ML18081A676

Forwards Info to Item 2 of Interim Position for Containment Purge & Vent Valve Operation Pending Resolution of Isolation Valve Operability

ML18081A676
Person / Time
Site:	Salem
Issue date:	11/21/1979
From:	Librizzi F Public Service Enterprise Group
To:	Schwencer A Office of Nuclear Reactor Regulation
References
NUDOCS 7912040410
Download: ML18081A676 (34)

Text

{{#Wiki_filter:* PS~G Public Service Electric and Gas Company 80 Park Place Newark, N.J. 07101 Phone 201 /430-7000 November 21, 1979 Mr. Albert Schwencer, Chief Operating Reactors Branch #1 Division of Operating Reactors U.S. Nuclear Regulatory Conunission Washington, DC 20555

Dear Mr. Schwencer:

CONTAINMENT PURGING AND VENTING DURING NORMAL OPERATION SALEM GENERATING STATION UNIT NO. 1 DOCKET NO. 50-272 . l In response to your letter of October -30, 1979 and the attached Interim Position for Containment Purge and Vent Valve Operation Pending Resolution of Isolation Valve Operability, we offer the following information to item 2 of the attachment. Position Item 2A

1.

The modifications to the 10" valves noted in our submittal to you dated October 5, 1979, have been accomplished and the valves have been reinstalled.

2.

The maximum valve opening for the 10" pressure vacuum

3.

relief valves was selected as 60° open to ensure that the original system design flow requirement of 2400 scfm was maintained. The valves with a 60° full open position will have a design flow rate of 2400 scfm whereas the original design flow rate for a 90° full open position was 5000 scfm. The maximum open position of 60° was justified by performing calculations to verify that the critical valve parts will not be damaged by DBA-LOCA loads and that the valve will tend to close when the fluid dynamic forces are introduced. In addition, failure mode calculations in the closed posi-tion were made by the valve vendor for both the 10 11 pressure vacuum relief valves and the 36" purge valves. Attachment No. 1 is a copy of the calculations. The 10" pressure and vacuum relief valves were tested to verify a closing time of less than 2 seconds required by the moa-m7H Ao3t s r:!@ n:\\llSOF Sl\\ll\\lCE Jfl 7 o:t2.o4o;'t~9' 95-2001 (ZOOM) 2-78

~:~ Albert Schwencer, Chief 2 - 11-21-79 Technical Specifications. Each of the two valves was tested under three different sets of conditions. A. Spring closure without air assist B. Spring closure with air assist

c.

Spring closure with air assist and a 47 psig back pressure on the solenoid exhaust The maximum closing time was 0.425 seconds. Attachment No. 2 shows the *valve closure time charts for the two valves for each of the three test conditions.

4.

A valve qualification program is being implemented on an expedited basis in accordance with the NRC's Guide-lines for Valve Operability and Mr. D. Eisenhut's letter of September 27, 1979. Position Tterri 2B

1.

An evaluation of the instrumentation and control cir-cuits was performed which confirmed that our design is no longer subject to override conditions which could prevent automatic valve closure during LOCA. This information was submitted to you in_ our letter dated January 30, 1979.

2.

Enclosed is the Control Division's Safety Evaluation CD-SE-9 "1-\\nalysis of Safeguards Equipment Control System and Solid State Protecition System" dated January 10, 1979. This is additional information which supplements the information submitted in January 1979.

3.

Enclosed are nine copie~ of the Public Service Logic Dia,gram No. 221057-B-9545-6, "Reactor Protection System Safegua,rds A.ctuation Signals". This logic diagram shows the original logic problem area (indicated by th.e red circle) and the iogic added (yellow line] to elim-inate the problem.

4.

We have reviewed the containment purge and pressure vacuum relief valve circuitry to verify that the design does not prevent automatic valve closure ~uring a LOCA.. Blocking signals will not prevent valve *closure. In our October 5, 1979 letter to you on this subject, Item 4, we stated "For the 36" purge valves, administ:r;'ative controls will be implemented to keep the valves closed in all operating modes

t Albert Schwencer, Chief 3 - 11-21-79 except modes 5 and 6 (cold shutdown and refueling)". It should be noted that when fulfilling technical specification surveil-lance requirements this restriction does not apply. Operation of these valves is required under the technical specifications in Sections 4.0.5, 4.3.2.1.l and 4.3.3.1. If you need any additional information, please feel free to contact us. Very truly yours, ~* Frank P. Li~ General Manager - Electric Production 1

I' .. ~ ATTACHMENT NO. 1 MASONEILAN INTERNATIONAL, INC. 10 mt1~1 llOtlrt PUBLIC SERVICE ELECTRIC I GAS COMPANY 10" 32200 BUTTERFLY VALVES BETTIS ACTUATOR MDL. 522C-SR-100 sc~-z.i-2.. L tv \\ \\.. "2-l-1-9 Tq(2.0Y.Otfl0 OPERATION ANALYSIS,11)£ n TURN TO UEACTOR nOCl{ET FILES /~. The Bettis Robotann is a spring opposed, pneumatic cylinder opera4;~r. During actuator loading, two 5" I.D. cylinders are pressurized to provide the necessary force to overcome the spring, valve friction, and dynamic loads. Although the spring force alone is sufficient to insure valve closure, an additional assist force is utilized to increase valve stroking {~ speed. The assist force is caused by air loading one cylinder in the direction to close the valve. The assist force and loading force will not act at the same time. Air for the assist force is obtained from the nonnal supply air. If the plant supply air fails, a backup accumulator tank will come on-line to air load the assist force. A postulated LOCA would raise the containment pressure to 47 psig. Actuator loading will change. Calculations to detennine the actuator forces during the various air loading configuration are shown on the attached sheets -*******

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OPS~G Public Service Eleclnc and Gas Company 80 Park Place Newark. N.J 07101 Phone 201/622-7000 Ja~uary 10, 1979 CONTROLS DIVISION SAFETY EVALUATION SALEM NUCLEAR GENERATING STATION CD-SE-9 ANALYSIS OF SAFEGUARDS EQUIPMENT CONTROL (SEC) SYSTEM AND SOLID STATE PROTECTION SYSTEM (SSPS) Summary Subsequent to an inadvertant blocking of a safety function due to a manual reset action, the NRC requested that an analysis of all such possibilities be performed. This safety evaluation presents the results of that study. The SEC and SSPS systems were analyzed to ascertain that a,manual reset upon completion of a logic sequence would not prevent proper acknowledgment and corrective action during a subsequent independent occurre~ce. Results of Analvsis The study revealed that, other than the occurrence reported to the NRC concerning the containment ventilation isolation system (reset of SSPS with high radiation condition present), no safety functions of the SSPS can be blocked by i manual reset of an unrelated occurrence. In the SEC System, no memory device would prevent it from switch-ing modes of operation. It was discovered that manual reset upon completion of a Mode 1 (LOCA) sequence could prevent proper action if a subsequent blackout were to occur. In this case, the SEC System would acknowledge only the blackout condition due to the reset of the LOCA signal from the SSPS. This problem bas been addressed in Station Emergency Instruction EI I4.4. which alerts the operator to this incident and the need to re-start safeguards pumps followin~ the completion of the blackout sequence (Mode III}. Conditions and Assumptions

l. Both systems were analyzed with the initial condition of normal power operation.

2.

The SSPS was analyzed on a circuit by circuit basis. I J

CD-SE-9 2 - 1/10/79 Conditions and Assumptions {Cont'd)

3.

The entire sequence of operation was followed through on the SEC System iccluding the shift from one mode to another and a second occurrence following manual reset. Discussion The SEC system analysis encompassed various operating modes of the system. They were:

l.

Undervoltage on all three 4-KV vital busses (blackout).

2.

Loss of Coolant Accident (LOCA) upon completion of diesel generator loading sequence (all 4-KV vital busses supplied fro~ the diesel generators) and before the SEC is reset.

3.

Reset of the SEC upon completion of protective functions. The SEC system performance was analyzed starting with the initial 2/3 vital bus undervoltage signal. No functions were found to be impaired due to the lack of system reset prior to a subsequent LOC.t; input. Other se~uences of operation analyzed were:

1.

Undervoltage an all three vital busses followed through to manual reset with a subsequent LOCA.

2.

LOCA condition followed through to manual reset followed by a blackout condition. During the analysis, it was found that the SEC system could not be manually reset until its predetermined functions were per-formed. The removal of the initiating signal (or signals) was another prerequisite for manual reset. Also, the manual reset did not impair any SEC functions required for subsequent actuat-ing signals except for the condition previously discussed (LOCA followed by manual reset and subsequent blackout). There exists the possibility that the manual reset would not operate due to equipment malfunction. In the event this occurs and the SEC system must be reset to obtain manual control of the safeguards equipment, the SEC system may be bypassed by de-energizing the 115V A.C. supply to the input relays. If this action is taken, any subsequent input signals will not be acknowledged by the SEC and its outputs would be defeated.

/ CD-SE-9 3 - l/10/79 Tbe SSPS vas analyzed on a circuit by circuit basis to determine if any manual reset could inadvertently block.a safety function. Tbe same philosophy vas used as in the SEC analysis, i.e., if one signal energized a memory device, would tbis action prevent a subsequent signal from being registered. No evidence of either possibility vas found.

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