ML20211N719
| ML20211N719 | |
| Person / Time | |
|---|---|
| Site: | Point Beach  |
| Issue date: | 06/27/1986 |
| From: | WISCONSIN ELECTRIC POWER CO. |
| To: | |
| Shared Package | |
| ML20211N715 | List: |
| References | |
| PROC-860627-01, NUDOCS 8607030207 | |
| Download: ML20211N719 (139) | |
Text
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INSERVICE TESTING PROGRAM WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT UNITS 1 & 2 4
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06-27-86 TABLE OF CONTENTS Page Revision Date INTRODUCTION ii 5
04-18-86 1.0 INSERVICE TESTING OF PUMPS.
5 04-18-86 1.1 General Information I
1.2 Program Information I
1.3 Test Frequency..
2 1.4 Request for Relief...
2 2.0 INSERVICE TESTING OF VALVES.
5 04-18-86 2.1 General Information...
1 2.2 Program Information...
1 2.3 Valve position Indicator Verification 4
2.4 Piping and Instrumentation Drawings..
4 2.5 Request for Relief.
6 2.6 Fail Safe Testing of Valves.
6 2.7 Explanation of Abbreviations and Notes 6
3.0 INSERVICE TESTING OF PROGRAM - PUMPS 3.1 Unit 1.
6 06-27-86 3.2 Unit 2.....................
6 06-27-86 Appendix A - Relief Requests for Pumps.
6 06-27-86 4.0 INSERVICE TESTING OF PROGRAM - Valves 4.1 Unit 1.....................
6 06-27-86 4.2 Unit 2.....................
6 06-27-86 Appendix B - Relief Requests for Valves.
6 06-27-86 Appendix C - Fail Safe Testing of Valves.
5 04-18-86 NOTE:
REVISION NUMBERS INDICATED ALONGSIDE OF SECTIONS IN THE TAB REFER TO THE REVISION NUMBER OF THE INDIVIDUAL SECTION AND NO
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THE ENTIRE IST PLAN.
REVISIONS TO~THE IST PLAN WILL BE DONE BY INDIVIDUAL SECTIONS ONLY.
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s Revision 5 04-18-86 i
INTRODUCTION The Inservice Testing Programs for Point Beach Nuclear Plant, Units 1 and 2, were developed in compliance with the rules and regulations of 10 CFR 50.55a and Section XI of the ASME Boiler and Pressure Vessel Code, 1977 Edition through Summer 1979 Addenda. Where these rules were determined to be impractical, specific relief was written.
Section 1.0 discusses the Inservice Testing Program of applicable ASME Class 1, 2, and 3 pumps. Section 2.0 discusses the Inservice Testing Program of applicable A3ME Class 1, 2, and 3 valves.
Both of these programs were initially developed to the guidelines suggested in an NRC letter dated January, 1978. A subsequent resubmittal, Revision 1, was made based on the results of a November 1, 1983, meeting with the NRC. Roughly a year following the submittal of Revision 1, Revision 2 was issued. Revision 2 includes an additional punp :elief request (No. 9) and other various minor program changes.
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r Section 1.0 Revision 5 04-18-86 Page 1 1.0 INSERVICE TESTING OF PUMPS 1.1 General Information The Inservice Testing Program of applicable ASME Class 1, 2, and 3 pumps was developed in accordance with, and meets the requirements of ASME Boiler and Pressure Vessel Code,Section XI, Subsection IWP, 1977 Edition through Summer 1979 Addenda.
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This Inservice Testing Program will remain in effect throughout the second 10-year inservice inspection interval.
Section 3.0 lists all Class 1, 2, and 3 pumps which are to be tested, along with the applicable parameters to be measured.
Pumps that serve a common safety function (i.e., function to serve both units), are included in the Unit 1 inservice testing program j
list.
1.2 Program Information The following information is included in the Inservice Testing Program for pumps:
1.2.1 Pump Number lists the pump identification number as shown on the P&ID's.
1.2.2 Pump Name descriies the pump's functional identification as it is related to system operation.
1.2.3 Class is the ASME classification of the pump.
1.2.4 Test Parameters indicates the required test quantities measured per Table IWP-3100-1.
1.2.5 Relief Request references the relief request contained in Appendix A that applies to the particular pump.
Also included are generic relief requests that are not specifically referenced in this column of the table, but apply to the pump program in general.
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I Section 1.0 Page 2 i
1 1.3 Test Frequency I
An inservice test shall be run on each pump nominally every three months during plant operation. If this frequency can reasonably be accomplished during shutdown periods it will be, however, this is not endatery. Where a pump is not tested on a three month frequency durina plant shutdown, it will be tested within one week after the plant is rei.urned to normal operation.
1.4 Request for Relief Where ASME Section XI requirements were determined to be impractical, a request for relief was written. These requests were developed to the guidelines suggested in an NRC letter dated January 1978, and a November 1, 1983, meeting with the NRC.
Where relief from an ASME Code requirement is granted within the provisions of 10 CFR 50.55a(g)(6)(i), it will be incorporated into Point Beach Units 1 and 2 Inservice Testing Program.
Relief requests are shown in Appendix A.
1.5 Pump Notes 1.
Pump discharge pressure is measured and compared with inlet pressure to determine differential pressure.
2.
Pump inlet pressure is determined with level in refueling water storage tank.
3.
Full-flow test is conducted during refueling periods.
4.
Pump inlet pressure is determined with level in circulating water forebay.
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5.
This pump is operated more frequently than every quarter and will not be stopped for a special test (IWP-3400 b).
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section 2.0 Revision 5 04-18-86 Page 1 2.0 INSERVICE TESTING OF VALVES 2.1 General Information The Inservice Testing Program for applicable ASME Class 1, 2, and 3 valves was developed in accordance with, and meets the requirements of ASME Boiler and Pressure Vessel Code,Section XI, Subsection IWV, 1977 Edition through Summer 1979 Addenda.
The Inservice Testing Program for valves will remain in effect throughout the second 10-year inservice inspection interval.
The Inservice Testing Program lists all applicable ASME Class 1, 2, and 3 valves that have been assigned valve categories. Except for valves directly in the flow path (B passive), valves exempted per IWV-1200 are not listed. Valves that serve a common safety function (i.e., function to serve both units) are included in the Unit 1 Inservice Testing Program list.
The tables are organized by system in order of the assigned P&ID number and are listed in Section 2.4.
2.2 Program Information The following information is included in the Inservice Testing Program for valves:
2.2.1 Valve Number lists the valve identification number as shown on the P&ID's.
2.2.2 P&ID and Coordinates references the P&ID on which the valve appears and its coordinates.
2.2.3 Class is the ASME classification of the valve.
2.2.4 Valve Category indicates the category assigned to the valve based on the definitions of IWV-2200.
2.2.5 Valve Size lists the nominal pipt size of the valve in inches.
2.2.6 Valve Type lists the valve design.
2.2.7 Actuator Type lists the type of valve actuator.
2.2.8 i
Valve Position indicates the normal position of the valve l
during plant operation; either normally open (0) or normally shut (S).
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l Section 2.0 Page 2 2.2.9 Stroke Direction indicates the direction which an active valve must stroke to perform its safety fun,ction. Also, the direction in which the valve will be stroked to satisfy the exercising requirements of IWV-3410 or IWV-3520. This may be specified as open (0), shut (S), or both (0/S).
2.2.10 Test lists the test or tests that will be performed for each valve to fulfill the requirements of Subsection IWV.
Seat Leak Test AT v_ ve will be seat l'ak tested at the appropriate functional e
differential pressure.
Full Stroke Exercise Test BT Valve will be full stroke exercised for operability in the direction necessary to fulfill its safety function.
Check Valve Exercise Test CVT Check valve will be exercised to the position required to fulfill its function. This functional test will be verified by the operation of the required system. Thus,
" full stroke exercising" a check valve may be accomplished by either providing sufficient flow to fully open the disc, or provide the flow necessary to fulfill its associated safety function.
Check Valve Partial Exercise Test CVP Check valve will be part stroke exercised, (i.e., disc moves away from seat) when full stroke exercising is impractical.
Fail-Safe Test FST All valves with fail-safe actuators will be tested to verify proper fail-safe operation upon loss of actuator power.
Relief Valve Set Point Check RVT Relief and safety valve set points will be verified in accordance with IWV-3510.
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Section 2.0 Page 3 2.2.11 Test Mode indicates the frequency at-which the above mentioned tests will be performed. The following abbreviations are used:
Cold Shutdown CS Valve testing at cold shutdown is valve testing which commences not later than 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after cold shutdown and continues until required testing is completed or plant startup, whichever occurs first. Completion of all required i
i valve testing is not a requisite to plant startup. = Valve testing which is not completed during a cold shutdown will i
be performed during subsequent cold shutdowns to meet the
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code specified testing requirements. No valve need be tested more often than once every 90 days.
j NOTE:
IT IS EXPECTED THAT THE REQUIRED VALVE TESTING WILL NORMALLY BE COMPLETED IN 96 HOURS FOLLOWING COLD SHUTDOWN.
l Specific Cold Shutdown E-CS i
Valve tests with this designation will be conducted at cold i
shutdown conditions that also require " Event V" reactor coolant system primary isolation valve testing.
" Event V" valve testing requirements may be found in plant Technical 3
Specification 15.3.16.
Normal Operation OP Valve tests with this designation will be performed once every three months.
Reactor Refueling 4
RR Valve tests with this designation will be conducted at reactor refueling outages only.
Specific Reactor Refueling
- RR Valve tests with this designation will be conducted at a reactor refueling once every 10-year inservice inspection interval.
Any reactor refueling within this pertod will suffice as long as overall plant conditions, associated with the specific refueling outage, will allow the performance of the required testing (i.e., core off-load if necessary, l
etc.).
l 2.2.12 Max Stroke Time lists the maximum allowed full stroke time in seconds for valves requiring test.
2.2.13 Relief Request references the relief request contained in Appendix B that applies to the particular valve, i
2.2.14 Remarks lists clarification remarks.
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s Section 2.0 Page 4
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2.3 Valve Positien Indicator Verification valves with remote position indicators will be observed at least once every two years to verify that remote valve indications accurately reflects valve operation.
2.4 Piping & Instrumentation Drawings The following P&ID's contain valves which are part of the Inservice Testing program:
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Section 2.0 Page 5 t
TITLE UNIT 1 UNIT 2 Safety Injection System 110E017 110E035 Sheets 1,2,3 Sheets 1,2,3 I
Auxiliary Coolant System 110E018 110E029 Sheets 1,2,4 Sheets 1,2 110E018 j
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Reactor Coolant System 541F091 541F445 Sheets 1&2 Sheets 1&2 Sampling System 541F092 541F448 Chemical & Volume Control 684J741 685J175 Waste Disposal System 684J971 684J971 Section 2 Section 2 Main and Reheat Steam M-201 M-2201 Sheet 1 Sheet 1 Service Water M-207 M-207 Sheets 1,2,3,4 Sheets 1,2,3,4 Service Air M-209 M-209 Instrument Air M-209 M-209 Sheet 5 Sheet 5 Auxiliary Steam, Heating Steam, Chilled & Hot Water 1
M-214 M-2214 Heating & Ventilation M-215 M-2215 Auxiliary Feedwater System M-217 M-217 Containment Venting System M-224
.M-224 Emergency Diesel Generator M-209 Air Start System Sheet 10 Deionized and Reactor Makeup Water PBM-231 PBM-231 l
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Section 2.0 Page 6
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2.5 Request for Relief Where ASME Section XI requirements were determined to be impractical, a request for relief was written. These requests were developed to the guidelines suggested in an NRC letter dated January, 1978 (see Appendix B) and a subsequent meeting on November 1, 1983, with the NRC.
2.6 Fail Safe Testing of Valves ASME Section XI, Article IWV 3415 requires that " Valves with fail safe actuators shall be tested by doserving the operation of the valves upon loss of actuator power.
. Appendix "C" is a listing of all the valves that require fail safe testing and the methods to be used to test the valves.
2.7 Explanation of Abbreviations and Notes I
2.7.1 Abbreviations See attached charts.
2.7.2 Notes a.
Valves 1.
This valve is checked for locked shut or locked i
open position.
I 2.
This valve is a pressure relief valve and will be tested at the frequency stated in IWV-3511.
3.
This valve is a passive valve and does not require testing.
4.
Exercising this valve during operation could result in overpressurization of a low pressure system if upstream pressure isolation check valves should leak through. There are no pressure monitors installed on the high pressure side of the subject valve to determine status of upstream pressure isolation valves.
4a. Exercising this valve during operation is not possible because the reactor coolant system pressure is higher than the safety injection pump discharge pressure (1500 psig) and the accumulator pressure i
(700 psig).
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Section 2.0 Page 7 l
5.
Exercising this valve during operation is not advisable as the valve alignment required to facilitate valve stroking would prevent boric acid from reaching the safety injection pump suctions.
6.
All motor operated valves fail-as-is and therefore do not require a fail safe test per IWV-3415.
7.
This valve is exercised during normal operation and therefore does not require a separate test.
8.
This valve is tested when the containment spray system is tested per Technical Specification.
9.
i This valve is "A" passive and will only receive a seat leakage test.
10.
The seat leakage test for this valve will be performed in accordance with 10 CFR 50, Appendix J requirements.
11.
This valve is within a nonsafety-related system, I
however, it is used for containment isolation and therefore, will receive a set leakage test in accordance with 10 CFR 50, Appendix J requirements.
12.
The valve alignment required to facilitate valve testing during power operation would isolate sodium hydroxide from the spray system.
12a. Full stroke exercising this valve during operation is not possible because the residual heat removal pump discharge pressure cannot overcome reactor coolant system pressure and the recirculation line is not capable of passing the required flow.
13.
Exercising this valve during operation would cause s
a loss of cooling water to the reactor coolant pump, which could result in damage to the pump.
i 14.
It is the NRC's position that the PORV's be exercised at cold shutdown.
15.
The PORV block valve will normally be stroke exercised during operation.
If a PORV is isolated l
per the Technical Specifications, the block valve will then be exercised at cold shutdown, not
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operation.
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1 Section 2.0 Page 8 1
16.
Exercising this valve during power cperation produces transients in the charging and letdown system. These transients affect seal injection flow to the reactor coolant pumps and could result in pump seal damage.
17.
Exercising this valve during power operation will cause isolation of main steam flow resulting in a turbine-reactor trip.
18.
Erarcising this valve results in securing service water to the turbine hall. The major components relying on service water cooling in the turbine hall includes the main turbine, main generator, steam generator feedwater pumps and condensate j
pumps. Thus, exercising this valve during
. operation could result in significant damage to secondary plant equipment.
19.
Exercising this valve during operation would result in thermal shocking the auxiliary feedline to main feedline nozzle.
20.
During operation, full stroke exercising of these i
valves would require injection of relatively cold auxiliary feedwater to the steam generators since l
the recirculation line cannot pass the required flow. This would result in thermal shocking the auxiliary feedline to main feedline nozzle.
21.
Exercising this valve during power operation will cause an interruption of feedwater flow which would result in a reactor trip.
- 22. These valves are not accessible during power operation due to their location within the reactor containment building.
J 23.
During normal operation, the subject valve is shut and the system / subsystem containing the valve is out of service. Thus, stroke testing the subject valve on a quarterly basis is not required during this period, per IWV-3416. Prior to returning the system to an operable status, the valve will be exercised and the code required schedule will be resumed.
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I 24.
This valve must be locked shut and may not be opened unless the reactor is in a cold shutdown or refueling shutdown condition, per the plant's Technical specifications. As long es the subject valve is maintained locked shut, the system is considered to be out of service. Thus, quarterly stroke testing of the subject valve, during any plant condition in which it is locked shut, is not required per IWV-3416. Prior to returning the system to an operable status, the valve will be exercised, and the code required schedule will be resumed.
25.
These valves serve no safety-related function.
They are presented in this program as a result of a commitment made to the NRC in a letter from Mr. C. W. Fay to Mr. H. R. Denton, dated 02-29-84.
Since they serve no safety-related function, no testing is required. However, these valves will be stroke tested during reactor refueling outages to assure their operability.
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACli NUCLEAR PLANT Sy: tem Explanation of Abbreviations P&ID m
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$j Remarks CliECK VALVE CVT EXERCISE TEST PARTIAL CliLLA VALVL CVP EXERCISE TEST sAFLTx vu utLitr RVT VALVE TEST FST FAIL SAFE TEST CS COLD SliUTDOWN COLD SHUTDOWN REQUIRING E-CS EVENT V VALVE TESTING RR REACTOR REFUELING AT REAC'IOR REFUELING ONCE
4 Revision 6 06-27-86 INSERVICE TESTING PROGRAM - PUMPS UNIT 1 i
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 PUMPS Revision 6 WISCONSIN ELECTRIC POWER COMPANY 06-27-86 POINT BEACH NUCLEAR PLANT Page 1
UNIT 1 TEST PARAMETERS Pump P&lD and Lube Inlet Diff Flow Brg Number Pump Name Coordinates Level Speed Press Press Rate Vib Temp Relief Request 110E018 RR-1, 2, 4, 9, 10 P10A Residual Heat Removal D-8 Yes NA Yes Yes No Yes Yes Notes-1, 3
110E01B RR-1, 2, 4, 9, 10 l
P10B Residual Heat Removal C-8 Yes NA Yes Yes No Yes Yes Notes-1, 3
110E017 RR-1, 2, 6, 9, 10 l
P14A Containment Spray I-7 Yes NA Yes Yes No Yes Yes Notes-1, 2
110E017 l
RR-1,2,6.9, 10 P14B Containment Spray C-7 Yes NA Yes Yes No Yes Yes Notes-1, 2
110E017 RR-1, 2, 3, 9, 10 l
PISA Safety Injection I-8 Yes NA Yes Yes No Yes Yes Notes-1, 2,
3 110EOl7 l
RR-1, 2, 3, 9, 10 PlSB Safety Injection H-8 Yes NA Yes Yes No Yes Yes Note.*- 1, 2,
3 M-217 RR-1, 2, 5, 9, 10 l
P29 Auxiliary Feed (Turbine)
B-4 Yes Yes Yes Yes No Yes Yes Note-1 M-207 RR-1, 2,
7, 8, 9, 10 l
P32A,
Service W ter D-1 No NA Yes Yes No Yes No Notes-1, 4,
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P32B Service Water D-1 No NA Yes Yes No Yes No Notes-1, 4,
5 M-207 RR-1, 2, 7, 8, 9, 10 l
P32C Service Water D-1 No NA Yes Yes No Yes No Notes-1, 4,
5 M-207 RR-1, 2, 7, 8, 9, 10 l
P32D Service Water F-1 No NA Yes Yes No Yes No Notes-1, 4,
5 M-207 RR-1, 2,
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P32E Service Water F-1 No NA Yes Yes No Yes No Notes-1, 4,
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Revision 6 06-27-86 APPENDIX A REQUEST FOR RELIEF FOR PUMPS l
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PUMP RELIEF REQUEST NO. 1 System:
Safety Related, Unit 1 Component:
All pumps in the program Class:
2 and 3 Function:
To provide flow to safety systems Test Requirement:
Comply with the requirements of Section XI of the ASME Boiler and Pressure Vessel Code, Division 1, 1977 Edition and Addenda through Summer,1978, per the requirements of 10 CFR 50.55a.
Basis For Relief:
To achieve identical inspection basis for both PBNF units for the Section XI pump and valve inservice testing program.
Alternate Testing:
Comply with the requirements of Section XI of the ASME Boiler and Pressure Vessel Code, Division 1, 1977 Edition and Addenda through Summer, 1979.
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PUMP RELIEF REQUEST NO. 2 i
System:
Safety Related, Units 1 and 2 Component:
All pumps in the program Class:
2 and 3 Function:
To provide flow to safety systems Test Requirement:
To test the pump nominally each month (IWP-3400a)
Basis For Relief:
Industry data indicates that monthly testing of pump operating parameters is not necessary to assure the reliability of a safety grade pump.
In fact, the acceptability of assessing a pump's operational readiness through a testing program based on a three-month interval is evidenced by the recommended program contained in the 1980 edition of Section XI of the ASME Boiler and Pressure Vessel Code.
Alternate Testing:
Test the pump nominally every three months during normal plant operation.
m
4 PUMP RELIEF REQUEST NO. 3
(
System:
Safety Injection, Units 1 and 2 Component:
P15-ASS Class:
2 Function:
To provide high pressure injection flow for cold leg and core deluge safety injection modes.
Test Requirement:
The resistance of the system shall be varied until either i
the measured differential pressure or the measured flowrate equals the corresponding reference value.
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1 except bearing temperatures, which shall be measured during at least one inservice test each year.
Basis For Relief:
The inservice testing is accomplished by operating the pumps in a recirculation mode through a flow-restricting orifice.
The flow-restricting orifice ensures a fixed-resistance, fixed-flow condition near the horizontal portion of the pump curve which is associated with shutoff head, therefore, flow measuring instrumentation is not indicative of pump performance and consequently does not provide meaningful information in this portion of the pump curve.
4 Alternate Testing:
During each inservice test, establish the recirculation mode system resistance via the fixed flow-restricting orifice.
Measure or observe all required parameters, except flow, and analyze these values per IWP-3200. During reactor refueling outages, when design system flow testing can be achieved, vary the system resistance to obtain flow and developed pump head data at three points along the pump curve and analyze these values per IWP-3200 with respect to the applicable reference values.
J i
a PUMP RELIEF REQUEST NO. 4 i
System:
Safety Injection, Jnits 1 and 2 Component:
P10-A&B class:
2 Function:
To provide low pressure injection flow for cold leg and core deluge safety injection modes.
Test Requirement:
the resistance of the system shall be varied until either the measured differential pressure or the measured flowrate equals the corresponding reference value.
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1 except bearing temperatures, which shall be measured during at least one inservice test each year.
Basis For Relief:
The inservice testing is accomplished by operating the pumps in a recirculation mode through a flow-restricting orifice.
The flow-restricting orifice ensures a fixed-resistance, j
fixed-flow condition near the horizontal portion of the pump curve which is associated with shutoff head, therefore, flow measuring instrumentation is not indicative of pump performance and consequently does not provide meaningful information in this portion of the pump curve.
Alternate Testing:
During each inservice test, establish the recirculation mode system resistance via the fixed flow restricting orifice.
Measure or observe all required parameters, except flow, and analyze these values per IWP-3200. During reactor refueling outages, when design system flow testing can be achieved, vary the system resistance to obtain flow and developed pump head data at three points along the pump curve and analyze these values per IWP-3200 with respect to the applicable reference values.
i l
L
- * * ' ^ ~ ~ " ^ ~ " ' ' " " " ' -
i
~
i PUMP RELIEF REQUEST NO. 5 i
System:
Auxiliary Feedwater, Units 1 and 2 4
Component:
P29, P38-A6a class:
3 i
Function:
To provide auxiliary feedwater flow to the steam generators i
for heat removal.
Test i
Requirement:
The resistance of the system shall be varied until either the measured differential pressure or the measured flowrate equals the corresponding reference value.
t Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1 except l
bearing temperatures, which shall be measured during at 1
least one inservice test each year.
Basis For i
Relief:
The inservice testing is accomplished by operating the pumps in a recirculation mode through a flow-restricting orifice.
The flow-restricting orifice ensures a. fixed-resistance, fixed-flow condition near the horizontal portion of the pump curve which is associated with shutoff head, therefore, flow measuring instrumentation is not indicative of pump performance and consequently does not provide meaningful information in this portion of the pump curve.
i Alternate Testing:
During each inservice test, establish the recirculation mode j
system resistance via the fixed flow restricting orifice.
i Measure or observe all required parameters, except flow, and analyze these values per IWP-3200. During cold shutdown conditions, when design system flow testing can be achieved without thermal shocking the auxiliary feedwater line to l
feedline nozzles, obtain flow and developed pump head data with system operation at or near design conditions. Analyze this data per IWP-3200 with respect to the applicable reference values.
]
i i
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/
e PUMP RELIEF REQUEST NO. 6 System:
Containment Spray, Units 1 and 2 Cp ponent:
P14-A&B Class:
2 Function:
To provide containment atmospheric heat removal and, if needed, iodine removal.
Test Requirement:
The resistance of the system shall be varied until either the measured differential pressure or the measured flowrate equals the corresponding reference value.
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1 except bearing temperatures, which shall be measured during at least one inservice tect cach year.
Basis For Relief:
The inservice testing is accomplished by operating the pumps in a recirculation mode through a ficw-restricting orifice.
The flow-restricting orifice ensures a fixed-resistance, fixed-flow condition near the horizontal portion of the pump curve which is associated with shutoff head, therefore, flow measuring instrumentation is not indicative of pump performance and consequently does not provide meaningful information in this portion of the pump curve.
Alternate Testing:
During each inservice test, establish the recirculation mode system resistance via the fixed flow restricting orifice.
Measure of observe all required parameters, except flow, and analyze these values per IWP-3200.
e
- - - - - - -~~ ~
~ ~ - - ~ ~ '
4 PUMP RELIEF REQUEST NO. 7 i
System:
Service Water, Units 1 and 2 Component:
P32-A, B, C, D, E, F Class:
3 Function:
To provide vital cooling water to safety-related equipment.
Test Requirement:
To vary system resistance until a reference flowrate is achieved then measure flowrae and AP.
Basis For Relief:
Normal plant operation requires a minimum of two pumps to be in operation on a fixed resistance system. With the system resistance the same for each test of paired pumps, a measured AP is indicative of pump performance.
Alternate Testing:
Operate a given pair of pumps on a fixed resistance system, measure AP and compare the measured AP to a reference value t
for the same flow condition. Perform periodic maintenance inspections (such that each pair of pumps is inspected once during every 10 year ISI interval) on paired pumps to determine if mechanical and/or hydraulic degradation is occurring.
PUMP RELIEF REQUEST NO. 8 i
System:
Service Water, Units 1 and 2 Component:
32-A, B, C, D, E, & F Class:
3 Function:
To provide vital cooling water to safety-related equipment.
Test Requirement:
Measure bearing temperature and lubricant level.
Basis For Relief:
These pumps are vertical water lubricated sump pumps located in the circulating water forebay. The pump bearings are submerged in the forebay and are inaccessible for temperature measurements. Lubricant level is also inaccessible and will not be observed.
Alternate Testing:
None i
i
--' ~ ~ ~ ~ ~ ~ ~
~ ~ ~ ~ ~
~~~
PUMP RELIEF REQUEST NO. 9 l
I System:
Safety Related, Units 1 and 2 Component:
All pumps in the program.
Class:
2 and 3 Function:
To provide flow to safety systems.
Test Requirement:
Articles IWP-3000 and IWP-4000 require that pump vibration monitoring be performed using displacement vibration amplitude (peak-to-peak composite) techniques.
Basis For Relief:
Vibration severity is a function of displacement and frequency. Since vibration velocity is also a function of displacement and frequency, it can be concluded that a measure of vibration velocity is a direct measure of vibration severity. This has been found, through experience, to be true for frequencies between 600 cycles per minute and 60,000 cycles per minute. All of the safety-related pumps at the Point Beach Nuclear Plant fall within this range.
I Alternate Testing:
During each inservice test, at least one broadband vibration velocity (in/sec. pk) measurement will be obtained. The allowable ranges of the inservice vibration velocity test data are shown on the following table.
1 1
i PUMP RELIEF REQUEST NO. 10 System:
All safety related pumps.
Component:
Flow and pressure instrumentation.
Class:
2 and 3 Function:
Provides a measure of pump performance.
Test Requirement:
According to Article IWP-4110, pressure and flow instrument accuracy shall be within the following limits.
Parameter Accuracy Pressure 12% of full scale Differential Pressure 12% of full scale Flow Rate 12% of full scale In addition, according to Article IWP-4120, the full scale range of each instrument shall be three times the reference value.
Basis For Relief:
The intent of Articles IWP-4110 and 4120 is to ensure that the recorded test parameters are accurate within certain bounds.
With an instrument accuracy of 12% of full scale and a range of less than three times the reference value, the maximum error in a parameter, measured at the reference value, would be 16%.
Any combination of instrument range and accuracy that will bound the error on a measured parameter by 16% would be equivalent to the range and accuracy requirements of Articles IWP-4120 and 4110 respectively.
Using existing control board and local indication for pump test parameter measurements, the largest error in any measured parameter would be 19.0%.
This assumes an overall instrument loop accuracy (includes accuracy of transmitters, intervening devices, and meters) of 13% of full scale and a maximum instrument range of three times the reference value.
For the purposes of pump operability determinations, 1
measurements with a maximum error of 19% should be adequate to identify degrading pump conditions.
t k
l
l I
PUMP RELIEF REQUEST NO. 10 (Cont.)
i Alternate Testing:
Pressure and flow instrumentation for pump and valve testing i
shall meet the following accuracy requirements:
Parameter Accuracy Pressure 13% of full scale Differential Pressure i3% of full scale Flow 13% of full scale The accuracies stated are overall instrument system accuracies including pressure transmitters, intervening devices, and meters.
The range on pressure and flow instruments shall be less than or equal to three times the reference values.
/
ALLOWABLE VIBRATION RANGES Reference Vibration Acceptable Alert Required Action Amplitude Range Range Range (in/see-peak)
_(in/sec-peak)
(in/sec-peak)
(in/sec-peak)
V 50.1 R
0 to 0.2 0.2 to 0.3
>0.3 0.1<V 50.3 0 to 2 V 2V to 3 V
- 3 Y R
R R
R R
0.3<V 50.6 0 to VR + 0.3 V
R R + 0.3 to VR + 0.6 WR + 0.6 VR >0.6 0 to 1.5 VR 1.5 V, to 2.0 V
>2.0 V R
R VR = Reference Vibration Amplitude (Unfiltered Velocity)
V
= Measured Vibration Amplitude (Unfiltered Velocity) 4 E
k f
s
9 s
Revision 6 06-27-86 INSERVICE TESTING PROGRAM - VALVES UNIT 1
~
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES Revision 6 WISCONSIN ELECTRIC POWER COMPANY 06-27-86 POINT BEACH NUCLEAR PLANT Page 1 UNIT 1 Sy tem SAFETY INJECTION SYSTEM lP&ID 110E017 Sheet 1 e
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC PCWER COMPANY POINT BEACH NUCLEAR PLANT Page 2 UNIT 1
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INSERVIC..ESTING PROGRAM 4
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ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY 1
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_____.....___.._._______.__m._.
e INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC PONER COMPANY POINT BEACH NUCLEAR PLANT Page 7
UNIT 1 Syctem SAFETY INJECTION SYSTEM lP&ID 110E017 Sheet 2 J
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n INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 10 UNIT 2
System AUXILIARY COOLANT SYSTEM PLID 110EO.'
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACII NUCLEAR PLANT Page 11 UNIT 2
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 12 UNIT 2
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 14 UNIT 2 4
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 15 UNIT 2
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 16 UNIT 2
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WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 18 UNIT 2
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 19 UNIT 2
System MAIN AND REHEAT STEAM P&ID M-22Ol-1 E
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.s INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 20 UNIT 2
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 21 UNIT 2
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l INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 22 UNIT 2
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INSERVICE TESTING PROGRAM j
ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 23 UNIT 2
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INSERVICE TESTING PROGRAM 3
ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 27 UNIT 2
System HEATING AND VENTILATION P&ID M-2215 a
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INSERVICE TESTING PROGRAM l
ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 28 UNIT 2
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INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY POINT BEACH NUCLEAR PLANT Page 29 UNIT 2
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e INSERVICE TESTING PROGRAM ASME CLASS 1, 2 & 3 VALVES WISCONSIN ELECTRIC POWER COMPANY FOINT BEACli NUCLEAR PLANT Page 30 UNIT 2
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Revision 6 06-27-86 APPENDIX B REQUEST FOR RELIEF FOR VALVES i
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VALVE RELIEF REQUEST NO. 0
(
System:
General, Units 1 and 2 Component:
Rapid acting power operated valves with a stroke time of three seconds or less.
category:
As applicable.
Class:
As applicable.
)
Function:
Safety related.
i i
Test Requirement:
Section XI - Division 1 IWV-3413 Power Operated Valves The stroke time of all power-operated valves shall be measured to the nearest second or 10% of the maximum allowable stroke time, whichever is lest, whenever such a valve is full-stroke tested.
If an increase in stroke time of 25% or more from the previous test for valves with stroke times greater than 10 seconds or 50% or more for valves with stroke times less than or equal to 10 seconds 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.
Basis For Relief:
Measuring the stroke time for rapid acting valves, per the requirements, is not practical as highly sophisticated measurement devices and valve modifications would become necessary. In addition, slight deviations in stroke times that would be encountered under normal conditions would result in exceeding code allowables due to the very restrictive band within this time range.
Alternate Testing:
Stroke time of rapid acting valves shall be measured to the nearest one-half second.
If an increase in stroke time of-1.5 seconds greater than the previous test is experienced, then the test frequency shall be increased to once each month until corrective action is taken.
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VALVE RELIEF REQUEST NO. 1 i
System:
General Component:
Unit 1, Safety-Related Valves Category:
As applicable.
Class:
As applicable.
Function:
Safety related.
Test Requirement:
Comply with the requirements of Section XI of the ASMF.
Boiler and Pressure Vessel Code, Divisir.n 1, 1977 Edition and Addenda through Summer,1978. per the requirements of 10 CFR 50.55a.
Basis For Relief:
To achieve identical irspectioa bases for each unit, for the Section XI pump and valve inservice testing program.
Alternate Testing:
Comply with the requirements of Section XI of the ASME Boiler and Pressure Vessel Code, Division 1, 1977 Edition and Addenda through Summer, 1979.
i l
l
VALVE RELIEF REQUEST NO. 2 i
System:
Safety Injection, Units 1 and 2 Component:
845-A, B, C, D, E, F Category:
A/C 9
class:
1 Function:
Valves open with differential pressure to provide flow path from safety injection pumps to the reactor coolant system and reactor vessel. Normally shut. In the shut position, these valves serve as reactor coolant system pressure isolation valves.
Test Requirements:
Exercise the valves every three months and perform a seat leakage test every two years.
Basis For Relief:
During normal operation, the safety injection pump discharge pressure of 1500 psig is insufficient to overcome reactor coolant system pressure. If the pumps could overcome reactor coolant system pressure, a reactivity excursion and thermal transient would take place during the injection of highly borated cold water. Testing during cold shutdown is prohibited because the pumps are deactivated for overpressurization protection. Lack of a recirculation path prohibits partial stroking.
Alternate Testing:
These valves will be full stroke exercised at refueling.
Seat leakage testing will be in accordance with the requirements of Technical Specification 15.3.16, " Reactor Coolant System Pressure Isolation Valve Leakage Tests."
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B
VALVE RELIEF REQUEST NO. 3 System:
Safety Injection, Units 1 and 2 Component:
853-A, B, C, & D Category:
A/C Class:
1 Function:
Valves open with differential pressure to-provide flow path for reactor vessel safety injection flow. Normally shut.
In the closed position, these valves serve as reactor coolant system pressure isolation valves.
Test Requirements:
Exercise the valve every three months and perform a seat leakage test every two years.
Basis For Relief:
Full or partial stroking during normal operation is not i
possible because low head safety injection pump discharge pressure is insufficient to overcome reactor coolant system pressure. Even if the pump discharge pressure,as high enough, any stroking could cause the injection of cold i
borated water into the system, resulting in a power and thermal transient.
Stroke testing the subject valves during cold shutdowns is possible, however, not desirable unless " Event V" valve a
testing is also scheduled. The " Event V" testing assures valve integrity, thus minimizing the possibility of an inter-system LOCA which bypasses containment. Exercising these valves during every cold shutdown may reduce the assurance that the valve is, in fact, properly seated, as established via the " Event V" testing.
Alternate Testing:
These valves will be full stroke exercised during pump full flow test at refueling. These valves will be full stroke i
exercised at cold shutdowns which also require the performance of " Event V" valve testing. Seat leakage testing will be in accordance with the requirements of Technical Specification 15.3.16, " Reactor Coolant System Pressure Isolation Valve Leakage Tests."
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VALVE RELIEF REQUEST NO. 4 System:
Safety injection, Units 1 and 2.
Component:
867-A Category:
A/C Class:
1 Function:
Valve opens with differential pressure to provide flow path for safety injection system to Loop "A" of the reactor coolant system. Normally shut.
In the shut position, this valve serves as a reactor coolant system pressure isolation valve.
Test Requirements:
Exercise the valve every three months and perform a seat leakage test every two years.
Basis For Relief:
During normal operation, safety injection pump discharge pressure of 1500 psig is sufficient to overcome reactor coolant system pressure so full or partial stroke testing is not possible.
During cold shutdowns, partial or full stroke testing via the use of the accumulators or safety injection pumps is not allowed to prevent any. possibility of a low temperature overpressurization event.
A full stroke test could be possible during refueling, when the reactor vessel head is removed, but the volume and flow rate required for the test could possibly damage core internals.
There would also be the possibility of forcing a nitrogen bubble through the reactor coolant system and refueling cavity resulting in possible safety implications which makes this testing concept inadvisable.
Alternate Testing:
This valve will be partial stroke tested during the transition period from hot shutdown to cold shutdown. Thisc l
will bs considered a cold shutdown test. However, this testing will not be performed if it will result in disturbing an " Event V" valve which is not required to be tested within the associated cold shutdown. In addition, this valve will be disassembled and inspected once per 10-year ISI interval. Seat leakage testing will be in accordance with the requirements of Technical Specification 15.3.16, " Reactor Coolant System Pressure Isolation Valve Leakage Tests."
/
VALVE RELIEF REQUEST NO. 5 1
1 i
System:
Safety Injection, Units 1 and 2 Component:
840-A & 840-B Category:
C class:
2 Function:
Valves open under differential pressure to protect the spray additive tank from excessive vacuum conditions and allow injection of spray additive.
Test Requirement:
Exercise the valves every three months per IWV-3522.
Basis For Relief:
Due to the nature of the spray additive fluid and system arrangement, in-place testing of these valves is not desirable. To maximize system availability, since testing 1
requires valve removal, testing will not be performed at operation or cold shutdowns.
Alternate Testino:
These valves will be exercised during reactor refueling outages.
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,y.
VALVE RELIEF REQUEST NO. 6
(
System:
Safety Injection, Units 1 and 2 Component:
854-A & B Category:
C Class:
2 Function:
Valves open with differential pressure to provide flow path from refueling water storage tank to low head safety injection pumps (RHR) during safety injection. Normally shut.
)
Test Requirement:
Exercise the valves every three months.
Basis For Relief:
Valve stroking is not possible during normal operation because the RHR pump discharge pressure is insufficient to overcome reactor coolant system pressure during normal operation. During cold shutdown condition, full stroke testing the valves is not possible because the reactor coolant system does not contain a sufficient expansion volume and that there is no return flow path back to the refueling water storage tank for recirculation.
Alternate
. Testing:
These valves will be full stroke exercised during the pump full flow test at refueling.
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VALVE RELIEF REQUEST NO. 7 I
System:
Safety Injection, Units 1 and 2 i
Component:
889-A & B Category:
C Class:
2 Function:
Valves open with differential pressure to provide flow path from the safety injection pumps to the reactor coolant system. Normally shut.
Test Requirement:
Exercise the valves every three months.
Basis For Relief:
Dur'8.ng operation, the safety injection pump discharge pressure (1500 psig) is insufficient to overcorse reactor coolant system pressure. The recirculation line size is also insufficient to allow full stroke exercising during operation.
During cold shutdowns, testing is prohibited because the safety injection pumps are deactivated for low temperature overpressurization protection reasons. Thus, a full stroke i
test is not possible.
Alternate Testing:
These valves will be full stroke tested during the pump full flow test at refueling shutdowns. These valves are also partially stroke exercised during operation.
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VALVE RELIEF RE0' JEST NO. 8
(
System:
Safety Injection, Units 1 and 2 Component:
858-A & B Category:
C Class:
2 Function:
Valves open with differential pressure to provide flow path from refueling water storage tank to the spray pump suction. Normally shut.
Test Requirement:
Exercise these valves every three months.
Basis For Relief:
These check valves can only be full stroke tested during a full-flow test of the spray pumps. A full-flow test of the spray pump would require actual spraying of borated water through the spray nozzles in containment.
Alternate Testing:
This valve will be partial stroke exercised during the containment spray system test required in the Technical Specification.
During reactor refueling shutdowns, this valve will be disassembled and visually inspected.
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VALVE RELIEF REQUEST NO. 9 System:
Safety Injection, Units 1 and 2 Component:
862-A & B l
Category:
A/C
{
l Class:
2 Function:
Valves open with differential pressure to provide flow path from the spray pumps to the contairment spray nozzles.
Normally shut. In the closed position, this valve serves as a containment isolation valve.
Test Requirement:
Exercise the valves every three months.
Basis For Relief:
These check valves can only be full stroke tested during a full-flow test of the spray pumps. A full-flow test of the spray pumps would require actually spraying borated water through the spray nozzles in containment. Partial stroke testing of these valves could also result in spraying containment, thus, will not be performed.
4 Alternate Testino:
These valves will be disassembled and visually inspected at reactor refueling outages.
Seat leakage testing of these valves will be performed in accordance with 10 CFR 50, Appendix J.
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h VALVE RELIEF REQUEST NO. 10 SZ, stem:
Auxiliary Coolant, Units 1 and 2 Component:
755-A & B e
Category:
A/C Class:
2 Function:
Valves shut with differential pressure to isolate the component cooling line in the event of containment isolation. Normally open.
Test Requirement:
Exercise the valves every three months and perform a seat leakage test every two years.
_B_ asis For Relief:
To properly stroke test the valve requires the securing of component cooling water flow to the reactor coolant pump.
This is not practical during normal operation because it could require the possible securing of a reactor coolant pump. Only method to verify full closure is to perform leak test on the valve.
Alternate resting:
These valves will be full stroke exercised at refueling.
Seat leakage testing will be performed in accordance with 10 CFR 50, Appendix J during reactor refuelings.
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e VALVE RELIEF REQUEST NO. 11 System:
Reactor Coolant, Units 1 and 2 Component:
528 Category:
A/C Class:
2 Function:
Valve shuts with differential pressure to isolate the nitrogen line to isolate the containment. Normally closed.
Test Requirement:
Exercise the valve every three months and perform a seat leakage test every two years.
Basis For Relief:
Valva is normally shut. The only method to verify closure is by leak test.
Alternste Testing:
This valve will be full stroke exercised at refueling.
Seat leakage testing will be performed in accordance with 10 CFR 50, Appendix J during reactor refueling outages.
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i VALVE RELIEF REQUEST NO. 12 i
System:
Chemical & Volume Control, Units 1 and 2 l
Component:
304-C & D Cateocry:
A/C Diass:
2 Function:
Valves shut with differential pressure to isolate the seal water injection line in the event of a containment isolation. Normally open.
Test Requirement:
Exercise the valves every three months and perform a seat leakage test every two years.
Basis For Relief:
Valve is normally open. The only way to verify the valve shuts is to secure reactor coolant pump seal flow and perform valve leak test. Shutting of this valve could cause reactor coolant pump damage.
Alternate Testino:
These valv.es will be verified shut via the performance of a seat leakage test at reactor refueling outages.
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i VALVE RELIEF REQUEST No. 13 i
System:
Chemical & Volume control, Units 1 & 2 Component:
370 Category:
A/C Class:
2 Function:
Valve shuts with differential pressure to isolate the charging line in the event of a containment isolation.
i Normally closed.
Test Requirement:
Exercise the valves every three months and perform a seat leakage test every two years.
Basis For Relief:
Valve is normally open. The only way to verify the valve shuts is to secure normal charging flow and perform valve leak test.
Shutting of this valve will cause a transient to reactor coolant pump seal injection flow with possible pump damage resulting.
Alternate Testing:
This valve will be verified shut via the performance of a seat leakage test at reactor refueling outages.
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1
VALVE RELIEF REQUEST NO. 14
- This request intentionally left ble.nk -
VALVE RELIEF REQUEST No. 15 System: Auxiliary Coolant System, Units 1 and 2 Component:
767 Category:
A/C class:
2 Function:
Valve shuts with differential pressure to isolate the component cooling line to effect containment isolation.
Test Requirement:
Exercise the valve every three months and perform a seat leakage test every two years.
Basis For Relief:
The only method to verify the valve shuts is by a seat leakage test, which is not performed during reactor operation for ALARA purposes.
Alternate Testing:
This valve is leak tested per 10 CFR 50, Appendix J during refueling outages.
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VALVE RELIEF REQUEST NO. 16 System:
Heating & Ventilation, Units 1 and 2 Component:
3200-AA Category:
A/C class:
2 Function:
This valve shuts with differential pressure, in the containment gas and particulate radiation monitor return line, to effect containment isolation.
Test Requirement:
Exercise the valve every three months and perform a seat leakage test every two years.
Basis For Relief:
During normal operation, gases from a continuous sampling system return to the containment through this line/ valve.
To test this valve during operation, or cold shutdown, it would be necessary to discharge potentially radioactive gases to the environment. There is no mechanism to partially stroke this valve.
Alternate Testing:
This valve will be verified shut using seat leakage testing at reactor refueling outages.
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VALVE RELIEF REQUEST NO. 17 1
l System:
Emergency Diesel Ger.erator Air Starting System, Units 1 and 2 Components:
CV-3057-A, CV-3057-B, CV-3058-A & CV-3058-B Category:
B Class:
3 Function:
This valve opens to provide starting air to the diesel generator.
Test Requirement:
Measure stroke time and analyze per IWV-3413.
Basis For Relief:
This is a rapid acting valve. Valve design prohibits visual observance of stroking.
Failure of the valve to stroke would result in the failure of the diesel generator to start on the initial attempt.
Since the diesel generators are tested biweekly, the subject valve is tested monthly.
Alternate Testing:
Valve stroke testing is performed monthly, in conjunction with the diesel generator start testing. Valve stroking parameters will be considered acceptable if the associated diesel generator start was acceptable. If the diesel generator failed to start, at no fault of the valve, the valve stroking parameters will be considered acceptable, which will be proven with a restart following diesel generator corrective action.
VALVE RELIEF REQUEST NO. 18 l
System:
Reactor Coolant, Units 1 and 2 Component:
529 Category:
A/C Class:
2 Function:
The valve shuts with differential pressure to isolate the reactor makeup water supply line to the pressurizer relief tank to effect containment igolation.
Test Requirement:
Exercise the valve every three months and perform a seat leakage test every two vears.
Basis For Relief:
The valve is hormally shut. The only method to verify the valve is shut is by a seat leakage test.
Alternate Testing:
This valve will be full stroke exercised-at reactor refueling outages. Seat leakage testing will be performed in accordance with 10 CFR 50, Appendix J.
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VALVE RELIEF REQUEST NO. 19 i
System:
Safety Injection, Units 1 and 2 Component:
842-A & 'd Category:
A/C Class:
1 i
Function:
Valves open with differential pressure to provide flow path 1
from accumulators to reactor coolant system during loss-of-coolant accident with plant depressurization.
I Normally closed.
In the shut position, these valves serve as reactor coolant system pressure isolation valves.
Test Requirements:
Exercise the valves every three months and perform a seat.
leakage test every two years.
Basis For Relief:
During normal operation, accumulator pressure.of 700 p.sig cannot overcome reactor coolant system pressure so full or l
partial stroke testing is not possible. Partial stroke testing during operation via use of the test line is also not possible as it would result in violating minimum accumulator levels as setforth in the plant Technical Specifications. A full or partial' stroke test is not practical during cold shutdown because the higher pressure accumulators would be connected'to,the solid primary system which could res..lt in a low temperature overpressurization event. A full stroke test could be possible during refuelings, when the reactor vessel head is removed, but the volume and flow rate required for the test could possibly damage core internals. There would also be the possibility of forcing a nitrogen bubble through the reactor coolant system and refueling cavity resulting in possible safety implications which makes this testing concept inadvisable.
Alternate Testino:
These valves will be partial stroke tested during the i
transition period from hot shutdown to cold shutdcwn. This will be considered a cold shutdown test. However, this testing will not be performed if it will result in disturbing an " Event V" valve which is not required to be i
tested within the associated cold shutdown. In addition, these valves will be disassembled and visually inspected once per 10-year ISI interval. Seat leakage testing will be performed 'uarterly_ coincident with the SI pump tests and q
a seat leakage rate of 5 gpm or less will be considered 1
acceptable.
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_ _ - _ _.. -. -..,. -. ~ _ _ _.
VALVE RELIEF REQUEST NO. 20 System:
Service Water, Units 1 and 2 Component:
ISV-2090 and 2SV-2090 Category:
B Class:
3 Function:
Valve opens upon an auxiliary feedwater pump start to provide cooling water to the turbine driver's bearings.
Test Requirement:
Measure the stroke time and analyze per IWV-3413.
Basis For Relief:
This is a rapid acting valve. The valve design prohibits visual observance of stroking.
Failure of the valve to stroke would result in unusually high turbine bearing temperatures during testing.
Alternate Testing:
This valve will be stroke tested during associated auxiliary feedwater pump testing. Acceptable valve operation will be based on acceptable bearing temperatures during testing.
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o VALVE RELIEF REQUEST NO. 21 i
System:
Main Feedwater, Units 1 & 2 Component:
466A, 466B, 476A, 476B Category:
C Class:
2 Function:
The main feedwater line to each steam generator has two normally open, in-line, series check valves. The function of the check valves is to close upon reversal of flow to ensure that auxiliary feedwater flow is unimpaired to at 1
least one of the two steam generators while main feedwater is not available. The series check valves also prevent l
^
simultaneous blowdown of both steam generators in the event i
of a main feed pipeline failure.
Test
/
Requirements:
1.
IWV-3521 - Check valves shall be exercised at least once every three months, except as provided in IWV-3522.
l 2.
IWV-3522(a) - Valves that are normally open during plant operation and whose function is to prevent reversed flow I
shall be tested in a manner that proves that the disc j
travels to the seat promptly on cessation or reversal of flow.
Basis For Relief:
As shown in Figure VRR-21-1, the main feed line to each steam generator consists of two series check valves. There
-j are no position indicators on these check valves, nor are there any pressure taps between the check valves.
It is, therefore, not feasible with the existing plant design to verify individual valve closure by valve position indication or the differential pressure across an individual check valve. Closure of at least one of the two series check j
valves could be verified by measuring the AP across, or the l
leakage past both series check valves.
j Prompt seating of each valve on cessation or reversal of flow cannot be verified at the instant of closure since no direct indication of valve position is available.
Valve testing can only be conducted at unit shutdowns since main feedwater must be secured to the steam generators to conduct the test.
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s VALVE RELIEF REQUEST NO. 21 (Cont.)
i Alternate Testing:
A valve exercise test of the main feedwater check valves will be conducted once each refueling outage. At least one
'j of the series valves will be verified closed after flow is secured by measuring the differential pressure across, or the leakage past, the series combination of check valves.
I Additionally, once every 10 years, the main feedwater check valves will be opened and inspected. The inspections will be distributed so that at least one valve is inspected every r
two to three years, and all vslves are inspected within a 10 year interval.
Since the split body construction of the second-off check f
valves 466A and 476A limits access to the valve internals, only those portions of the valve internals accessible from a side access port will be inspected. Complete disassembly of j
these valves is not practical since it would require that large pipe support structures would have to be cut and piping be moved.
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The construction of the first-off check valves 466B and 476B j
permits access to valve internals for inspection with no i
known limitations.
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Revision 5 04-18-86 APPENDIX "C" FAIL SAFE TESTING OF VALVES ASME Section XI, Article IWV 3415, states the following for valves having fail safe actuators:
" Valves with fail safe actuators shall be tested by observing the operation of the valves upon loss of actuator power."
This type of test demonstrates that a valve will go to its required position to fulfill its safety function upon loss of actuator power.
The following describes the requirements for fail safe tests for the different types of actuators.
Actuator Type Fail Safe Test Motor Valve will fail as is.
No test is required.
Solenoid Valve fails to its safe position upon loss of power to the solenoid.
Air Valve fails to its safe position upon loss of control air to the actuator and/or loss of control power to its associated solenoid valve.
A fail safe test can only be performed on solenoid operated and air operated valves. Upon loss of power, a motor operated valve is incapable of moving and fails as is.
Fail safe testing of motor operated valves will not be performed at PBNP.
A fail safe test of solenoid operated valves will be conducted by deenergizing the solenoid and observing that the valve moves to its fail safe position. Deenergization of the solenoid will be performed by operating the valve control switch to the position that corresponds to the fail safe position (i.e., open or shut).
A fail safe test of air operated valves will be conducted by deenergizing the solenoid control valve, which will in turn vent air from the valve actuator and result in the valve moving to its fail safe position. Operation of the A0V control switch to the position corresponding to the fail safe position (i.e.,
open or shut) will deenergize the solenoid operated valve and vent air from the A0V's actuator.
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o Appendix "C" Page 2 In some cases, a controller, I/P (electric / pneumatic) converter, and a positioner is used to control air to the actuator of an A0V.
For these cases, one of the following methods will be used to perform a fail safe test of the A0V.
1.
Secure power to the I/P converter which in turn will secure air to the AOV actuator.
2.
With the controller in manual, adjust the valve to its fail safe position.
Operation of a controller in this manner sends a minimum control signal to the I/P converter and causes the I/P converter to cut off air to the valve actuator. This is similar to securing control power to the I/P converter, except a small control signal is still present.
Table C-1 provides a listing of the valves which will be fail safe test'ed and the method in which they will be tested.
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o Attachment "C" Page 3 TABLE C-1 FAIL SAFE TEST AIR OPERATED VALVES Control Controller Controller Unit valve Switch Off Minimum Remarks SA-9
/
SA-10 J
LW-61
/
LW-62
/
1&2 313A J
1&2 371
/
1&2 371A J
1&2 508
/
1&2 538 J
1&2 539
/
1&2 836A J
1&2 836B
/
1&2 846
/
1&2 897A J
1&2 897B J
g 1&2 951
/
1&2 953 J
1&2 955 4
1&2 966A
/
1&2 966B
/
1&2 966C
/
1&2 1003A J
1&2 1003B
/
1&2 1721
/
1&2 1786
/
1&2 1787 4
1&2 2017
/
Solenoid control valves must be energized to vent air from the valve actuator. On loss of control power, solenoid control air valves fail as is.
1&2 2018
/
Same as 2017.
1&2 2083 J
1&2 2084
/
2838 4
l 2839
/
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0 Attachment C" Page 4 TABLE C-1 (continued)
FAIL SAFE TEST AIR OPERATED VALVES Control Controller Controller Unit Valve Switch Off Minimum Remarks 1&2 3047 J
1&2 3048 4
4012 J
4019
/
1&2 5958 J
1&2 5959 4
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Notes:
1.
Control Switch - indicates the fail safe test is conducted by placing the valve's control switch to the position corresponding to the fail safe
- position, i.e.,
open or shut.
2.
Controller Off - indicates the fail safe test is conducted by turning the cor. troller off.
3.
Controller Minimum - indicates that the fail safe test is conducted by placing the controller in manual and positioning the valve to its fail safe position.
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