ML20245E856

Safety Evaluation Supporting Util Responses to Generic Ltr 83-28, Reactor Trip Sys Reliability for All Domestic Operating Reactors

ML20245E856
Person / Time
Site:	Calvert Cliffs
Issue date:	06/22/1989
From:	Office of Nuclear Reactor Regulation
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ML20245E855	List: ML20245E851 ML20245E856
References
GL-83-28, NUDOCS 8906270479
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l SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION

. BALTIMORE GA5 AND ELECTRIC COMPANY CALVERT CLIFF 5 NUCLEAR POWER PLANT UNITS 1 AND 2 DOCKET N05. 50-317 AND 50-318 REGARDING GENERIC LtIIER 83-28, ITEM 4.5.3 REACTOR TRIP SYSTEM RELIABILITY FOR ALL DOMESTIC OPERATING REACTO C

1.0 INTRODUCTION

On February 25, 1983, both of the scram circuit breakers at Unit 1 of the Salem Nuclear Power Plant failed to open upon an automatic reactor trip signal from the reactor protection system (RPS). This incident was terminated manually by the operator about 30 secnnds after the initiation of the automatic l trip signal. The failure of the circuit breakers was determined to be related to the sticking of the undervoltage trip attachment. Prior to this incident, on February 22, 1983, at Unit 1 o_f the Salem Nuclear Power Plant, an' automatic  !

trip signal was generated based on steam generator low-low level during plant startup. In this case, the reactor was tripped manually by the operator almost coincidentally with the automatic trip.

Following these incidents, on February 28, 1983, the NRC Executive Director for Operations (ED0), directed the staff to investigate and report on the generie implications of these occurrences at Unit 1 of the Salem Nuclear Power Plant. The results of the staff's inquiry into the generic implications of the Salem Unit 1 incidents are reported in NUREG-1000, " Generic Implications of the ATWS Events at the Salem Nuclear Power Plant". As a result of this investigation the Connission (NRC) requested (by Generic Letter 83-28 dated July 8, 1983),all licensees of operating reactors, applicants for an operating license, and holders of construction permits to respond to generic issues raised by the analyses of these two ATWS events.

The licensees were required by Generic Letter 83-28, Item 4.5.3 to confirm that on-linefunctionaltestingofthereactortripsystem(RTS), including independent testing of the diverse trip features, was being performed at all plants.

Existing intervals for on-line functional testing required by Technical Specifications were to be reviewed to determine if the test intervals were adequate for achieving high RTS availability when accounting for considerations such as: (1) uncertainties in component failure rates; (2) uncertainties in common mode failure rates; (3) reduced redundancy during testing; (4) operator error during testing; and (5) component " wear-out" caused by the testing, j 2.0 DISCUSSION l The NRC's contractor, Idaho National Engineering Laboratory (INEL), reviewed the licensee Owners Group availability analyses and evaluated the adequacy of  :

the existing test intervals, with a consideration of the above five items, for all plants. The results of this review are reported in detail in EGG-NTA-8341, "A Review of Reactor Trip System Availability Analyses for Generic Letter  :

83-28 Item 4.5.3 Resolution," dated March 1989 and summarized in this report. l The results of our evaluation of Item 4.5.3 and our review of EGG-NTA-8341 are presented below.

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The Babcock & Wilcox (BAW), Combustion Engineering (CE), General Electric (GE), and Westinghouse (W) Owners Groups have submitted topical reports either.

in response to GL 83-28 Item 4.5.3 or to provide a basis for requesting Technical Specification changes to extend RTS surveillance test intervals (STI). The owners groups' analyses addressed the adequacy of the existing intervals for on-line functional testing of the RTS, with the considerations required by Item 4.5.3, by quantitatively estimating the unavailability of the RTS. These analyses found that the RTS was very reliable and that the unavailability was dominated by common cause failure and human error.

The ability to accurately estimate unavailability for very reliable systems was considered extensively in NUREG-0460, " Anticipated Transients Without Scram for Light Water Reactors", and the ATWS rulemaking. The uncertainties of such estimates are large, because the systems are highly reliable, very little experience exists to support the estimates, and common cause failure probabilities are difficult to estimate. Therefore we believe that the RTS unavailability estimates in these studies, while useful for evaluating test intervals, must be used with caution.

NUREG-0460 also states that for systems with low failure probability, such as the RTS, comon mode failures tend to predominate, and, for a number of reasons, additional testing will not appreciably lower RTS unavailability.

First, testing more frequently than weekly is generally impractical, and even so the increased testing could at best lower the failure proh bility by less than a factor of four compared to monthly testing. Secondly, increased testing could possibly increase the probability of a common mode failure through increased stress on the system. Finally, not all potential failures are detectable by testing. In summary, NUREG-0460 provides additional justification to demonstrate that the current monthly test intervals are adequate to maintain high RTS availability.

3.0 CONCLUSION

All four vendors' topical reports have shown the currently configured RTS to be highly reliable with the current monthly test intervals. Our contractor has reviewed these analyses and performed independent estimates of their own which conclude that the current test intervals provide high reliability. In addition, the analyses in NUREG-0460 have shown that for a number of reasons, more frequent testing than monthly will not appreciably lower the estimates of failure probability.

Based on our review of the Owners Group topical reports, our contractor's independent analysis, and the findings noted in NUREG-0460, we conclude that the existing intervals, as recomended in the topical reports, for on-line functional testing are consistent with achieving high RTS availability at all operating reactors.

ENCLOSURE 3 EGG-NTA-6341 March 1989 TECHNICAL EVALUATION REPORT

/daho National A REVIEW OF REACTOR TRIP SYSTEM AVAILABILITY ANALYSES FOR GENERIC LETTER 83-28, ITEM 4.5.3, Engineering RESOLUTION Laboratory Managed Oy the U S. David P. Mackowiak Department John A. Schroeder ofEnergy n

• gggy _ Prepared for the '

U.S. NUCLEAR REGULATORY COMMISSION

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b NOTICE This report was prepared as an account of work sponered by an agency of the Uruted States Government. Neither the Uruted Sates Govertiment nor any agency thereof, not any of their employees, rnakes any warranty, expressej Of imphed, or assumes any le5aj habibty or responsMty for any tiurd party's use or the results of such use, of any mformauon apparatus. product or proe.

ess daclosed m this report, or represents that str use by such thttd party would not ininnge pnvately owned nghts.

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EGG-NTA-8341 TECHNICAL EVALUATION REPORT: A REVIEW OF REACTOR TRIP SYSTEM AVAILABILITY ANALYSES FOR GENERIC LETTER 83-28, ITEM 4.5.3, RESOLUTION David P. Mackowiak John A. Schreeder i

1 EG&G Idaho, Inc. 1 Idaho Falls, Icaho 83415 t

I FIN 06001: Evaluation of Conformance to Generic Letter 83-28 for ors (Project 2)

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ABSTRACT The Idaho National Engineering Laboratory (INEL) conducted a technical review of the commercial nuclear reactor licensees' responses to the requirements of tne Nuclear Regulatory Commission's (NRC's)

Generic Letter 83-28 (GL 83-28), Item 4.5.3. The results of this review, if all plants are shown to be covered by an adequate analysis, will provide the NRC staff with a basis to close out this issue with no further review. The Itcensees, as the four venders' Owners' Groups, submitted analyses to the NRC either cirectly in response to GL 83-28, Item 4.5.3, or to provide a basis for requesting changes to the Technical Specifications (TS) that would extend the Reactor Protection System (RPS) surveillance test intervals (STIs). To conduct the review, the INEL defined three criteria to dete-mine the adequacy, plant applicability, and acceptability of the results. The INEL examined the Owners Groups' reports to determine if the analyses and results met the established criteria. Fort St. Vrain's responses to Item 4.5.3 were also reviewed.

The INEL review results show that all licensees of currently operating commercial nuclear reactors have adecuately demonstrated that their current cr-line RPS test intervals meet the requirements of GL 83-28, Item 4.5.3.

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SUMMARY

The two anticipated transient without scram (ATWS) events at the Salem Nuclear Power Plant in February of 1983, focused the attention of the Nuclear Regulatory Commission (NRC) on the generic implications of ATWS events. The NRC then published Generic letter 83-28 (GL 83-28) which listed the. actions the NRC required of all licensees holding  ;

operating licenses and others with respect to assuring the reliability of )

the Reactor Protection System (RPS). GL 83-28, Item 4.5.3, required licensees to demonstrate by review that the current on-line functional testing intervals are consistent with achieving high reactor trip system (RTS) availability. The licensees responded to the GL 83-28, Item 4.5.3, i requirements as Owners Groups with reports either in direct response to  ;

Item 4 5.3, or with a technical basis for requesting extensions to the surveillance test intervals (STIs) that generally included the Item 4.5.3 )

requirea reviews. I i

l The NRC's Instrumentation and Control Systems Branch (ICSB), Office of Nuclear Reactor Regulation (NRR), requested the Idaho National Engineering Laboratory (INEL) to review the licensee availability i analyses ano evaluate the overall adequacy of the existing test 1 intervals. INEL review results showing general compliance with Item 4.5.3 will provide the NRC with a basis to close out Item 4.5.3 without  !

further review.

For the review, the INEL defined three acceptance criteria, reviewed the licensees topical reports, contractor review reports, and NRC safety evaluations, and determined the adequacy of the analyses and the RTS availability estimates with regard to the review criteria, The INEL review criteria to determine the licensees' Item 4.5.3 compliance were, (1) the five areas of concern of Item 4.5.3, (2) the analyses' plant applicability, and (3) the NRC's RTS electrical unavailability base case estimates from the ATWS Rulemaking Paper, SECY-83-293.

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Each Owners Groups' reports were reviewed to ensure that all five areas of concern,from Item 4.5.3 were either included in the analyses or shown not to be significant with regard to RTS availability. The INEL

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review also ensured that the individual plants' differences from the analysis' models were taken into account and their effects were shown not to significantly affect RTS unavailability. The Fort St. Vrain responses to Item 4.5.3 were also reviewed.

The Owners Groups' RTS unavailability estimates were compared to the NRC's ATWS Rulemaking generic RTS unavailability estimates to determine the acceptability of the Owners Groups' conclusions that high RTS availability was demonstrated in the analyses.

The results of the INEL review showed that all licensees of currently operating commercial nuclear reactors have adequately demonstrated that their current on-line surveillance test intervals are consistent with achieving high RTS availability.

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ACRONYMS i

ATWS Anticipated Transient Without Scram B&W Babcock & Wilcox BNL Brookhaven National Laboratory CE Comoustion Engineering GE General Electric HTGR High-Temperature Gas-Cooled Reactor ICSB Instrumentation and Control Systems Branch INEL Idaho National Engineering Laboratory LWR Light Water Reactor NFSC Nuclear Facility Safety Committee NRC Nuclear Regulatory Commission NRR Office of Nuclear Reactor Regulation-PORC Plant Operations Review Committee PSC Public Sarvice Company of Colorado PWR Pressurized Water Reactor RSSMAP Reactor Safety Study Metnocology Applications Program RPS Reactor Protection System RTS Reactor Trip System SER Safety Evaluation Recert STI Surveillance Test Interval TER Technical Evaluation Report W Westinghouse 1

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CONTENTS ABSTRACT ... .. . . .. .

........ ............... ....... ..... ii

SUMMARY

...... ..... ..... .. ..... ............ iii ACRONYMS .. ..

................................... ................ v

1. INTRODUCTION ................. ....

......................... .... 1 1.1 Historical Background ................................. .. . I 1.2 Review Purpose ........... .. .............................. 3

2. REVIEW CRITERIA ........

. . ......... ....... ................ 4

3. REVIEW METHODOLOGY

... . .......... ........................ .... 6 4 REVIEW RESULTS . .. ..

... .. . . ........ .. .... . .. 7 4.1 B&W Plants ........ ... .

.............. ........ .. .. .. 8 4.2 CE Plants ................ .......... ..................... 7 4.3 GE Plants ...... ..

.... ................................ 9 4.4 Westinghouse Plants

..................... ......... .. .. 10 4.5 Quantitative Review of Vendors' RTS Unavailab111 ties . . . 11 4.6 Fort St. Vrain .. .......... .............. ......... ... . 14

5. REVIEW CONCLUSIONS .....

...... ........... . ...... ............ 16 Rtr. n N. .a e

6. .. ...... .... . .

. ............ ............... I ,t TABLES 1.

Comparison of Vendor and NRC RTS Unavailability Estimates .... ............... ................ ....... . .. . 13 vi 1 l

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TECHNICAL EVALUATION REPORT: A REVIEW OF REACTOR TRIP SYSTEM AVAILABILITY ANALYSES FOR GENERIC LETTER 83-28,

. ITEM 4.5.3 RESOLUTION

1. -INTRODUCTION 1.1 Historical Background j In February of 1983, two events occurred at the Salem Nuclear j l ' Generating Station that focused Nuclear Regulatory Commission (NRC) l attention on the generic implications of anticipated transient without scram (ATWS) events.

First, on Feb uary 22, during startup of Unit 1 an automatic. trip signal generated as a result of a steam generator low-low level failed to.

1 cause a reactor scram. The reactor was tripped manually by'an operator-almost coincidentally with the automatic trip signal, so the fact that the automatic trip had failed to cause a scram went. unnoticed, j ]

l Three days later on February 25, both of the scram' breakers at Unit I failed to open on an automatic reactor protection-system (RPS). scram i signal. The operators took action to control this second ATWS and I succeeded in terminating the incident'in about 30 seconds. Subsequent investigation related the failure cf the Unit 1 RPS to cause a scram to 'j l sticking of the undervoltage trip attachment in the scram circuit breakers.

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As a result of these events the NRC Executive Director for Operations .

directed the staff to undertake three related activities: (1) an evaluation of when and under what conditions the Salem plants would be j <

allowed to restart; (2) a fact finding report.of the events at Salem 1.and

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i the circumstances leading to them; and (3)- a report on the generic  !

implications o' these events.

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To address (3) above an interoffice,' interdisciplinary group was )

i formed includ'ng members'from the Office of Nuclear Reactor. Regulation's 4 1

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y (NRR's) Division of Licensing, Division of Systems Integration, Division of Human Factors Safety, Division of Engineering, Division of Safety Technology, the Office of Inspection and Enforcement, the Office for Analysis and Evaluation of Operational Data, and NRC's Region I Office.

This group published NUREG-10001 as a result of their efforts to resolve the following questions: (1) is there a need for prompt actions to address similar eauipment in other facilities; (2) are the NRC and its licensees learning the safety management lessons; and (3) how should the priority and content of the ATWS Rule be adjusted.

As a result of the NUREG-1000 findings, tne NRC issued Generic Letter 83-282 (GL 83-28). The actions described in GL 83-28 address issues related to reactor trip system (RTS) reliability. The actions covered fall into the f ollowing four areas: (1) Post-Trip Review, (2)

Equipment Classification and Vender Interface, (3) Post-Maintenance Testing, and (4) Reactor Trip System Reliability Improvements.

Item 4, above, is aimed at assuring that vendor-recommended reactor trip breaker modifications and associated reactor protection system changes are completed in pressurized water reactors (PWRs), that a comprehensive program of preventive maintenance and surveillance testing is implemented for the reactor trip breakers in PWRs, that the shunt trip attachment activates automatically in all PWRs that use circuit breakers in their reactor trip systems, and to ensure that on-line functional testing of the reactor trip system is performeo on all light water reactors (LWRs).

The specific requirements of GL 83-28, Item 4.5.3, are that existing intervals for on-line functional testing required by Technical Specifications shall be reviewed to determine if the intervals are consistent with achieving high RTS availability when accounting for considerations such as: (1) uncertainties in component ft;.are rates; (2) '

uncertainties in common mode failure rates; (3) reduced redundancy during testirg; (4) operator errors during testing; and (5) component " wear-cut" caused by testing.

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The Babcock & Wilcox (B&W), Combustion Engineering (CE), General Electric (GE), and Westinghouse (W) Owners Groups have submitted topical j

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reports either in response to GL 83-28, Item 4.5.3'3'4 or a prWe a basis for requesting RTS surveillance test interval (STI) extensions.5,6,7,8,9,10,11 In general, the owners groups' analyses were not done on a plant specific basis. Instead, the analyses addressed a particular c% ss of reactor trip system and then discussed the applicability of the analysis to specific product lines. The.NRC reviewed i these reports for, among other things, their applicability to GL 83-28, Item 4.5.3 and summarized their findings in Safety Evaluation R4oorts12,13 (SERs).

1.2 Review Purpose This report cocuments a review of the Owners Groups' topical reports, I the NRC SERs, and other analyses done at the Idaho National Engineering Laboratory (INEL) by personnel in the NRC Risk Analysis Unit of EG&G Idaho, Inc. The INEL conducted the review at the request of the U.S. Nuclear Regulatory Commission, Office of Nuclear Reactor Regulation, Instrumentation and Control Systems Branch (ICSB). The review was performed to determine if the Owners Groups' analyses demonstrated high RTS availability for the current test intervals, if the analyses included the five areas of concern from GL 83-28, and if all of the plants were covered by the analyses. The results of the review, if all plants are shown to be covered by an adequate analysis, would provide the NRC with a basis for i closing out GL 83-28, Item 4.5.3, for all U.S. commercial nuclear reactors without further review.

The body of this report presents the review and it's findings with regard to the stated objectives. Section 2 describes the criteria used in the review to determine the adequacy of the analyses. The review l methodology is discussed in Section 3. Section 4 presents the review l results. The review conclusions are given in Section 5.

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2. REVIEW CRITERIA To conduct a review, one must have criteria, or standards, on which a judgment or decisions may be' based. In this section, the INEL availability analyses review criteria are presented.

GL B3-28 established the three criteria used in the INEL review.

GL 83-23 stated that: (1) all licensees et al., (2) must demonstrate high RTS avaliacility for the current test intervals by documented review when (3) accounting for such considerations as the five areas of concern listed in Section 1.1. While GL 83-28 established all three criteria, it only defined two of them- who had to do a review and what the review had to take into account. The third and most subjective criterion, "high availability", was not defined.

To establish a definition of high availability, the INEL used the electrical unavailability base case estimates presented in Table A-1 of Appendix A to SECY-83-293.14 Unavailability is defined as 1.0 minus availability. A low unavailability is equivalent to a high availability.

Most analyses calculate a system unavailability rather than an availability. Therefore, our criteria for a "high availability" will be expressed in terms of low unavailability for compatibility. These RTS unavailability estimates from Reference 14 were used for two reasons.

First, they were used because they were developed by the NRC's ATWS Task Force as a reevaluation of the bases for the RTS unavailabilities used in ATWS rule value-impact evaluations. Second, as stated in Reference 14, this NRC analysis

. bases the RTS unavailabilities on worldwide experience to date. It is believed that this gives a reasonable estimate of RTS unavailability that includes the common cause contributions that are believed to dominate. The experience based values are distributed across the four vendor designs based on a comparative reliability analysis that evaluates the major cif#erences among the designs."

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The estimates from the NRC ATWS analysis provide. a framework with which to consider the topical. report analyses estimates. The numerical estimates in the SECY-83-293.for the four vendors combined with the five areas of concern from GL 83-28, Item 4.5.3, form the criteria used for this review to determine if the vendors' analyses ~and estimates met the requirements of Item 4.5.3.

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3. REVIEW METHODOLOGY The INEL conducted this review by examining the vendors' topical reports (References 3, 4, 5, 6, 7, 8, 9, 10, and 11), the technical evaluation reports 15,16.17,18 (TERs) done as a part of the NRC topical report review pr: cess, the NRC's SERs (References 12 and 13), and NUREG/CR-5197, Evaluation of Generic Issue 115, " Enhancement of Westinghouse Solic State protection System."19 This was done for three reasons. First, the reports were examined to find out whether or not the vendors' analyses addressed the areas of concern from Item 4.5.3 and reflected a high RTS availability. Second, they were examined to determine what plants were covered by the vendors' analyses. Third, the Generic Issue 115 report provided an independent, updated estimate of the availability of the W solid state RTS for comparison to the review criteria.

For the plants covered by the vendors' analyses or the NUREG/CR-5197 analysis, the appropriate analysis and availability were compared to the review criteria established in Section 2. If the analysis adequately addressed the areas of concern and demonstrated a high RTS availability, the plant was accepted as having met the requirements of GL $3-28, Item 4.5.3. The results of the comparisons for plants covered by a vendor analysis are given by vender in Section 4 For plants not directly covered by a vendor's analysi:, an acceptable means was found to extend the analyses to cover the plants. Th'is was done for two plants: The means by which Clinton 1 (GE) and Maine Yankee (CE).

the analyses were extended to cover these two plants are also discussed by vendor in Section 4 One plant, Fort St. Vrain, a high temperature, gas-cooled reactor (HTGR), was not covered by any of the four vendors' analyses and required special consideration. The INEL examined the responses from Fort St. Vrain recuired by GL 83-28, Item 4.5.3 to decermine if the responses demonstrated an acceptably high RTS availability. The review of the Fort St. Vrain responses is given in Section 4.6.

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4. REVIEW RESULTS This section summarizes the results of the INEL review of the vendors' analyses with regard to the five areas of concern and plant applicability.

The venders' estimates of RTS availability are compared to the review availability criteria. Also, some insights concerning RTS availability, gained from an examination of RTS importance measures from selected PRAs, I are examined.

4.1 B&W Plants I 1

The issues of GL 83-28, Item 4.5.3, were addressed by .the B&W Owners Group and the results'were submitted to the NRC by the individual utilities in their responses to GL 83-28. Topical Report BAW-10167 (Reference 5) was ]

submitted to tne NRC to provide a technical basis for increasing the l on-line STIs and allowed outage times ( A0Ts) for B&W RTS instrument  ;

strings. The analysis presented in BAW-10167 was built upon the previous i i

analysis done tr address the GL 83-28, Item 4.5.3 issues. However, some  ;

information tnat was resolved in the generic letter analysis was not repeated in the subsequent Topical Report because it was not relevant to the proposed Technical Specification changes. To make BAW-10167 applicable to both GL 83-28, Item 4.5.3 and STI/A0T issues, the Owners Group submitted BAW-10'.67, Supplement 1 (Reference 6), to the NRC. Supplement 1 completed the B&W analysis by addressing all remaining Item 4.5.3 issues. The  !

BAW -10167 and Supplement I analyses included the implementation of the automatic shunt trip on the reactor trip circuit breakers as required by GL 83-28, Item 4.3.

The INEL has previously reviewed the BAW-10167 and Supplement 1 analyses and documented the review in a TER, EGG-REQ-7718 (Reference 15)..

For the TER, sensitivity stucies which included all of the Item 4.5.3 areas of concern were conducted on the RTS mocels. The sensisity study results showed the models to be insensitive to variations in t',e failure rates associate with the Item 4.5.3 areas of concern.

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. l The INEL reviewed BAW-10167, BAW-10167, Supplement 1, and the TER and determined that t'he B&W analyses adequately covered all five areas of concern and that all currently operating B&W reactors are included.

4.2 CE plants Licensees with CE reactors responded to the requirements of GL 83-28, Item 4.5.3, as the CE Owners Group by submitting CE NPSD-277 (Reference 3) to the NRC. The NPSD-277 RTS availability analysis specifically included all five areas of concern and all currently operating CE reactors except Waterford 3, which was not in commercial operation until September 1985.

The CE Owners Group also submitted CEN-327 (Reference 7) to provide licensees with a basis for requesting RTS STI extensions. This later analysis expanded on the simplified models of NPSD-277 to include all RTS input parameters. All currently operating CE plants except Maine Yankee were covered in the CEN-327 analysis. The CEN-327 STI inalysis specifically included the NPSD-277 analyses of th Item 4.5.3 areas of concern except component " wear-cut" during testing. The CEN-327 analysis showed that the major contributors to RTS unavailability for the four plant classes are common cause failures of the trip circuit breakers which are tested on a monthly basis.

In both NPSD-277 and CEN-327, the CE RPS designs are grouped into four classes by signal processing and trip device differences, otherwise the logic and physical layouts of the RTS are the same for all RTS plant classes. In NPSD-277, Maine Yankee is included in RPS Plant Class 2. In CEN-327, Waterford 3 is included in RpS Plant Class 3. Between NPSD-277 ard "EN-327, all of the CE plants are included in plant classes analyzed in CEN-327. This review considers the analysis and results in CEN-327 adecuate for Item 4.5.3 resolution for all classes of CE plants.

Tne INEL has previously reviewed CEN-327 with regard to STI extension effects and cocumented the review in a TER, EGG-REQ-7768 (Reference 16).

The results of sensitivity studies done for the TER show the models to be insensitive to an orcer of magnitude increase in the component independent 8

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failure rates. The insensitivity to increased component failure rates along with the CE analysis results showing trip circuit breaker common-cause failures to be the major contributor to RTS unavailability-provides a a basis for this review to conclude that RTS test-induced component wear-out is not an issue at CE reactors.

The INEL reviewed CEN-327 and the TER and determined that the CE analyses have adequately covered all five areas of concern or they have been shown not to contribute to RTS unavailability and that all. currently operating CE reactors are included.

4.3 GE Plants Licensees with GE reactors responded to the GL 83-28, item 4.5.3 requirements as the BWR Owners' Group by submitting NECD-30844 (Reference 4) to the NRC. The RTS availability analysis specifically included the five areas of concern and covered both generic relay and solid-state RTS designs which includes all currently operating BWRs. GE stated that the relay RPS configurations for BWR plants have the same primary design features. Therefore, the generic reley RTS models used in NECD-30844 do not differ significantly from the specific BWR plants. GE used the Clinton 1 erawings for the solid-state RTS models. Since Clinton 1 is currently the only GE plant with a solid state RTS, no plant unique analysis is necessary.

The BWR Owners' Group also submitted NECD-30851P (Reference 8) to the NRC. The analysis in this second report used the base case results from NECD-30844 to establish a basis for requesting revisions to the current Technical Specifications for the RTS. The INEL had previously reviewed NECD-30844 and NECD-30851P with regard to both Item 4.5.3 and STI extension acceptability and documented the review in a TER, EGG-EA-7105 (Reference 17). Due to insufficient information, the INEL review could act com;lete the solid-state RTS review and accepted only the relay RTS analysis results. The NRC reviewed the topical reports and the TER and 9

4 issued an SER (Reference 12). The NRC accepted the analysis results as a reference for TS ~ changes related to the RTS and as resolution to GL 83-28, Item 4.5.3, for GE relay plants only. The INEL later completed the solid 6 state RTS analysis review and issued Rev 1 to the TER (Reference 18), thus accepting the analyses for all classes of GE plants.

This review examined both GE analyses and the Rev 1 TER and determined that all five areas of concern are included in the analyses and that all currently operating GE reactors are included.

4.4 Westincheuse Plants Licensees with Westinghouse reactors did not respond directly to the requirements of GL 83-28, Item 4.5.3. Prior to the Salem ATWS, they had submitted WCAP-10271 (Reference 9) to the NRC to provide a basis for recuesting changes to the Technical Specifications regarding the RTS. The Westinghouse methodology attempted to balance safety and operability and was applied to a typical Westinghouse four loop reactor plant with a solid state RTS in WCAP-10271. The methodology was extended to cover RTSs for two, three, and four loop plants with either relay or solid state logic in l WCAP-10271 Supplement 1 (Reference 10).

l The NRC reviewed the Westinghouse topical reports with the assistance of Brookhaven National Laboratory (BNL) and issued an SER (Reference 13) )

limiting their acceptance to changes to only the analog channel STIs at Westinghouse plants.

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The W methodology used fault trees to model the RTS. The models I included the following five major contributors to RTS trip unavailability: I

1. Unavailability of components due to random failures

2. Unavailability of components due to test l l

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3. Unavailability of components due to unscheduled maintenance 4 Unavailability of components due to human error:

5. Unavailability of components due to common cause failure.  !

While the y analysis did not dire:tly include any sensitivity studies I cencerning these five areas, the component unavailabilities were increased as the test interval length increased. The STI analysis results'showed a factor of 3 to 5 increase in the RTS unavailability estimates for the longer test interval. Two conservatism exist in the models that are relevant: first, no credit was taken for early failures that would be .

detected and, second, no credit was taken for the diversity inherent in the

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y RTS design. These two conservatism, had they been included in the ]

model, would cause the increase in the RTS unavailability estimates to be smaller than the observed factors.

Test-induced component wear-cut was not addressed in any manner in the W RTS analysis. However, the RTS analyses done by the other vendors, References 3, 4 and 6, specifically investigated the effects of this issue on RTS unavailability. Despite the differences among the other vendors' RTS cesigns, they all found the effects of test induced component wear-cut on RTS unavailability to be insignificant. Based on the other vendors

• analyses, the INEL concluded that the effects of test-induced' component , )

wear-out on y RTS unavailability would also be insignificant. Therefore, the INEL consicers all y plants to be coverec by adequate analyses, a.5 Quantitative Review of Vendors' RtS Availab111 ties

~ i So far, only the adequacy of the vendors' analyses has been j discussed. No determination has been made of the' acceptability of the l 1

numerical estimates from the various RTS availability analyses. In this  !

section, the INEL review considers the four Owners Groups' RT5 availability  ;

estimates to determine if they are inceed indicative of "high availability." )

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In Table 1, the four vendors' RTS unavailability estimates are compared to the review estimates of low unavailability as defined in Section 2, The B&W and GE vendors' estimates are given as an overall RTS unavailability per demand by plant model and RTS type, respectively. The CE and W vendors' estimates are given on a similar basis with an additional consideration that was not necessary for the B&W and GE analyses. In the CE and W analyses, RTS unavailability was estimated for all input parameters.

For the CE and W unavailability estimates in Table 1, the INEL used the unavailability estimates for high pressurizer pressure, the parameter analyzed in Reference 19 as the limiting o* ameter for an ATWS in terms of the number of input channels and diver 1ty of trip signal.

The differences in the relative values of the three PWR vendors' RTS unavailability estimates can be attributed to design differences among the RTSs.

B&W and CE RTSs have four analog channel inputs for each monitored parameter with four trip logic channels while W RTSs have three or four analog channel inputs for each parameter with only two trip logic channels.

The 2 of 4 analog channels for the B&W and CE RTS designs are inherently more reliable than the 2 of 3 analog channels for some parameters in the W design. Also the 2 of 4 trip logic in the B&W and CE RTSs is more reliable than the W 1 of 2 trip logic. The combination of these two design differences make the W RTS unreliability somewhat higher than the other vendors' RTS unavailabilities.

The comparison shows the B&W, CE, and GE RTS unavailability estimates are lower than the NRC's estimates while the W estimates are the same as the NRC's. The INEL review recognizes the Vendors' estimates and the NRC's estimates are influenced by a number of factors. These factors include, (1) the data uncertainties for both the NRC and Vendors analyses, (2) the scarcity of actual RTS failures world wide, (3) the modeling assumptions and simplifications used by both the NRC and the Vendors, and (4) the differing levels of model development between the NRC analysis and the Venders' analyses and between different Venders' analyses. These factors 12

a TABLE 1. COMPARISON OF VENDOR AND NRC RTS UNAVAILABILITY ESTIMATES *

~

.i Vendor RTS NRC RTS Unavailability Estimates b f Unavailability Estimates Vendor (Failures / Demand) (Failures / Demand)

- B&W 1

.  ?

C d Davis Bessie Model IE 3E-5 l d

Oconee Class Model IE-6 C 3E-5 CE Plant Class 1 2E-7' 2E-5 Plant Class 2' 3E-6'- 2E-5 Plant Class 3 3E-6' 2E-5 i Plant Class 4 2E-6' 2E-5

)

GE f

Relay Plants ' E-4 6 2E-5 f

Solid-state Plants 3E-6 2E-5 Y

Relay Plants d SE-59 SE-5 Solid-state Plants 5E-59 '5E-5d

a. All estimates are rounded off to one significant digit, 1

b. From Reference 14, Table A-1, base' case RTS electrical unavailability-estimates,

c. From Reference 5, base case,

d. Includes automatic shunt trip on the reactor trip circuit breakers.

e. From Reference 7, Tables a.1-1, 4.2-2, 4.1-3, and 4.1-4, respectively; base case test interval, high pressurizer pressure unavailability estimate.

f. From Reference 4.

g. From Reference 19, solid state RTS base case. Applied to relay-plants based on similarity of design (see Reference 11, Section 3.2.2 and 3.2.3).

13

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help explain the differences between the Vendors' and the NRC's point estimates cf RTS~ availability.

4.6 Fort St. Vrain Fort St. Vrain responded to GL 83-28, Item 4.5.3 in a letter to 20 Eisenhut dated November 4, 1983 , stating:

" Existing intervals for on-line functional testing required by the Technical Specifications are currently under review by Public Service Company of Colorado (PSC) and the Nuclear Regulatory Commission Region IV staff. The current I testing frecuency at Fort St. Vrain has been dictated by the Nuclear Regulatory Commission staff." (Uncerline added)

In response to a request for information from the NRC concerning the l Fort St. Vrain responses to GL 83-28 previously sent, PSC sent the following reply to the NRC in a letter to Johnson, dated June 12, 1985 21

" Existing intervals for the on-line testing required by the Technical Specifications were reviewed by Public Service Company of Colorado. A Technical Specification change to Limiting Conditions for Operation 4.4.1 (Plant Protective System) and its associated surveillance requirements (SR 5.4.1) are currently being reviewed Dy the Plant Operations Review Committee (PORC).

This Technical Specification change is expected to be approved by the PORC and the Nuclear Facility Safety Committee (NSFC) by June 30, 1985.. As part of the development process for these proposed changes to the Technical Specifications, on-line functional testing requirements were reviewed based on past experience.

Possible changes to the testing intervals in certain cases where available test data may support such changes has (sic) been discussed at length with the Nuclear Regulatory Commission staff. The Nuclear Regulatory Commission staff has informed Public Service Company of Colorado that no such changes would be acceptable at this time."

The INEL review interpreted these responses from Fort St. Vrain to mean the N3 has established Fort St. Vrain's RTS current test intervals, the current test intervals have been evaluated by PSC, and the NRC will not allow changes to the test intervals at this time.

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From these responses, the INEL concluded that Fort St. Vrain has conducted the review required by GL 83-28, Item 4.5.3, and that the NRC considers the PSC and NRC reviews adequate to meet the Item 4.5.3 requirements.

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. s 5 REVIEW CONCLUSIONS ,

All four LWR vendors have submitted topical reports either in response to GL 83-28, Item 4.5.3, or to provide a basis for RTS STI extensions, or both. For the most part, these reports have addrested all of the issues in Item 4.5.3. Licensees not covered by the topical reports have submitted individual responses to Item 4.5.3.

1 The analyses in the topical report have shown the currently configured RTSs to be highly reliable with the current t*:t intervals and prior to )

implementing some of the requirements of GL 83-28. -Implementation of these additional requirements will reduce the ATWS risk even further.

The INEL has reviewed the relevant topical reports, TERs, SERs, accitional analyses, and the individual licensee submittals with regard to GL 83-28, Item 4.5.3, requirements and the review criteria. Based on that review, the INEL concludes that all licensees of currently operating commercial nuclear power plants have adequately demonstrated that their current RTS test intervals are consistent with achieving high RTS availability.

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6. REFERENCES

1. U.S. Nuclear Regulatory Commission, Generic Implications of ATWS Events at the Salem Nuclear Power Plant, NUREG-1000, April 1983.

2. U.S. Nuclear Regulatory Commission Letter, D. G. Eisenhut to All Licensees et al., Required Actions Based on Generic Implications of Salem ATWS Events Generic Letter 83-28, July 8,1983.

3. Combustion Engineering, Reactor Protection System Test Interval Evaluation, Task 486, CE NPSD-277, Decemoer 1984.

4 S. Visweswaran et al., BWR Owners' Group Response to NRC Generic Letter 83-28, Item 4.5.3, NECD-30844, January 1985.

5. R. S. Enzinna et al., Justification for Increasing the Reactor Trip System On-line Test Interval, BAW-10167, May 1986.

6. R. S. Enzinna et al., Justification for Increasing the Reactor Trip System On-line Test Interval, Supplement Numeer 1 BAW-10167, Supplement Numoer 1, Fectuary 1988.

7. Cembustion Engineering, RPS/ESFAS Extended Test Interval Evaluation, CEN-327, May 1986.

8. W. P. Sullivan et al., Technical Specification Improvement Analyses for BWR Reacter Protection System, NECD-30851P, May 1985.

9. R. L. Jansen et al., Evaluation of Surveillance Frequencies and Out of Service Times for the Reactor Protection Instrumentation System, WCAP-10271, January 1983.

10. R. L. Jansen et al., Evaluation of Surveillance Frequencies and Out of Service Times for the Reactor Protection Instrumentation System.

Supolement 1, WCAP-10271, Supplement 1, July 1983.

11. R. L. Jansen et al., Evaluation of Surveillance Frequencies and Out of Service Times for the Reactor Protection Instrumentation System.

Sucplement 1-P-A, WCAP-10271, Supplement 1-P-A, May 1986.

12. U.S. Nuclear Regulatory Commission Memorandum, G. C. Lainas to E. J.

Butcher, Acceotance for Referencing of General Electric Company (GE)

Topical Reports NECD-30844, " swr Owners' Group Response to NRC Generic Letter 83-28," and NECD-30851P, " Technical Specification Improvement Analyses for BWR Reactor Protection System,"' April 28, 1986.

13. U.S. Nuclear Regulatory Commission Letter, C. O Thomas to J. J.

Sheppard, Acceptance for Referencing of Licensing Topical Recort WCAP-10271, " Evaluation of Surveillance Frequencies anc Out of Service l

Times for the Reactor Protection Instrumentatier Systems," February 21, 1985.

17 I

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14. U.S. Nuclear Regulatory Commission, Amendments to 10 CFR 50 Related to Anticipated ~ Transients Without Scram ( ATWS) Events, SECY-83-293, July 19, 1983. ,

15. J. P, Poloski and S. D. Matthews, Review of B&W Dwner's Group Analyses for increasing The Reactor Trip System On-line Test Interval, EGG-REQ-7718, September 1988.

16. D. P. Mackowiak and B. L. Collins, A Review of the Combustion Engineering Evaluation For Extending the RPS and ESFAS Test Intervals, EGG-REQ-7768, September 1988.

17. R. E. Wrignt and B. L. Collins, A Review of the BWR Owners' Group Technical Specificaf. ion Improvement Analyses for the BwR Reactor Protection System, IGG-EA-7105, January 1986.

18. R. E. Wright and B. L. Collins, A Review of the BWR Owners' Grovo Technical $ specification Improvement Analyses for the BWR Reactor (

Protection System, EGG-EA-7105, Rev 1, Marcn 1987.

l

19. D. A. Reny et al., Evaluation of Generic Issue 115 Enhancement of the Reliability of Westinghouse Solid State Protection Systems, NUREG/CR-5197, January 1989.

20. Public Service Company of Colorado Letter, O. R. Lee to D. G.

Eisenhut, Response to Generic Letter 83-28, November 4, 1983.

21. Public Service Company of Colorado Letter, J. W. Gham to E. H.

Johnson, Response to Generic Letter 83-28, June 12, 1985.  ;

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TECHNICAL EVALUATION REr~0RT: A REVIEW.0F REACTOR TRIP SYSTEM AVAILABILITY' ANALYSES FOR GENERIC LETTER 83-28, ITEM 4.5.3, RESOLUTION  :

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.......... March -1989 David P. Mackcwiak . :. . n n. u..:

John A. Schroeder e. ....

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I Regulatory and Technical Assistance EG&G Idaho, Inc. "'-"'

P. O. Box 1625 Idaho Falls. ID 83415 D6001

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• o. neo.e Instrumentation and Control Systems Branch Technical Evaluation Report Division of Engineering and System Technology Office of Nuclear Reactor Regulation '"*'**'o"8"--'-'--

U.S. Nuclear Regulatory Comission Washington. DC 20555

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The Idaho National Engineering Laboratory (INEL) conducted a technical review of the commercial nuclear reactor licensees' responses to the requirements of the Nuclear  ;

Regulatory Commission's (NRC's) Generic Letter 83-28 (GL 83-28), Item 4.5.3. Theresultsf' of this review, if all plants are shown to be covered by an adequate Analysis, will j provide the NRC staff with a basis to close out this issue with no further review. j The licensees, as the four vendors' Owners' Groups, submitted saalyses to the NRC either i

directly in response to GL 83-26, Item 4.5.3, or to provide a basis for requesting changes l to the Technical Specifications (TSs) that would extend the Reactor Protection System '

(RPS) surveillance test intervals (STIs). To conduct the review, the INEL defined three criteria to determine the adequacy, the plant applicability, and the acceptability of the results. The INEL examined the Owners Groups' reports to determine if the analyses and results met the established criteria. Fort St. Vrain's responses to Item 4.5.3 were also reviewed. The INEL review results.show that all licensees of currently opera -

l ting commercial nuclear reactors have adequately demonstrated that their current on-line RPS test intervals meet the requirements of GL 83-28, Item 4.5.3.

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