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Category:SAFETY EVALUATION REPORT--LICENSING & RELATED ISSUES
MONTHYEARML20212J9251999-10-0101 October 1999 Safety Evaluation Accepting Licensee Relief Request IWE-3 for Second 10-year ISI for Plant ML20211N2611999-09-0808 September 1999 Safety Evaluation Concluding That Proposed Irradiation of Fuel Rods Beyond Current Lead Rod Burnup Limit & Clarification of Terminology with Respect to Reconstituted Fuel Assemblies Acceptable ML20211J2421999-08-31031 August 1999 Safety Evaluation Supporting Removal of Augmented Insp Program on RCS Bypass Lines from Licensing Basis of North Anna,Units 1 & 2 ML20211J2561999-08-31031 August 1999 Safety Evaluation Accepting Elimination of Augmented ISI Program for Pressurizer Spray Lines at North Anna Unit 2 ML20210T0791999-08-13013 August 1999 Safety Evaluation Concluding That Revised Withdrawal Schedules for North Anna Units 1 & 2 Satisfy Requirements of App H to 10CFR50 & Therefore Acceptable ML20206L4831999-05-10010 May 1999 SER Accepting Request to Delay Submitting Plant,Unit 1 Class 1 Piping ISI Program for Third Insp Interval Until 010430, to Permit Development of Risk Informed ISI Program for Class 1 Piping ML20205S0391999-04-21021 April 1999 SER Accepting Request for Relief IWE5,per 10CFR50.55a(a)(3) & Proposed Alternatives for IWE2,IWE4,IWE6 & IWL2 Authorized Per 10CFR50.55a(a)(3)(ii) ML20198H9541998-12-0303 December 1998 Safety Evaluation Authorizing Proposed Alternative for Remainder of Second 10-yr Insp Interval for Plant ML20196G1381998-11-0303 November 1998 Safety Evaluation Authorizing Rev to Relief Request NDE-32 for Remainder of Second 10-yr Insp Interval for Each Unit ML20236K5531998-07-0707 July 1998 SER Accepting Request for Change in ISI Commitment on Protection Against Pipe Breaks Outside Containment ML20248C8831998-05-29029 May 1998 SER Accepting Alternatives Proposed by Licensee for Use of Code Case N-535,pursuant to 10CFRa(a)(3)(i) in ASME Section XI Inservice Insp Program ML20217B5321998-04-20020 April 1998 Safety Evaluation Supporting Proposed Alternative to ASME Code for Surface Exam of Seal Welds on Threaded Caps for Plant Reactor Vessel Head Penetrations for part-length CRDMs ML20216E8801998-03-0606 March 1998 Safety Evaluation Authorizing Licensee Request for Relief from ASME Code Requirements,Paragraph IWA-2400(c) (Summer Edition W/Summer 1983 Addenda),For Upcoming Naps,Unit 1 Outage,Per 10CFR50.55a(a)(3)(ii) ML20199J6431998-02-0202 February 1998 Safety Evaluation Approving Request for Approval to Repair Flaws in Accordance W/Gl 90-05 for ASME Code Class 3 SW Piping for North Anna,Unit 1,as Submitted in ISI Relief Request NDE-46 on 971218 ML20198S7571998-01-15015 January 1998 Safety Evaluation Accepting Licensee Request for Approval to Repair Flaws IAW GL-90-05 for ASME Code Class 3 Svc Water Piping ML20198H5541997-12-29029 December 1997 SER Accepting Request for Approval of ASME Case N-498,rev 1, as an Alternative to Required Hydrostatic Pressure Test for Plant,Unit 2 ML20197K1541997-12-18018 December 1997 SER Granting Request for Approval to Repair Flaws in Accordance W/Gl 90-05 for ASME Code Class 3 Service Water Piping for North Anna Power Station,Per Util 970919 Submittal ML20199L0501997-11-24024 November 1997 SER Accepting Inservice Insp Program Relief Request NDE-32 ML20199E4971997-11-14014 November 1997 Safety Evaluation Authorizing Proposed Alternative of Licensee Relief Requests NDE-35 & NDE-37,for Plant,Units 1 & 2 During Second 10 Yr Interval ML20217E0701997-09-24024 September 1997 Safety Evaluation Granting Licensee ASME Section XI Relief Request NDE-33 at Plant,Unit 1 ML20217E2411997-09-24024 September 1997 SER Accepting Request for Approval to Repair Flaws in Accordance W/Gl 90-05 for ASME Code Class 3 Service Water Piping,Virginia Electric & Power Co,North Anna Power Station,Unit 1 ML20217E1871997-09-24024 September 1997 SER Approving Request for Approval to Repair Flaws in Accordance W/Gl 90-05 for ASME Code Class 3 Service Water Piping,Virginia Electric & Power Co,North Anna Power Station,Units 1 & 2 ML20149L2001997-07-29029 July 1997 SER Granting Requests for Relief NDE-33,34 & 35 Re ISI Program,Per 10CFR50.55a(g)(6)(i) ML20149F1321997-07-17017 July 1997 Safety Evaluation Supporting Amends 205 & 186 to Licenses NPF-4 & NPF-7,respectively ML20148H1971997-06-0404 June 1997 Safety Evaluation Granting Licensee Relief Request NDE-31 Related to Inservice Insp Program ML20140F4811997-04-30030 April 1997 Safety Evaluation Accepting Licensee 951207 Proposed Alternative in Request for Relief SPT-16 Re Second 10-yr Interval Inservice Insp Program for Unit 2 ML20133G1561997-01-10010 January 1997 Safety Evaluation Accepting Second 10-year Relief Requests for Relief Numbers NDE-27,NDE-28 & NDE-29 ML20133G1911997-01-10010 January 1997 Safety Evaluation Accepting Second 10-year Interval Inservice Insp Plan Relief Request NDE-30 ML20138G1931996-10-16016 October 1996 SER Accepting Second 10-year Interval Inservice Insp Plan Request for Relief SPT-14,rev 1 Virginia Electric & Power Co North Anna Power Station,Unit 2 ML20128P1701996-10-10010 October 1996 Safety Evaluation Supporting Second 10-year Interval Inservice Insp Program Plan Requests for Relief NDE-23 Through NDE-30 for Plant Unit 2 ML20128F5981996-10-0101 October 1996 Safety Evaluation Authorizing Licensee Proposed Alternative to Examine Terminal End Welds on Lower Regenerative Heat Exchanger sub-vessels,per 10CFR50.55a(a)(3)(ii) ML20059M1181993-11-15015 November 1993 SER Accepting Category 3 Qualification in Lieu of Category 2 for Pressure Monitoring Instrumentation ML20057C0401993-09-17017 September 1993 Safety Evaluation Re Inservice Testting Program Requests for Relief ML20126C1221992-12-0404 December 1992 Safety Evaluation Authorizing Util to Continue Current Test Method for Interim Period,Based on Util Plans to Develop & Implement Use of non-intrusive Testing Techniques for Check Valves Following 1993 Unit 2 Refueling Outage ML20125B7251992-12-0303 December 1992 Safety Evaluation Granting Temporary Exemptions from Requirements of GDC-2 & 10CFR50.49 for Phase 1,stage 1 of Svc Water Sys Restoration Project ML20062C4441990-10-18018 October 1990 SER Re Station Blackout.Plant Does Not Conform W/Station Blackout Rule ML20247C2091989-09-0707 September 1989 Safety Evaluation Accepting Util 890512 Response to IE Bulletin 80-11, Masonry Wall Design ML20245J8401989-06-28028 June 1989 Safety Evaluation Supporting Restart of Unit 1 & Util 890528 Response to NRC Bulletin 89-001, Failure of Westinghouse Mechanical Steam Generator Tube Plugs ML20195J0061988-11-29029 November 1988 Safety Evaluation Supporting Licensee Responses to NRC Bulletin 88-002, Rapidly Propagating Fatigue Cracks in Steam Generator Tubes, Subj to Util Adopting Addl Administrative Controls ML20207F1391988-08-12012 August 1988 Safety Evaluation Supporting Util Responses to IE Bulletin 80-11, Masonry Wall Design, W/Exception of One Open Item ML20196G9081988-03-0404 March 1988 SER Re Util 831104 & 850208 Responses to Generic Ltr 83-28, Item 2.2.1, Equipment Classification (Program for All Safety-Related Components. Responses Acceptable ML20149J9301988-02-18018 February 1988 Safety Evaluation Re Relief Request 6 of Inservice Testing Program for Pumps & Valves ML20154E8221987-12-11011 December 1987 Safety Evaluation Supporting Util Identification of Major Causal Factors Leading to 870715 Tube Rupture Event & Adequacy of Diagnostic & Corrective Measures Implemented in Order to Preclude Similar Events ML20237B5981987-12-11011 December 1987 Safety Evaluation Accepting Util 870915 & 0925 Responses to Steam Generator Tube Rupture on 870715.Util Has Adequately Demonstrated That Primary Failure Mechanism Leading to Event Caused by flow-induced Vibration ML20236F4971987-10-23023 October 1987 Safety Evaluation Re Util 870925 Request for Approval of Steam Generator Downcomer Flow Resistance Plate Mods & Increase in Calculated Offsite Dose Per 10CFR50.59.Mods Acceptable ML20235U8811987-07-13013 July 1987 Safety Evaluation Supporting Request for Relief from Certain Exam & Hydrostatic Test Requirements of ASME Code ML20213G8081987-05-11011 May 1987 SER Re Util 850208 Response to Generic Ltr 83-28,Item 2.1 (Part 2), Vendor Interface Programs (Reactor Trip Sys Components. Program Acceptable ML20212K5111987-02-27027 February 1987 SER Accepting Licensee 831104 Response to Generic Ltr 83-28, Item 4.5.2, Reactor Trip Sys Reliability,On-Line Testing ML20207Q0651987-01-0909 January 1987 Safety Evaluation Denying Util 850401 Request to Reduce Number of Thimbles Required for Monthly Surveillance Flux Mapping ML20215D0811986-09-30030 September 1986 Safety Evaluation Granting Util 860613 Request for Relief from Inservice Hydrostatic Test Requirements for Svc Water Spray Sys 1999-09-08
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217N9281999-10-20020 October 1999 Special Rept:On 991003,PZR PORV Actuation Mitigated RCS low- Temp Overpressure Transient.Caused by a RCP Facilitating Sweeping of Entrained Air Out of RCS Loops.Operating Procedure 2-OP-5.1 Will Be Revised ML20217H3631999-10-14014 October 1999 Rev 0 to COLR for North Anna 2 Cycle 14 Pattern Su ML18152A2811999-10-12012 October 1999 Technical Basis for Elimination of Nozzle Inner Radius Insps (for Nozzles Other than Reactor Vessel),Technical Basis for ASME Section XI Code Case N-619. ML20212J9251999-10-0101 October 1999 Safety Evaluation Accepting Licensee Relief Request IWE-3 for Second 10-year ISI for Plant ML20217D6851999-09-30030 September 1999 Monthly Operating Repts for Sept 1999 for North Anna Power Station,Units 1 & 2.With ML20211N2611999-09-0808 September 1999 Safety Evaluation Concluding That Proposed Irradiation of Fuel Rods Beyond Current Lead Rod Burnup Limit & Clarification of Terminology with Respect to Reconstituted Fuel Assemblies Acceptable ML20211J2561999-08-31031 August 1999 Safety Evaluation Accepting Elimination of Augmented ISI Program for Pressurizer Spray Lines at North Anna Unit 2 ML20216E5011999-08-31031 August 1999 Monthly Operating Repts for Aug 1999 for Naps,Units 1 & 2. with ML20211J2421999-08-31031 August 1999 Safety Evaluation Supporting Removal of Augmented Insp Program on RCS Bypass Lines from Licensing Basis of North Anna,Units 1 & 2 ML20210T0791999-08-13013 August 1999 Safety Evaluation Concluding That Revised Withdrawal Schedules for North Anna Units 1 & 2 Satisfy Requirements of App H to 10CFR50 & Therefore Acceptable ML20210S1411999-07-31031 July 1999 Monthly Operating Repts for July 1999 for North Anna Power Station.With ML20210Q9931999-07-31031 July 1999 Rev 1 to COLR for North Anna Power Station,Unit 2 Cycle 13 Pattern Ud ML20209E5641999-06-30030 June 1999 Monthly Operating Repts for June 1999 for North Anna Power Stations,Units 1 & 2.With ML20195G1901999-05-31031 May 1999 Monthly Operating Rept for May 1999 for NAPS Units 1 & 2. with ML20206L4831999-05-10010 May 1999 SER Accepting Request to Delay Submitting Plant,Unit 1 Class 1 Piping ISI Program for Third Insp Interval Until 010430, to Permit Development of Risk Informed ISI Program for Class 1 Piping ML20206Q6671999-04-30030 April 1999 Monthly Operating Repts for Apr 1999 for North Anna Power Station,Units 1 & 2.With ML20205S0391999-04-21021 April 1999 SER Accepting Request for Relief IWE5,per 10CFR50.55a(a)(3) & Proposed Alternatives for IWE2,IWE4,IWE6 & IWL2 Authorized Per 10CFR50.55a(a)(3)(ii) ML20205K3041999-03-31031 March 1999 Monthly Operating Repts for Mar 1999 for North Anna Power Station,Units 1 & 2.With ML20207K5921999-02-28028 February 1999 Monthly Operating Repts for Feb 1999 for North Anna Power Station,Units 1 & 2.With ML20207E1731999-02-18018 February 1999 Informs Commission of Status of Preparations of IAEA Osart Mission to North Anna Nuclear Power Plant Early Next Year ML20205A0241998-12-31031 December 1998 Summary of Facility Changes,Tests & Experiments,Including Summary of SEs Implemented at Plant During 1998,per 10CFR50.59(b)(2).With ML20199C8781998-12-31031 December 1998 Monthly Operating Repts for Dec 1998 for North Anna Power Station,Units 1 & 2.With ML20198H9541998-12-0303 December 1998 Safety Evaluation Authorizing Proposed Alternative for Remainder of Second 10-yr Insp Interval for Plant ML20198J5561998-12-0303 December 1998 ISI Summary Rept for North Anna Power Station,Unit 1 1998 Refueling Outage Owner Rept for Inservice Insps ML20197G8551998-11-30030 November 1998 Monthly Operating Repts for Nov 1998 for North Anna Power Station,Units 1 & 2.With ML20196G1381998-11-0303 November 1998 Safety Evaluation Authorizing Rev to Relief Request NDE-32 for Remainder of Second 10-yr Insp Interval for Each Unit ML20195D0571998-10-31031 October 1998 Monthly Operating Repts for Oct 1998 for North Anna Power Station,Units 1 & 2.With ML20154L0691998-10-14014 October 1998 COLR for North Anna Power Station Unit 1 Cycle 14 Pattern Xy ML20155J6911998-10-0909 October 1998 Staff Response to Tasking Memorandum & Stakeholder Concerns ML20154H4001998-09-30030 September 1998 Monthly Operating Repts for Sept 1998 for North Anna Power Station,Units 1 & 2.With ML20151X8011998-09-10010 September 1998 Special Rept:On 980622,groundwater Level at Piezometer P-22 Was Again Noted to Be Above Max Water Level by 0.71 Feet. Increased Frequency of Piezometer Monitoring & Installed Addl Piezometers at Toe of Slope Along Southwest Section ML20151W4711998-08-31031 August 1998 Monthly Operating Repts for Aug 1998 for North Anna Power Station Units 1 & 2.With ML20237A4341998-07-31031 July 1998 Monthly Operating Repts for July 1998 for North Anna Power Station,Units 1 & 2 ML20236V1251998-07-14014 July 1998 ISI Summary Rept for Naps,Unit 2,1998 Refueling Outage Owners Rept of Isis ML20236K5531998-07-0707 July 1998 SER Accepting Request for Change in ISI Commitment on Protection Against Pipe Breaks Outside Containment ML20236M3381998-06-30030 June 1998 Monthly Operating Repts for June 1998 for North Anna Power Station,Units 1 & 2 ML20248M1011998-05-31031 May 1998 Monthly Operating Repts for May 1998 for North Anna Power Station,Units 1 & 2 ML20248C8831998-05-29029 May 1998 SER Accepting Alternatives Proposed by Licensee for Use of Code Case N-535,pursuant to 10CFRa(a)(3)(i) in ASME Section XI Inservice Insp Program ML20247K9281998-05-15015 May 1998 Special Rept:On 980428,letdown PCV Exhibited Slow Response When C RCP Was Started.Cause to Be Determined.Review of Operating Procedure Will Be Performed to Determine If Enhancements Are Necessary ML20216A8971998-05-0606 May 1998 Rev 0 to Cycle 13 Pattern Ud COLR for North Anna Unit 2 ML20247F4441998-04-30030 April 1998 Monthly Operating Repts for Apr 1998 for North Anna Power Station,Units 1 & 2 ML20217B5321998-04-20020 April 1998 Safety Evaluation Supporting Proposed Alternative to ASME Code for Surface Exam of Seal Welds on Threaded Caps for Plant Reactor Vessel Head Penetrations for part-length CRDMs ML20217H9611998-04-0707 April 1998 Special Rept:On 980216,groundwater Level at Piezometer P-22, Again Noted to Be Above Max Water Level by 0.41 Feet.Design Package for Installation of Addl Standpipe Piezometers at Toe of Slope Southeast Section,Developed ML20216B1891998-03-31031 March 1998 Monthly Operating Repts for Mar 1998 for North Anna Power Station,Units 1 & 2 ML20216E8801998-03-0606 March 1998 Safety Evaluation Authorizing Licensee Request for Relief from ASME Code Requirements,Paragraph IWA-2400(c) (Summer Edition W/Summer 1983 Addenda),For Upcoming Naps,Unit 1 Outage,Per 10CFR50.55a(a)(3)(ii) ML20216E2561998-02-28028 February 1998 Monthly Operating Repts for Feb 1998 for North Anna Power Station,Units 1 & 2 ML20199J6431998-02-0202 February 1998 Safety Evaluation Approving Request for Approval to Repair Flaws in Accordance W/Gl 90-05 for ASME Code Class 3 SW Piping for North Anna,Unit 1,as Submitted in ISI Relief Request NDE-46 on 971218 ML20202D5811998-01-31031 January 1998 Monthly Operating Repts for Jan 1998 for North Anna Power Station,Units 1 & 2 ML20198S7571998-01-15015 January 1998 Safety Evaluation Accepting Licensee Request for Approval to Repair Flaws IAW GL-90-05 for ASME Code Class 3 Svc Water Piping ML20198P1351997-12-31031 December 1997 Monthly Operating Repts for Dec 1997 for North Anna Power Station,Units 1 & 2 1999-09-08
[Table view] |
Text
( . . . .- . . - . . - . - - - - ..
- f. 4 UNITED STATES NUCLEAR REGULATORY COMMISSION 5 '
WASHINGTON, D.C. 2006M001 I
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l 1
SAFETY EVALUATION BY THE OFFICE OF NVCLEAR REACTOR REGULATION
, RELATED TO AMENDMENT NOS. 205 AND 186 TO I l
FACILITY OPERATING LICENSE NCS. NPF-4 AND NPF-7 VIRGINIA ELECTRIC AND POWER COMPAN1
. l OLD DOMINION ELECTRIC COOPERATIVE- l l
. NORTH ANNA POWER STATION. UNIT NOS. 1 AND 2 QQCKET NOS. 50-338 AND 50-339
1.0 INTRODUCTION
i By letter dated December 17, 1996, Virginia Electric and Power Company (licensee) requested temporary changes to Technical Specifications (TS) 3.7.3.1, " Component Cooling Water (CCW) Subsystem - Operating," and 3.7.4.1, " Service Water System (SWS) - Operating, for North Anna Power Station, Units 1 and 2. The proposed changes would allow one of the two service water (SW) loops to be isolated from the component cooling water heat exchangers (CCHXs) during two-unit power operation to facilitate repair-of the concrete-encased portions of the isolated SW headers. The licensee proposed 4
one time (temporary) TS changes to Unit 1 and 2 for two periods of up to 35 days each. ;
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The exposed portions of these SW lines were repaired under TS Amendment No.
194 for Unit 1 and TS Amendment No. 175 for Unit 2. Prior to issuing Amendment Nos. 194 and 175, service water pipe refurbishment work had been implemented by using the current Action Statement "d" of TS 3.7.4.1, which
' allows one of the two redundant SW loops to be removed from service for up to 7 days for SWS upgrades.
2.0 BACKGROUND
The plant SWS consists of two redundant loops which are shared between Unit 1 and Unit-2. The SW pumps (two for each unit) can be aligned to either of the SW loops. During normal operation, one SW pump is usually running on each SW loop that provides the re pump lube-oil, gear box, and quired sealcooling coolers,water two airforcompressors, one CCHX, threeand one charging main control room (CR) air conditioning condenser. During design basis accident' (DBA) conditions, at least one SW pump is running on each SW loop to provide
' the required cooling water for the following loads: two recirculation spray heat exchangers (RSHXs) on the accident unit three charging pump lube-oil, 4
gear box, and seal coolers; one air compresso;r; one main CR air conditioning 1
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- 9707220049 970717 PDR ADOCK 05000338 P PDR
7 s .
1 l
condenser; and one CCHX on the non-accident unit initially and two CCHXs ;
placed in service later for cooldown of the non-accident unit. With the l exception of the RSHXs, the components that are cooled by the SWS can be i aligned to either of the main SW loops. Two of the RSHXs in each unit (four total) are cooled by one SW loop, and the remaining four RSHXs are cooled by the other SW loop. Each unit requires only two RSHXs to mitigate the effects of an accident.
In order to minimize corrosion, prolong the remaining service life of the piping system, and repair / replace the degraded piping sections, the licensee initiated an SWS restoration project. The scope of the project includes refurbishment of the 24-inch concrete-encased SW headers (35-40 ft of encased portion for each SW pipe, four pipes total) and short sections (10-15 ft) of exposed portion of each SW pipe (four pipes total) up to the first isolation ,
valve on the header. All four 24-inch SW headers are connected to the main 36-inch concrete-encased SW headers.
Each 35-day period is based on the following work activity schedule:
- 1) Approximately 7 days to isolate one main SW loop, install plugs inside the 24" supply and return lines in concrete-encased sections, remove the supply ,
and return valves to/from the CCHX header, and install the 24" blind flanges, f j Simultaneously install the cross-connect piping which will provide a bypass flow path for this partially isolated main SW loop and connect temporary SW lines to supply second source of SW to the charging pump coolers, air compressor coolers, SFP coolers and Unit 2 CR chillers. These activities are performed within the 168-hour action statement allowed by TS 3.7.4.1.
- 2) Approximately 21 days for piping refurbishment.
, 3) Approximately 7 days to isolate one main SW loop, remove crossconnect with temporary piping, remove plugs from inside of 24" to/from CCHXs, remove the 24" blind flanges and reinstall the valves. These activities are performed within the 168-hour action statement allowed by TS 3.7.4.1.
3.0 EVALUATION In order to proceed with the SW refurbishment activities, the licensee
- requested revision to TS 3.7.3.1 (Component Cooling Water System) with a "**"
, footnote which allows operation of the SWS with one independent source of SW to/from the Unit 1 and Unit 2 CCHXs for two periods of up to 35 days each. In conformity with the change, TS 3.7.4.1 (Service Water System) is also revised with a "*" footnote which allows one of the two SW loops to temporarily bypass the CCHXs, provided all other requirements in the TS are met. The footnote provides clarification that the provisions of TS 3.0.4 are not applicable provided two SW loops are capable of providing cooling for the other operable plant components.
The SWS is needed for normal plant operation and to mitigate the effects of a DBA. With one of the two SW loops isolated, the reliability of the CCW system
j 1-
! and all of the equipment' cooled.by the CCW system will be affected. To' assure
! that the SWS and CCW cooling functions are not jeopardized during the' SWS j piping refurbishment,.the licensee evaluated the impact on initiating event j frequency of previously analyzed design basis events for the TS changes. ,
The licensee evaluated the SWS and CCW system operability during DBA
- conditions for operating the single SW loop with temporary cross-connect 1 installed. A hydraulic analysis was performed to verify whether adequate SW j ' flow will be provided to the containment RSHXs assuming the occurrence of the i most limiting single failure. In addition, the automatic closure feature of the SW valves serving the CCHXs will be defeated in order to avoid the
- undesired interruption of CCW cooling to the unaffected unit in an accident
- condition. The defeating of the automatic valve operation will be addressed by-station administration procedures.
- l. The hydraulic and heat transfer analyses for the CCW system were performed and
! the.following facts were indicated:
- Normal CCW heat transfer loads can be met with two CCHXs operated on one
- SW header with two SW pumps.
-The fast cooldown heat transfer loads can be met with three CCHXs j operated on one SW header with two SW pumps, but the SW supply temperature must be less than or equal to 75* F. For SW temperature between 75* F to 78.5* F, a slow cooldown can be achieved with the same
, system configuration.
1
- Containment atmospheric temperature limits can be maintained since the
! containment heat removal portion of the SWS is not affected by the SWS refurbishment activities.
] The' staff finds that the licensee's safety analyses and results for the SWS a refurbishment activities are comprehensive.
. .To reduce risk of damage to the operat,ing SW header and to provide backup i means of cooling equipment, the licensee proposed.to implement the following
{ contingencies or compensatory actions:
I
- During periods of operation in Action Statement "d" of TS 3.7.4.1 (168-
[ hour action statement) when the SW system is on one header, a temporary i' source of cooling water to the charging pumps coolers will be provided i from the fire protection or primary grade water systems should the SW supply be interrupted.
0
! *- Further, an alternate source of cooling water to the control room /
4 emergency switch gear room (CR/ESGR) air conditioning system will be '
i provided as a precautionary measure in the event that a loss of service water occur. The use of this alternate cooling water source is addressed i in Abnormal Procedure 0-AP-12, " Loss of Service Water." Operators are
- trained in the use of Abnormal Procedure 0-AP-12 for loss of service water.
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1 During portions.of the 35-day periods of operation with only one SW loop
.available to/from the CCHXs, the' automatic closure feature' of the SW isolation valves to the CCHXs will be defeated to prevent unnecessarily
. isolating the CCHXs and assure that all four_ SW pumps (two on each loop) will be available to the single SW loop. .
To avoid operation of the SW pump at abnormal conditions (low flow) on this partially deadlocked header, a temporary cross-connect (with a l
-manually operated control valve) will be installed between the supply and _
. return headers of the affected main SW loop to provide a flow path bypassing the CCHXs.- -
The pipe _ refurbishment work will be scheduled when SW supply temperatures can be maintained at 75* F (typically October through Api 11) to minimize the flow demands to the CCHXs for. plant cooling.
The temporary cross-connect and temporary piping to the charging pump, air compressor, and SFP coolers and Unit 2 CR chillers will be seismically designed and qualified i.t accordance with the safety-related piping design criteria.
l
- During the two 35-day periods, temporary pipe clamps and emergency repair equipment will be staged in the auxiliary. building to facilitate the capability for emergency repair of the SWS piping in case the SWS header is ruptured.
When operating with one available SW header supplying the CCHXs, no major-maintenance or testing will be planned on the SW pumps. Routine periodic ,
tests and maintenance work will be scheduled before or after the 35-day periods. If an SW pump is rendered inoperable, an operable SW pump from the other header will be' realigned to this header to maintain at least two operable pumps available to the SW header.
- No planned outages will be allowed during the 35-day pariods. In the event of an unplanned unit shutdown, all pipe refurbishment work will be ;
stopped and actions will be determined based on the status of the ;
refurbishment.
The compensatory actions discussed above are based on the licensee's safety analyses for the TS changes and are plant specific. From engineering considerations, the staff finds that the licensee's safety analyses and compensatory actions are rational and justified.
- The licensee also performed a Probability Safety Assessment (PSA) to evaluate the impact on initiating event frequency based on the Electric Power Research Institute (EPRI) PSA Application Guide TR-105396. The licensee developed a PSA model for Individual Plant Examination (IPE) for the North Anna plant.
However, the staff's review and approval of this temporary TS change request
._ - ~ _ 1
T !
is not an endorsement of the licensee's PSA work. The staff's acceptance is based on the licensee's safety evaluations and the compensatory actions performed for these TS changes as discussed above.
1
, 4.0
SUMMARY
l The staff has reviewed the licensee's submittal for the temporary TS changes, l which permits one of the two service water loops to be isolated from the I component cooling water heat exchangers during two-unit power operation.
The licensee has justified its position that these SWS refurbishment activities i will-not adversely affect safe operation of the plant. The licensee also l 4
performed safety evaluations for the design basis conditions for the 35-day periods that the tNorary TS changes are valid. Based on this review, the l
, staff concludes that the temporary TS changes for North Anna Unit 1 and Unit 2
- are acceptable on the basis that
i a the TS changes are justified by the licensee with technical bases that 3
have been reviewed by the staff.
- the licensee has evaluated the functional capability and availability of the SWS and CCW system to maintain safe plant operation.
- . the licensee has performed safety evaluations for the DBA conditions and determined that the SWS will remain capable of performing its function during normal plant operation as well as during accident conditions.
e 4 Beyond these measures necessary for the approval of the TS changes, the licensee has proposed to implement contingencies and compensatory actions to assure continued operability and availability of the SWS and CCW system, j 5.0 SJJ_IE CONSULTATION l
In accordance with the Commission's regulations, the Virginia State official was . tified of the proposed issuance of the amendments. The State official had no comment.
6.0 ENVIRONMENTAL CONSIDERATION
These amendments change a requirement with respect to installation or use of a facility component located within the restricted area as defined in 10 CFR Part 20. The NRC staff has determined that the amendments involve no significant increase in the amounts, and no significant change in the types, of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission has previously issued a proposed finding that these amendments involve no significant hazards consideration and there has been no public comment on such finding (62 FR 6580). Accordingly, these amendments meet the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 10 CFR 51.22(b) no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.
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7.0 CONCLUSION
I Based on the considerations discussed above, the staff concludes that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendments will not be inimical to the ccmmon defense and '
security or to the health and safety of the public.
Principal Contributor: N. Kalyanam Date: July 17,1997 j
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