ML20199J758
| ML20199J758 | |
| Person / Time | |
|---|---|
| Site: | Byron  |
| Issue date: | 12/31/1997 |
| From: | COMMONWEALTH EDISON CO. |
| To: | |
| Shared Package | |
| ML20199J753 | List: |
| References | |
| PROC-971231, NUDOCS 9802060032 | |
| Download: ML20199J758 (173) | |
Text
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Byron 2nd Interval IST Plan Revision 1 December, 1997 INSERVICE TESTING PLAN PUMPS AND VALVES BYRON NUCLEAR GENERATING STATION UNITS #1 AND #2 COMMONWEALTH EDISON COMPANY BYRON NUCLEAR POWER STATION 4450 NORTH GERMAN CHURCH ROAD
-BYRON, ILLINOIS 61010
.i
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9002060032 980129 DR ADOCK 05 4y4 '
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Byron 2nd Interval IST Plan Revision 1 December, 1997 REVISION SUFt4ARY SHEET (Byron Station 2nd Interval)
Revision Date of Page(s) Revised Reason for Revision Revision 0 Dec.'95 All Initial 2nd Ten Year Interval-Submittal 1 Dec. '97 Table of Add information on how ECCS Contents Pg. v Instrument Uncertainty is addressed.
Section 2.1.1 Pg.1 of 1 1 Dec. '97 Section 1.1 Pg. Update program to reflect NRC SER 1 of 1 dated 11/18/96.
Section 2.3.2 Pg. 1 of 1 1 Dec. '97 Section 2.4,1 Adds new NRC correspondence Pg. 1 of 1 references.
1 Dec. '97 Section 3.1.1 Clarification of test frequency Pg. 7 of 8 requirements for SY, 10Y and SD/TS 1 Dec. '97 Section 3.1.1 Adds Sample Disassembly / Technical Pg. 7 of 8 Specifications in accordance with Section 3.1.2 Relief Request VR-2.
Pg. 5 of 42 1 Dec, '97 Section 3.1.2 Clarify Backflow Test Frequency due Pg. 4.5,6, 17, to denial of Relief Request VR-1, 22, 23 of 42 1 Dec. '97 Section 3.1.2 Clarify Position Test Frcquency due Pg. 23 of 42 to denial of Relief Request VR-1 1 Dec. '97 Section 3.1.2 Correct typographical omission for Fg 7 of 42 open stroke direction for 1/2CV8152 and 1/2CV8160.
1 Dec. '97 Section 3.1.2 Add closure test of 1/2CV8546 and Pg. 8,36 of 44 1/2 SIB 926 per PIF#454-201-96-1443 and Operability Assessment 96-032.
Add Reference to Refuel Outage Justification ROJ-16 for closure test.
1 Dec. '97 Section 3.1.2 1FWO43A-D deleted as valves were Pg. 14 of 42 removed in new Unit 1 Steam Generator Modifications.
1 Dec. '97 Section 3.1.2 Remove Partial Stroke Tests of Pg. 13,18, of 1/2FWOO9A-D and 1/2MS001A-D in 42 accordance with Cold Shutdown Justification VC-1.
1 Dec. '97 Section 3.1.2 Change Main Steam Safeties P.
3 18,19 of 42 1/2MS013A-D, 1/2MS014A-D, 1/2MS015A-D, 1/2MS016A-D, 1/2MS017A-D to 5 Yr.
Freq. and add reference to Note 15 to clarify.
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Byron 2nd Interval IST Plan Revision 1 December, 1997 Revision Date of Page(s) Revised Reason for Revision Revision 1 Dec. '97 Section 3.1.2 Correct typographical error of 'BF" Pg. 21,38 of 42 to-'BTF" for valves 00G059-65 and 1/2SX005.
1 Dec. '97 Section 3.1.2 Remove valve 1PR002G as it is non-Pg. 21 of 42: operable due to line being capped Section 3.1.3 (see DCP 9600179).
Pg. 1 of 5 1 Dec. '97 Section 3.1.2 Add Refuel Outage Justification ROJ-Pg, 15 necessary due to denial of Relief 4,5,6,17,22,23, Request VR-1, 29,37,42 of 42 1 Dec. '97 Section 3.1.2 Correct typographical error of 'GT" Pg. 33 of 44 to 'GA" for valves 1/2SIBBOBA-D 1 Dec. '97 Section 3.1.2 Delete valves OSX127A/B due to Pg. 39 of 42 removal from system due to plant Exempt Change DCP 9700294, ER No.
j, 97-004105 1 Dec. '97 '6n 3.1.2 Adds valves 0WWO49A,B electively l i ,, L. of 42 incorporated in program per Note 16.
Section 3.1.3 Pg. 4.5 of 5 1 Dec. '97 Section 3.1.3 Changes updated reference on Note 11 Pg . 3 of 5 from ASME Code Section XI, IWV 3420 to OMa-1988, Part 10, paragraph 4.2.2 1 Dec. '97 Section 3.1.3 Adds Note 15 to clarify that Main Pg. 4 of 5 Steam Safety valves 1/2MS013A-D, 1/2MS014A-D, 1/2MS015A-D. 1/2MS016A-D, 1/2MS017A-D are tested at a5 year frequency.
1 Dec. '97 Section 3.3.1 Adds 1/2FWOO9A-D to VC-1.
Pg. 1 of 2 1 Dec. '97 Section 3.3.1 Deletes VC-3 as 1/2FWOO9A-D combined Pg. 1 of 2 in VC-1.
1 Dec. '97 Section 3.3.1 1/2RH3702A/B typographical omission Pg. 1 of 2 added to summary.
1 Dec. '97 Section 3.3.2 Eliminates partial strokes due to Pg. 1,2 of 28 adverse risk of inadvertent closure.
1/2FWOO9A-D consolidated to this Cold Shutdown Justification.
Specifies full stroke testing at a y Cold Shutdown Frequency for all these valves.
1 Dec. '97 Section 3.3.2 Eliminates this Cold Shutdown Pg. 4 of 28 Justification for 1/2FWOO9A-D valves by combining them in VC-1.
1 Dec. '97 Section 3.3.2 Changes limiting time from 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Pg. ~7 of 28 to 7 duys as the Technical Specification allows 7 days.
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Byron 2nd Interval IST Plan Revision 1 December, 1997 Revision Date of Page(s) Revised Reason for .'.evision Revision 1 D3c. '97 Section 3.4.1 Removes OSX127A/B from Summary as Pg. 1 of 2 they have been removed from the system. (Reference Exempt Change DCP 9700294, ER No. 97-004105) 1 Dec. '97 Section 3.4.1 Adds Refuel Outage Justification Pg. 2 of 2 references to Summary for ROJ-15 and ROJ-16.
1 Dec. '97 Section 3.4.2 Renioves OSX127A/B from Justification Pg. 1,2 of 33 as they have been removed from the system. (Reference Exempt Change DCP 9700294, ER No. 97-004105) 1 Dec. ' 97- Section 3.4.2 Clarifies methodology and Pg. 27 of 33 justification rationale.
1 Dec. '97 Section 3.4.2 Refuel Outage Justification (ROJ-15)
Pg. 30,31,32 established for those valves as of 33 required when Relief Request VR-1
, was denied.
1 Dec. '97 Section 3.4.2 Refuel Outage Justification (ROJ-16)
Pg. 33 of 33 established for valves 1/2CV8546 and 1/2SI8926 added to the program per PIF#454-201-96-1443 and Operability Assessment 96-032 1 Dec. '97 Section 3.5.1 Adds ' Denied" as status option.
Pg. 1 of 1 Updates status of Relief Requests #
1,2,3,6 per NRC SER dated 11/18/96.
Withdraws VR-7 due to removal of OSX127A/B from the system.
(Reference Exempt Change DCP 9700294, ER No. 97-004105) 1 Dec. '97 Section 3.5.2 Indicate Relief Request Denied Pg. 1-4 of 28 1 Dec. '97 Section 3.5.2 Changes made per conditional Pg.-9-10 of 28 approval by NRC SER dated 11/18/96.
1 Dec. '97 Section 3.5.2 Indicates approval per NRC SER dated Pg. 12 of 28 11/18/96.
1 Dec. '97 Section 3.5,2 Indicater approval per NRC SER dated Pg. 15 of 28 11/18/96.
1 Dec., '97 Section 3.5.2 Indicates approval per NRC SER dated Pg. 18 of 29 11/18/96.
1 Dec. '97 Section 3.5.2 Indicates approval per NAC SER dated Pg. 23 of 29 11/18/96.
1 Dec. '97 Section 3.5.2 Indicates approval per NRC SER dated Pg. 26 of 29 11/18/96.
1 Dec. '97 Section 3.5.2 Deletes typographical mark -
Pg. 27 of 29 inappropriate underline.
1 Dec. '97 Section 3.5.2 Indicates approval per NRC SER dated Pg. 28 of 29 11/18/96.
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Byron 2nd Interval IST Plea Revision 1 December, 1997 Revision Date of Page(s) Revised Reason for Revision Revision 1 Dec. '97 Section 3.6.1 Adds new NRC correspondence Pg. 1 of 1 references.
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i Byron 2nd Interval IST Plan Revision 1 December, 1997 TABLE OF CONTENTS 1.0 IST INFORMATION cot 440N TO PUMPS AND VALVES 1.1 Introduction and Program Description . . . . . . . . . . . . . . . 1 2.0 IST PUMP PLAN 2.1 Pump Components and Testing Information 2.1.1 Pump Table Descriptions . . . . . . . . . . . . . . . . . 1 2.1.2 ECCS Instrument Uncertainty . . . . . . . . . . . . . . . .1 1 Pump 2 ables 1-4 . . , . . . . . . . . . . . . . . . . 2.2 Pump Technical Positions 2.2.1 Summary . . . . . . . . . , . . . . . . . . . . , . . . . 1 2.2.2 Complete Listings . . . , . . . . . . . . . . . . . . 1-5 2.3 Pump Relief Requests 2.3.1 Summary . . . . . . . . . . . . . . . . . . . . . . . . 1 2.3.2 Complete Listings . . . . . . , . . . . . . . . . . . 1-4 2.4 Pump References 2.4.1 Pump reference List . . , , . . . . . . . . . . . . . . , 1 3.0 IST VALVE PLAN 3.1 Valve components and Testing Information 3.1.1 Valve Table gescriptions . . . . . . . . . , . . . 1-8 3.1.2 Valve Tables . . . . . . . . . . . . . . . . . . . . 1 - 42 3.1.3 Valve Notes . . . . . . . . . . . . . . . . . . . . . 1-5 3.2 Valve Technical Positions 3.2.1 Summary . . . . . . . . . . . . . . . . . . , , . . . 1 3.2,2 Complete Listings . . . . . . . . . . . . , , . . . 1 -6 3.3 Valve Cold Shutdown Justifications 3.3.1 Summary . . . . . . . . . . . . . . . . . . . . . . . 1-2 3.3.2 Complete Listings . . . . . . . . . . . , . . . . . .1-28 3.4 Valve Refueling outage Justifications 3.4.1 Summary . . . . . . . . . . . . . . . . . . . . . 1 -2 3.4.2 Complete Listings . . . . . . . . . . . . . . . . . . 1 - 33 3.5 Valve Relief Requests 3.5.1 Summary . . . . . . . . . . . . . . . . . . . . . . . . 1 3.5.2 Complete Listings . . . . . . . . . . . . . . . . 1 - 28 3.6 Valve References 3,6.1 Valve Reference List . . . . . . . . . . . . . . 1 p:\sec\ist\istrevia.wpf v
Byron and Interval IST Plan Revision 1 December,-1997 TABLE OF CONTENTS 1.0 ' IST INFORMATION CCte40N TO PUMPS AND VALVES 1.1 Introduction and Program Desc'-iption . .. . . . . . . . . . . . . . 1 2.0 IST PUMP PLAN 2.1 Pump components and Testing Information 2.1.1 Pump Table Descriptions . . . . . . . . . . . . . . . . . 1 i_
2.1.2 ECCS Instrument Uncertainty . . . .. . , .. . . . . . . .1 l 2.1.3 Pump Tables ..................... 1-4 2.2 ' Pump Technical Positions 2.2.1 Sununary . ...... . . . . . . . . . . . . . . . . .. 1.
.2.2.2- complete Listings . . . . . . . . . . . . . . . . . . 1-5 J 2.3 Pump Relief Requests 2.3.1 sununary . .......... . . . . . . . . . .. . . . 1 2.3.2 complete Listings . . . . . . . . . . . . . . . . .. 1-4 2.4 Pump References 2.4.1 Pump Reference List . . . . . . . . . . . . . . . . . . . 1
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- 3. 0 - IST VALVE PLAN 3.1 Valve components and Testing Information 3.1.1 Valve Table Descriptions . . . . . . .. , . . . . . 1-8 3.1.2 Valve Tables . . . . . . . . . . . . . . . . . . ' . . 1 - 42 3.1.3 Valve Notes . . . . . . . . . . . . . , . . . . . .-
5-3.2 Valve Technical Positions
-3.2.1 Sununary . ......................... 1 3.2,2 complete Listings . . . .. . . . . . . . . . . . . . 1-6 3.3 Valve cold shutdown Justifications 3.3.1 - sununary . ...................... 1-2 3.3.2 complete Listings . . . . . . . . . . . . . . . . . . 1 - 2B 3,4 Valve Refueling Outage Justifications
- 3.4.1 summary . ...................... 1-2
, 3.4.2 complete-Listinga . . . . , . . . . . . . . . . . . . 1 - 33 3.E ' Valve Relief Requests 3.5.1 sunenary . ....................... 1 3.5.2 complete Listings . . . . . . . . . . . . . . . . . . 1-28 3.6 Valve References 3.6.1 Valve Reference List . . . . . . . . . . . . . . . . . 1 p \sec\ist\istrevla.wpf v l
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Byron 2nd Interval IST Plcn Revision 1 December, 1997 SECT 10N 1.0 IST INFORMATION COMMON TO PUMPS AND VALVES pi\sec\ist\istrevla.wpf
Byron 2nd Interval IST Plcn Revision 1 l December, 1997 I
I 1.1 IHIf0 DUCTION AND PROGRAM DESCRIPTION The Byron. Inservice Testing Plan for pumps and valves was developed in accordance with the inservice testing requirements from the 1989 edition of the'ASME Boiler and Pressure Vessel Code,Section XI, Subsections IWP and IWV. The 1989 edition of ASME Section XI subsequently references ASME/ ANSI OM (Part 6) for pump testing, and ASME/ ANSI OM (Part 10) for valve testing. The version of ASME/ ANSI OM Part 6 and Part 10 followed shall be the OMa-1988 addendum to the OM-1987 edition. Where these requirements are determined to be impractical, specific relief is requested.
This Inservice Testing Plan will be effective for U-1 and U-2 from July 1, 1996 through and including June 30, 2006.
The Commercial Service Date for Byron Unit 1 is September 16, 1985 and for byron Unit 2 is August 21, 1987 The key features of this Plan are: the Pump and Valve table listings, .,
. Relief Requests, Refueling Outage: Justifications, Cold Shutdown Justifications, and Technical Positions. Administrative procedures, surveillance testing procedures, and other records required to define and execute the Inservice Testing Plan are all retained and available at Byron Station.
e pr\sec\ist\istrevla.wpf Section 1.1 Pg. 1 of 1 J
Byron 2nd Interval IST Plan Revision 1 December, 1997 SECTION 2.0 IST PUMP PLAN pr\sec\ist\istrevla.wpf
' Byron 2nd Interval IST Plan -
Revision 1 December, 1997 2.1 PUMP c0MPONENTS AND TESTING INFORMATION 2 .1.1 -. PUMP TABLE DESCRIPTIONS The following_information'1s included-in the pump program tables:-
PUMP NUMBER: The unique Byron Station Equipment Piece-Nutrber -
PUMP NAME: The common name for the pump class: The ASME Code Class iG P&ID: The Piping and Instrument Drawing number. If the pump _
appears on mul,lple P'& ID's, the primary P & ID will be listed..
-SPEED: "Yes" signifies that speed-will be measured; "no"-
signifies a constant speed pump and speed will not be measured.
PREssUREJ "AP" indicates that differential pressure will be -
measured; "P" indicates that discharge pressure will be measured- (positive displacement pumps) . _ Relief requests or Technical Positions are indicated where-applicable, rLow RATE: The flow rate of'the pump, measured using permanently installed instruments or other means, provided the equipment accuracy meets-the requirements _of OMa-1988, Part 6, Paragraph 4.6.1.1, Table 1. "Q" indicates that the flow rate will be measured.
VIBRATION: Pump vibration measurements shall be made using; portable-or hand held instruments at locations as marked ~on:the pumps. A "V"' indicates that vibration measurements will be taken. If required, a more-detailed explanation of~the vibration data collection methodology is described in the relief request or technical position indicated.
TEST INTERVAL: Indicates the frequency of performing the Inservice Tests.
2.1.2 ECes INSTRUMENT UNCERTAINTY ^
Measurement acertainty for' installed ECCS flow and pressure instrumentation is accounted for in the applicable 10CFR50.46 LOCA Safety Analysis in accordance with NUREG-1482 and ASME Section XI, OMa-198d Psrt 6 guidance, p \sec\ist\istrevla.wpf Section 2.1.1 Pg. 1 of 1
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Cyron 2nd Interval IST Plcn Revision O December, 1995 TEST PARAMETERS PUMP NUMBER PUMP NAME CLASS P&ID SPEED PRESSURE FLOW VIBRATION 'a EST RATE INTERVAL 1AF01PA Auxiliary 3 M-37 No AP Q V Quarterly Feedwater Pump (Motor Driven) 1AF01PB Auxiliary 3 M-37 Yes AP Q v Quarterly Fee.C#ater Pump (Diesel Driven) 2AF01PA Auxiliary 3 M-122 No AP Q V Quarterly Feedwater Pump (Motor Driven) 2AF01PB Auxiliary 3 M-122 Yer AP Q V Quarterly Feedwater Pump (Diesel Driven)
OCC01P Component 3 M-66-3A No AP Q V Quarterly Cooling Pump ICC01PA component 3 M-66-3A No AP Q V Quarterly Coo 1ing Pump ICC01PB Component 3 M-66-3A No AP Q V Quarterly Cooling Pump 2CC01PA Component 3 M-66-3A No ap Q V Quarterly Cooling Pump 2CC01PB Componert 3 Fi-66-3A No AP Q V Quarterly Coo 1ing Pump 1CS01PA Containment 2 M-46-1A No AP. Q V Qucrterly Spray Pump 1CS01PB containment 2 M-46-IA No AP Q V Quarterly Spray Pump p:\sec\ist\istrevla.wpf Section 2.1.2 Pg. 1 of 4
Cyron 2nd Interval IST Pir.n Revision 0 December, 3995 TEST PARAMETERS PUMP NUMBER PUMP NAME CLASS P&ID SPEED PRESSURE FLOW VIBRATION TEST RATE INTERVAL 2CS01PA containment 2 M-129-1A No AP Q V Quarterly Spray Pump 2CS01PB contairmnent 2 M-129-1A No AP Q V Quarterly Spray Pump ICV 01PA centrifugal 2 M-64-3A No AP Q V Quarterly Charging Pump 1CV01PB centrifugal 2 M-64-3A No AP Q V Quarterly charging Pump 2CV01PA centrifugal 2 M-138-3A No AP Q V Quarterly charging Pump 2CV01PB centrifugal 2 M-138-3A No AP Q V Quarterly Charging Pump 1DOO1PA Diesel oil 3 M-50-1B No P,PR-1 Q V Quarterly Transfer Pump 1DOO1PB Diesel oil 3 M-50-1A No P,PR-1 Q V Quarterly Transfer Pump 1DOO1PC Diesel oil 3 M-50-1B No P,PR-1 Q V Quarterly Transfer Pump 1DOO1PD Diesel oil 3 M-50-1A No P,PR-1 Q V Quarterly Transfer Pump 2DOO1PA Diesel oil 3 M-130-1A No P,PR-1 Q V Quarterly T-ansfer Pump p:\sec\ist\istrevla.wpf Section 2.1.2 Pg. 2 of 4 i
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Dyren 2nd Interval'IST Plc.n Revision O December, 1995 TEST PARAMETERS PUMP NUMBFR PUMP NAME CLASS P&ID SPEED PRESSURE FLOW VIBRATION TEST RATE INTERVAL 2DOO1PB Diesel oil 3- M-130-1E No P,PR-1 Q V Quarterly Transfer Pump 2DOO1PC Diesel oil 3 f1-130-1A No P,PR-1 Q V Quarterly Transfer Pump 2DOO1PD Die =*1 oil 3 M-130-1B No P,PR-1 Q V Quarterly Transfer Pump 1RH01PA Residual Heat 2 M-62 No aP Q V Quarterly Removal Pump 1RH01PB Residual Heat 2 M-62 No AP Q V Quarterly Removal Pump 2RH01PA Residual Heat 2 M-137 No AP Q V Quarterly Removal Pump g 2RH01PB Residual Heat 2 M-137 No aP Q V Quarterly Removal Pump ISIO1PA safety 2 M-61-1A No AP Q V Quarterly Injection Pump ISIO1PB Safety- 2 M-61-1A No AP Q V Quarterly Injection Pump 2SIO1PA safety 2 M-136-1 No AP Q V Quarterly Injeetion Pump 2SIO1PB safety 2 M-136-1 No AP Q V Quarterly Injection Pump r
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Lyron 2nd Interval IST Plan Revision O December, 1995' TEST PARAMETERS PLMP NUMBER PUMP NAME CLASS P&ID OPEED PRESSURE FLOW VIBRATION TEST RATE Ih M /AL OSX02PA E**en. eervice ? M-42-6 Yes aP Q V, PA-1 Quarterly Water Makeup Pump (Diesel Driveni OSXO2PB E**en. service 3 M-42-6 Yes AP Q V, PA-1 Quarterly Water Makeup.
Purpp (Dieeel Driven)
ISX01PA E**ential 3 M-42-1B No aP Q V Quarterly ser ice water M*P 1SX01PB Essential 3 M-42-1A No aP Q V Quarterly Servlee Water
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2SX01PA E**ential 3 M-42-1B No AP Q V Quarterly Service Water 3
2SX01PB Essential 3 M-42-1A No aP Q V Quarterly Service w ater h*P ISXO4P 18 AFw SK 3 14 - 4 2 - 3 Yes AP Q V Quarterly Booster Pump j 2SX04P 2B ATW SX 3 M-126-1 Yes AP Q V Quarterly Booster Pump OWOO1PA control moom 3 M-118-1 No AP Q V Quarterly Chilled water Pump OWOO1PB control Room 3 M-118-1 No AP Q V Quarterly chiller water Pe w p:\sec\ist\istrevla.wpf Section 2.1.2 Pg. 4 of 4
Byron 2nd Interval'IST Plc.n Revision 1 December, 1997 SECTION 2.2 4
PUMP TECHNICAL POSITIONS a
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Byron 2nd Interval IST Plan Revision 1 December, 1997 2.2.1 PUMP TECHNICAL POSITION StDenRY link _ tr Eppponent(e} Deserlotion PA-01: OSX02PA/B Byron's position on collecting vibration data. The non ASME vibration associated with gears meshing in the gearbox of these pumps have been factored out of the IST vibration monitoring data.
PA-02: 0/1/2AB03P Oives basis for the exclusion of the Boric Acid Transfer Pumps from the IST Program.
However, they will continue to be tested outside of the IST program.
pi\sec\ist\istrevla.wpf Section 2.2.1 Pg. 1 of 1 a.
Byron 2nd Interval IST Plcn Revision 1 December, 1997 PUMP TECHNICAL POSITION PA 01 71TL31 Method of Collecting Data for the Essential Service Water Makeup pumps PUMPb AFFECTRQ1 OSX02PA, OSX02PB pumps COD E R KOUI R EMENT ( S ) /DI S CJ2131Q1{1 ANSI /ASME OMa-1988 Part 6: Table 3a Ranges for Test Parameters, Paragraph 4.6.4 (a) Vibration Measurementn, Paragraph 4.6.1.6 Frequency Response Range.
POSITION:
The Essential Service Water Makeup Pumps OS702PA & B are of a very unique design (see Fig. I and Fig. 2) . The pump is attached to a horizontal diesel driver via a right angle gear drive, and the gear drive is located approximately 39 feet above the pump. This configuration assures pump operab41 sty during the design basis flooding of the Rock River.
The Essential Service Water Makeup Pumps OSX02PA & B are classified as centrifugal pumps. ANSI /ASME OMa-1988 Part 6 Paragraph 4.6.4 (a) requires that for centrifugal pumps, vibration measurements are to be taken in two directions on each accessible pump bearing housing and in the axial direction on each accessible pump thrust bearing housing. The OM Code does not require vibration monitoring of the gear drive. For the Essential Service Water Makeup Pumps, however, the pump thrust bearings are physically located within the gearbox which houses the gear drive. This pump configuration is not addressed by OM Part 6. With this unique configuration, the only means of collecting vibration readings for the pump thrust bearing is to physically take the vibration measurements on the gearbox itself. The limitations of taking the vibration readings at this location is that the resultant vibration readings are not solely attributable to the pump thrust bearing. The vibration readings obtained are the result of other factors such as the vibration induced by the gear drive itself.
When recording vibration results based on a f requency response range to 2000 Hz., which has been the customary practice at Byron for these pumps, the gear dri te significantly contribnes to the vibration which is measured at the gearbox location The vibcation induced by the gear drive is largely due to the gears meshing. Taking into account the pump running speed and the number of gear teeth, Byron has calculated the gear mesh frequency and hence a
_ vibration _ frequency attributable to the gear drive. This frequency was calculated to be pt\uec\ist\istrevla.wpf Section 2.2.2 Pg. 1 of 5
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Dyron 2nd Interval IST Pir.n Revision 1 December, 1997
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PUMP TECHNICA1, POSITION PA 01 (continued) 1080 Hz. By performing spectral analysis of the vibration data obtained at the gearbox locations, engineering personnel were able to identify the vibration which was attributable to the gear drive, as there was an easily identifiable peak within this 1080 Hz frequency range. This particular peak, associated with the gear mesh frequency, exceeded the acceptance criteria of Table 3a of OM Part 6. The OM part 6 Table 3a acceptance criteria applies to pump bearings and pump thrust bearings, and not to gear drives which induce vibrat!on due to the gears meshing. Additionally, Paragraph 4.6.1.6 of OM Part 6 states that the frequency response range of the vibration measuring transducers and their readout system shall be to at least 1000 Hz. The 1080 Hz gear mesh frequency goes beyond what is required for the trequency response range of the vibration measuring transducers and their readout system. As a result, for the gearbox locations on these pumps, Byron will apply the OM Part 6 Table 3a acceptance limits in the frequency range of one third minimum pump shaft rotational speed up to and incluaing 1000 Hz, and will not apply the OM Part 6 acceptance limits to the gear drive frequencies above 1000 Hz. By applying a eutoff at 1000 Hz, the resulting peak reading is more applicable to the vibration from the pump thrust bearing. The 1000 Hz cutoff meets the requirements of OM Part 6 for frequency response tange of the vibration measuring transducers and their readout system.
Additionally, vibration measurements will continue to be taken at the lowest accessible bushing on the pump shaft. These vibration readings will be subject to the OM Part 6 Table 3a acceptance criteria.
Both the A and B pumps have experienced vibration at the gearbox location in the vicinity of 0,4 - 0.45 in/see since installation, at which time they were verified by the vendor to be operating properly. They have continued to display such vibration levels throughout their service life. In August of 1992, the gearbox for pump OSX02PA was replaced. The replacement was performed due to repair work which was performed on the pump and was not attributable to a gearbox problem. It was felt that this was an opportunity to discover if a rebuilt gearbox would reduce the vibration levels.
Replacement with a rebuilt gearbox did not significantly reduce vibration levels at the gearbox location. Additionally, an inspection of the original gearbox revealed that it was in an acceptable condition. Also, in 1995, the OSX02PA gearbox was opened and visually inspected. It should be noted that the OSX02PA pump has experienced slightly higher vibration levels at the gearbox location than the OSX02PB pump. The gearbox of the OSXO2PA pump was found to be in' excellent condition. Comed's conclusions are that the vibration levels recorded at the gearbox locations do not have a detrimental affect on the gearbox or the pump, and that this vibration level is normal for such a pump configuration- Although the OM Code vibration limits will not be applied to the_ vibration levels attributed _to the_ gear mesh frequencies, ts a will continue to monitor these vibration levels, and take action as appropriate, p \sec\ist\istrevla.wpf Section 2.2.2 Pg. 2 of 5 !
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S*.C' TYP l 2%) on the set reference values of discharge pressure.
pr\sec\ist\istrevla.wpf Section 2.3.1 Pg. 1 of 1
Dyron 2nd Interval IST Plan Revision 1 Decenter, 1997 RELIEF REQUEST PR-1 TITLE: Diesel Oil Transfer Pump Discharge Pressure Tolerance Increase I CODE DRAWING DRAWING PtHP NtHBER CLASS NUMBER COORDINATE 1/20001PA 3 M 50-1B(M 130-1A) E4 (CS) 1/2D001PB 3 M 50 1A(M 130 1B) E4 (CS) 1/2D001PC 3 M-50-1B (M 130-1 A) E4 (CS) 1/2D001PD 3 M 50 1A(M 130 1B) E4 (C5) rUNcT!oN ( B) :
The 1/20001PA-PD pumps transfer diesel fuel oil from storage tanks to the diesel generator day tanks.
code REQUIREMENT (s) 1
- 1. Per OMa 1988, Part 6, pacagraph 5.2, an inservice test shall be conducted with the pump operating at specified test reference conditions.
- 2. Per NUREG 1482, section 5.3, a total tolerance of +/-2 percent of the reference value is allowed without approval from the NRC.
RASIs tor RELIETt Tne Diesel 011 Transfer pumps are positive displacement pumps which transfer diesel oil to the diesel generator day tanks. The discharge pressure (constant for positive displacement pumps) is considered the set value for the pumps and have indicated consistent values in the past. The lowest discharge pressure reference value for a specific Diesel Oil Transfer Pump is currently 23 psig and the highest reference value is 25.5 psig. Numbers this low allow only a small tolerance for the discharge pressure when applying the +/ 2%
tolerance (as noted in NUREG 1482, section 5.3). For instance, in considering a reference value of 23 psig, the +/-2% criteria allows only a +/- 0.46 psig tolerance. The pressure indicators are 0 60 psig analog gauges with increments of 0.5 psig, allowing readability to the nearest 0.25 psig (readings are acceptable to a degree of precision no greater than one half the smallest increment). To be within the +/-2% criteria, only a readability range of +/- 0.25 psig would be possible (next higher reading of +/-0.5 psig would represent a tolerance > 2%). For the reference values of 25 psig or above, only a readability range of +/- 0.5 psig would be possible to remain within the +/ 2% tolerance. History indicates that there would be a few
" acceptable" data points that would fall outside of these tignt ranges. Bfron proposes a more practical acceptable range of +/- 1 psig, p \sec\ist\istrevla.wpf Section 2.3.2 Pg. 1 of 2 j
Byron 2nd Interval IST Plan Revision 1 De cembe r., 1997 ALLIEP REQUEST PR-1 (continued)
Discharge pressure for there positive displacement pumps are considered to be constant. There are no throttling techniques or other methods available to adjust the discharge pressure. It would be impractical to set up strict ranges of +/-2% due to the small magnitude of the numbers invoi.ved. In addition, the readability of the gauges are limited. History has shown acceptable pump operation for values within the +/- 1 psig tolerance. The level of safety concerning the operation of these pumps will not be compromised by allowing a tolerance of +/-1 psig versus a strict +/ 2%
tolerance. Any deviacions greater than 1 psig from the reference value would result in an investigation of the pump performance.
To encompass all the pumps on a consistent basis, a +/-1 poig tolerance on the discharge pressure reference value is requested, which would represent a tolerance of +/-3.9% to +/-4.3% of the existing reference values.
PR3PosFD ALTERNATIVE TESTING!
Byron will use a dischargr. pressure tolerance of +/- 1 psig from the reference value when testing the Diesel Oil Transfer Pumps. The Flow will be compared to Table 3b of OM 6 to ensure the measured value is within the necessary acceptable limits.
APPROVAL STATUSt
- 1. Submitted with Revision 0 of Byton's 2nd Interval Program (December, 1995).
- 2. Approved per NRC SER, dated Novenber 18, 1996 [4n respot.se to Revision 0 o f Byron's 2nd Interval Program) .
pi\sec\ist\istrevla.wpf Sectien 2.3.2 Pg. 2 of 2 J
Byron 2nd Interyc1 IST Plan Revision 1 De cettbe r , 1997 SECTION 2.4 PUMP REFERENCES pt\sec\ist\fstrevia.wpf
Byron 2nd Interval IST Plan Revision 1 December, 1997
)'
EEEE_RttgRE;fCE LIST i 4
- 1. Title 10, Code of Federal Regulations, Part 50, Domestic Licensing of Production and Utilisation Facilities, particularly Section 50.$5a, ,
Codes and Standards, i
- 2. ASME Boiler and Pressu';u vessel Code,Section XI, Rulea for Inservice :
Inspection of Nuclear Power Plant Components, 1989 Edition. !
, 3. ASME/ ANSI OM-1987, Operation and Maintenance of Nuclear Power Plants, including 1988 Addenda, Part 6, Inservice Testing of Pumps in Light Water Reactor Power Plants.
- 4. U.S. Nuclear Regulatory Commission, Generic Letter 89-04, Guidance on i
Developing Acceptable Inservice Testing Progratas,
- 5. US Nuclear Regulatory Commission, Generic Letter 89-04, Supplement 1, NUREG 1482 Guidance on Developing Acceptable Inservice Testing Programs.
- 6. Byron /Braidwood Station UFSAR, Section 3.9.6.1, Inservice Testing of 1
Pumps.
7.. Byron Station Technical Specification, 3/4.0.5, Generic ASME Program Requirement.
B. Byron Procedure, DVP 200-1, IST Requirements for Pumps.
- 9. Roger A. Capra (Office of Nuclear Reactor Regulacion) letter to Mr. D.
L. Farrar (Comed) , dated February 7, 1996- allowing Byron Station to ;
implement concurrent intervals throughout the life of U.it 1 and Unit 2.
- 10. Roger A. Capra (office of Nuclear Reactor Regulation), letter to Ms.
Irene M. Johnson (Comed) dated November 10, 1996, transmitting Byron ,
Station's NRC SER for Revision 0 of Byron's 2nd Interval IST Pump and Valve Program.
1 1
i J
4 p:\sec\ist\istrevia.wpf Section 2.4.1 Pg. 1 of 1
Dyron 2nd Interval IST Plc.n R3 vision 1 December, 1997 SECTION 3.0 IST VALVE PLAN o
pt\see\ist\istrevla.wpf
Byron 2nd Interval IST Plen Revision 1 December, 1997 I
3.1 VALVE COMPONENTS AND TESTING INFORMATION 3.1.1 Valve Table Descriptinna A. Egy1AIQH The revision corresponds to the current revision of the program.
B. RAqg The pages are numbered sequentially and show the total number of pages.
C. VALVE NUMBER The valve number referonces the unique Byron Station equipment piece number (EPN) . This specific valve number identifies the unit and system.
D. E11p The P&ID column references the specific P&ID number which the valves are located on. The Unit 2 P&ID number is given directly underneath the Unit 1 P&ID number, where applicable.
E. Chhag The " class" refers to the safety-related ASME clasr 1, 2, or 3 assigned to the specific valve. A "NONE". generally indicates that the valve is nor.-safety and the test requirements are augmented tosts.
F. VALVE QAIgqQJ,y The valve category identifies the valve category defined in OMa-1988, Part 10, paragraph 1.4 as follows:
Category A - valves for which seat leakage is limited to a specific maximum amount in the closed position for fulfillment of their required function (s) .
=. =._ __
p \sec\ist\istrevia.wpf Section 3.1.1 Pg. 1 of B
Byron 2nd Intervol IST Pica Revision 1 December, 1997 3.1.1 Valve Table Descriptions (continued)
F. VALVE CATEGORY (continutdl Category D - vals a for which seat leakage in the closed position is inconsequential for fulfillment of the required function (s).
Category C - valves which are self-actuating in response to some system characteristic, such as pressure (relief valves) or flow direction (check valves) for fulfillment of the required function (n).
Category D valves which are actuated by an energy source capable of only one operation, such as rupture disks or explosively actuated valves.
G. VALVE SIZE The valve size lists the nominal pipe size of each valve in inchen.
H. ybLVE TYPE The valve type categorizes the valve as to its valve design.
The following abbreviationr will be used to identify specific valve types:
Gate GA Globe GL Butterfly BTF Check CK Safety Valve SV Relief Valve RV Power Operated Relief Valve PORV Diaphragm seated D Plug P Angle AN pi\sec\ist\istrevla.wpf section 3.1.1 Pg. 2 of 8
, _ . , . , . . . _ _ _ .J
Dyron 2nd Interval IST Plan Revision 1 December, 1997 3.1.3 Valve Table Descriptions (continued)
- 1. ACT. TIEE The actuator type identifies the valve actuator. The following abbreviations will be used to designate specific types of valve actuators:
Motor Operated M.O.
Air Operated A.O.
Hydraulic Operated H.O.
Self Actuated S.A.
Manual M Solenoid Operated S.O.
J. FORMAL POSITION Normal position identifies the normal operating position of a specific valve. Q for open and g for closed.
K. STROKE _ DIRECTION The stroke direction identifies the direction the valve actuator moves a specific valve stem to place the valve disc in a position to perform its designed safety funetton(s) . Q for open, and g for closed. This identifies the direction (s) the valve stem will move when tested.
Note: Exercising of a power operated valve will ir.volvc stroking the valve to both its open and closed position. The valve will only be timed, however, in the direction (s) designated to perform its safety function (s). Therefore, the program plan specifies only the direction (s) in which valves must be stroke timed.
p \sec\ist\istrevia.wpf Section 3.1.1 Pg. 3 of 8
______o
Byron 2nd Interval IST Plan Revision 1 Decenter, 1997 3.1.1 valve Table Descriptions (continued)
L. 7tST HITHoD The test method column identifies specific tests which will be performed on specific valves to fulfill the requirements of OMa 1988, Part 10. The test and abbreviations used are as follows:
(Bt) check Valve Back riow Test The check valve disc will be exercised to the closed position required to fulfill its safety function by verifying that the disc travels to the seat on cessation or reversal of flow.
(et) Check Valve Full Stroke Test The check valve disc will be exercised to the open position required to fulfill its safety function by verifying the maximum required accident flow through the valve.
Alternatives to full flow testing, per NRC Generic Letter 89-04, Attachment 1. Positions 1 and 2, may also be used in specific cases.
(ro) rail Safe Test Open or (rc) rail Safe Test closed Valves with fall safe actuators will be tested to verify the valve operator moves the valve stem to the required fail safe position upon loss of actuating power, in accordance with OMa-1988, Part 10, paragraph 4.2.1.6.
In general, this will be accomplished during the normal stroking of the valve. Upon stroking a valve to its fail safe position, the solenoid operator is de-energized causing air to be vented which in turn allows the spring to move the valve to its fail safe position. This condition simulates loss of actuating power (Electric and/or Air) and hence satisfies the fail safe test requirements of OMa 1988, Part 10, paragraph 4.2.1.6.
pi\sec\ist\istrevla.wpf Section 3.1.1 Pg. 4 of 8
Byron 2nd Interval IST Plan Revision 1 December, 1997 3.1.1 Valve Table Description (continued)
L. IEST MET} LOD -(continued)
(It) Position Indjcation Tegl Valves which are identified to require a Position Indication Test will be inspected in accordance with OMa-1988, Part 10, paragraph 4.1.
JLt) Seat Leakane Test The seat leakaae tests will meet the requirements of OMa-1988, Part 10, paragraph 4.2.2 for Category A valves. On these valves, seat leakage is limited to a spetific maximum amount in the closed position for fulfillment of their safety function.
(Rt) Salety Valve Setooint Test safety valve setpoints will be verified in accordance with OM 1, as referenced in OMa-1988, Part 10, Paragraph 4.3.1.
(St) Full Stroke Test (also called Stroke Time Test) valve exercising tests of category A and B valves will be performed in accordance with LMa-19BB, Part 10, paragraph 4.2. The test will include full stroke testing to verify operability in the direction required to fulfill the requirad safety function.
_(X t ) Partial-Stroke Tent If only limited operation is practical during certain plant conditions, the valves shall be partial-stroke (Xt) exercised when plant conditions allow and full-stroke exercised when plant conditions allow in accordance with OMa-1988, Part 10, paragraph 4.2.1.2 or 4.3.2.2.
M. IgjI FREQUENCY:
Denotes the frequency and plant condition necessary to perform a given test. The following abbreviations are used:
Quarter 1v (0)
Tests designated "Q" will be performed a minimum of once every 92 days, except in those plant operating modes in which the valve is not required to be everacle.
p \sec\ist\istrevia.wpf Section 3.1.1 Pg. 5 of 8
~
Byron 2nd Interval IST Plan Revision 1 December, 1997 J.1.1 Valve Table Description (continued) 11 _ Test rREQUENcY (continued) cold Shutdown (cs)
Valve terting will commence within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> of achieving cold shutdown, with completion of cold shutdown valve testing not being a prerequisite to plant startup.
Per OMa-1968, Part 10, paragraph 4.2.1.2 (g) , for extended outages, testing need not be commenced in 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> provided all valves required to be tested during cold shutdown will be tested prior to plant startup. However, it is not the intent of this part to keep the plant in cold shutdown in order to complete this testing. In case of frequent cold chutdowns, valve testing need not be performed more often than once during any three month period.
Tech spec cold shutdown (csTs)
Tests with this designation shall be tested during cold shutdowns in accordance with Byron Technical Specifications.
Reactor Refueling (RR)
Tests with this designation will be conducted during reactor refueling outages only, Eighteen Months (18m)
Tests with this designation will be conducted a minimum of once every eighteen months.
p \sec\ist\istrevla.wpf Section 3.1.1 Pg. 6 of 8
Byron 2nd Interval 1st Plan Revision 1 December, 1997 3.1.1 valve Table Description (continued) 11 TEST TREQUEHeY (con tinued)
Two Years (2Y)
Tests with this designation will be condacted a minimum of once every two years.
Five Years ($Y)
Tests with this designation, generally involving Class 1 pressure relief devices, will be tested a minimum of once every 5 years. Additionally, a minimum of 20% of all class 1 relief valves of each type and manufacturer shall be tested within any 24 months. This 20% shall be previously untested valves, if they exist. Test expansions will be conducted in accordance with OM 1, where applicable t0M-1987 Part 3. Section 1.3.4)
Ten Years (10Y)
Tests with this designation, generally involving class 2 and 3 pressure relief devices, will be tested a minimum of once every 10 years. Additionally, a minimum of 20% of all class 2 and 3 relief valves of each type and manufacturer shall be tested within any 48 months. This 20% shall be previously untested valves, if they exit. Test expansions will be conducted in accordance with OM-1, where applicable (OM-1987, Part 1, Section 1.3.4),
sample Disassembly (sD)
Tests with this designation follow sample disassembly plans originated from GL 89-04. Refer tu the appropriate Relief Request, Technical Position, or Refueling Outage Justification for specific detailc.
Sample Disassembly /Techr]9al Speciff-ations (sD/TS)
Tests with this designation foi q; ple disassembly plans originating from GLB9-04 on an lv L..ith frequency. When Technical specification full stroke testing is completed within the 18 month frequency requirement, it may be used to satisfy full stroke testing in lieu of the disassembly plan.
Refer to Relief Request VR 2.
Appendix J Test Frequency Tests with this designation will be conducted at a frequency consistent with the Appendix J 1eak test frequency.
p \sec\ist\istrevla.wpf Smetion 3.1.1 Pg. 7 of B
4 SYRON 2ND INTEbAL IST PLAN REVISION 1 NOVEMBER,1997 VALVE VALVE IECH. COLD WALVE CATEGOR SIZE VALVE ACT. NORMAL STROKE TEST TEST POS SHUTDOWN REFUELFeG REUEF NUSAJER P&lD CLASS Y {1N ) TYPE TYPE POSITION OfRECT. ME' HOD FREO NOTES fvAF JUST. OUTAGE JUST. REOUEST 1/2AFOO1 A M-3 7 3 C 6.0 CK S.A. C 0 XtEt Ots VC-11 U-122 C Bt SD VR4 1/2AFOO18 M-3 7 3 C 6O CK S.A. C O Xt%t OCS VC- 11 M-122 C Bt SD 7R4 1/2AFOO3A M-37 3 C 6.0 CK $ A. C O At!Cr CCS VC- 1 1 M-122 1/2AFOO3B M'3 7 3 C 6.0 CK S.A. C O Xtit QCS VC-11 M-122 1/2AFOO6A M-3 7 3 B 6.0 GA M.O. C O St O 1.3 M-122 It 2Y 4 1/2 AF OO68 M-3 7 3 8 6.0 GA M.O. C 0 St Q 1.3 M-122 w 2Y 4 1/2M013A M-37 2 B 4.0 GL M.O. O C St O 1.3 M-122 R 2Y 4 1/3AF0138 M-3 7 2 B 4.0 GL M O. O C St O 1.3 M-122 h 2Y 4 1/2M013C M-3 7 2 B 4.0 GL M O. O C St Q 1.3 M-122 '
k 2Y 4 1/2670130 M-3 7 2 8 4.0 GL M.O. O C St O 1.3 M-122 h 2Y 4 1/2M013E M-3 7 2 8 4.0 GL M.O. O C St O 1.3 M-122 M 2Y 4 1/2AF013J M-3 7 2 B 4.0 GL M.D. O C St Q 1.3 M-122 R 2V 4 1/2 AF013G M-3 7 2 8 4.0 GL M.O. O C St O 1.3 M-122 R 2Y 4 1/2AF013H M-3 7 2 8 4.0 GL M.O. O C St O 1.3 M-122 It 2Y 4 1/24WO14A M-37 2 C 4.0 CK S.A. C O Ct CS VC-11 M-122 C' Bt CS VC.11 1/2c40148 M-3 7 2 C 4.0 CK S A. C O C CS VC-11 M-122 C Bt CS VC-11 1/2AF0140 M 37 2 C 4.0 CK S A. C O C1 CS VC-11 M-122 C BT CS VC-17 1/2AF0140 M-3 7 2 C 4.0 CK SA C O Ct CS VC-11 M-122 C Bt CS VC-11 1/2AF014E u-3 7 2 C 40 CK S.A. C O C CS VC 11 M-122 C Br CS VC-11 1/24WO14F M-3 7 2 C 4.0 CK S.A. C O Ct CS VC-11 M-122 C Bt CS VC-11 (pisec\rs*\vaiv-nov97.uls-1197) 3.1.2 - Page 1 et 42
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CATEGOR SIZE VALVE ACT- NORMAL STROKE TEST TEST : POS. SHUTDOWN REFUELING RFUEF NUMBER P&fD CLASS Y (!N 1 TYPE TYPE POSITION DIRECT. METHOD FREO NOTES fvA) JUST. OUTAGE JUST. REQUEST 1/2FWOO9A M-36-1 C 2 8 16_O GA H.O. O C St CS 1.3 VC- 1 M-121 18 l
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BYR(Kt 2ND INTERVAL iST PLAN REVISION 1 NOVEMBER,1997 VALVE VALVE TECH. COLD VALVE CATEGOR SIZE VALVE ACT, NORMAL STRCKE TEST TEST POS. SHUTDOWN REFUELING OUTAGE RELIEF NUMBER P&fD CLASS Y (IN.1 TYTT TYPE POSITION DtRECT. METl40D FREO NOTES (VA) JUST. JUST. REQUEST 1/2FWO36C M 3&10 2 C 3.0 CK S.A. O C Bt CS VC-20 M 1211C 1/2FWO360 M 3618 2 C 30 CK S.A. O C Bt CS VC-20 M 1211C 1/2FWO39A M 3&lC 2 8 6.0 GA A.O. O C St CS 1,3 VC-9 M 12118 ft 2Y 4 Fe CS 2 VC-9 1/2FWO398 M341A 2 8 6.0 GA A.O. O C St CS 1,3 VC-9 M 121.tB lt 2Y 4 Fe CS 2 VC-9 1/2FWO39C M 3610 2 8 6.0 GA A.O. O C St CS 1,3 VC-9 M 1211 A 11 2Y 4 Fe CS 2 VC-9 1/2FWO390 M3&l8 2 8 6.0 GA A.O. O C St CS 1,3 VC-9 M 121 IC ft 2Y 4 Fe
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BVRON 2ND INTERVAL t37 PLRN REVISION 1 NOVEMBER,1997 I VALVE VALVE TECH. COLD VALVE CATEGOR $!ZE VALVE ACT. NORMAL STROKE TEST TEST POS. SHUTDOWN REFUEUNG OUTAGE RELIEF NUMBER P&l0 CLASS Y (IN 1 TYPE TYPE POSITION DtREN. METHOD FREO NOTES (VA) JUST. JUST. REQUEST 1/2MSOl6A M-35 2 2 C 6.O x SV S.A. O OC Rt SY 15 M 120 2A 10.0 1/2MSO168 M 351 2 C 6.0 x SV S.A. O 9/C Rt SV 15 M 12S1 10.0 1/2MSOl6C M 352 2 C 60m SV S.A. O O/C Rt SV 15 M 120 28 10.0 1/2MSOl60 M-351 2 C 6.0 x SV S.A. O O/C Rt SY 15 M12S! 10.0 1/2MSOl 7A M 35-? 2 C 6.0 m SV S.A. O OtC Rt 5Y 15 M 120 2A 10.0 1/2MSO178 M 3S l 2 C 6.O x SV S.A. O O/C Rt SY 15 M 1231 10.0 1/2MSO17C M 35 2 2 C 6.0 x SV S.A. O O/C Rt SY 15 M 120 28 10.0 1/2MSO170 W 351 2 C 6.0 m SV S.A. O O/C Rt SY 15 M 1261 10.0 1/2MS018A M 35 2 2 B 6.0 x PORV H.O. C C/O St O- 1.3 M 1202A 6.0 it 2Y 4 Fe O 2 1/2MSO188 M 351 2 8 6.0 m PORV H O. C C/O St O 1.3 M 1201 6.0 ft 2Y 4 Fe O 2 1/2MSO18C M 352 2 8 6.0 m PORV H.O. C C/O St O 1,3 M 120 28 6.0 ft 2Y 4 Fe O 2 1/2MS018D M 351 2 8 6.0 m PORV H.O. C C/O St O 1.3 M 120 l 6.0 ft 2Y 4 Fe O 2 1/2MSO19A M 35 2 2 B 8.0 GA M O C St O 6 M 120 2A 1/2MSO190 M 351 2 8 8.0 GA M O C St O 6 M 12S1 112MSO19C M 352 2 8 8.0 GA M O C St O 6 M 120 28 1/2MSO190 M 351 2 8 8.0 GA M O C St O 6 M 1201 _
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SYROE6 208D INTERVAL ISV PLAN -
REVtSION 1 NOVEMBER,1997 VALVE VALVE TECH. COLD VALVE CATEGOR SIZE VALVE ACT. NORMAL STROKE TEST TEST POS. SHUTDOWN REFUELING OUTAGE RELIEF NUMBER P&:D CLASS Y (IN 1 TYPE TYPE POSITION OtRECT. METHOD FREO NOTES (VA) JUST. JUST. REQUEST 1/2RYO30A M 60 8 3 C O.75x1.0 RV S.A. C O/C Rt 10Y M 135 8 1/2RYO308 M 60 8 3 C O. 75 x 1.0 RV S.A. C O/C Rt 10Y M i35 8 1/2RYO15 M 2060 6 2 A O.5 GL M C C Lt AJ 1 M 2135 6 1/2RY455A M 60 5 1 8 3.0 PORV ' A.O. C OIC St CS 1,3 VC-14 M 135 5 ft RR 12 4 Fc CS 2 VC-14 1/2RY456 M 605 1 B 3.0 PORV A.O. C O/C St CS 1.3 VC-14 M 135 5 ft RR 12 4 Fe CS 2 VC-14 1/2RYBOOOA M 60-5 1 0 3.0 GA M.O. O C St O 1.3 M 1355 ft RR 12 4 1/2RY80000 M 60 5 1 0 3.0 GA M.O. O C St C 1,3 M 135 5 ft RR 12 4 1/2RY8010A M 60 5 1 C 6.0 SV S.A. C O!C Rt 5Y M 135 5 ft RR 12 4 1/2RY B0108 M 60 5 1 C 6.0 SV S.A. C O/C Rt SY M 135 5 W RR 12 4 1/2RY8010C M 60-5 1 C 6.0 SV S.A. C O/C Rt SY M 135 5 et RR 12 4 1/2RY8025 M 60-6 St O 1,3 M 135 6 2 A .375 GL A.O. C C Lt AJ 1 it RR 12 4 fc 0 2 1/2RY8026 M CO S St O 1.3 M 135 6 2 A .375 GL A.O. O C Lt AJ 1 h RR 12 4 Fe O 2 1/2RY802C M 60 6 St O 1.3 M 135 6 2 A .75 D A.O. O C Lt AJ 1 It RR 12 4 a Fe O 2 1/2RY8033 M 60 6 St O 1,3 M 135 6 2 A O.8 O A.O. O C Lt AJ 1 h RR 12 Fe O , 2 1/2RY SO46 M 60 6 2 AC 3.0 CK S.A. C C Lt AJ 1 41356 Bt RR ROJ-15 V ' 1 Dmed 1/2RY8047 M 60 6 2 AC O.75 CK S.A. C C Lt AJ 1 M 135 5 Bt RR ROJ-15 VR-1 Demed (p:uechst\valv-nov97.xis-119 7) 3.1.2 - Page 29 of 42
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3.1.2 - Page 33 of 42 (pAsec\istivalv-nov97.xis-119 7)
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REVISION 1 NOVEMBER,1997 VALVE VALVE TECH. COLD TEST POS. SHUTDOWN REFUELING RELIEF VALVE CATEGOR 31ZE VALVE .ACT. NORMAL STROKE TEST POSITION DIRECT. ?JETHOD FREO NOTES (VA) JUST. OUTAGE JUST. REQUEST NUMBER P&lD CLASS Y (tN.) TYPE TYPE 24.0 M.O. C O/C St RH 1.3 ROJ-4 1/25188118 M 61-4 2 8 GA.
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3.1.2 - Page 34 of 42 (p:\secVst\valv-nov97.xis-1197)
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, NOVEMBER.1S97 VALVE VALVE TECM. COLD VALVE CATEGOR STIE VALVE ACT. NORMAL STROKE TEST TEST" POS. SMUTOOWN REFUELING OUTAGE RE1!Er NUM9ER P&l0 CLASS Y (IN I TYPE TYPE POSITtON D*ECT. METHOD FREO NOTES (Val JUST. JUST. REQUEST 1GVF01M W 51- 18 None C 6.0 RV S.A C O 8 Rt 10Y 3 W151 1/2VOOO1 A u 1051 2 A 48.0 BTF H.O. C C Lt AJ 1
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1 4
a (pAsochtivalv-nov9 7.nts-11971 3.1.2 - Page 41 of 42
_ _ _ _ _ _ _ . .. _. .. - . . . _ . _.. m._ _ . . . . . . _ < . ._ - . . . .
Q7AON 2ND INTERVOL IST PLAEe REVISON 1 NOVEMBE R,1997
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t VALVE VALVE T E CH. COLD VALVE CATEGOR ..J VALVE ACT. NORMAL STROKE TEST TEST POS. SHUTDOWN REFUELP4 0VT AGE REUEF l NL*4BER P&lO CLASS Y (IN ! TYPE TYPE POSITION D8tECT. METHOO FREO NOTES fvAl JUST. JUST. REQUEST
^
1/2WM 190 W el la 2 A 2.0 GL M C C Lt AJ 1 W4918 j 1/2WM191 W4S14 2- AC 2.0 CK SA C C Lt AJ 1 j # 4978 9t RR ROA15 V85-1 Dermed OWOOO2A W t ts 1 3 BC 3.0 CK SA O O Ct O OWOOO26 # 118 1 3 BC 3.0 CK SA O O Ct O
- *r2WOOO6A W 118 5 2 A 10.0 GA M O. O C St O 1.3 5 til T Lt AJ 1 ft 2V 4 1/2WOOO69 41685 2 A 10.0 GA M.O. O C St Q 1.3 W 115 7 Lt AJ 1 4 2V 4 1/?WOOO7A - W 113 5 2 AC 10.0 CK SA C C Lt AJ 1 W 118 7 et Rs4 ROA15 VR 1 DM 1/2WOOOI8 W 118 5 2 AC 10.0 CK S A. C C Lt AJ 1 W 179 F 91 RR ROJ.? S VR-1 Danseel 1/2 WOO 20A St Q 1.3
- 118 5 2 A 10 0 GA M.C. O C Lt AJ 1 W 118 7 et 2V 4 1/2 WOO 200 St Q 1.3 W it8 5 2 A 10 0 GA M .O. O C Lt AJ 1 W til F et 2v 4 OWOO28A 41181 3 C 1.5= 2.5 RV S.A. C OC Rt 10V OWOO289 41191 3 C 1.5 =2.5 RV SA C O/C Rt 10Y 1/2 WOOS 6A St O 1.3
- 118 5 2 A 10.0 GA M.O. O C Lt AJ 1 W 118 7 se 2v 4 1/2 WOOS 6B St O 1.3 2 '91185 2 A 10.0 GA M.D. O C Lt AJ 1 W 118 7 ft 2Y 4 j OWWO49A 4426 None SC 3.0 CK SA C O Ct See Note 16 See Note 16 d
16
i (p:Bec%stivatw cov97.mts-1197) 3.1.2 - Page 42 e4 42
Byron 2nd Interval IST Plan Revision 1 Decenber, 1997 NOTE 1 The following category A valves, which are containment isolation volves, will be seat leakage tested (Lt) in accordance with Federal Regdation 10CFR50, Appendix J, per DMa-198P, part 10, paragraph 4.2.2.2 (unless otherwise directed by more conservative Technical Specifications).
VALVE # VALVE # VALVE N
- 1) 1/2CC685 41) 1/2PR033B 82) 1/2 SIB 964
- 2) 1/2CC9413A 42) 1/2PR033C 83) 1/2S18968
- 3) 1/2CC9414 43) 1/2PR033D 84) 1/2VQ001A
- 4) 1/2CC9416 44) 1/2PR066 85) 1/2VQ001B
- 5) 1/2CC9438 45) 1/2PS228A 86) 1/2VQ002A
- 6) 1/2CC9486 46) 1/2PS228B 87) 1/2VQOO2B
- 7) 1/2CC9518 47) 1/2PS229A 88) 1/2VQ003
- 8) 1/2CC9534 48) 1/2PS229B 89) 1/2VQ004A
- 9) 1/2CS007A 49) 1/2PS230A 90) 1/2VQOO4B
- 10) 1/2CS007B 50) 1/2PS230B 91) 1/2VQ005A
- 31) 1/2CS008A 51) 1/2PS231A 92) 1/2VQ005B s
- 12) 1/2CS000B 52) 1/2PS231B 93) 1/2VQ005C
- 13) 1/2CV8100 53) 1/2PS9354A 94) 1/2VQOl6
- 14) 1/2CV8112 54) 1/2PS9354B 95) 1/2VQ017
- 15) 1/2CV8113 55) 1/2PS9355A 96) 1/2VQ018
- 16) 1/2CV8152 56) 1/2PS9355B 97) 1/2VQ019
- 17) 1/2CV8160 57) 1/2PS9356A 98) 1/2WM190
- 38) 1/2FC009 58) 1/2PS9356B 99) 1/2WM191
- 19) 1/2FC010 59) 1/2PS9357A 100) 1/2WOOO6A
- 20) 1/2FC011 60) 1/2PS9357B 101) 1/2WOOO6B
- 21) 1/2FC012 61) 1/2RE100; 102) 1/2WOOO7A
- 22) 1/2IA065 62) 1/2RE9157 A03) 1/2WOOO7B
- 23) 1/2IA066 63) 1/2RE9159A 104) 1/2 WOO 20A
- 24) 1/2IA091 64) 1/2RE9159B 105) 1/2 WOO 20B
- 25) 1/20G057A 65) 1/2RE9160A 206) 1/2 WOO 56A
- 26) 1/20G079 66) 1/2RE9160B 107) 1/2 WOOS 6B 271 1/20G0B0 67) 1/2RE9170
- 28) 1/20G081 68) 1/2RF026
- 29) 1/20G002 69) 1/2RF027
- 30) 1/20G083 70) 1/2RYO75
- 31) 1/20G084 71) 1/2RY8025
- 32) 1/20G085 72) 1/2RY8026
- 33) 1/2PR001A 73) 1/2RYB028
- 34) 1/2PR001B 74) 1/2RY8033
- 35) 1/2PR002E 75) 1/2RY8046
- 36) 1/2PR002F' 76) 1/2RY8047
- 37) 2PR0020 77) 1/2sA032
-38) 1/2PR002H 78) 1/2SA033
- 39) 1/2PR032 79) _1/2 SIB 871
- 40) 1/2PR033A 80) 1/2SI8880 P
- 81) 1/2SI8888 p \sec\ist\istrevla.wpf Section 3.1.3 Pg. 1 of 5
Byron 2nd Interval IST Plen Revision 1 December, 1997 MEJ Per URC request, the post accident hydrogen monitoring system check valves l'2PS231A and 1/2PS231B will be stroke exercised open on a quarterly frequency to verify operability.
NOTE 3 The 1/2VF01M are vacuum relief devices located on the Refueling Water Storage Tanks (RWST). Their function in the open direction is to prevent a collapse of the RWST and/or prevent drawing vacuum in the tank. The successful operation of these devices would ensure that the net positive suction head for the ECf8 pumps is maintained. Although these devicee are non-safety and are considered to fall outside the scope of the IST Program, they will be listad in the IST tables and tested in accordance with OM-1 due to their safety significance.
EO,lg_i The following valves are stroke timed locally and do not require a position indication test (see Technical Position VA-4 for more details).
1/2CV120 1/2SX173 1SD054A-H 1/2SX170 2SD0548,D,F,H NOTE u The remote position indicator for these valves cannot be observed directly due to the encapsulated design of the solenoid valve body. During the indication test. indirect evidence of the necessary valve disk movement shall be used, in accordance with OM-10, paragraph 4.1. The valves affected are listed below:
ICV 8114 1PS230A/B 2PS22BA/9 3CV8116 1RC014A-D 2PS229A/B iPS220A/B 2CV8114 2PS230A/B iPS229A/B 2CV8116 2RC014A D NOTE _6 The following valves are manually stroked locally and do not require a position indication test (see Technical Position VA-4 for more details).
1/20C9458 1/2CC9467A-C 1/2CC9459A, B 1/2MS019A-D p \sec\ist\istrevla.wpf Section 3.1.3 Pg. 2 of 5
l Pyron 2nd Interval IST Plan Revision 1 December, 1997 NOTE 7 1/2 SIB 818A D, 1/2SIBB19A D, and 1/2SI6948A/B are Event V check valves, which are defined as two check valves in series at a low pressure /RCS interface whose failure may result in a LOCA that bypasses containment. They are individually leak tested in accordance with NRC Generic Letter 89-04, position
- 4b.
NOTE 8 1/2CC9518, 1/2CC9534, 1/2CV8113, and 1/2RHB705A/B are check valves designed to relieve pressure between two containmont isolation valves. The full flow limiting value is zero, since the safety function of these valves in the open direction is to relieve pressure only.
NOTE 9 The 1/2 SIB 919A/B check valves are the Safety Injection Pump mini-flow recirculation line valves which open to allow recirculation flow during IST Surveillances. Since full stroking these valves will depend on the reference point of testing, acceptable full stroke will be verified whenever the recorded mini-recirculation flowrate is greater than the minimum allowed flowrate given in the surveillance.
NOTE 10 The Essential Service Water (SX) and Make-Up Pump discharge check valves (06X028A/B) open to permit make-up water flow from the Rock River to the SX System Basin. These check valves are downstream of the pump discharge tap-off to the SX Make-Up Jacket Water Heat Exchanger and Gear Oil Cooler. Since this tap off line is orificed, the flowrate through this line, and therefore the flowrhte through pump discharge check valves OSX028A/B, will depend on the reference point of testing. Acceptable OSX028A/B full stroke will be verified whenever the recorded total pump flow minus the tap off line flow is greater than the minimum allowed flow contained in the ASME pump surveillance.
NOTE 11 Per Byron Technical Specifications Amendment, valves 1/2SD002A-H,and 1/2SD005A D have been removed from the list of valves to be tested under 10CFR50 Appendix J and will now be tested per OMa-1988, Part 10, paragraph 4.2.2. However, Byron Station has committed to the NRC to continue to perform a category A leak test on these valves. Refer to Chron #114244.
pi\sec\ist\istrevla.wpf Section J.1.3 Pg. 3 of 5
Byron 2nd Interval IST Plan Revision 1 December, 1997 NOTE 12 Valves 1/2RY8025, 1/2RY8026, 1/2RY8028, 1/2RY8010A, 1/2RY8010B, 1/2RY8010C, 1/2RY8033, 1/2RY8000A, 1/2RY8000B, 1/2RY455A and 1/2RY456 will receive position indication tests on a refuel frequency per Generic Letter 90 06.
NOTE 13 .
For the purposes of the IST Program, the starting air receiver overpressurization-relief valves, 1/2SA148A-D, will be conservatively classified as safety category I, quality group "C" (ASME Class 3) valves, rather than safety category I, quality group "G" (Non ASME) valves, as noted in P&ID M-54-4A, Note 3. They will be tested in accordance with the IST Program.
NOTE 14 The 1/2SI121A/B Relief Valves will be installed to prevent pressure locking of the 1/2 SIB 811A/B containment sump valves due to pressure buildup in the 1/2SI6811A/B valve bonnets. The U-1 valves are scheduled to be installed during BIR07 (Spring of 1996) and the U-2 valves are scheduled to be installed during B2R06 (Fall of 1996).
NOTE lb Per DM 1987 Part 1, paragraph 1.3.4.1, PWR main steam safety valves 1/2MS013A-D, 1/2MS014A-D, 1/2MS015A D, 1/2MS016A-D, and 1/2MS017A-D shall be tested in accordance with paragraph 1.3.3.1. Consequentially, even though they are class 2 valves, they must be f.ested to the class 1 interval, 5 years.
NOTE 16 Valves OWWO49A/B were formerly EPNs OSX127A/B. In the previous configuration, the WW and SX systems discharged into the SX basin via a commpmn discharge point. Check valves OSX127A/B prevented flow from SX entering the WW system when clossd. Valve OSX127A/B allowed WW flow to the-SX basin when open. A modifichiton provided separate discharge points for SX and WW to the SX basin.
As a result of the modification the OSX127A/B valves were redesignated as OWWO49A/B, repositioned slightly, and retained in the WW discharge pathway to the SX basin.
Valves OSX127A/B were Safety-Related, ASME Code Class 3 valves. Because of their function and Code class they were required to be within the scope of the IST Program.
t p \sec\ist\istrevla.wpf Section 3.1.3 Pg. 4 of 5
Byron 2nd Interval IST Plc.n Revision 1 December, 1997 Valves OWWO49A/B are non Safety-Related and non-Code Class (not Class 1, 2 or
- 3) components. NUREG-1482, Section 2.2 indicates that non-Code components are E21 required to be within the scope of the IST program. Valves OWWO49A/B are electively being added for conservatism to the IST Program, though not required.
It is important to ensure the Deep Well is capable of transferring water to the ultimate heat sink. In NUREG 1482, NRC Staff Position 11, it is indicated that critericn 1 in Appendix A to 10 CFR Part 50 requires, among other things, that components important to safety be tested to quality standards commensurate with the importance of the safety functions to be performed. The Deep Well system is tested to ensure it is capable of providing water to the SX basin in procedure OBvS 7.5.1-1, " Unit O Deep Well pump Make-Up Flow Verification."
In OBVS 7.5.i-1, it indicates that testing may be performed in any mode, at the interval of 6 months and is applicable for modes 1, 2, 3 and 4. One additional test will be performed during the moaths of June, July or August each year. Valves OWWO49A/B will be tested in accordance with CBVS 7.5.1-1 at the f requency prescribed.
The frequency in OBVS 7.5.1-1 differs from that established in OM-1988 Part
- 10. NUREG 1482, Section 2.2 indicates that Relief Requests for non-Code components may be implemented without NRC evaluation and approval. It further indicates that these deviations need not be written as " Relief Requests.*
Finally NUREG-1482 states that notes, footnotes, or short escriptions in the program often document such deviations. The deviation in irequency of testing of the OWWO49A/B valves in accordance with OBVS 7.5.i-1 is being documented by this note.
pi\sec\ist\istrevla.wpf Section 3.1.3 Pg. 5 of 5
Byron 2nd Interval IST Pltn Revision 1 December, 1997 i
SECTION 3.2 VALVE TECHNICAL POSITIONS r
1 pi\sec\ist\istrevia,wpf
Byron 2nd Interval IST Plan Revision 1 Decenber, 1997 3.2.1 valve Technical Position Swnmary Numbel ,qpsppnent (s) Description VA-1 All Power operated Method of Stroke Timing Valves Valves VA 2 Valven with Fail- Method of Fail-Safe Testing Valves Safe Actuators VA-3 All Power operated Method of Establishing Acceptance Criteria Valve s for Power-operated Valves VA-4 Valves with Remote Method of Position Indication Testing Position Indicators i
pr\sec\1st\istrevla.wpf Section 3.2.1 Pg. 1 of 1
____---.J
Byron 2nd Interval IST Plan RevAsion 1 December, 1997 l
VALVE TECH'12 CAL POSITION VA 1 IITLE:
Method of Stroke Timing Valves YALVES AFFECTED:
Power Operated Valves Requiring Stroke Time Testing EQDE REQUIREMEFT(D) / DISCUSSION:
The use of the control board open and closed lights to determine the stroke time of power-operated valves is the issue discussed in this Technical Position. Paragraph 1.3 of OMa-19BB, Part 10, defines " full-stroke time" as "the time interval from initiation of the actuating signal to the indication of the end of the operating stroke." It is common industry practice to measure stroke time as the time interval between placing the operator swit ch on the control board in the "close" or "open" position and indication tha- 'he valve is open or closed on the control board (switch to light) .
POSITIOH1 The way in which the limit switches that operate the remote position indicator lights are set may result in " closed" or "open" indication before the valve obturator has actually completed its travel. This is not considered to be a problem, as the purpose of the test is to determine if degradation of the valve operator system is occurring, which is determined by observing changes in stroke time relative to the reference stroke time. Stroke time measurements may be rounded to the nearest tenth (0,1) of a second. Standard rounding techniques are to be used when rounding stop watch readings during valve stroke time testing (e.g., 10.45 rounds to 10.5 and 10.44 rounds to 10.4). Reference values will be established to the nearest tenth of a second although stroke times may be recorded to the- hundredths place (0.01) . This technique satisfies OM-10, paragraph 4.2.1.4 (b) , in that all power operated valves will be measured to at least the nearest second.
For those specific cases in which a valve must be stroke timed locally, the
, stroke timing will begin with the initiation of the actuating signal and end with the completion of valve movement in the field, pi\sec\ist\istrevla.wpf Section 3.2.2 Pg. 1 of 6
7 Byron 2nd Interval IST Plcr Revision 1 December, 1997 l
VALVE TECHNICAL POSITION l
VA.2 TITLE:
Method of Fail Safe Testing Valves.
VALVES AFFECTRE1 See IST Valve Tables (Fc = Fail Safe Test closed; Fo = Fail Safe Test open)
RQRE_REQVJERMgNT ( B ) / I S SUE _ DI S CEL91QllL Paragraph 4.2.1.6 of OM-10 states that avalves with fail safe actuators shall be tested by observing the operation of the actuator upon loss of valve actuator power in accordance with the exercising frequency of paragraph 4.2.1.1 of OM-10.
POSITI.QH1 Most valves with fail safe positions have actuators that use the fail-safe mechanism to stroke the valve to the fail-safe position during normal operation. For example, an air-operated valve that fails closed may use air to open the valve against spring pressure. When the actuator is placed in the closed position, air is vented from the diaphragm and the spring moves the obturator to the closed position.
In the cases where normal valve operator action moves the valve to the closed position by de-energizing the operator electrically, by venting air or both (e.g., an electric solenoid in the air system of a valve operator moves to the vent position on loss of power), no additional fail-safe testing is required.
Valves with fail-safe actuators that do not operate as part of normal actuator operation must be tested by other means.
Using a valve remote position indicator as verification of proper fail-safe operation is acceptable, provided the indicator $ s rtriodically verified to be operating properly as required by OM-10, paragraph 4.1.
The f ail-saf e test is generally performed at the same frequ' .cy as the stroke
< -time exercise test. Where the exercise test is performed less frequent than every 3 months, a cold shutdown justifiestion, refueling outage justification, or relief request has been written. The same justifications for the stroke timing would also apply to the fail-safe tests.
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Byron 2nd Interva? IST Plan Revision 1 Decembe r, 1997 VALVE TEC}D12 CAL POSITION VA 3 TITLE:
Method of Establishing Acceptance Criteria for Power-operated Valves.
VALVES AFF.gCTED:
Power Operated Valves Requiring Stroke Time Testing CODE . R EQQJA5 BENT ( 5 ) /IHyLplF CUS S IOlit The IST Program requires that reference values be established in accordance with paragraphs 3.3, 3.4, or 3.5 of OM-10. Per paragraph 1.3 of OM-10, a reference value is *one or more values of test parameters measured or determined when the equipment is known to be operating acceptably."
Acceptable bands are determined based on these reference values in accordance with paragraph 4.2.1.8 of OM 10.
Per paragraph 4.2.1. 4 (a) of OM-10, "The limiting valuu (s) of full-stroke time of each power-operated valve shall be specified by the Owner." According to NRC Generic Letter 89-04, the limiting value should be a reasonable deviation from this reference stroke time based on the valve size, valve type, and actuator type. The deviation should not be so restrictive that it results in a valve being declared inoperable due to reasonable stroke time variations.
However, the deviation used to establish the limit should be such that corrective action would be taken for a valve that may not perform its intended function. When the calculated limiting value for a full-stroke is greater than a Technical Specification (TS) or safety analysis limit, the TS or safety analysis limit should be used as the limiting value of full-strone time.
RQSITION:
Table VA-3.1 will be used to establish the Acceptable Ranges (per paragraph 4.2.1.8) and Limiting Values (determined by Byron Station) for power-operated valves subject to the Notes listed as fo11cws:
-1. Tau is the reference value in seconds of a valve when it is known to be operating acceptably.
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I Byron 2nd Interval IST Plen l Revision 1 l December, 1997 l
VALVE TECHNICAL POSITION VA.3 (continued)
- 2. Reference values will be rounded off to the nearest tenth of a second.
Acceptable Ranges will be rounded off to the nearest tenth of a second, calculated IST limiting values will be rounded off to the nearest whole number. Standard rounding techniques are to be used when rounding (e.g.,
10.45 rounds to 10.5, and 10.44 rounds to 10.4 seconds).
- 3. The most conservative limiting value between the IST calculated limit (as determined from Table VA-3.1, below), UFSAR limit, Tech Spec Limit or manufacturer limit should be used as the Maximum / Limiting stroke time.
Any deviations from this criteria will be evaluated and documented in writing.
- 4. When a valve or its control system has been replaced, repaired, or has undergone .naintenance that could affect the valve's perf ormance, a new reference value shall be determined or the previous value reconfirmed by an inservice test run prior to the time it is returned to service.
TABLE VA 3.1 valve Reference Acceptable Maximum / Limiting Operator Stroke Time (sec.) Ranae (sec.) Stroke Time (sec.)
Motor Tu, > 10 0. 8 5Tur - 1.1STur '1. 2 57ur Tur s 10 'O 75Tur - 1.2 5Tur 1.50Tur Other Tu r > 10 0.75Tur
- 1.25Tur 8 1.75Tur Tur s 10 0. 50Tur - 1. 5Tur 2.0Tur All (Optional) 'Tu, < 2 s 2.0 2.0
'or Tur + 20, whichever is more conservative (lower)
'or Tur i leec, whichever is greater, when compared to reference value 8
cr Tur + 20, whichever is more conservative (lower)
'In general, a valve with a reference value of 1.2 seconds or below will use this option
. _ _ _ == _ _.
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Byron 2nd Intervsl IST Plen Revision 1 December, 1997 VALVE TECHNICAL POSITION VA 4 MLL Method of Position Indication Testing YALVES AFFECTED _
All valves with Remote Position Indicators
.CQPI_REQVlLEliMT (D ) / DIACMaM 9El OMa-1988, Part 10, paragraph 4.1, states that avalves with remote position indicators shall be observed at least once every 2 years to verify that valve operation is accurately indicated."
F.QALILQH1 In reference to Steven Weinman (Boil +. and Pressure Vessel Committee) reply letter to Russell J. Tamminga (Comed), dated November 14, 1988, concerning Inquiry number IN88-015, the following question was answered Question: Is it the intent of Section XI, IWV-3300 that for valves having remote position indicatcra at multiple locations (such as in the control room and also on a remote shutdown panel and/or sampling panel) that only the remote position indicator at the location utilized in exercising the valve (IWV-3412) and timing the stroke of the valve (I WV-3413) be verified that the valve operation is accurately indicated?
Reply: Yes This Inquiry also applies to the applicable sections in OMa-1988, Part 10:
- 1. Paragraph 4.1, Valve Position Verification
- 2. Paragraph 4.2.1, Valve Exercising Test 3, Paragraph 4.2.1.4, Power-operated Valve Stroke Testing In summary, the remote position indicator utilized during valve exerciaing (OM-10, paragraph 4.2.1) and stroke timing (OM-10, paragraph 4.2.1.4) is the indicator which is used to verify that valve operation is accurately indicated (OM-10, paragraph 4.1). However, if a valve is stroke time tested locally or manually exercised locally, a remote position indication test is not required.
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Byren 2nd Interval IST Plcn Revision 1 December, 1997 VALVE TECHNICAL POSITION VA 4 (continued)
The remote position indication test is to be performed as follows:
-An individual is dispatched to the valve to locally observe the valve movement and he/she establishes communication with an individual at the remote position indicator. As the valve is exercised in both directions, the individual at the remote position indicator veri 2ies that the-indicator shows the proper position by communicating with the local observer, who is observing the valve stem movement. When the valve stem movement cannot be direct 3y observed, indirect means may be employed to vtcity the change in valve-position. These may include observations such as char 3es in system pressure or establishment / cessation cf flow.
Note Byror. Station's conversion f rom the 1983 Edition of Section XI of the ASME Code to the 1989 Edition of Section XI of the ASME Code, which references OMa-1988, Part 10, for valves, has not been interpreted as requiring an expansion of scope for the sole purpose of performing an indication test on a valve (reference Table 1 of OM 10) . It is Byron's interpretation that tb9 intent of OM 10 was not to expand the scope of the IST Program due to position indication testing alone. A joint, aliving" bases document between Dyron/Braidwood has been created to maintain the bases for inclusion / exclusion of valves in the IST Program, pt\sec\ist\istrevia.wpf Section 3.2.2 Pg. 6 of 6
Byron 2nd Interval IST Plen Revision 1 Decettbe r , 1997 i
SECTION 3.3 VALVE COLD SHUTDOWN JUSTIFICATIONS s
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Byron 2nd Interve1 IST Plc.n Revision 1 December, 1997 3.3.1 valve Cold shutdown Justification Sume=ry Humber gpyggnent (s) Deseriet1.9B VC-1 1/2MS001A D Stroke Time Test (SL) During Cold Shutdown 1/2FWOO9A.D l
VC 2 1/2CV8104; 1/2CVB442 Full Stroke Test (Ct) of 1/2CV8442 and 1/2CV8804A; 1/2CV112D; Stroke Time Test (St) of Remaining Valves 1/2CV112E During Cold Shutdown VC 3 1/2FW009A D Deleted - combined with VC-1 l VC 4 1/2CV112Bl 1/2CV112C Stroke Time Test (St) During Cold Shutdown 1/2CV8105; 1/2CV8106 and Fail Safe Test Closed (Fc) of 1/2CV8152; 1/2CV8160 1/2CV8152 and 1/2CV8160 During Cold Shutdown VC-5 1/2Ril8701 A/B; Stroke Time Test (St) During Cold Shutdown 1/2 RH8702A/B l VC 6 1/2RC014A-D Stroke Time Test (St) / Fail Safe Test Closed (FC) During Cold Shutdown VC 7 1/2RH8730A/B Full Stroke Test (Ct) / Backflow Test (Bt) During Cold Shutdown and Partial Stroke Test (Xt) Quarterly VC 8 1/2SI8818A-D Full Stroke Test (Ct) During Cold Shutdown 1/2SIG95BA/B VC-9 1/2FWO39A D Stroke Time Test (St) and Fail Safe Test Closed (Fc) During Cold Shutdown VC-10 1/2CV459; 1/2CV460 Stroke Time Test (St) and Fail Safe Test 1/2CV8149A C Closed (Fc) During Cold Shutdown VC 11 1/2AF001A/B; 1/2AF003A/B Full Stroke Test (Ct) of all valves During 1/2AF014A-H; 1/2AF029A/B Cold Shutdown, Partial Stroke Test (Xt)
Quarterly for 1/2AF001A/B and 1/2AF003A/B and Backflow Test (Bt) During Cold Shutdown f'* 1/2AF014A-H VC-12 1/2 SIB 801A/B Stroke Time Test (St) During Cold Shutdown.
VC-13 1/2 SIB 802A/B; 1/2 SIB 806 Stroke Time Test (St) During Cold Shutdown 1/2SI8809A/B; 1/28I8813 1/2SI8835;.1/2 SIB 840
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Byron 2nd Interval IST Pltn Revision 1 December, 1997 3.3.1 Valve Cold Shutdown Justification Susanary (continued) thpthu ,Q,qgioonent ( s i peserintion VC-14 1/2RY455As 1/2RY456 Stroke Time Test (St) and Fail Safe-Test closed (FC) During Cold Shutdown VC-15 Pressure Isolation Leak Test (Lt) During Cold shutdown for Valves (PIVS) and all Per Technical Specifications and 1/2RH9705A/B Valves Backflow Test (Bt) for Check Valves at the same Frequency VC 16 1/2CV8440 Backflow Test (Bt) During Cold shutdown.
VC-17 1/2 SIB 99BA-D Partial Stroke Test (Xt) During Cold shutdown' VC 18 1/2RHB716A/B Stroke Time Test (St) During Cold Shutdown VC-19 1/2CC685; 1/2CC9413A Stroke Time Test (St) During Cold Shutdown 1/2CC9414; 1/2CC9415 1/2CC9416s 1/2CC943B 1/2CV8100J 1/2CV8112 VC-20 1/2FWO36A D Backflow Test (Bt) During Cold Shutdown VC-21 1/2 SIB 008A-D Stroke Titae Test (St) During Cold shutdown VC-22 1,4.W8355A D Stroke Time Test (St) During Cold Shutdown VC-23 1SD054A-H; Stroke Time Test (St) and Fail Safe Test 2SD054B,D,F,H Closed (Fe) During Cold shutdown VC-24 1/2VQ001A,B Stroke Time Test (St) During Cold shutdown 1/2VQ002A,B or as Required to Declare Operability pt\sec\ist\istrevla.wpf 3.3.1 Pg. 2 of 2
Byron 2nd Intsrval IST Plc.n Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC 1 CODE DRAWING DRAWING YALVE.NUMRIB flIE92RX EMAI L %t lB B C00RDIN6IE 1/2MS001A B 2 M 35 2 (120 2A) C4 (DS) 1/2MS001B B 2 M 35-1 (120-1) E5 (EL) 1/2MS001C B 2 M-35 2 (12 0- 2 B) E4 (D5) 1/2MS001D. B 2 M-35-1 (120 1 B5 (BL) 1/2FWOO9A B 2 M 36-1C (121-1B) C5 (C5) 1/;FWOO9B B 2 M 36-1A (121-1D) C5 (CS) '
1/2FWOOPC B 2 M-36 1D (121-1A) CS (CS) 1/2FWOO9D B 2 M-36 1B (121 1C) C5 (CS)
FUNCTIOH (S) :
1/2MS001A-D l
These are the Main Steam Isolation Valves (MSIVs). In the normally open position, steam is supplied to the turbine. The valves are required to close to isolate the main steam line to prevents reverse flow into containment during a main steam line break, Steam Generator Blowdown during a major steamline break outside of containment, and secondary system contamination from a Steam Generator tube rupture.
1/2FWOO9A-Di These are the main Feedwater Isolation Valves (FWIVs). They are open during normal operation to allow f. low to the Steam Generator (non-IST function).
They are required to close for Feedwater Isolation and Containment Isolation.
EMGTIFICATION:
The Main Steam Isolation Valves are on the outlet of the Steam Generators while the Main Feedwater Isolation Valves are on the inlet to the Steam Generators.
Closure of the Main Steam Isolation Valves during unit operation would result in a reactor trip. Failure of these valves during partial stroke testing can result in valve closure and subsequent reactor trip. NUREG 1482 states that MSIVs should not be tested at nower, since even a part-stroke exercise increases the risk 01 a v.1ve closure when the unit is generating power.
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Byron 2nd Interval IST Plc.n Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-2 CODE DRAWING DRAWING VALVE NUMBIB CATEGORY QLAda HUMB_E_.B CQQRDINATE 1/2CV8104 B 2 M-64 -4B (13 8 * ' C3 (C2) 1/2CV8442 C 2 M 64-4B(138-4A) B3 (B2) 1/2CV8804A B 2 M 64-4B (138 4 A) C7 (C7) 1/2CV112D B 2 M 64-4B(138 4A) B5 (BS) 1/2CV112E B 2 M- 6 4 - 4 B (13 8 - 4 A) A5 (AS) f_VMEIl0N (6) :
These are the emergency boration flowpath valves. The 1/2CV8104 is the emergency boration valve and the 1/2CVB442 is the emergency boration header check valve. The 1/2CV8804A is the RH heat exchanger 1A to charging pumps saction isolation valve required to be open for Post BOCA recovery. The 1/2CV112D and 1/2CV112E are the RWST to chstging pumps suction isolation valves which are in the emergency boration flowpath when the RhST is the Boration Source.
JUSTIFICATION:
The testing of any emergency boration flowpath valves during unit operation is
.not practical. Stroke testing the Boric Acid injection isolation valve 1/2CV8104 and check valve 1/2CVB442, the RH to CV pump suction isolation valve 1/2CV8804A, or the RWST to CV pump suction isolation valves 1/2CV112D/E could result in boration of the RCS, resulting in a cooldown transient. Aligning the system in this configuration even for a short duration is, therefore, unacceptable. These valves will be stroke tested during cold shutdown, in accordance with OM-10, paragraph 4.2.1.2 and 4.3.2.2.
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Byron 2nd Intwrval IST Plan '
Revision 1 L3cember, 1997 l
COLD SHUTDOWN JUSTIFICATION VC 4 CODE DRAWING DRAWING YALVE_NUMBKB CAIE22BI CLASS UVMBER C00RDINhI,5 1/2CV112B B 2 M-64-4A (138-4B) B4 (C3) 1/2CV112C .B 2- M 64-4A (138 4B) B3 (C3) 1/2CV8105 B 2 M 64 3B (138-3B) E6 (E6) 1/2CV8106 B- 2 M-64-3B (138-3B) ES (ES) 1/2CV8152 A 2 M 64 5 (138 5A) E4 (E7) 1/2CV8160 A 2 M 64-5 (138-5A) F5 (EB)
DIECT19RL&18 The 1/2CV1128 & C are the volume control tank outlet isolation / charging pump suction valves. The 1/2CV8105 and 1/2CV8106 are the normal charging path containment isolation valves. The 1/2CVB152 and the 1/2CV8160 are the letdown line containment isolation valves. These valves are part of the chemical and volume control system (CVCS).
JUBTIFIChilpH Closure of these letdown and charging makeup valves 1/2CV112B/C, 1/2CV8105, 1/2CV8106, 1/2CV9152, and 1/2CV8160 during normal unit operation would cause a loss of charging flow which would result in a reactor coolant inventory transient, and possibly, a subsequent reactor trip. These valves will be stroke time tested during cold shutdown in accordance with OM 10, paragraph 4.2.1.2 (also covers f ail-saf e tests for 1/2CV8152 and 1/2CV8160) ,
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P Byron 2nd. Intervol IST Plan Revision 1 December, 1997 C8 .,D SHUTDOWN JUSTIFICATION l VC 6 I
CODE DRAWING DRAWING YALVE NUMBIB CATEGORY CLASD NUMBEI) RQp_R,pll%IE R
1/2RC014A B 1 M-60-1B (135-1B) - F3 (F2) 1/2RC014B B 1 M 60-1B (135-1b; 23 (E2) 1/2RC014C D 1 M 60-1B (135 1B) E3 (E2) 1/2RC014D B 1 M 60 1B (135-1B) 93 (E2)
FUNCTION (Rl:
These are the reacter head vent valves and are used to vent the reactor of hydrogen or other post-accident gases. They serve as a pressure irolation valve in the closed position.
JUSTIFICAIlQHe The Reactor Pressure Vessel Vent Valves 1RC014A-D and 2RC014A D cannot be stroked during unit operation, as they provide a pressure boundary between the Reactor Coolant system and containment atmosphere. Failure of one of these valves in the open position would result in leaving only one valve as the high pressure boundary. These valves will be full stroke / fail safe exercised when the RCS pressure is at u minimum during cold shutdown, in accordance with OM-10, paragraph 4,2,1.2.
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ie Byron 2nd Interval IST plrn Revision 1 December, 1997 L
COLD SHUTDOWN JUSTIFICATION VC-7 CODE DRAWING DRAWING VfLVE NUMB _E_B QATEGORY CLASS NUMBER COORDINATE 1/2RH8730A C 2 M-62 (137 E4 (ES) 1/2RHB730D C 2 M-62 (137) C4 (CS)
FUNCTION (S):
These are the RHR pump discharge check valves. The open function of these valves is to provide an RHR pump flowpath. The closure function is to prevent back leakage while the opposite train is in question in pest-accident situations.
JUSTIFICATION:
The. Residual Heat Removal Pump discharge check valves 1RH8730A/B and s
2RH8730A/B cannot be full stroke exercised during unit operation due to the 4 RCS pressure being greater than the RH pumps are capable of putting out.
These check valves will be partial stroke tested, however, on a quarterly basis during the mini-flow recirculation LHR pump tests and full. stroke exercised during cold shutdown. This is in accordance with OM-10, paragraph 4.3.2.2.
Additions.:.ly, it would be impractical to backflow test these valves during unit operation. The methodology for testing these valves .avolves closing the mini-flow valve on the train being testad and having the opposite train provide pressure against the check valve being tested. The test'is satisfied by verifying that the pump on the sama train as the check valve is not rotating backwards. However, this testing would put the plant in an
' undesirable condition as both trains of RH would be considered inoperable.
During cold shutdowns, the train running on shutdown cooling may be used to pressurite against the opposite train's check valve. For this reason, these volves will be backflow tested during cold shutdown in accordance a:th GM-10, paregraph 4.3.2.2.
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Byron 2nd Intervol IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-8 CODE DRAWING DRAWING VALVE NUMBER CATEGORY QLASS NUMBER COORDINATE 1/2SI8818A AC 1 M-61-4 (136-4) F7 (F2) 1/2SI8818B AC 1 M-61-4 (136-4 D7 (D2) 1/2SI8818C AC 1 M-61-4 (136-4) D7 (D2) 1/2SI8810D AC 1 M-61-4 (136-4) E7 (E2) 1/2 SIB 958A C 2 M-61-4 (136-4) C4 (C7) 1/2 SIB 958B C 2 M-61-4 (136-4) B4 (B7)
FUNCTION (S):
The SIB 818 valvas are the safety injection RCS Loop 1 cold leg upstream check valves located in the flowpath from the Residual Heat Removal (RHR) pumps.
The SIB 958 valves are the safety injection RWST outlet check valves to the RHR
- pumps,
@SIIFICATIQHs Due to the high RCS pressure during unit operation (2235 psi) , these valves cannot be full or partial stroke exercised during quarterly testing. The 1/2SI8958A/B cluck valves, although located at the suction of the RHR pumps, are not in the recirculation flow path to allow partial stroking each quarter.
These valves will be full stroke exercised during cold shutdown, in accordance with OM-10, paragraph 4.3.2.2, 1
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Byron 2nd biterval IST Plan Revision 1 December, 1997 i
COLD SHUTDOWN JUSTIFICATION VC-9 CODX DRAWING DRAWING VALVE NUMBER p_ATEGORY ME.E ME EQORDINATE 1/2FWO39A B 2 M-36-1C (121-1B) C4 (C4) 1/2FWO39B B 2 M-36-1A (121-1D C4 (D4) 1/2 FWO39C D 2 M-36-1D (121-1A) C4 (D4) 1/2 FWO39D B 2 M-36-1B (121-1C) C4 (C4) 4 EUNCTION(S):
These are the steam generator feedwater preheater bypass downstream isolation valves. They provide for Feedwater/ Containment isolation in the closed position. They are normally open air operated valves located on the cross-tie linen connecting the main FW line to the tempering line.
gpSTIFICAT*.y_
It is not practical for th- 1FWO39A-D and 2FWO39A-D valves to be stroke tested during normal operation as losure of these valvus would require a power reduction from full power > less than 80%. Stroking these valves closed above 80% would result in undesirable preheater tube vibrations within the Steam Generators. These valves will be stroke time / fail safe tested during cold shutdown, in ordance with OM-10, paragraph 4.2.1.2.
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Byron 2nd Intervol 2ST Plan :
RQvision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-10 CODE DRAWING DRAWING YALVE NUMBER CATEGORY ,qLASS NUMBER COORDINATE 1 (2 ) CV4 59 B 1 M 64-5(138-5B) E7 (FS) 1 (2 ) CV4 60 B 1 M 64-5(138-5B) F8 (F7) 1 (2) CV814 9A B 2 M 64-5(138-5B) F6 (E2) 1 (2) CV814 9B B 2 M 64-5 (138-5B) F6 (E3) 1 (2) CV814 9C B 2 M 64-5(138-5B) F5 (F2)
TUNCTION(S):
CV459 & 460 valves are normally OPEN with the Unit at power, allowing letdown flow to occur. The valves auto close on low Pressurizer level and on letdown iaolation due to an interlock with the orifice isolation valves.
CV8149 Orifice Isolation Valves are interlocked with CV459/460 to Close on Phase A Containment Isolation signal. One or more of thesc valves are normally OPEN to maintain letdown flow.
ZUSTIFICATION:
It is impractical to exercise and stroke time the above listed valves on a quarterly basis. Due to the interlocks between the 459, 460, & the 8149 valves, exercising these valves during normal operation results in (multiple) total letdown flow isolation events. The affect of a letdown isolation with the Unit at power is a thermal transient to the letdown lines, heat exchangers, and other components. A letdown isolation also results in some amount of pressuriter level fluctuation until equilibrium letdown and makeup is re-established. While the piping and components are designed for thermal transients, each cycle presents some additional stress to all of the affected equipment. It is prudent to minimize the number of transients the equipment is required to undergo to prevent premature failures.
Due to the above, these valves will be tested in Cold shutdowns of sufficient duration in accordance with OM-10, paragraph 4.2.1.2.
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Byron 2nd Interval IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-11 CODE DRAWING DRAWING VALVE NUMBEB CATEGORY EMSJ NUMBER COORDINATE 1/2AF001A C 3 M-37 (122) D2 (E7) 1/2AF001B C 3 M-37 (122) B2 (B7) 1/2AF003A C 3 M-37 (122) DS (ES) 1/2AF003B C 3 M-37 (122) B5 (CS) 1/2AF029A C 3 M-37 (122) C5 (ES) 1/2AF029B C 3 M-37 (122) B5 (C4) 1/2AF014A C 2 M-37 (122) DB (D2) 1/2AF014B C 2 M-37 (122) AB (B2) 1/2AF014C C 2 M-37 (122) E8 (E2) 1/2AF014D C 2 M-37 (132) B8 (C2) 1/2AF014E C 2 M-37 (122) DB (E2) 1/2AF014F C 2 M-37 (122) B3 (B2) 1/2AF0140 C 2 M-37 (322) E8 (F2) 1/2AF014H C 2 M-37 (122, CB (D2)
EEMETION(S1 f; The AF001 valves are the AFW pump suction check valve from the condensate storage tanks. The AF003 valves are the AFW pump discharge check valves. The AF029 valves are the AFW pump header check valves downstream to the mini-flow recirculation line. The AF014 valves are the individual header check valves to the steam generato s.
All these valves are required to open to provide a flowpath to the Steam Generators.
Also covered in this cold shutdown justification is the closure function for the 1/2AF014A-H valves. These valves are required to close in order to prevent Eteam Generator inventory loss, prevent steam binding of the AFW pumps, and provide containment isolation during a steam generator tube rupture.
JUSTIFICATION:
The Auxiliary Feedwater check valves 1/2AF001A/B, 1/2AF003A/B, 1/2AF014A-H, and 1/2AF029A/D cannot be full stroke tested during unit operation, as this would induce potentially damaging thermal stresses in the upper feedwater nozzle piping. The 1/2AF001A/B and 1/2AF003A/B valves will be partially '
stroke tested during operation, and all valves full stroke tested during cold shutdown, in accordance with OM-10, paragraph 4.3.2.2.
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l-Byron 2nd Interval IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-11 (continued)
Check valves 1/2AF014A H are veritied to be closed each-shift by the Operating Department, by verifying that the temperature at 1/2AF005A-H is s 130*F, per BOP 199-EA Al and BOP 199-EA A2. If the temperature is > 130*F at any
- 1/2AF005 valve, then abnormal operating procedure 1/2 BOA SEC-7, " Auxiliary Feedwater Check Valve Lcakage", .s entered to isolate and cool down the affected lines. This shiftly monitoring of 1/2AF014A-H in the closed position-adequately monitors the status of these valves during unit operation.
However, at the NRC's request, the official IST backflow test will be performed following the full flow test during cold shutdowns in the same procedure, in accordance with OM-10, paragraph 4.3.2.2.
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Byron 2nd Interval IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-12 CODE DRAWING DRAWING VALVE NUPSEE CATEGORY CLASS. NUMBER COORDINATE 1/2 SIB 801A B 2 M-61-2 (136-2) D3 (D6) 1/2 SIB 801B. D' 2 M-61-2 (136-2) C3 (C6)
FUNCTION (S):
These are the charging pumps to RCS cold leg isolation valves. They are required to open to provide a flow path for the high head safety injection portion of ECCS, They are required to close for containment isolation, JUSTIFICATION:
The High Head Injecticn Isolation Valves 1SI8801A/B and 2SI8801A/B cannot be stroke tested during unit operation. These valses isolate the CV system from the RCS, Opening them during operation would enable charging flow to pass directly into the RCS, bypassing the regenerative heat exchanger, _ The temperature difference of the charging flow and the RCS could result in damaging thermal stresses to the cold leg nozzles as well as cause a reactivity change which would, in turn, cause a plant transient. These valves will be stroke time tested during cold shutdown in accordance with OM-10, paragraph 4.2.1.2 p:\sec\ist\istrevia.wpf 3.3.2 Pg. 13 of 28
Byron 2nd Interval IST Plcn Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-13 CODE DRAWING DRAWING YALyg NUMB,El CATEGORY QMER NUMBER COORDINATE 1/2S 'A B 2 M-61-3 (136-3) E3 (E6) 1/2SledO2B B 2 M-61-3 (136-3) D3 (D6) 1/2 SIB 806 B 2 M-61-1A (136-1) D2 (C6) 1/2 SIB 009A B 2 M-61-4 (136-4) E4 (ES) 1/2SI8809B B 2 M-61-4 (136-4) D4 (DS) 1/2 SIB 013 B 2 M-61-1B (136-1) D7 (E4) 1/2SI8835 B 2 M-61-3 (136-3) C4 (C5)
J/2SIH840 B 2 M-61-3 (136-3) B4 (BS)
FUNCTIQN (S) :
The SIB 002 valves are the Safety Injection to the Reactor Coolant System (RCS) hot leg (1A/1D, 18/1C) isolation valves. The SI8806 valves are the A and B train SI pump suction isolation valves from the RWST. The SIB 809 valvea are the Residual Heat Removal (RHR) pumps to RCS cold leg isolation valves. The <
SIB 813 valves are the SI pumps common mini-flow recirculation isolation valves. The SIB 835 valves are the SI pumps cold leg isolation valves. The SI8840 valves are the RHR to RCS hot legs 1A/1D isolation valves.
JUSTIFICATION:
The safety injection system SVAG (Spurious Valve Actuation Group) valves 1/2SI8802A/B, 1/2SI8806, 1/2 SIB 009A/B, 1/2SI8813, 1/2SI8835, and 1/2SI8840 cannot be stroke tested during unit operation. These valves are required by Technical Specification 4.5.2 to be de-energized in their proper positions during unit operation. Stroking them would be a violation of the Technical Specifications as well as defeating the de-energized SVAG valve principle, These valves will be stroke tested during cold shutdown when they are not required to be de-energized. This is in accordance with OM-10, paragraph 4.2.1.2.
p:\sec\ist\istre -f 3.3.2 Pg. 14 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUETIFICATION VC-14 CODE DRAWING DRAWING VALVE NUMBER CATEGORY CLASS NUMBER COORDINATE 1/2RY455A B 1 M- 6 0- 5 (13 5 - 5) C8 (CB) 1/2RY456 B 1 M-60-5(135-5) DB (DB)
TUNCTION(S):
Pressurizer Power Operated Relief Valves are required to open for low temperature overpressure protection. The closed function is for pressure isolation.
@STIFICATION:
PORV's 1/2RY455A and 1/2RY456 will be stroke / fail safe tested on a cold shutdown frequency per Generic Letter 90-06. This recommendation comes from Enclosure A to Generic Letter 90-06, which addresses the NRC staff positions concerning PORV and Block Valve Reliability. Item number 3.1.2 states that the "Stcoke testing of PORVs should only be performed during mode 3 (HOT STANDBY) or mode 4 (HOT SHUTDOWN) and in all cases prior to establishing conditions where the PORVs are used for low-temperature overpressure protection. Stroke testing of the PORV's should not be performed during power operation." For this reason, these valves will be stroke time tested / fail-safe tested during cold shutdowns in accordance with OM-10, paragraph 4.2.1.2 and Generic Letter 90-06, p:\sec\ist\istrevla.wpf 3.3.2 Pg. 15 of 28
3yron 2nd Interval IST Plan Revision 1 December, 1997
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COLD SHUTDOWN JUSTIFICATION NUMBER:
VC-15 CODE DRAWING DRAWING VALVE NUMBER CATEGORY CLASS NUMBER COORDINATE 1/2RH8701A A 1 M-62(M-137) El (E7) 1/2Rh8701B A 1 M-62(M-137) El (EB) 1/2RH8702A A 1 M-62(M-137) C1 (C7) 1/2RH8702B A 1 M-62(M-137) C1 (C8) 1/2RH8705A AC 2 M-62(M-137) D1 (DB) 1/2RH8705B AC 2 M-62(M-137) C1 (C8) 1/2SI8815 AC 1 M-61-2(M-136-2) DS (D4) 1/2SI8818A AC 1 M-61-4(M-136-4) F7 (F2) 1/2SI8818B AC 1 M-61-4(M-136-4) D7 (D2) 1/2 SIB 818C AC 1 M-61-4(M-136-4) D7 (D2) 1/2SI8818D AC 1 M-61-4(M-136-4) E7 (E2) 1/2SI8819A AC 1 M-61-3(M-136-3) A5 (B4) 1/2SI8819B AC 1 M-61-3(M-136-3) A7 (B2) 1/2 SIB 819C AC 1 M-61-3(M-136-3) A6 (B2) 1/2SI8819D AC 1 M-61-3(M-136-3) A6 (B3) 1/2SI8841A AC 1 M 3 (M- 13 6 - 3 ) E4 (E4) 1/2 SIB 8418 AC 1 M-61-3(M-136-3) C7 (C2) 1/2SI8900A AC 1 M-61-2 (M- 13 6 -2) E7 (E2)
-1/2SI8900B AC 1 M-61-2(M-136-2) D7 (D2) 1/2SI8000C AC 1 M-61-2(M-136-2) C7 (C2) 1/2 SIB 900D AC 1 M-61-2(M-136-2) B7 (B2) 1/2 SIB 905A AC 1 M-61-3(M-136-3) E4 (E4) 1/2SI8905B AC 1 M-61-3(M-136-3) D7 (D2) 1/2SI8905C AC 1 M-61-3(M-136-3) C7 (C2) 1/2 SIB 905D AC 1 M-61-3(M-136-3) E4 (ES) 1/2SI8948A AC 1 M-61-5(M-136-5) B7 (B2) 1/2 SIB 948B AC 1 M-61-5(M-136-5) B4 (BS) 1/2SI8948C AC 1 M-61-6(M-136-6) AB (B1) 1/2 SIB 94BD AC 1 M-61-6(M-136-6) A5 (B4) 1/2SI8949A AC 1 M-61-3(M-136-3) EB (E1) 1/2SI8949B AC 1 M-61-3(M-136-3) D8 (D1) 1/2SI8949C AC 1 M 3 (M- 13 6 - 3 ) C8 (C1) 1/2SI8949D AC 1 M-61-3(M-136-3) E8 (E1) 1/2 SIB 956A AC 1 M- 61-5 (M- 13 6 - 5) B7 (B3) 1/2 SIB 956B AC 1 M 5 (M- 13 6 - 5) B4 (B6) 1/2 SIB 956C AC 1 M-61-6 (M-136 6) A8 (B2) 1/2 SIB 956D AC 1 M-61-6(M-136-6) A5 (B4) p \sec\ist\istrevla.wpf 3.3.2 Pg. 16 of 28
Byron 2nd Interval IST Plnn Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION:
VC-16 CODE DRAWING DRAWING VALVE NUMBER CATE00Ri QLASS' NUMBER Q,00RDINATE 1/2CV8440 C 2 M-64-4B(M-138-4B) F6 (DS)
FUNCTION (S):
These check valves allow flow f rom the Volume Control Tank (VCT) to the suction of the CV pumps. During the injection phase of an accidene, these.
valves prevent pump deadheading by allowing a pump mini-flow flow path.
During the hot leg recirculation phase of a safety injection, these valves close to prevent diversionary flos back to the VoT via the seal water heat exchanger relief valve, which could potentially lead to an unfiltered release of radioactivity to the environment. The closed function is the subject of this cold shutdown justification.
/
JUSTIFICATION:
These valves may only be tested closed during cold shutdowns, when all 4 RCPs
(- and charging pumps are off. Isolation at power would isolate flow to the auction of the CV pumps, which, in turn would isolate charging flow and flow to the RCP seals. Refer to CHRON #0117821, dated November 23, 1992. Closure testing of these check valves will be performed during cold shutdowns, using non-intrusive techniques (as conditions allow), in accordance with OM-10, paragraph 4.3.2.2.
pt\sec\ist\istrevla.wpf 3.3.2 Pg. 18 of 28 l
Byron 2nd Interval IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-19 CODE DRAWING DRAWING VALVE NUMBER CATEGORY CLASS NUMBER COORDINATE 1/2CC685 A 2 M-66-1A(M-139-1) B4 (B6) 1/2CC9413A A 2 M- 6 6 - 1A (M-13 9 -1) E3 (E7) 1/2CC9414 A 2 M- 6 6 - 1 A (M- 13 9 - 1) A4 (B6) 1/2CC9415 B 3 M-66-4D C6 (C3) 1/2CC9416 A 2 M 66-1A(M-139 1) A6 (B6) 1/2C09438 A 2 M 1A (M-13 9 1) B6 (B6) 1/2CV8100 A 2 .
M-64-2(M-13P-2) F1 (F1) 1/2CV8112 A 2 M-64-2u* ;.,8-2)
F2 (F2)
FUNCTION (S) :
Motor Operated Valves 1/2CC685 and 1/2CC9438 are located on the Component Cooling return line from the Reactor Coolant Pump (RCP) thermal barrier cooling coils. The safety function of these valves in the closed direction is to provide a leak-tight barrier between the containment atmosphere and the environment during post accident conditions after a postulated rupture of the thermal barrier heat exchanger. The function of these valves in the open
-direction is to provide Component Cooling water return from the Reactor Coolant Pump thermal barriers.
Motor Operated Valves 1/2CC9413A are located on the Component Cooling supply line to the Reactor Coolant Pumps (RCPs). The safety function of these valves in the closed direction is to provide a leak-tight barrier between the containment atmosphere and the environment during accident conditions. The open function of th se valves is to supply Component Cooling water to the Reactor-Coolant Pumps.
Motor Operated Valves 1/2CC9414 and 1/2CC9416 are located on the Component Cooling return lit.: from the Reactor Coolant Pump (RCP) upper and lower motor bearing coolers. The safety function of these valves in the closed direction is to provide a leak-tight barrier between the containment atmosphere and the environment during accident conditions. The open function of these valves is to provide Component Cooling water return from the Reactor Coolant Pumps upper and lower motor bearing coolers.
Motor Operated Valves 1/2CC9415 are in the supply line to the RCPs and other non-essential Component Cooling Water loads. They close to isolate non-essential loads from essential loads during accident conditions.
Additionally, these valves may need to be reopened to cool the Excess Letdown HX to maintain control of pressurizer level during a post accident scenario, p:\sec\ist\istrevla.wpf 3.3.2 Pg. 21 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-19 (continued)
Motor Operated Valves 1/2CV8100 and 1/2CV8112.are located in the Reactor Coolant Pump seal water return lines. The safety function of these valves in the closed direction is to provide a leak-tight barrier between the containment atmosphere and the environment during accident conditions. The open function of these valves is to permit seal water return flow from the Reactor Coolant Pumps to the seal water heat exchanger.
JUSTIFIch7 ION:
These valves cannot be stroked during normal operations because they would isolate flow to the Reactor Coolant Pumps. Failure of one of the CC valves in a closed position during an exercise test would result in a loss of cooling flow to the pumps and eventual pump damage and/or trip. Failure of a CV valve in the closed direction would result in seal water return flow being diverted to the Pressurizer Relief Tank (PRT) by lifting a relief valve (1/2 CV8121) upstream of the isolation valves. Therefore, these valves will be stroke tested during cold shutdowns, provided all of the RCPs may be shutdown (and seal leek-off may be isolated for 1/2CV8100 and 1/2Cv8112), in accordance with OM-10, paragraph 4.2.1.2. This test frequency wil'. adequately maintain these valves in a state of operational readiness by testing them as often as safely possible.
p:\sec\ist\istrevla.wpf 3.3.2 Pg. 22 of 20
Byron 2nd Interval IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-20 CODE DRAWING DRA1,ING yhLVE NUMBEB pATEGORY CLAS_S NUMBER -COORDINATE 1/2FWO36A C 2 M-36-1C(M-121-1B) E3 (E3) 1/2FWO36B C ? M-36-1A(M-121-1A) E3 (E3) 1/2FWO36C C 2 M-36-1D(M-121-1C) E3 (E3)
- 1/2 FWO36D C 2 M-36-1B(M-121-1C) E3 (E3)
FUNCTION (S):
The feedwater tempering flow check valves (1/2FWO36A-D) are open during full /high power operation to ensure the S/G upper nozzle subcooled margin is maintained above the 75*F minimum. They also open to allow tempering flow during shutdown and startup. The IST fuaction is to close to provide an immediate isolation during a feedwater line break accident to mitigate a loss of secondary make-up and/or inventory.
JUSTIFICATION __t_
The 1/2FWO36A-D are 3" swing type check valves with no position indication.
Flow through this line at full /high power cannot be stopped for longer than one minute while in mode 1. Also, flow / pressure is always toward the Steam Generators during operation, making it impractical to perform a back leakage or back_ pressure test to prove valve closure. These check valves will be tested during cold shutdowns using non-intrusive techniques to prove valve closure in accordance with OM-10, paragraph 4.3.2.2.
p:\sec\ist\istrevla.wpf 3.3.2 Pg. 23 of 2B
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i Byron 2nd Interval IST Plcn Revision 1 l
December, 1997 COLD SirJTDOWN JUSTIFICATION VC-21 CODE DRAWING DRAWING VALVE NUMBER CATEGQEX CLASS NUMBER COORDINATE 1(2)SI8808A B 1 M 61 (13 6 ) - 5 C6 (C3) 1(2)SI8808B B- 1 M 61(136) -5 C4 (C6) 1(2) SIB 808C B 1 M 61(136)-6 C7 (D2) 1(2)SI8808D B 1 M 61(136)-6 C5 (D4)
LUNCTION ( S)_ :
The 1/2 SIB 808A-D valves are Motor Operated Safety Injection Accumulator Discharge Isolation Valves. These valves are OPEN with Power Removed for Modes 1, 2, and 3 with Pressurizer Pressure above 1000 psig.
These valves were included in the IST Program for their need to be closed after all of the water in the Accumulator has been injected into the RCS, Closure of these valves would prevent injection of a Nit *; ogen bubble into the RCS. These valves are included in the IST Program for testing in both OPEN and CLOSED directions.
JUSTIFICATION:
Technical Specification 3/4.5.1.a requires "The (Accumulator) isolation valve open and power removed." while in Modes 1, 2 or_3 (with pressurizer pressure above 1000 psig).
Since the Technical Specifications require these valves to be OPEN with power to their motor operators removed during periods when pressurizer pressure is above 1000 psig, the valves cannot be exercised every three mt .hs . In lieu of stroke time testing the valves every three months, these valves will be tested during heatup or cooldown (the pressure transition between 800 and 1000 psig pressurizer pressure) or, they will be tested with the RCS depressurized and the associated accumulator vented and drained. This cold shutdown testing frequency is in accordance with OM-10, paragrcph 4.2.1.2.
p:\sec\ist\istrevla.wpf 3.3.2 Pg. 24 of 28 i
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Byron 2nd Interval IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-22 CODE DRAWING DRAWING VJbVE NUMBER CATEGOM CLASS NUMBER COORDINATE 1(2 ) CVa 355A B 2 M 64 (138)-1 B8 (B8) 1 (2) CV8 3 55B B 2 M 64 (138)-1 B4 (B4) 1 (2) CV8 355C B 2 M 64 (138) -2 BB (BB) 1 (2) CV83 55D B 2 M 64 (138) -2 B5 (BS)
LUNCTION(S):
The CVB355 valves are Motor Operated Isolation valves in the seal injection line to the Reactor Coolant Pumps. Additionally, the CV835Ss are designated Containment Isolation valves but are exeti; t from Local Leth Rate Testing of 10 CFR 50, Appendix J. The C"' . s have no automatic closure function as part of Containment Isolation.
JMRIIPICATION -
Reactor Coolant Pumps (RCPs) are required to be in operation in Mode 1, Power Operation. Seal injection flow must be maintained when the RCPs are running.
Interruption of seal injection flow with the RCPs in operation, even for a short duration, is detrimental to the RCP seals. The above lasted valves are Seal Injection Inlet valves and are designated Containment Isolation valves
'(CIVs).
The 1/2CV8355A-D valves are exempt from Local Leakage Rate testing of 10 CFR 50, Appendix C, but due to their designation as CIVs, they will be tested per ASME Code in the Closed direction. Due to tae above, these valves will not be exercised during plant operation, but they will be exercised during-Cold Shutdown WHEN THE RCPs ARE NOT RUNNING. Short duration forced outages to Cold Shutdown seldom require shutdown of RCPs as they are part of the normal heat removal loop. It is NOT the intent of this justification to require RCP shutdown only to perform the exercise tests for these valycc. IC is anticipated that these valves may not normally be tested more often than once per refueling outige. However, these valves will be tested during cold shutdowns in which the RCPs are secured for sufficient time to perform the tests, which is in accordance with OM-10, paragraph 4.2.1.2.
p:\sec\ist\isteevla.wpf 3.3.2 Pg. 25 of 28
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Byron 2nd Interval IST Plen Revision 1 December, 1997 COLE SHUTDOWN JUSTIFICATION NUMBER VC-23 CODE DRAWING DRAWING YALVE NUMBER CATEGORY CLASS NUMBER COORDINATE ISD054A B 2 M 48-5A D8 111)SD054B B 2 M 48-5A(5B) D7 (DB)
{
1SD054C D 2 M 48-5A D6 1(2)SD054D D 2 M 48-5A(5B) D6 (D6) 1SD054E B 2 M 48-5A D5 1(2)SD054F B 2 M 48-5A(5B) D4 (D4)
ISD054G B 2 M 48-5A D3 1(2)SD054H B 2 M 48-5A(5B) D2 (D2)
FUNCTION (S):
The SD054 valves are normal Steam Generator Blowdown throttle control valves.
An additional function of the Unit 1, (A through H valves) and the Unit 2, (B train valves (B, D, F, & H]) is to isolate Blowdown for High Energy Line Break (HELB).
JUSTIFICATION:
It is impractical to exercise and stroke time the above listed valves on a quarterly basis. The valves have no Open / Closed handswitch. They are normally operated by means of a potentiometer which ultimately controls an air signal to a positioner. Attainment of repeatable stroke time results requires the valves to be stroked by causing (or simulating) HELB relay actuation. This method of closure causes multiple valve actuations resulting in complete steam generator blowdown isolation. Furthermore, the remote position indicator, (a 0-100% indicator - not based on limit switch operation) may lag actual valve position. Therefore the only repeatable rethod of stroke timing these valves involves stationing personnel locally at
- the valve (s) - to witness actual valve movement.
Full stroke exercising the valves is a Unit operation concern in that closure of-these valves during normal operation presents a thermal transient to the downstream piping and components including the blowdown condenser. While the valves, piping, and components are designed to withstand this thermal transient, each transient produces stress which may lead to premature failure of the affected components. It is prudent to minimize the number of thermal transients that these high energy lines are required to undergo.
p \sec\ict\istrevia.wpf 3.3.2 Pg. 26 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 COLD SHUTDOWN JUSTIFICATION VC-23 (continued)
Personnel safety concerns exist wich this stroking exercise during normal operation in that the valves are physically located in the Main Steam Isolation (MSIV) Valve House. This room contains the MSIVs, Feedwater Isolation Valves (FWIVs), Main Steam Safety Valves, Main Steam PORVs, and other miscellaneous piping and valves. The normal ambient temperature in this room with the Unit at power is greater than 110 'F. Almost all of the piping (most of which is insulated) and instrument tubing in the room are normally at temperatures of approximately 500 *? or more. The SD054 valves are located above the floor some 16 to 20 feet and are not visible from the floor being obscured by Main Steam and Feedwater Piping. Since personnel must be stationed locally at'the valve to witness actual valve movement, it is necessary to climb around very hot piping in a hot and very noisy ambient atmosphere. In some cases it may be necessary to erect scaffolding to conduct this test with the Unit in normal operation.
Due to the above, these valves will be stroks time / fail safe tested during Cold shutdowns of sufficient duration to allow safe access to the valves, including the erection of scaffolding, if required. This testing frequency is in accordance with OM-10, paragraph 4.2.1.2.
p:\sec\ist\istrevia.wpf 3.3.2 Pg. 27 of 28 l
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Byron 2nd Interval IST plan Revision 1 Decembe*, 1997 ,
COLD SHUTDOWN JUSTIFICATION VC-24 CODE DRAWING DRAWING VALVE NUMBER CATEGOEX CLASS NUMBER QOQRDINATE 1/2VQ001A A 2 M-105-1 (M-106-1) ES (ES) 1/2VQ001B A 2 M-105-1 (M-106-1) E6 (E6) 1/2VQOO2A A 2 M-105-1 (M 106-1) E4-(E4)
.1/2VQOO2B A 2 M-105-1 (M-106-1) E3 (E3)
FUNCTION (S) :
The 1/2VQ001A/B valves are the containment purge supply isolation valves.
The 1/2VQ002A/B valves are the containment purge exhaust isolation valves.
They were designed to purge 7ntainment under normal shutdown conditions. The IST function of closure is for containment isolation.
JUSTIFICATIOH1 The Primary containment Purge supply and Exhaust Valves, 1/2VQ001A/B and I 1/2VQ002A/B, cannot be stroke time tested during unit operation. These 48-inch valves are the only isolation points between the containment atmosphere and the environment. Stroking these valves at any time other than modes 5 or 6_ would be a violation of Byron Technical Specification 3.6.1.7 (a) . in which it states that in modes 1-4, the valves "..shall be closed and power removed."
Administrative 1y, these valves are maintained Out of Servics Closed.
As a containment isolation valve, the clorure function is considered to be operable. The valves are leak tested in accordance with Appendix J and a monthly verification is performed to verify that these valves are closed and power is removed. The monthly verification is completed by verifying the closed indication of the Group 6 monitor lights in the control room and that each power supply is off. However, if re-positioning thir valve is necessary and the valve needs to be considered operable in association with exercising capabilities cf it, then the IST stroke time testing and remote position indication testing will be completed prior to declaring the valve operable per OM-10, paragraph 4.3.2.5. It is anticipated that the necessary stroke time testing of these valves will be very infrequent, if at all, it. the future.
TEST FREQUENCY:
The 1/2VQ001A/B and 1/2VQ002A/B es will ne stroke time tested during cold shutdowns, as necessary, to declar the valve exercising capabilities operable, in accordance with OM-10, para.t. 4.2.1.2 and 4.3.2.5.
pi\sec\ist\istrevla.wpf 3.3.2 Pg. 28 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 t
SECTION 3.4 VALVE REFUELING OUTAGE JUSTIFICATIONS p.\sec\ist\istrevla.wpf
Byron 2nd Interval IST Plen Revision 1 December, 1997 3.4.1 Valve Refueling Outage Justification Summary Hymhet- Component Description ROJ-1 OSX143A/B Backflow Test (Bt) during Refueling Outages (U-1 and U-2) l ROJ 1/2 SIB 948A-D; Full Stroke Test (Ct) - during 1/2 SIB 956A-D Refueling (verified with Sampling Acoustic Testing),
and Partial Stroke. Test (Xt) of 1/2 SIB 948A-D during Cold Shutdown (see VC-3 7)
ROJ-3 1/2CC9456; 1/2CC9459A/B; All Valves Manually Stroke 1/2CC9467A-C Tested (St)in preparation /
during each M11 Refueling.
ROJ-4. 1/2 SIB 811A/B Stroke Time Tested (St) during Refueling ROJ-5 1/2IA065; 1/2IA066; Stroke Time Test (St) and Fail 1/2IA091 Safe Test Closed (Fc) of 1/2IA065 and 1/2IA066 during Refueling, and Full Stroke Test (Ct) of 1/2IA091 during Refueling ROJ-6 1/2 SIB 819A-D;
}j All Valves Full Stroke Tested 1/2SI8905A-D; (Ct) during Refueling, and the 1/2 SIB 922A/B; 1/2 SIB 926 Valves are Partial 1/2 SIB 926; 1/2SI8949B,D Stroke Tested (Xt) Quarterly ROJ-7 1/2CVB481A/B; 1/2CV8546; All Valves Full Stroke Tested 1/2 SIB 815; (Ct)'during Refueling, and the 1/2 SIB 900A-D 1/2CVB481A/B Valves are Partial Stroke Tested (Xt)
Quarterly.
ROJ-8 1/2SI8841A/B; Full Stroke Test (Ct) during 1/2SI8949A,C Refueling ROJ-9 1/2RH8705A/B Full Stroke Test (Ct) during Refueling ROJ-10 1/2FP345 Backflow Test (Bt) during Refueling 4 ROJ-11 1/2CV8348 Backflow Test (Bt) during Refueling ROJ-12 1/2CV8368A-D Backflow Test (Bt) during Refueling p:\sec\ist\istrevla.wpf 3.4.1 Pg. 1 of 2
I Byron 2nd Interval IST Plan Revision 1 December, 1997 3.4.1 Valve Refueling Outage Justification summary (continued)
Number component Description ROJ-13 1/2CC9495A-D Backflow Test (Bt) during Refueling ROJ 14- 1/2FW510A; 1/2FW520A; Augmented Fail-Safe Test 1/2FW530A; 1/2FW540A; Closed (Fc) during Refueling 1/2FW510; 1/2FW520; per Byron Technical 1/2FW530; 1/2FW540; Specifications 1/2 FWO34 A-D ROJ-15 1/2CC9486; 1/2CC9518; Backflow Test (Bt) during 1/2CC9534; 1/2CS008A/B; Refueling 1/2CS008A/B 1/2CV8113; 1/2IA091; 2PR002G; 1/2PR002H 1/2PR032; 1/2PS231A/B; 1/2RY8046; 1/2RY8047; 1/2 SIB 968; 1/2WM191; 1/2WOOO7A/B 1/2CC9518; 1/2CC9534; Full Stroke Test (Ct) during 1/2CV8113 Refueling ROJ-16 1/2CV8546; Backflow Test (8t) during 1/2SI8926 Refueling I
e 6
p:\sec\ist\istrevla.wpf 3.4.1 Pg. 2 of 2
Byron 2nd Interval IST Plan Revision 1 December, 1997 RETUEI,ING OUTAGE JUSTIFICATION RoJ-1 CODE DRAWING DRAWING VALVE NUMBER CATEGORY CLASS NUMBER COORDINATE OSX143A/B BC 3 M-42-6 B2 (B4)
I rUNCTIoN (S) :
OSX143A.B: Thase valves are the Circ Water Pump Makeup Discharge Check Valves, which are in the flowpath to the Essential Service Water Cooling Towers.
These check-valves are required to close to prevent backflow into_the Circ Water Makeup (non-safety) supply line to the SX towers. These valves are located at the safety related/non-safety related boundery.
JUSTIFICATION:
The OSX143A/B check valves were thoroughly investigated for possible closure l testing, and it was determined that the only way to determine closure would be through nonintrusive techniques. Traditional methods of measuring leakage, etc. were not possible. The initial' testing on these valves occurred in March of 1995 (prior to the end date of B2R05). Initially, acoustic testing was investigated using various system lineups with limited results. Alternate testing methods, which would establish future repeatable tests, were investigated. Both radiography ar.d UT testing were attempted. UT testing produced a weak backwall signal and is inadequate at this time. Radiography produced the most conclusive test results concerning valve closure.
Subsequent test results with radiography have confirmed that it is the most conclusive and repeatable.
Performing the radiograpny on these valves requires the use of nucside contractor personnel. This is costly and impractical to perform on a quarterly basis or cold shutdown frequency. It is much more practical and less costly to perform the radiography on these valves during refueling outages, when radiography crews are available and on site performing other radiography associated with the refueling outage. This justification for deferral of testing to refueling is in accordance with OM-10, paragraph 4.3.2.2 4
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Byron 2nd Interval IST Plan Revision 1 Decunbe r, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-1 (continued)
TEST FREQ2ENCYt The OSX143A/B backflow radiography tests will be completed during each l refueling outage (U-1 and U-2)in accordance with OM 10, paragraph 4.3.2.2.
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Byron 2nd Interval IST Plan Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-2 CODE DRAWING DRAWING J
V LVE NUMBER QATEGORY CLASS NUMBER COORDINATE 1/2 SIB 948A AC 1 M 61-5(M-136-5) B7 (B2) 1/2 SIB 948B AC 1 M 5 (M- 13 6 - 5) B4 (BS) 1/2SI8940C AC 1 M-61-6(M-136-6) AB (B1) 1/2SI8948D AC 1 M-61-6(M 136-6) A5 (B4) 1/2 SIB 956A AC 1 M-61-5(M-136-5) B7 (B3) 1/2 SIB 956B AC 1 M 5 (M-13 6 - 5) B4 (B6) 1/2 SIB 956C AC 1 M-61-6(M-136-6) A8 (B2) 1/2 SIB 956D AC 1 M-61-6(M-136-6) A5 (B4)
ZyHgTlnN(S) :
The 1/2SI8948A-D and 1/2 SIB 956A-D check valves are located inside the containment building miss_le barrier on the lines from the accumulator tanks to the Reactor Coolant System (RCS) cold legs. These 10" check valves have safety functions in both the open and closed directions. This Refueling Outage Justification will address the check valve open test only. The open direction function of these check valves is to permit the injection of boratec*
water into the reactor vessel cold legs during the passive injection phase of a safety injection.
JUSTIFICATION:
Check valves 1/2 SIB 956A-D cannot be full or partial tested during unit operation due to the pressure differential between the accumulators (650 psig) and the reactor coolant system (2235 psig). Full or partial stroke exercising of these valves could occur only with a rapid depressurization of the reactor coolant system.
Check valves 1/2SI8948A-D cannot be full or partial stroke tested during unit operation without depressurizing the RCS to 1600 psig (to stroke using Safety Injection pumps) or to 200 psig (to use the Residual Heat Removal pumps) .
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1 Byron 2nd Interval IST PlGn Revision 1 December, 1997 I
REFUELING OUTAGE JUSTIFICATION ROJ-2 (continued)
Full stroking these valves during cold shutdowns, routine or forced, would impose hardship with no compensating increase in plant safety. To perform this test, .e reactor coolant system (RCS) must be at approximately 40 psi with all 4 reactor pumps (RCPs) off End accumulator pressure at approximately 100 psi over RCS pressure. The full stroke test is accomplished by opening the flowpath to the RCS by stroking the respective SIB 800 valve open, and then closed. During this aburping" of the accumulators, strip chart recorders are
-used to obtain data that will be used to calculate the pressurizer level increase with time and verify that the flow that passed through the respective SIB 956 and SI8948 check valves is greater than a calculated full flow value for the check valves. In addition, nonintrusive testing, which has proven the full stroke for each valve in the past, is performed on one valve frcm each group, consistent with NUREG 1482, section 4.1.2 (this also eliminates high radiation exposures associated with the nonintrusive testing of all valves),
t A concern with testing is that at or near end-of-core life, the boron concentration of the RCS is low compared to the approximate 2000 ppm concentration of the accumulators. This injection test requires that
.approximately 8 thousand gallons of this boron concentrated water be injected into the RCS. This would result in a considerable increase in the boron concentration of the RCS. The feed and bleed process required to restore desired RCS boron concentration would result in considerable increases in restoration time and in amounts of radioactive water-rejected from the site.
The partial stroke exercising of the 1/2 SIB 948 valves will be completed during cold shutdowns using the RH or SI pumps since there are alternate flowpaths available and it can be done with little or no ef fect on the RCS system (see VC-17). Partial stroking of the 1/2 SIB 956 valves will not be completed during cold shutdowns because the same test methodology used for the full stroke test would be required to perform the partial test.
This justification is consistent with OM-10, paragraph 4.3.2.2, in which deferral of testing to refueling is allowed without relief.
TEST FREQUENCY:
Byron Station will full stroke exercise (CT) the 1/2 SIB 948A-D and 1/2 SIB 956A-D chec't valves during each respective -U-1 or U-2 refueling outage and partially
- s. stroke the 1/2 SIB 948 valves during cold shutdowns (See VC-17) in accordance with OM-10, paragraph 4.3.2.2 pi\sec\ict\istrevla.wpf 3.4.2 Pg. 4 of 33
Byron 2nd Interval T.ST Plcn Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-2 (continued)
The ISIB948A-D, 1 SIB 956A-D, 2SI8948A-D, and 2 SIB 956A-D valves each represent their own sampling group since each set of valves are of the same size, model number and system function. Under the sampling program, one valve will be nonintrusively tested per group (one SIB 948 valve and one SIB 956 valve per outage), on a rotating schedule, while the balance of the plant groups will be flow tested with less than accident flow. If a problem is fouad with the nonintrusively tested valve, then the remaining three valves in that particular group will be checked using nonintrusives during the same outage. '
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Byron 2nd Interval IST Plan Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-3 CODE DRAWING DRAWING VALVE NUMBEB QATEGORY CLAS_,1 NUMBER COORDINATE 1/2CC9458 B 3 M-66-3B C6 (C3) 1/2CC9459A B 3 M-66-3A D6 (D3) 1/2CC9459B B 3 M 66-3A DS (D4) 1/2CC9467A B 3 M-66-4D C6 (C3) 1/2CC9467B B 3 M-66-4D C5 (C3) 1/2CC9467C B 3 M-66-3B D6 (D2)
FUNCTION (S ) i 1/2CC9458: CC pump Discharge Header Manual Isolation Valves which may provide for train separation in a post accident situation.
1/2CC9459A: CC Pump Suc:. ion Header Crosstie Manual Isolation valves which may provide for separation / isolation of the CC system into two redundant trains during recirculation phase of RHR operation during a LOCA and other applicable accident modes.
1/2CC9459B: CC Pump Suction Header Crosstie Manual Isolation valves which may provide for separation / isolation of Unit 1 and Unit 2 CC systems during normal cooldown and recirculation phase of RER operation.
1/2CC9467A CC heat exchanger Outlet Header Crosstie Manual Isolation Valves which provide for possible manual isolation of flow to the unit normal plant loads if-the respective CC9415 valve fails open.
1/2CC9467B: CC Heat Exchanger Header Crosstie Manual Isolation Valves which may provide for train separation while the tubject unit undergoes Post LOCA cooldown. Provides separation / isolation of Unit 1 and Unit 2 CC systems during normal cooldown and recirculation phase of RHR operation.
1/2CC9467Ci CC Supply Header Crosstie Manual Isolation Valve which may need to be called upon due to a single failure within the CC system configuration.
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Byron 2nd Interval IST Plc.n Revision 1 December, 1997 REFUELING OUTAGE JUST2'2 CATION ROJ-3 (continued)
JUPTIFICATIONt i
General Informatient In general, the 1(2)CC9459B and 1(2)CC9467B CC manual valves are safety '
significant valves that belong in the IST Program, as identified in the Region III NRC Inspection Report, dated February 18, 1994. This refueling outage justification will address these valves in great detail. The remaining valves in this refueling outage justification (CC9458, CC9459A, CC9467A,B) are much less significant within the CC system. None of these remaining valves would function as a primary means of mitigating an accident, and none of them are considered " active" valves per UPSAR table 3.9.16. The reason for their inclusion is the possibility that they may be called upon following a single failure within the CC system. In addition, there are several other
" maintenance" type valves that would also be available for isolation purposes.
In a post accident situation, there are no specific directions taken within the CC system. If a malfunction were to occur, operators would be dispatched and the problem isolated as required. Dyron conservatively added these valves to the program due to the uniquene' ; of the CC system and to address possible concerns about the valves' ability to isolate. In addition, Byron will be exercising these valves on the same f raquency as the CC9459B and C:'9467B valves. 1here would be no value added and it would be impractical to exercise them on a more frequent basis. The following is specific information Oo'.cerning the valves in this refueling outage justification.
poecific Information 34 1/2CC9459B and 1/2CC9467B Manual valves 1/2CC9459B and 1/2CC9467R 4re used to provide train separation and/or isolation of the Component Coe' ng Water (CCW) System. More specifically, they are aligned to place the Unit 0 Heat Exchanger and Pump on the Unit 1 or Unit 2 side of CCW to ensure adequate cooling taring shutdowns and/or Post-Accident.
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Dyron 2nd Intervul IST Plan Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-3 (continued)
Exercising these valvet presents a conceen for the equipment cooled by the CCW System. The CCW system is e delicately balanced system that has the potential for beccming upset upon swapping the Unit 0 Heat Exchanger and pump from one unf.t to the other. History has shown that stroking these valves will cause oscillation in the lines, dinrupt flow balancing due to D/P differences throughout the eystem, and would place the normal loads at risk for adequate cooling. For instance, the CC685 velve, which is the Reactor Coolant Pump (RCP) thermal barrier Component Cooling Water return valve, autocloses on high flow, which would result in a loss of flow to the RCP thermal Farriers. The CC685 valve could potentially close during the exercising of the CC manual valver, due to the upset flow conditions. Exercising tne CC manual valves quarterly is impractical for the reasons presented above. .
The normal alignment of the CCW System io to have the Unit 0 heat exchancer and Unit 0 Pump aligned to Unit 1. It would be impractical due to the taasens presented previously (flow concerns, etc) to exercise the CC manual valves during a Unit i refueling outage or cold shutdown since the Unit 0 heat .,
exchanger and Unit 0 pump would normally already be aligneo in the desired 'y) position for the Unit 1 outage or cold shutdown. However, before entering a Unit 2 refueling outage or before a planned U-2 cold shutdown (or just after a forced U-2 cold shutdown), the 2CC9459B and 2CC9467B CC manual valves would be exerciscd open and the respective U-1 valves would be exercised closed to align the Unit 0 heat exchanger and Unit 0 Pump to Unit 2 to ensure adequate cooling is available. Despi*- this necessity to f.afill plant operations, it would be impractical to routinely return the valves to their original position during a U-2 cold shutdown (following RH cooling as the plant is ascending to mode 1) due to the fact that it may interfere with other outage activities.
These valves require very careful plant monitoring and a considerable amount of time to physically exercise.
Due to the above justification, in accordance with OM 10, paragraph A.2.1.2, Byron will exercise the 1(2)CC9459B and 1(!)CC9467B manual
- alves in the following manner: In preparation for a Unit 2 refueling outage, the 2CC3459B and 2CC9467B Component Cooling manual valves would be exercised open and the respective U-1 valves will be exercised closed to align the Unit 0 heat exchanger and pump to Unit 2. Prior to entry into mode 1, the valves would be exercised in the opposite direction to re-align the Unit 0 heat exchanger and pump to their normal alignment for Ur.it 1.
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Byron 2nd Interval IST Plen Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ.3 (continued)
To further support this refueling outage justification, a review of ,
maintenance history dating back to 1983 was netformed at Byron. The ICC9459B ~
and ICC9467B valves were repacked with 9 .1 in 1983 and the 2CC9459B was repachid with graphoil in 1986. In addit the ICC94$9B had a small leak repaired by tightening bolts in 1985, had . limit switch adjustment made in 1987, and was repacked in 1994. The 2CC9467B valve had valve packing adjusted in 1986 and a gearbox oil leak repaired in 1995. This review showed that there has been no evidence of valve exercising malfunctions for these valves from 1983 to the present.
- h. 1/2CC9467A Exercising these valves quarterly is impractical. One function of these valves is to serve as another means of isolating flow to the normal plant loads in a post-at ident situation in the event that the respective CC9415 valve were to fail open. Due to its function, it is an undesirable practice to exercise these manual valves during normal operations. When the plant is in its normal lineup, closing the 2CC9467A valve would interrupt flow to the normal plant J oads. For Unit 1, if the ICC9467A valve was exercised closed.
CC flow would need to be diverted through the Unit o heat exchanger, which may cause disruptions within the CC system.
In addition, a maintenance history search at Byron indicates that both valves were repacked with graphoil in 1984, and the U-2 valve had screws tightened on the gear housing due to a minor grease leak in 1990. There is no evidence of valve exercising malfunctions.
It is impractical to induce the disruptions described above during normal operations. Additionally, finding an appropriate window to stroke these-valves during a cold shutdown could possibly result in an extension of the cold shutdown and there would be no compensated increase in plant safety. The most practical alternative method is to exercise these valves at the same frequency (within the same procedure) as valves 1/2CC9459B and 1/2CC9407B.
- g. 1/2CC9458. 1/2CC9459A. and 1/2CC9467C If these manual valves were everciced during a valve lineup which varied from the normal lineup, there are possibilities of disrupting the CC system. There would be instances in which pumps may need to be swapped, or further re-routing of flow may be necesstry due to other misc, work being performed throughout the system.
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Byron 2nd Interval IST Plc.n Revision 1 l December, 1997
)
REFUELING OUTAGE JUSTIFICATION ROJ-3 (continued)
-Maintenance history since 1983 at Byron indicates that there have not been problems asociated with manual exercising these valves. There are no 3
indications of binding or other trouble. The work on them aas consisted of the following the U-1 valves were all repacked with grapholl in 1983 and all of the U-2 valves were reparked with graphcil in 1986; the ICC9458 valve had a limit switch adjustment in 1992 at4d 1993; the ICC9459A valve had the ground strap reattached for the limit switch in 1991; and the ICC9467C valve had broken seal-tite repaired in 1984.
For reasons justified in the general section and throughout this refueling outage justificatinn, it is more practical to exercise these manual valves at-the same frequency as described for the manual valves in Part a and Part b of this refueling outage justification. A U-2 refueling outage frequency is more than sufficient for monitoring degradation on these valves, gonclusionsi To conclude, the most practical method of exercising all the CC manual valves included in this justification is to test all of them under the same procedure, under cer-h01y controlled conditions, to ensure that all necessary precautions / actions are taken. To test them in a different manner would be impractical.
7EST FREQUENCY:
The 1DiCC9459B and 1(2)CC9467B valves will normally ba exercised in one direct 4on in preparation for a Unit 2 refueling outage, and then exercised in the opposite direction prior to entry into mode 1. The remaining valves in this refueling outage justification will normally be exercised within the same procedure. The executing procedure, containing documentation of all Component Cooling manual valve strokes, will be tracked as a U-2 refueling outage activity with the Work Planning Departmenc. This testing-is being deferred to every U 2 Refueling oatage in accordance with OM-10, paragraph 4.2.1.2 (e) .
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Byron 2nd Interval IST Plc.n Revision 1 December, 1997 l
I REFUELING OUTAGE JUSTIFICATION ROJ 4 CODE DRAWING DRAWING yALVE NtHBER CATEGQM CLASS HGiB_EB COORDINME 1/2 SIB 011A B 2 M 61-4(M-136-4) BS (B6) 1/2 SIB 811B B 2 M 61-4 (M 106-4) AS (A6)
FUNCTION (S):
These normally closed motor operated gate valves are located on the Containment Recirculation Sump discharge line. The valves are required to be closed during the injection phase of ECCS along with functioning as a contair ent isolation valve. These valves are required to open during the recircuantion phase of ECCS.
QUSTIFICATION:
The stroke time testing of the 1/2SIBB11A/B valves require the suctions of the Residual Heat Removal Pumps to be drained, thus rendering the train that is being tested inoperable. The stroke time testing of these valves during unit operation would be clearly impractica) due to the extensive activities required to perform this testing, along with rendering a subsystem uf ECCS (RHR) inoperable for an exeended period of time (placing the plant in an undesirable condition).
-The routine testing of these valves during cold shutdowns is also impractical for the following reasons:
- 1. For a cold shutdown in which the Reactor Coolant Loops remain filled and there is one train of Residual Heat Removal declared inoperable, Byron Station's Technical Specification 3.4.2.4.1 requires the s9eondary side narrow range water level of at least two steam generators to be greater than 41% for Unit 1 (18% for Unit 2) . However, if the cold shutdown was necessitated by a problem requiring draining of the secondary side of the Steam Canerators (i.e. tube leaks), Byron Station's Technical Specification 3.4.1.4.1 would preclude the testing of the containment sump outlet isolation valves until such time as the affected steam generators had been refilled,
- 2. For Cold Shutdown operations with the Reactor Coolant boops not filled (i.e., drained down to support Reactor Vessel Incore Seal Table, Loop Stop Valve, Reactor Coolant Pump and Seal Maintenance or primary leakage),
Byron Station's Technical Specification-3.4.1.4.2 would preclude the testing of the Containme. . Sump outlet Isolation Valves as it mandates that "two residual beat removal (RHR) Loops shall be operable and at least one RHR Loop shall be in operation",
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Byron 2nd Interval IST Plc.n i
Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ 4 (continued)
- 3. The full stroke testing of the 1/2 SIB 811A, B valves; An conjunction with system draining, filling and venting of each train, accounts for an additional six days (3 days per train) of scheduling requirements and increased radiation dose to operators and radiological control personnel. Processing of thousands of gallons of containment water, and subsequent required liquid ef fluent discharges would also result f rom the draining, refilling and venting of tne RHR system. This time duration required to perform the surveillance tasting of the Containment Sump Outlet Isolation Valves during Cold Shutdown activities, could, as a result, cause a violation of the action requirements for Byron Station's Technical Specifications 3.4.1.4.1 and 3.4.1.4.2. The violations woald occur since these action statements require (as noted in their respective foot note sections) the return of the inoperable residual heat removal loop to service within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, if such loop was removed for surveillance testing provided the other RHR Loop is operable and in operation.
- 4. In addition, NRC Generic Letter 88-17, Loss of Decay Heat Removal, highlights the consequences of a loss of RH during reduced Reactor Coolant System inventory (bulow three feet below the rSactor vessel flange). If the operating RH pump is lost due to air entrainment, and the other train is inoperable for the stroke test, then the " operable" train must be vented to restore decay heat removal. Under worst E2nditions, boiling in the core would occur in approximately 10 minutes, the core would be uncovered in approximately 30 minutes, and fuel damage wo.1d occur in approximately 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
Given the apparent disparity between the Technical Specification time I
requirements for an inoperable RHR Loop return to service (2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />) and the time required to perform surveillance scroke testing of the Containment Sump Outlet Isolation valves (3 days) during Cold Shutdown, the alternate testing frequency of refueling outage periodicity will adequately maintain the system in a state of operational readiness, while not imposing undue hardships or sacrificing the safety of the plant.
TEST FREQUENCY:
The 1/2SIBB11A/B valves will be stroke timed during refueling outages in accordance with OM-10, paragraph 4.2.1.2.
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Byron 2nd Interval IST plon Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-5 CODE DRAWING DRAWING YALVE NUMBEB ghTEGORY CLASE NUMBER COORDINATE 1/22A065 A 2 M-55 4 (M 55-5) D3 (E6) 1/2IA066 A 2 M-55-4(M-55-5) D6 (E4) 1/21A091 AC 2 M-55-4(M-55+5) ES (ES)
FUNCTION (S):
Air Operated Valves 1/2IA065 and 1/2IA066 are the outboard and inboard (respectively) containment isolation valves for Instrument Air supply lines to containment. The closed safety function of these valves is to provide a leak-tight barrier between the containment atmosphere and the environment during accident conditions.
Check Valves 1/2IA091 are located on the air supply lines to the 1/2IA066 valves (inboard containmen*. isolation valves) . The safety function of the 1/2IA091 valves in the closed direction is to provide a leak-tight barrier between the containment atmosphere and the environment during accident conditions (see Note 1 and VR-12). The function in the open direction is to supply control air to the 1/2IA066 valves. The open full stroke test of the 1/2IA091 valves is satisfied by the open stroke test of the 1/2IA066 valves.
JUSTIFICATION:
Stroke / fail-safe testing of the 1/2IA065 and 1/2IA066 valves (and full stroke testing of the 1/2IA091 valves upon re-opening of the 1/2IA066 valves) during plant operation or cold shutdowns would, by design, isolate the air to air operated instruments inside the containment building. This would introduce the possibility of major operating perturbations and/or personnel safety concerns should these valves fail to re-open during testing activities. This would result in scenarios such as:
- 1. Loss of Pressurizer pressure Control -
The pressurizer spray valves 1/2RY455B & C and the pressurizer auxiliary spray valv 1/2CV8145 would fail closed and not be available for pressurizer pressure control.
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Byron 2nd Interval IST Pir.n Revision 1 Decorber, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-5 (continued)
- 2. Loss of Chemical Volume Control System Letdown Flow (both normal and excess) and Charging Flow -
The loss of instrument air would cause a disruption in the unit letdown flow paths resulting in pressurizer level increases. Such valves as the letdown orifice containment outlet header isolation valve 1/2CV8160, the letdown line isolation valves 1/2CV459 and 1/2CV460, the letdown orifice outlet isolation valves 1/2CV8149A, B & C, the excess letdown heat exchanger inlet isolation valves 1/2CV8153A & B, and the regenerative-heat exchanger letdown inlet isolation valves 1/2CV8389A & B would go to their fa!1 closed positions. Additionally, the ability to normally make up reactor coolant inventory and adjust the reactor chemical shim (i.e. normal boration/ dilution) would also be lost as the regenerative heat exchanger inlet isolation valves 1/2CV8324A & B would fail to their respective closed positions.
- 3. Loss of Component Cooling to containment Penetrations -
The loss of instrument air supply would cause the penetration cooling supply flow control valve 1/2CC053 to go to its fail closed position.
The loss of penetration cooling would result in elevated temperatures being imposed or, the penetrations being supported by the component cooling system.
- 4. Loss of Personnel Breathing Air -
The loss of Instrument Air supply to the Service Air downstream isolation valve 1/2sA033 would cause.this valve to go to its fall close position. This loss of Service Air in the containment building would eliminate the normal source of supplied breathing air needed to support numerous maintenance and component inspection activities in a contaminated environment.
TEST FREQUENCY:
Air Operated Valves 1/21A065 and 1/2IA066 will be stroke tested and fail safe tested (and subsequently 1/2IA091 full-stroke tested with the open stroke time test of the 1/2IA066 valves) during refueling outages on the respective un in accordance with OM-10, paragraphs 4.2.1.2 and 4.3.2.2.
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Byron 2nd Interval IST Plen Revision 1 December, 1997
-REFUELING OUTAGE JUSTIFICATION ROJ-6 CODE DRA WING DRAWING VALVE NUMRIE GAIK9)BX CLASS NUMBER QQQRDINATE 1/2 SIB 819A AC 1 M 61-3(M-136-3) A5 (B4) 1/2 SIB 819B AC 1 M 3 (f t-136-3) A7 (B2) 1/2 SIB 819C AC 1 M 61-3(M-136-3) A6 (B2) 1/2SI8819D AC 1 M 61 3(M 136 3) A6 (B3) 1/2 SIB 90$A AC 1 M 61-3(M-136-3) E4 (E4) 1/2 SOB 90$B AC 1 M- 6".- 3 (M- 13 6 - 3 ) D7 (D2J 1/2 SIB 905C AC 1 f
1 M-61-3(M-136-3) E8 (E1)
FUNCTION (S):
All of the "AC" category valves in this refueling outage justification are pressure isolation valves (PIVs) and will be leak tested (and backflow tested) per Dyron Station Tech Specs (see VC-2 5) . This refueling outage justification will only include the open functions of all the check valves listed above.
Check valves 1/2 SIB 819A-D are located in the lines going from the Safety Injection pumps to the reactor vessel cold leas. Their safety function in the open direction is to permit flow of coolant to the reactor vessel cold legs during a safety injection.
Check valves 1/2 SIB 905A-D and 1/2 SIB 949B/D are located in the lines going from the Safety Injection pumps to the reactor vessel het leos. Their safety function in the open direction is to permit flow of coolant to the reactor vessel hot legs during the Hot Leg Recirculation portion of a safety injection.
Check valves 1/2 SIB 922A/B are located on the Safety Injection pumps discharge 1e. They are required to open for ECCS injection and recirculation phases.
Check valves 1/2 SIB 926 are located on the SI pumps' suction line from the RWST. They are required to open for the ECCS injection phase, s-p \sec\ist\istrevia.wpf 3.4.2 Pg. 15 of 33
Byron 2nd Intstv:1 IST Plan Revision 1 December, 1997 REFUELING OUTAGE JUST7'ICATION l ROJ-6 (continued) l 2pSTIFICATION These valves cannot be full stroke exercised during operation as the shut-off head of the Safety Injection pumps is lower than the reactor coolant system pressure. These valves cannot be full stroke exercised during routine mode 5 cold shutdowns due to Byron Station Technical Specification 1/4.5.3 requirement that all Safety Injection pumps and all but one Charging pump be inoperable during modes 4, 5, and 6 (temperature less than 350 F), except when the reactor vessel head is removed (mode 6 refueling outages only) . This requirement minimizes the possibility of low temperature overpressurization (LTOP) of the Reactor Coolant System (RCS). The alternate method of protecting against over-pressurization by partially draining the RCS to provide a surge volume is not considered a safe practice due to concerns of maintaining adequate water level above the reactor core. Full stroke exercising of these valves may only be safely performed in Mode G with the Reactor vessel head removed.
IRST FREQUENCl These valves will be full stroke exercised during refueling outages in accordance with OM-10, psragraph 4.3.2.2. Additionally, the 1/2 SIB 926 check valves will be partial stroke tested quarterly during the Safety Injection mini-flow recirculation pump runs.
p \sec\ist\istrevla.wpf 3.4.2 Pg. 16 of 33
Byron 2nd Interval IST Plen Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-7 CODE DRAWING DRAhING YALVE NUMBER FAT _EGORY 9_14Ef_ NUMBE COORDINATE 1/2CV8481A C 2 M- 6 4 - 3 A (M-13 8 - 3 A) D6 (D6) 1/2CV8481B C 2 M 64-3A(M-138-34) C6 (C7) 1/2CV8546 C 2 M-64-4B(M-138-4) B5 (A5) 1/2 SIB 815 AC 1 M-61-2*M-136-2) DS (D4) 1/2 SIB 900A AC 1 M 61 2 (M 136-2) E7 (E2) 1/2 SIB 900B AC 1 M-61-2(M-136 2) D7 (D2) 1/2SI8900C AC 1 M-61 2(M-136-2) C7 (C2) 1/2 SIB 900D AC 2 M-61-2fM-136-2) B7 (B2)
FUNCTION (S):
All of the "Aca category valves in this refueling catage justification are pressure isolation valves 19IVs) and will be leak tested (and backflow tested) per Byron Station Tech Specs (see VC-15). This refueling outage justification will only include the open functions of all the check valves listed above.
Check valves 1/2 SIB 015 are located in che lines from the Chemical and Volume control (CV) Centrifugal Chargi.ig pump. Their safety function in the open direction is to permit flow of coolant from the centrifugal chstging pumps to the four lines which branch off and provide flow to the reactor vessel cold legs during the high pressure injection phase of a saf*ty injection.
Check Valves 1/2 SIB 900A-D are in the four lines which branch off from the lines containing the 1/2SI8815 valves, their safety function in the open direction is to permit flow of coolant from the chemical and volume Control Centrifugal Charging Pumps to the reactor vessel cold lega during the high pressure injection phase of a safety injection.
Check valves 1/2CV8481A/B are located at the discharge of the Chemical and volume control charging pumps. They are required to open to permit flow of coolant during a safety injection.
Check valves 1/.*CV8546 are located on the CV pumps' suction line from the RWST. They are required to open to permit fl0w of coo! nt when the charging pumps take suction from the RWST during a safety injection.
JUTTIFICATION:
The full stroke exercising of check valves 1/2SI8815 and 1/2 SIB 900A-D ussociated with the Emergency Core Cooling System during operation would induce thermal stresses on their respective reactor vessel nozzles as the Reactor coolant System (maintained at greater than 500'F) is injected with water from the Refueling Water Storage Tank (maintained at approximately 65'F). The 1/2CV8481A/B and 1/2CV8546 cheek. valves are in series and cannot be full stroke exercised without causing stroking of 1/2SI8815 and 1/2 SIB 900A-D check valves.
pi\sec\ist\istrevla.wpf 3.4.2 Pg. 17 of 33
ifron 2nd Interval IST Plc.n avision 1 Dec. Der, 1997 REFUELING OUTAGE JUSTIFICATION ROJ 7 (continued)
These valves cannot be full stroke exercised during routir.e mode 5 co).d shutdowns due to Dyron Station Technical Specifications 3/4.5.3 and 3/4.5.4.1 requirements that all Safety Injection pumps and all. but one Charging pump be inoperable during medes g, 5, and 6, except when the reactor vessel head is removed (mode 6 of refueling outages only). This requirement minimizes the possibility of low temperature overpressurization (LTOP) of the Reactor coolant Symrem (RCS) . i..e alternate method of protecting against over-pressurization by partially draining the RCS to provide a surge volume is not considered a safe practice due to concerns of maintaining adequate water level above the reactor core. In addition, injecting large quantities of highly borated water from the RWST would likely delay reactor start up and the cost of processing the reactor coolant to restore the optimum boron concentration is consequential. Full stroke exercising of these valves may only be safely performed in Mode 6 with the Reactor vessel head removed, TEST FREQUENCYt These valves will be full stroke exercised during refueling outages in accordance with OM-10, paragraph 4.3.2.2. Additionally, the 1/2CV8481A/B check valves will be partial stroke tested quarterly during the A and B train CV mini-flow recirculation pump runs.
p:\sec\ist\1strevia.wpf 3.4.2 Pg. 18 of 33
~~ - _- - ,
Byron 2nd Interval IST pit.n Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-8 CODE DRAWING DRAWING YALVK_lfUMBER FATEGORY EMag NUMBER COORDINATE 1/2SI8841A AC 1 M-61-3(M 136-3) E4 (E4) 1/2 SIB 841B AC 1 M 61-3 (M-136 3) C7 (C2) 1/2 SIB 949A AC 1 M 61-3(M ~36-3) E8 (E1) 1/2 SIB 949C AC 1 M-61-3(M-136-3) C8 (C1)
FUNCTION (S):
All of the "AC" category valves in this refueling outage justification are pressure isolation valves (pIVs) ar.d will be leak tested (and backflow tested) per Byron Station Tech specs (see VC-15), This refueling outage justification will only include the open functions of all the check valves listed above, check valves 1/2SI8841A/B are located in the lines from the Residual Heat Removal (RHR) pumps to the "A" and "C" Reactor Coolant System hot legs. Their safety function in the open direction is to permit flow of coolant from the RHR pumps to the reactor vessel hot legs during the Hot Leg Recirculation phase of a safety injection.
Check Valves 1/2 SIB 949A/C are located in an ECCS line to the RCS "A" and "C" hot legs. They are required to open to permit flow of makeup water upon a safety injection from: (1) the Safety Injection pumps during the high pressure safety injection phase, or (2) the RHR pumps during the Hot Leg Recirculation
_ phase, to the reactor vessel hot legs.
JUSTIFICATION:
The full stroke exercising of check valves 1/2SIBB41A/B and 1/2 SIB 949A/C, associated with the Emergency Core Cooling System (ECCS) and the Residual Heat Removal (RHR) System cannot be accomplished during normal reactor operation because the low head developed by the RHR pumps (less than 250 psi) is not great enough to inject into the RCS (2235 psi) . Similarly, the 1/2SI8949A/C check valves cannot be partial stroke tested during normal reactor operation with the Safety Injection (SI) pumps since the RCS pressere cannot be overcome by the SI pump developed head (1500 psi).
Full or partial stroke testing of these valves during cold shutdowns would induce thermal stresses on their respective reactor vessel nozzles as the Reactor Coolant System (maintained at approximately 180 F) is injected with water from the Refueling Water Storage Tank (maintained at approximately 65 F) . Additionally, the margin of safety is reduced for brittle fracture prevention and an unacceptable reactivity excursion could be created (high boron concentration and low temperature water).
ps\sec\ist\istrevla.wpf 3.4.2 pg. 19 of 33 l
Byron 2nd Interval IST Pim Revision 1 December, 1997 i
REFUELING OUTAGE JUSTIFICATION ROJ.B (continued)
Finally, during Lold shutdowns in which the Technical Specification leak rate testing is not to be performed, tne partial or full stroking of these valves would necessitate the requirement to perform the leak test on these check vd1ves, Causing a delay in returning the plant to power in addition to Cauaing unnecessary radiation exprsure to test personnel.
TEST FARQUENCY These valves will be full stroke exercised during refueling oucages in accordance with OM 10, paragraph 4. 3.2.2.
4 p?\sec\ist\istrevla.wpf 3,4.2 Pg. 20 of 33
Byron 2nd Interval IST Plen Revision 1 Decenber, 1997 REFUELING OUTAGE JUSTIFICATION ROJ.9 CODE DRAWING DRAWING YALVE NUMBEB CATEGORY plJdE NUMBER COORDINATE 1/2RHB705A AC 2 M 62 (M-137) D1 (DB) 1/2RH8705B AC 2 M* 62 (M-13 7) C1 (C8)
EMFCTION (8) :
These check valves are leak tested in conjunction with pressure isolation valves (PIVs) 1/2RHB701B and 1/2RH8702B and will be leak tested (and backflow tested) at the same frequency as the 1/2RH8702B valves (see VC-15). This refueling outage justification will only include the open functions of the check valves listed above.
These valves are located on the 3/4" branch line between the 1/2RH8701A/B and 1/2RHG702A/D suction isolation valves. Their safety function in the cpen directicn is to relieve excess pressure due to thermal expansion back to the RCS when both suction isolation valves are closed in order to prevent over pr:ssurization of the piping between the two valves.
JUSTIFICATION: ,
These valves are simple spring loaded lift check valves and are not equipped with an external operator or disk position indicator. The only way to verify operability in the open direction is by verifying that the piping between the suction isolation valves is able to be depressurized through tho applicable valve via a field test. It would be impractical to perform this testing during unit operation due to the necessity to enter containtcent, hookup a pressurized water source to the piping via a test / vent valve, and slowly increase the pressure until the check valve opens to relieve the pressure.
Additionally, the RCS must be depressurized in order to perform this test.
It would be' impractical to perform this test during cold shutdr ma as it requires placing the standby train of Residual Heat Removal (R' in an inoperable condition and the RCS must be depressurized (require 6 all reactor coolant pumps to be stopped). Then, due to the extensive field iTiolved, there is a potential for delaying reactor start up and return to L nr.
Additionally, taking away the backup / redundant train of RHR reduces both the plant decay removal capability and the available safety margin regarding ,
shutdown risk assessment.
Testing these valves each refueling, in mode 6, is adequate to maintain this portion of RHR in a state of operational readiness, while not sacrificing the safety of the plant.
pi\sec\ist\istrevla.wpf 3.4.2 Pg. 21 of 33
Byron 2nd Interval IST Plan Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION AOJ.9 (continued)
ILST FFEQEgNCY These valves will be full stroke exercised during refueling outages in accordance with OM-10, paragraph 4.3.2.2.
t p \sec\ist\istrevla.wpf 3.4.2 Pg. 22 of 33
Byron 2nd Interval IST Plc.n Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ 10 CODE DRAWING yJLVE FUMBER QATEGORY CLASS NUMBER COORDINATE 3/2FP345 BC 2 M 52-1(M 52 1) E7 (E2)
TUNCTIOt[{g[1 These check valves arc in the line from the Fire Protection System to Containment. The open function allows Fire protection Water to reach the Containment building (non-IST). The closed function (the subject of this justification), is for containment isolation.
MEIU.LQATIOHi y
These v41ves are exempt from Local Leakage Rate testing of 10 ,
Appen'.tx J, but due to their designation as CIvn, they shal* .sted in the closed direction. The valves are physically located inside .ainment. Even though personnel access to the containment (outside the biologAcal shield) while the reactor is operating is allowed, it is not a routine practice.
There is no flow through these valves during periods when the associated reactor is at power, and there is very seldom any flow through these valves during any mode of operation. This valve is as passive as a check valve can be in the closed position. Testing these valves more frequently than each associated refueling ou age adds no additional confidence in the valve's closure capability but it deos add to the occupational radiation exposure of those personnel required to perform the test.
Testing these valves on a frequency of every three months during normal operation adds undue hardship without a compensating increase in the level of safety. Testing the valves every three months or on a cold shutdown basis adds to the occupational radiation exposure of the personnel required to perform the test. There is normally no flow through this valve to result in the valve disc leaving the seat, therefore the valve remains passively closed during periods of normal operation. No additional confidence in the ability of the valve to close is gained by subjecting this valve to quarterly or cold shutdown testing versus testing on a refueling outage frequency.
IEST FREQUENCY:
These valves will be tested on a refueling outage frequency to verify closure in accordance with OM-10, paragraph 4.3.2.2.
pi\sec\ist\istrevla.spf 3.4.2 Pg. 23 of 33
Dyron 2nd Interval IST Plen Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-ll CODE DRAWING DRAWING VALVE N14LBIB CATEGE 1 CLASS NUMBER EQQJLDJjnTE 1/2CVB348 BC 2 M-64-3B(M 138-3B) E2 (E2)
FUNCTIONSI The above listed valves are Reactor Coolant Loop Fill Check valves in the Chemical and Volume Control fystem (CV) and are designated containment Iselation valves (CIVs). Thet. valves are normally closed and are required to remain closed for containment isolation.
2VSTIFICATION:
These valves are exempt from Local Leakage Rate testing of 10 CFR 50, Appendix J, but due to their designation as CIVs, they shall be tested in the Closed direction. The valves are physically located inside containment approximately 14 feet above the floor, requiring scaf folding for access. Even though personnel access to the containment (outside the biological shield) while the reactor is operating is allowed, it is not a routine practice. There is no flow through these valves during periods when the associated reactor is at power, and there is very seldom any flow through these valves during any mode of operation. This valve is as passive as a check valve can be in the closed position. Testing these valves more frequently than every associated refueling outage adds no additional confidence on the valves closure capability but it does add to the occupational radiation exposure of those personnel required to perform the test.
Testing these valves on a frequency of every three months during normal operation adds to the occupational radiation exposure of the personnel required to perferm the test. Erection of scaffolding inside containment while at power presents unique hazards and requires extensive analysis and evaluation. There is normally no flow through this valve to result in the valve disc leaving the seat, therefere the valve remains passively closed during periods of normal operation. No additional confidence in the ability of the valve to close is gained by subjecting this valve to quarterly or cold shutdown testing versus testing on a refueling outage frequency.
TEST FREQUENCY The above listed valves will be tested on a refueling outage frequency to verify closure in accordance with OM-10, paragraph 4.3.2.2.
pt\sec\ist\istrevla.wpf 3.4.2 Pg. 24 of 33
Byron 2nd Intorvol IST Plan Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-12 CODE DRAWING DRAWING s VALVE NUMBE CATEQQBX GLA$1 ((pMBER EQQ]tDINATE 7 1/2CV8368A BC 2 M 64 (138)-1 B7 (B7) 1/2CVB36BB BC 2 M 64 (138)-1 C4 (C4) 1/2CV8368C BC 2 M 64 (138) 2 BB (DB) 1/2CV8368D BC 2 M- 6 4 (13 C ) - 2 BS (B5)
FUNCTION (S):
The 1/2CV8368A D check valves are in the seal injection line to the Reactor Coolant Pumps. Additionally, they are designated as containment isolation valves, but are exempt from local leak rate testing in accordance with 10CFR50, Appendix J.
JUSTIFICATION:
These valves are exempt from local leak rate testing, but due to their designation as Containment Isolation Valves, they will be conservatively tested per the ASME code in the closed direction. Reactor Coolant Pumps (RCPs) are required to be in operation in Mode 1, power operation. Seal injection flow must be maintained when the RCPs are running. Seal injection flow stoppage with the RCPs in operation, even for a short duration, is detrimental to the RCP seals. Therefore, these valves cannot be tested at power.
It would appear that the 1/2CVB360A-D valves would be candidates for cold shutdown testing with all the RCPs off. However, these particular check valves are difficult to test in the closed direction. Traditional methods of measuring leakage and/or closure are not sufficient for these valves. Non-intrusive techniques are required to test these valves adequately. For this type of check valve (2" Kerotest), UT methods at Byron are still in the experimental stage with an adequate degree of uncertainty. Hence, radiography, which has proven very effective in other IST applications, will be used to verify closure.
Performing radiography requires the use of outside contractor personnel, which are onsite during refueling outages (not for cold shutdowns). Also, to safely
-perform the required non intrusive testing on these valves (UT or RT),
, scaffolding will be required. Additionally, cold shutdown testing would add to the occupational radiation exposure of the personnel required to complete the test, with the test duration possibly holding up a cold shutdown. For these_ reasons, it would be costly and impractical to perform this testing on a cold shutdown f.equency. Testing these valves for closure at a refueling outage frequency is sufficient for maintaining these valves in a state of operational readiness, pi\sec\ist\istrevla.wpf 3.4.2 Pg. 25 of 33 f _ _ _ _ _ _ _ _ _ _
i l
Dyron 2nd Interval IST Plan Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-12 (continued)
TEST FREQUENCY:
These check valves will be tested for c)osure during refueline outages in accordance witu OM-10, paragraph 4.3.2.2.
d i
pi\aec\ist\istrevia.wpf 3.4.2 Pg. 26 of 33 l
l l
Byron 2nd Interval IST Plan Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ 13 CODE DRAWA. DRAWING VALVE NUMBEB ph, 1QBX CLASS NUMBER COORDINAT4 1/2CC9495A BC 3 M-66-1B(M 139-1) E2 (ES) 1/2CC9495B BC 3 M- 6 6 - 1B (M- 13 9 - 1) D2 (DS) 1/2CC9495C BC 3 M 66 1B(M-139 1) C2 (CS) 1/2CC9495D BC 3 M-66-1B(M 139-1) B2 (CS)
FUNCTION (S) :
The 1/2CC9495A-D check valves are the component cooling water supply check valves to the Reactor Coolant Pump (RCP) Thermal Barriers. These valves are required to close to isolate the component cooling system in the event of a thermal barrier tube failure.
JUSTIFICATION:
These valves cannot be verified for' closure during unit operation. In order to verify these valves are closed, the corresponding ".CP must be off and cooling flow isolated. Isolating component Cooling Water flow to the RCP during unit operation would result in eventual pump damage and/or trip.
Additionally, these valves are located in the containment building, inside the missile barrier, where entry at power is very rare and generally only possible at low power levels due to the high radiation levels. Test personnel would also receive unnecessary radiation exposure during cold shutdowns.
Byron will conduct sample disassembly and inspection of these valves as allowed by Generic Letter 89-04, position 2. Due to the area radiation levels, and operatirnal constraints, it would be impractical to verify closure of these valves during unit operation or cold shutdowns.
TEST FREOUENCY:
These check valves will be tested for alosure during refueling outages in accordance with OM 10, paragraph 4.3. 1.
p:\sec\ int \istrevia.wpf 3.4.2 Pg. 27 of 33 1
(
l Byron 2nd Interval IST Plan Revision 1 '
December, 1997 REFUILING OUTAGE JUSTIFICATION ROJ-14 CODE DRAWING DRAWING
,VJLVE NUMBER CATEGOPJ G_Aff, A NUMBER COORDINATE 1/2FW510A B None M-36-1C(M 121-1B) C2 (C2) 1/2FW520A B None M-36-1A(M-121-1D) C2 (C2) 1/2FW530A B None M-36-1D(M-121 1A) C2 (C2) 1/2FW540A B None M 36-1B(M-121-1C) C2 (C2) 1/2FW510 h Hone M-36-1C(M-121-1B) D2 (D2) 1/2FW520 B None M-36-1A(M 121 1D) D2 (D2) 1/2FW530 B None M 36-1D(M-121-1A) D2 (D2) 1/2FW540 B None M-36-1B(M-121-1C) D2 (D2) 1/2FWO34A B None M-36-1C(M-121-1B) E2 (E2) 1/2FWO34B B None M 36-1A(M-121-1D) E2 (E2) 1/2FWO34C B None M-36-1D(M-121-1A) E2 (E2) 1/2FWO34D B None M-3 6 -1B (M-121 1C) E2 (E2)
FUNCTION (S):
The Feedwater Regulating Bypass Valves (1FW510A. 1FW520A, 1FW530A, and 1FW540A), the Feedwater Regulating Valves (1FW510, 1FW520, 1FW530, and 1FW540) and the Feedwater Tempering Flow Control Valves (1FWO34A D) are non-safety related valves which perform a backup function to isolate Feedwater. These valves are not considered to be Containment Isolation Valves per the Byron Station Technical Specifications, and are considered only Feedwater Control Valves that, additionally, serve as backup Feedwater Isolation Valves. They are not considered to be in the scope of the IST Proctam (per OM-10, paragraph 1.1). This has always been Byron's position on these valves. However, since they do receive a Feedwater Isolation signal, an augmented test to verify the fail-safe test will be tracked within the-IST Program, JUSTIFICATIONL A commitment was made to only perform an augmented Fail-Safe on these valves in Byron's original program. These valves are all part of the surveillance (1/2BOS 3.2.1-13) executed to satisfy Tech Spec 3.3.2 (Table 4.3-2, item #1a),
which manually simulates an SI signal, causing these valves to fail closed.
These valves will be fail-safe tested to satisfy the requirements of this Technical Sp?qification (Refueling Outage Frequency) .
Additionally, the cler.ure of the Main Feedwater Regulating Bypass Valves (1/2 FW510A, 1/2FW520A, 1/2FW530A, and 1/2FW540A) during unit operation would require the Main Feedwater Regulating Valves to correct for bypassed flow and could result in a plant transient with a possible reactor trip as a result.
The closure of the Main Feedwater Regulating Valves (1/2FW510, 1/2FW520, p:\sec\ int \istrevia.wpf 3.4.2 Pg. 29 of 33
. . - . . . - _ = . -. - --
I Dyron 2nd Interval IST Plon Revision: 1 December, 1997
)
l REFUELING OUTAGE JUSTIFICATION ROJ 15 CODE DRAWING DRAWING VALVE _NUMBE CATEGORY plAES NUMBER COORDINhlg 1/2CC9486 AC 2 M-66-1A (M 139-1) E6 (E6) 1/2CC9518 AC 2 M 66-1A (M 139-1) B6 (B6) 1/2CC9534 AC 2 M 66-1A (M-139-1) B6 (A6) 1/2CS00BA AC 2 M 46-1C (M 129-1C) D6 (D3) 1/2CS000B AC 2 M-46-1C (M-129-1C) B6 (B3) 1/2CV8113 AC 2 M-64-2 (M-138 2) F2 (F2) 1/2IA091 AC 2 M-55-4 (M-55-5) ES (ES) 2PROO20 AC 2 M 78-6 C4 (C4) 1/2PROO2H AC 2 M-78-6 C4 (C4) 1/2 PRO 32 AC 2 M-78-10 (M-151 1) E1 (E1) 1/2PS231A AC 2 M-68-7 (M-140-6) D8 (D8) 1/2PS231B AC 2 M-68-7 (M-140 6) A8 (AB) 1/2RY8046 AC 2 M 60-6 (M 135-6) E3 (E3) 1/2RY8047 AC 2 M-60-6 (M-135-6) E3 (E3) 1/2 SIB 968 AC 2 M 61-6 (M-136-6) F4 (F5) 1/2WM191- AC 2 M-49-1A (M-49-1B) E6 (E3) 1/2WOOO7A AC 2 M-118-5 (M-118-7) ES (ES) 1/2WOOO7B AC 2 M-118-5 (M 118-7) B4 (B4)
FUNCTION (S):
1/2CC9486: Closed: Containment Isolation; Isolates "CC" flow to the RCPs 1/2CC9518: Closed: Containment Isolation; Isolates bypass flowpath around CC9438 Open: Provides pressure equalization path between Cc943 and CC685 1/2CC9534: Closed: Containmens Isolation; Isolates bypass flowpath around CC9416 Open: Relieves pressure between CC9416 and CC9414 1/2CS008A/B Closed: Containment Isolation; Isolates Bypass flowpath around CV8112 Open: Prevents pressure buildup between CV8112 and CV8100 1/2%A091: Closed: Containment Isolation; Isolates Instrument Air to Containment pi\sec\ist\istrevia.wpf 3.4.2 Pg. 30 of 33
Byron 2nd Interval IST Plan Revision 1 December, 1997 REFUELING OUTAGE JUSTIFICATION ROJ-15 (continued) 2PROO2Gs Closed: Containment Isolation; Isolates containment air sampling capabilities 1/2PROO2H Closedi Containment Isolation; Isolates containment air sampling capabilities 1/2PR032: Closed: Containment Isolation; Isolates containment air sampling capabilities 1/2PS231A/B Closed: Containment Isolation; Isolates containment hydrogen monitoring capabilities 1/2RYB046: Closedi Containment Isolation; Isolates Primary Water to Pressurizer Relief Tank (PRT) 1/2RYB047: Closed: Containment Isolation; Isolates N2 to PRT 1/2818968: Closed: Containment Isolation; Isolates N2 to accumulator 1/2WM191: Closed: Containment Isolation; Isolates Demin Water to Containment 1/2WOOO7A/B Closed: Containment Isolation; leolates Chilled Water to Chilled Water Coils JUSTIFICATIO!!1 The check valves in this listing are verified closed by leakage testing in accordance with 10 CFR 50, Appendix J, per paragraph 4.2.2.2 of OM 10. Under OM 10, check valves are to be exercised to the position (s) required to fulfill their safety function (s) quarterly, during cold shutdowns, or during refueling outages depending upon the practicality of performing the exercising during power operations or during cold shutdowns, In Section 4.1.4 of NUREG-1482, the NRC Staf f recommends that for check valves verified closed by leakage testing, the verification be performed on a refueling outage basis.
Additionally, the 1/2CC9518, 1/2CC9534, and 1/2CV8113 check valves are containment isolation valves, but are also designed to open to relieve pressure between two other containment isolation valves. The most practical method of full stroke testing cf the (Component cooling) check valves is through local leak rate testing of the respective penetration (check valves are located between the two other containment isolation valves).
The testing in this Refueling Outage Justification would not be practical to perform routinely at power or during cold shutdowns. The test equipment and testing methodology used to satisfy the testing involves a considerable amount of planning and setup, in addition to taking containment penetrations out of service. First, in considering the test equipment, the test rig and air supply lines would need to be ran throughout the containment building and the penetration area, Secondly, the testing would involve determining plant conditions which would allow the test to take place, isolating boundary valves for each penetration affected, taking the boundary valves out of service (generally) , draining between the boundary valves at a minimum (wster-filled systems), performing the test, filling and venting the system (water systems),
-and returning to service any out of services which were previously placed.
p \sec\ist\istrevla.wpf 3.4.2 Pg. 31 of 33
Dyron and Intuval IST Plan Revision 1 December, 1997 RETUELING OUTAGE JUSTITICATION RCJ-16 l
CODE DRAWING DhAWING VALVE NUMBER CATEGORY CLAS5 NUMBER COORDINATE I 1/2CV8546 C 2 M-64-4B (M-138-4) B5 (A$)
1/2S18926 C 2 M-61-1A (M-136-1) D2 (C6) rUNcTION(D):
This refueling outage justification will only include the backflow test (close function) of the above listed valves.
Motor operated valves 1/2CV112D and 1/2CV112E are aligned in parallel upstream of the 1/2CV8546 check valve. If 1/2CV112D or 1/2CV112E were to fail, the 1/2CV8546 check valve is expected to provide backup isolation to prevent flow into the RWST.
Motor operated valve 1/2SI8806 is located upstream of check valve 1/2518926. !
If 1/2SI8806 fails to close, 1/2SI6926 is expected to provide backup I isolation.
JUSTIrICATIoN:
\
There are no system provisions to backflow test the 1/2CV8546 and 1/2 SIB 926 valves. This necessitates the setup and usage of non-intrusive equipment for testing. Operation limitations also require ECCS full flow testing to be conducted during refuel modes (see ROJ-6 and ROJ-7) . Because of the need to utilize non-intrusive testing and due to operational considerations, the backflow tests of these valves will be conducted during refueling.
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pt\sec\ist\istrevla.wpf 3.4.2 Pg. 33 of 33
Dyron 2nd Interval IST Plan Revision 1 December, 1997 Denied RELIEr REQUEST vR-1 I
TITLE: Appendix J Test Frequency for Tests Other Than Leakage Tests CODE DRAWING DRAWING VALVE NUMBER CATEGORY class NUMBER CookDINAT_E 1/2CC9486 AC 2 M 66 1A;M-139-1) E6 (E6) 1/2CC9518 AC 2 M 66-1A(M 139 1) D6 (B6) 1/2CC9534 AC 2 M-66-1A(M-139-1) B6 (A6) 1/2CS00BA AC 2 M-46 1C(M 129 1C) D6 (D3) 1/2CS008B AC 2 M- 4 6 1C (M- 12 9 1C) B6 (B3) 1/2CV8113 AC 2 M-64 2(M-138-2) F2 (f2) 1/2IA091 AC 2 M-5%-4 (M-55-5) E5 (ES) 1/2PROO2G AC 2 M-78-6 C4 (C4) 1/2PROO2H AC 2 1 78 6 C4 (C4) 1/2PR032 AC 2 M-78-10(M 151-1) El (E1) 1/2PS228A A 2 M-68-7 (M 14 0-6) E7 (E7) 1/2PS22BB A 2 M-GB-7(M-140-6) C7 (C7) 1/2PS229A A 2 M 68-7(M-140-6) E6 (E6) 1/2PS229B A 2 M-68-7(M-140-6) C6 (C6) 1/2PS230A A 2 M-68-7(M-140-6) D7 (D7) 1/2PS230B A 2 M-68-7 (M 14 0-6) A7 (A7) 1/2PS231A AC 2 M 68-7 (M-14 0-6) DB (DB) 1/2PS231B AC 2 M-68-7(M-140 6) AB (AB) 1/2RYB046 AC 2 M 60-6 (M-135-6) E3 (E3) 1/2RY8047 AC 2 M-60-6(M-135 6) E3 (E3) 1/2SI8968 AC 2 M 61-6(M 136 6) F4 (F5) 1/2WM191 AC 2 M 49 1A(M 49-1B) E6 (E3) 1/JWOOO7A AC 2 M-118-5(M-118-7) E5 (ES) 1/2WOOO7B AC 2 M-118-5 (M-118 7) B4 (B4) 1 TUNCTIoN (8) :
1/2CC9486: Closed: Containment Isolation Isolates "CC" flow to the RCPs 1/2CC9518: Closed: Containment Isolation; Iso?stes bypass flowpath around CC9438 Openi Provides pressure equalization path between CC9438 and CC685 1/2CC9534: Closed: Containment Isolations Isolates bypass flowpath around CC9416 Open: Relieves pressure between CC9416 and CC9414 1/2CS008A/B: Closed: Containment Isolation: Isolates flow to Spray Nozzles 1/2CV8113: Closed: Containment Isolation; Isolates Bypass flowpath around CV8112 Open: Prevents pressure buildup between CV8112 and CV8100 1/2IA091: Closed: Containment Isolation; Isolates Instrument Air to Containment p \sec\isc\istrevla.wpf 3.5.2 Pg. 1 of 28
- . _ _ - ~_ -- _ - - . - - -. . _ . ..- -.-- -- _-- _-
Byron 2nd Interval IST Plan Revision 1 December, 1997 '
Denied RELitr nroursT va-1 (continued)
The check valves in this relief request de not have remote or local position indication devices tc indicate the posit.- of the check valve. Additionally, the 1/2CC9518, 1/2CC9534 and 1/2CVB113 checx valves are containment isolation valves, but are also designed to open to relieve pressure between two other containment isolation valves. The Process Sampling solenoid valves crw completely encapsulated so that local position verification cannot be observed. '
~
d The most practical method for verifying closure for the check valves in tlis relief request, verifying proper indication for the Process Sampling soientid valve indication testing, and for the full stroke testing of the CC check-valves, is through the execution of the Appendix J local leak rate testing methods. The closure test for these check valves is identical to the Appendix J local leak rate test. The indication testing for the Process Sampling
- encapsulated valves is determined thrnugh local _ leak rate testing flow measurements when the valves are leak tested, and opened, with corresponding remote verification of valve position in the control room. Finally, full flow is passed thrcugh the 1/2CC9518, 1/2CC9534, and 1/2CV8113 check valves during the local leak rate testing of their respective penetration (check valtes are located between two other containment isolation valves).
The testing in this relief request would not be practical to perform routinely at power or during_ cold shutdowns. The same test equipment and testing methodology would be used to satisfv the testing in this relief request as for the Appendix J 1eak test. which involves a considerable amount of planning and set up, in addition to taking containment penetrations out of service, first, in_considering the test equipment, the test rig and air supply lines would need to be ran throughout the containment building and the penetration area.
Secondly, the teating would involve determining plant conditions-which would allow the test to take place, isolating boundary val /es for each penetration af fected, taking the boundary valves out of service (generally), draining between the boundary valves at a minimum (water filled systems), performing.
the test, filling and venting the system (water systems), and returning to service any out of services which were previously placea.
In many cases, plant conditions at power would not allow this testing to be
- performed. For those cases in which the testing could be performed at power, routine quarterly testing would result in numerous containment entries, '
resulting in ernecessary exposure to neutron radiation in addition to the normal gamma and beta radiation. Testing these valves during cold shutdowns could result in unnecessary delays in unit startup and unnecessary accumulation of radiation dose. 1
- p \sec\ist\istrevia.wpf 3.5.2 Pg. 3 of 28
Byron 2nd Intorval IST Plan Revision 1 December, 1997 RELIEF REQUEST VR-2 TITLE: Disassembly of Containment Spray Check Valves CODE DRAWING DRAWING VALVE NUMBER CATEGORY CI. ABS NUMBER COORDINATE 1/2CS003A C 2 M 4 6-1A(M-12 9-1A) E6 (E3) 1/2CS003B C 2 M 46-1A(M-129-1A) C6 (C3) 1/2CS000A AC 2 M-46-1C(M 129 1C) D6 (D3) 1/2CS008B AC 2 M 46-1C(M 129-1C) B6 (B3) 1/2CS011A C 2 M-46-1A(M-129-1A) D2 (DB) 1/2CS011B C 2 M 46-1A(M 129 1A) B2 (B8) 1/2CS020A C 2 M 46 1B(M 129 1A) B2 (DS) 1/2CS020B C 2 M 46-1B(M 129-1B) B5 (AS) rUNCTION(8):
./2CS003A/B: Open: Supply water to the Spray Nozzles 1/2CS008A/B: Open: Provides flowpath to Spray Nozzles Closed: Containment Isolation (see VR 1) 1/2CS011A/B: Open Supplies NaOH to suction of the CS pump (Eductor Outlet) 1/2CS020A/B: Open Supplies NaOH to suction of the CS pump (Eductor Inlet / Discharge of Spray Add Tank Closed: trevents backflow to the spray additive tank (quarterly test)
CODE REQUIREMENT (B):
Per OMa 1988 Part 10, paragraph 4.3.2.1, check valves shall be exercised nominally every 3 months, except as provided by paras. 4.3.2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5.
t BASIS FOR RELIEF:
Generali Currently, full flow recirculation flow paths do not exist for the Containment Spray pumps. Extensive modifications to the existing plant design would be required to accommodate full flow testing of the 1/2CS003A,B and 1/2C5008A/B check valves, including the penetratic? of containment integrity.
Additionally, NCDH in the spray additive tank limits the stroking of the 1/2CS011A,B and 1/2CS020A/B valves. Finally, the use of nonintrusive techniques, such as acoustic monitoring and magnetics, have not been successful in proving full stroking on this type of valve (dual disk).
_= _
p \sec\ist\1strevla.wpf 3.5.2 Pg. 5 of 28 l
Byron 2nd Interval IST Plan Revision 1 Decenber, 1997 RELIEF REQUEST VR-2 (continued)
Becau,e of the sig.aficant work involved with the isolation, draining, maintenance, infipections, and partial stroke testing of the valves, along with the superior results of past inspections, it is clearly impractical and burdensome to perform disassemblies as frequently as quarterly or during cold shutdowns. Additionally, it would not be consistent with Generic Letter 89-04.
Additional technical support in justification for this relief request is provided for each set of valves in parte. A-D of this section.
A. 1/2CS000A.B: With the existing plant configuration, these valves cannot be full flow or partial flow tested during unit operation, cold shutdown or refueling, as water from the CS pumps would be discharged through the CS ring headers, causing undesirable effects on system components inside containment. Additionally, it is impractical to erect temporary large bore piping from the CS line to the reactor cavity, during cold shutdowns or refueling outages, in order to perform a full stroke test on these valves. The filling of the cavity would require the removal of the reactor vessel head to preclude equipment damage from borated water and the construction of the temporary piping would take an estimated nine to twelve shif ts (or longer) to complete. There would be even more time involved with the draining and removal of the piping from cor- ~ ' ment following the completion of the test.
Partial stroking of these valves using air during unit operation, cold shutdown, or refueling does not provide adequate assurance of valve operability and may be detrimental for the following reasons:
- a. There is no correlatica between air flow and angle of disc movement,
- b. Venting and draining the required portion of piping to perform this test may cause deposition of boric acid residue which could in turn promote binding of the check valve internals.
B. 1/2CS003A.B: These valves cannot be full stroke tested due to the existing plant configurations, as previously discussed fur the 1/2CS00PA,B valves. However, these valves are partially stroked quarterly since they are in the flowpath of their respective Containment Spray pump runs.
C. 1/2CS011A B: These valves cannot be full stroke tested (130 gpm eductor flow clus 55 gpm NaOH flow) during unit operation or cold shutdown as NaOH from the spray additive tank would be disenarged throughout the CS system causing undesirable chemical effects on the re ctor makeup supply (DWST) and associated systems. Additionally, personnel safety would also be a 2
factor. However, these valves are partially stroked quarterly during respective Containment Spray Pump runs in which the eductor flow passes through the valve, but the spray additive tank is isolated, eliminating the NaOH flow required for the full stroke, p:\sec\ist\istrevla.wpf ' 5.2
. Pg. 7 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 RELIEF REQUEST VR-2 (continued)
PROPOSED ALTERNATIVE TESTING:
Per Generic Letter 89-04, position 2, " ... valve disassembly and inspection can be used as a positive means of determining that e valve's disk will full stroke exercise open..." The provisions of tnis position may be used in the s case of the CS check valves for the open direction as follows:
The A and B train valves for each valve number are of the same design (manuf acturer, size, model number, and materials construction) and have the same service conditions, including orientation, and, therefore, form sample y disassembly groups. 1 Group 1 (U-1) Group 2 (U-1) Group 3 (U-1) Group 4 (U-1) ,
1CS003A 1CS008A 1CS011A 1CS020A 1CS003B 1CS008B 1CS011B ICS020B Group 1 (U-2)
Group 2 (U-2) Group 3 (U-2) Group 4 (U-2) 2CS003A 2CS008A 2CS011A 2CS020A 2CS003B 2CS008B 2CS011B 2CS020B Grouc r mbers 1. 3. and 4: One valve from each group, on a per unit basis, will be disassembled on an eighteen month fregt.ency during any plant mode.
Additionally, following re-installation, the 1/2CS003A,B and 1/2CS011A,8 valves will be partial stroke tested using the CS pumps and the 1/2CS020A,B valves will be partial stroke tested using an alternate water source (Note:
the 1/2CS020A,B test for the closed position is currently performed quarterly during the execution of the respective CS019 stroke time test). When the Technical Specification full stroke testing of the respective CS020 and CS011 valves is completed, it may be used to satisfy the full stroke testing in lieu of the disassembly plan (if within the 10 month frequency guidelines established). If a valve disassembled during power operation is found failed or excessively degraded, Byron should immediately (generally befcre the er.d of the shift during which the failure is discovered) analyze the valve failure to determine the degradation mechanism and the likelihood that the remaining valve in the grot p is signi ficantly affected by this mechanism. This evaluation will determine the operability status of the remaining valve in the group, and establish a time period in which is must be disassembled (consistent with guidance in GL 91-18).
p:\sec\ist\istrevla.wpf 3.5.2 Pg. 9 of 28 y
_m _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Byron 2nd Interval IST Pla'.
- Retibion 1 December, 1997 RELIET REQUEST VR-3 TITLE: Motor Driven Auxiliary Feedwater Pump Essential Service Water Lube Oil Cooler Outlet Isolation Valve Stroke Test CODE DRAWI'NG DRAWING VALVE NUMBER CATEGORY CLASS NUMBER COORDINATE
- 1/2SX101A B 3 M- 4 2 - 3 (M- 12 6 - 1) E3 (E6)
PUNCTIoN(S):
The 1/2SX101A valves are the Essential Service (SX) Water outlet iso _a' ion valves for the Unit 1 and 2 motor driven Auxiliary Feedwater Pu.np lube oil coolers. These valves are required to open to provide a flow path for Essential Service Water through the motor driven APW pump oil coolers.
CODE REQUIREMENT (S):
Stroke Time testing per OM-10, paragraph 4.2.1.4, development of stroke time acceptance criteria per OM-10, paragraph 4.2.1.8, corrective actions per OM-10, paragraph 4.2.1.9 and fail-safe testing per OM-10, paragraph 4.2.1.6.
BASIS FoR RELIEF:
Both of these valves are completely encapsulated per design and do not have local or remote position indicators which could be used to time the valve stroke.
The 1/2SX101A valves are pilot operated globe type solenoid valves which are energized to close. Upon de-energizing (pump start), the valve opens with the aid of a spring force against the plunger, and differential pressure across the mair. disk. Upon energizing, the valve closes by the magnetic force of the coil pulling the plunger down and pressure buildup above the main disk. In the absence of any pressure differential across the main disk, the spring or magnetic force is sufficient to open or close the valve, respectively.
Per the code requirements, these valves cannot be tested by the traditional means of stopwatch and indicating lights. The proposed alternative testing will adequately maintain the system in a state of operational readiness, while not sacrificing the safewy of the plant.
PROPOSED ALTERNATIVE TESTING:
The 1/2SX101A solenoid valves will be verified to open during each quarter?,y ASME surveillance of the motor driven Auxiliary Feedwater Pumps. In additien, these valves are stroked monthly during Auxiliary Feedwater Pump surveillances required by Byron Station Technical Specifications.
p:\sec\ist\istrevla.wpf 3.5.2 Pg. 11 of 28 l
Byrcn 2nd Interval IST M sn Revision 1 December, 1997 RELIEF REQUEST VR-4 TITLE: Difassembly and/or Acoustic Testing of the 1/2AF001A/B Check Valves CODE DRAWING DRAWING VALVE NtMBER CATEGORY CLASS NUMBER COORDINATE 1/2AF001A C 3 M-37(M-122) D2 (E7) 1/2AF001B C 3 M-37(M-122) B2 (B7)
FUNCTION (S):
The open function of these check valves is covered under cold shutdown M justification VC-11.
The closure function of these valves (covered in this relief request) is to maintain adequate suction to the Auxiliary Feedwater Pump and to prevent loss of SX water to the CST when SX is used as the water scarce.
CODE REQUIREMENT (S):
Check valves shall be exercised nominally every 3 months, exces as provided by paras, 4,3.2.2, 4.3.2.3, 4,3.2,4, and 4.3.2,5.
BASIS FoR RELIE1':
Performing a pressure test (by attaching a pump or other pressure source to a test connection and pressurizing the line) to verify closure is impractical due to the system configuration. Adequate closure capabilities of these check valves cannot be verified due to the multiple potential leakage paths (valves, pump seal, and instrument lines). This configuration makes it impossible to assign any observed leakage to any individual component.
Since there are no conventional ways to verify closure of these check valves, acoustic monitoring has been investigated. First, it was attempted co verify closure during the Operating Department Cold Shutdown full stroke test of the 1/2AF001A/B valves in which only a single train of AFW is ran at a time. With an AFW pump running on mini-flow recirculation, flow is initiated to each S/G and increased on a gradual basis, while simultaneously reducing Feedwater flow. As soon as the required flow data is obtained, AFW flow is gradually reduced, while simultaneously increasing Feedwater flow. This is done to minimize Feedwater perturbations to the S/Gs. Due to this gradual change in flow, the open and closed acoustical impacts cannot be detected with acoustical equipment.
However, the acoustic data taken during the 18 month dual pump injection test has provided Byron with a limited amount of success in detecting closure of the 1/2AF001A/B check valves. This test is only performed on refueling outage frequencies due to the large transient placed on Feedwaser flow and the thermal stresses imposed on the Steam Generators. This techniqae may continue to be pursued in future outages.
p:\sec\ist\istrevia.wpf 3.5.2 Pg. 13 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 BILIEF REQUEST VR-4 (continued)
APPROVAL STATUS:
- 1. Submitted with Revision 0 of Byron's 2nd Interval Program (Dec., 1995).
- 2. _ Relief granted per GL 89-04 (Dec., 1995).
3 Approved per NRC SER, dated November 18, 1996 (In response to Revision 0 of Byron's 2nd Interval Program]
, p:\sec\ist\istrevla.wpf 3.5.2 Pg. 15 of 28 I.,
r Byron 2nd Interval IST Plan Revision 1 December, 1997 RELIEF REQUEST VR-5 TITLE: Disassembly of the Main Feedwater Header Check Valves CODE DRAWING DRAWING VALVE NUMBER CATEGORY CLASS NUMBER COORDINATE 1/2FWO79A -C 2 M-36-1C(M-121-1B) C4 (C4) 1/2FWO79B C 2 M-36-1A(M-121-1D) C4 (C4) 1/2FWO79C C 2 M- 3 6 - 1D (M-l'e l- 1 A) C4 (C4) 1/2FWO79D C 2 M-36-1B(M-121-1C) C4 (C4)
FUNCTION (S);
1/2FWO79A-D: Closed: Isolate Steam Generators from an upstream pipe break CODE REQUIREMENT (s):
Per OMa-1988 Part 10, paragraph 4.3.2.1, chcck valves shal'.. be exercised nominally every 3 months, except as provided by paras. 4.3.2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5.
BASIS FoR RELIEF:
The main feedwater header flow check valves are 16-inch tilting disk check valves built with a vertical piston and rod assembly that serves as an eati-4 slam mechanism; the valves do not have external position indicators. The valves are designed to have a delayed closure time of 2 to 3 seconds to isolate flow during a feedwater line break accident without inducing significant water hammer transients. Their closed safety functions are to 1) mitigate a loss of secondary inventory and/or make-up, and 2) provide pressure integrity between the safety and non-safety related portions of piping.
These valves cannot be exercited to their closeo position during power operations because feed flow to a steam gene.rator would be isolated, causing loss of Steam Generator water inventory and a subsequent low S/G level Reactor Trip.
Non-intrusive testing during cold situtdowns has been attempted at Braidwood and Byron Stations with still unproven results. Specifically, ultrasonic examination of the piston rod position has not conclusively demonstrated valve closure: The anti-slam mechanism prevents the disk from travelling completely to its seat after cessation of forward flow. In fact, during normal feedwater system shutdown evolutions, the valves routinely come to rest at a partial open position -- substantial reverse flow or reverse differential pressure would be required to bring the disk into contact with the seat.
p:\sec\ist\istrevla.wpf 3.5.2 Pg. 16 of 2B
L Byron 2nd Interval IST Plan Revision 1 December, 1997 RELIEF REQUEST VR-5 (continued)
Traditional backflow testing methods were considered, but it has been determined that reverse flow and/or differential pressure sufficient to close the valve cannot be obtained without major modification to the existing plant configuration. Clearly, acoustic testing techniques which require contact noise between disk and seat cannot be used for this application, either.
Full-stroke exercising these valves by performing complete disassembly and inspection of each valve during cold shutdown conditions is undesirable and impractical because:
- 1) The main feedwater system would have to be drained. This would both delay reactor start-up and eliminate a method of reactor decay heat removal. The latter, in particular, could adversely affect shutdown safety.
- 2) Complete disassembly often requires' machining activities that remove metal from the valve walls which may jeopardize minimum
-wall _ thickness. If minimum wall thickness is approached, then costly and difficult weld overlay techniques and associated machining would be required. _
- 3) Scaffolding must be built and removed to allow examination of these valves.
Full-stroke exercising these valves by performing partial disassembly (i.e.
removing'only the actuator bonnets) of all four valves on a refueling or cold shutdown frequency is burdensome because of the system draining necessary and the potential wall material loss associated with disassembly and inspection work.
Because major plant modifications would be required to establish enough reverse flow / pressure to fully close the valves,_in-service testing in accordance with NRC Generic Letter'89-04 is justified. The Generic Letter allows valves of similar design, service conditions, etcetera to be classified in sample disassembly and inspection groups of up to four members with testing of one valve in the group during each refueling outage.
In-service testing of the valves that close on a feedwater isolation signal, including the safety-related feedwater containment isolation valves (FWOO9A-D), the non-safety-related feedwater regulating valves (FW510, 520, 530, 540),
and the feedwater regulating bypass valves (FW510A, 520A,...) helps ensure that the pot:er operated valves and the system are capable of safely responding to an initiating feedwater line break accident regardless of FWO79 check valve position.
1 p:\sec\ist\istrevla.apf 3.5.2 Pg. 17 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 RELIEF REQUEST VR-5 (continued)
The alternate test method is sufficient to ensure operability of these valves and is consistent with Generic Letter 89-04 sample disassembly and inspection program. The alternate test method in conjunction with other existing in-service testing of feedwater valves is more than sufficient to ensure the ,
system's ability to ;afely respond to a feedwater line break accident.
PRoPo.9ED ALTERNATIVE TESTING:
The four valves on each unit are of the same design (manufacturer, size, model number, and materials of construction) and nave the same service conditions, including orienta* ion; therefore, they form a sample disassembly group.
One valve from each group, on a per unit basis, will be fully disassembled and examined each refueling outage. If the initial disassembled valve is not capable of being full stroke exercised or if there is binding or failure of internals, subsequent disassembly and inspection of the remaining three group members will be commencurate with the initial valve's failure mode.
This means that the remaining three valves may be " partially" disassembled, which refers to the removal of the actuator (upper) bonnet for inspection of the piston, piston seal ring, mating surfaces, and also for manual full stroke closing. A " fully" disassembled valve (minimum of one per outage) would additionally include removal of the valve body (lower] bonnet, giving access to the disk and seating surfaces. The subsequent disassembly requirements would be saticfied through either " partial" or " full" disassemblies depending on what is found with the initial disassembled valve. This will both satisfy the testing requirements to demonstrate all four valves' ability to perform their safety function and minimize the potential concerns regarding minimum wall thickness discussed earlier. This approach is consistent with Generic Letter 89-04, position 2.
A partial stroke test following complete installation will not be required for these check valves since an "as left" stroke is performed prior to the installation of the actuator bonnet; installation of the actuator bonnet does not affect the stroke of the valve. In addition, the plant operates with these valves in the open position and open stroke problems would be readily iden*.ified during plant startup.
APPROVAL STATUS:
- 1. Submitted with Revision 0 of Byron's 2nd Interval Program (Dec., 1995)
- 2. Relief granted per Generic Letter 89-04 (Dec., 1995).
- 3. Approved per NRC SER dated November 18, 1996 (In response to Revision 0 of Byron's 2nd Interval Program]
p \sec\ist\istrevla.wpf 3.5.2 Pg. 18 of 2B
Byron 2nd Interval IST Plan Revision 1 December. 1997 RELInF REQUEST VR-6 TITLE: Eighteen Month Frequency for the Essential Service Water (SX)
Makeup Pump Discharge Check Valve Closure Test CODE DRAWING DRAWING VALVE NUMBER CATEGORY CLASS NUMBER COORDINATE OSX028A/B C 3 M-42-6 B7 (BG)
FUNCTION (S) ;
OSX028A/B: CloseJ: These check valves need to close to prevent piping druin down from the basins to the river screen house.
Open: Provides a flowpath for Essential Service Water makeup to the basins (full flow tested quarterly)
CODE REQUIREMENT (S)
Per OMa-1988, Pert 10, paragraph 4.3.2.1, check valves shall be exercised nominally every 3 months, except as provided by paras. 4.3.2.2, 4.3,2,3, 4.3.2.4, and 4.3.2.5.
BASIS FCR RELIEF The backflow test for the OSX028A/B check valves was added to the IST Valve Program in Rev 12 of the First Ten Year IST Interval Program due to their closure function to prevent piping drain down from the basins to the river screen house. Since their incorporation into the program, the OSX028A and OSX028B check valves have been successfully tested for closure using acoustics y during the respective A or B makeup pump runs a minimum of once each quarter.
Each valve has succersfully been tested 7 consecutive times without any signs of degradation or failure.
Nonintrusive techniquet e considered to be "other positive means" in accordance with ASME Sect.an XI INV-3522. As described in NUREG 1482, nonintrusive techniques may be used to verify the capability (of check valves]
to open, close, and fully stroke.
The acoustic testing of both of these valves on an eighteen month frequency (at approximately the same time period) is justified for the following reasons:
piisec\ist\istrevia.wpf 3.5.2 Pg. 19 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 RELIEF REQUEST VR-6 (continued)
Byron Resconse;
- a. Low Risk Sionificance Associated with the Check Valves Failino to Close The failure of these check valves to close is considered a non-risk significant event due to the redundant equipment available to ensure that the basins will retain their inventory and receive makeup cooling water, as required. The failure of these check valves to close is not specifically modeled in the PRA. When evaluating risk, all safety and non-safety related equipment available for mitigating the event, is reviewed. If one of these valves fails to close and backleakage occurs, the line could be isolated from the basin by closure of a manual valve next to the check valve (not tested by IST) or MOVs near the entry into the basin (not tested by IST). An alternate way to overcome the leakage would be to start up the pump on the line with the defective valve.
Finally, there are alternate ways to makeup to the SX basins, which include the non-safet.y related Circulating Water makeup lines or the non-safety related, but ';eismically qualified, Deep Well Water makeup lines. During normal-operation, Circulating Water is the preferred method of makeup to the bosin. Additionally, the two SX basins overflow into each other at a level cf 64%.
- b. Low Safety Sionificance Associated with the Check Valves Failino to Close:
The safety significance of these check valves failing to close would result in a potential for piping drain down from the basins to the river screen house, approximately 5 miles away from the plant. The safety-related SX makeup pumps are the emergency source of makeup to the basins. If an SX pump is called upon to operate in a post-accident situation, it is desirable to avoid the potential delay involved in transporting water to the basin to ensure that the ultimate heat sink analysis remains valid. The ultimate heat sink consiets of the two essential service water mechanical draft cooling towers and the makeup system to these cooling towers. The elevation difference of approximately 200 feet between the river and the SX basins make this a possibility.
The SX basins should not be drained to a point of concern even if one of the makeup check valves did fail. During normal operations, the SX "A" and "B" basin levels are maintained at approximately 82%, with makeup generally coming from the non-safety related Circulating Water pumps.
At 64% level, the SX basins overflow into one another. If the leve in one basin reaches 56%, an alarm is received in the Control Room and automatic makeup from the respective SX makeup pump begins at 53% level.
Even if the alarms and automatic makeup failed, the SX makeup lines enter the basin at a level near the Technical Specification limit of 50%, ensuring that significant levels will remain in the basins.
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Byron 2nd Interval IST Plan Revision 1 December, '997 i
RELIEI' REQUEST VR-6 (continued)
Additionally, either train of SX makeup would be capable of supplying the basins with enough water to satisfy the ultimate heat sink analysis.
In the unlikely event that the downstream piping of an SX Makeup Pump were to completely drain, the pump suction at the river would have enough suction head to allow the refilling of the downstream piping and establishment of makeup to the SX basin without extraordinary operator actions er damage to the SX Makeup Pump. The failure of one of these check va2ves to close would be minimal and easily overcome,
- c. Performing the acoustic test on both valves on an eighteen month frequency will ensure the operational readiness of the valves. These valves have been in operation for approximately 10 years without failure '
and have successfully passed their acoustic testing for seven tests in a row since being added to the IST program.
Byron's assessment of this valve is solely based on the testing performed on the valve. The open valve position is tested quarterly with full flow during each pump run. An acoustic test is used to prove closure. This test is currently performed quarterly, during the same surveillance, when the pump is shut down. Due to the elevation differences between the piping discharging into the basin and the much lower elevation of the river screen house (location of the SX makeup pump discharge check valves), a good signal is recorded for the closure of these check valves.
A maintenance history review of these SX discharge check valves has indicated that maintenance has been nonexistent since startup on these valves. There are no past or present work requests for them. However, due to the corrosive nature of the.SX system, Byron plans on beginning a program to disassemble and inspect a series v. SX check valves associated with maintaining the ultimate heat sink water inventory (included are the "A" and "B" train IST check valves for isolating Circulating Water makeup, "A" and "B" train IST check valves for isolating the Deep Well Water makeup, and the SX makeup check valves discussed in this relief request) Byron currently has internal parts for the first valve disassembly, but is waiting for a valve body to arrive. This would allow a quick disassembly and replacement necessitated by LCOAR time requirements. If a rebuild is required, maintenance personnel could do this without the time pressures involved with the LCOAR. This program will begin shortly after the arrival of the valve body (replacement would most likely occur during the 1st quarter of 1996). Following the inspection of these valves, the resulto will be reviewed to determine an optimum disassembly intervtl. Based or.
the good test results obtained for the SX discharge check valvet for closure and the fact that they have not failed in over 10 years, these check valves may be inspected last in the rotation. These disassembly pr\sec\ist\istrevla.wpf 3.5.2 Pg. 21 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 RELIEF REQUEST VR-6 (continued) and inspections will be highly dependent on the availability of parts and appropriate plant conditions, bat completion ' this rotation would be expected within the next few years,
test is completed. The check valve will be opened and then closed on cessation of flow. The full flow test will be completed quarterly, verifying operability in the forward flow direction.
- e. In addition, this eighteen month frequency will reduce the amount of manhours required in performing the acous;ics at the river screen house a few miles from the Byron plant on the Rock River. 1-or each test (8 times a year), approxir..ately one full day (8 days a year) is expended by the qualified acoustic monitoring individual to transfer the equipment to the river screen house, set up the equinment, record the data, transfer the equipment back to the station, evaluate the data, and complete surveillances.
A typical test day would b* gin down at the river screen house, setting up, coordinating with Operations and the System Engineer for running the test. The afternoon would typically be spent evaluating the data and completing the surveillances.
Byron's Check Valve Program resides in the Site Engineering Pr0 grams group. Individuals within this group generally have multiple responsibilities assigned to them. One respo;sibility of the Check Valve Coordinator is to perform acoustic tests on check valves, where applicable. In addition, this individual is responsible for maintaining a Check Valve Program of over 500 valves (with plans to review another 2000 balance of plant check valves). Additional tasks of the individual who has recently become the Check Valve Coordinrtor includes the ASME Pressure Test Program. Byron does not have an individual who is totally dedicated to acoustic monitoring. The individual who performs this testing will always have other collateral duties which will consume a considerable amount of time. Hence, it is desired to test components such as these checs valves at a frequency which is commensurate to their level of safety to ensure all activities receive the appropriate level of attention, p:\sec\ist\istrevla.wpf 3.5.2 Pg. 22 of 28 l
Byron 2nd Interval IST Plan Revision 1 December, 1997 RELIEF REQUEST VR-6 (continued)
PROPOSED ALTERNATIVE TESTING:
Byron proposes to complete bpqth of the OSX028A/B backflow acoustic tests at a minimum of once per 18 months.
APPROVAL STATUS:
- 1. Submitted with Revision 0 of Byron's 2nd Internal Program (Dec. ,1995) .
- 2. Approved per NRC SER, dated November 18, 1996 (In response to Revision 0 of Byron e 2nd Interval Program].
4-p:\sec\ist\istrevla.wpf 3.5.2 Pg. 23 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 Withdrawn l
RELIEF REQUEST VR-7 I
) TITLE: Eighteen Month Frequency for the Full Stroke Tesc of the Deep Well Pump Discharge Check Valves CODE DRAWING DRAWING VALVE NUMBER CATEGORY CLASS NUMBER COORDINATE 05X127A/B BC 3 M-42-6 B2 (B4)
FUNCTION ( 5) :
OSX127A/B: Closed: These check valves need to close to prevent a loss of required emergency makeup water flow into the Deep Wells rather than to the Ultimate Heat Sink (see ROJ-1)
Open: These check valves are required to open to provide a flow path for Deep Well Water to the Ultimate Heat Sink as a backup to the Emergency Makeup Pumps.
CODE REQUIREMENT (S) :
Per OMa-1968, Part 10, paragraph 4.3.2.1, check valves shall be exercised nominally every 3 months, except as provided by paras, 4.3.2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5.
BASIS FoR RELIEF:
The OSX127A and OSX127B check valves open to provide a flow path for Deep Well Water to the Ultimate Heat Sink as a backup to the Emergency Makeup Pumps.
The nonsafety related, seismically qualified, Deep Well P;rps
( 0NWU1PA/0NWO1PB) are physically inaccessible and we *e not designed or installed in accordance with ASME code and are not required as long as the Emergency SX Makeup Pumps are available. Although the pumps do not fit the requirements of the IST Program, they do have significant importance and are tested outside of tha IST Program as required per Tech Spec 3.'4.7.5. The safety related check valves referenced in this relief request were conservatively added to the IST Program in the open direction to acknowledge the importance of ensuring the deep well flow path is capable of transferring water to the ultima:e heat sink.
in reference to the deep well pumps, per Tech Spec 4.7.5, the Ultimate Heat Sink shall be determined operable: at least once per 31 days by starting each deep well pump, operating it for at least 15 minutes and verifying that each valve (manual, power-operated, or automatic) in the flow path is in its correct position and; at least once per 18 months by verifying each deep well pump will provide at least 550 gpm flow rate.
p:\sec\ist\istrevla.wpf 3.5.2 Pg. 24 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1697 Withdrawn l RELIEF REQUEST VR-7 (continued)
- Byron proposes to complete a full stroke test for check valves USX127A and OSX127B at a minimum of once every eighteen months, as required by Technical Specifications. Testing on a more frequent basis would be completed in accordan>;e with station commitments. This test will be accomplished by executing the Byron Station deep well surveillance in which, first, the "A" pump is lined up to the "A" basin and an ultrasonic flowmeter is attached to the makeup line (following the removal of a security barrier). The demand (throttling) valve is opened until a minimun flow reading of at least 550 gpm is obtained through the line (and check valve OSX127A) . In addition, the amperage of the pump is recorded. Then, the "A" pump is shut down and the valves are re-aligned to the "B" Basin, in which there is no accessible piping of adequate length to attach an ultrasonic flowmeter. However, the same "A" pump is restarted and set to an amperage greate: than or equal to the amps just recorded for the A basin flovpath. Byron Station trends flow versus amps for the Deep Well Pumps to help track degradation with the pumps, as required through a station commitment to the NRC. This should assure a full stroke test for the OSX127B cneck valve (using other " positive means"). In addition, the A and B basins overflow into each other at 64% level, minimizing the importance of knowing the exact flow through the "B" makeup line (although it should be the same as just recorded through the "A" makeup line). Finally, the "B" pump is verified to generate an output greater than 550 gpm through the "A" train makeup line-to satisfy the Tech Spec requirement.
In addition to the above terting, Byron will ensure operability of the Deep Well Pumps by executing an operating surveillance monthly in which the "A" pump is lined up to the "A" basis and the "B" pump is lined up to the "B" basin. In each case the demand for each pump will be at oc near 100%, which should assure a full stroke of each check valve every month. However, since flow is not measured, it will be considered a partial stroke each month.
The alternative _ testing requirements will not compromise the level of quality and safety when compared to quarterly code testit.g for the following reasons:
- a. Byron Tech Specs are being satisfied through the eighteen month Deep Well Pump procedure and the monthly operating procedure. This testing will satisfy the operability lequirements for the Deep Well Pumps and the flowpaths to the SX basin. In addition, the same or more flow is transferred through the check valves each month than during the procedure executed every eighteen months. The flowrates would be verified during the eighteen month procedure.
- b. An ultrasonic flowmeter cannot be used on the "B" basin makeup line due to the lack of accessible piping available. In addition, at this time, inconclusive acousti; results were obtained for the full stroke test 3ng on these valves. Finally, flow versus amps is trended to help aid in determining any degradatica in the Deep Well Pumps.
p:\sec\ist\1strevla.wpf 3.5.2 Pg. 25 of 28 l
Byron 2nd Intervel IST Plan Revision 1 December, 1997 Withdrawn RELIEF REQUEST VR-7 (continued)
PROPOSED ALTERNATE TESTING:
These valves will be tested in accordance with Byron Tech Specs. The full stroke test for check valves OSX127A and 03X127B will be completed on an eighteen month frequency in addition to a monthly flowpath verification (considered partial stroke).
APPROVAL STATUS:
- 1. Submitted with Revision 0 of Byron's 2nd Interval Program (Dec., 1995).
- 2. Approved per NRC SER, dated November 18, 1996 (In response to Revision 0 of Byron's 2nd Interval Program) .
- 3. Withdrawn as modification removed OSX127A/B, p:\sec\ist\istrevla.wpf 3.5.2 Pg. 26 of 28
Byron 2nd Interval IST Plan Revision 1 December, 1997 RELIEF RIQUEST VR-B TITLE: Non-IST Monthly Test of Diesel Generator Air Start System Valves CODE DRAWING DRAWING VALVE NUMBER CATEGORY CLASS NUMBER COORDINATE_
1/2DG5182A B N/A M-152-20 B5 (BS) 1/2DG5182B B N/A M-152-20 BS (BS) 1/2DC5183A B N/A M-152-20 ES (ES) 1/2DG5183B B N/A M-152-20 ES (ES) 1/2DG5184A C N/A M-152-20 B6 (B6) 1/2DG5184B C N/A M-152-20 B6 (B6) 1/2DG5185A C N/A M-152-20 F6 (F6) 1/2DG5185B C N/A M-152-20 F6 (F6) l FUNCTION ( s) :
This relief request covers the open function of these valves only. They are required to open in order to supply starting air to the Diesel Generators, code REQUIREMENT (S) :
These valves are not within the scope of the IST Program per 10CFR50.55 (a).
However, the requirements for stroke timing and trending of the valves associated with the Diesel Air Start System are being mandated by the NRC as an augmented testing requirement pursuant to 10CFR50.55 (6) (11) .
Therefore, valves associated with the Diesel Air Start System shall be exercised to the position required to fulfill their function per OM-10, Paragraphs 4.2.1.1 and 4.3.2.2. Additionally, the stroke testing of power operated valves shall be measuced to the nearest second and such stroke times compared to the initial reference valves to document continued valve
, operational readiness per OM-10, paras . 4.2.1.4 (b) , 4.2.1.8, and'4.2.1.9.
BASIS FoR DELIEF:
The monthly Diesel Generator testing program, outlined in Byron Station's Technical Specifications and implemented by station operating procedures, exceeds the incent of the quarterly valve testing program which would be required by OM-10, Paragraph 4.2.1.2. Additionally, the stroke timing of solenoid operated valves associated with the Diesel Air Start System is impractical due to the fast actuation of these valves.
Proper valve operation w!11 be d?monstrated on a monthly basis by the verification of diesel generator air start capability. Such verification will compare the air pressures contained in the receiver tanks both before and after the diesel generator start, thus verifying the operability of the air start control valves. The proposed testing methodology at the increased frequency satisfies the intent of the Section XI requirements without pocing undue hardships or difficulties, ps\sec\ist\istrevla.wpf 3.5.2 Pg. 27 of 28
Byron 2nd Interval IST Plan Revision.1 December, 1997 RELIEF ITWUEST VR-8 (continued)
PROPOSED ALTERNATIVE TESTING:
The performance of Byron Station's Diesel Generator operability monthly surveillance-will verify the operational readiness of the valves associated with the Diesel Air Start System.
This surveillance testing will require the recording of the air pressures contained in both trains A & B of the Diesel Generator Air Start Receiver Tanks both before and immediately after diesel generator start.
By the comparison of these valves between trains, the satisfactory operation of the power operated and self-actuated check valves associated with the Diesel Air Start System can be adequately demonstrated.
APPROVAL STATUS:
- 1. Submitted with Revision 0 of Byron's 2nd Interval Program (Dec. ,1995) .
- 2. Relief granted due to involvement of Non-IST Components (Dec., 1995).
- 3. Approved per NRC SER, dated November 18, 1996 (In response to Revision 0 of-Byron's 2nd Interval Program),
p:\sec\ist\istrevla.wpf 3.5.2 Pg. 28 of 28 l
Byron 2nd Intsrval IST Plar.
Revision 1 December, 1997 VALVE _REFERENc3 LIST
~
1.
Title 10 Code of Federal Regulations, Part 50, Domestic Licensing of Production and Utilization Facilitaes, particularly Section 50.55a, Codes and Standards.
- 2. ASME Boiler and Pressure Vessel Code,Section XI, Rules for Inservice Inspection of Nuclear Power Plant Components, 1989 Edition.
- 3. ASME/ ANSI OM-1987, Operation and Maintenance of Nuclear Power Plants, including 1988 Addenda, Part 10, Inservice Testing of Valves in Lignt Water Reactor Power Plants.
4.
U.S. Nuclear Regulatory Commission, Generic Letter 89-04, Guidance on Developirg Acceptable Inservice Testing Programs.
- 5. US Nuclear Regulatory Commission, Generic Letter 89-04, Supplement 1 NUREG 1482 Guidance on Developing Acceptable Inservice Testing Programs.
- 6. Byron /Braidwood Station UFSAR, Section 3.9.6.2, Inservice Testing of Valves.
7 Byron Station Technical Specification 3/4.0.5, Generic ASME Program Requ irement .
- 8. Byron Technical Staff Procedure, BVP 200-2, IST Requirements for Valves.
- 9. Robert A. Capra (Office of Nuclear Reactor Regulation) letter to Mr. D.
L. Farrar (Comed), da*.ed February 7, 1996, allowing Syron Station to implement concurrent intervals throughout c 1 life of Unit 1 and Unit 2.
- 30. Roger A. Capra (Office of Nuclear Reactor Regulation) letter to Ms.
Irene M. Johnson (Comed), dated November 18, 1996, transmittir g Byron station's NRC SER .for Revision 0 Byron's 2nd Interval IST Pump and Valve
-Program, a
(Final) pr\sec\ist\istrevla.wpf Section 3.6.1 Pg. 1 of 1 1
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