Text

Responds to NRC 870527 Request for Addl Info Re Inservice Insp & Testing Program,Supplementing Util 850627 & 860729 Submittals
	ML20236G892
Person / Time
Site:	Millstone
Issue date:	07/31/1987
From:	Mroczka E; NORTHEAST NUCLEAR ENERGY CO., NORTHEAST UTILITIES
To:	; NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM)
References
	A06578, A6578, NUDOCS 8708040413
	Download: ML20236G892 (73)
	v • d • e

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, c u.w HARTFORD, CONNECTICUT 06141-0270 (203) 665-5000 July 31,1987 Docket No. 50-336 A06578 Re: 10CFR50.55a(g)

U.S. Nuclear Regulatory Commission Attn: Document Control Desk

. Washington, D.C. 20555 i Gentlemen:

Millstone Nuclear Power Station, Unit No. 2 l In-Service Inspection and Testing Program By letter dated June 27, 1985,(1) Northeast Nuclear Energy Company (NNECO) submitted, as required by 10CFR50.55a(g), a description of the in-service inspec- ;

tion and testing program, and " requests for relief" from code requirements as !

necessary, for the second ten-year inspection interval for Millstone Unit No. 2.

By letter de ted July 29, 1986,(2) the NRC Staff requested that NNECO provide additional information regarding the in-service inspection program at Millstone Unit No. 2. NNECO responded to the request by letter dated December 23, 1986.13) That submittal included an updated version of the in-service inspection and testing program, revised " requests for relief," and the additional information requested by tne Staff.

In response to the NRC Staff's request dated May 27, 1987,(4) NNECO hereby provides the following additional information regarding the in-service inspection and testing program.

NNECO believes that the attached information fully addresses the additional information requested by the Staff in Reference (4).

(1) 3. F. Opeka letter to the Director of Nuclear Reactor Regulation, dated June 27,1985, " Millstone Nuclear Power Station, Unit No. 2, In-Service Inspection and Testing Prs a m ."

(2) D. H. Jaffe letter to 3. F. Opeka, dated July 29,1986.

(3) E. 3. Mroczka letter to Director of Nuclear Reactor Regulation, dated ;

December 23,1986, " Millstone Nuclear Power Station, Unit No. 2 Inservice Inspection and Testing Program, Request for Additional Information."

(4) D. H. Jaffe letter to E. 3. Mroczka, dated May 27,1987, " Millstone Nuclear Station, Unit No. 2 (TAC #59265)." \

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U. S. Nuclear Regulatory Commission A06578/Page 2.

-3uly 31,1987 Please contact us if ycu have any questions.

'1 Very truly yours, !

NORTHEAST NUCLEAR ENERGY COMPANY M xv E. 7.ffr6c'zf<a' (/

Seni6r Vice President P

cc: W. T. Russell, Region 1 Administrator D. H. Jaffe, NRC Project Manager, Millstone Unit No. 2 T. Rebelowski, Resident Inspector, Millstone Unit Nos. I and 2 4

4 Docket No. 50-336 A06578 Attachment Millstone Nuclear Power Station, Unit No. 2 Additional Information on In-Service Inspection and Testing Program July 1987

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RESPONSE T0 NRC REQUEST FOR ADDITIONAL INFORMATION ON MILLSTONE UNIT 2 PUMP AND VALVE INSERVICE TESTING PROGRAM I; VALVE TESTING .

r As General Questions and Comments

1. Provide a list of all valves that perform both a containment isolation function and a pressure boundary ,

isolation function and that are not leak rate tested to both the Appendix J and Section XI requirements.

There are five valves which perform both a pressure boundary isolation and a containment isolation valve function. None of these valves are tested in accordance with Section XI requirements. All are tested in accordance with Appendix J requirements. These valves are:

2-CH-516 Letdown Isolation 2-CH-517 Auxiliary Spray Isolation .

2-CH-518' Loop 2A Charging Header Isolation 2-CH-519 Loop 1A Charging Header Isolation 2-SI-651 Shutdown Cooling Isolation Attachment 1 discusses these valves and others which have been considered in determining that there are "no valves for which seat leakage is limited to a specific maximum amount in the closed position of fulfillment of their function". No leakage rate testing is required by ASME Section XI.

.2. Provide a list of all valves that are Appendix J, Type C, leak rate tested that are not included in the IST Program and categorized A or A/C.

Attachment 11 has been revised so that all valves subject to Appendix J, Type C, leak rate testing are included in the IST Program and categorized A or A/C.

3. Provide the limiting value of full-stroke time for all power operated valves in the IST Program for the staff's j

review.

This limiting value of full-stroke time for power operated valves is listed in Attachment 3.

4. The NRC has concluded that the applicable leak test procedures and requirements for containment isolation valves are determined by 10CFR50, Appendix J, however, the licensee must comply with the Analysis of Leakage Rates and Corrective Action Requirements paragraphs of Section XI, IWV-3426 and IWV-3427.

Acknowledged.

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5. Valves whose test frequency is required to be increased to once each month as required by IWV-3417 and which can (

only be tested during cold shutdowns or refueling outages

shall be repaired before plant startup.

Northeast Nuclear Energy Company proposes the following i alternative:

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" Valves which can only be tested during cold shutdowns or refueling outages shall be retested to verify compliance with the acceptance criteria of Relief Request RR #36 or repaired _before plant startup. Evaluation of acceptable degraded performance or increased frequency tests shall not be used to allow continued operability of the valve.

The cause of the originally identified degradation shall be documented in the record of the test."

Vse of this criteria will avoid unnecessary repairs, with the attendant cost and personnel radiation exposure.

6. All valves with remote position indicators shall be observed at least once every 2 years to verify that valve operation is accurately indicated per IWV-3300.

Acknowledged. This Code requirement will be met. Valve lists have been updated to accurately reflect this requirement.

B. Spent Fuel Pool Cooling System

1. How are check valve 2-RW-67 and 222 verified to close?

These valves are not tested to the closed position.

Section XI, Article IWV-3522 requires: " Check valves shall be exercised to the position required to fulfill their function..." Article IWV-3522(b) states: " Valves that are normally closed during plant operation and whose function is to open on reversal of pressure differential shall be tested by proving that the disk moves promptly away from the seat when the closing pressure differential is removed and flow through.the valve is initiated..."

The safety-related function of these valves is to admit flow to the Spent Fuel Pool in the event makeup is required. The shut position of the check valve provides operational reliability and convenience but is not required to fulfill the safety-related function of the system. Backflow prevention is provided by the siphon breaker in the Spent Fuel Pool inlet line. Piping up to at least the first isolation valve meets the seismic design criteria. Thus testing these valves in the open direction only is appropriate. ;

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C. Main Steam System

1. How are valves 2-MS-4A and 4B verified to full-stroke

open quarterly? How are these valves verified to close quarterly?

These-valves are verified to fully open by starting the Terry Turbine Auxiliary Feedwater Pump, and verifying that it can be operated at full speed.

These valves are verified to close quarterly by shutting 2-MS-201/202 alternately while the Terry Turbine Auxiliary Feedwater Pump is running at full speed, opening the piping between 2-MS-201/202 to the drains 4 system and verifying that pressure in the piping between 2-MS-201/202 and the check valve promptly decreases and recovers slowly or not at all.

2. Provide a more specific technical justification for not full-stroke exercising valves 2-MS-65A and 658 quarterly.

The original Basis for Relief stated:

" Valves are normally closed and not required to change position during plant operation. Failure of one of these valves in the open position during exercise would jeopardize the ability to stop steam flow in the event of ;

a downstream rupture." i The following additional information is provided:

These valves are used to bypass the Main Steam Isolation Valves (MSIV) during plant startup to allov controlled .

piping warmup and equalization of pressure prior to 1 l

opening the MSIV's. Once the MSIV's are oper.ed, these valves are shut by plant operating procedure and remain shut during normal plant operation.

During plant startup, while the valves are open, a Main Steam Isolation Signal will close the valve automatical- .

ly. This signal does not cause any valve action during j periods when the valves are shut. -

l During any test, there exists a finite probability that one of the valves will malfunction. If these valves are opened for test during reactor operation and malfunction !

they could remain open. Allowing these valves to remain I open would provide a 3" bypass line around the MSIV to remain open if piping downstream of the MSIV ruptured, thus precluding complete flow interruption and interfering with the function of the Main Steam Isolation Signal. In this instance, plant shutdown and cooldown could be required to repair the valve. ,

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These valve are only opened during startup from cold shutdown. Testing the valves during cold shutdown and refuelings will provide adequate assurance that the valve

will be operable during the period it will be open.

.3. Provide a more specific technical justification for not full-stroke exercising valves 2-MS-190A and 190B quarterly.

These valves are the atmospheric steam dump valves.

Their principal function is to prevent steam generator pressure excursions following reactor or turbine trips.

While these valves are not required to be operable during reactor operation they do serve to minimize the challenges to the Main Steam Safety Valves.

Testing these valves during reactor operation would cause a substantial reactor power excursion unless the manual inlet valve was closed. Closing the manual inlet valve removes the protection provided by these valves. Northeast Nuclear Energy Company considers deliberate reduction of the protection margin provided by these valves during the time needed to test these valves unwarranted and therefore proposes to test these valves during cold shutdowns.

4 Review the safety function of valves 2-MS-1A and IB (P&ID location J-7 and D-9) to determine if they should be included in the IST Program.

The safety function of these valves is to limit reactor cooldown and containment pressurization in the event of a main steam line rupture upstream of the Main Steam Isolation Valves. These valves should be included in the IST program. Attachment 11 provides a revised valve list adding these valves to the program and Attachment 4 provides a relief request for the testing of these valves.

D. Containment Spray System

1. The NRC staff has determined that the air flow / audible test method of verifying the full-stroke capability of check valves is not acceptable, therefore, an alternate means of verifying full-stroke capability of valves 2-CS-5A and SB must be identified.

Northeast Nuclear Energy Company requests the NRC staff reconsider the acceptability of the air flow / audible test method of verifying full-stroke operation of these check valves.

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i This valve functions to allow flow to the spray header following a . Containment Spray Actuation System event. It also functions as the inside containment isolation valve "

on a line which is open to the containment atmosphere and penetrates the containment boundary.

The' valve is installed in a vertical pipe leading to the containment spray nozzles. The disk rests naturally in the closed position. Water, the normal f.uid in the system, cannot be used to test the valve'in the open direction since massive containment wetting would occur if full flow was passed through. the valve.

Northeast Nuclear Energy Company considers, based on experience, that admitting air upstream of the valve and.

verifying that the valve moves promptly to the open position by noting the sound of the valve impacting the disk stop provides adequate assurance that the valve moves freely and will move to the full open position when subjected to water flow.

Since no other fluid test will effectively test the operation of the valve, the u.ual alternative would be to disassemble the valve and verify manually that the disk travels as required. Northeast Nuclear Energy Company considers an air test which demonstrates full, free movement of the valve disk substantially more effective in demonstrating actual operability than disassembly of the valve.

Northeast Nuclear Energy Company requests the NRC staff approve the relief request as written.

2. Provide a more specific technical justification for not full-stroke exercising valves 2-CS-13.1A and 13.1B quarterly.

These valves are Category B, passive. In accordance with Table IWV-3700-1 Note 1, "No tests (are) required for Category B, C, and D passive valves." This correction is reflected in Attachment 11 and the revised relief requests.

3. Provide a more specific technical justification for not Tull-stroke exercising valves 2-CS-15A and ISB during cold shutdown or each refueling outage.

These valves cannot be stroke tested using system fluids.

To attempt to do so would require filling the containment-to design post-accident water depth. The proposed alternative, i.e., disassembly, visual examination and manually stroking the valve through full travel -

, requires that the safety injection suction header be isolated and drained. This creates approximately 15,000 gallons of radioactive liquid waste.

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!' .These valves sit in a carefully controlled water l environment. They are not subject to wear or other damage mechanisms. When the valves were first visually ~

examined in 1981 after more than seven years of " service" there was no evidence of corrosion or wear which could impact the operation or integrity of the valve. Northeast Nuclear Energy' Company considers _the more' frequent disassembly and inspection of these valves to have a higher potential for adverse impact than the proposed-examination schedule. Since no increase in' reliability or safety would result from increased examinations, the costs and personnel exposure as well as the genera' tion of radioactive liquid and solid waste associated with such tests, are considered not warranted. It should be noted

.that if degradation is found in the valve examined the other similar. valve would also be examined prior to reactor startup.

E. Safety Injection System

1. How are valves 2-51-215, 225, 235, and 245 full-stroke exercised during refueling outages?

These valves are tested by filling each Safety Injection Tank to the normal level, pressurizing the tank to approximately two atmospheres, and opening the outlet valve, (2-SI-614, 624, 634, or 644) allowing the tank to blow down to the refueling pool and measuring the rate of level: decrease. Engineering calculations have shown that a level decrease of approximately 10% of tank level per minute will lift the valve disk to the full open position.

2. How are valves 2-SI-217, 227, 237, and 247 full-stroke exercised during cold shutdown?

These valves are exercised full open by using them as the Shutdown Cooling injection flow path and verifying that flow in each header is at least full design flow. Valves are verified to shut by monitoring safety injection header pressure after cessation of shutdown cooling.

3. Evaluate the use of the six inch SI and containment spray test line to the RWST to full- or partial-stroke valves 2-SI-434 and 446 quarterly during power operation.

The use of the six inch SI and containment spray test line to the RWST is not warranted for-testing valves-2-SI-434 and 446 quarterly. Attempting to use this line could significantly detract from the ability of safety systems to perform their intended function.

e T The test line is not available without disabling both LPSI pumps and one containment spray header during the test. Opening either valve 2-SI-452 or 2-SI-453 opens ,

the discharge of both LPSI pumps to the selected containment spray header which must be manually isolated and realigned to provide access to the test line. (NOTE:

Valve 2-SI-657 is required to be locked closed during reactor operation thus direct access to the test line is impossible.) This action would seriously jeopardize the ability of the safety injection systems to perform their intended function in the event of an accident during the test. While not accurately calculated it is highly probable that sufficient flow would be diverted from the Low Pressure Safety Injection System to require that both trains of Low Pressure Safety Injection be considered IN0PERABLE during the conduct of the test. Unit Technical Specifications require plant shutdown within one hour if both trains of the Low Pressure Safety Injection System are inoperable.

The Low Pressure Safety Injection Pump discharge check valves are not subject to significant wear during reactor operation. Failures in large diameter check valves are almost exclusively caused by wear. There is normally no flow through these valves thus minimizing the potential for significant wear.

4. What is the "ET" test requirement as identified for valves 2-SI-614, 624, 634, and 644?

The designation "ET" for test requirement is an editorial error not detected prior to the submittal of the program.

The program has been reviewed and corrected. This correction is reflected in Attachment 11.

5. Provide the relief request or cold shutdown justification pertaining to valves 2-SI-618, 628, 638, and 648.

Relief Request RR #35 is included as Attachment 5. The relief requested is only for the fail-safe operation of the valve. Since the valves are inside containment fail-safe testing during reactor. operation is not practical.

The valves are exercised full-stroke quarterly.

6. Provide a list of valves that are leak rate tested as reactor coolant system pressure boundary isolation valves.

There are no reactor coolant system pressure boundary isolation valves that are leak rate tested in Millstone Unit 2. See Attachment 1 for a further discussion of this item.

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7. Describe any hot leg injection method that is used for .

long term recirculation post-LOCA at Millstone Unit 2.

Two methods are planned:

1. With a Low Pressure Safety Injection Pump taking suction on the containment sump, discharge flow is isolated from the normal flow path and directed to the Shutdown Cooling Suction Line via the warmup line. This flow path is shown in Attachment 6.

2. With a High Pressure Safety Injection Pump taking suction on the containment sump, discharge flow is routed.to the pressurizer via the charging header and the auxiliary spray line.

8. Review the safety function of valves 2-SI-662 and 663 to determine if they should be included in the IST Program.

These valves have no analyzed safety function. No plant operating or emergency procedures make use of this piping or these valves. Thus these valves are not required to be included in the IST Program.

F. Feedwater System

1. Although the valve operator is not directly connected to the valve obturator for 2-FW-5A and 5B, discuss the reasons for not exercising the obturator during cold shutdowns or refueling outages. What is the safety function of these valves in the open position?

These valves have no safety function in the open position.

Relief Request RR #16 proposes disassembly and stroke testing of one valve each refueling outage.

While the valve will normally close during shutdown from power operation, and valve closure can be visually determined, there is no practical method to meet the Code requirement to " prove that the disk travels to the seat promptly on cessat';, or reversal of flow." Deliberate, abrupt cessation or reversal of flow in the 18 inch diameter feed line is not considered prudent. Such action could result in system damage or undesirable transients in steam generator level.

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Northeast Nuclear Energy Company experience indicates

. that these valves are not subject to rapid wear. _The c only failure of these valves to operate as expected i occurred as a result of a valve modification which .

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in valve. movement. Examining one valve eaci, refueling outage is considered adequate to assure the operability of these valves. O

2. What is the safety function of valves 2-FW-12A and B in the closed position?

These valves have no safety function in the closed position. These valves are normally closed and are required to open to admit auxiliary feedwater flow to the steam generator.

3. Why is the stroke . time not measured during the quarterly testing of-valves 2-FW-43A, B, and 44?

Stroke time is measured during quarterly testing. The designator "Q" includes measurement of stroke time.

4. Describe any credit taken in the safety analysis for the emergency water supply from the fire water system to the auxiliary feedwater system.

No reference can be found in the safety analysis to the fire water system providing an emergency water supply to the auxiliary feedwater system. However, the Technical Specifications require the fire water system to be operable if the Condensate Storage tank contains less than 150,000 gallons of water.

5. Describe any credit taken in the safety analysis for the auxiliary feedwater supply to the spent fuel pool. I No credit is taken in the safety analysis for the auxiliary feedwater supply to the spent fuel pool.

G. Reactor Building Component Cooling Water System

1. Why are valves 2-RB-30.1A, B and 2-RB-37.2A and B categorized A and no leak rate test identified for these valves?

This was an editorial error. The valves are subject to leak rate testing in accordance with 10CFR50 Appendix J.

Attachment 11 corrects this error.

H. Chemical'and Volume' Control System

1. Why are both valves 2-CH-518 and 519 required to be open at all times .during power operation?

The requirement to keep both these valves open has been deleted from the Technical Specifications. These valves can be tested quarterly. Attachment 11 reflects this change.- Revised Relief Request RR #27 (IWV) has been included in' Attachment 10.

2. - ' Review the safety function'of valves 2-CH-118, 132, 191, and-431-(P&lD locations F-9, E-8, E-9, and J-13) to t determine if they should be included in the-IST program.

NOTE: The valve which appears to be 2-CH-132 on the P&ID provided is actually 2-CH-192.

Of these valves only 2-CH-431 has a safety function. In the alternate, post-LOCI. recirculation mode this valve may be required to open to allow High Pressure Safety Injection Pump discharge flow through the Auxiliary. Spray line. This valve has been added to the revised valve lists of Attachment 11 and to Relief Request RR #26.

Valve 2-CH-118 (VCT Outlet Check Valve) has no safety function.. The valve immediately upstream, 2-CH-501, automatically closes on a Safety Injection Actuation-Signal. Thus this valve provides no function.

Valves 2-CH-191 and 2-CH-192 (RWST to Charging Pump-Suction) (appears to be 2-CH-132 on the provided P&ID) are in the Refueling Water Storage Tank Supply.to the Chargin9 Pumps with valve 2-CH-504. While this flow path may be used for boration control during some modes of plant operation, there is no safety function related to these valves. Charging Pump suction is provided from the boric acid storage tanks during accident operations.

Valves 2-CH-118, 191, and 192 do not need to be included in the IST Program.

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I. Reactor Coolant System I

1. If valves 2-RC-402 and 404 are used for low-temperature overpressure protection of the reactor coolant system . !

during shutdowns, these valves must be categorized B/C l and be exercised during cold shutdowns and refueling outages. ;

Northeast Nuclear Energy Company requests the NRC staff reconsider this additional requirement which is above and beyond the-ASME' Code requirements.

Millstone Unit 2 Technical Specification 4.4.9.3.1 provides detailed requirements for verifying operability of the valves during periods when they are used for low temperature overpressurization protection. These requirements verify that the instrumentation will properly actuate the valves and that the valves have been proven reliable in accordance with Subsection IWV-3510 of the Code. These surveillance requirements have proven adequate to assure reliability of these valves.

In addition-to the Technical Specification mandated surveillance testing, these valves are normally operated during the process of cooling the pressurizer and depressurizing. This normal operation during the cooldown is adequate to assure the valves are operable.

Classifying these valves as B/C would provide no further assurance of operability.

2. Provide a more specific technical justification for not full-stroke exercising the reactor vessel and pressurizer vent valves during cold shutdowns.

Further review has indicated that these valves can be effectively exercised during cold shutdown. Relief Request RR #28 and the valve lists have been revised to reflect testing during cold shutdowns.

J. Containment Isolation System

1. Provide the P&ID that shows. valve 2-AC-51.

A complete set of current P&ID's for all safety related systems is attached.

2. Provide the request for relief for the valve in the containment isolation system that have a fail-safe test during cold shutdown (FTCS) as identified in the testing alternative column of the valve table.

Relief Request RR #36 is included as Attachment 9.

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3. What specific code requirement is relief requested from in containment isolation system Relief Request No. 4 and for which valves does this relief request apply? .

Information previously submitted as Relief Request No. 4 has been Request RRpreviously)

33 (IWV . clarified and resubmitted as Relief II. PUMP TESTING PROGRAM

1. How is the inlet pressure and pump flowrate measured for the service water pumps?

Inlet pressure is determined by measuring sea level and calculating the suction pressure based on pump drawings which show depth of submersion of the pump inlet.

Flowrate is measured by adding up the individual flowrates of components supplied by the system. If appropriate equipment can be obtained, header flow will be measured with a portable non-intrusive flowmeter.

2. The NRC staff agrees that pump vibration monitoring utilizing pump vibration velocity rather than pump vibration displace-ment can provide more useful information for evaluation of sump degradation, however the acceptance criteria in the Millstone Unit 2 IST Program is not acceptable to the staff because there is no absolute limiting values-in the acceptance criteria. The acceptance criteria as defincd in ASME OM6, Inservice Testing of Pumps, Draft 8 provides one acceptance criterion for vibration velocity testing which is acceptable to the staff.

Relief Request RR #5 (Attachment 7) has been revised to include absolute limits for vibration. The specified limits are consistent with the intent of ASME OM6, Draft 10 and recognize the body of operating experience already developed for specific pumps at Millstone Unit 2.

3. Table IWP-3100-1 requires the measurement of both pump Ffferential pressure and flowrate for each pump identified in the IST Program irrespective of fixed resistance or variable resistance flowpaths. How can the pump differential pressure and flowrate be measured for the auxiliary feedwater, safety injection, containment spray, charging, and boric acid pumps?

All the listed pumps except the Boric Acid Pumps have suction and discharge pressure instruments available that allow measurement of differential pressure. The Boric Acid Pumps have discharge pressure instrumentation but no suction pressure instrumentation. Suction pressure is calculated based on Boric Acid Storage Tank level and the relative elevations of the pump and tank.

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Charging Pump flow is available from the charging header flow H instrument. For the other listed pumps discharge flow is ' c(

l measured using a calibrated, portable, non-intrusive flowmeter. .

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4. Do the charging pumps have a variable speed coupling between the pump and the motor requiring measurement of pump shaft speed as required by IWP-44007 t, No.

'5. 'Is pump shaft rotational s)eed measured for the turbine driven auxiliary feedwater pump 51 aft speed as required by IWP-4400?

Yes.

6. How is inlet pressure measured for the Boric Acid Pumps?

Inlet pressure is' calculated based on Boric Acid Storage. Tank level and the relative elevations of the pump and tank.

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ATTACHMENTS

-ATTACHMENT'I -

REVIEW OF POTENTIAL CATEGORY A VALVES IN MILLSTONE UNIT 2 ATTACHMENT 2 - DELETED

- ATTACHMENT 3 - LIMITING STR0KE TIMES USED AT MILLSTONE UNIT 2 ATTACHMENT 4 - RELIEF REQUEST RR #34 (IWV) (NEW)

ATTACHMENT 5 - ' RELIEF REQUEST RR #35 (IWV) (NEW)

ATTACHMENT 6 - FLOW PATH FOR HOT LEG INJECTION FOR LONG TERM RECIRCULATION ATTACHMENT 7 - REVISEDRELIEFREQUESTRR#5(PUMPVIBRATION)

ATTACHMENT 8 - REVISED RELIEF REQUEST RR #36 (IWV) (NEW)

ATTACHMENT 9 - REVISED AND UPDATED PUMP LIST-ATTACHMENT 10 - REVISED RELIEF REQUESTS (IWV)

ATTACHMENT 11 - REVISED AND UPDATED VALVE LIST i

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,. ATTACHMENT 1 Page 1 of 4 REVIEW 0F POTENTIAL CATEGORY A VALVES IN MILLSTONE UNIT 2 ,

Drawing 2.5203-26015 - Piping and Instrument Diagram - Safety Injection Systems- 3 Sheets Boundary Valves Between CCA and CCB (Primary Rating 1500# at 1125 F-ASME Class 2) Piping 2-SI-114, 124, 134, 144 (Sheet 2) 2-SI-011, 012, 013, 014 (Sheet 2) 2-51-113, 123, 133, 143 (Sheet 2) 2-51-614, 624, 634, 644 (Sheet 3)

Boundary Valves Between CCB and DCB (Primary Rating 900# at 1125 F)

Piping 2-SI-656 (Sheet 2) 2-51-616, 626, 636, 646 (Sheet 2)

Boundary Valves Between CCB and GCB (Primary Rating 300# at 1125 F)

Piping 2-SI-615,625,635,645(Sheet 1) 2-51-215, 225, 235, 245 (Sheet 3)

Boundary Valves Between CCA and GCB Piping 2-SI-651 2-SI-618, 628, 638, 648 Analysis of leakage limit requirements:

No leakage limit requirements are necessary at the boundary between CCA and CCB piping, The Primary Ratings are identical. Thus the CCB piping is capable of withstanding full Reactor Coolant System pressure without distress.

No leakage limit requirements are necessary for the vahe.s at the CCB/DCB boundary, at the CCB/GCB boundary or at the CCA/GCG bounda ry. Review of the downstream piping (piping closer to the Reactor Coolant System) and valve configuration indicates there is no realistic possibility of exposing the lower pressure rated piping to pressures which could lead to system overpressurization.

The downstream piping is shown on Drawing 25203-26015 Sheet 3,

" Piping and Instrumentation Diagram - Safety Injection Tanks". The pressure source, the Reactor Coolant System,is downstream of 2-SI-217, 227, 237, 247 and upstream of 2-SI-652. The check valves are normally closed by Reactor Coolant System pressure. There are no normal operating events which cause these check valves to

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reposition. Only a safeguards system actuation with actual low Reactor Coolant System pressure could cause these valves to open.

Leakage through these valves would be contained between valves -

2-51-215, 225, 235, 245.and valves 2-SI-706A, B, C, D (Valves 2-SI-614, 624, 634, 644 are locked open during reactor operation).

Pressure in this piping is indicated on Panel C01 in the Control Room and monitored by a High Pressure Alarm in the Control Room set at 250 PSIG. Normal pressure in this section of piping is 225 PSIG, caused by the overpressure on.the Safety Injection Tanks.

Valves 2-SI-618, 628, 638, and 648 provide the means to reduce pressure in this piping if minor amounts of leakage through 2-SI-217, 227, 237, 247 do occur. - Normal operating controls limit the pressure in.this piping below the alarm setpoint.

Shutdown Cooling System Isolation Valve 2-SI-651 is locked closed and deenergized during reactor operation. Further it is equipped with an interlock which closes the valve if it is open when Reactor Coolant System Pressure exceeds 300 PSIG. In addition to this locked closed valve, a redundant isolation valve (2-SI-652) is also

-locked closed during reactor operation and equipped with an interlock which closes the valve if it is open when Reactor Coolant System Pressure exceeds 300 PSIG. In addition, a relief valve between the redundant isolation valves is set at 300 PSIG and capable _of relieving 54 gallons per minute. Thus there is no credible way the GCB piping in the Shutdown Cooling System suction can be exposed to pressures in excess of its design rating.

Since the pressure in the piping between the Reactor Coolant System and the DCB/GCB piping is limited to 300 PSIG there is no credible method of exceeding the pressure rating of the DCB or GCB piping.

Since valves 2-SI-217, 227, 237, and 247 do not operate, once seated by Reactor Coolant System Pressure, the valves will remain seated. In the incredible event of spontaneous leakage initiation through these valves the pressure alarms, pressure indication, and pressure reduction capability of the system preclude pressurization of the boundary valves to pressures exceeding the normal design ratings of the system.

Considering the incredible event of spontaneous leakage initiation through 2-51-217, 227, 237, 247 and operator failure to initiate corrective action required by procedures, the Safety Injection tanks are protected by relief valves set at 250 PSIG and capable of relieving 497 ctibic feet per minute. This capacity is capable of controlling tank pressure at credible inleakage rates. Other upstream piping is further isolated by series valves 2-SI-706A, B, C, D, and 2-51-009, 010, 011, 012, 2-SI-113, 123, 133, 143, and 51-114, 124, 134, 144 and further protected by relief valves.

Relief valves on the High Pressure Safety Injection System DCB piping are set at 1750 PSIG and are capable of relieving 41 gallons per minute. Relief valves on the Low Pressure Safety Injection System GCB piping are set at 500 PSIG and are capable of reli9ving 21 gallons per minute. These capacities are capable of controlling pipe system pressure at credible inleakage rates.

. . ATTACHMENT 1 Page 3 of 4 Piping downstream of 2-SI-618, 628, 638, and 648 is protected by

l. the same indication and alarm as discussed above. In addition, a relief valve set at 560 PSIG with a capacity of 103 GPM protects *

, s . this piping.

Further, the presence of the pressure indication and alarm is, in effect, a continuous leakage monitoring system between the high pressure source, the Reactor Coolant System, and the attached piping. While the leakage through valves 2-S1-217, 227, 237, 247 is 'not quantified, the presence of the pressure indication and alarm provides equivalent protection.to that which would be '

provided by periodic leak rate testing of these valves.

Conclusion Piping shown on this drawing is adequately protected by design, operating restrictions, redundant isolation valves, and relief

, valves. None of the valves on this drawing are " valves for which

- seat leakage is limited to a specific maximum amount in the closed position of fulfillment of their function". Thus except for those valves which are required to be tested in accordance with Appendix J of 10CFR50 these valves are properly listed as Category B or Category C valves.

Drawing 25203-26017 - Piping and Instrumentation Diagram -

Chemical and Volume Control System -

3 Sheets Boundary Valves Between CCA and CCB Piping 2-CH-517, 518, 519 2-CH-435 Boundary Between CCB and HCB (Primary Rating 150# at 500 F) Piping.

Charging Pumps Analysis of leakage limit requirements:

No leakage limit requirements are necessary at the boundary between CCA and CCB piping. The Primary Ratings are identical. Thus the CCB piping is capable of' withstanding full Reactor Coolant System pressure without distress.

The Charging Pump discharge check valves 2-CH-331, 334, 339 and the integral poppet valves in the charging pumps provide a three valve boundary between CCB and HCB piping. Routine monitoring of charging flow during normal charging pump operation and the per_ iodic measurement of charging pump flow provides adequate assurance that these valves are not leaking significantly. In addition relief valve 2-CH-331 set at 140 PSIG with a relief capacity of 11 gallons per minute provides additional protection from backleakage.

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ATTACHMENT 1 Page 4 of 4 Conclusion c Piping shown on this drawing is adequately protected by design, operating restrictions, redundant isolation valves, and relief

) valves. None of the valves on this drawing are " valves for which seat leakage is limited to a specific maximum amount in the closed position of fulfillment of their function". Thus except for those 0 valves which are required to be tested in accordance with Appendix-J of 10CFR50 these valves are properly listed as Category B or Category C valves.

6

\

4

ATTACHMENT 2 Page 1 of 1 ATTACHMENT 2 DELETED THIS PAGE LEFT BLANK INTENTIONALLY f'

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..- NTTACHMENT3 Page 1 of 3 LIMITING STR0KE TIME FOR POWER OPERATED VALVES LIMITING VALVE NO. FUNCTION TYPE STROKE TIME 2-MS-64A 'NO. 1 MSIV A0 6 SEC 2-MS-64B NO. 2 MSIV AD 6 SEC 2-MS-65A NO. l.MSIV BYPASS M0 30 SEC-2-MS-65B N0. 2 MSIV BYPASS M0 30 SEC 2-MS-190A NO. 1 SG ATMOS. DUMP A0 3 SEC 2-MS-1908 N0. 2 SG ATMOS. DUMP A0 3 SEC 2-MS-201 NO. 1 SUPPLY TO AUX FD M0 30 SEC 2-MS-202 NO. 2 SUPPLY TO AUX FD MO 30 SEC SW-4188 .STM. TO AUX FD TURBINE M0 20 SEC 2-MS-265B STM. DRAIN ISOLATION A0 15 SEC 2-MS-266B STM. DRAIN ISOLATION A0 15 SEC 2-CS-16.1A CTMT SUMP OUT ISOL M0 45 SEC ,,

2-CS-16.1B CTMT SUMP OUT ISOL M0 45 SEC

2-SI-615 LPSI HDR'INJ STOP MO 10 SEC 51-616 HPSI B TO LOOP 1A MO 10 SEC 2-SI-617 HPSI A TO LOOP 1A MO 10 SEC 2-SI-618 SI HDR DRAIN STOP A0 5 SEC 2-SI-625 LPSI HDR INJ STOP MO 10 SEC 2aSI-626 HPSI B TO LOOP 18 MO 10 SEC 2-SI-627 HPSI A TO LOOP IB MO 10 SEC 2-SI-628 SI HDR DRAIN'STOP A0 5 SEC 2-S1-635 LPSI HDR INJ STOP MO 10 SEC 2-SI-636 HPSI B TO LOOP n. MO 10 SEC 2-SI-637 HPSI A TO LOOP 2A MO 10 SEC 2-SI-638 SI HDR DRAIN STOP A0 5 SEC 2-SI-645 LPSI HDR INJ STOP MO 10 SEC 2-51-646 HPSI B TO LOOP 2B MO 10 SEC 2-SI-647 HPSI A TO LOOP 28 MO 10 SEC 2-51-648 SI HDR DRAIN STOP A0 5 SEC 2-51-652 SDC ISOLATION MO 90 SEC 2-SI-659 MIN FLOW ISOLATION A0 5 SEC 2-51-660 MIN FLOW ISOLATION A0 5 SEC 2-FW-5A FEEDWATER TO SG #1 A0 20'SEC 2-FW-5B FEEDk?TER TO SG #2 A0 20 SEC 2-FW-12A AUX FEED TO SG #1 A0 20 SEC 2-FW-12B AUX FEED TO SG #2 A0 20 SEC 2-FW-43A AUX FEED REG VALVE A0 30 SEC 2-FW-43B AUX FEED REG VALVE A0 30 SEC 2-FW-44 AUX FEED CROSS-TIE M0 10 SEC 2-RB-8.1A NON-VITAL LOAD ISOL AD 20 SEC 2-RB-8.1B NON-VITAL LOAD ISOL A0 20 SEC j

l

ATTACHMENT 3 Pags 2 of 3 !

l 4

LIMITING VALVE NO. FUNCTION TYPE STR0KE TIME 2-RB-13.'1A SD HT EXH OUTLET- .A0 20 SEC 2-RB-13.1B SD HT EXH OUTLET A0 20 SEC 2-RB-28.3A RBCCW FROM CAR COOLER A0 20 SEC-

?-RB-28.3B' RBCCW FROM CAR COOLER A0- 20 SEC-2-RB-28.3C RBCCW FROM CAR COOLER A0 20 SEC 1 2-RB-28.3D RBCCW FROM CAR COOLER A0 20 SEC 2-RB-30.1A RBCCW TO RCP ETC. MO 90'SEC '

2-RB-30.1B RBCCW TO RCP ETC. MO 90.SEC 2-RB-37.2A RBCCW FROM RCP ETC. M0 90 SEC 2-RB-37.28 RBCCW FROM RCP ETC. MO 90 SEC 2-RB-68.1A ENG SG ROOM COOLER A0 5 SEC i 2-RB-68.1B ENG SG ROOM COOLER A0 5 SEC 2-RB-210 DEGASSIFIER RETURN A0 20 SEC 2-SW-3.2A SERV WTR TO NON-VITAL A0 20 SEC 2-SW-3.2B SERV WTR TO NON-VITAL A0 20 SEC l 2-SW-B 1A RBCCW HX' TEMP CONTROL A0 60 SEC 2-SW-8.18 RBCCW HX TEMP CONTROL A0 60 SEC 2-SW-8.1C RBCCW HX TEMP CONTROL A0 60 SEC 2-SW-89A EMERG DIESEL TEMP CON A0 20 SEC 2-SW-89B EMERG DIESCL TEMP CON A0 -20 SEC 2-SW-102- SERV WTR TO CHILLER A0 20 SEC 2-SW-104 SERV WTR TO CHILLER A0 20 3EC 2-SW-231A ENERG DIESEL BYPASS A0 20 SEC 2-SW-231B EMERG blESEL BYPASS A0 20 SEC l CH-510 BA PUMP RECIRC AD 5 SEC 2-CH-511 BA PUMP RECIRC A0 5 SEC .

2-CH-512 VCT MAKEUP A0 5 SEC !

2-CH-515 CHG PUMP EMERG SUP A0 10 SEC 2-CH-517 ' AUX SPRAY CHARGING A0 10 SEC 2-CH-518 CHARGING HDR ISOL A0 5 SEC 2-CH-519 CHARGING HDR ISOL A0 5 SEC ,

2-CHW-3 CH WTR TO A/C UNIT A0 5 SEC 2-CHW-33 CH WTR TO A/C UNIT A0 5 SEC 2-CHW-11 HDR CROSS-TIE A0 5 SEC l 2-CHW-12 HDR CROSS-TIE , A0. 5 SEC 2-CHW-13 HDR CROSS-TIE A0 5 SEC l 2-CHW-14 HDR CR05S-TIE A0 5 SEC 2-CHW-4 TEMP CONTROL VALVE A0 15 SEC

.2-CHW-34 TEMP CONTROL VALVE A0 15 SEC 1:

2-RC-402 POWER OP RELIEF VLV SOL 2 SEC 2-RC-404 POWER OP RELIEF VLV SOL 2 SEC 2-RC-414 REACTOR VESSEL VENT SOL 2 SEC 2-RC-415 REACTOR VESSEL VENT SOL 2 SEC u_ _ --__

. ATTACHMENT 3 Page 3 of 3 LIMITING VALVE NO. FUNCTION TYPE STROKE TIME ,

2-kC-416 REACTOR VESSEL VENT SOL 2 SEC

, 2-RC-417 . REACTOR VESSEL VENT SOL 2 SEC-2-RC-422 PRESSURIZER VENT. SOL 2 SEC 2-RC-423 PRESSURIZER VENT SOL 2 SEC 2-RC-424- PRESSURIZER VENT. SOL 2 SEC 2-RC-425 ' PRESSURIZER VENT SOL 2 SEC

.2-AC-47 CTMT AIR SAMPLE A0 5 SEC

~2-EB-88 CTMT AIR SAMPLE A0 5 SEC

.2-EB-89 CTMT AIR SAMPLE A0 5 SEC' 2-EB-91 HYDR 0 GEN PURGE A0 5 SEC 2-EB-92 HYDROGEN PURGE A0 5 SEC 2-EB-99 HYDROGEN PURGE A0 5 SEC 2-EB-'100 HYDROGEN PURGE A0 5 SEC EB-651 SDC ISOLATION MO 90 SEC 2-SSP-16.1 CTMT SUMP DISCH A0 5 SEC 2-SSP-16.2 CTMT SUMP DISCH A0 5 SEC 2-AC-4 CTMT PURGE SUPPLY A0 5 SEC 2-AC-5 CTNT PURGE SUPPLY A0 5 SEC 2-AC CTMT PURGE SUPPLY. A0 5 SEC 2-AC-7 CTMT PURGE SUPPLY A0 5 SEC.

2-AC-12 CTMT AIR SAMPLE A0 5 SEC 1

, 2-AC-12 CTMT AIR SAMPLE A0 5 SEC 2-AC-15 CTMT AIR SAMPLE A0 5 SEC 2-AC-20 CTMT AIR SAMPLE A0 5 SEC 2-MS-220A. ST GEN BLOWDOWN ISOL A0 5 SEC 2-MS-220B ST GEN BLOWDOWN ISOL A0 5 SEC 2-GR-11.1 WASTE GAS HEADER'ISOL A0 5 SEC 2-GR-11.2 WASTE GAS HEADER ISOL A0 5 SEC 2-LRR-43.1 PRIMARY DR TANK DISCH A0 5 SEC 2-LRR-43.2 PRIMARY DR TANK DISCH A0 5 SEC '

2-LRR-61.1 QUENCH TANK SAMPLE A0 5 SEC 2-CH-506 RCP SEAL BLEED 0FF A0 5 SEC 2-CH-516 LETDOWN ISOLATION A0 5 SEC 2-CS-4.1A C1MT SPRAY MO 15 SEC 2-CS-4.1B CTMT SPRAY MO 15 SEC 2-51-312 NITROGEN TO SI TANKS A0 5 SEC l2-MS-191A STEAM GEN BLOWDOWN . A0- 5 SEC 2-MS-191B STEAM GEN BLOWDOWN A0 5 SEC 2-PMW-43 DEM WTR TO QUENCH TK A0 5 SEC 2-RC-001 RCS SAMPLE ISOL A0 5 SEC RC-002 RCS SAMPLE ISOL A0 5 SEC !

2-RC-003 RCS SAMPLE ISOL A0 5 SEC 2-RC-45 RCS SAMPLE ISOL A0 5 SEC 2-CH-089 LETDOWN ISOL A0 5 SEC 2-CH-198 RCP SEAL LEAK 0FF A0 5 SEC 2-CH-505 RCP SEAL LEAK 0FF A0 5 SEC

A

. ATTACHMENT 4 Page 1 of 1 MILLSTONE NUCLEAR POWER STATION UNIT NO. 2 SECOND TEN TEAR INTERVAL Relief from In-Service Testing Requirements

Relief Request: RR #34 Main Steam System Reverse Flow Check Valves 2-MS-1A 2-MS-1B Component Identification:

ASME Code Class: None IWV 2200 Valve Category: C Valve Function:

Prevent backflow in main steam lines from steam generator in the event of main steam line rupture.

Code Requirement:

Paragraph IWV-3412 requires that valves be exercised quarterly to the position required to fulfill their function.

Code Relief Requested:

Relief is requested from exercising the valve to the closed position, in accordance with Code requirements.

Basis for Relief:

Closing this valve would require a plant shutdown. Even with a plant shutdown there is no means to verify "that the disk travels to the seat promptly on cessation or reversal of flow." Valve operation can be verified by observation of the counterweight but no means exist to abruptly stop flow. Observation of normal valve operation during reduction of steam plant load provides adequate assurance that the valve is operable. .

Proposed Alternative Testing:

Verify during each cold shutdown that the valve travsls smoothly and completely to the closed position as steam plant load is reduced.

ATTACHMENT 5 Page 1 of 1 1

MILLSTONE NUCLEAR POWER STATION UNIT NO. 2 SECOND TEN YEAR INTERVAL

Relief from In-Service Testing Requirements

- Relief Request: RR #35 Safety Injection System Header Drain Valves 2-SI-618, 628, 638, 648 Component Identification:

ASME Code Class: 1 IWV 2200 Valve Category: B Valve Function:

Open to allow depressurization of the safety injection header in the event of leakage through valves 2-SI-217, 227, 237, or 247.

Code Requirement:

l Paragraph IWV-3415 requires that valves be tested by observing the operation of the valves upon loss of actuator power.

Code Relief Requested:

Relief is requested from testing the fail-safe operation of the i valve quarterly.

Ba_ sis for Relief:

The valves are in containment and thus inaccessible during reactor operation.

Proposed Alternative Testing:

The fail-safe operation of the valve will be tested during cold shutdowns.

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ATTACHMENT 7 ,

1 Page 1 of 2 MILLSTONE NUCLEAR POWER STATION UNIT NO. 2 SECOND TEN YEAR INTERVAL ,

Relief from In-Service Testing Requirements {

Relief Request: RR#5(Revised)

Pump Vibration Monitoring Inservice Test Pump Identification:

ASME Code Class 2 and 3 Category: IWP i Applicable Pumps:

List of applicable pumps as shown on Table IWP attached.

Pump Function:

Centrifugal and positive displacement pumps that are required to perform a specific function in shutting down the reactor or in mitigating the consequences of an accident.

Code Requirement:

Table IWP-3100-1 and IWP-3100-2, of the 1980 Edition, Winter 1981 Addenda requires that vibration amplitude be measured. Paragraph IWP-4510 requires that at least one displacement vibration amplitude (peak to peak composite) shall be read during the inservice test.

Code Relief Requested:

Relief is requested from measuring the overall vibration amplitude in mils (thousandths of an inch). l l

Basis for Relief:

Experience has shown that measurement of overall vibration amplitude in mils does not provide the desired early warning of pump degradation. Vibratior amplitude is adequate for measuring unbalance, misalignment, ano other low frequency failure modes. It does not give early warning of bearing degradation since the magnitude of higher frequency vibration created by such degradation is 10 to 1,000 times lower than the normal pump movements.

Experience has shown that raonitoring pump vibration velocity (in/sec) provides earlier warning of pump degradation. Collection and review of vibration " signatures" (plots of vibration velocity vs. frequency) over a range from slightly below runnin; frequency to several times running frequency provides optimal early warning of pump degradation.

n .,

4 s ATTACHMENT 7 Page 2 of 2 Proposerl Alternative Testing:

For centrifugal pumps at least two measurements will be taken in a plane perpendicular to the rotating shaft in two orthogonal tiirections and one measurement taken in the axial direction.

1 For . reciprocating pumps, similar measurements will be taken on a j bearing housing of the crankshaft.

On vertical line shaft pumps measurements will be taken on the uppe.r motor bearing housing in three orthogonal directions including one axial direction.

Vibration will be monitored using equipment which collects vibration signatures over a range from less than one-half running speed to at least eight times running speed.

Overall vibration velocity will be compared to the following acceptance criteria:

Acceptable Range - less than 2.5 times reference velocity Alert Range - 2.5 to 5 times reference velocit but not

. greater than 0.325 in/sec (RMS) y Required Action Range - greater than 5 times reference velocity but not greater than 0.7 in/sec (RMS)

Reference velocity shall be_ the average overall velocity determined during an inservice' test at reference conditions when the pump is known to be operating acceptably.

In addition to the above quantitative analysis of overall vibration-levels, vibration signatures will be reviewed at least quarterly to identify potential bearing degradation or other developing faults.

When potential f aults are identified, action as required for a pump in the Alert Range of vibration will be initiated.

i l

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. ATTACHMENT 8 i Page 1 of 2 !

I MILLSTONE NUCLEAR POWER STATION UNIT NO. 2 SECOND TEN YEAR INTERVAL

Relief from In-Service Testing Requirements ,

i Relief Request: RR #36 (IWV) i All power operated valves listed in the valve lists.

Component Identification:

ASME Code Class: 1,2,3 IWV 2200 Valve Category: A, B Valve Function:

As identified in valves lists.

Code Requirement:

Paragraph IWV-3417 "(a) If, for power operated valves, an increase in stroke time of 25% or more from the previous test for valves with full-stroke times greater than 10 sec or 50% or more for valves with full-stroke times less than or equal to 10 sec is observed, test frequency shall be increased to once each month until corrective action is taken, at which time the original test frequency shall be resumed. In any case, any abnormality or erratic action shall be reported.

Code Relief:

Relief is requested from comparing present stroke times to stroke times from the previous test.

Basis for Relief:

Use of the " previous test" stroke time does not adequately identify slow degradation of valve performance. For example, repeated increases in stro,ke time of 15 to 24 percent would not require that the valve be considered in " Alert", with attendant additional investigation and testing. The proposed alternative acceptance 4 criteria would identify such valves and require that they be j formally evaluated for acceptability or declared inoperable. In instances where the evaluation does not result in a determination of inoperability additional or increased frequency testing may be specified to aid in evaluating valve performance. This criteria ,

provides increased assurance that degrading valves are promptly identified and that such degradation is promptly evaluated for its impact on valve operability.

.. ATTACHMENT 8 Page 2 of 2 Proposed Alternative: '

~

' Test results.shall be compared to the reference values of stroke time for each valve.

~

a. Valves.with reference stroke times greater than 10 seconds shall exhibit no more than a 25% change in stroke time when compared to the reference value, j

b. Valves with reference stroke times less than 10 seconds shall exhibit no more than a 50% or 1 second (which ever is greater) change in stroke time when compared to the reference value.

c. Valves with reference stroke times of less than 2 seconds shall not exhibit a stroke time in excess of 2 seconds.

Valves with measured stroke times which do not meet the above acceptance criteria shall be immediately retested (or declared inoperable).

If retested and the second set of data also does not meet the acceptance criteria the data shall be analyzed within 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> to verify that the new stroke time represents acceptable valve operation, or the valve shall be declared inoperable. When the evaluation indicates the deviation is acceptable, operation of the valve'shall be tested monthly until it is repaired, declared inoperable or a new reference value established. If trended test results of a valve which previously did not meet the acceptance criteria indicate the valve will exceed the limiting value of stroke time prior to the next test or that valve operation is unreliable the valve shall be declared inoperable. The evaluation ;

shall be documented in the record of the tests.

If the second set of data meets the acceptance criteria, the cause of the initial deviation shall be analyzed and the results documented in the record of tests.

. 1 Valves for which measured stroke times exceed limiting values for stroke times shall be immediately declared inoperable.

Valves which are declared inoperable shall be readjusted, repaired, or replaced prior to returning the valve to service. A test demonstrating satisfactory valve performance shall be performed prior to returning the valves to service.

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ccc i1 n1 SSS SS ii iii cc iii l1 i1 WWW aa ggg rrr tt nn l l 58 P vvv rrr i1 xx b1 rx CCC CCC

. . . . . tt nn aaa ee ll ii rr M ii U eee uu uu BBB P. P. P. P. P. oo hhh pp _ hh oo RR P SSS AA TA RRR HHH LL CC CCC SS _. CC BB X0*RR,

' ATTACHMENT 10 1.-

1 Page 1 of-7 o

. MILLSTONE NUCLEAR POWER S'TATION UNIT NO. 2

~ 'b SECOND TEN YEAR INTERVAL Relief from In-Service Testing Requirements -

.l

~

Relief Reciuest: RR #28 (IWV) (Revised)

Reactor Coolant System Venting Solenoid Valves

,. 2-RC-414, 415, 416, 417, 422, 423, 424, and 425 Component Identification:

ASME Code Class: 1 IWV'2200 Valve Category: B Valve Function:

To. provide: venting of reactor' coolant system.

Code Requirement:

IWV-3000 requires that these valves be exer:ised (full open }

position) every' three months. l Code Relief Requested: j kelief is requested from performing the required exercise during plaht operations every three months.

Basis for Relief:-

These valves are designed for emergency use only; testing of these valves during operation could result in a loss-of-coolant accident.

Proposed Alternative Testing:

0 h Exercise full-stroke during cold shutdown.

H 1

i

4 1

ATTACHMENT 10

Page 2 of 7 MILLSTONE NUCLEAR POWER STATION UNIT NO. 2 y i

SECOND TEN YEAR INTERVAL 1

Relief from In-Service Testing Requirements ,

l l

Relief Request: RR #26 (IWV) (Revised) i Chemical and Volume Control Globe Valve 2-CH-517 3 2-CH-431 Component Identification:

ASME Code Class: l' IWV 2200 Valve Category: B Valve Function:

To provide flow to pressurizer vapor. space during depressurization.

Code Requirement:

IWV-3000 requires that this valve be. exercised (full-stroke) and the stroke time measured every three months.

Code Relief Request:

Relief is requested from performing the required exercise and stroke measurement during plant operations every three months.

Requested relief for valve:

Basis for Relief:

Valve exercise during reactor operation could cause loss of reactor l coolant system pressure control _with consequent plant shutdown and/or excessive thermal transients on the pressurizer spray piping.

Proposed Alternative Testing:

Exercise (full-stroke) and measure stroke time during cold shutdown. l

ATTACHMENT 10 Page 3 of 7 MILLSTONE NUCLEAR POWER STATION UNIT NO. 2 o SECOND TEN YEAR INTERVAL

Relief from In-Service Testing Requirements Relief Request: RR #5 (IWV) (Revised) l RELIEF REQUEST CANCELLED.

i

,g'

ATTACPMENT 10 Page ., of 7 MILLSTONE NUCLEAR POWER STATION UNIT NO. 2 l SECOND TEN-YEAR INTERVAL L -

i Relief-from In-Service Testing Requirements t

' Relief Request: RR #25 (IWV) (Revised)

Chemical and-. Volume Control Globe Valve-2-CH-515-2-CH-429

Component Identification:

ASME Code Class: 2 IWV.2200 Valve Category: B Valve Function:

To isolate reactor coolant system charging and letdown line.

Code Requirement:

IWV-3000_ requires that this valve' be ' exercised (full stroke) and the stroke time measured every three months.

Code Relie'f Requested:

' Relief.is requested from performing the required exercise and stroke time measurement during plant operation every three months.

Requested relief for valve:

Basis for Relief:

Operation of this valve during plant operation would cause undesirable thermal transients of approximately 400 on the regenerative heat exchanger. This component has a limited number of design thermal transients. Valve design precludes part stroke testing.

Proposed Alternative Testing: .

Exercise full stroke and measure stroke time during cold shutdown.

a

- .- _ _ _ - _ _ _ - _ _ _ _ _ _ - _ _ _ _ - _ - - _ - _ _ _ = _ _ _ _ _ _ _ _ _ _ _.

ATTACHMENT 10 Page 5 of 7 MILLSTONE NUCLEAR POWER STATION 'JNIT NO. 2 3 SECOND TEN-YEAR INTERVAL

Relief from In-Service Testing Requirements l

Relief Request: RR#33(IWV)(Revised)

All. Class 2, Category A and A Passive (AP) Containment Isolation Valves' for applicable valves, see attached list.

Component Identification:

ASME Code Class: 2 IWV 2200 Valve Categories: A and AP Valve Function:

To insure containment integrity in event of requirements to isolate.

Code Requirement:

IWV-3424 by measuring the feed rate required to maintain pressure between two valves or between two seats of a gate valve, provided the total apparent leak rate is charged to the valve or gate valve seat being tested, and that the conditions required by IWV-3423 are satisfied.

Code Relief Requested:

Relief is requested from the requirements of IWV-3424b, that requires valve seat leakage be determined by measuring the feed rate required to maintain pressure between two valves be credited to a single valve.

Relief is also requested to use an alternative test technique based on pressure decay rate between isolation valves when leakage exceeds the measurement limits of feed rate measuring devices.

Basis for Relief:

The proposed alternative testing and alternate test technique comply with the requirements of Appendix J in IOCFR50.

The proposed alternative test provides assurance that total containment leakage remains within limits yet allows trouble shooting to identify individual leaking valves without requiring quantification of leakage through a single valve.

.. 1 ATTACHMENT 10-Page 6 of 7 1

.1 MILLSTONE NUCLEAR POWER STATION UNIT NO. 2 SECOND TEN-YEAR INTERVAL ~

Relief from In-Service Testing Requirements-f.

Proposed Alternative Testing:

Leak' Test Category A valves singly or in groups. Where multiple j

~

valves on a single penetration are tested in a single test, the-leakage will be. attributed to the penetration not to an individual valve.

Analysis of-leakage' rate and establishment of maximum allowable leak rates will be based on total penetration leakage.

Where leakage rates exceed measurement limits of feed rate measuring devices, an alternative test based on pressure decay rate between isolation valves will be used.

9

1

. l

-.; ATTACHMENT 10 Page 7 of.7 l ,

LIST OF APPLICABLE VALVES

. L\

Class / Valve Class l Valve.

Category Number Category ;

Number k

2A 2-CH-198- 2A 2-AC-47 2-CH-505 2A 2-AC 2AP i 2-RW-154 2AP 2-EB-88 2A 2-RW-232 2AP 2-EB-89 2A.

2A 2-SSP-16.1 2A 2-EB-91 2A 2-SSP-16.2 2A 2-EB-92 4 2-AC-4 2AP 2-EB-99 2A' 2-AC-5 2AP 2-EB-100 2A 2-AC-6 2AP 2-SA-19 2AP 2-AC-7 2AP

.2-CH-506 2A 2A 2-AC-12 2A 2-CH-516 2-AC-15 2A 2-CS-4.1A 2A 2-AC-20 2A 2-CS-4.18 2A 2A 2-MS-220A 2A 2-SI-312 2-MS-220B 2A 2-S1-463 c'AP 2-GR-11.1 2A 2-51-709 2AP 2-GR-11.2 2A 2-MS-191A 2A 2-LRR-43.1 2A 2-MS-1918 2A 2-LRR-43.2 2A 2-PMW-43 2A 2-LLR-61.1 2A 2-RC-001 2A 2-RW-21 2AP 2-RC-001 2A 2-RW-63 2AP 2-RC-002 2A 2-AC-112 2AP 2-RC-003 2A 2-AC-114 2AP 2-RC-45 2A 2-AC-116 2AP 2-CH-089 2A 2-AC-117 2AP 2-AC-46 2AP 2-IA-27.1 2A 2-CH-429 2A

O e

e ATTACHMENT 11 IW TABLES LISTING THE APPLICABLE VALVES 2e84/611136

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1 LEGEN3 FOR VALVE TESTING i

I Q - Exercise valve full stroke (to the position required to fulfill its safety-related function) for' operability every three (3) months. If applicable, take stroke time measurements and compare to the stroke time limiting value per Section XI, Article IWV-3410 (see Note 1).

QP - Exercise valyx part stroke (in the direction required to fulfill its safety-related function) for operability every.three (3) months.

QCS - Exercise valve full stroke (to the position required to fulfill its safety-related function) for operability i during cold shutdowns. If applicable, take stroke time measurements and compare to the stroke time limiting value per Section XI, Article IWV-3410 (see Note 1).

QPCS - Exercise valve part stroke (in the direction to fulfill its safety-related function) for operability during cold shutdowns.

QR - Exercise valve full stroke (to the position required to fulfill its safety-related function) for operability during refueling. If applicable, take stroke time measurements and compare to the stroke time limiting value per Section XI. Article IWV-3410 (see Note 1).

QPR -

Exercise valve part stroke (in the direction required to fulfill its safety-related function) for operability during refueling.

4 l

PI - Visually observe, at least once every two years, actual -

l valve position to confirm that remote valve position j indications accurantely reflect valve operation. .

\

l FT - Remove actuator power from valves with f ail-safe j actuators to confirm that the valve travels to its )

)

fail-safe position every three (3) months. j l

l LT - Leak test valve per Section XI, Ari:icle IWV-3420. or applicable relief request.

LLRT - Leak test valve in conformance with the criteria specified in Appendix J of 10CFR50. )

SRV - Test safety and relief valves per Section XI, Article IWV-3510.

FTCS - Remove actuator power from valves with fail-safe actuators to confirm that the valve travels to its fail-safe position during cold shutdowns.

DET - Disassemble, Inspect, and Manually Stroke NOTE 1: NRC Guidance for Check Valve Testing "Since disk position is not always observable, fluid flow tests are acceptable and it is considered full stroking when the flow used is at least that which is identified l in the plant's safety analyses for the appropriate valve in question. Any less flow used will be considered as a partial stroke, unless it can be demonstrated that the lesser flow will still place the valve disk in the same position as the flow in the plant's safety analyses."

(Ref: Safety Evaluation Regarding Requests for Relief (

from Inservice Testing Requirements (Para. A3), NRC i

l I

. _ _ _ _ _

A06578, Responds to NRC 870527 Request for Addl Info Re Inservice Insp & Testing Program,Supplementing Util 850627 & 860729 Submittals

Text

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A06578, Responds to NRC 870527 Request for Addl Info Re Inservice Insp & Testing Program,Supplementing Util 850627 & 860729 Submittals

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