A.4;. temperature. IIethodetegy - l 3.6.A.5; Figures ~ L(5.6.6.b) 3.6.1, 2, & 3 3.4.9-R, 4.6.A.1 Requirements for when the RCS temperature surveillance for Procedures 10CFR50.59-heet, and cooldouns may be discentinued (intit the difforence between any 2 readings taken over a 45 minute period is less than 5 degrees F). 3.4.9-R, 4.6.A.1.o; 4.6.A.1.b Specific RCS locations (bottom head drain aruf. recircutetton Procedures 10CFR50.59 toops. A and 5) for monitoring temperature during heetg and cooldouns. . j 3.4.9-R. 4.6.A.1 Detells of. the Reactor veneet test specimen location and UFSAR-

10CFR50.59.

details regarding the sample program. CTS 3.6.8.2-R, 3/4.6.5.2 Respairement for controls for reector unter quality including: Tat 10CFR50.59 chloride concentration; conthsetivity; and pet. 3.5.1-R, 3.5.A.1.o; - Detells L of what constitutes a core sprey and LPCI subsystem seees seses Controt 3.5.A.1.b; and their minlaus requirements for an operable flow path. Program (5.5.10) 3.5.A.3.e; 3.5.A.3.b; 3.5.A.6 i 3.5.1-R, 4.5.A.1.e Requirement for - delty checks. and quarterty celibretten of the ime 10LFR50.59 Core Spray heeder Dette P instrumentation. j i 1 3.5.1-R, 4.5.G.1 - Details of the method to be employed to assure that the NPCI - Bases teses Control and RCIC discharge pimp discherge tines are futt of unter. Program (5.5.10) b ~ 3.5.1-R. 4.5.G.2 Requirement.that the tevet euttches that monitor ' the LPCI and Processres 10CFR50.59 CS tines to ensure these tines are fILted utth weter are functionetty tested every operating cycle. t 3.5.1-R, 3.5.N; 4.5.N Respairements ~ for en Engineered Safeguards Campertments cooling- - TWI '10CFR50.59 and ventitetion. l 3.5.1-R. 4.6,0.4 Requirement that each' retlef volve be operated senusity once seees seees controt per operating cycle and the details _ of the perforunnee of this Program (5.5.10). surveltIance. l 3.5.2-R, 3.5.F.1.o; 3.5.F.1.b Definition of ediet eenetitutes e od oystem and description of Bases - seees Controt einlese requirements for an GPEtesLE fleu path.- Program-(5.5.10)- l 3.5.3 R, 4.5.0 teote

Requirement to include automatic restert on tem unter level Bases teses Centrol signet. during a simeteted automatic actuation ' test once per Program (5.5.10)<

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k' g : EWCLOSURE.--1: RELOCATED !7945 IIATRIN (pese 9 of 15)- L l ITS CTS Description Lacetten Change Centrolo 3.5.3-R, 4.5.0.1.f Requirement to vertfy automatic transfer ~ from CST to ' ' teese /teses contret' onepression puot on tou CST unter level once x e cycle. Program (5.5.10) 3.5.3-R, 4.5.s.1 Requirement to ensure thet the pipine ' is futt from the . esses, sense Centret - discherge volve to the injection velve by venting the RCIC Program (5.5.10)-- from the high point. i ' 3.5.3-R. 3.5.N; 4.5.N Reesirement for testing the compartment cooters. - Tait 10CHISO.59 t 3.6.1.1-R, 4.7.A.2.b; ' Proceduret ~ type details that are not addressed in 10 CFR 50 Procedures = 10Cnt50.59 4.7.A.2.d; Appendix J and specific vetues for parameters -(P.; P.; and L.). 4.7.A.2.f; 4.7.A.4.c i I 3.6.1.1-R, 4.7.A.2.f; Tatde List of containment penetretions. UFSAR- . 10CHt50.59 - ' 3.7.2; Table 3.7.3; Tebte 3.7.4; Table Notes 2, 3, & 9-22 3.6.1.1-R, 4.7.A.2.s Requirement for a continuous Leek Rate Ilonitor. Procesares -10 Crit 50.59 - 3.6.1.1-R. - 4.7.A.2.h; 4.7.A.4.c ' Regstrement to perfone - visuet inspections of the eiepreselon Processres 10CFit50.59 chamber interior and the dryvett-to-oigpression chamber vacuise i breakers. l 3.6.1.2-R, 4.7.A.2.f; Tebte The value of P.. saoes teses. Control - 3.7.2 mote 8 Program (5.5.10) i 3.6.1.2-R, Table 3.7.2 note 1 One hour miniense test duration for vetwee and penetrations. Precedures 10Cnt50.59 - 3.6.1.3-R,- - Table - 3.7.1 List of PCIVs. UFSAR" 10CFR50.59 : 3.6.1.3-R, 4.7.D.2.b ~ Requirement specifying - the PCIVs be demonstrated Operelde Procesares 10CFit50.59 4 prior to betfie returned to service efter maintenance on or reptocament of the velve; actuator; control or peuer circuit by performance of a cycling - test; and verification of footation time. power operated footation vetves (eecept. for the lesIVs) ohett.. Procedures 10CFIt50.59 3.6.1.3-R, 4.7.D.1.b.1 Details of surveittence specifying that ett nonostly span be futty - closed and reopened. 3.6.1.3-R. 4.7.0.1.b.2 Requirement for peuer. to be ' < 75X to perform IIBIV' Isoletten Proceesres 10CFIt50.59 f tlet testing. 3.6.1.3-R, 4.7.d.1.c Requirement - to esercise the main steen line power-sperated Precedures 10Cret50.59 leetetlen vetves tur portiet closure end seesessent opening. I ' i w w w T y ww-v w vye-w p,m w w 1mm-- we,wrw-veu-rwisewweew w w spee wewemywww W w yww,-musei'www--wy-me-*ge+.e,e ,w-4e ww _ _ M i, wwgiur e i e e h e-umsw r v4 te y,- e e g.ww A, e mp e r q-w-p - ge W egswt -g-9eppg%WMr-.-yvuuss.--+w pe=-ws-t -m

g EucLeeURE 1: RELOCATED ITEMS M4TIII -. (page 10 of 15) L ~ ' ' 175 CTS Description Location Change Centrols 1 3.6.1.3-R. 4.7.E.2 Requirement specifying the LLRT for the terse contelament Proceshares 10CFR50.59 l ventitation isoletion - volves be coopered to the previously meeeured teek rete to detect excessive volve degradetion.- 3.6.1.3-R, 3.7.E.2.b Respairement specifying the acciasstated time e purge or vent Procedures 10CFR50.59 - flow path esists he tielted to 90 hours per calender year. 3.6.1.3-R,. 3.7.E.2.c Penetrations and flou path volves identified as being adject Prece& ares 10CFR50.59.' to the primary conteirament purge and exhaust volve specification. 3.6.1.3-R., 1.0 Primary Details thet constitute primary conteirament integrity with seees seees Contret conteirveent respect to PCIVs. Progree -(5.5.10) Integrity Defin'*lon ~ 3.6.1.6-R, 3.7.A.4.b Respairement to ottow vecines breekers to be considered eteeed teses seees Control even if the not futty eeste:F' indication is present if a test Program (5.5.10) test confirms the bypeos eroe between the drywett and suppression poet is less then or equivalent to e one-inch diameter hole. 3.6.2.1 R, 4.7.A.2 Requirement to monitor suppression poet temperature den there Procedures 10CFR50.59 is indication of retlef volve operation (except when the . reactor is being shutdeun ord torus cooling is being established) or testing dich adds heet to the suppressica pool. 3.6.2.3-R, 4.5.3.1.d Torus cooling MDW testing requirements. Precedures 10CFR50.59 1 3.6.2.3-R, ' 3.6.s.4.e Details dich defines uhet constitutes en ant suppreselon poet aseos seees Centret .l cooline o d oystem (toep) and description of the minimus Program (5.5.10) requirements for en operable flow path. 3.6.2.4-R, 4.5.3.1.f; 3.5.5.5 Respairements for testing Torus Spray MDvs. Procesares 10CFR50.59 3.6.2.4-R, 4.5.8.1.e; 4.5.3.1.s Respairements for dryuett sprey. tan 10CFR50.59 3.6.2.4 R, 3.5.5.6.e . Requirements for uhet eenetitutes en RNR suppression poot tones seees Centret ' oprey edeystem (toep) and the description of. the minieses Program (5.5.10) requirements for en operable flow path. 3.6.3.1-R, 3.7.A.6.e Requirement specifying the CAD System must be operable to Deses Besse Centrol sigipty nitrogen to either Unit 2 or Unit 3 contairement for. Program (5.5.10) etmosphere dilutten if respaired by post-LOCA canditions. 3.6.3.1-C, 4.7.A.6.e Requirement for a post-LOCA CAD System Functional Test once Procesares 10CFR50.59 per operating cycle.

.~re-2.w-ENCL 0suRE 1: RELOCATED ITEng' MATRIX fosse.11 of ' 15) +. ITS CTS Description Lecetion Charge Centrots -- 3.6.3.1-k, 3.7.A.6.d Post Accident requirement that e 30 pelo limit is the musimso Proceshares . 10CFR50.59' containment repressurization ettouable using the Ca0 System and venting via the SGT system to this stock sunt be initletsd et 30 psig following the inittet peak pressure et 49.1 pois. 4 3.6.3.2-R, 3.7.A.5 Requirement to inert with nitrogen gas. Procesares 10CFR50.59 3.6.3.2-R, 4.7.A.5 Respairement to record the containment osygen concentration. Proceshares 10CFR50.59 6 3.6.4.1-R. 4.7.C.1.c Respairement to perform the secondary contaisuunt capability Proceshares - 10CFR50.59 test with the SGT system st& system prior to refueling. 3.6.4.1 R, 4.7.C.1.d Requirement to operate the SGT system ef ter e secondary Procedures 10CFR50.59 contalement vlotetten is determined and has been isoleted to check if it een mainteln the proper vacutse. 3.6.4.1-R, 3.7.C.1.d Rosystrement that ascendary containment be maintained if the Procedures 10CFR50.59 fuel cook is being moved in the reactor building. 3.6.4.1-R. 3.7.C.1.c Deteits/ requirements of the Design. seees geoes Centret i Program '(5.5.10) 3.6.4.2-R, 3.7.C.1.d Requirement thet secondary conteirwent be meintained if the Procedures 10CFR50.59 fuel cask is being moved in the reactor building. L 3.6.4.3-R, 3.7.3.1; 3.7.E.2.d; Requirement that both ' SGT trains shall be Operable when Procesksres - 10CFR50.59-3.7.E.2.e venting or purging the primary containment and that only one of the two SGT trains shett be used at e time for primary contalement purge / vent' operetions. 3 3.6.4.3-R, 3.7.3.1; 3.7.3.3 Detells of what constitutes en Operable SGT sidoystem.. gases ' gooes. control Program (5.5.10) 3.6.4.3-R, - 4.7.3.2.e Requirement to unintain a dry ges purge through the SGT Proceshares 10CFR50.59 filters to molnteln rotative hiseidity below 70X during idle periods. i 3.7.1 - R, 4.5.3.1 Innervice ' testing ' respairements for the NPW pumps. Processrgs ' 10CFR50.59. i 3.7.2-R, 3.9.C.4; 4.9.C.2 Respairement that the EW ' fens be operable in order for the EW .TIgl 10CFR50.59 pisups to be Operable. 3.7.2-R, 4.9.C.1 - Innervice Testing Respairement for the EW System. Processres 10CFR50.59 to inopoet and eteen as necessory to roomve Procochares 10CFR50.59 3.7.2-R, 4.9.C.4 Requirement escesolve sitt from the bottom of the "A" (for Unit 2) ' and l i- "g" (for Unit 3) EW Puep intake structure. m.- 4-.s. ..e-.+ ,--,..,rm_m_m_ =- m. -.nw.- --,e-m. w--.w-+.m ,,w__.---.--e m.mm.-es.2 m. . e.-- <u. m --a m

EWCLOSURE 1: itELOCATED ITEMS MATRIX (page 12 of 15) s ITS CTS Description Location Change Controts 3.7.3-R, 4.11.8.2 Regairement to test the portable fire puup used to provide Procedures 10CFR50.59 makety to the emergency reservoir. 3.7.3-R, 4.11.B.3.a inservice Testing Requirement for the ECW pwp and ESW Booster Procedares 10CFR50.59 P m ps. 3.7.4-R, 4.11.A.2.d Requirements that a dry gas purge provided to the MCREV Procedures 10CFR50.59 filters to ensure the relative hueldity in the filter system does not exceed 70% when the system is idle since moisture could reduce the efficiency of the charcoal fitters. 3.7.5-R, 3.8.C.7.b; 4.8.C.7.b Requirements governing the testing of the Steam Jet Air TRM 10CFR50.59 Ejector radiation sonitors. 3.7.5-R, 4.8.C.7.a Detalts of the perforsunce of the surveillance (radioactive Bases Bases Control release rate of the noble gases from the steam Jet air ejector Program (5.5.10) discharge). 3.7.7-R, 3.10.C.2 Requirement to suspend crane operation with toads in the spent Procedures 10CFR50.59 fuel storage pool aree af ter placing the fuel assenbtles and l crane toad in a safe condition when levet in the spent fuel pool is not within limit. 3.7.7-R, 3.10.D Crane limits. Procedures 10CFR50.59 CTS 3/4.8 R, 3/4.8.G Mechanical Vacuum Pwp Specification. TRM 10CFR50.59 CTS 3/4.11.0-R, 3/4.11.0 Snubber inspection requirements. TRM 10CFR50.59 CTS 3/4.12-R, 3/4.12 Requirement for River Level. TRM 10CFR50.59 CTS 3/4.13-R, 3/4.13 Requirement for Miscellaneous Radioactive Materlats Sources. TRM 10CFR50.59 3.8.1-R, 4.9.A.1.2 Details relating to the operation and testing of the DG. Procedures 10CFR50.39 3.8.1-R, Tabte 3.2.8 Details related to the design of the 480 V toed center timers UFSAR 10CFR50.59 and the 4 kV bus sequentlei toeding relays. I 3.8.1-R, Table 3.2.5 Details related to the trip settings of the 480 V toad center Procedures 10CFR50.59 timers and the 4 kV bus sequentist loading relays. 3.8.1-R, 4.9.A.1.2.f Requirement to inspect the DG in accordance with procedures Prwedares 10CFR50.59 prepared in accordance with manufacturers reconumendations. 3.8.1-R. 3.9.s.8; 4.9.3.8 Requirement for the conowingo Tie-Line Operability TRM 10CFR50.59 (notification to the NRC and periodic verification) associated with Station Blackout requirements.

ENCLOSURE 1: RELOCATED ITEMS MATRIX (pege 13 of 15) ITS CTS Description Location Change Controls 3.8.1-R. 3.9.A.1 Details of what constitutes two qualified offsite circuits Bases. Bases Contrnt (physically independent). Program (5.5.10) 3.8.1-R. Table 3.2.s Note 7 Requirements dictating which Technical specification applies Procedures 10CFR50.59 when a 480 V toad center timer is inoperable. 3.8.1-R, Tabte 4.2.s Requirement that en instrument functionet test of the 4 kV Procedures 10CFR50.59 Emergency Power system voltage Relays. 3.8.1-R, 4.9.A.1.2.1 Emergency Diesel Generator accelerated testing requirements. Maint Pros 10CFR50.59 Procedures 3.8.1-R, 4.9.A.1.2.g.1 The detait of what constitutes the targest single toed (RNR Seses Beses Controt pump motor) for the dieset generator single toed rejection Program (5.5.10) test. 3.8.3-R, 4.9.A.1.2.g.6; Details relating to the design; operation; and maintenance of Procedures 10CFR50.59 3.9.g.6.d the fuel transfer system; tube ott 4ystem; and starting air system. 3.8.3-R, 4.9.A.1.2.] The requirement to drain; remove sediment; and clean each fuel Procedsres 10CFR50.59 cil tank. 3.8.3-R, 3.9.g.6.c Requirement that fuet of t li, the other three storage tanks be Procedures 10CFR50.59 sempted within 24 hours following the determinetton that fuet of t sagted from any tank failed to meet requirements. 3.8.3-R. 4.9.A.1.2.k Requirements to inspect; et teest once every two senths; the Procedures 10CFR50.59 cathodic protection rectifiers and to perform a test every 12 months to determine if the protection is adequete. 3.8.4-R, 4.9.A.2.e; Requirements that are processret in nature; specificatty the Processres 10CFR50.59 4.9.A.2.c; 3.9.8.5 requirement that repelr work en the betteries are initiated in the most expeditious menner to return the failed component to en operable state. 3.8.4-R, 3.9.5.5 Requirements which ties the Actions of the Betteries with the Procedures 10CFR50.59 ECCS and the DG System. 3.8.4-R, 4.9.A.2.c; 3.9.A.4 The mmber of betteries and chargers required and Bases seees Controt interpretetton of what each 60 months means es it retetes to Program (5.5.10) the perfonnance of a discharge test. 3.8.6-R, 4.9.A.2.o; 4.9.A.2.b Requirements that are proceduret in nature; specificetty the Procedures 10CFR50.59 tolerance of the instrument. 3.8.7-R, 3.9.A.3 Details rotating to system design and what Operable seens Bases Bases Control (e.g.; energized) and the AC buses listed. Program (5.5.10)

(' c e EWCLoguRE '1: RELOCATED ITEMS NAT21K tpose 14 of 15) ' ' V I ITS CTS J Deecription Lacetion Change Centrote ' 3.9.1-R, 4.10.A.1 Requirement that any time the Operability of a system or Proceshares ,10CFR50.59 cogonent has been effected by repelr; maintenance or-reptocement of a component; post maintenance testing is respaired to demonstrate Operability of the system or cogonent. 3.9.1-R, 3.10.A.3: 3.10.A.4 poist ioed setpoints ' Proceshares 10CFR50.59 3.9.2-R, 4.10.A.1 Requirements that governs the surveittence testing of the Procedures 10CFR50.59 refueling interlocks foltouing repelr work on the interlocks. 4.0-R, 5.1; 5.3; 5.4; 5.6; Design requirements for the of the Reector Vessel; WSAR '10CFR50.59 1.0 Site goedery Conteinment; and Setemic Design and the description of the Definition - Site Feetures. 4.0-R, 5.5.C Requirement that the spent fuel be stored in spent fuel poet Procedures 10CFR50.59 only in a verticet orientation in approved storage rocks. 5.0-R, 6.2.2.e: Table 6.2.1 minleue Shift Crew composition Table. Proceshares 10CFR50.59-5.0-R, 6.2.2.e Requirement for en SRO to be present during fuel hendting and Procedures 10CFR50.59 to swervise att core alterations. 5.0-R, 6.1.2 Requirement for management directive stating uno has control Procochsres 10CFR50.59 room cessiend function responsibility. 5.0-R. 6.2.3 IsEG Recpairements GA Program 10CFR50.54(e) 5.0-R. 6.5.1; 6.5.2; Review and Audit Requirements (FORC & mucteer Review goerd); WSAR 10CFR50.59 6.6.1.b; 6.8.1.c; Requirement - for procesksres that meet the requirements of ANSI 6.12 N18.7-1972; and Regsfrements that procedures covering en for - envirorumntet monitoring use the guidance in R.G. 4.1. 4 5.0-R. 6.4.1 Respairements that a retraining and reptocement training-WSAR 10CFR50.59 program for the feellity staff shalt be maintained meer the direction of the Sgerintendent freining and shalt meet the respairements of ANSI W18.1 1971 and 10 CFR 55; Appendix A. 5.0-R. 6.9.2.o; 6.9.2.b; Requirement for Loos of Son Report; RV Inservice Inspection Procentsres '10CFR50.59 6.9.2.c; 6.9.2.d; Report; Selenic Montt Inst Insp Report; Primary Cent Leek Rete 6.9.2.f Testing Report; and Seeled source Leekage Report. 5.0-R. 6.19; 6.20 gases for Post Accident Sempting Requirements and for site W SAR 10CFR50.59 stoff uortivg hrs. 5.0-R, 6.6.1.e Roostruments for Reportable Event Action. Proceshares 10CFR50.59 4 3 p 1 ~ .--,-.._.~..n. ...,-.-~,,.._.-n-.,,~.-,.-.n.,-,..

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m .. :y m ,.,C QC gj V ~ EWCLOGURE - ~ 12 RELOCATED ITEMS RRTRIX ' (page.15 of 15) ITS CTS Description 'Lecation ' Change Centrets 5.0-R. 6.9.1.e.4 Re wirement dich states dere to send uRC Reports; Program Proceshsres 10CPR50.59f - - Revisions. + 5.0-R, 6.9.2.h.2 Re pirements for Setid Weste reporting. Procedures 10Cn50.59 5.0-R,. 6.11; 6.15 Respairements for the Radiation Protection Program and the Precedures f10CM50.59 l ledine stonitoring Program; respectively. ~

5. 0 - R,,

6.5.3; 6.8.2; 6.8.3 Requirement for Procentsre Review and Approvet and for iUFSAR - 110CR50.59 i Temporary Procethare Changes. 5.0 - R,, 6.9.1.e . Respairement to seemit a ' Start, Report. Procesares 10CM50.59-5.0-R,, 6.9.2.e; 6.9.2.g: Respairements for mejor changes to the Red Weste Treatment sys; esOI. esos (5.5.1 A) - 6.9.2.h.1; - the Red Dose Asees Report; and specific details -for the Red 6.9.2.h.2; Em op Report and the Red Effluent Ret Report; es well es the 6.9.2.h.3; 6.18 sidseittet reipsirements for these reports and programs. L 0CPR50.54(e) 1 i 5.0-R,. 6.10 Reepairements for record retentlen. ' en Program 5.0-R,. 4.9.A.1.2.d; Roepairements for testing neu and stored diesel fuet-oil ~ geoes geoes Contret-.. 4.9.A.1.2.e (duecriptions of test perferiuance and acceptance criterie for . Program (5.5.10).A the roepsired fuel oil tests that are contained in the ASTN Diesel' Fuel Oil - stenderds). . Test Program n (5.5.9) ~ 5.0-R,, 3.8.C.6; 4.8.C.6 Respairements for monitoring emptosive ses dounstream of the ~ TAM ~ 10CFR50.59 Off-Ges 'Roccabiners. 5.0-R,, 6.9.1.c Respairements for reporting chetterges to eefety and retlef Prece hsres 10CFR50.59 volves. 3/4.8-L, 3/4.8.A; 3/4.8.g; Radioactive Meteriet Centrols;' Liaquid EffLuonts; Geseous 0g05' 'OgGI (5.5.1.c). 3/4.8.C.1; Effluents; Contalement Purging; 48 CR 190; Radiotegical 3/4.8.C.2; Environmental IIenitoring 4 -3/4.8.C.3; j 3/4.8.C.4; 1 3/4.8.C.5; 3/4.8.C.8; 3/4.8.D; l 3/4.8.E 3/4.8-L, 3/4.8.F Solid Radioactive Weste Proceshsres 10CFR50.59 4 1 emu.a-- m.-e 3.s.-.-me

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_t., f i.,,. l-;;.;7 > - [ c .s ?,. - -F I i a L i ? 3 [*#. 'l 5 i ENCLOSURE 2 i t-PECO ENERGY RESPONSE TO t I NRC QUESTIONS REGARDING ITS SECTION 3.3. j 5 i t 'I l 3 i f I 3 l I i l,

i' l 1*'

ENCLOSURE 2' l

i Restated below are the NRC gh regarding ITS Section 3.3 followed by the PECO Energy response. -NRC Ouestion A-1: l The following clarification is requested in the support of documentation for i RELOCATED requirements (replaces former question General-1).' l i NRC Ouestion A-1.a. 3.3.1.1.R, -l -The Discussion of Change (DOC) indicates, "These definitions will be relocated 4 to a licensee controlled document." Please identdy the type of document, in as much specificity as possible, to which these definitions will be relocated (e.g.,- l UFSAR, plant procedures, OA Plan). In addition, please discuss the reasons why relocation of these definitions is justified. j PECO Energy Response to NRC Ouestion A-1.a. ' 3.3.1.1.R, j The Allowable Value for the APRM Flow Biased High Scram contains the term j "W". Consistent with NUREG-1433, this term has not been defined in the l Technical Specifications and the Owner Controlled Document that defines 'W' is not identified in the Technical Specifications. The term "W", which is the loop i recirculation flow in percent of design, will be defined in the UFSAR. In addition, the instrumentation setting in the plant is actually expressed in terms of Volts-DC. The Technical Specifications' Allowable Value is expressed in terms used l by the analyst. As a result, the definition of the term used in the equation for the APRM Flow Biased High Scram Function Allowable Valu6 is not necessary to include in the Technical Specifications. NRC Ouestion A-1.b. 3.3.1.1.R, The DOC indicates, 'This change proposes to relocate the APRM Flow Biased ] Scram Relationship to Normal Operating Conditions Figure to a licensee controlled document." Please identify the type of document, in as much ' I specificity as possible, to which this item will be relocated (e.g., UFSAR, plant procedures, OA Plan). In addition, please discuss the reasons why relocation -l of this item is justified. ) i PECO Energy Response to NRC Ouestion A-1.b. 3.3.1.1.R2 The APRM Flow Biased Scram Relationship to Normal Operating Conditions Figure relocation is justified since the Figure is not referenced in the current Technical Speedications (CTS) or Bases. As a result, it is not necessary for assuring the OPERABILITY of the APRM Flow Biased High Scram. The type of document where this requirement will be relocated is identified in Enclosure 1. 1

y y 1 3 j p up *.. w, i i 4 1 ]

ENCLOSURE 2 1

aj

NRC Question A-1.c.

3.3.1.1.R,7 The DOC indicates, "This change proposes to relocate the response time j testing surveillance along with the acceptance criteria to plant procedures." v CTS 3.1.A states the RPS response times shall not exceed 50 milliseconds. J CTS 4.1.A requires demonstration of the response time once per operating. lj cycle. Describe the basis for the present requirements. Please discuss the ' .l reasons why relocation of this item is justified. i PECO Energy Response to NRC Ouestion A-1.c. 3.3.1.1.R - s The RPS response time requirements in the CTS is only a test of designed j response time from opening of sensor contact up to and including the opening i 2 of trip actuator contacts. 'The basis of this requirement from UFSAR Section ~' 7.2.3.9 is to cGhiYi the system electrical characteristics regarding response time are maintained consistent with the original design. The NUREG-1433 j definition of RPS RESPONSE TIME and associated testing requirements require a test to be performed from the point of exceeding the trip setpoint 'at the channel sensor until de-energization of the scram pilot valve solenoids. As a result, the RPS response time testing requirements of the ITS are more i comprehensive than the CTS requirements. Relocation of the existing PBAPS RPS response time requirement is justified since it verifies design requirements, not analysis assumptions, and the current licensing basis in the CTS does not require full testing of the response tim of the RPS channels. -i i NRC Ouestion A-1.d. 3.3.1.1.R. The DOC indicates, "'lhis change relocates the requirement that an APRM will be considered Operable if there are at least 2 LPRM inputs per level and at i least 14 LPRM inputs of the normal complement." l Please discuss the reasons j why relocation of this item is justified. PECO Energy Response to NRC Ouestion A-1.d. 3.3.1.1.R. The LPRM inputs for OPERABILITY of the APRM have been relocated to the Bases consistent with NUREG-1433. As stated in NEDC-31681,"BWR Owners' Group Improved BWR Technical Specifications," dated April 1989, these details are not necessary in the instrumentation Tables. The definition of OPERABILITY suffices. NEDC-31681 was the BWR Owners' Group Topical Report from which NUREG-1433 was developed. NRC Ouestion A-1.e. 3.3.1.1.R. The DOC Indicates, "This change proposes to relocate the number of instrument channels provided by design column for each Function." Please 2

m 6 . t ENCLOSURE 2. l 1 discuss the reasons why relocation of this item is justified. -i i . PECO Energy Response to,NRC Question A-1.e. 3.3.1.1.R. ~ j The number of instrument channels provided by design is a design detail that is j . not necessary to ensure the OPERABILITY of the RPS Functions since j

OPERABILilY requirements are adequately addressed in Table 3.3.1.1-1.

NRC Ouestion A-1.f. 3.3.1.1.R i 7 ' The DOC indicates, "This change propones to relocate the statement regarding. j the functions design which permits closure of any two lines without a scram being initiated." Please discuss the reasons why relocation of this item is justified. ) PECO Energy Response to NRC Ouestion A-1.f. 3.3.1.1.R7 The statement regarding the Function's design which permits closure of any two lines without a scram being initiated is a description of the design which is q not necessary to assure the OPERABILITY of the RPS-Main Steam isolation Valve Function. j 1 i NRC Ouestion A-1.g. 3.3.1.1.R. The DOC indicates, "This change proposes to relocate Note 5, "lRM's are bypassed when APRM's are onscale and the reactor mode switch is in the run position," which is associated with the IRM High Flux and IRM inoperative Functions and Note 10, 'the APRM downscale trip is autoin64icr4 bypassed when the IRM instrumentation is operable and not high,' which is associated with the APRM Downscale Function." Please discuss the reasons why J relocation of this item is justified. PECO Energy Response to NRC Ouestion A-1.g. 3.3.1.1.R. The statement in Note 5 (IRM's are bypassed when APRMs are onscale and the reactor mode switch is in the run position) and Note 10 (the APRM downscale trip is automatically bypassed when the IRM instrumentation is Operable and not high) are descript;0ns of the design which are not necessary to assure OPERABILITY of the IRM High Flux and IRM inop Functions (for Note 5) and j APRM Downscale Function (for Note 10). ~ i NRC Ouestion A-1.h. 3.3.1.1.Ru The DOC indicates, 'frip setpoints are an operational detail that is not directly related to the Operability of the instrumentation and will be relocated to a l 3

7 ' ENCLOSURE 2 - licensee controlled document." Please identify the type 'of document, in as much specificity as possible, to which this item will be relocated (e.g., UFSAR, plant procedures, QA Plan). PECO Energy Response to NRC Question A-1.h. 3.3.1.1.R,, The type of document where this requirement will be relocated is identified in. NRC Question A-1.i. 3.3.1.2.R, The DOC indicates, "This existing requirement is being relocated to plant procedures to provide assurance it will be maintained." Please discuss the reasons why relocation of this item is justified. PECO Energy Response to NRC Question A-1.1. 3.3.1.2.R, The requirement that SRMs be inserted at normal operating level during core alterations is a procedural detail not necessary for assuring SRM OPERABILITY. The ITS Surveillance Requirements (SRs) provide adequate assurance the ' SRMs are OPERABLE. The SRMs will be inserted at the levels necessary for meeting the SRs. NRC Ouestion A-1.J. 3.3.1.2.R, The DOC indicates, "This existing requirement is being relocated to plant procedures to provide assurance it will be maintained." Please discuss the reasons why relocation of this item is justified. PECO Energy Response to NRC Question A-1.J. 3.3.1.2.R2 The requirement that the SRM minimum count rate during core alterations must be achieved with all rods fully inserted in the core is a procedural detail that is not necessary for assuring SRM OPERABIL!TY. The SRs provide adequate assurance the SRMs are OPERABLE. NRC Ouestion A-1.k. 3.3.2.1.R2 The DOC indicates, "This information will be relocated to the Applicable Safety Analyses section of the proposed Bases for Specifications 3.3.2.1." Please discuss the reasons why relocation of this item is justif' d. e PECO Energy Response to NRC Question A-1.k. 3.3.2.1.R, The number of instrument channels provided by design is a design detail that is not necessary to ensure the OPERABILITY of the Control Rod Block Functions 4

a ENCLOSURE 2 since OPERABluTY requirements are adequately addressed in Table 3.3.2.1-1. I NRC Ouestion A-1.1. 3.3.2.1.R. The DOC indicates, "NUREG-1433 has no equivalent check for the RBM so performance of the daily " Instrument Check" of the Rod Block Monitor will be relocated to plant procedures..." Please discuss the reasons why relocation of this item is justified (see PECO Energy response to NRC Ouestion 3.3.2.1.01, dated January 30,1995). PECO Energy Response to NRC Ouestion A-1.1. 3.3.2.1.R3 The rationale for not including an instrument Check in the PBAPS ITS was that i there was no equivalent requirement in the STS. The RBM design at PBAPS is the same as that utilized in the STS. RBM Channel Checks were not included in the STS since each time a rod is selected the system renulls itself making the Channel Check meaningless. In addition, signals are only fed to the RBM channels upon selection of a rod for withdrawal or insertion. Upon selection of a rod, the appropriate LPRM signals are routed to the RBM. The RBM is then filtered to reduce signal noise. Once the filtered signal nears equilibrium, a gain is applied to null the RBM to a reference source signal. Therefore, a meaningful test would require a rod to be selected which initiates the nulling sequence. However, a Channel Check is the qualitative assessment, by observation, of channel behavior and does not require a rod to be selected. NRC Ouestion A-1.m. 3.3.3.1.Ri The DOC indicates, "The instruments not meeting this criteria, and their associated Technical Specification requirements have been relocated to plant controlled documents." Piease identify the type of document, in as much specificity as possible, to which this item will be relocated (e.g., UFSAR, plant procedures, OA Plan) PECO Energy Response to NRC Ouestion A-1.m. 3.3.3.1.Ri The type of document where this requirement will be relocated is identified in. { NRC Ouestion A-1.n. 3.3.3.1.R2 The DOC indicates, " Details of the system Operability requirements and description of the instruments are relocated to the Bases, procedures, and the UFSAR. Placing this information in these documents provides assurance it will be maintained." Please discuss the reasons why rebcation of this item is 5

^ f .] 2,. i ENCLOSURE 2 justified. PECO Energy Response to NRC Ouestion A-1.n. 3.3.3.1.R j 3 The details of Post Accident Monitoring (PAM) instrumentation (instrument numbers, type of instrument indication, and range) in the CTS are related to t design and are not necessary for assuring the OPERABluTY of the PAM instrumsntation. NRC Ouestion A-1.o. 3.3.3.1.R 3 The DOC indicates, " Details of the performance of surveillance have been relocated to plant procedures. Placing these details in procedures provides assurance they will be maintained..." Please discuss the reasons why relocation of this item is justified. PECO Energy Response to NRC Ouestion A-1.o. 3.3.3.1.R - 3 The procedural details of the performance of a Channel Calibration are not necessary to assure PAM instrumentation OPERABluTY. The SRs and the definidon of CHANNEL CAllBRATION provide adequate assurance the PAM instruments are OPERABLE. 5 NRC Ouestion A-1.p. 3.3.3.1.R4 The CTS 4.7.A.6.c functional test of the atmospheric analyzing system (once per operating cycle) is relocated to plant procedures. The DOC states that the test is performed every time the CAD System is tested per CTS 4.7.A.6.a. The ITS 3.6.3.1 SRs do not include a functional test. Per Bases B 3.6.3.1, the surveillances support containment isolation and CAD system vent operation and must support the feed and bleed approach to maintaining hydrogen and oxygen concentration below combustible levels. How does ITS SR 3.6.3.1.5 3 show a valid functional test of the CAD and atmospheric analyzing system? PECO Energy Response to NRC Ouestion A-1.p. 3.3.3.1.R4 The requirement to functionally test the primary containment atmospheric analyzing system once per operating cycle in conjunction with existing CTS 4.7.A.S.a was relocated since the functional test of the CAD System was relocated. The requirement to functionally test the primary containment analyzing system once per operating cycle is not necessary to assure system OPERABluTY since a CHANNEL CAUBRATION of this system is required by SR 3.3.3.1.2 once per 92 days. The ITS definition of CHANNEL CAUBRATION includes the requirement to perform a CHANNEL FUNCTIONAL TEST. As described in the Bases B 3.3.3.1 for the Drywell and Suppression Chamber ) 6 j

g ; 7 y w, } ~- - c w-y- n 3:4 o l } + c 7

ENCLOSURE 2 j

y Hydrogen and Oxygen Anahrms (primary containment atmospheric analyziet system), oech gas analyzer must be capable of sampling either the drywoM or the Mr-+::t-r, chamber. 4 Since this de6nes a channel with respect to these g CAllBRATION includes venfying the capability to semple and analyze the. 1 Functions, the CHANNEL FUNCTIONAL TEST requirement of the CHANNEL. drywel and suppression chamber atnesphere once per_92 days. _ As a result,L i the rhM requirement is not necessary to assure the OPERABILITY of the; ~ Drywell and Suppression Chamber Hydrogen and Oxygen Analyzers. 1 NRC Ouestion A-1.q. 3.3.4.1.R, The DOC indicates, "...ARI function requirements are being relocated to a licensee controlled document." Please identify the type of document, in as much specificity as possible, to which this item will be relocated (e.g., _UFSAR, j plant procedures, OA Plan). PECO Energy Response to NRC Ouestion A-1.q. 3.3.4.1.Ri j The type of document where this requirement will be relocated is identified in j l NRC Ouestion A-1.r. 3.3.4.1.R, The DOC indicates, "...ATWS-RPT manual actuation function requirements are j being relocated to a licensee controlled document." Please identify the type of l document, in as much specificity as possible, to which this item will be i j relocated (e.g., UFSAR, plant procedures, OA Plan). PECO Energy Response to NRC Ouestion A-1.r. 3.3.4.1.R, j l The type of document where this requirement will be relocated is identified in j. 3 ' NRC Ouestion A-1.s. 3.3.4.1.R t 3 [ The DOC indicates, "This type of information will be relocated to the Bases in l the section entitled Applicable Safety Analyses, LCO, and Applicability and will 4 be controlled in accordance with 10 CFR 50.59.* Please discuss the reasons l why relocation of this item is justified. .} PECO Energy Response to NRC Ouestion A-1.s. 3.3.4.1.R i 3 The phrase " automatic actuation of logic and actuation dev'ces" when l describing features of the ATWS-RPT function that are required to be ) 4' OPERABLE for the ATWS-RPT Function to be OPERABLE is a detail that { j 7 i -l f f I f i

+ 1

i, ENCLOSURE 2 ?

describes what constitutes tho' system. This detail is rot necessary to be specified in the iTS to assure OPERABILITY. ,c e NRC Question A-1.t. 3.3.4.1.R. 1 The DOC indicates, _"This type of information will be_ relocated to the plant f procedure and design documents and will be controlled in accordance with 10 : CFR 50.59." Please discuss the reasons why relocation of this item is justified. PECO Energy Response to NRC Question A-1.t. 3.3.4.1.R. The number of the A1WS.RPT instrument channels provided by design and the - statement that the ATWS-RPT instruments are the same instruments used by.. the Core and Cooling Systems are design dotads. These details are not necessary to assure the OPERABILITY of the ATWS-RPT instruments. In addition, the detail regarding the number of channels provided by design is not h necessary to be specified since the OPERABILITY requirements are adequately addressed in LCO 3.3.4.1. NRC Question A-1.u. 3.3.4.1.R. The DOC indicates, " Performance every 3 months of a Logic System Functional Test of the ATWS-RPT function without tripping the recirculation pump breaker provides additional assurance of proper operation of the trip units and logic systems but is not required by NUREG-1433. Since this additional requirement for testing can be wtwy M controlled by administrative procedures, this testing requirement will be relocated to plant procedures and controlled in - accordance with 10 CFR 50.59." Please discuss the reasons why relocation of - this item is justified. PECO Energy Response to NRC Question A-1.u. 3.3.4.1.R. The 92 day ATWS-RPT Logic System Functional Test (which excluded recirculation pump trip) was added to the CTS to address an issue in the NRC Safety Evaluation Report dated 12/21/88 regarding PBAPS Units 2 and 3 compliance with the ATWS rule for the ARI and RPT Systems. The NRC concem was that, for the trip units and logic,' a once por operating cycle functional test frequency had not been accepted. Foxboro electronic trip units from the reactor level compensation instrumentation are used in the ARl/RPT System. Foxboro electronic trip units from the reactor level compensation instruir=idatiori are also used by ECCS instrumentation, RCIC instrumentation, PAM instrumentation, and Remote . Shutdown instrumentation. No requirements regarding 92 day Logic System 8

r

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~ y d x. ? ENCLOSURE 2'. Functional Tests of trip units and logic for instrumentation, other ATWS-RPT. Instrumentation, were imposed to assure OPERABILITY of instrumentation. As a result, the proposed relocated requirement is not considered necessary to assure OPERABILITY of the ATWS-RPT instrumentation. NRC Ouestion A-1.v. 3.3.5.1.R, The DOC indicates, "This change will relocate items which are procedural in nature (e.g., conversions, specific instructions, etc.) to procedures." Please l discuss the reasons why relocation of this item is justified. J PECO Energy Response to NRC Question A-1.v. 3.3.5.1.R 3 The details proposed to be relocated by this Discussion of Change are design ] details describing the comprses the functions initiate, setpoint conversions, cnd details of how to pedorm a Channel Functional Test. These details are not necessary to assure the OPERABILITY of the ECCS Instrumentation Functions. In addition, the details of how to perform a Channel Functional Test are adequately addressed by the definition of CHANNEL FUNCTIONAL TEST. 1 NRC Question A-1.w. 3.3.5.1.R, I The DOC indicates, " Trip setpoints are an operational detail that is not directly j related to the Operability of the instrumentation and will be relocated to a. l licensee controlled document." Please identify the type of document, in as j much specificity as possible, to which this item will be relocated (e.g., UFSAR,~ l plant procedures, QA Plan). ] PECO Energy Response to NRC Question A-1.w. 3.3.5.1.R, The type of document where this requirement will be relocated is identified in. I NRC Ouestion A-1.x. 3.3.5.1.R3 The DOC indicates, "This change proposes to relocate specific information about the Functions..." Please discuss the reasons why relocation of this item is justified. PECO Energy Response to NRC Question A-1.x. 3.3.5.1.Ra The details proposed to be relocated by this Discussion of Change are design details describing the components the functions initiate and are not necessary to assure the OPERABILITY of the ECCS Instrumentation Functions.' l 9 i a l i

m 4 ::: i? l s j. = NRC Ouestion A-1.y.1 3.3.5.1.Rf j . The DOC indicates, "This change relocates the requirements for the Trip system ]j bus power monitors, the core spray sparger differential pressure monitor, the LPCI Cross Connect Position Indication, and the Surveillance requirements for? I the ADS. Relief Valves Bellows pressure switches to a licensee controlled document." Please identify the type of document,'in'as much specificity as 1 possible, to which this item will be relocated (e.g., UFSAR, plant procedures,.

)

' OA Plan). l PECO Energy Response to NRC Ouestion A-1.y. 3.3.5.1.R '1 t The type of document where this requirement will be relocated is identified in ~ i NRC Question A-1.z. 3.3.5.1.R. The DOC indicates, "This change proposes to relocate specifics about the i instruments (what they consist of, etc.) to the procedures / bases." Please .j discuss the reasons why relocation of this item is justified, j PECO Energy Response to NRC Ouestion A-1.z. 3.3.5.1.R.. 1 The details proposed to be relocated by this Discussion of Change are design l details describing the types of components that make up the channels (analog transmitters,-indicators, and electronic trip units) and are not necessary to' l assure the OPERABILITY of the ECCS Instrumentation Functions. l I NRC Ouestion A-1.aa. 3.3.5.1.R l 7 The DOC indicates, "This instrument Function is being relocated to plant specific controls." Please identify the type of document, in as much specificity l as possible, to which this item will be relocated (e.g., UFSAR, plant procedures, OA Plan). l t PECO Energy Response to NRC Ouestion A-1.aa. 3.3.5.1.R. 7 The type of document where this requirement will be relocated is identified in j. 1 i NRC Ouestion A-1.bb. 3.3.5.2.R, j The DOC indicates, "This change _will relocate items which are procedural in i nature (e.g., conversions, specific instructions, etc.) to procedures." Please ] discuss the reasons why relocation of this item is justified. \\ j i.,

m 10 I

l u 4 ,y

ENCLOSURE 2 PECO Energy Response to NRC Ouestion A-1.bb. _3.3.5.2.Rf The details proposed to be relocated by this Discussion of Change are design ) details related to setpoint conversions, details of how to perform a Logic System Functional Test and details of how to perform a Channel Functional ] Test. These details are nog necessary to assure the OPERABILITY of the RCIC Instrumentation. In addition, the details of how to perform a Logic System Functional Test and a Channel Functional Test are adequately addressed by the I definitions of LOGIC SYSTEM FUNCTIONAL TEST and CHANNEL FUNCTIONAL TEST, respectively, i NRC Ouestion A-1.cc. 3.3.5.2.R 2 The DOC indicates, " Trip setpoints are an operational detail that is not directly related to the Operability of the instrumentation and will be relocated to a licensee controlled document." Please identify the type of document, in as much specificity as possible, to which this item will be relocated (e.g., UFSAR, plant procedures, OA Plan). PECO Energy Response to NRC Ouestion A-1.cc. 3.3.5.2.R2 The type of document where this requirement will be relocated is identified in. NRC Ouestion A-1.dd. 3.3.5.2.R l 3 The DOC indicates, "This change proposes to relocate specifics about the instruments (what they consist of, etc.) to the procedures / Bases." Please discuss the reasons why relocation of this item is justified. 1 PECO Energy Response to NRC Ouestion A-1.dd. 3.3.5.2.R3 The details proposed to be relocated by this Discussion of Change are design details describing the components the functions initiate and the types of components that make up the channels (analog transmitters, indicators, and electronic trip units). These design details are not necessary to assure the OPERABILITY of the RC;C Instrumentation Functions. NRC Ouestion A-1.ee. 3.3.5.2.R4 The DOC indicates, "This change relocates the requirements for the Trip System bus power monitor to a licensee controlled document." Please identify the type - of document, in as much specificity as possible, to which this item will be relocated (e.g., UFSAR, plant procedures, OA Plan). 11 i

m .g< ENCLOSURE 2. PECO Energy. Response to NRC Question A-1.ee. 13.3.5.2.R.. The type of document where this requirement will.be relocated is identified in. 4. H NRC Question A-1.ff. 3.3.6.R, y The DOC indicates, "This change proposes to relocate the number of instrument channels provided by design column for each Function." Please discuss the reasons why relocation of this item is justified. U PECO Energy Response to NRC Ouestion A-1.ff. 3.3.6.R, The number of instrument channels provided by design is a design detail that isR not necessary to assure the OPERABILITY of the Primary Containment isolation Functions since OPERABluTY requirements are adequately addressed byTable 3.3.6.1-1. - NRC Ouestion A-1.gg. 3.3.6.1.R. - The DOC indicates, " Trip setpoints are an operational detail that is not <r ctly related to the Operability of the instrumentation and will be relocated to c licensee controlled document." Please identify the type of document, in as much specificity as possible, to which this item will be relocated (e.g., UFSAR, . plant procedures, QA Plan). PECO Energy Response to NRC Question A-1.gg. 3.3.6.1.R. The type of document where this requirement will be relocated is identified in. NRC Ouestion A-1.hh. 3.3.6.2.Ri The DCC indicates, " Trip setpoints are an operational detail that is not directly q related to the Operability of the instrumentation and will be relocated to a j licensee controlled document." Please identify the type of document, in as j much specificity as possible, to which this item will be relocated (e.'g., UFSAR, plant procedures, OA Plan). 4 PECO Energy Response to NRC Question A-1.hh. 3.3.6.2.R ~l i The type of document where this requirement will be relocated is identified in ~ ~ f NRC Question A-1.ii. 3.3.7.1.Ri 12 l b

,f -m i y ' E'NCLOSURE 2 e '1 g ' The DOC indicates, " Trip setpoints are 'an operational detail that is not directly

related to the Operability of the instrumentation and will be relocated to a' 0s

' licensee controlled document." Please identify the type of document, in as much specificity as possible, to which this item will be relocated (e.g., UFSAR, plant procedures, OA Plan).' F PECO Energy Response to NRC Question A-1.ii. 3.3.7.1.Rf L The type of document where this requirement will be relocated is identified in L li ' NRC Ouestion A-1.#. 3.3.7.1.R, The DOC indicates, "This change proposes to relocate' specific details about the instrument (number of channels provided by design, etc.) to the Bases. Please discuss the reasons why relocation of this item is justified. PECO Energy Response to NRC Question A-1.j. 3.3.7.1.R2 The details proposed to be relocated by this Discussion of Change are details related to the number of channels provided by design, thel description of the. L parameter monitored by the trip system, and the description of what constitutes ~ maintaining trip capability. These design details are not necessary to assure.- the OPERABILITY of the Main Control Room Emergency Ventilation (MCREV).. i System instrumentation. In addition, OPERABILITY requirements with regard to i the number of channels provided by design are adequately addressed by LCO j 3.3.7.1. NRC Ouestion A-1.kk. 3.3.7.1.R 3 The DOC indicates, "The requirements for trip functions for the MCREV initiation instrumentation not associated with the Control Room Air intake Radiation-High I channels have been relocated to a licensee controlled document." Please I identify the type of document, in as much specificity as possible, to which this - 'l item will be relocated (e.g., UFSAR, plant procedures, OA Plan). O PECO Energy Response to NRC Question A-1.kk. 3.3.7.1.R3 The type of document where this requirement will be relocated is identified in. NRC Ouestion A-1.II. 3.3.7.1.R4 The DOC indicates, "This change will relocate items which are procedural in f: nature (e.g., conversions, speedic instructions, etc.) to procedures." Please I' 13

+ l l%fA N i ~ l l x ENCLOSURE 2 discuss the reasons why relocation of this item is Justified. 1 j s PECO Energy Response to NRC Ouestion A-1.ll. 3.3.7.1.R4 _ !l The details proposed to be relocated by this Discussion of Change are procedural details related to the performance of the Channel Calibration of the 1 MCREV System Instrumentation Radiation Monitor and are not necessary to. assure the OPERABILITY of the MCREV System Instrumentation. In addition, the details of how to perform a Channel Calibration are_ adequately addressed l by the definition of CHANNEL CAUBRATION. j NRC Ouestion A-1.mm. 3.3.8.1.R i i The DOC indicates, "This change will relocate items which are procedural in j nature (e.g., conversions, specific instructions, etc.) to procedures." Please discuss the reasons why relocation of this item is justified. -1 .PECO Energy Response to NRC Ouestion A-1.mm. 3.3.8.1.R, i The details proposed to be relocated by this Discussion of Change are design details related to the setpoint conversion (percent of rated voltage to volts) and the procedural details related to the test conditions used for the time delay, relays. These details are not necessary to assure the OPERABILITY of the Loss of Power (LOP) instrumentation. 1 4 s NRC Ouestion A-1.nn. 3.3.8.1.R, The DOC indicates, " Trip setpoints are an operational detail that is not directly related to the Operability of the instrumentation and will be relocated to a j licensee controlled document." Please identify the type of document, in as much specificity as possible, to which this item will be relocated (e.g., UFSAR, l plant procedures, OA Plan). 1 PECO Energy Response to NRC Ouestion A-1.nn. 3.3.8.1.R2 The type of document where this requirement will be relocated is identified in l. j i NRC Ouestion A-1.oo. 3.3.8.1.R l 7 The DOC indicates, "This change proposes to relocate specifics about the instruments (the specific functions (s) they perform, etc.) to the UFSAR/ Bases." Please discuss the reasons why relocation of this item is justified. j 14 1 I

i j s w.; +- b ;* e e ENCLOSURE 2 ' l PECO Energy Response to NRC Ouestion A-1.oo. 3.3.8.1.R, The details proposed to be relocated by this Discussion of Change are design

s. -

details describing the components the functions initiate, the relay type,' and. nomenclature. These design details are not necessary to assure the OPERABILITY of the LOP instrumentation Functions. 3 1 ou J .- NRC Ouestion A-1.pp. 3.3.8.1.R l 4 The DOC indicates, " Trip setpoints are an optional detail that is not directly 1 related to the Operability of the instrumentation and will be relocated to a licensee controlled document." Please identify the type of document, in as j much specificity as possible, to which this item will be telocated (e.g., UFSAR, 1 plant procedures, OA Plan). 4 FECO Energy Response to NRC Ouestion A-1.pp. 3.3.8.1.R The type of document where this requirement will be relocated is identified in i. i NRC Ouestion A-1.qq. 3.3.8.2.R, The DOC indicates, "This proposed change will relocate CTS 3/4.15, " Seismic ~ j Monitoring instrumentation," and associated Bases to a licensee controlled i document." Please identify the type of document, in as much specificity as 'l possible, to which this item will be relocated (e.g., UFSAR, plant procedures, OA Plan). 1 PECO Energy Response to NRC Ouestion A-1.qq. 3.3.8.2.R, The type of document where this requirement will be relocated is identWied in 1 NRC Ouestion A-2 The response to question 3.3.5.1.02 states Table 3.3.5.1-1 Action E is applied .j to Functions 1.d, 2.g, and 3.f. Required Action E.1, Note 1 states "only applicable 'in MODES 1,2, and 3" and Note 2 states the action is "only applicable to Functions 1.d and 2.g." Per Table 3.3.5.1-1, Function 1.d is. applicable in Modes 1,2,3,4"), and 5"), Function 2.g is ap)icable in Modes 1, 2,3,4 ),5"), and Function 3.f is applicable in Modes 1,2(, and 3, where (a) W = when associated subsystem (s) are required to be OPERABLE and (d) = with reactor pressure > 150 psig. I 15 l t l

/ i.: l 1 ENCLOSURE 2 j Resolve the following: { Table 3.3.5.1-1, Function 1.d, is not applicable in Modes 4 ) and 5*) per Note 1 l i Table 3.3.5.'1-1, Function 2.g, is not applicable in Modes 4*) and 5 ) per Note 1. 'l Table 3.3.5.1-1, Function 3.f, is not Applicable per Note 2 We note the logical AND between Required Actions E.1 and E.2, implying that Required Action E.1 is applicable to Function 3.f despite Note 2. Resolve these j discrepancies. 1 - PECO Energy Response to NRC Question A-2 The resolution of the apparent discrepancy between Required Actions E.1 and j E.2 of Specification 3.3.5.1 and the associated Functions is addressed in the i following discussion from Bases B 3.3.5.1.

l i

" Required Action E.1 is intended to ensure that appropriate actions are taken if - multiple, inoperable channels within the Core Spray and Low Pressure Coolant j injection Pump, Discharge Flow - Low (Bypass) Functions result in redundant automatic initiation capability being lost for the feature (s)..." "In this situation (loss of redundant automatic initiation capability), the 7. day allowance of Required Action E.2 is not appropriate and the subsystem i associated _with each inoperable channel must be declared inoperable within -l 1 hour. As noted (Note 1 to Required Action E.1), Required Action E.1 is only. applicable in MODES 1, 2, and 3. In MODES 4 and 5, he specific initiation time of the ECCS is not assumed and the probability of a LOCA is lower. Thus, a ~j total loss of initiation capability for 7 days (as allowed by Required Action E.2) is allowed during MODES 4 and 5. A Note is also provided (Note 2 to Required j Action E.1) to delineate that Required Action E.1 is only applicable to low r pressure ECCS Functions. Required Action E.1 is not applicable to HPCI Function 3.f since the loss of one channel results in a loss of function (one-out-of-one logic). This loss was considered during the development of Reference 5 and considered acceptable for the 7 days allowed by Rsquired Action E.2." g -i Reference 5 of B 3.3.5.1 is NEDC-30936-P-A, "BWR Owners' Group Technical l Specification improvement Analyses for ECCS Actuation instrumentation, Part - j 2," December 1988. j i l 1 i is j i i a

p E z7 y Il ' ', l ^ ENCLOSURE 2 NRC Question A-3 s0

In response to question 3.3.8.104, the justification for the 30-day allowed outage time (AOT) for Required Action A.2 when one channel por source of the 4-kVac Emergency Bus Undervoltage (Degraded Voltage High Setting) and the 4-Kvac Emergency Bus Undervoltage (Degraded Voltage non-LOCA) Functions are inoperable for up to two buses is based on the. multiple number of relays A

per source times the total of eight buses for both units, the diversity of f e other Functions, and tim capability to manually transfer to the alternate source. This. 1 " ensures that the operator will have the indication of a degraded voltage condition from at least 2 of the 4kV emergency buses during the proposed 1 ' cu *=ca time." The response to 3.3.8.1.05 states that three of the four diesel generators are required to start. If the bus undervoltage relay is inoperable, the associated source breaker will not automatically trip. Therefore, if the 4-Kvac Emergency Bus Undervoltage relays for two buses are inoperable (for up to 30 days), the associated diesel generators will not automatically start as designed ] for.a degraded voltage condition..On what basis is the ability of only two of the - four diesel generators to start acceptable for 30 days? lq PECO Energy Response to NRC Question A-3 j Condition B of Specification 3.3.8.1 only applies to the 4kV Emergency Bus' Undervoltage (Degraded Voltage High Setting) and the 4kV Emergency Bus Undervottage (Degraded Voltage non-LOCA) Functions.. The 30 day allowed i outage time (AOT) when one channel per source of the 4kv Emergency Bus -l Undervoltage (Degraded Voltage High Setting) and the 4kv Emergency Bus 1 Undervoltage (Degraded Voltage non-LOCA) Functions are inoperable for one - i or two buses takes into consideration the diversity of the degraded voltage functions, the fact that the Degraded Voltage High Setting and the Degraded j Voltage non-LOCA Functions provide only a marginal increase in the protection j provided by the voltage monitoring scheme, the low probability of the grid operating in the voltage band protected by these Functions for any length of 3 time without actuating any of the other degraded voltage relays, and the ability j of the operators to perform the functions manually. In the event of loss of the' j Degraded Voltage High Setting and the Degraded Voltage non-LOCA Functions i on one or two of the four 4kV buses on a unit, degraded voltage protection .l (transfer to the alternate source and diesel generator start if the transfer to the j attemate source does not result in adequate bus power) would be provided as j follors: 'j 1)~ Automatically by the 4kV Emergency Bus Undervoltage (Degraded Voltage l Low Setting) Function; or

2) Automatically by the 4kV Emergency Bus Undervoltage (Degraded Voltage

-l l ] 97 i ) I l

w ENCLOSURE 2 ~ i . LOCA) Function in the event of a LOCA; or I

3) Manually by operator action in response to a degraded voltage relay 1

J actuation on the remaining buses with Operable 4kV Emergency Bus - Undervoltage (Degraded Voltage High Setting) and the 4kV Emergency Bus Undervoltage (Degraded Voltage non-LOCA) Functions. .j j i . NRC Ouestion A-4 ^ l LCO 3.3.8.1, Surveillance Requirements, Note 2, discusses the acceptability of { delayirg entry into the associated Conditions and Required Actions for up to 2 hours when a channel is rendered inoperable solely for the performance of a .l required surveillance. Discuss the basis for the acceptability of this change for Functions 2,3,4, and 5 (see PECO Energy Response to NRC Ouestion .j 3.3.8.105 dated January 30,1995). i Note: " Initiation capability for 3 DGs" and "undervoltage transfer l capability for three 4 kV emergency buses" is the terminology used. It appears that the logic cepsbility may be available but not the end device (DG or attemate source). j What controls are there to prevent rendering a channel inoperable when a non-associated DG or altamate source is inoperable for some other cause? j PECO Energy Response to NRC Ouestion A-4 l The acceptability of allowing a 2 hour delay in entering the associated l Conditions and Required Actions for an inoperable channel that was made inoperable solely for performance of required surveillances for Specification 3.3.8.1, Functions 2,3,4, and 5, is the same as described in Discussion of + Change L, for ITS 3.3.8.1 (only 3 of the 4 diesel generators are required to start : within the required time for the design basis accident). The rationale for applying this justification to Functions 2,3,4, and 5 (degraded voltage j Functions) as described in the Bases for Specification 3.3.8.1 is as follows: j i When the setpoint is exceeded for a degraded voltage channel,' the preferred offsite source breaker to the 4kv emergency bus,is tripped and l autotransfer to the altemate offsite source is initiated. If the altemate source does not provide adequate power to the DJs as sensed by the i undervoltage relay, a diesel generator start signal is initiated. i The controls to prevent rendering a Loss of Power inst Enent channel inoperable when a non-associated diesel generator or alternate source is I 18 I i

~ ~ c

p h.

L = ENCLOSURE 2. inoperable for some other cause are the reviews of log' entries prior to rendering a Loss of Power instrument channelinoperable. The reviews of the _ log entries will be performed in accordance with Specification 5.5.11, "Salsty Function Determination Program", to ensure a loss of safety function would not oocur (i.e., the non-associated desel generators or alternate source,-.as x applicable, are available). ' NRC Ouestion A-5 Provide (in tabular format,' if possible) a list by ITS Function (per.the tables in Section 3.3) the following liJuriristion: a. The ITS Table and Function number b. The ITS Allowable Value c. The corresponding trip setting d. The corresponding CTS Trip Level Setting e. ' The correspond;ng CTS location of the Trip Level Setting f. A brief explanation for the changes, such as revised setpoint due to new L setpoint ir thodology or change to the instrument range (such as with the reactor vessel level channels using instrument zero instead of the reference to vessel zero). PECO Energy Response to NRC Question A-5 See Attachment A of Enclosure 2 for requested iiJurmation. l NRC Ouestion A4 Please identify any differences between the Unit 2 ITS and the Unit 3 ITS for Section 3.3. PECO Energy Response to NRC Question A4 Differences between the PBAPS Unit 2 and Unit 3 ITS and Bases for Section 3.3 are identified in the marked up pages in Attachment B of Enclosure 2. l NRC Ouestion A-7 Implementation of the General Electric (GE) setpoint irmihedology (NEDC-31336, " General Electric Instrumentation Setpoint Methodology") results in - setpoints designed to provide a 95% probability of providing the trip function before the process variable reaches the analytical limit with h'gh confidence. The staff approved NEDC-31336 in an SE dated February 9,1993, and noted the use of independent, random and normally distributed data but expressed i l 19 l \\

.= x e an _ i3 -{2 - } i. s '. ENCLOSURE 2. concern with the use 'of only a one sided distribution with _a 95 percent. ) probability but an undefined confidence level.' The staff notes that Regulatory 1 Guide (RG) 1.105, " Instrument Setpoints for Safety-Related Systems," _1982, i does_not provide specific guidance on confidence level. The staff also notes that ISA 67-04, "Setpoints for Nuclear Power Plants," 1982 defines neither a confidence interval or level but requires justification for the adaqwy of the l irme.cdelegy chosen to comtine uncertainty terms. The staff subsequently j G endorsed ISA 67.04,1982 in RG 1.105, Revision 2, dated February 1986. j Licensee's adopting the GE methodology must ' provide justification for'an ~l undefned confidence interval when developing a trip.setpoint. Reference to a -l "high degree of confidence" (undefined confidence Svel) is not. acceptable to - I the staff. In general the staff has accepted 95/95 confidence interval / levels for plant safety-related setpoints. Based on the above, please provide. additional J justification for the use of undefined confidence intervals and/or levels when 1 utilizing the GE r ;pcin; ir ;hodeicgy in plant setpoint calculations. l PECO Energy Response to NRC Question A-7 PECO Energy supports the position contained in GE letter (MFN-142-93) dated l September 8,1993 from D. Robare (GE) to B. Boger (NRC), that there are no ~j regulatory requirements to use a specific confidence level in instrument setpoint. j rreibodology. The regulatory basis established for determining protective l system instrument setpoints is contained in Regulatory Guide 1.105, Revision 2, i " Instrument Setpoints for Safety-Related Systems.".The Regulatory Position Section of Regulatory Guide 1.105 endorses standard ISA-S67.04-1982, "Setpoints for Nuclear Safety-Related instrumentation Usod in Nuclear Power Plants." This standard does not establish a specific confidence level to be used l in determining trip setpoints or allowable values. Consequently, Regulatory j Guide 1.105 does not require a specific confidence level. Therefore utilization of-l a specific confidence level is beyond the scope of current regulatory guidance l and instrument setpoint irminodology does not address a specific confidence l level. In addition, guidanoe provided in Generic Letter 91-04, " Changes in. Technical Specification Surveillance intervals to Accommodate a 24-month Fuel. Cycle" recommends to " Confirm that the values of drift for each instrument type. j (make, model, and range) and applicistion have been determined with a high j probability and a high degree of confidence". Nonetheless, we have a high - i degree of confidence that the trips will occur as_ required based on many years . of operating experience and design. j i Confidence data are not generally available from instrument vendors in j instrument setpoint ir ihodology, vendor limits for accuracy error, calibration i error, error due to drift, etc., are conservatively interpreted as two or three 'l l 20 l ) f 'f .u. __.,., _,. _ J

=- ,l 9 i 3 1 ENCLOSURE 2 - j standard deviations of a normal distribution. We believe that vendor error limits j in each Magary almost oortainly cover a greater number of standard deviations d

than the number assumed, so the sigma values used are greater than those

? _ implied by the vendor limits. Moreover, plant surveillance data as documented in NEDC-32180P contain evidence that the total sigma used for each instrument is greater than 'actually being realized by the instruments in service, j Confirmation Ratios (i.e, the ratio of obsened value to allowed value) obtained .l from these field data which are greater than 1.0 are much fewer than the 5% .l ' that would be. expected from a 95% probabihty criterion. This irdmaa that the" .l instruments are performing within the limits derived from combining the error j categories. These observations were further evidenced in subsequent PECO. -i Energy As-Found/As-Left data analyses performed to support 24 month refuel i cycles. In these PECO Energy analyses, the allowed value.used was conservative!y established as procedural aHowance, thereby not taking credit for the effects.of Accuracy Error, Drift, and Temperature Effect on Drift. _j Considering the foregoing, we believe that_ utilization of a specific confidence I level is beyond the scope of current regulatory guidance and we believe that ' ( 95% probability values are conservatively evaluated because the vendor j instrument error limits were interpreted so as to result in larger sigma then-( required. This conservatism is substantiated by instrument field performance. j data which show that, with rare exception, actual instrument errors are less than j allowed. 1 NRC Ouestion A-8 For instruments used that are different than those described in Section 2.0 'of NEDC-31336, please provide discussion of how the drift evaluation is in conformance to the criteria set forth in NEDC-31336 PECO Energy Response to NRC Question A-8 In addition to those instruments described in Section 2.0 of NEDC-31336, As. Found/As-Left data for additional types of instrumentation have been analyzed 1 in NEDC-32160P, " Calibration Interval Extension" and in analyses performed by { PECO Energy to support 24-month fuel cycles. These studies have been performed using the drift confirmation model described in NEDC-31336.- With the exception of the functions listed below, the ITS functions listed in [ Attachment A are composed of instruments similar to those described in j Section 2.0 of NEDC-31336, or included in NEDC-32160P or analyses performed by PECO Energy to support 24-month fuel cycles. j The following instrument functions are comprised of components that are not l 1 21 l t U

- ?.; ^2 v q ci' - ' ENCLOSURE 2 - t =! similar to those analyzed in the previously mention studies and have not had i drift analyses completed: ~! 1. MSIV Closure -l

2..

Turbine Stop Valve Closure -j 3. HPCI Pump Discharge Flow 4. - Core Spray Pump Discharge Flow 5. LPCI Pump Discharge Flow. 1 6. HPCI Steam Line Flow

. g 7.

RCIC Steam Line Flow l 8. RWCU Flow t .n; { NRC Question A-9 Provide a discussion on the use of a single sided probability distribution for - instrument channels (note that the GE methodology bounds RPS and bistables): { that provide trips or permissive for both increasing and decreasing variables. I PECO Energy Response to NRC Ouestion A-9 PECO Energy supports the position for the use of single-sided distributions 1 contained in GE letter (MFN-1_42-93) dated September 8,1993 from D. Robare - (GE) to B. Boger (NRC). The use of single-sided distributions for channels that - j provide trips or permissives for both increasing and decreasing variables is j Justdied if the upper and lower analytical limits cannot be reached. _ j simultaneously, or if independent trip devices, one associated with each analytical limit, are used. The scope of instrument setpoint methodology is setpoints and does not include requirements for what errors must be included i for indicators and recorders. l a 'I -i i 1 1 i l 22 i I i

t.. _W. c b (l,y ; t '!:) - 4 a-s;.,. - f l 1 ~ 4 '1 ENCLOSURE 2 i ATTACHMENT A 1 PECO ENERGY RESPONSE r .t TO NRC QUESTION A-5 i ~ ITS FUNCTION MATRIX i i i i l .I I

g-PEACH BOTTOM ATOMIC POWER STATION IMPROVED TECHNICAL SPECIFICATIONS PROJECT RAI FOR SECTION 3 FUNCTION DESCRFI1ON rrS ALLOWABt2 "IRIP SET POINT C13 TRIP CI3 LOCATION NOTES VALVE (AV) LEVEL SETTING Table 3.3.1.1-1: Reactor Protection Instrumentation 1.a IRM Neutron Flux s120/125 divisions 115.69 % s120/125 divisions Table 3.1.1(3) 1 High 1.b IRM Inop NA 2.a APRM Startup High s15.0% RTP 13% Power s15% Power Table 3.1.1(8) 1 Flux Scram 2.b APRM Flow Biased so.66 + 63.9% 0.66W + 62.7% 0.66W + 66% - Table 3.1.1(5) 2 High Scram RTP; (0.66W + 0.66AW 63.9% - 0.66AW RTP for Single Loop Operation) 2.c APRM Scram Camp s118.0% RTP 117 % 120 % Table 3.1.1(5) 2 2.d APRM Downscale 22.5% RTP 4.5% 22.5% Indication Table 3.1.1(7) 2 2.e APRM Inop NA NA 3 Reactor Pressure s1085.0 psig 1073.5 psig s1085.0 psig Table 3.1.1(9) 1 High 4 Reactor Vessel al.0in. 1.5in 20 in Table 3.1.1(11) 3 Water Ixvel.lew(L3) 5 MSIV Qosure s10% closed s10 % s10% closure Table 3.1.1(15) 1 6 Drywell Pressure-s2.0 psig 1.925 psig s2.0 psig Table 3.1.1(10) 1 High 7 SDV Water Level-s50.0 Gallons 44.28 Gallons s50.0 Table 3.1.1(12) 1 High Gallons 8 'ISV-Oosure s10% closed s10 % s10% closure Table 3.1.1(17) 1 9 TCV Fast Gosure, 2500.0 psig 600.0 psig 500<P450 psig Table 3.1.1(16) 2, 5 Trip Oil Pressure-Low

.....w. - '-=.,,,. 5 f.' -' ~ ~ 10 Tcrbine Condenser-223.0 la. Hg 23.45 is Hg m23.0 is Hg - Table 3.1.1(13) 1-l Low Vacuum vacuum - 11 Main Steam Line-15 x Full Power 3 x 10E4 mR/hr - s15 x Full Power-Table 3.1.1(14) 1. High Radiation

Background

Background 12 Reactor Mode NA-Switch-Shutdown Position 13 - Manual Scram NA l 14. RPS Channel Test NA ( Svdich Tahle 3.3.2.1-1: Constrol Rod Block Instrumnastation 1.a law Power Range-COLR Per COLR s10E6 Counts / Table 3.2.C(10) 2, 4 Upscale Second 1.b Intermediate Power COLR Per COLR s108% Indication Table 3.2.C(8) - 2, 4 Range-Upsale 1.c High Power Range. COLR Per COLR .66W + 54% - Table 3.2.C(4) 2, 4 Upscale 0.66AW Clamp @ 108% 1.d INOP NA 1.e Downscale COLR-Per COLR COLR Table 3.2.C(5) - 1.f Bypass Time Delay COLR Per COLR NA 2 Rod Worth NA Minimizer 3 Reactor Mode Switch NA Table 3.3.5.1 1: Esserpency Core Coellmg Systema Instrunnentation 1.a Core Spray System: a-160.0 in. -153.84 in, a-160 in. Table 3.2.B(2) 1 Reactor Vessel ^ Water I.mel-low law Inw (L1). 1.b Drywell Pressure. s2.0 psig 1.925 psig : s2.0 psig Table 3.2.B(7) 1-High

~ 4 4. 1.c. Reactor Pressure - 2425.0 psig -- 450.0 pig 400 500 psig. Table 3.2.B(8) 2o Iam s475.0 psig ' 1.d Core Spray Pump 2319.0 psid; 325 psid DEC NA l Discharge Flow Low s351.0 psid - 345 psid INC 1.e Core Spray Pump a5.0 seconds 6 seconds 6 +/- 1 second Table 3.2.B(11) 1 Start-Time Delay s7.0 scoonds Relay (th0P) l l 1.f (Pumps Core Spray Pump a12.1 seconds 13 seconds 13 seconds +/- 7% Table 3.2B(11) 1 ( A C) Start-Time Delay s13.9 seconds setting ' t Rc5 l 1.f (Pumps Core Spray Pump 221.4 seconds 23 seconds 23 seconds +/- 7% Table 3.2.B(11) 1 l B,D) Start-Vme Delay s24.6 seconds setting Relay 2.a LPCI System: 2-160 in. -153.84 in. 2160i:i. Table 3.2.B(2) 1 Reactor Vessel Water level-Law Inw inw (L1) 2.b Drywell Pressure s2.0 psig 1.925 psig. s2.0 psig Table 3.2.B(7). 1 High 1 2.c Reactor Pressure-2425.0 psig 450 psig 400 500 psig Table 3.2.B(8) 2-hw A 75.0 p 4 2.d Reactor Pressure-a211.0 psig 225 psig 200 250 pig Table 3.2.B(9) 2, 5 ' ~ Inw 2.e Reactor Vessel a-22&O in. -215.55 in. a+312 in. above Table 3.2.B(4) +312 in. above a vessel aero is Shroud Ixvel-(IA) vessel zero equivalent to -226.0 in. indicated level. l 2.f (Pumps LPCI Pump Start-- 21.9 seconds 2 seconds 2 seconds +/- 7% Tables 3.2.B(13) 1 A,B) Time Delay Relay s2.1 seconds setting s 2.f (Pumps LPCI Pump Start-17.5 seconds 8 seconds 8 seconds Table 3.2.B(13) 1 C,D) Tinne Delay Relay s8.5 seconds +/- 7% setting 2.g LPCI Pump m299.0 psid 305 psid DEC NA l Discharge Flow. low 's331.0 paid 325 psid INC 3.a HPCI Reactor Vessel a-48 in. -41.78 in ~a-48 in. Table 3.2.B(1) 1 Water Ixvel-Iow low (L2) L.-.._..-..-.-.....--.--.,--_: =... - -... .-.-...z..-.-.-.=...-.=

4e - + qy = 3.b Drywell Pressure-s2.0 pig 1.925 psig - s2.0 psig ' . Table 3.2.B(7) 1: + High 3.c Reactor Vessel s46 in. 42.00 in s+45 in. Table 3.2.B(3) 2, The TIS AV is less conservative Water Level-High than the CI3 Trip level Setting, (L8) but is consistent with the analysis requirements e in NEDC.32213. 3.d Condensate Storage 25.25 ft.above 67 in. 25 ft above tank Table 3.2.B(24) 2 Tank Level-Iow tank bottom bottom 3.e Suppression Pool s5.0 in. above 4.5in. s5 in. above torus - Table 3.2.B(25) 1 level-High torus midpoint midpoint 3.f HPCI Pump a3.5 in-we and 4.30 in-wc DEC. NA Discharge Flow-Iow s19.0 in-we 17.21 in-we INC 4.a ADS Reactor Vessel 4-160.0 in. -153.84 in. a-160 in. Table 3.2.B(2) 1 Water level-Iow Low low (LI) 4.b Drywell Pressure-s2.0 psig 1.925 psig s2!) psig Table 3.2.B(7) 1 High 4.c ADS Initiation 'Ilmer s115.0 seconds 105 seconds 90 s T s 120 Table 3.2.B(14). _2, 6. seconds 4.d Reactor Vessel a-160.0 in. . -153.84 in. a-160 in.. Table 3.2.B(2) 1 Water level-law Imw Low (L1) 4.e Reactor Vessel a6.0in. 6.9in. 26.0in. Table 3.2.B(6) 1 ~' Water Confirmatory level-Low (L4) 4.f Core Spray Pump a175.0 psig and 185 psig 185 +/- 10 psig Table 3.2.B(17) 1 Discharge Pressure-s195.0 psig High 4.g LPCI Pump a40.0 psig and-50 psig 50 +/- 10 psig Table 3.2.B(16)' 1-Discharge-High s60.0 psig 4.h ADS Inw Water - s9.5 minutes. 9 minutes 8sTs'10I 'Ibble 3.2.B(15) 2, 6 level Actuation - minutes Timer = - - - - - - ~. -..-....... -.. = - -....,... - -....-. _.. -.. . - -. a ^

7 .-s. .. i ' SD-ADS Reactor Vessel a-160.0 la -253.84 i:D.. 2-160 in. Table 3.2.B(2). 1-Water Imel-Imr. - '~ Imr Imr (L1) 5.b Drywell Pressure-s2.0 pig 1.925 pig s2.0 psig_ Table 3.2.B(7) - High 5.c ADS Initiation Timer s115.0 seconds 105 semads 90 s T s 120 - Table 3.2.B(14) 2, 6 l. semnds i 5.d. Reactor Vessel a-160.0 in. -153.84 in. 1-160.0 in. Table 3.2.B(2) 1 Water Imel-Imr l Imr Imr (L1) 5.e Reactor Vessel 26.0 in. 6.9 in. a6.0 in. Table 3.2.B(6) 1 Water Confirmatory i Imel-Imr (L4) 5.f Core Spey Pump =175.0 pig and 185 pig 185 +/- 10 pig Table 3.2.B(17) 1 Discharge Pressure-s195.0 pig High n 5.g LPCI Pump 240.0 pig and 50 psig 50 +/- 10 pig Table 3.2.B(16) 1 Discharge-High s60.0 pig 5.h ADS Imr Water s9.5 minutes 9 minutes 8 s T s 10 Table 3.2.B(15). 2, 6 Imet Actuation minutes Timer Table 3.3.5.21: Rencear Core Ih CooIIng Systems Insernmentation 1. Reactor Vessel a48.0 in. -41.78 in. 248.0 in. Table 3.2.B(1) 1 ~ Water Imel-Imr (L2) 2. Reactor Vessel - s46.0 in 42 in. - s+45 in. Table 3.2.B(1) ~ See item 3.C for Thble 33.2.1-1 - Water Imel-High - (IE) 3. Condensate Storage 25.25 ft above' 67.5 in a5 ft above tank Table 3.2.B(26) 2 Tank Imel.Imr tank bottom bottora Table 3.3.6.1-1: Primary Containment Isolation Instrumentation 1.a Main Steam IJae - a-160.0 in. -156.8 in. a160 in. Table 3.2.A(3) 1-Isolation Reactor ' Vessel Water Imel-Imr Imr Imr (L1) ... - - -. - ~. - - -. = -. -. - = -..--.--- --

m. _.,

r .c W* l 1.b Main Steam Une. 28500 pig 867.5 psig 2850 psig Table 3.2.A(6) - 1 Pressure-Iow ~ l: 1.c Main Steam Une s123.3 pid 121 psid s140% Rated Table 3.2.A(7) 2 Pkw-High Steam Flow l l 1.d Main Steam Une-15 x Full Power 3 x 10E4 mR/hr. 15 x Normal Full Table 3.2.A(5) 1 j High Radiation

Background

Power Background l 1.e Main Steam Tunnel s200.0*F 192.5'F s200*F Table 3.2.;8). 1. . Temperature-High 2.a Primary Containment 21.0 in. 1.5in. 20 in. Table 3.2.A(1) 3 Isolation Reactor Vessel Water Ixvel-IEw(13) 2.b Drywell Pressure-s2.0 psig 1.925 psig s2.0 psig Table 3.2.A(4) 1 High 2.c Main Stack Monitor s1 x 10E6 cps 5500 cps s10E6 Table 3.2.D(3) 1 Radiation-High Counts / Seconds i 2.d Reactor Building s16.0 mR/hr 10 mR/hr sl6 mR/hr Table 3.2.D(2) 1 Ventilation Exhaust Radiation-High 4 2.e Refuel Floor sl6.0 mR/hr 10 mR/hr s16 mR/hr Table 3.2.D(1) 1 Ventilation Exhaust Radiation-High 3.a HPCI Steam Une s225.0 in-wc 210 in-we . s225 in-we Table 3.2.A(31) - 1 Flow-High 3.b HPCI Steam Une s10.0 seconds 3 seconds 3 +/- 1 second Table 3.2.A(33) 2,6, The ITS AV is less Flow -Time Delay conservative than the CIS Trip Relays Level Setting, but is consistent with - the analysis requirements - documented in GENE report NEDE-24953. 3.c HPCI Steam Supply 260.0 psig 75 pag 100 > P > 50 psig Table 3.2.A(34) '2, 5 Une Pressure-Iow 3.d Drywell Pressure. s2.0 psig 1925 psig s2.0 psig. Table 3.2.A(4) ' 1. High

3.e HPCI Compartment s200.0*F 192.5 7 s200.0 T Table 3.2.A 1

[

and Steam Line Area (35, 36) Temperature High 4.a RCIC Steam Une. s450.0 in-we 428.5 in-we s450 in.we Table 3.2.A(27) 1 Flow-High ' 4.b RCIC Steam Line s10.0 seconds 3 seconds 3 +/- 1 second Table 3.2.A(28) See item 3.C of Table 3.3.6.1-1. Flow-Tinie Delay Relays' L 4.c RCIC Steam Supply 260.0 pig 75 pig 100 > P > 75 psig Table 3.2.A (31) 2, 5 Line Pressure-Inw 4.d Drywell Pressure s2.0 psig 1.925 psig s2.0 psig Table 3.2.A(4) 1. High 4.e RCIC Compartment s200.0 oF -192.5 7 s200.0 7 Table 3.2.A 1 and Steam Line Area (29,30) Temperaterc High 5.a RWCU Flow-High s125% rated flow 22.00 in-we <300% Rated Table 3.2.A(10) 2 (23.0 in-wc) (122% Rated Flow Flow) 5.b SLC System NA Initiation 1 5.c Reactor Vessel 21.0 in. 1.5in. 20 in. Table 3.2.A(1) 3 Water Level-Low (L3) 6.a Shutdown Cooling 570.0 pig 60.5 pig s75 psig Table 3.2.A(2) 2-System Isolation Reactor Pressure-High 6.b Reactor Vessel 21.0 in. 1.5in. a0 in. Table 3.2.A(1) 3-Water Level.Iow (13) 7.a Feedwater ; s600 psig 592 pig s600 psig Table 3.2.A(12). 1 Recirculation isolation Reactor Pressure-High Table 3.3.6.2-1: , Coatsimament Isointion Instrumeestation

- p 4n' 1. Reactor Vessel : =1.0in. 1.5in. 20 in. - _ Table 3.2.A(1) _ 3 Water Ievel-Imr (13) 4 2. Drywell Pressure-s2.0 psig 1.925 pig s2.0 pig Table 3.2.A(4) 1 J High 3. Reactor Building s16 mR/hr 10 mR/hr s16 mR/hr Table 3.2.D(2) 1 Ventilation Exhaust Radiation.High 4. Refuel Floor s16 mR/hr 10 mR/hr - s16 mR/hr Table 3.2.D(1) - 1 Ventilation Exhaust Radiation-High Table 3.3.R.1-1: Imse of Power Instrussentation i 1. 4kV Emergency Bus. NA Undervoltage (loss of Voltage 2.a 4kV Emergency Bus a2288 V 24% V - 60% +/- 5% Table 3.2.B(41), 1 Undervoltage s2704 V (Degraded Voltage low Setting). Undervoltage 2.b Time Delay al.6 seconds 1.8 seconds 1.8 +/- 10% Table 3.2.B(41) > 1 s2.0 seconds seconds .6 3.a 4kV Emergency Bus a3411 V 3619 V 87% +/- 5% ' Table 3.2.B(44) 1, Undervoltage s3827 V (Degraded Voltage High Setting) Undervoltage i 3.b Time Delay a27.0 seconds 30 seconds 30 seconds +/- - Table 3.2.B(44). 1 s33.0 seconds 10 % 4.a 4kV Emergency Bus a3691.V 3702 V - 3702 +/- 11 V - Table 3.2.B(43) - 1 Undervoltage s3713 V (%-= Voltage LOCA) Undervoltage 1 4.b 'Ilme Delay 28.4 seconds 9 seconds 9 seconds +/- 7%. Table 3.2.B(43) 1. s9.6 seconds -u.i. --.e.-es. raw.e<re-e.-- weu, e- % .., e+aem

s w = eemn-wa wa. - w... e-a as+. e m e.e'e--'

w i w weaw 6w + s- -r e av a. w-a e ewr ne in~#. 4 e e-- ca weee.. e es.J ~w-a+w,.4-.w-,-e+ e*.eew-.----m--e--- m. +..e- -.mm mm-m-

m

e. ) -

5.a - 4kV Emergency Bus 24065 V 4077 V 4077 +/- 12 V Table 3.2.B (42) 1-Undervoltage s4089 V (Degraded Voltage Non-LOCA) Undervoltage 5.b Time Delay 257.C seconds 60 seconds 60 seconds +/- 5% Thole 3.2.B(42) 1 s63.0 seconds dotes:

1. Cl3 Ixvel Setting = ITS AV

2. The ITS AV is established by applying instrument setpoint methodology and supports the existing plant trip setting. The existing plant trip setting was set more conservative than the CTS Trip level Setting. No change to the existing plant trip setting is required as a result of applying instrument setpoint methodology for FIS.

3. The ITS AV is established by cpplying instrument setpoint methodology. The existing plant trip setting will be revised as part ITS implementation, so that a whole number, rather that a fractional number, can be used for the ITS AV, for ease of operator training.

4. Allowable Values have been relocated to the COLR.

5. There are no design limit or safety analyses assumptions that require an upper Allowable Value to be specirmi in fl3.

6. There are no design limit or safety analyses assumptions that require a lower Allowable Value to be specified in ITS.}}

ML20080T722

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