ML20138M516

Summary of 851126 Meeting W/Util in Bethesda,Md Re Operability of Steam Line Safety Valves.List of Attendees, Viewgraphs & Util Conclusions Re Valve Setpoints Encl

ML20138M516
Person / Time
Site:	Calvert Cliffs
Issue date:	12/13/1985
From:	Jaffe D Office of Nuclear Reactor Regulation
To:	Thadani A Office of Nuclear Reactor Regulation
References
NUDOCS 8512230002
Download: ML20138M516 (26)

Text

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December 13, 1985

- Docket,Nos. 50-317 and 50-318 MEMORANDUM FOR:' Ashok C..Tha'dani, Director PWR Project Directorate #8 Division of PWR Licensing-B o-FROM: D. H. Jaffe, . Project Manager PWR Project Directorate #8

. Division of PWR Licensing-B-

SUMMARY

OF MEETING WITH BALTIM0RE GAS & ELECTRIC COMPANY (BG8E) CONCERNING OPERABILITY OF STEAM LINE SAFETY VALVES On November 26, 1985, representatives of BG&E and .the NRC staff met in _ Room 12242-of the' Air Rights Building in Bethesda, Maryland. Enclosure 1 contains the list of attendees. The purpose of the meeting was to discuss the operability of the Calvert Cliffs Unit 2 Main Steam Safety Valves (MSSVs).

.The'NRC' staff l indicated concern _regarding the as-found setpoints for the Unit 2 LMSSVs.- The setpoints violated existing Technical Specification (TS) requirements and would have _ violated the new, more liberal (TS) requirements

'to.be issued as part of a Unit 2, Cycle 7, license amendment.

BG&E responded to staff concerns regarding the Unit 2 MSSVs in a presentation summarized in Enclosure 2 Although several miror MSSV problems seemed to exist, no single or cumulative cause for the setpoint problem could be identified.' Evidence presented by BG&E seemed to point to a problem associated with setpoint measurement techniques. In light _of this finding,

. BG8E committed to the following corrective actions related to MSSV setpoint verification:

• Procedural Enhancements Set. valves at 530*F vice 500*F Provide QC coverage while verifying setpoints

-* Independently reverify setpoints of 4 valves 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after initial setting.

Lf * .

Verify setpoints of 4 valves.during first outage after 4 month operation.

BG8E:also presented its conclusions regarding the Unit 1 MSSV setpoints.

This material is contained-in Enclosure 3.

8512230002 DR 851213 ADOCK 05000317 4 PDR -

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s Following the BG8E presentation and discussions among the NRC staff, it was concluded by the NRC staff that based upon information presented by BG8E:

(1). safety analyses performed by BG&E, assuming as-found MSSV setpoints, showed no violation of safety limits or the criteria of 10 CFR 50.46,

~ (2) improvements proposed by BG&E would likely. improve MSSV setpoint measurement, and (3) the Unit 1 MSSVs appeared to be showing as-expected MSSV setpoint behavior. Based upon the above, it was concluded that no safety problems associated with MSSVs could be identified which would prevent- the return of Unit 2 to power operation.

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. H. ffeV oject Manager PWR Project Directorate #8 Division of PWR Licensing-B

Enclosures:

As stated cc w/ enclosures:

See next page

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A Mr. A. E. Lundvall,' Jr.

- Baltimore Gas & Electric Company Calvert Cliffs Nuclear Power Plant cc:

Mr. William T. Bowen, President Regional Administrator, Region I Calvert County Board of U.S. Nuclear Regulatory Commission Commissioners Office of Executive Director Prince Frederick, Maryland 20768 for Operations 631 Park Avenue D. A. Brune, Esq. King of Prussia, Pennysivania 19406 General Counsel Baltimore Gas and Electric Company Mr. Charles B. Brinkman P. O. Box 1475 Manager - Washington Nuclear Operations Baltimore, Maryland 21203 Combustion Engineering, Inc.

7910 Woodmont Avenue George F. Trowbridge, Csq. Bethesda, Maryland 20814 Shaw, Pittman, Potts and Trowbridge 1800 M Street, NW Mr. J. A. Tiernan, Manager Washington, DC 20036 Nuclear Power Department Calvert Cliffs Nuclear Power Plant Mr. R. C. L. Olson, Principal Engineer Maryland Routes 2 and 4 Nuclear Licensing Analysis Unit Lusby, Maryland 20657 Baltimore Gas and Electric Company Room 720 - G&E Building Mr. R. E. Denton, General Supervisor P. O. Box 1475 Training and Technical Services Baltimore, Maryland 21203 Calvert Cliffs Nuclear Power Plant Maryland Routes 2 and 4 Lusby, Maryland 20657 Resident Inspector c/o U.S. Nuclear Regulatory Commission Combustion Engineering, Inc.

P. O. Box 437 ATTN: Mr. R. R. Mills, Manager

. Lusby, Maryland 20657 Engineering Services P. O. Box 500 Mr. Leon B. Russell Windsor, Connecticut 06095 Plant Superintendent Calvert Cliffs Nuclear Power Plant Department of Natural Resources Maryland Routes 2 and 4 Energy Administration, Power Plant Lusby, Maryland 20657 Siting Program ATTN: Mr. T. Magette Bechtel Power Corporation Tawes State Office Building ATTN: Mr. D. E. Stewart Annapolis, Maryland 21204 Calvert Cliffs Project Engineer 15740 Shady Grove Road Gaithersburg, Maryland 20760 Mr. R. M. Douglass, Manager

. Quality Assurance Department Baltimore Gas and Electric Company Fort Smallwood Road Complex P. O. Box 1475 -

. Baltimore, Maryland 21203 ,,

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. Enclosure 1 List of Attendees NRC D. Jaffe T. Foley F. C. Cherny A. Thadani M. Caruso G. Hamer M. S. Weg'.er R. Perfetti BG&E L. B. Russel J. F. Williams J. A. Mihalcik J. T. Carroll R. R. Allen

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- Enngiu 2 l AGENDA U-2

. Describe Safety Valves

. Describe As-Found Results

. Results of Safety Analysis

. Outline Test Program I

. Test Program Results

. Conclusions

. Future Actions h

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MSSV UNIT 2 LIFT SETPOINT TEST (AS FOUND/AS LEFT PSIG)

. As Found With Setpoint Hydroset Valve (t 1% PSIG) Oct.1982 Apr.1984 Oct.1985 Correction

'3992 985 1009/982 991/991 987 3993 985 963/975 1015/985 1011 3994 995 1022/996 1001/1001 997 i 3995 995 962/989 1035/1004 1031 3996 1015 1021/1021 1037/1006 1024/1024 1020 3997 1015 1015/1015 1044/1008 1020/1020 1016 3998 1035 929/1035+10 1065/1038 1044/1044 1040 3999 1035 1032/1032- 1053/1038 1057/1038 1053 4000 985 974/981 1037/993 1033 4001 985 987/987 972/985 1040/992 1036 4002 995 998/998 1004/1004 1059/993 1055 4003 995 996/996 1014/990 1047/997 1043 4004 1015 1018/1018 1070/1018 1065 4005 1015 1012/1012 1054/1018 1050 4006 1035 991/1036 1104/1035 1100 4007 1035 980/1034 1106/1039 1102 Test Results: 1 Low 6 Low 0 Low 0 Low 0 High 7 High 11 High 11 High 6 Sat 3 Sat 5 Sat SSat

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ACCIDENTS PREDICTING MSSV OPERATION

. Loss of Load

. Loss of Load to One Steam Generator

. CEA Withdrawal

. Feed Line Break

. Imms of NoeEmergency AC Power

. Loss of Feedwater

. Small Break LOCA 4

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. _ MAIN STEAM SAFETY VALVE SAFETY ANALYSIS Nominal - - As-FoEnd As-Found UIC8*

Setpoint Setpoint Analysis Analysis F31G PSIG PSIG PSIG I RV-3993/4000 985 991/1037 1037/1037 1035**

RV-3993/4001 985 1015/1040 1040/1040 1035**

P RV-3994/4003 995 1001/1059 1059/1959 1035

. I RV-3995/4003 995 1035/1047 1047/10'47 1035 RY-3996/4004 1015 1024/1070 ,

1070/1070 1085 RY-3997/4005 1015 1020/1054 1054/l054 __ 1065

i RV-3998/4006 1035 1044/1104 1104/1104+ 1065

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RV-3999/4007 1035 1057/1106 1106/1106+ 1065

• This configuration has been shown to be applicable for USCE.

" Small Break LOCA assumes 995 PSIG.

+ RV-4004 and RV-4007 were assumed stuck closed for Loss of Load analysis.

RV-3998 and RV-3999 opened at 991 and 1001 PSIG, respectively.

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RESULTS SMALL BREAK LOCA

. Available High Promstre Safety hijection flow is ligher than assumed in analysis.

. Higher flow compensates for higher MSSV setpoints.

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. Imms of Load

. Loss of Load to one steam generator  ;

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LIMFFING PARAMETER  ;

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_, system pressure: Limit less than 1100 PIRA.

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e RESULTS NON-LOCA SAFETY ANALYSB i

LOSS OF LOAD TO ONE STEAM GENERATOR

. As-fomd setpoints used

. Otherwise identical to UICS analysis

. Peak sooondary system pressire = 1980 psia LOS8 OF LOAD

. Ae-foted setpoints used

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. BrFC = 0.0E-4 delta rho /F vs. +0.7E-4 delta rho /F (U1CS) I 1

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. Otherwise identical to UICS analysis

. Peak secondary system pressure = 1993 psia 1

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i MSSV TESTING PROGRAM 2-RV-3993

1. At 700F ambient,500 0F steam

a. Thermal equilibrium

b. Test set pressure

.c. Full Flow Test

d. Check leakage

e. Retest set pressure.

2. At 700F ambient,5300F steam, repeat la - e.

3. Heat up transient at 120 F ambient,530 F steam prior to thermal equilibrium, repeat Ib - d.

4. Heat up to thermal equilibrium at 120 F ambient,530 F steam, repeat Ib - e.

5. Set with new hydroset, check with old hydroset at 985,995,1015, and 1035 psig.

6. Reset to 985 psig at 1200 F ambient and 530 F steam, repeat Ib - e and check with 2 full flow tests.

2-RV-3992

1. At 120 F ambient,530 F steam

a. Thermal equilibrium

b. Test set pressure

c. Full Flow Test

d. Checkleakage

- e. Retest set pressure

. NOTE: For all tests, record value of temperature vs. time for inlet nozzle, body, spring, and outlet flange.

2RV Oe O

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Wyle Test Valve BM-7771 11/12 - 14/85 1.. Valve Set at 985 + 10 Ambient - Avg. 86.30F System - Avg. 495.50F Hydroset - Avg. 975.6 psi set pressure Full Flow - Avg. 986.3 psi pop pressure 2.. Ambient - Avg. 74.60F System - Avg. 537.7 F Hydroset - Avg. 966.3 psi set pressure Full Flow - Avg. 979 psi pop pressure

3. Ambient - Avg. Il9.80F 1 hr. heat up System - Avg. 526.2 F Hydroset - Avg. 973.8 psi Full Flow - Avg. 979 psi

4. Ambient - Avg. Il8.30F 4 hr. heat up System - Avg.527 F Hydroset - Avg. 965.8 psi set pressure Full Flow - Avg. 976 psi pop pressure

5. Valve set at 1035 1 10

. Ambient - Avg.119.5 F System - Avg. 327.5 F Hydroset - Avg.1035.6 psi set pressure Full Flow - Avg.1030.5 pop pressure

- 6. Valve Reset at 985 1 10 Ambient - Avg.119 F System - Avg. 523.5 F Hydroset - Avg. 967.5 psi set pressure Full Flow - Avg. 981.3 psi pop pressure

7. Wyle Test Valve BM 7787 - 11/14/85 Ambient - Avg.122.7 F System - Avg. 3230F ,

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Hydroset - Avg. 966.3 psi set pressure ..

Full Flow - Avg. 984.5 psi pop pressure wyle

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1985 Ring Setting Stem Avg.' Disk Maximum As Found Vrive Top Bottom Surface Run Out to Guide Set Pressure 2-RV Set Pressure (Note 2) Film /Cond. (Note 1) Clearance ** (PSIG) (PSIG) 3992 -7t -2 very light / good OK 19t 995 987-3993 +22t +12 very light / good OK 17t 935 1011 3994 Il3t -15 very light / good 8t 18t 1005 997 3995 6t -2 very light /some wear OK 15t 1005 1031 -

t 3996 .-11t -3 very light / good 15t 15t 1025 1020 3997 12t -2 very light / good 8t 13t 1025 1016 3998 13t -

heavy / good 10t 14t 1045 1040 3999 -7t -1 heavy / good 24t 13t 1045 1053 4000 4t -9 very li 21t 14t 995 1033 ii001 12t -1 heavygood /ght/ good 14t 14t 995 1036 2002 95t -3 very light / good 10t 14t !C05 1055 4003 12t -7 heavy / good 13t 13t 1005 1043 4004 25t -3 very light / good 29t lit 1025 1065 4005 52t -3 very light / good 20t 15t 1025 1050 4006 27t -1 very light / good 13t 13t 1045 1100 4007 22t -1 very light / good 18t 12t 1045 1102 s

t = 10-3 inches

• • Min. old disk to guide clearance 10t

• • Min. new disk.to guide clearance 15t

1. No effect below 0.%25"

2. As-Found ring positions affect setpoint by less than 1% and yield 15% or less blowdown.

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U-2 CONCLUSIONS t

Apparent setpoint changes not explained by

• as-found condition of valves.

i Apparent setpoint changes may possibly be the result of measurement technique.

Rebuilt valves will perform as designed.

On 0

49

. . . - =. . . ._

o e_e U-2 FUTURE ACTIONS Procedural Enhancements Set valves at 5300 F vice 500 F Provide QC coverage while verifying setpoints Independently reverify setpoints of 4 valves 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> af ter initial setting.

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Verify setpoints of 4 valves during

. first outage after 4 month operation.

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-A ENCIIEURE 3 AGENDA U-1

. Past Test Results

. Estimated Current Condition of Valves

. Conclusions .

. . Future Actions me D

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4 MSSV UNIT 1 LIFT SETPOINT TEST (AS FOUND/AS LEFT PSIG)

As Left Setpoint Hydroset Test Hydroset Test Hydroset Test Valve - (11% PSIG) Oct. I1,1983 April,1985 June,1985 3

3992 985 959/975 933 3993 985 975/988 3994 995 995/995 3995 995 987/987 990 3996 1015 989/1024 1024/1024 3997 1015 1014/1014 3998 1035 1023/1028 3999 1035 1010/1034 4000 ' , 985 990/9'90 980/980 978 4001 985 981/981 964/983 983 4002 995 961/996 990 4003 995 987/987 999 4004 1015 1024/1024 1016 4005:- 1015 -

986/1010 1012 4006 1035 1058/1040 1030 4007 1035 1043/1043 Test Results: 1 Low 6 Low 1 High 0 High 3 Sat 8 Sat mssvul G

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U-1 CONCLUSIONS Valves will open, provide full capaciti, and reset as designed.

No safety implications est GP G

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• FUTURE ACTIONS Verify setpoints of all 16 valves during next outage.

Reset any valves outside1 1%

If necessary to reset any valve, verify setpoint of valves during first outage after 3 months operation.

G em Se e

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MEETING

SUMMARY

DISTRIBUTION

./h Licensee: Baltimore Gas & Electric Company

• Cepies also sent to those people on service (cc) list for subject plant (s).

x Docket File NRC PDR L PDR PBD-8 Rdg JPartlow (Emergency Preparedness only)

AThadani DJaffe OELD EJordan BGrimes ACRS-10 NRC Participants

' TFoley FClierny MCaruso GHamer MSWegner RPerfetti e

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