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Category:SAFETY EVALUATION REPORT--LICENSING & RELATED ISSUES
MONTHYEARML20217L8831999-10-21021 October 1999 Safety Evaluation Supporting Proposed Alternatives to Code Requirements Described in RR-V17 & RR-V18 ML20217G2041999-10-13013 October 1999 Safety Evaluation Supporting Amend 179 to License DPR-28 ML20212C2551999-09-17017 September 1999 Safety Evaluation Supporting Amend 175 to License DPR-28 ML20206E8741999-04-29029 April 1999 SER Determined That Flaw Evaluation Meets Rules of ASME Code & Assumed Crack Growth Rate Adequate for Application ML20205K7581999-04-0707 April 1999 Safety Evaluation Supporting Alternative Proposal for Reexamination of Circumferential Welds with Detected Flaw Indications in Plant RPV ML20203H9881999-02-18018 February 1999 SER Accepting Alternative to 10CFR50.55a(g)(6)(ii)(A) Augmented Reactor Vessel Exam at Vermont Yankee Nuclear Power Station.Technical Ltr Rept Encl ML20199K7151999-01-21021 January 1999 Corrected Safety Evaluation Supporting Amend 163 Issued to FOL DPR-28.Pages 2 & 3 Required Correction & Clarification ML20199K6991999-01-20020 January 1999 Safety Evaluation Concluding That Request to Use YAEC-1339, Yankee Atomic Electric Co Application of FIBWR2 Core Hydraulics Code to BWR Reload Analysis, at Vermont Yankee Acceptable ML20199L5951999-01-14014 January 1999 Safety Evaluation Accepting Licensee Proposed Alternative to Code Requirement,Described in Rev 2 to Pump Relief Request RR-P10 Pursuant to 10CFR50.55a(a)(3)(i) ML20195C4161998-11-0909 November 1998 SER Accepting Request That NRC Approve ASME Code Case N-560, Alternative Exam Requirement for Class 1,Category B-J Piping Welds ML20155B6471998-10-26026 October 1998 Safety Evaluation Accepting Jet Pump Riser Insp Results & Flaw Evaluation,Conducted During 1998 Refueling Outage ML20154B6951998-10-0101 October 1998 SER Re Licensee Response to GL 95-07, Pressure Locking & Thermal Binding of Safety-Related Power-Operated Gate Valves, for Vermont Yankee Nuclear Power Station ML20239A1361998-09-0202 September 1998 SER Re License Request for NRC Review & Concurrence W/Changes to NRC-approved Fire Protection Program ML20216F1001998-04-15015 April 1998 Safety Evaluation Accepting 980331 Licensee Proposal to Perform Alternative Testing for Containment Pressurization Test for Vynp ML20217F3421998-03-25025 March 1998 SER Accepting Plans for 1998 & 1999 Refueling Outages Re Reactor Vessel Internals for Plant ML20212H1521998-03-0606 March 1998 Correction to Page 7 of SE Re Relief Request for Third 10-yr Interval Pump & Valve IST Program for Plant ML20217N4911998-02-27027 February 1998 SER Pertaining to Cracking of EDG Lube Oil Piping at Vermont Yankee ML20198P9941998-01-15015 January 1998 SE Authorizing Relief Requests for Third Interval Pump & Valve Inservice Testing Program ML20141A4151997-06-18018 June 1997 Revised SE Accepting Proposed Onsite Disposal of Slightly Contaminated Silt Removed from Vermont Yankee Cooling Towers ML20135E5401997-03-0303 March 1997 Safety Assessment Accepting Mod of RHR & CS Sys Containment Isolation Function Configuration ML20134N8271996-11-20020 November 1996 Safety Evaluation Accepting Licensee Scope & Insp Methods Proposed for Insp of Core Spray Internal Piping During Fall 1996 Refueling Outage at Plant ML20134F9631996-11-0505 November 1996 Safety Evaluation Re Power/Flow Exclusion Region Calculation Method Using LAPUR5 Computer Code & Implementation of Solomon Stability Monitor for Licensee Facility ML20128N3531996-10-11011 October 1996 Safety Evaluation Accepting Licensee Flaw Evaluation of Indication Found During Reactor Pressure Vessel Insp at Plant ML20129G3611996-10-0202 October 1996 Safety Evaluation Accepting Proposed Repair for Plant Core Shroud ML20057A6991993-09-0303 September 1993 Safety Evaluation of IST Program Relief Requests for Pumps & Valves for Third 10-yr Insp Interval ML20057A2791993-08-12012 August 1993 Safety Evaluation Accepting Licensee Reasons Given for Delay in Completing short-term Actions Requested in Ieb 93-003, Resolution of Issues Re to Rv Water Level Instrumentation in Bwrs ML20246D7731989-08-21021 August 1989 Safety Evaluation Supporting Util Response to Generic Ltr 83-28,Item 2.2.1, Required Actions Based on Generic Implications of Salem ATWS Events. Equipment Classification Program for safety-related Components Acceptable ML20244D0311989-06-0707 June 1989 Safety Evaluation Accepting Util Second 10-yr Interval Inservice Insp Program Plan ML20205T4181988-10-14014 October 1988 Errata to Safety Evaluation Concluding Util Submittal Re Spent Fuel Pool Expansion ML20204F7271988-10-14014 October 1988 Safety Evaluation Supporting Proposed Expansion of Spent Fuel Pool at Facility ML20236N6461987-08-0707 August 1987 Safety Evaluation Re Permanent Elimination of Liquid Penetrant Exam of Feedwater Nozzles at Facility.Due to Lack of Reasonable Assurance That Ultrasonic Exam Can Totally Replace Penetrant Exam,Request Unacceptable ML20214T9891987-05-28028 May 1987 Safety Evaluation Re Util 870112 Proposed Plans to Inspect Two Overlay Repaired Core Spray safe-ends in Lieu of Replacement During Upcoming 1987 Refueling Outage.Plans Acceptable,Providing That Insp Results Satisfactory ML20207S7801987-03-12012 March 1987 Safety Evaluation Granting Relief from Tech Spec 4.7.A.3 on one-time Basis to Perform RHR Pump Wear Ring Replacement ML20214T4921986-11-24024 November 1986 Safety Evaluation Accepting Licensee 830511 & 860117 Responses to Generic Ltr 83-08 Re Mod of Vaccum Breakers on Mark I Containments ML20215M5871986-10-24024 October 1986 Preliminary Evaluation of Containment Study Transmitted w/860902 Ltr.Licensee Estimates Appear Optimistic Considering Uncertainties Inherent in Failure Rate Data ML20206F3651986-06-16016 June 1986 Safety Evaluation Re Proposed Repair of Core Spray safe- Ends,During Current Refueling Outage.Plant Can Be Safely Returned to Power Operation After Satisfactory Completion of Core Spray safe-end Repairs ML20206F0681986-06-13013 June 1986 Safety Evaluation Supporting 850514,0710,860327,0411 & 0513 Requests for Approval to Use Pvrc Damping Values (ASME Code Case N-411) for Piping Sys Reanalysis ML20202J4211986-03-31031 March 1986 Safety Evaluation Accepting Util Design Mods & Tech Spec Changes Re Degraded Grid Voltage Protection for Class 1E Sys.Lll Technical Evaluation Rept Encl ML20155B8351986-03-31031 March 1986 Safety Evaluation Supporting Revised Procedure OP-3140, Providing Technically Acceptable Actions During Degraded Grid Voltage Conditions W/O LOCA to Assure Protection of Class 1E Electrical Sys & Equipment ML20140H9881986-03-25025 March 1986 Safety Evaluation Re Util 851008 Request to Install Carpet Over Vinyl Asbestos Tiled Control Room Floor Covering. Installation of Carpet Will Not Decrease Level of Fire Safety in Control Room & Deviation Acceptable ML20138E4201985-12-0202 December 1985 Safety Evaluation Supporting Util 831107 & 840320 Responses to Generic Ltr 83-28,Items 3.1.1,3.1.2,3.2.1,3.2.2 & 4.5.1 Re post-maint Testing & Reactor Trip Sys Reliability ML20136F1241985-11-18018 November 1985 Safety Evaluation Re IE Bulletin 80-11, Masonry Wall Design. Issues Re Arching Action Theory Resolved ML20137S7331985-09-27027 September 1985 Safety Evaluation Approving Use of Fuel Thermal Performance Code,Frosstey,For Analysis of LOCA Conditions at Low & Moderate Burnups ML20135C8921985-09-10010 September 1985 Safety Evaluation Supporting 840824 Commitment to Convert Air Containment Atmosphere Dilution Sys to Nitrogen Sys,In Response to Generic Ltr 84-09 ML20135C9121985-09-10010 September 1985 Safety Evaluation Supporting Conclusion That Diversification of Scram Discharge Vol Level Instrumentation Not Necessary & Tech Specs,As Modified in Amend 76,resolve Staff Concerns Re Need for Instrumentation Diversity ML20134K7351985-08-19019 August 1985 Safety Evaluation Accepting 831107 Response to Generic Ltr 83-28,Items 3.1.3 & 3.2.3 Re post-maint Testing ML20136G3611985-08-12012 August 1985 Safety Evaluation Accepting Seismic Design Criteria Utilized for Evaluation of Modified Recirculation Sys ML20132D8971985-07-22022 July 1985 Safety Evaluation Supporting Use of Pvrc Damping Values (ASME Code Case N-411) for Response Spectrum Seismic Piping Analyses ML20127D8991985-05-0606 May 1985 Safety Evaluation Re 840925 & 1002 Responses to Generic Ltr 83-28,Item 1.1 Concerning post-trip Review Program & Procedures.Program & Procedures Acceptable 1999-09-17
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217L8831999-10-21021 October 1999 Safety Evaluation Supporting Proposed Alternatives to Code Requirements Described in RR-V17 & RR-V18 ML20217G2041999-10-13013 October 1999 Safety Evaluation Supporting Amend 179 to License DPR-28 BVY-99-127, Monthly Operating Rept for Sept 1999 for Vermont Yankee Nuclear Power Station.With1999-09-30030 September 1999 Monthly Operating Rept for Sept 1999 for Vermont Yankee Nuclear Power Station.With ML20212C2551999-09-17017 September 1999 Safety Evaluation Supporting Amend 175 to License DPR-28 BVY-99-112, Monthly Operating Rept for Aug 1999 for Vermont Yankee.With1999-08-31031 August 1999 Monthly Operating Rept for Aug 1999 for Vermont Yankee.With BVY-99-109, Ro:On 990812,stack Ng Effluent Instrumentation for PAM Was Declared Oos.Caused by Instrument Drift Due to Electronic Components Based on Insps by Instrumentation & Controls Dept.Detector & Preamplifier Will Be Replaced on 9908311999-08-19019 August 1999 Ro:On 990812,stack Ng Effluent Instrumentation for PAM Was Declared Oos.Caused by Instrument Drift Due to Electronic Components Based on Insps by Instrumentation & Controls Dept.Detector & Preamplifier Will Be Replaced on 990831 BVY-99-102, Monthly Operating Rept for July 1999 for Vermont Yankee. with1999-07-31031 July 1999 Monthly Operating Rept for July 1999 for Vermont Yankee. with ML20209J0081999-07-14014 July 1999 Special Rept:On 990615,diesel Driven Fire Pump Failed to Achieve Rated Flow of 2500 Gallons Per Minute.Pump Was Inoperable for Greater than 7 Days.Corrective Maint Was Performed to Reset Pump Lift Setting BVY-99-090, Monthly Operating Rept for June 1999 for Vermont Yankee Nuclear Power Station.With1999-06-30030 June 1999 Monthly Operating Rept for June 1999 for Vermont Yankee Nuclear Power Station.With ML20196G5071999-06-23023 June 1999 Vynp Assessment of On-Site Disposal of Contaminated Soil by Land Spreading BVY-99-077, Monthly Operating Rept for May 1999 for Vermont Yankee Nuclear Power Station.With1999-05-31031 May 1999 Monthly Operating Rept for May 1999 for Vermont Yankee Nuclear Power Station.With BVY-99-068, Monthly Operating Rept for Apr 1999 for Vynp.With1999-04-30030 April 1999 Monthly Operating Rept for Apr 1999 for Vynp.With ML20206E8741999-04-29029 April 1999 SER Determined That Flaw Evaluation Meets Rules of ASME Code & Assumed Crack Growth Rate Adequate for Application ML20206D9301999-04-27027 April 1999 1999 Emergency Preparedness Exercise 990427 Exercise Manual (Plume Portion) ML20205S4211999-04-16016 April 1999 Non-proprietary Version of Revised Page 4-3 of HI-981932 Technical Rept for Vermont Yankee Spent Fuel Pool Storage Expansion ML20205K7581999-04-0707 April 1999 Safety Evaluation Supporting Alternative Proposal for Reexamination of Circumferential Welds with Detected Flaw Indications in Plant RPV BVY-99-046, Monthly Operating Rept for Mar 1999 for Vermont Yankee Nuclear Power Station.With1999-03-31031 March 1999 Monthly Operating Rept for Mar 1999 for Vermont Yankee Nuclear Power Station.With ML20205F6631999-03-0404 March 1999 Jet Pump Riser Weld Leakage Evaluation BVY-99-035, Monthly Operating Rept for Feb 1999 for Vermont Yankee Nuclear Station.With1999-02-28028 February 1999 Monthly Operating Rept for Feb 1999 for Vermont Yankee Nuclear Station.With ML20205P8241999-02-28028 February 1999 Rev 2 to Vermont Yankee Cycle 20 Colr ML20203H9881999-02-18018 February 1999 SER Accepting Alternative to 10CFR50.55a(g)(6)(ii)(A) Augmented Reactor Vessel Exam at Vermont Yankee Nuclear Power Station.Technical Ltr Rept Encl ML20203A6951999-02-0404 February 1999 Revised Rev 2,App B to Vermont Yankee Operational QA Manual (Voqam) ML20199K7151999-01-21021 January 1999 Corrected Safety Evaluation Supporting Amend 163 Issued to FOL DPR-28.Pages 2 & 3 Required Correction & Clarification ML20199K6991999-01-20020 January 1999 Safety Evaluation Concluding That Request to Use YAEC-1339, Yankee Atomic Electric Co Application of FIBWR2 Core Hydraulics Code to BWR Reload Analysis, at Vermont Yankee Acceptable ML20199L5951999-01-14014 January 1999 Safety Evaluation Accepting Licensee Proposed Alternative to Code Requirement,Described in Rev 2 to Pump Relief Request RR-P10 Pursuant to 10CFR50.55a(a)(3)(i) BVY-99-071, Corp 1998 Annual Rept. with1998-12-31031 December 1998 Corp 1998 Annual Rept. with BVY-99-001, Monthly Operating Rept for Dec 1998 for Vermont Yankee Nuclear Power Station1998-12-31031 December 1998 Monthly Operating Rept for Dec 1998 for Vermont Yankee Nuclear Power Station ML20198H5481998-12-23023 December 1998 Rev 2 to Vermont Operational QA Manual,Voqam ML20196H8641998-12-0101 December 1998 Cycle 19 Operating Rept BVY-98-163, Monthly Operating Rept for Nov 1998 for Vermont Yankee Nuclear Power Station.With1998-11-30030 November 1998 Monthly Operating Rept for Nov 1998 for Vermont Yankee Nuclear Power Station.With ML20195C4161998-11-0909 November 1998 SER Accepting Request That NRC Approve ASME Code Case N-560, Alternative Exam Requirement for Class 1,Category B-J Piping Welds BVY-98-154, Monthly Operating Rept for Oct 1998 for Vermont Yankee Nuclear Power Station.With1998-10-31031 October 1998 Monthly Operating Rept for Oct 1998 for Vermont Yankee Nuclear Power Station.With ML20155B6471998-10-26026 October 1998 Safety Evaluation Accepting Jet Pump Riser Insp Results & Flaw Evaluation,Conducted During 1998 Refueling Outage ML20154N0891998-10-16016 October 1998 Rev 1 to Vermont Operational QA Program Manual (Voqam) ML20154B6951998-10-0101 October 1998 SER Re Licensee Response to GL 95-07, Pressure Locking & Thermal Binding of Safety-Related Power-Operated Gate Valves, for Vermont Yankee Nuclear Power Station BVY-98-149, Monthly Operating Rept for Sept 1998 for Vermont Yankee Nuclear Power Station.With1998-09-30030 September 1998 Monthly Operating Rept for Sept 1998 for Vermont Yankee Nuclear Power Station.With ML20239A1361998-09-0202 September 1998 SER Re License Request for NRC Review & Concurrence W/Changes to NRC-approved Fire Protection Program BVY-98-135, Monthly Operating Rept for Aug 1998 for Vermont Yankee Nuclear Power Station.With1998-08-31031 August 1998 Monthly Operating Rept for Aug 1998 for Vermont Yankee Nuclear Power Station.With ML20151U0361998-08-28028 August 1998 Non-proprietary Rev 1 to Holtec Rept HI-981932, Vermont Yankee Nuclear Power Station Spent Storage Expansion Project ML20237E9221998-08-20020 August 1998 Vynp 1998 Form NIS-1 Owners Summary Rept for ISI, 961103-980603 BVY-98-122, Monthly Operating Rept for July 1998 for Vermont Yankee Nuclear Power Station1998-07-31031 July 1998 Monthly Operating Rept for July 1998 for Vermont Yankee Nuclear Power Station ML20205F6491998-07-31031 July 1998 Rev 1 to GE-NE-B13-01935-02, Jet Pump Assembly Welds Flaw Evaluation Handbook for Vermont Yankee ML20236G0011998-06-30030 June 1998 Individual Plant Exam External Events BVY-98-098, Monthly Operating Rept for June 1998 for Vermont Yankee Nuclear Power Station1998-06-30030 June 1998 Monthly Operating Rept for June 1998 for Vermont Yankee Nuclear Power Station ML20248C5081998-05-31031 May 1998 Rev 2 to 24A5416, Supplemental Reload Licensing Rept for Vermont Yankee Nuclear Power Station Reload 19 Cycle 20 ML20248C4951998-05-31031 May 1998 Rev 1 to Vermont Yankee Nuclear Power Station Cycle 20 Colr BVY-98-081, Monthly Operating Rept for May 1998 for Vermont Yankee Nuclear Power Station1998-05-31031 May 1998 Monthly Operating Rept for May 1998 for Vermont Yankee Nuclear Power Station ML20247J8341998-05-31031 May 1998 Peak Suppression Pool Temp Analyses for Large Break LOCA Scenarios, for May 1998 ML20247G4001998-05-12012 May 1998 Interview Rept of Ej Massey ML20247E6351998-04-30030 April 1998 Rev 1 to GE-NE-B13-01935-LTR, Jet Pump Riser Welds Allowable Flaw Sizes Ltr Rept for Vermont Yankee 1999-09-30
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SAFETY EVALUATION BY THE REGION I 0FFICE REGARDING RELIEF FROM TECHNICAL SPECIFICATION 4.7.A.3 VERMONT YANKEE NUCLEAR POWER CORP 0r.ATION VERMONT YANKEE NUCLEAR POWER M ATION DOCKET NO. 50-271
1.0 INTRODUCTION
By letter dated March 3, 1987, Vermont Yankee Nuclear Power Corporation (VYNPC or the licensee) requested relief from the requirements of the Vermont Yankee Nuclear Power Station (Vermont Yankee) Technical Specification 4.7. A.3, in order to perform residual heat removal (RHR) pump wear ring replacement.
Subsequently, during discussions between the Vermont Yankee plant manager and the NRC senior resident inspector, as described in NRC Region I Inspection Report 50-271/87-06, additional conditions were specified to assure that ade-quate system integrity and leakage detection provisions are provided. Licen-see acceptance of these conditions (see Attachment 1) was confirmed on March 12, 1987 during a telephone conversation between Mr. J. Weigand, President and Chief Executive Officer, VYNPC and Mr. W. Kane, Director, Division of Reactor Projects, NRC Region I. The NRC Region I review and assessment of this matter is described below.
2.0 EVALUATION The licensee has proposed using alternate means instead of Type C leak rate testing to demonstrate the leak tightness of the following containment pene-trations: (1) X224A and B, which provides the torus suction for the four RHR pumps and contains one normally open isolation valve at the suction of each pump, V10-13A, B, C, and D; and (2) X12, which is the shutdown cooling letdown line from the A recirculation loop and contains two normally closed valves, V10-17 and V10-18. Valves V10-13A, B, C, and D are Walworth 20" dual wedge gate valves. Valve V10-17 is a Walworth 20" pressure seal wedge gate, and V10-18 is a Darling 20" double disc gate valve. Valves V10-15A, B, C, and D, downstream of the V10-17 and V10-18 valves, will be used as a pump main-tenance boundary, and are 20" Walworth dual wedge gate valves.
The alternate methods to verify acceptable leakage are discussed below along with the technical evaluation. The post accident containment pressure re-sponse, from FSAR Figure 14.6-5, is as follows: peak pressure of 44 psig within 1 second of the start of the accident; reduction to 27 psig at 10 seconds; reduction to 8 psig in 15 minutes; and, reduction to 5 psig in 1 day.
The post-LOCA source term discussed in FSAR Section 14.9 and in the bases for Technical Specification 4.7.A.3 is as follows: for a TID-14844 fission product release fraction and an assumed 1.5 wt % per day containment leak rate, the resultant site boundary doses are 1.65 rem whole body and 280 rem thyroid.
8703200265 870312 1 PDR ADOCK 0500
Safety Evaluation 2 Penetration X12 To assure an intact containment barrier for this penetration, the licensee states that the V10-15 valve will be administratively controlled closed with its motor supply breaker open when inspections are performed on the associated RHR pump. The licensee considers the closed valve equivalent to a blind flange. In addition to closing the valve, the licensee shall also lock it closed with a chain and padlock and subsequently attempt to open the valve using the associated CRP 9-3 control panel switch, to assure that the proper supply breaker is open. These controls will provide adequate assurance that a passive mechanical barrier is intact for containment isolation purposes during accident conditions.
Tail pipe leakage and pressure monitoring downstream of the V10-18 and V10-17 valves can provide verification that there is not excessive leakage from the primary system through this penetration. The licensee shall back up the ex-isting PS-118 pressure switch with an on-line local pressure indicator that is surveiled once every four hours to provide early detection of any leakage.
The licensee shall keep the V10-17 and V10-18 valves closed, which will pro-vide three valves as a barrier between the primary system and an opening in any RHR pump. The penetration can be verified to be leak tight by the above methods under present conditions with 1000 psig on the primary side. Under postulated post accident conditions, the piping upstream of V10-18 could lose its water seal from the reactor vessel, but the pressure on the valve seat under those conditions will be limited to 44 psig and water between V10-17 and V10-15 should maintain a water seal on the V10-15 valve seat.
The administrative controls on the V10-17, V10-18, and V10-15A, B, C, and D valves and the use of the pressure sensing instrumentation downstream of V10-17 provide an adequate test alternative to demonstrate the acceptability of leakage through penetration X12 for the time it will take to replace the RHR pump wear rings.
Penetration X224A and B To assure an intact containment barrier for this penetration, the V10-13A, B, C, and D valves (one for each pump) will be administrative 1y controlled closed with the motor supply breaker open when inspections are performed on the asso::tated RHR pump. The licensee shall also lock the respective V10-13A, B, C, or D valve with a chain and padlock and subsequently attempt to open the valve using the associated CRP 9-3 control panel switch, to assure that the proper supply breaker is open. These controls will provide adequate as-surance that the torus will not be inadvertertly drained through the open RHR pump during normal operations, and will furth3r assure that a passive mechani-cal barrier is intact for containment isolation purposes during accident con-ditions.
Safety Evaluation 3 The licensee stated that primary containment integrity is maintained for pene-tratio- X224A and B by the water seal on valves V10-13A, B, C, and D assured by the torus. The minimum torus water level allowed by the technical speci-fications (68,000 cu. ft.) provides at least 9 feet of submergence.for the torus suction line for anticipated normal, transient, and accident conditions.
The minimum torus level can be maintained from several systems (core spray, HPCI, RCIC) in the post-accident configuration, so that no single active failure can prevent maintenance of the water seal for at least 30 days. Use of the core spray system to replenish the torus assumes entry into the RHR corner room to open a manual suction valve from the condensate storage tank.
The combination of the above controls on the V10-13A, B, C, and D valves, the water seal on the these valve seats maintained by the torus, and control of any leakage out of the penetration (discussed below) provides an adequate test alternative to demonstrate the acceptability of leakage through penetrations X244A and B.
Leakage Potential The licensee estimated that the amount of acceptable leakage through the V10-13 and V10-15 barriers will be small in order to complete the necessary work inside the pump casing. The actual amount of leakage past the valves cannot be estimated until the pump is drained in preparation for the inspection, or further quantified until the pump boundary is open.
The licensee stated thh~, their evaluation concluded for design basis LOCA con-ditions that the coolant leakage past the V10-13 and V10-15 boundaries and potential airborne activity would be minimized. Also, the boundary leakage would be controlled. However, the licensee failed to quantify the leakage source term for staff review and comparison with the acceptable release source terms established in the accident analyses.
While the V10-13 water seal will provide a barrier against the post accident gaseous source term, operation of the operable RHR train in the loop under repair will put water with the post accident particulate source term at the V10-13 valve seat. Potential leakage past the valve seat could result in the release of dissolved gases (from torus water at 170 degrees F) and the subse-quent airborne activity from resuspension of particulate activity following evaporation of any water leakage not contained. The leakage from the pene-tration for the open RHR pump shall be collected and contained by the licensee.
As shown in FSAR Drawing 4.8-2, there is a 3/4 inch drain line from the bottom of the pump bowl that is hard piped to the floor drain sump located in each RHR corner room. The floor drain sump is in turn pumped to radwaste via the reactor building floor drain sump pump (FSAR Drawings 9.2-3 and 9.2-4) and is held for processing in the 25,000 gallon floor drain collector tank in the radwaste building. The post-accident source term available from this poten-tial leakage source shall be assumed to leak to the reactor building atmos-phere and subsequently be released to the environs following filtration from the SBGTS.
Safety Evaluation 4 The licensee informed the NRC orally on March 9, 1987, that in order to minim-ize the potential for containment boundary leakage and any resultant environ-mental release, the RHR pump disassembly would not be performed if there is any measurable leakage flow from the containment boundary. Further work on any pump not inspected as a result of potential containment boundary leakage will be deferred until the next refueling outage, currently scheduled for August 1987.
Some uncertainty exists relative to the additional rost-accident source term available for release to the environs from the essentially zero leakage from the established valve boundaries. The incremental increase (if any) is judged to be small and shall be minimized by the licensee by the provisions that there will be no measurable leakage flow. Acceptance of the source term un-certainty is justified by the low probability of an accident in the eight days (four pumps X two days / pump) of plant operation with the RHR pumps disassembled.
Based on the above, the licensee shall establish a hold point in the pump inspection procedure that will, after pump drain down and prior to RHR pump disassembly, verify that the leakage is essentially zero (i.e., no steady stream) to assure the barrier is intact. This measure will assure that the post-accident radioactive source term emanating from any leakage will result in an acceptably small incremental increase to the post accident source term released to the environs described in the bases for Technical Specification 4.7.A.3.
Contingency Plans The licensee estimates that it will take about five days to perform the in-spections on any one pump, and during that period, the pump boundary would be open for about two days. During this period, surveillance shall be per-formed of the open boundary using operator tours once every four hours. If any leakage is detected while the RHR inspection is in progress, actions shall be taken immediately to close the opening in the RHR pumps as soon as possible.
The licensee stated that the pump could be closed within about three hours by installing the old pump internals if necessary, along with the stuffing box and shaft seal package. The three hours includes calling in workers on a back shift since the licensee intends to run the job only on ten-hour day shifts.
The preferred course of action, conditions permitting, is to restore the RHR loop to its full operability. Therefore, should a need arise to implement this contingency plan, at the discretion of the shift supervisor, the RHR pump reassembly shall be performed on a round-the-clock basis, restoring the pump to an operable status with a new impeller. This action could take up to three days to complete.
Safety Evaluation 5
3.0 CONCLUSION
The staff has reviewed the licensee's submittal dated March 3: 1987 and per-formed its own independent evaluations. The staff has determined that, sub- I ject to the conditions described in Attachment 1, the licensee can safely perform the RHR pump inspections.
Based on the above considerations, and the fact that the planned inspection and maintenance of residual heat removal (RHR) pumps should enhance overall system safety and reliability, the staff concludes that the licensee's meas-ures to provide alternative leakage detection and piping isolation of the RHR system are adequate to meet the intent of Technical Specification 4.7.A.3.
4.0 Relief from Technical Specification 4.7.A.3 Based on the authority of the Regional Administrator to exercise enforcement discretion regarding Technical Specifications, as delegated by the Director, Office of Nuclear Reactor Regulation and the Director, Office of Inspection and Enforcement, in a memorandum dated February 27, 1987, I have determined that the above circumstances, in which a license amendment would not be ap-propriate, are suitable for the use of such enforcement discretion. Further-more, the granting of specific relief from Technical Specification 4.7.A.3, for the limited purposes described above and subject to the conditions of Attachment 1, will not endanger life, property, or the common defense and security of the public.
Therefore, the requested relief from Technical Specification 4.7.A.3, as described in the VYNPC letter dated March 3, 1987, and subject to the condi-tions in Attachment 1, is hereby granted.
' Original ~ signed lif, Thru r. Murley, -
Thomas E. Murley Regional Administrator Dated: 12 MAR 1987
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ATTACHMENT 1 The licensee shall:
- 1. Administratively control the associated V-10-13A, B, C, and D and the V-10-15A, B, C,.and D valves as follows: locked closed with chain and lock, along with opening their MOV supply breakers, and subsequently test that the proper sup-ply breakers are.open by attempting to open each valve using the CRP 9-3 con-trol panel switch for each valve, one at a time.
- 2. Provide an on-line local pressure indicator in addition to the PS-118 pressure switch both of which shall be surveiled once every four hours to provide early indication of any leakage through the X12 penetration.
- 3. Establish a hold point in the pump inspection procedure that will verify, after pump drain down and prior to RHR pump disassembly, that there is no measurable leakage from penetrations X12, X224A, and X224B, i.e., no steady stream.
- 4. Maintain surveillance over the open boundary using operator tours once every four hours. If measurable leakage from the containment is detected, i.e.,
a steady stream, the shift supervisor shall order the pump to be reassembled expeditiously. Should a need arise to implement this action, the RHR pump reassembly shall be performed on a round-the-clock basis, with the intent to restore the pump to an operable status with a new impeller.
- 5. Develo; and implement a contingency plan (using the pump reassembly procedure) that wil! provide for rapid closure of the RHR piping boundary (e.g., in about three hcurs) in response to a decision by the operations shift supervisor that such action is necessary, if leakage conditions do not permit reassembly using the new impeller, i
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