ML031120327

Response to NRC Request for Additional Informational Related to TS Changes to Post-Accident Monitoring Instrumentation Requirements

ML031120327
Person / Time
Site:	Pilgrim
Issue date:	04/14/2003
From:	Bellamy R Entergy Nuclear Operations
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
2.03.044
Download: ML031120327 (31)

Text

"Entergy Entergy Nuclear Operations, Inc.

Pilgrim Nuclear Power Station 600 Rocky Hill Road Plymouth, MA 02360 Mike Bellamy Site Vice President April 14, 2003 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555

SUBJECT:

Entergy Nuclear Operations, Inc.

Pilgrim Nuclear Power Station Docket 50-293 License No. DPR-35 Response to NRC Request for Additional Information Related to Technical Specification Changes to Post-Accident Monitoring Instrumentation Requirements

REFERENCES:

1. Entergy letter to the NRC, 2.02.072, Request for Amendment to the Technical Specifications - Changes to Post-Accident Monitoring Instrumentation Requirements, dated August 19, 2002

2. Entergy letter to the NRC, 2.03.019, Request for Amendment to the Technical Specifications - Changes to Post-Accident Monitoring Instrumentation Requirements, dated February 14, 2003.

3. Entergy letter to the NRC, 2.03.034, Response to NRC Request for Additional Information Related to Technical Specification Changes to Post-Accident Monitoring Instrumentation Requirements, dated March 27, 2003.

LETTER NUMBER: 2.03.044

Dear Sir or Madam:

Discussions with the NRC on April 10, 2003 indicated that additional information was needed to complete their review of the proposed License Amendment submittal (Reference 1). Attached is the additional information requested.

This response does not change the no significant hazard conclusions previously submitted in Reference 1.

Should you have any questions or comments concerning this submittal, please contact Bryan Ford at (508) 830-8403.

- DDl 2.03.044

Entergy Nuclear Operations, Inc. Letter Number: 2.03.044 Pilgrim Nuclear Power Station Page 2 I declare under penalty of perjury that the foregoing is true and correct. Executed on the 14th day of April 2003.

Sincerely, Robert M. Bellamy BSF/dd Attachments: 1. Response to NRC Request for Additional Information (5 pages)

2. Proposed Technical Specification and Bases Changes (Mark-up) (22 pages) cc: Mr. Travis Tate, Project Manager Mr. Robert Walker Office of Nuclear Reactor Regulation Radiation Control Program Mail Stop: 0-8B-1 Commonwealth of Massachusetts U.S. Nuclear Regulatory Commission Exec Offices of Health & Human Services 1 White Flint North 174 Portland Street 11555 Rockville Pike Boston, MA 02114 Rockville, MD 20852 U.S. Nuclear Regulatory Commission Mr. Steve McGrail, Director Region 1 Mass. Emergency Management Agency 475 Allendale Road 400 Worcester Road King of Prussia, PA 19406 P.O. Box 1496 Framingham, MA 01702 Senior Resident Inspector Pilgrim Nuclear Power Station 2.03.044

ATTACHMENT 1 Response to NRC Request for Additional Information Changes to Post-Accident Monitoring Instrumentation Requirements 2.03.044

Letter Number 2.03.044 Page 1 of 5 Clarification 1 The title of this Specification is being changed to Post-Accident Monitoring Instrumentation in all locations including the Table of Contents and Table headings. As discussed in the original submittal this change in the title is an editorial change.

Clarification 2 The Table column headings on Table 3.2.F are being editorially changed:

Current Column Heading Proposed Column Heading Minimum # of Operable Instrument Channels Minimum # of Operable Instrument Channels (pages 3/4.2-25 and 3/4.2-27)

Minimum # of Channels Minimum # of Operable Instrument Channels (page 3/4.2-26)

Parameter Function (pages 3/4.2-25, 3/4.2-26 and 3/4.2-27)

The Table column headings on Table 4.2.F are being editorially changed:

Current Column Heading Proposed Column Heading Instrument Channel Function (pages 3/4.2-37 and 3/4.2-38)

Clarification 3 In the current Specification 3.7.A.7.c, the requirements discuss 2 required H2 analyzers. These 2 H2 analyzers are described as 2 required Containment H2 Analyzer instrument channels in the proposed Specification.

Clarification 4

1. The Parameter called Suppression Chamber Air Temperature on current Table 3.2.F is part of the function covered under the Instrument Channel called Suppression Chamber Temperature on current Table 4.2.F and is proposed to be removed from the Technical Specifications via Proposed Change 2.1 as the Suppression Chamber Air Temperature Function.

2. The Parameter called Suppression Chamber Water Temperature on current Table 3.2.F is part of the function covered under the Instrument Channel called Suppression Chamber Temperature on current Table 4.2.F and is proposed to be maintained in the Technical Specifications as the Suppression Chamber Water Temperature Function. TRU-5021-1 A and TRU-5022-1 B are currently required for this function and as identified in the submittal and associated Bases are being maintained as required for the proposed Function. The table comparing the current Technical Specification instrumentation requirements for each Function to the proposed instrumentation requirements has been revised to reflect these instruments in the current Technical Specification instrumentation requirements column.

Letter Number 2.03.044 Page 2 of 5

3. The instrumentation identified as an LPRM in the Type Indication and Range column for Neutron Monitoring on current Table 3.2.F is discussed as an APRM in the original submittal. The table comparing the current Technical Specification instrumentation requirements for each Function to the proposed instrumentation requirements has been revised to reflect the LPRM designator instead of APRM in the current Technical Specification instrumentation requirements column.

4. The Parameter called Drywell/Torus Diff. Pressure on current Table 3.2.F is the same function covered under the Instrument Channel called Drywell/Torus Differential Pressure on current Table 4.2. F and is proposed to be removed from the Technical Specifications via Proposed Change 2.1 as the Drywell/Torus Differential Pressure Function.

5. The name for the Parameter/instrument Channel called Drywell Pressure Torus Pressure on current Tables 3.2.F and 4.2.F is changed to the Suppression Chamber Bottom Pressure Function in the proposed Technical Specifications. Drywell Pressure monitoring requirements are covered via Functions 8 and 9 in the proposed Technical Specifications.

The table comparing the current Technical Specification instrumentation requirements for each Function to the proposed instrumentation requirements has been revised to reflect the current Drywell Pressure instrument in the current Technical Specification instrumentation requirements column for the Drywell Pressure (Wide Range) Function.

6. The Parameter called Safety/Relief Valve Position on current Table 3.2.F is the same function covered under the Instrument Channel called Safety/Relief Valve Position Indicator (Primary/Secondary) on current Table 4.2. F and is proposed to be removed from the Technical Specifications via Proposed Change 2.1 as the Safety/Relief Valve Position.

7. The Parameter called Safety Valve Position Indicator on current Table 3.2.F is the same function covered under the Instrument Channel called Safety Valve Position Indicator (Primary/Secondary) on current Table 4.2. F and is proposed to be removed from the Technical Specifications via Proposed Change 2.1 as the Safety Valve Position Indicator.

8. The name for the Parameter/instrument Channel called Torus Water Level (Wide Range) on current Tables 3.2.F and 4.2.F is changed to the Suppression Chamber Water Level Function in the proposed Technical Specifications. The instruments currently required by Table 3.2.F for this function are being maintained as required for the proposed Function as identified in the original submittal and associated Bases. The table comparing the current Technical Specification instrumentation requirements for each Function to the proposed instrumentation requirements has been revised to reflect these instruments in the current Technical Specification instrumentation requirements column. Suppression Chamber Water Level instruments were identified in the current Technical Specifications associated with the Suppression Chamber Water Level and Torus Water Level (Wide Range) parameters on Table 3.2.F. The Regulatory Guide 1.97 instruments required for this function are those previously associated with the Torus Water Level (Wide Range) parameter on Table 3.2.F.

9. The Parameter called Containment Pressure, (High Range) on current Table 3.2.F is part of the function covered under the Instrument Channel called Containment Pressure on current Table 4.2.F and maintained in the proposed Technical Specification as the Drywell Pressure (Wide Range) Function. This proposed Function along with the proposed Drywell Pressure (Narrow Range) Function addresses the instruments necessary to be in the Technical Specifications as Regulatory Guide 1.97, Type A or Category 1, non-Type A, instruments needed to monitor Drywell Pressure. Drywell pressure instruments were identified in the current Technical Specifications associated with the Drywell Pressure, Drywell Pressure Torus Pressure, Containment Pressure, (High Range), and Containment Pressure, (Low Range) Parameters on Table 3.2.F. The table comparing the current Technical Specification instrumentation requirements for each Function to the proposed

Letter Number 2.03.044 Page 3 of 5 instrumentation requirements has been revised to reflect these instruments in the current Technical Specification instrumentation requirements column. The Regulatory Guide 1.97 instruments required for this function are those previously associated with the Containment Pressure, (High Range) parameter on Table 3.2.F.

10. The Parameter called Containment Pressure, (Low Range) on current Table 3.2.F is part of the function covered under the Instrument Channel called Containment Pressure on current Table 4.2.F and maintained in the Technical Specification as the Drywell Pressure (Narrow Range) Function.

11. The Parameter called Containment High Radiation (Drywell) on current Table 3.2.F is the same function covered under the Instrument Channel called Containment High Radiation on current Table 4.2.F and maintained in the Technical Specifications as the Drywell High Radiation Function.

12. The Parameter called Reactor Building Vent on current Table 3.2.F is the same function covered under the Instrument Channel called Reactor Building Vent Radiation Monitor on current Table 4.2. F and is proposed to be removed from the Technical Specifications via Proposed Change 2.1 as the Reactor Building Vent Function.

13. The Parameter called Main Stack Vent on current Table 3.2.F is the same function covered under the Instrument Channel called Main Stack Vent Radiation Monitor on current Table 4.2. F and is proposed to be removed from the Technical Specifications via Proposed Change 2.1 as the Main Stack Vent Function.

14. The Parameter called Turbine Building Vent on current Table 3.2.F is the same function covered under the Instrument Channel called Turbine Building Vent Radiation Monitor on current Table 4.2. F and is proposed to be removed from the Technical Specifications via Proposed Change 2.1 as the Turbine Building Vent Function.

The following is a revision to the table included in the original submittal comparing the current Technical Specification instrumentation requirements for each Function to the proposed instrumentation requirements with the changes discussed above.

Function Current TS Regulatory Guide Instruments 1.97 Instruments

1. Reactor Water Level 640-29A LI-263-1 OOA 640-29B LI-263-1 00B LI-263-106A LI-263-106B LI-1 001 -650A LI-1 001 -650B LR-1 001 -604A LR-1 001 -604B

2. Reactor Pressure 640-25A PI-263-49A 640-25B PI-263-49B PR-1001 -600A PR-1 001 -600B

3. Drywell Temperature TRU-9044 TRU-9044 TI-9019 TI-9019

Letter Number 2.03.044 Page 4 of 5 Function Current TS Regulatory Guide Instruments 1.97 Instruments

4. Neutron Monitoring LPRM APRM IRM SRM SRM

5. Suppression Chamber Water TI-5021 -2A TI 5021-02A Temperature TI-5022-2B TI 5022-02B TRU-5021 -1A TRU-5021 -01 A TRU-5022-1 B TRU-5022-01 B

6. Suppression Chamber Bottom PiD-5067A Pl-1001 -69A Pressure PiD-5067B Pl-1001 -69B PR-1 001 -69

7. Suppression Chamber Water Level LI-1001 604A LI-1001 604A LI-1001 604B LI-1001 604B LR-1 001 -604A LR-1001 -604A LR-1 001 -604B LR-1001 -604B LR-5038 LR-5049

8. Drywell Pressure (Wide Range) Pl-1001 -600A Pl-1001 -600A PR-1001 -600A PR-1001 -600A Pl-1001 -600B Pl-1001 -600B PR-1001 -600B PR-1 001 -600B PID-5067A TRU-9044 TRU-9045

9. Drywell Pressure (Narrow Range) P1-1001-601 A Pl-1001-601 A PR-1 001 -600A PR-1001 -600A Pl-1001-601 B PI-1001-601B PR-1001 -600B PR-1 001 -600B

10. Drywell High Radiation RIT-1001 -606A RIT- 001 -606A RIT-1001 -606B RIT- 001 -606B RR-1 001 -606A RR-1 001 -606A RR-1001 606B RR-1001 606B

11. Containment H2 Analyzer AR-1 001 -612A AR-1 001 -612A AR-1 001 -612B AR-1001 -612B Al-1 -5184A Al-1 -5184B Clarification 5 By letter dated March 27, 2003, Entergy responded to an NRC question concerning the applicable calibration frequency for the proposed Suppression Chamber Water Level Function.

In this response Entergy mistakenly changed the proposed frequency to 6 months from 24

Letter Number 2.03.044 Page 5 of 5 months. The instruments currently required by Table 3.2.F for the Torus Water Level (Wide Range) parameter are the instruments being maintained for the proposed Suppression Chamber Water Level Function. Current Table 4.2.F identifies a channel calibration frequency of each refueling outage for these instruments which is an effective 24 month frequency. The markups are modified to reflect this 24 month frequency.

Clarification 6 Revised Technical Specification mark-up pages are attached to ensure clarity of the requested changes.

ATTACHMENT 2 PROPOSED TECHNICAL SPECIFICATION AND BASES CHANGES (MARK-UP)

(22 Pages)

TABLE OF CONTENTS 1.0 DEFINITIONS 1-1 2.0 SAFETY LIMITS 2-1 2.1 Safety Limits 2-1 2.2 Safety Limit Violation 2-1 BASES 22-1 LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.1 REACTOR PROTECTION SYSTEM 4.1 3/4.1-1 BASES B3/4.1 -1 3.2 PROTECTIVE INSTRUMENTATION 4.2 3/4.2-1 A. Primary Containment Isolation Functions A 3/4.2-1 B. Core and Containment Cooling Systems B 3/4.2-1 C. Control Rod Block Actuation C 3/4.2-2 D. Radiation Monitoring Systems D 3/4.2-2 E. Drywell Leak Detection f E 3/4.2-3 F. -Surveillanc Informai Rdus ;cs rJccideA F 3/4.2-3 G. Recirculation Pump Trip/Alternate Rod XTrilMnevntcL*OA G Insertion 3/4.2-4 H. Drywell Temperature -- H 3/4.2-5 BASES 23/4.2-1 3.3 REACTIVITY CONTROL 4.3 3/4.3-1 A. Reactivity Margin - Core Loading A 3/4.3-1

\ B. Control Rod Operability B 3/4.3-2 C. Scram Insertion Times C 3/4.3-7 D. Control Rod Accumulator D 3/4.3-8 E. Reactivity Anomalies E 3/4.3-10 F. Rod Worth Minimizer (RWM) F G. Scram Discharge Volume 3/4.3-11 G 3/4.3-12 H. Rod Pattern Control H 3/4.3-13 BASES 33/4.3-1 3.4 STANDBY LIQUID CONTROL SYSTEM 4.4 3/4.4-1 BASES 23/4.4-1 3.5 CORE AND CONTAINMENT COOLING 4.5 - 3/4.5-1 SYSTEMS A. Core Spray and LPCI Systems A 3/4.5-1 B. Containment Cooling System B 3/4.5-3 C. HPCI System C

• 3/4.5-7 D. Reactor Core Isolation Cooling (RCIC) System D 3/4.5-8 E. Automatic Depressurization System (ADS) E 3/4.s-9 F. Minimum Low Pressure Cooling and Diesel F Generator Availability 3/4.5-10 G. (Deleted) G 3/4.5-11 H. Maintenance of Filled Discharge Pipe H 3/4.5-12 BASES B3/4.5-1

'II PNPS i Amendment No.4

LIMITING CONDITION FOR OPERATION SURVEILLANCE REOUIREMENT 3.2 PROTECTIVE INSTRUMENTATION (Cont) 4.2 PROTECTIVE INSTRUMENTATION (Cont E. Drvwell Leak Detection E. 2DrvweLl Leak Detection The limiting conditions of Instrumentation shall be operation for the instrumentation that monitors drywell leak functionally tested, calibrated and checked as indicated in detection are given in Section Section 4.6.C.

3.6.C.

F. Fr oSurveillmce Information Readouts F

The limiting conditions for t it______ Insrmett io sall be alibrated and checked as instrumentation that provides asurveillance e 4.2.F.

Tinforma e

- are given in Table 3.2.F.

Amendment No. &9,-7_-

3/4.2-3

INSERT 3/4.2-3A F. Post-Accident Monitorinq Instrumentation F. Post-Accident Monitoring Instrumentation During the RUN MODE and the STARTUP Instrumentation shall be calibrated and MODE the limiting conditions for the checked as indicated in Table 4.2.F.

instrumentation that provides post-accident monitoring are given in Table 3.2.F.

PNPS TABLE 3.2.F SURV\EILLANCE INSTRUMENTATION Mininib I of Operable Insbrent Instrument # Parameter Clhannels Type Indication and Range Notes 2 6401 A& B RIeactor Water Level Indicator 0-60" (1) (2) (3) 2 640-25A & B eactor Pressure Indicator 0-1200 psig (1) (2) (3) 2 TRU-9044 DrywelrPressure TRU-9045 Recorder 0-80 psia (1) (2) (3) 2 TRU-9044 Drywell Temperature Recorder, Indicator 0-400°F (1) (2)

I I-U01 9 I, I I ,1 (31 2 TRU-9045 Suppression Chamber Air TI-9018 Temperature (1) (2) (3) 2 LR-5038 Suppression Chamber Water LR-5049 Recorder -7 to es (1) (2) (3)

Level 1 NA INleutron I

Monitoring SRM, IRM, LPRM (1) (2) 0 to 100% power (F~~Isr C- ;2'f,s Amendment No. ,4a-8a3-1 3/4.2-25 1

INSERT 3/4.2-25A PNPS TABLE 3.2.F Post-Accident Monitoring Instrumentation Minimum # of Operable Function .

Instrument Channels Notes

1. Reactor Water Level 2 (1) (2)

2. Reactor Pressure 2 (1) (2)

3. Drywell Temperature 2 (1) (2)

4. Neutron Monitoring 2 (1) (2)

5. Suppression Chamber Water Temperature 2 (1) (2)

6. Suppression Chamber Bottom Pressure 2 (1) (2) 7 Suppression Chamber Water Level 2 (1) (2)

8. Drywell Pressure (Wide Range) 2 (1) (2)

9. Drywell Pressure (Narrow Range) 2 (1) (2)

10. Drywell High Radiation 2 (1) (3)

11. Containment H2 Analyzer 2 (1) (4)

l.,-'PMps 9-) TABLUi 3.2.F (Cont)

I _ .I Type Indication Notes and Range I . .I TI-5021 -2A Suppression Chamber Indicator/

TRU-5021-1A Water Temperature Multipoint Recorder 2 (1) (2) (3) (4) 30-230°F (BUlIIk)

Q22-2B Suppression Chamber Indicator/

TRU-6W2-1B Water Temperature Multipoint Recorder (1) (2) (3) (4) 30-230°F (Bulk)

I I 1 PID-5021 Drywell/Torus Diff. Indicator -.25 - +3.0 psig Pressure (1) (2) (3) (4y ,

II 1 PID-5067A D ~el~ressure PID-5067B __ TorusP J Indicator -.25 - +3.0 psig Indicator - 1.0 - +2.0 psig (1) (2) (3 ) (4);'

I 1Nalve (a)Primary Safety/Relief V*vaq,, (a) Acoustic monitor (5) or Position (b) Thermocouple (b) Backup I . I I I I. I . _ .

1/Valve (a)Primary Safety Valve Position (a;A oustic monitor (5) or Indicator (b) ThepPcouple (b) Backup

_ - I I 1/Valve See Note (6) Tail Pipe Temperature +

Thermocouple (6)

Indication

- _ I_ _ .

LI-1001-604A Torus Water Level Indicator/Multipoint 2 LR-1001-604A (1)>2-) (4)

(Wide Range) Recorder 0-300"1 H2 0 LI-1001-604B LR-1001-604B Torus Water Level Indicator/Multipoint (1) (2) (3) (4)

(Wide Range) Recorder 0-300" H2 0

_ .. .. . I -

-Amedmntio n N19656 8, Amendment No. 5 6 r83i,-i-7-2

INSERT 3/4.2-26A Notes for Table 3.2.F (1) With less than the minimum number of instrument channels, restore the inoperable channel(s) within 30 days. If the inoperable channel(s) are not restored, prepare and submit a special report to the Commission within 14 days of the event outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the channels to operable status.

(2) With the instrument channel(s) providing no indication to the control room, restore the indication to the control room within 7 days. If the indication is not restored, an orderly shutdown shall be initiated and the reactor shall be in the Hot Shutdown Condition within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

(3) With the instrument channel(s) providing no indication to the control room,.restore the indication to the control room within 7 days. If the indication is not restored, prepare and submit a special report to the Commission within 14 days of the event outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the channels to operable status.

(4) With the instrument channel providing no indication to the control room, restore the indication to the control room within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. If the indication is not restored, an orderly shutdown shall be initiated and the reactor shall be in the Hot Shutdown Condition within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

f L \-

X

~~~~PNPS (

TABLE 3.2.F (Cont)

SURVEILLANCE INSTRUMENTATION Minimutm # of Operabi O Instrument LIannels \

C nt Type Indication PInst Parameter and Range Notes (PR 1001-600A Containrent Pressure (PR 1001-600A 2 Indicator/Multipoint (4) (1) (2) (3)

High Range) Recorder 0-225 psig 2(

(PI 1001-600B Containment Pressure, (PR 1001-600B Indicator/Mtultipoint (4) (1) (2) (3)

(lligh Rh ge) Recorder 0-225 psig (PI 1001-601A C nment Pr'sure, (PR 1001-600A Indicator/Multipoint (4) (1) (2) (3) 2 (Low Range)

Recorder -5 to 5 psig (PI 1001-601B pi Containment Pressure, Indicator/Multipoint (PR 1001-600B (Low Range) (4) (1) (2) (3)

Ns Recorder -5 to 5 psig (RIT 1001-606A Containment lligh Radiation 2 (RRT 1001-606A MN ktor/Mlultipoint (Drywell) Recorder (RR 1001-606A (4) (7) 1 to lx107 R/hr (RR 1001-606B I RI 1001-609 Reactor Building Vent RR 1001-608 Indicator/Multip'o (4) (7)

Recorder 10-1 to 104 R/hr 1 RI 1001-608 Main Stack Vent Tndicator/Mtultipoint PR 1001-608 (4) (7)

Recorder 10-1 to 104 R/hr 1 RI 1001-610 Turbine Building Vent RR 1001-608 Indicator/Multipoint (4) (7)

Recorderr 10-1 t-n 104 DlA-IL (Revision 177t - -- II/

Amendment No. 47

INSERT 3/4.2-27A This page is intentionally left blank

N-I F -T- -B-3.-

,NOTES FOR TABLE 332.2.F_

X With less than the miniMunumber of instrument channels, restore the inoperable channel(s) within 30 days.

.5 (2) ith the instrument channel(s) providing no indication to the control room, re tore the indication to the control room within seven days.

(3) If the requirements of notes (1) or (2) cannot be met, an orderly shutdown shall e initiated and the reactor shall be in the Cold Shutdown Condition within hours.

(4) These surv illance instruments are considered to be redundant to each other.

(5) At a minimum, the primary or back-up* parameter indicators shall be operable for each valve hen the valves are required to be operable. With both primar and backup* inst ument channels inoperable either return one (1) channel to operable status wr, in 31 days or be in a shutdown mode within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

The following instruments are associated with the safety/relief and safety valves:

Secondary Tail Pipe Temperature Thermocouple 203-3A ZT-203-3A TE6271

• 203-3B ZT-203-3B TE6272

• 203-3C ZT-203- 3C \ TE6273

• 203-3D ZT-203-3D TE6276

• 203-4A ZT-203 -4A TE6274-B 203-4B ZT-203-4B TE6275-B I

• See Note (6)

(6) At a minimum, for thermocouples providing SRV tail pipe temperature, one of the dual thermocouples will be operable for each SRV when the valves are required to be operable. If a thermocouple becomes inoperable, it shall be returned to an operable condition within 31 days or the reactor shall be placed in a shutdown mode within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

(7) With less than the minimum number of operable instrument channels, restore the inoperable channels to operable status within 7 days or prepare aid submit a special report to the Commission within 14 days of the event outlining the action taken, the cause of the inoperability and the plans and schelule for restoring the channels to operable status.

Amendment No. Go 3/4.2-28

INSERT 3/4.2-28A This page is intentionally left blank

- VT

(~u SZv1sTe 3/qy. no 3/2Y PNPS TABLE 4.2.F MINIMUM TEST AND CALIBRATION FREQUENCY FOR SURVEILLANCE INSTRUMENTATION Ins ment Channel Calibration Frequency Instrument Check

1) Reactor Water eve Each Refueling Outage Each Shift

2) Reactor Pressure Each Refueling Outage Each Shift

3) Drywell Pressure Each Refueling Outage Each Shift

4) Drywell Temperature Once/6 Months Each Shift

5) Suppression Chamber Temperature Once/6 Months Each Shift

6) Suppression Chamber Water Level Onc/6, is Each Shift

7) NA N

8) Neutron Monitoring (2) Each Shift

9) Drywell/Torus Differential Pressure Once/6 Months Each Shift

10) Drywell Pressure Once/6 Months Torus Pressure Each Shift Once/6 Months

11) Safety/Relief Valve Position Indicator Each refueling outage (Primary/Secondary) Once.oeach day

12) Safety Valve Position Indicator Each refueling outage (Primary/ Secondary) l Once each day Kmendon21( N 4 3/4.2-37

INSERT 3/4.2-37A PNPS TABLE 4.2.F MINIMUM TEST AND CALIBRATION FREQUENCY FOR Post-Accident Monitoring Instrumentation Calibration Instrument Function Frequency Check

1. Reactor Water Level Once/24 Months Once/31 Days

2. Reactor Pressure Once/24 Months Once/31 Days

3. Drywell Temperature Once/6 Months Once/31 Days

4. Neutron Monitoring Once/24 Months OnceI31 Days 5 Suppression Chamber Water Temperature Once/6 Months Once/31 Days

6. Suppression Chamber Bottom Pressure Once/6 Months Once/31 Days

7. Suppression Chamber Water Level Once/24 Months Once/31 Days

8. Drywell Pressure (Wide Range) Once/24 Months Once/31 Days

9. Drywell Pressure (Narrow Range) Once/24 Months Once/31 Days

10. Drywell High Radiation Once/24 Months Once/31 Days

11. Containment H2 Analyzer Once/6 Months Once/31 Days

PNIOS TABLE 4.2.F (Cont)

MINIMUM Calibration Frequency Instrument Check

13) Each refueling outage Once every 30 days

14) Containment Pressure Each refueling outage Once every 30 days

15) Containment High Radiation Once every 30 days

16) Reactor Building Vent Radiation Monitor Once every 30 days ,.

17) Main Stack Vent Radiation Monitor Once/Operating Cycle Once every 30 days

18) Turbine Building Vent Radiation Monitor Once/Operating Cycle ,Qgce every 30 days itRevision 216fi Amendment No. A2-g3-,489, 3/4.2-38

INSERT 3/4.2-38A This page is intentionally left blank

NOTES FOR TABLES 4.2.A THROUGH 4.2.G

1. Initially bnce per month until exposure hours (M as defined on Figure 4.1.1) is 2.0 x 105; thereafter, according to Figure 4.1.1 with an interval not less than one month nor more than three months.

2. Functional tests, calibrations and instrument checks are not required when these instruments are not required to be operable or are tripped. Functional tests shall be performed before each startup with a required frequency not to exceed once per weekpalbtin of IsAs aFndS vEs narlb-e -pe-ffommedduring each s-t-a-Rlu l dungcontrolled o shutdowns with a required frequency not to exceed once per weesument checks shal e peforme at least once per day uring ose periods when the instruments are required to be operable.

3. Deleted.

4. Simulated automatic actuation shall be performed once each operating cycle.

Where possible, all logic system functional tests will be performed using the test jacks.

5. Reactor low water level and high drywell pressure are not included on Table 4.2.A since they are tested on Tables 4.1.1 and 4.1.2.

6. The logic system functional tests shall include a calibration of time delay relays and timers necessary for proper functioning of the trip systems.

7. Calibration of analog trip units will be performed concurrent with functional testing.

The functional test will consist of injecting a simulated electrical signal into the measurement channel. Calibration of associated analog transmitters will be performed each refueling outage.

Amendment No. 12, 99, 110, 117, 151,  ! 96 3/4.2-41

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.7 CONTAINMENT SYSTEMS (Cont) 4.7 CONTAINMENT SYSTEMS (Cont)

A. Primary Containment (Cont) A. Primarv Containment (Cont)

7. Containment Atmosphere Dilution 7. Containment Atmosphere Dilution

a. Within the 24-hour period a. The post-LOCA containment after placing the reactor in atmosphere dilution system the Run Mode the Post-LOCA shall be functionally tested Containment Atmosphere once per operating cycle.

Dilution System must be operable and capable of b. The level in the liquid N2 supplying nitrogen to the storage tank shall be containment for atmosphere recorded weekly.

dilution. If this kd-specification cannot be met, c. analyzers sha e the system must be restored teste operabeility once to an operable condition per month an 11 be within 30 days or the calibrated once per reactor must be at least in months.___-~~

Hot Shutdown within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. d. Once per month each manual or power operated valve in

b. Within the 24-hour period the CAD system flow path not after placing the reactor in locked, sealed or otherwise the Run Mode, the Nitrogen secured in position shall be Storage Tank shall contain a observed and recorded to be minimum of 1500 gallons of in its correct position.

liquid N2 . If this specification cannot be met the minimum volume will be restored within 30 days or the reactor must be in at least Hot Shutdown within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

There are 2 H2 analyzers vailable to serve the d

\ ell.

With o 1 H2 analyzer operable, eactor operation is allowed r up to 7 days.

If the inopera e analyzer is not made full operable within 7 days, the eactor shall be in a least Shutdown within the nex 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

Amendment No. d-3 3/4. 7-10

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 4.7 CONTAINMENT SYSTEMS (Cont.)

B. Standbv Gas Treatment Svstem and Control Room High Efficiency Air Filtration Svstem

1. Standby Gas Treatment System 1. Standby Gas Treatment System

a. Except as specified in 3 .7.B.1.c or a. 1. At least once per operating cycle, 3.7.B.1.e below, both trains of the it shall be demonstrated that standby gas treatment shall be pressure drop across the operable when in the Run, Startup, combined high efficiency filters and and Hot Shutdown MODES, during charcoal adsorber banks is less movement of irradiated fuel than 8 inches of water at 4000 cfm.

assemblies in the secondary containment, and during movement 2. At least once per operating cycle, of new fuel over the spent fuel pool, demonstrate that the inlet heaters and during CORE ALTERATIONS, on each train are operable and are I and during operations with a capable of an output of at least 20 potential for draining the reactor kW.

vessel (OPDRVs), 3. The tests and analysis of Specification 3.7.B.1.b. shall be or performed at least once per operating cycle or following painting, fire or chemical release in the reactor shall be in cold any ventilation zone shutdown within the next 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. communicating with the system

b. 1. The results of the in-place cold while the system is operating that DOP tests on HEPA filters shall could contaminate the HEPA filters show >99% DOP removal. The or charcoal adsorbers.

results of halogenated 4. At least once per operating cycle, hydrocarbon tests on charcoal automatic initiation of adsorber banks shall show

>99.9% halogenated hydrocarbon removal.

Ari~iaiiit~o 1, 12, 50, 51, 5211211,151- , 1E7;, _-z 161a170!,

-, 3/4.7-11

BASES:

3.2 PROTECTIVE INSTRUMENTATION (Cant)

X Trip settings of < 100 mr/hr for the monitors in the refueling area ventilation exhaust ducts are based upon initiating normal ventilation isolation and standby gas treatment system operation so that none of the activity released during the refueling accident leaves the Reactor Building via the normal ventilation path but rather all the activity is processed by the standby gas treatment system.

For most parameters monitored, as listed in Table 3.2.F, there are two (2) channels of instrumentation. By comparing readings between these two (2) channels, a near continuous surveillance of instrument performance is available. Meaningful deviation in comparative readings of these instruments will initiate an early recalibration, thereby maintaining the quality of the instrument readings.

The Safety - a ition indication instrumentation provides Eli* \ ithe operator with information on sele ssess these variables during and following an accident.

r and In response to NUREG-0737, modifications were made to the ADS logic to extend automatic ADS operation to a class of transients that involve slowly uncovering the core without depressurizing the vessel or pressurizing the drywell. These transients were analyzed assuming no high pressure injection systems (feedwater, HPCI or RCIC)-are available.

Only ADS is considered available to depressurize the vessel, permitting operation of LPCI. The transients generally involve pipe breaks outside containment.

Automatic ADS would not occur on low water level because high drywell pressure would not be present and ADS logic has a high drywell pressure permissive. The modification added a timer to the ADS logic which bypasses the high drywell pressure permissive, and a manual inhibit switch which allows the operator to inhibit automatic ADS initiation for events where automatic initiation is not desirable.

An analysis was performed to determine an upper time limit on the bypass timer. The goal was to ensure ADS is automatically initiated in time to prevent peak clad temperature (PCT) from exceeding 1500'F for a limiting break, which was determined to be a Reactor Water Cleanup line break. The analysis concluded that there are 18 minutes between the low water level initiation of the timer and the heatup of the cladding to the limit. Since the logic includes a 2 minute delay already, the bypass timer upper limit can not be more than 16 minutes, which provides a conservative margin for PCT and allows sufficient time for operator intervention if required. A minimum. time delay is incorporated to allow RPV water level to recover, resetting the timer and preventing depressurization. The choice of a timer setting of 11 minutes places the setting in the middle and provides maximum tolerance from either limit. (

Reference:

GE Report "Bypass Timer Calculation for the ADS/ECCS Modification for Pilgrim Station" December 16, 1986).

Revision +/-1' B3/4.2-5

INSERT B3/4.2-5A The following are the instruments which meet the quality requirements of Regulatory Guide 1.97 and can be credited to meet the operability requirements of Specification 3/4.2.F. Two channels of indication in the control room from the below list must be available to meet the Specification requirements.

Specification 3/4.2.F Function Regulatory Guide 1.97 Instruments

1. Reactor Water Level Li 263-1OA, LI 263-106A, LR 1001-604A Li 263-100B, Li 263-106B, LR 1001-604B Li 1001-650A, Li 1001-650B

2. Reactor Pressure PI 263-49A, PR-1001-600A PI 263-49B, PR-1001-600B

3. Drywell Temperature TRU-9044, TI-9019

4. Neutron Monitoring APRM, SRM

5. Suppression Chamber Water Temperature TI 5021-02A, TRU-5021-01A TI 5022-02B, TRU-5022-01 B

6. Suppression Chamber Bottom Pressure Pl 1001-69A, PI 1001-69B PR 1001-69

7. Suppression Chamber Water Level Li 1001 -604A, LR 1001 -604A Li 1001-604B, LR 1001-604B

8. Drywell Pressure (Wide Range) Pl-1001 -600A, PR-1 001 -600A Pl-1001 -600B, PR-1 001 -600B

9. Drywell Pressure (Narrow Range) Pl-1001-601A, PR-1001-600A Pl-1001 -601 B, PR-1 001 -600B

10. Drywell High Radiation RIT-1001-606A, RR 1001-606A RIT-1001-606B, RR 1001-606B

11. Containment H2 Analyzer Al-1-5184A, AR 1001-612A Al-1-5184B, AR 1001-612B

BASES:

3/4.7 CONTAINMENT SYSTEMS (Cont)

A. Primary Containment (Cont) wetwell pressure differential to keep the suppression chamber downcomer legs clear of water significantly reduced suppression chamber post LOCA hydrodynamic loads. A pressure of 1.17 psid is required to sufficiently clear the water legs of the downcomers without bubbling nitrogen into the suppression chamber at the 3.00 ft.

downcomer submergence which corresponds approximately 84,000 ft.3 of water. to Maximum downcomer submergence is 3.25 at operating suppression chamber water ft.

level. The above pressure differential and submergence number are used in the Pilgrim I Plant Unique Analysis.

Post LOCA Atmosnhere Dilution In order to ensure that the containment atmosphere remains inerted, i.e. the oxygen-hydrogen mixture below the flammable limit, the capability to inject nitrogen into the containment after a LOCA is provided. A minimum of gallons of liquid N2 in the storage 1500 tank assures that a three-day supply for post-LOCA containment inerting is of N2 available. Since the inerting makeup system is continually functioning, no periodic testing of the system is required.

The Post-LOCA Containment Atmospheric Dilution (CAD) System is designed to meet the requirements of AEC Regulatory Guides 1.3, 1.7 and 1.29, ASME Section III, Class 2 (except for code stamping) and seismic Class I as defined in the PNPS FSAR.

In summary, the limiting criteria are:

1. Maintain hydrogen concentration in the containment during post-LOCA conditions to less than 4%.

2. Limit the buildup in the containment pressure due to nitrogen addition to less than 28 psig.

3. To limit the offsite dose due to containment venting (for pressure control) to less than 300 Rem to the thyroid.

By maintaining at least a 3-day supply of N2 on site there will be sufficient time after the occurrence of a LOCA for obtaining additional nitrogen supply

> from local commercial sources.(1) The system design contains sufficient redundancy to ensure its reliability.

Thus, it is sufficient to test the o si system once pe't operating cycle, h will provide redundancy for it e drywell i.e., ere a

• ana yzers for the Unit. By permitting reactor o r days with one of the two H /

analyzers inope - , unoancy of analyzing capability will 2 not imposing an immediate interruption be maintained gJ in plant operation. Monthly 4 (1) As listed in Pilgrim Nuclear Power Station Procedure No. 5.4.6 "Post Accident Venting".

Revision 1-endmentNo. 5 B3/4.7-8

BASES:

3/4.7 CONTAINMENT SYSTEMS (Cont

• ,alrzers using H2 will be adequate to ensure the system's readiness because of the design. balzers are normally not in operation there will blitedterioration due to use. In ofde ao-dtes;un-poncentration, the ,

analzersmust be warmed up 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> prior to putting intogs ~

is acceptable for accident conditions because a 4% H level will not be reached in the drywell until 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> following the accident. Due to nitrogen addition, the e ai increase with time. Under the worst expected conditions the containment pressure will reach 28 psig in approximately 45 days. If and when that pressure is reached, venting from the containment shall be manually initiated per the requirements of 10CFR50.44. The venting path will be through the Standby Gas Treatment system in order to minimize the off site dose.

B.1 Standby Gas Treatment System The Standby Gas-Treatment System is designed to filter and exhaust the reactor

- building atmosphere to the stack during secondary containment isolation conditions. Upon containment isolation, both standby gas treatment fans are designed to start to bring the reactor building pressure negative so that all leakage should be in leakage. After a preset time delay, the standby fan automatically shuts down so the reactor building pressure is maintained approximately 1/4 inch of water negative. Should one system fail to start, the redundant system is designed to start automatically. Each of the two trains has 100% capacity.

High Efficiency Particulate Air (HEPA) filters are installed before and after the charcoal adsorbers to minimize potential release of particulates to the environment and to prevent clogging of the iodine adsorbers. The charcoal adsorbers are installed to reduce the potential release of radioiodine to the environment. The in-place test results should indicate a system leak tightness of less than 1 percent bypass leakage for the charcoal adsorbers and a HEPA filter efficiency of at least 99 percent removal of cold DOP particulates. The laboratory carbon sample test results should indicate a methyl iodide removal efficiency of at least 95 percent for expected accident conditions. The specified efficiencies for the charcoal and particulate filters is sufficient to preclude exceeding 10CFR100 guidelines for the accidents analyzed. The analysis of the loss of coolant accident assumed a charcoal adsorber efficiency of 95% and TID 14844 fission product source terms, hence, installing two banks of adsorbers and filters in each train provides adequate margin. A 20 kW heater maintains relative humidity below 70% in order to ensure lJ the efficient removal of methyl iodide on the impregnated charcoal adsorbers.

Considering the relative simplicity of the heating circuit, the test frequency of once/operating cycle is adequate to demonstrate operability.

Air flow through the filters and charcoal adsorbers for 15 minutes each month assures operability of the system. Since the system heaters areI automatically controlled, the air flowing through the filters and adsorbers will be <70% relative humidity and will have the desired drying effect.

nF'. 1-, 6 R evision Kmendrnent No. 12, 11, 11 8194}Th-~.. p3/4.7-9