Text

Rev 1 to WNP-2 IST Program Plan (Pumps & Valves) 2nd Interval (941213-041212).
	ML17292A616
Person / Time
Site:	Columbia
Issue date:	11/19/1996
From:	Rana R; WASHINGTON PUBLIC POWER SUPPLY SYSTEM
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ML17292A615	List: ML17292A613; ML17292A616;
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	PROC-961119, NUDOCS 9612030247
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j 96~'doaozyy 9 ppDR AoocK'aooos9V 'DR INSERVICB TESTING PROGRAM PLAN SECOND TBN-YEAR INSPECTION INTERVAL WASHINGTON PUBLIC POWER SUPPLY SYSTEM NUCLEAR PLAN'I'O. 2 USNRC DOCKET NO. 50-397 FACILITYOPERATING LICENSE NO. NPF-21 COMMERCIAL OPERATION DATE: DECEMBER 13, 1984

Washington Public Power Supply System Nuclear Plant No. 2 INSERVICE TESTING PROGRAM PLAN Second Ten-Year Interval (13 DEC 1994 through 12 DEC 2004)

Revision 1 Prepared by R IST Program Engineer Date Reviewed by /I Jl'5/9 g Reviewing gin eer Date Concurrence ger, Engin grams Concurrence C

)~g ager, System Engineering Dae Concurrence Supervisor, Quality Servi s Date Concurrence Authorized Nuclear Inservice Inspector Approved by Ge ral ger, ineering Date

N 1.0 Table of Contents 2.0 Introduction ~ ~ ~ 1 2.1 Program Administration ~ ~ ~ 2 2.2 Program Database.... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3 2.3 References ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4 3.0 Pump Inservice Testing Program 5 3 .1 Introductxon 5 3.2 0 ~ ~

Program Implementation

~

3.2.1 Preservice Testing

~ ~ ~

~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 0 ~ ~ ~ ~

~ ~ ~ 6

~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 6 3.2.2 Inservice Testing 6 3.2.3 Reference Values 3.2.4 Instrumentation Accuracy

................... ... ~..........

~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~

6 6

3.2.5 Test Parameters.................... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 7 3.2.6 Allowable Ranges For Test Parameters...... 7 3.2.7 Testing Methods 7 3.2.8 Test Procedure ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 8 3.2.9 Trending 8 3.3 Pump Reference List 9 3.4 Pump Inservice Test Table.......... ~....... . 11 3.5 Technical Positions . 13 3.6 Relief Requests From Certain OM Part 6 Requirements 14 3.7 3.8 Proposed Pump Test Flow Paths Records and Reports of Pumps

............... . 35

. 48 Valve Inservice Testing Program ..... 52 4.1 Introduction.................... ..... 52 4.2 Program Implementation............ ..... 53 4.2.1 Preservice Testing ..... 53 4.2.2 Inservice Testing

............ ..... 53 4.2.3 Reference Values ..... 53 4.2.4 Fail-Safe Valves............. ..... 53 4.2.5 Valve Seat Leakage Rate Test ..... 54 4.2.6 Test Procedure 4.2.7 Trending

..... 54 54

.... 54

~ ~ ~ ~ ~

4.2.8 Safety Valve and'Relief Valve Tests 4.3 4.4 Valve Test Tables ................

Inservice Testing Program Notes.......

..... 55 111 4.5 Technical Positions 115 4.6 Cold Shutdown Justifications 124 4.7 Refueling Outage Justifications ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 141 4.8 Relief Requests from Certain OM Part 1 and Part 10 Requirements 156 4.9 Records and Reports of Valves ........ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 0

~ 167 5.0 Quality Assurance Program...... ~............ ~............. 170 6.0 Piping and Instrument Diagrams............... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 171 111

IST Program Plan 2nd 10- Year Interval WNP-2 Page 1 Revision of 171 1

2.0 Introduction ii This Inservice Testing (IST) Program Plan is applicable to the WPPSS'Nuclear Project No. 2, hereinafter referred to as WNP-2. A single unit Boiling Water Reactor (BWR),

the power plant is located 11 miles north of Richland, Washington, on the Hanford Reservation. The plant employs a General Electric (GE) supplied nuclear steam designated as BWR/5.

supply'ystem The reactor, is contained within an over-under drywell/wetwell cohtainment vessel designated Mark II. The plant rated electrical output is 1,230 MWe. I This program plan is referenced in the WNP-2 FSAR, Section3.9.6, and has been prepared as the controlling document governing Pump and Valve Inservice Testing at WNP-2. This IST Program Plan complies with the requirements of 10 CFR Part 50.55a(b)(2) and Part 50.55a(f). The 1989 edition of Section XI was incorporated by reference into paragraph 50.55a(b) by rulemaking on September 8, 1992. 'The 1989 edition specifies that the rules for the IST of pumps and valves are stated in the ASME/ANSI Operations and Maintenance (OM) Standards, Part 6, "Inservice Testing of Pumps in Light-Water Reactor Power Plants," and Part 10, "Inservice Testing of Valves in Light-Water Reactor Power Plants." Revision date for ASME/ANSI Part 6, and ASME/ANSI Part 10 shall be the OMa-1988 Addenda to the OM-1987 Edition. The scope of this plan encompasses the testing of safety-related ASME Section III Nuclear Class 1, 2 and 3 pumps and valves, as defined by ASME/ANSI Part 6 and Part 10. This program plan also complies with the recommendations of Generic Letter 89-04. Where conformance with certain Code acquirements is impractical, relief requests are included in each section with supporting information and proposed alternatives. This is consistent with FSAR commitments and with federal requirements for component testing as stated in 10 CFR Part 50.55a(f).

This Program Plan is comprised of two subprograms the Pump Inservice Testing Program and the Valve Inservice Testing Program. The detailed description of the scope, implementation, and administration of these two programs is detailed in subsequent sections (3.0 and 4.0).

IST Program Plan 2nd 10- Year Interval WNP-2 Page 2 of 171 Revision 1 2.1 Pro m Admini tration Responsibilities for development, maintenance, and implementation of the IST Program Plan are detailed in Supply System procedures.

Changes to the IST Program Plan that do not require a relief request for impractical Code requirements will be accomplished consistent with Generic Letter 89-04 and will be submitted to the Authorized Nuclear Inservice Inspector for concurrence prior to incorporation into the Program Plan.

Changes to the IST Program Plan involving a relief request from impractical Code requirements will be accomplished consistent with 10CFR50.55a, Generic Letter 89-04 and NUREG-1482.

Components failing to meet test requirements will be dispositioned by the Plant's Problem Evaluation Request (PER) program. Specific responsibilities are defined in the Plant procedures.

t

~'

IST Program Plan 2nd 10- Year Interval WNP-2 Page 3 of Revision 171 1

2.2 Pro m Database The IST Program Plan for the second ten year interval was developed based on a review of pumps and valves at WNP-2 and the applicable Code inservice testing requirements.

To provide added assurance that. the IST Program described herein accurately reflected the current requirements, design basis, and licensing commitments, the'xisting IST, Program database was enlarged and upgraded. Two independent reviews were utilind .

to identify which pumps and valves should be included in the IST Program. First, the flow diagrams of systems and components iequired to perform a safety function were reviewed and associated pumps and valves identified. The other review utilized MEL (Master Equipment List), a database with information on components installed at WNP-2.

The total MEL population of pumps and valves was reduced to about 10,000 by eliminating pumps and valves that were not ASME Code Class 1, 2 or 3. Each pump and valve thus identified by these reviews were evaluated for inclusion in the IST Program. This evaluation addressed the identification of active and passive safety functions, categorization per Code requirements, required testing and test frequencies, Where compliance with specified test requirements were deemed impractical, relief from such requirements is requested.

The administrative process for design and configuration management requucs changes be reviewed for impact on the IST Program. This will assure that potential changes affecting the commitments described herein are identified in a timely manner and allow for the associated database to be updated accordingly.

IST Program Plan 2nd 10-Year Interval WNP-2 Page 4 of 171 Revision 1 2.3 R~eference 2.3.1 10 CFR 50.50a, Codes and Standards.

2.3.2 WNP-2 Technical. Specifications Section 4.0.5.

2.3.3 FSAR Section 3.9.6.

2.3.4 10 CFR 50, Appendix J, Primary Reactor Containment Leakage Testing For Water-cooled Power Reactors.

2.3;5 ASME/ANSI Standard, Operations and Maintenance of Nuclear Power Plants, 1987 Edition through OMa-1988 Addenda.

2.3.6 ASME/ANSI OM Part 1, Requirements for Inservice Performance Testing of Nuclear Power Plant Prcssure Relief Devices.

2.3.7 ASME/ANSI OM Part 6, Inservice Testing of Pumps in Light-Water Reactor Power Plants.

2.3.8 ASME/ANSI OM Part 10, Inservice Testing of Valves in Light-Water Reactor Power Plants.

2.3.9 Generic Letter No. 89-04, Guidance on Developing Acceptable Inservice Testing Program, April 1989.

2.3.10 NRC Temporary Instruction 2515/110, Performance of safety-related check valves, November 1991.

r 2.3.11 NRC Temporary Instruction, 2515/114, Inspection Requirements for Generic Letter 89-04, Acceptable Inservice Testing Programs, January 1992.

2.3.12 Draft NUREG-1482, Guidelines for Inservice Testing at Nuclear Power Plants, November 1993.

2.3.13 NUIREG-1482, Guidelines for Inservice Testing at Nuclear Power Plants, April 1995.

2.3.14 Safety Evaluation of WNP-2 Pump and Valve Inservice Testing Program by NRC dated May 7, 1991 (TAC NO. 60493) and September 30, 1993 (TAC NO. M84553).

IST Program Plan 2nd 10- Year Interval WNP-2 Page 5 of Revision 171 1,

2.3.15 ASME Boiler and Pressure Vessel Code,Section XI, 1989 Edition with no addenda, Rules for Inservice Inspection of Nuclear Power Plant Components 2.3.16 WNP-2 Final Safety Analysis Report (FSAR).

2.3.17 NOS-34, "Inservice Testing of Pumps and valves".

3.0 Pum Inservice Testin Pro 3.1 Introduction Highly reliable safety related equipment is a vital consideration in the operation of a nuclear generating station. To help assure operability, the WNP-2 Pump Inservice Testing Program has been developed. The program establishes the requirements for preservice and inservice testing to assess the operational readiness of safety related pumps. The Program is based on the requirements of the ASME/ANSI OM Standard, OMa-1988 Addenda, Part 6, ",Inservice Testing of Pumps in Light-Water Reactor Power Plants." The Program complies with the specifications of the approved Codes (1),

-Regulations (2), and Generic Letters (3). 'This program includes those ASME pumps which are provided with an emergency power source and are required for shutting down the reactor to the cold shutdown condition, maintaining the cold shutdown condition, or mitigating the consequences 'of an accident.

The Program Plan establishes test intervals, parameters to be measured and evaluated, acceptance criteria, corrective actions, and records zcquirements. Where conformance with certain Code mquhements is impractical, relief requests are included in Section 3.6 with supporting information and proposed alternatives.

References:

1) ASME/ANSI OM Standard, OMa-1988 Addenda, Part 6, "Inservice Testing of Pumps in Light-Water Reactor Power Plants."

2) 10CFR 50.55 a(f).

3) Generic Letter 89-04.

j, IST Program Plan Page 6 of 171 2nd 10- Year Interval Revision 1 m Im lementation 3.2.1 Preservice Te tin Each pump shall be tested during the preservice test period. This testing shall be conducted under conditions as near as practicable to those expected during .

subsequent inservice testing. Picservice testing applies only to newly added components.

3.2.2 I~iT Inservice testing shall commence prior to when the pump(s) is required to be operable. Surveillance testing is performed for each pump listed in the program, nominally every 3 months. For pumps in systems out of service (declared inoperable or not required to be operable), the test is performed prior to placing the system in an operable status and the test schedule resumed. The WNP-2 Pump Inservice Testing Program is implemented as part of the Technical Specification required surveillance testing program; 3.2.3 Reference Values Reference values are established and maintained in accordance with OM Part 6, paragraph 4.3. and measured in accordance with OM Part 6, paragraph 4.6. In most cases, test parameters are measured with permanently installed plant instrumentation. This approach simplifies the test program and promotes timely completion of surveillance testing. Where permanently installed instrumentation is not available, portable instrumentation is used to record the required parameters.

3.2.4 Instrumentation Accurac The limits for instrumentation accuracy are provided in Table 1 of OM Part 6.

The WNP-2 instruments used for pump testing meet these requirements except where written relief has been requested.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 7 of Revision 171 1

3.2.3 3 Speed (N) - Pump speed is only measured for variable speed pumps.

Differential Pressure (W).- Differential pressure is calculated from suction and discharge pressure or obtained by direct differential pressure measurement.

Discharge Pressure (P) - Discharge pressure is measured for positive displacement pumps.

Flow Rate (Q) - Flow rate is measured using a rate or quantity meter installed in the pump test circuit.

Vibration (V) - Vibration measurements for centrifugal pumps, vertical line shaft pumps, and reciprocating pumps shall be taken at the locations specified in OM Part 6, paragraph 4.6.4. Ifa portable vibration indicator is used, the reference points are clearly identified on the pump to permit subsequent duplication in both location and plane; 3.2.6 Allowable Ran es For Te t Parameters

!I Tables 3a and 3b of OM Part 6 provide the allowable ranges for pump testing parameters. When the allowable range is more restrictive in the Technical Specifications, or other similar governing document, the more restrictive ranges are Used.

3.2.7 T~iM 3 3 During an inservice test, flow rate is normally selected as the independent test parameter and is set to match the reference fiow rate. Then other hydraulic and mechanical test parameters are measured in accordance with OM Part 6, paragraph 4.6, and evaluated against the appropriate reference values in accordance with OM Part 6, paragraph 6. The results of such evaluations determine whether or not corrective action is required.

IST Program Plan 2nd 10-Year Interval WNP-2 Page 8 of Revision 171 1

3.2.8 'Test Procedure Each pump in the Pump Testing Program is tested according to detailed test procedures. The procedure includes, as a minimum:

a) Statement of Test Purpose. Identification of test objectives, references applicable Technical Specifications and may note the operating modes for which the test is appropriate.

b) Prerequisites for Testing. System valve alignment, equipment for proper pump operation (cooling water, ventilation, etc.) and additional instrumentation (e.g., portable temperature or vibration monitors) is noted.

Identification numbers, range and calibration verification of instrumentation ~ recorded..

c) Test Instructions. Directions are sufficiently detailed to assure completeness and uniformity of testing. Instructions include provisions for returning system to its normal standby configuration following testing.

(For informational purposes, proposed flow paths are illustrated in Section 3 7).

d) Acceptance Criteria. The ranges within which test data is considered acceptable is established by the Supply System and included in the test procedure. In the event that the data fall outside the acceptable ranges, corrective actions am taken in accordance with OM Part 6, paragraph 6.1.

e) Test Instruments. A description of instruments used.

f) Reference Values.

3.2.9 ~Tn:ndin Test parameters shown in OM Part 6, Table 1, except for fixed values, will be trended.

Finally, it is recognized that the Pump Inservice Testing Program sets forth minimum testing requucments. Additional testing will be performed, as required, after pump maintenance or as determiiled necessary by the Plant Staff.

9 of 171 IST Program Plan 2nd 10- Year Interval WNP-2 Page Revision 1 Pum Reference List This list gives a brief description of each pump identified in the Pump Inservice Test Table, Section 3.4.

DO-P-1A, 1B, 2 These pumps transfer diesel generator fuel oil from the subterranean storage tanks to the diesel's Day Tanks. Pump 2 is dedicated to the HPCS Diesel., The discharge lines of Pump 1A and 1B are cross tied, and each pump can supply fuel to either Diesel 1A or 1B.

FPC-P-1A, 1B The Fuel Pool Circulation (FPC) pumps take suction on the spent fuel pool and discharge through the FPC heat exchangers and, during normal operation, through the Fuel Pool Filter/Demineralizers.

HPCS-P-1 The High Pressure Core Spray pump provides emergency cooling spray to the reactor core. It is capable of injecting coolant at pressures equal to or above normal reactor operating pressures. The pump can take suction from the Condensate Storage Tank or from the Suppression Pool.

HPCS-P-2 This pump is dedicated to providing cooling water to the HPCS Emergency Diesel Generator, the standby power source for the High Pressure Core Spray System.

HPCS-P-2 is located in the Service Water Pump House and takes suction from the spray pozld.

LPCS-P-1 A high capacity, low head pump, the Low Pressure Coze Spray pump provides cooling spray to the reactor core. LPCS-P-1 takes suction from the suppression pool.

RCIC-P-1 The turbine driven Reactor Core Isolation Cooling pump supplies coolant to the core in the event of reactor vessel isolation. It can take suction from either the Condensate Storage Tank or from the suppression pool.

of IST Program Plan 2nd 10-Year Interval WNP-2 Page 10 Revision 171 1

RHR-P-2A, 2B, 2C P

The Residual Heat Removal pumps are high capacity, low head pumps which have multiple uses during normal and emergency plant conditions. Briefly the system:

a) In conjunction with.other systems, restores and maintains reactor coolant inventory in the event of a LOCA b) Removes decay heat after shutdown c) Cools the suppression pool d) Can provide cooling spray to upper and lower drywell and to the wetwell e) Can assist in fuel pool cooling f) Can provide a condensing spray to the reactor head g) Provides a flow path for Standby Service Water in case containment flooding is required.

Pumps take suction from the suppression pool in the standby operating mode.

SLC-P-1A, 1B The Standby Liquid Control pumps are used to inject negative xcactivity (sodium pentaborate) into the reactor core independently of the contxol rod system. Suction is obtained from a storage tank containing the sodium pentaborate solution.

SW-P-1A, 1B The Standby Service Water pumps supply cooling water to separate trains of safety related equipment. The pumps take suction on their respective spray ponds but discharge to the opposite pond. The two spray ponds constitute the ultimate heat sink.

IST Program Plan, 2nd 10- Year Interval WNP-2 Page 11 of Revision 171 1

The pumps included in the WNP-2 IST Program are listed in the Test Table. The information contained in this table identifies those pumps required to be tested to the requirements of ASME/ANSI OM Part 6, the testing parameters and frequency of testing, and associated relief requests.

~Le end Q = Quarterly (92 day interval) test N/A = Not applicable. See Relief Requests NR = Not required by Code

N IST Program Plan 2nd 10- Year Interval WNP-2 Page 12 of Revision 171 1

Pump Inservice Test Table Flow Inlet Disch Diff Flow Vib Pump Relief Pump Ident Diagram e

Pump Press Press Press Vel Speed Requests &

& Class Ape Technical C rd Pi Po aP Q V N Positions DO-P-1A M512Q Vertical 2,6 B10 Line ShaA Q Q Q Q Q TP01 M512% Vertical 2,6 DO-P-1B Q Q Q Q Q Glo Line ShaA TP01 DO-P-2 M512< Vertical 2,6 C2 Line ShaA Q Q Q Q Q TP01 M526 Centri-D13 fugal Q Q Q Q Q FPC-P-1A'PC-P-1B M526 Centri-C13 fugal Q Q Q Q Q HPCS-P-1 M520 Vertical B6 Line ShaA Q Q Q Q Q 4,5 M524-1 Vertical HPCS-P-2 N/A Q N/A Q Q 1,3 GS Line Shaft LPCS-P-1 M520 Vertical B12 Line ShaA Q Q Q Q Q RCIC-P-1 M519 Centri-D12 fugal Q Q Q Q Q M521-1 Vertical RHR-P-2A Q Q Q Q Q 4,5 B11 Line Shaft M521-2 Vertical RHR-P-2B Q Q Q Q Q 4,5 D4 Line Shaft M521-2 Vertical RHR-P-2C Q Q Q Q Q 4,5

, D6 Line ShaA .

SLC-P-1A M522 Positive F6 NR Q . NR Q Q Displ.

M522 Positive SLC-P-1B NR Q NR Q Q D6 Displ.

M524-1 Vertical SW-P-1A N/A Q N/A Q Q 1,3 G4 Line ShaA M524-2 Vertical SW-P-1B N/A Q N/A Q Q 1,3 F5 Line Shaft

IST Program Plan 2nd 10- Year Interval WNP-2 Page 13 of Revision 171 1

3.5 Technical Positions Technical Position TPOI Pump Code Class PEcID Dwg. Number System(s)

DO-P-1A M512, SH 4 DO-P-1B M512, SH 4 Diesel Oil Transfer DO-P-2 M512, SH 4 Title Use of tank level to calculate differential pressure of pumps DO-P-1A, DO-P-1B and DO-P-2 h'"

OM Part 6, paragraph 4.6.2.2, states that the differential pressure is the difference between the pressure at a point in the inlet pipe and the pressure at a point in the discharge pipe.

NUTMEG-1482, section 5.5.3, states that when inlet pressure gauges are not installed in the inlet of a vertical line shaft pump, it is impractical to directly measure inlet pressure for use in differential pressure for the pump. The NRC staff recommends use of tank level 'etermining to determine the suction pressure of vertical line shaft pumps and a relief request is not required.

The method is in accordance with a determination of differential pressure allowed by the Code.

~Po ition Suction pressure is determined by, measuring storage tank level before pump start. Storage tank level changes when the pump is running, so accurate suction pressure measurements cannot be determined while the pump is running. Suction pressure is calculated based on the height of the fluid level above pump suction and the reading scale for measuring the level and the calculational method yield Code required accuracy of + 2%. This method yields the information needed for monitoring the hydraulic condition of the pumps without the need to install suction (inlet) pressure gauges which are not practical due to design limitations.

IST Program Plan 2nd 10-Year Interval WNP-2 Page 14 of Revision 171 1

3.6 Relief R uest From Certain OM Part 6 R uirements Relief Requests identify Code requirements which are impractical for WNP-2 and provide technical justification for the requested exception. Where appropriate, they also propose alternate testing to be performed in lieu of the Code requbed testing.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 15 of Revision 171 1

S Relief Request RP01

~

Pump Code Class P Sc ID Dwg. No. System(s)

SW-P-1A M524, SH 1 SW-P-IB, M524, SH 2 Standby Service Water HPCS-P-2 M524, SH 1 OM Part 6 Code R uirement f r which Relief i R uested Measure pump differential pressure, W. (Paragraph 5.2, Table 2) f f f

1) SW-P-1A, '1B, and HPCS-P-2 are vertical line shaft type pumps which are immersed in their water source. They have no suction line which can be instrumented.

2) Technical Specification states minimum allowable spray pond level to assure adequate NPSH and ultimate heat sink capability.

3) The difference between allowable minimum and overflow pond level is only twenty one (21) inches of water or 0.8 psi. This small difference will not be significant to the Test Program and suction pressure will be considered constant. Administratively, the pond

'level is controlled within a nine (9) inch band.

4) 'cceptable flowrate and discharge pressure will suffice as proof of adequate suction pressure.

Alternate Testin t be Performed Pump discharge pressure will be recorded during the testing of these pumps.

S f*

The effect of setting the Code Acceptance Criteria on discharge pressure instead of differential pressure as specified in the Code will have no negative impact on detecting pump degradation.

A review of the discharge pressure gauge reading, which is uncorrected for elevation, compared to differential pressure readings shows that basing corrective action on discharge pressure more conservative than basing it on differential pressure for these pump installations. is'lightly

IST Program Plan 2nd 10- Year Interval WNP-2 Page 16 of Revision 171 1

Relief Request RP01 (Continued)

C Ac tance/SER Dated November 27 1 Relief granted provided that the discharge pressure is less than the calculated differential pressure considering the entre range of suction pressures, such that acceptance criteria assigned to the discharge pressure gives equivalent protection provided by the Code for differential pIcs sure.

Maximum elevation of spray pond level is 434 feet 6 inches and minimum elevation of discharge piping for these pumps is 442 feet. Thus discharge pressure for these pumps will always be lower than the calculated differential pressure for the entire range of suction pressures.

Assigning acceptance criteria to the discharge pressure for these pumps gives equivalent protection provided by the Code for differential prcssure.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 17 of Revision 171 1

Relief Request RP02 Pump Code Class P&ID Dwg. No. System(s)

DO-P-1A M512, SH 4 DO-P-1B M512, SH 4 Diesel Oil Transfer .

DO-P-2 M512, SH 4 M Part 6 Code R uirement For Which Relief is R ue ted Paragraph 4.6.5. Flow rate shall be measured using a rate or quantity meter installed in the pump test circuit.

B it 1iF r

A rate or quantity meter is not installed in the test circuit. To have one instaHed would be costly and time consuming with few compensating benefits.

Alternate T tin t be Performed Pump flow rate will be determined by measuring the volume of fluid pumped and dividing by the corresponding pump run time. The volume of fluid pumped will be determined by the difference in fluid level in the day tank at the beginning and end of the pump run (day tank fluid level corresponds to volume of fluid in the tank). The pump flow rate calculation methodology meets the accuracy requirements of OM Part 6, Table 1.

uali Safe Im a The day tanks aic horizontal cylindrical tanks with elliptical ends. The tank fluid volume is approximately 3,200 gallons. Fluid level measurement is accurate to an eighth inch which corxesponds to an average volume error of approximately 11 gallons. The test methodology used to'calculate pump flow rate will provide results consistent with Code mquirements. This will provide adequate assurance of acceptable pump performance.

NRC A tance/SHR Dated N vember 27 1 5 Relief granted provided the calculated methods are properly proceduralized and meet quality assurance requirements.

Calculation methods are specified in the surveillance procedures and meet the quality assurance requirements.

1 IST Program Plan 2nd 10-Year Interval WNP-2 Page 18 of Revision 171 1

Relief Request RP03 Pump Code Class P&ID Dwg. Number System(s)

SW-P-1A M524, SH 1 Standby Service Water SW-P-IB M524, SH 2 Standby Service Water HPCS-P-2 'M524, SH 1 Standby Service Water, HPCS M Part 6 Code R uirements For Which Relief is R ue ted Paragraph 5.2(b) requires that the system resistance be varied until either the measured differential pressure or measured fiow.rate equals the corresponding reference value. The quantities of Table 2 are then measured or observed and compared to the corresponding reference value.

Bif lif

1) Service Water systems are designed such that the total pump flow cannot be adjusted to one finite value for the purpose of testing without adversely affecting the system flow balance and Technical Specification operability requirements. Thus, these pumps must be tested in a manner that the Service Water loop remains properly flow balanced during and after the testing and each supplied load remains, fully operable to maintain the required level of plant safety.

2) The Service Water system loops are not designed with a full flow test line with a single throttle valve. Thus the flow cannot be throttled to a fixed reference value. Total pump fiow rate can only be measured using the total system flow indication installed on the common return header. There are no valves in any of the loops, either on the common supply or return lines, available for the purpose of throttling total system flow. Only the flows of the served components can be individually throttled. Each main loop of service water supplies 17-18 safety related loads, all piped in parallel with each other. The HPCS-P-2 pump loop supplies four loads, each in parallel. Each pump is independent from the others (ie.no loads are common between the pumps). Each load is throttled to a FSAR required flow range which must be satisfied for the loads to be operable. All loads are aligned in parallel, and all receive service water flow when the associated service water pump is running, regardless of whether the served component itself is in service. During power operation, all loops of ser vice water are required to be operable per Technical Specifications. A loop of service water cannot be taken out of service for testing without entering an Action Statement for a Limiting Condition for Operation (LCO). Individual component flows outside of the FSAR mandated flow ranges also induce their own Technical Specification action statements that in turn can induce plant shutdown in as little as two hours, depending on the load in question.

IST Program Plan Page 19 of 171 2nd 10-Year Interval Revision 1 Relief Request RP03 (Continued)

3) Each loop of Service Water is flow balanced before exiting each refueling outage to ensure that all loads are adequately supplied. A flow range is specified for each load.

Once properly flow balanced, very little flow adjustment can be made for any one particular load without adversely impacting the operability of the remaining loads (increasing fiow for one load reduces flow for all the others). Each time the system is flow balanced, proper individual component flows are produced, but this in turn does not necessarily result in one specific value for total flow. Because each load has an acceptable flow range, overall system full flow (the sum of the individual loads) also has a range. Total system flow can conceivably be in the ranges of approximately 9,200-10,100 GPM for SW-P-1A and SW-P-1B pumps and approximately 1,050 - 1,160 GPM for HPCS-P-2 pump. Consequently, the zquirement to quarterly adjust service water loop flow to one specific flow value for the performance of inservice testing conflicts with system design and component operability requirements (i.e., fiow balance) as required by Technical Specification, Alternate Testin t be Performed As discussed above in the basis for relief section, it is extremely difficultor impossible to return to a specific value of flow rate or discharge pressure for testing of these pumps. Multiple reference points could be established according to the Code, but it would be impossible to obtain reference values at every possible point, even over a small range. An alternate to the testing requirements of Paragraph 5.2 is to base the acceptance criteria on a reference curve. Flow rate and discharge pressure are measured during inservice testing in the as found condition and compared to an established reference curve. Discharge pressure instead of differential pressure is used to determine pump operational readiness as described in Relief Request RP01. The following elements are used in developing and implementing the reference pump curves.

1) A reference pump curve (flow rate vs discharge pressure) has been established for SW-P-1A and SW-P-1B from data taken on these pumps when they were known to be operating acceptably. These pump curves represent pump performance almost identical to prcoperational test data. The methodology employed for establishing a reference pump curve is similar to that for performing a comprehensive test proposed by the later edition of the OM Code.

2) Pump curves are based on seven or more test points beyond the flat portion of the curve (at flow rate greater than 4800 gpm). Rated capacity of these pumps is 12,000 gpm.

Three or more test data points were at flow rate greater than 9,000 gpm. The pumps are being tested at or near full design flow rate.

IST Program Plan 2nd 10-Year Interval WNP-2 Page 20 of 171 Revision 1 Relief Request RP03 (Continued)

3) To reduce the uncertainty associated with the pump curves and the adequacy of the acceptance criteria, special test gauges (+ 0.5% full scale accuracy) were installed to take test data in addition to plant installed gauges and Transient Data Acquisition System (TDAS). All instruments used either met or exceeded the Code iequired accuracy.

4) For HPCS-P-2 pump, the reference pump curve is based on the manufacturer's pump curve as modified by preoperational test data.

5) Review of the pump hydraulic data trend plots indicates close correlation with the established pump reference curves, thus further validating the accuracy and adequacy of the pump curves to assess pump operational readiness.

6) The reference pump curves are based on flow rate vs discharge pressure. Acceptance criteria curves are based on differential pressure limits given in Table 3b. Setting the Code Acceptance Criteria on discharge pressure using differential limits is slightly more conservative for these pump installations with suction lift (Relief Request RP01). See the attached sample SW-P-1A pump Acceptance Criteria sheet. Area 1-2-5-6 is the acceptable range for pump performance. Area 3-4-5-6 defines the Alert Range, and the area outside 1-2-3-4 defines the required Action Range. These acceptance criteria limits do not conflict with Technical Specifications or FSAR criteria.

Only a small portion of the established reference curve is being used to accommodate fiow rate variance due to flow balancing of various system loads.

8) Review of vibration data trend plots indicates that the change in vibration readings over the narrow range of pump curves being used is insignificant and thus only one fixed reference value has been assigned for each vibration measurement location.

9) After maintenance or repair that may affect the existing reference pump curve, a new reference pump curve shall be determined or the existing pump curve revalidated by an inservice test. A new reference pump curve shall be established based on at least 5 points beyond the flat portion of the pump curve.

r, IST Program Plan 2nd 10- Year Interval WNP-2 Page 21 of 171 1 'evision Relief Request RP03 (Continued)

~li Sf I Design of the WNP-2 Service Water system and the Technical Specification requirements make it impractical to adjust system flow to a.fixed reference value for inservice testing without adversely affecting the system flow balance and Technical Specification operability requirements.

Proposed alternate Testing using a reference pump curve for each pump provides adequate assurance and accuracy in monitoring pump condition to assess pump operational readiness and shall adequately detect pump degradation. Alternate testing willhave no adverse impact on plant and public safety.

NRC Ac tance/SER Dated N yern er 27 l 5 Relief granted as requested.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 22 of 171 Revision 1 '

Relief Request RP03 (Continued)

SAMPLE DATA SHEET SW-P-1A ACCEPTANCE CRITEUA f

ACIIO RANGE ALERT GB ACIXO RANGE 9A50 9830 9~ 9 J30 9A30 9S30 9 tn0 9.730 9430 9.930 10A30 1L330 FLOW- GPM "

ALERTRANGE ~ Area Inside 3'-6 ~ ACHON RANGE = Area Outside 1-2-M

IST Program Plan 2nd 10- Year Interval WNP-2 Page 23 of Revision 171 1

Relief Request RP04 Pump Code Class PAID Dwg. Number System(s)

LPCS-P-1 M520 Low Pressure Core Spray RHR-P-2A M521, SH 1 RHR-P-2B M521, SH 2 Residual Heat Removal RHR-P-2C M521, SH 2 HPCS-P-1 M520 High Pressure Core Spray RCIC-P-1 M519 Reactor Core Isolation Cooling OM Part 6 Code R uirements F r Which Relief is R uested Paragraph 5.2(b) requires that the system resistance be varied until either the measured differential pressure or measured flow rate equals the corresponding reference value. The quantities of Table 2 are then measured or observed and compared to the corresponding reference value.

Basis for Relief Reference values are defined as one or more fixed sets of values of quantities as measured or observed when the equipment is known to be operating acceptably. All subsequent test results are to be compared to these reference values. Based on operating experience, flow rate (independent variable during inservice testing) for these pumps cannot be readily duplicated with the existing flow control systems. Flow control for these systems can only be accomplished through the operation of relatively large motor operated globe valves as throttling valves.

Because these valves are not equipped with position indicators which reflect percent open, the operator must repeatedly jog the motor operator to try to make even minor adjustments in flow rate. These efforts, to exactly duplicate the reference value, would require excessive valve manipulation which could ultimately result in damage to valves or motor operators.

24 of 171 IST Program Plan 2nd 10-Year Interval WNP-2 Page Revision 1 Relief Request RP04 (Continued)

Alternate Testin to be Performed As discussed above in the basis for relief. section, it is extremely difficultor impossible to return to a specific value of flow rate or differential pressure for testing of these pumps. Since the independent reference variable (flow rate) for these pumps is very difficult to adjust to a fixed .

reference value and requires excessive valve manipulation, the maximum variance shall be limited to J 2% of the reference value. Thus, fiow rate shall be adjusted to be within J 2%

of the reference flow rate and the corresponding differential pressure shall be measured and compared to the reference differential pressure value determined from the pump reference curve established for this narrow range of flow rate. Slope of the pump reference curve is not flat even over this narrow range of flow rate. Assuming the fiow rate to be fixed over this narrow range can result in additional error in calculating the deviation between the measured and reference differential pressure and at times this deviation can be non-conservative. ASME Code allows establishing multiple reference points but does not specify any variance from the fixed reference values. Since the dependent variable (differential pressure) can be assumed to vary linearly with flow rate in this narrow range, establishing multiple reference points in this narrow range is similar to establishing a reference pump curve representing multiple reference points.

This assumption of linearity between differential pressure and flow rate is supported by the manufacturer pump curves in the stable design flow rate region. For RCIC-P-1 pump both flow rate and speed are adjusted to be within + 2% of their respective reference values and the differential pressure is measured. The following elements are used in developing and implementing these reference curves.

1) A reference pump curve (fiow rate vs differential pressure) has been established for RHR pumps from data taken on these pumps when they were known to be operating acceptably. These pump curves represent pump performance almost identical to manufacturer's test data. The methodology employed for establishing a reference pump curve is similar to that for performing a comprehensive test proposed by the later edition of the OM Code.

2) For RCIC-P-l, a variable speed drive pump, flow rate is set within + 2% of the reference flow rate and the reference curve is based on speed with acceptance criteria based on differential pressure. This is done because of the difficulty in setting speed to a specific reference value as specified by the Code. AdditionaHy, evaluation of the manufacturer pump data, preoperational and special test data used to establish the pump reference curve indicates insignificant change (0.25 psi/gpm) in differential pressure with small variation (J 12 gpm) in flow rate.

3) For EPCS-P-1 and LPCS-P-1 pumps, the reference pump curve is based on the manufacturer pump curve which was validated during the preoperational testing.

ISY Program Plan 2nd 10- Year Interval WNP-2 Page 25 of 171 Revision 1 Relief Request RP04 (Continued)

4) RHR and RCIC pump curves are based on seven or more test points beyond the flat portion of the curve. These ECCS pumps have minimum flow rate requirements specified in Technical Specifications and are being tested at or near full design flow rate.

5) To reduce the uncertainty associated with the pump curves and to ensure the adequacy of the acceptance criteria, special test gauges (+ 0.5% full scale accuracy) were installed to take test data in addition to plant installed gauges and Transient Data Acquisition System (TDAS). All instruments used either met or exceeded the Code required accuracy.

6) Review of the pump hydraulic data trend plots indicates close correlation with the established pump reference curves, thus further validating the accuracy and adequacy of the pump curves to assess pumps operational readiness.

7) Acceptance criteria curves are based on differential pressure limits given in Table 3b. See the attached sample RHR-P-2A pump Acceptance Criteria sheet. Area 1-2-5-6 is the acceptable range for pump performance. Area 3-4-5-6 defines the Alert Range and the area outside 1-2-3-4 defines the mquhed Action Range. These acceptance criteria limits do not conflict with Technical Specifications or Final Safety Analysis Report operability criteria.

8) Only a small portion of the established reference curve is being used to accommodate flow rate variance.

9) Review of vibration data trend plots indicates that the change in vibration readings over the narrow range of pump curves being used is insignificant and thus only one fixed reference value has been assigned for each vibration measurement location.

10) After.maintenance or repair that may affect the existing reference pump curve, a new reference pump curve shall be determined or the existing pump curve revalidated by an inservice test. A new reference pump curve'shall be established based on at least 5 test points beyond the fiat portion of the pump curve.

Due to impracticality and difficulty of adjusting independent variables (flow rate, and speed for variable drive RCIC pump) to a fixed reference value for inservice testing without system modifications, alternate testing to vary the variables over a very narrow range (J 2% of reference values) and using pump reference curves for this narrow range is proposed. Alternate testing using a reference pump curve for each pump provides adequate assurance and accuracy in monitoring pump condition to assess pump operational readiness and will adequately detect pump degradation. Alternate testing will have no adverse impact on plant and public safety.

IST Program Plan Page 26 of 171 2nd 10-Year Interval Revision 1 Relief Request RP04 (Continued)

NRC A tance/SER Dated Novem er 27 l 5 Relief granted as requested.

Page 27 of 171 ISrr g Pl~

2nd 10- Year Interval WNP-2 Revision 1 ...

Relief Request RP04 (Continued)

SAMPLB DATA SHEET RHR-P-2A ACCEPTANCE CRITBRIA N GE I

111 g4 11 111 1'Q Q 111 GE 7490 7SOO 7S10 7S20 7SSO '7$ 40 7SSO 7S60 7$ 70 7540 7S90 7600 7610 7670 7630 7640 76SO INDICATEDPLOVER - GPM ALERTRANGE ~ Area Inside R-54 ACHON RANGE ~ Area Outside 1-2 $ 4

IST Program Plan 2nd 10-Year Interval WNP-2 Page 28 of Revision 171 1

Pump Code Class P&ID Dwg. Number System(s)

RHR-P-2A 2 M521, SH 1 RHR-P-2B M521, SH 2 Residual Heat Removal RHR-P-2C M521, SH 2 HPCS-P-1 M520 High Pressure Core Spray OM Part 6 Code R uirements For Which Relief is R uested Paragraph 4.6.1.2(a) Range, the full scale range of each analog instrument shall be not greater than three times the reference value.

Basis for Relief

1) Paragraph 4.6 specifies both accuracy and range requirements for each instrument used in measuring pump performance parameters. The purpose of instrument requirements is to ensure that pump test measurements are sufficiently accurate and repeatable to permit evaluation of pump condition and detection of degradation. Instrument accuracy limits the inaccuracy associated with the measured test data. Thus, higher instrument accuracy lowers the uncertainty associated with the measured data. The purpose of the Code range requirement is to ensure reading accuracy and repeatability of test data.

2) Since the TDAS data is being obtained to an accuracy of + 1% of full scale, it consistently yields measurements more accurate than would be provided by instruments meeting the Code instrument accuracy requirement of + 2% of full scale and range requirement of three times the reference value. Equivalent Code accuracy being obtained by TDAS measurements is calculated below.

~Ref. Instrument Test Instrument Range Equivalent Code Pump Value Loop Parameter I.D. (PSIG) Accuracy (PSIG) Accuracy RHR-P-2A Discharge RHR-PT-37A + 1%, 6/(3x136)x100 0-600 136 Pressure TDAS FI'55 + 6 psig =1.47%

Discharge RHR-PT-37B g 1%, 6/(3x132)x100 RHR-P-2B 0400 132 Pressure TDAS PT 076 + 6 psig =1.52%

RHR-P-2C Discharge RHR-PT-37C + 1%, 6/(3x143)x100 0400 143 Pressure TDAS PT 091 J 6psig =1A0%

Discharge HPCS-PT-4 J. 1%, 15/(3x430)x100 HPCS-P-1 0-1500 430 Pressure TDAS PT 107 + 15 psig =1.16%

Reference values are specified in the implementing procedures. This table will not be updated to reflect changes in reference values.

29 of 171 IST Program Plan 2nd 10-Year Interval WNP-2 Page Revision 1 Relief Request RP05 (Continued)

Thus the range and accuracy of TDAS instruments being used to measure pump discharge pressure result in data measurements of higher accuracy than that required by the Code and thus will provide reasonable assurance of pump operational readiness. It should also be noted that the TDAS system averages many readings, therefore giving a significantly more accurate reading than would be obtained by visual observation of a gauge.

3) Installing temporary test gauges every quarter to obtain discharge pressure readings would be burdensome and costly and would not provide a pressure measurement that is any more accurate or reliable. Additionally, using different test gauges for IST from one test to another may introduce its unique systematic error and thus affect the quality and repeatability of test data.

Alternate Testin to be Perf rmed During quarterly pump inservice testing, pump discharge pressure which is used to determine differential pressure shall be measured by respective TDAS points listed above for each pump.

ualit Safet Im act TDAS data wiH consistently provide acceptable accuracy to ensure that the pumps are performing at the flow and pressure conditions to fulfilltheir design function. TDAS data is sufficiently accurate for evaluating pump condition and in detecting pump degradation. The effect of granting this relief request willhave no adverse impact on plant and public safety. Test quality will be enhanced by getting slightly better, more repeatable data.

NRC Acc tance!SER D ted Novem r 27 1 Relief granted with provisions.

The range of the PTs used for these applications were selected to bound the expected pump discharge pressure range during all normal and emergency operating conditions (the maximum expected discharge pressure for the RHR and HPCS pumps is approximately 450 psig and 1400 psig respectively). However, during inservice testing the pumps are tested at full fiow, resulting in lower discharge pressures than the elevated discharge pressure that can occur during some operating conditions. For this reason the pump reference value is significantly below the maximum expected operational discharge pressure. A reduction of the range of the PTs to three times the reference value would, in these cases, no longer bound the expected discharge pressure range for these pumps, and therefore is not practicable. If a pressure transmitter were to fail, a like replacement would have to be used due to the above identified reasons of replacing a pressure transmitter with one not suited for aH pump flow conditions. However, this is not a concern because the existing instrumentation provides pump discharge pressure indication of higher accuracy and better resolution than that xequiied by the Code for evaluating pump condition and detecting degradation.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 30 of 171 Revision 1 Relief Request RP06 Pump Code Class PAID Dwg. Number System(s)

DO-P-1A M512, SH 4 DO-P-IB M512, SH 4 Diesel Oil Transfer System DO-P-2 M512, SH 4 OM Part 6 Code R uirement For Which Relief i R uested Paragraph 5.2(b) requhes that the system resistance be varied until either the measured differential pressure or measured flow rate equals the corresponding reference value.

Function The fuel oil storage and transfer system consists of separate, independent diesel oil supply subsystems serving each of the two tandem diesel generators (1A and 1B) and the HPCS diesel engine generator (1C). In each subsystem, a transfer pump takes suction from the diesel oil storage tank and discharges to an associated diesel generator fuel oil day tank to maintain the fuel oil level within the day tank. The transfer pump is sized to provide a flow of 4.4 times the maximum engine consumption rate (of 110% load) and is automatically controlled by level switches activated by day tank fuel level. The volume of the day tank permits eight and one-half hours of engine operation of the associated diesel generator without supply to the day tank. In case of loss of fuel to one diesel generator, the other generator can provide sufficient capacity for emergency conditions, including safe shutdown of the reactor coincident with loss of offsite power.

Basis for Relief

1) Diesel fuel transfer pumps do not have inline flow meters and the pump flow rate is determined by measuring the volume of fuel oil pumped and dividing by the corresponding pump run time. Use of a clamp-on flow meter does not provide an accurate and repeatable flow rate due to the low flow rate and lack of time available to set up the flow meter with the pump running.

2) Pump discharge piping has manual discharge isolation and day tank inlet isolation valves which are fully open. These valves are provided for system maintenance only, System resistance based on the system design and lineup remains constant from test to test.

Since the flow rate is calculated based on the change in tank level, it is impractical to adjust flow rate with the globe valve.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 31 of Revision 171 1

Relief Request RP06 (Continued)

3) Differential pressure for these pumps is calculated by measuring discharge pressure using the discharge pressure gauge and suction pressure is calculated by measuring the level of the storage tank before-the pump start. Storage tank level changes during the pump run. Thus, due to system design and lack of instrumentation it is impractical to adjust the differential pressure to the reference value by varying the 'flow rate during pump operation.

4) It is extremely difficultor impossible to fix either fiow rate or differential pressure to the reference value for testing of these pumps. As the system zcsistance based on the system design and lineup remains constant from test to test, the provisions of paragraph 5.2(c),

"where system resistance cannot be varied, flow rate and pressure shall be determined and compared to their respective reference values", can be used to evaluate operational readiness of these pumps.

5) Review of previous hydraulic and mechanical pump performance parameters indicates no degrading trends. Disassembly of these pumps during various maintenance activities revealed no degradation.

Alternate Te tin to be Perf rmed The subject system will be treated as a fixed resistance system as defined by paragraph 5.2(c) and all applicable Code requirements adhered to. That is, pressure, flow rate, and vibration shall be determined and compared with corresponding reference values. All deviations from the reference values shall be compared with the limits given in Table 3 and corrective actions taken as specified in paragraph 6.1.

Design of the WNP.-2 Diesel Fuel Oil Transfer system and lack of instrumentation make it impractical to adjust the system flow rate or differential pressure to a fixed reference value for inservice testing. Proposed alternate testing by maintaining system xcsistance constant from test to test and determining flow rate and differential piessure and comparing to their respective reference values provides adequate assurance and accuracy in monitoring pump condition to assess pump operational readiness and will adequately detect pump degradation. Alternate testing will have no adverse impact on plant and public safety.

~Reference FSAR Section 9.5.4 NRC Ac tance SER Dated November 27 1 5 Relief not required.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 32 of 171 Revision 1 Relief Request RP07 P&ID Dwg.

Pump Code Class System(s)

Number SLC-P-1A M522 Standby Liquid Contxol SLC-P-1B M522 M Part 6 Code R uirement For %'hich Relief is R ue ted Paragraph 4.6.1.6, Frequency Response Range. The frequency response range of the vibration measuring transducers and their xeadout system shall be from one third minimum pump shaft rotational speed to at least 1000 Hz.

~Fnction SLC-P-IA and 1B inject borated water into the reactor vessel as an alternate means of introducing negative reactivity to shutdown the reactor.

Basis for Relief

1) The motor speed of 30 Hertz is transfeaed to the pump shaft through a 4.8:1 ratio gear box which reduces motor speed and produces a shaft rotation of 6.25 Hertz. Paragraph 4.6.1.6 requires a frequency range of one third pump shaft rotating frequency to one KiloHertz; in this case that frequency range is 2 Hertz through one KiloHertz + 5%.

A search for field applicable certifiable instrumentation that can satisfy these criteria has been unsuccessful.

2) Vibration instruments include high-pass filters in the signal processing scheme for the purpose of eliminating low frequency electronic noise. Low frequency vibration is thus filtered out of the processed signal. This is a common practice in nearly all available field usable instrumentation, because there is no xequirement for collecting vibration data at such low frequencies. Thus, the procurement of practical, field applicable instrumentation capable of accurate detection down to 2 Hertz is improbable.

3) The Supply System uses high quality instrumentation that has been certified to a lower frequency range of six Hertz and an upper range of three KiloHertz with an accuracy of at least J 5%, and meets the other requirements of the Code for plant rotating machinery. This instrumentation has been made part of the Quality Class I calibration program, which is traceable to the National Bureau Of Standards, and is used for Quality Class I rotating machinery vibration data collection, including the SLC pumps.

IST Program Plan Page 33 of 171 2nd 10- Year Interval Revision 1 Relief Request RP07 (Continued)

4) The requirement of one third minimum pump shaft rotation speed is useful when subsynchronous vibration frequencies must be monitored. Subsynchronous vibration monitoring can be used to identify rotor dynamic problems that are common in rotating machines such as shaft rubs, fluid whirl in journal bearings, axial instabilities, and other such problems that are not normally found in reciprocating machines. The necessity of collecting subsynchronous vibration data on the SLC pumps was discussed with the manufacturer. The Union Pump Company agreed that vibration data at less than rotating frequency would not be necessary.

5) The SLC pumps at WNP-2 operate only during required surveillance testing, and thus experience very little service, such that a mechanical fault is very unlikely. Moreover, the SLC pumps are included in the WNP-2 Vibration Monitoring Program, as well as in the IST program. The Vibration Monitoring Program collects vibration data on plant machinery, and analyzes and trends the collected vibration data for use in maintenance decisions as well as machinery operability determinations. The SLC Pumps have been monitored since November 1993. Their spectra is consistent and has shown only minor statistical changes during the period of surveillance. The subsynchronous region shows a very low amplitude and consistent pattern, as expected.

Al ernate Testin t be Perf rmed The vibration measurements willbe taken using instrumentation accurate to within + 5% of full scale over a frequency range of 6 Hertz to 3 KiloHertz. Alldeviations from the reference values shall be compared with the limits given in Table 3 and corrective actions taken as specified in paragraph 6.1.

ualit Safet Im act The Supply System is of the opinion that the use of high quality, commercially available vibration monitoring equipment calibrated to be accurate to at least J 5% over a range of 6 Hertz to 3 KiloHertz is a technically acceptable method of monitoring the mechanical condition of the SLC pumps. The instruments that are used provide meaningful and useful vibration data over the frequency range in which pump faults would be expected to develop a'nd manifest. In addition to this, the 3 KiloHertz range includes the frequencies at which rolling element bearing faults occur, and thus provides an additional range of protection. Thus, the monitoring program meets the intent of the Code and will neither adversely impact system reliability nor the health and safety of the general public.

IST Program Plan 2nd 10-Year Interval WNP-2 Page 34 of 171 Revnnon 1 Relief Request RP07 (Continued)

NRC A tance/SER Dated November 27 1 5 Relief granted with provisions. In the event it becomes necessary to replace the existing analyzer and its matching accelerometer, and ifanother matched unit capable of response down to 2 Hz is available and is compatible with the existing vendor software, the Supply System will procure the replacement equipment. Alternately, if the Supply System changes the method of vibration data acquisition (i.e, to utilize proximity probes which measure vibration by displacement), all code requirements will be met.

This contingency to upgrade the vibration equipment has been added to the component condition monitoring program.

IST Program Plan 2nd 10-Year Interval WNP-2 Page 35 of Revision 171 1

3.7 Pro osed Pum Test Flow Paths These flow paths are proposed for use during pump and valve testing. Surveillance procedures define actual system lineup for testing pumps and valves.

PT 16 V-711

~l 1/2 V-12 V-11 V-10 1/2 2

PT 118 V-701B 1/2 V-40B V-4B V-2B V-1B 1/2 r

V-5 2

1 1/2 ~

V-44 PT 11A V-701A V-40A V-4A ~ 1 1/2 V-2A V-1A 1/2 2

8EEEBB!KRx.

PRIO 8512 SM 1 HS12 SM 4

4 V-146A V-1468 FE-16 2

(-10

~ 0IFFUSERS~

4 g 6g 3 V-112A V-116A (-8 V-147 V-175 Pl Pl V-7O9A 9AG RO-6 V-rOBA Y-140 V-118A 6

~ 8

~

sg V-124 V-184 V-1128 V-1168

%=EBB V-172 PI Pl V-7068 6BG V 7098 9BG V-158 ',

V-11BB V-173

14 10 CST

'-11 V-10 V-1 I g

I 20 V-2 1 V-701 PT V-710 4

LPCS HPCS FT FE-7 V-709 24 16 12 V-24 00 C

0 PRIO H HPR R PRAY H520

r~w i%X II WW

~! ~ 4 V ) ~

A ~ I

~ L

V-1 12 RO-4 V-12 V-60 I U

I PT V-709 Pl 1

V-701 LPCS HPCS V-708 FT FE-2 3

V-707 16 24 V-3 14 LK~

P8 I D P Y 8520

T~l ~ ~

RR Wa4 S g

~ 0 ~ S

FE-14A I

IO hCI 18 6 I

20 FT 15 V-3A FI V-27A R603 V-24A V-172A RO RO BA BA V-4A 20 18 V-6A 18 24 IS Pl V-701 A 2A 14 ga cs C

I 24 V-31A RO-SA BEHHKHKSa 0 P8 I 0 HS21 SH 1

~ I M T

~

~ ~

k

~ ~

F~

i&i ~ ~

~

I

18 V-21 V-174 24 RO RO BC V-4C V-729V VENT STRAINER FT Fl FE-14C 15 R603 V-728C IS Pl V-rOSC V-701C IB 14 24 V-110C V-31C RO-SC

BEEEBEK~

PRI0 8521 SH 2

OEIIlN MATER SUPPLY V-9 V-17 5LGJIH V-16 Pl V-31 V-701 1 1/2 1 1/2 V-4A SLC-P-1A V-3A V-33A 1 1/2 3*

V-2A 1 1/2 V-4B V-3B SLC-P-IB V-33B 3

V-2B P8 I D HS22

20 V-2A V-1A 16 20 20 18 BBM~

RHR-,V-GBA RHR-V-14A y LPGA Pl 32A BK~ ~~ 20 FE-GA 18 20 PUMP HOUSE WALL 12 20 PCV-38A V-12A 20 20 OC'M HX-1A2 V-170A FE-1A OCII HX-1Al V-4A V-3A BEKHEHKRa, RO-2A P8 01 M524 SH 1 AV WAT A

V-28 V-18 2LPA 20 20 18 20 20 18.

Pl

'I y g088 328 RHR-V<<GBB RHR-V-148 FE-68 PUHP HOUSE WALL 12 lCI PCY-388 V-128 18 18 20 FE-18 V-1708 18 OCW HX-182 RO-28 DCW HX-181 Y-48 Y-38 BEEEBEH~

P a 1 O RV AT 8524 SH 2

IST Program Plan 2nd 10-Year Interval WNP-2 Page 48 of 171 Revision 1 Records and reports of pumps in the Program willbe maintained in accordance with OM Part 6 paragraph 7. The files will contain the following:

1) Pump records will be maintained in accordance with paragraph 7.1.

2) Inservice test plans are issued as pump surveillance test procedures. The inservice testing records for pumps in the Program will be maintained in accordance with paragraph 7.2.

3) Records of tests for pumps in the Program will be maintained in accordance with paragraph 7.3. Completed surveillance test procedures are retained per plant administrative procedures.

')

Records of corrective actions for pumps in the Program will be maintained in accordance with paragraph 7.4. Corrective actions are documented on Work Orders and/or Problem Evaluation Requests (PERs).

The Pump Inservice Test Program, associated surveillance test procedures and results, and corrective actions are retained per plant administrative procedures. For informational purposes, a sample pump test data sheet is provided.

r

49 of 171 IST Program Plan 2nd 10-Year Interval WNP-2 Page Revision 1 SAMPLE DATA SHEET PUMP OPERABILITY DATA SHEET FOR HPCS-P-1 TEST REF " ACTION ALERT MEASURED ACTION VALUE LO (+1) LO (+1) VALUE HI(+1)

Driver Lubrication SAT N/A N/A UNSAT Pump Lubrication N/A SAT N/A N/A UNSAT Suction Pressure at test 16.5 5.7 N/A N/A PSIG flow per Test Gauge Discharge Pressure per PSIG N/A N/A N/A N/A TDAS 107 Differential Pressure (Discharge Pressure- PSID 413.0 (+2) (+3) (+2) uction Pressure per te gauge)

Indicated Flowrate per TDAS 122 GPM

(+4) 6560 '/6500 N/A NA CST level per N/A N/A N/A N/A COND-LIPOA/40B

'/A Motor Voltage VAC N/A N/A N/A Motor Current N/A N/A N/A N/A tboard Motor Bearin 'F N/A N/A N/A N/A Temperature per W134 Inboard Motor Bearing 'F N/A N/A N/A N/A Temperature per W135

(+1) For measured values beyond the ALERT Value or ACTION Value refer to Precaution 4.8 or 4.9, respectively.

(+2) The ACTION Range is defined as outside the area described by points 1, 2, 3 and 4 on Attachment 9.4.

(+3) The ALERT Range is defined as inside the area described by points 3, 4, 5 and 6 on Attachment 9.4.

(+4) Indicated flow GE 6500 gpm provides corrected flow GT 6350 gpm (I'echnical Specification Limit) for fluid temperature GE 40 'F.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 50 of 171 Revision 1

'AMPLE DATA SHEET VIBRATIONDATA SHEET FOR HPCS-P-1 MUA 0 MUE MUS HPCS- P- 1 MLE MLS PS PA G RTH VIBRATIONVELOCITY (IN/SEC)

PROBE LOCATION REFER MEASURED ALERT HI ACTION HI VALUE VALUE (+1) (+1)

MUA 0.027 0.068 0.162 MUE 0.040 0.100 0.240 MUS 0.072 0.180 0.432 MLE 0.079 N/A N/A NON- 0.061 N/A N/A ASME PA 0.176 N/A N/A PE 0.097 N/A N/A 0.074 N/A N/A

(+ I) For MEASURED VALUES beyond the ALERT HI value or ACTION HI value refer to Precautions and Limitations 4.8 or 4.9, respectively.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 51 of Revision 171 1.

SAMPLE DATA SHEET HPCS-P-I ACCEPTANCE CRITERIA N GE 41 4

N GE 649 S 6$ 0$ 6$ 1S 6S2$ 6$ $ $ 6$ 4$ 6SSS 6$ 6$ 6$ 7$ 6$ 8$ 6$ 9$ 660$ 661$ 662S 663$ 664$ 66SS 666S 667$ 668$ 669S INDICATEDFLOW - GPM ALERTRANGE ~ Area Inside R-5-6 ACITONRANGE ~ Area Outside 1-2-M

IST Program Plan 2nd 10- Year Interval WNP-2 Page 52 of 171 Revision 1 4.0 Valve Inservice Testin Pro 4.1 Introduction ASME OM Code requires periodic testing of certain safety related valves in order to verify their operability and leak tight integrity. The WNP-2 Valve Inservice Testing Program satisfies these requirements and conforms to FSAR commitments and Technical Specifications for ASME valve testing. The program establishes the requirements for preservice and inservice testing to assess the operational readiness of safety related valves. The Program is based on the requirements of the ASME/ANSI OM Standard, OMa-1988 Addenda, Part 10, "Inservice Testing of Valves in Light-Water Reactor Power Plants." The Program complies with the specifications of the approved Codes (1),

Regulations (2), and Generic Letters (3). This program includes those ASME valves which are required in shutting down the reactor to the cold shutdown condition, maintaining the cold shutdown condition, or mitigating the consequences of an accident.

The Code recognized that certain of its requirements may be impractical for a specific plant and contains provisions for requesting relief from impractical requirements. The relief requests for the Valve Inservice Testing Program (Section 4.8) identify testing impracticalities, provide technical basis for the request and propose alternate testing where warranted.

References:

1) ASME/ANSI OM Standard, OMa-1988 Addenda, Part 10, "Inservice Testing of Valves in Light-Water Reactor Power Plants."

2) 10CFR 50.55 a(f).

3) Generic Letter 89-04.

of IST Program Plan 2nd 10-Year Interval WNP-2 Page 53 Revision 171 1

4.2 Pro ram Im lementation 4.2.1 Preservice Testin Each valve shall be tested during the preservice test period. This testing shall be conducted under conditions as near as practicable to those expected during subsequent inservice testing. service testing applies only to newly added components.

4.2.2 I~i Inservice testing shall commence when the valves are required to be operable.

Surveillance testing is performed for each valve listed in the program, nominally every 3 months. For valves in systems. out of service (declared inoperable or not required to be operable), the test is performed prior to placing the system in an operable status and the test schedule msumed. The WNP-2 Valve Inservice Testing Program is implemented as part of the technical surveillance testing program. Active and passive valves in categories A, B, C, and D are tested in accordance with the requirements specified in Part 10, Table 1.

I 4.2.3 Reference Value Reference values are established and maintained in accordance with OM Part 10, paragraph 3.3. Baseline data for stmke times has been obtained from initial Valve Operability Tests. The limiting value(s) of full-stroke time of each power-operated valve is listed in the test procedures. Reference values are obtained from baseline tests or post maintenance tests. Many times the reference values are more accurately determined by an average of stroke times. This practice is in accordance with position 5 of GL 89-04.

4.2.4 Fail-Safe Valve Pail-safe testing is required only for those valves for which a fail-safe feature is a required safety function of the valve. Fail safe valves as identified by the valve test tables are tested by observing the operation of the actuator upon loss of valve electrical, pneumatic or hydraulic actuating power. In most cases, loss of electrical power causes loss of actuating fluid and can be accomplished using normal control circuits. Pail-safe testing is performed at the same frequency as the exercising test frequency of Part 10 paragraph 4.2.1.1.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 54 of 171 Revision 1 4.2.5 Valve Seat Leaka e Rate Test The category A valves identified in this program are seat leakage tested in accordance with the requirements of Part 10 paragraph 4.2.2. See Technical Position TV02.

4.2.6 Test Procedure Valves in the Valve Testing Program are tested according to detailed procedures.

The procedures include, as a minimum:

a) Statement of Test Purpose. This section identifies test objectives, references applicable Technical Specifications and notes the operating modes for which the test is appropriate.

b) Prerequisites for Testing. System valve alignment and additional instrumentation (e.g., stop watch) is noted. Identification numbers, range and calibration verification of additional instrumentation is ncorded.

c) Test Instructions. Directions are sufficiently detailed to assure completeness and uniformity of testing. Instructions include provisions for returning the system to its normal standby configuration following testing.

d) Acceptance Criteria. The ranges within which test data is considered acceptable have been established by the Supply System and included in the test procedure. In the event that the test data falls outside the acceptable ranges, corrective actions are taken in accordance with Code requirements.

e) Reference Values.

4.2.7 ~Tn:ndin Stroke times of power-operated valves are trended.

4.2.8 Safe Valve and Relief Valve Tests Safety and relief valves will meet the test requirements of OM Part l.

Finally, it is recognized that the Valve Inservice Testing Program sets forth minimum testing requirements. 'Additional testing. will be performed, as required, after valve maintenance, or as determined necessary by the Plant staff.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 55 of 171 Revision 1 4.3 Valve Test Tables The Valve Test Tables are the essence of the Supply System's Program for compliance with valve IST requirements. The Tables include active valves which are required to operate in order to safely shutdown the reactor, maintain it in the cold shutdown condition, or mitigate the consequences of an accident. Additionally, passive valves which require leak rate testing and valve position verification are also included. The Tables reflect the positions taken in support of the relief requests.

To aid in the interpretation of the Tables, brief explanations of the Table headings and abbreviations are provided.

(1) VALVE Each valve in the plant has a unique "tag" number. This is divided into'three parts. The first identifies the system to which the valve belongs (ie. RHR, HPCS, ..), the second part identifies

~

type of valve (flow control valve = FCV, relief valve = RV, rupture disc = RD, etc.), and the third part is serialized to insure each valve number is unique. A brief functional description of the valve is also provided.

(2) DWG & COORD The flow diagram drawing is identified along with the coordinates indicating where on the drawing the valve is located.

(3a) CLASS ASME Code Class per Section III of the ASME Boiler and Pressure Vessel Code.

1,2 or 3 = ASME Class 1, 2 or 3 D = Non-ASME (3b) CAT Valve categories A, B, C, and D are defined in accordance with Code requirements. Each valve has specific testing requirements which are determined by the category to which it belongs.

(4a) ACTUATOR Type The following abbreviations are used to describe actuator types.

Valves may be actuated in more than one way.

AO: '= Air operated HO ..=. Hydraulic operated MA = Manually operated MO = Motor operated SA = Self actuated SO = Solenoid operated

IST Program Plan 2nd 10-Year Interval WNP-2 Page 56 of 171 Revision 1 (4b) VALVEType The following abbreviations are used to describe valve type:

BA = Ball Valve RD Rupture Disc BF = Butterfly Valve RV Relief Valve CK = Check Valve SC Stopcheck Valve DI = Diaphragm Valve SR Safety/Relief Valve EX = Explosive Valve SV Solenoid Valve GB = Globe Valve 3W Three.Way Valve GT = Gate Valve (4c) SIZE Nominal pipe diameter to which the valve connects is given in inches.

(Sa) SAFIHY Position Safety position identifies the position(s) the valve must assume to fulfillits safety function(s).

C = Closed A NA = Not Applicable (ie. overpmssure protection devices, valves included at the Owner's discretion, or valves with no required safety position) 0 = Open 0/C = Both Open and Closed (Sb) FAIIZDPosition Failed position identifies the position the valve assumes upon loss of actuating power.

FAI = Fail As Is FC = Failed Close FO = Failed Open NA = Not Applicable.

(Sc) NORMAL Position Normal position identifies the valve position during normal power operation.'C

= Locked Close LO = Locked Open NC = Normally Closed NO = Normally Open NT = Normally Throttled

IST Program Plan 2nd 10- Year Interval WNP-2 Page 57 of Revision 171 1

(6a) TESTS This column lists a code corresponding to the test requirements applicable to that valve.

OM Part 10, Paragraph 4.1 Verify the accuracy of remote position indicators.

H OM Part 10, Paragraphs 4.2.1.2 or 4.3.2.2 (for check valves)

Full stroke exercise the valve to its required position.

OM Part 10, Paragraph 4.2.1.4 Measure. the stroke time of power operated valves.

OM Part 10, Paragraph 4.2.1.6 Testing valves with fail-safe actuators (fail-safe testing is required only for those valves for which the fail-safe feature is a required safety function of the valve).

OM Part 10, Paragraph 4.2.2 Valve seat leakage rate test.

P OM Part 10, Paragraph 4.3.1 Safety and relief valve test per OM Part 1 requirements.

OM Part 1 Vacuum Relief Setpoint Test OM Part 10, Paragraph 4.4.1 Explosively actuated valve test.

OM Part 10, Paragraph 4.4.2 Rupture discs shall meet the requirements for nonrcclosing pressure relief devices of OM Part 1.

IST Program Plan 2nd 10-Year Interval WNP-2 Page 58 of 171 Revision 1

, (6b) FREQUENCY This column identifies the required testing frequency.

~Le end ~Men nin CS Test performed during cold shutdowns but not mop frequently than once every 92 days. Valve testing shall commence within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after cold shutdown is'achieved and continue until complete .

or until the plant is ready to return to power.

Test explosive valve per OM Part 10 schedule.

Leakage rest per primary Containment Leakage Rate Testing Program (10 CFR 50 Appendix J, Option B)

N Not Applicable.

Test performed once every 92 days.

Test rupture disc per OM Part 1 schedule.

Test performed each refueling outage.

RV Test relief valve per OM Part 1 schedule.

TS Test performed per Technical Specification or Licensee Controlled Specification.

2Y Test performed once every two years.

Test performed semiannually.

18M Test performed every 18 months.

(6c) PPM This identifies the implementing procedure. This field is for information only and may be changed without formal amendment to the valve tables.

(7) TESTING EXCEPTIONS This field is used to identify any applicable Relief Requests (RVs), Refueling Outage Justifications (ROJs) or Cold Shutdown Justifications (CSJs).

(8) REMARK This field is used to provide reference to explanatory notes or Technical Positions located at the end of the Valve Test Tables.

Minor changes to the program via change notices may also be identified in this field.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 59 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg 4 Chss Exceptions (Notes h Valve EPN Coord S Cat Actuat, Safety, Tests, Frequency 4 PPM (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position)

& Size Normal CAC-RD-IA M554 2 SA NA N09 D12 D RD NA 2 NC DES CRIPI'ION CAC MOISTURE SEPARATOR &, AFTERCOOLER RUPTURE DISC CAC-RD-IB M554 2 SA NA N09 D4 D RD NA 2 NC 4

DESCRIPTION: CAC MOISTURE SEPARATOR & AFfERCOOLER RUFfURE DISC CAC RV-63A M554 2 SA NA P RV 7.4.0.5.20 TV03 E12 C RV NA I X2 NC DESCRIPTION: SW TO CAC-EV-IA RV CAC-RV-63B M554 2 SA NA P RV 7.4.0.5.20 TV03 E04 C RV NA I X2 NC DESCRIFfION: SW TO CAC-EV-IB RV CAC-RV-65A M554 2 SA NA P RV 7.4.0.5.20 TV03 D14 C RV NA 1.5 X 3 NC DESCRIFTION: CAC-EV-IA DISCH RV CAC-RV-65B M554 2 SA NA P RV 7.4.0.5.20 TV03

'V D4 C NA 15X3 NC DESCRIPI'ION: CAC-EV-IB DISCH RV CAC-TCV-4A M554 3 HO 0 H TS 7.4.6.6.1.3E N07 D12 B GB FO 2 NO DESCRIPTION: SW TO CAC-EV-IA TCV (SKID MOUNTED)

CAC-TCVAB M554 3 HO 0 H TS 7.4.6.6.1.3F N07 D5 B GB FO 2 NO DESCRIPTION: SW TO CAC-EV-IB TCV (SKID MOUNTED)

CAC-V-IA M554 2 HO 0 G 2Y 7.4.0.5.14A TVOI F15 B DI FC HJ Q ~ 7.4.0.5.14A 2 NC DESCRIPTION: CAC-AW-1A INLET CAC-V-IB M554 2 HO 0 G 2Y 7.4.0.5.14B TVOI F2 B DI FC HJ Q 7.4.0.5.14B 2 NC DESCRIP110N: CAC-AW-IB INLET CAC-V-2 M554 2 MO 0/C G 2Y 7.4.0.5.14A TV01,2 Glo A GT FAI HJ Q 7.4.0.5.14A 4 NC L J 7.4.6.1.

2.4 DESCRIPTION

CAC ISO TO PENETRATION X-96 (CIV)

CAC-V-2A M554 2 HO 0/C G 2Y 7.4.0.5.14A TVOI F12 B DI FC HJ Q 7.4.0.5.14A 2 NO DESCRIPTION: CAC RETURN

of IST Program Plan 2nd 10- Year Interval WNP-2 Page 61 Revision 171 1

WNP-2 Valve Test Tables Type Position Testmg Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, Reliefs) Position)

& Sixe Normal CAC-V-2B M554 2. HO 0/C G 2Y 7.4.0.5.14B TV01 F4 B DI FC HJ Q 7.4.0.5.14B 2 NO DESCRIPTION: CAC RETURN CAC-V-3A M554 2 HO 0/C H TS 7.4.6.6.1.3A N07 D12 B GB FC 0.7S NC DESCRIFTION: CAC-MS-IA DRN (SKID MOUNTED)

CAC-V-3B M554 2 HO 0/C H TS 7.4.6.6.1.3B N07 D4 B GB FC 0.75 NC DESCRIPTION: CAC-MS-1B DRN (SKID MOUNTED)

CAC-VA M554 2 MO 0/C G 2Y 7.4.0.5.14A TV01,2 Elo A GT FAl HJ Q 7.4.0.5.14A 4 NC L J 7.4.6.1.2.4 DESCRIFflON: CAC ISO TO PENETRATION X-102 (CIV)

CAC-V-6 M554 2 MO 0/C G 2Y 7.4.0.5. 14A TVOI)2 HIO A GT FAI HJ Q 7.4.0.5.14A 4 NC L J 7.4.6.1.2.4 DESCRIFTION: CAC ISO FROM PENETRATION X-99 (CIV)

CAC-V-8 M554 2 MO 0/C G 2Y 7.4.0.5.14A TV01,2 D10 A GT FAI HJ Q 7.4.0.5.14A 4 NC L J 7.4.6.1.2.4 DESCRIFIMN: CAC ISO FROM PENETRATION X-105 (CIV)

CAC-V-ll M554 2 MO 0/C G 2Y 7.4.0.5.14B TV01,2 G6 A GT FAI HJ Q 7.4.0.5.14B 4 NC L J 7.4.6.1.2.4 DESCRIFTION: CAC ISO TO PENEfRATION X-98 (CIV)

CAC-V-13 M554 2 MO 0/C G 2Y 7.4.0.5.14B TV01,2 E7 A GT FAI HJ Q 7.4.0.5.14B 4 NC L J 7.4.6.1.

2.4 DESCRIPTION

CAC ISO TO PENETRATION X-103 (CIV)

CAC-V-15 M554 2 MO 0/C G 2Y 7.4.0.5.14B TV01,2 H6 A GT FAI HJ Q 7.4.0.5.14B 4 NC L J 7.4.6.1.

2.4 DESCRIPTION

CAC ISO FROM PENEfRATION X-97 (CIV)

CAC-V-17 M554 2 MO 0/C G 2Y 7.4.0.5.14B TV01,2 D6 A GT FAI HJ Q 7.4.0.5.14B 4 NC L J 7.4.6.1.

2.4 DESCRIPTION

CAC ISO FROM PENETRATION X-104 (CIV)

CAS-V-29A MSIO-2 3 SA C HL RF 7.4.0.S.60 ROJ02 THRU D A AC CK NA J8 0.50 NC DESCRIFfiON: CAS TO MS-V-28A,B,C,D (MSIV) OPERATOR CHK CAS-V-730 MS 10-2 2 MA C L J 7.4.6.1.2.4 TV02 H12 A GB NA 1 LC DESCRIFI'ION: AIR LINE ISO FOR TESTING WW-DW VACUUM BRKRS (CIV)

IST Program Plan 2nd 10- Year Interval WNP-2 Page 62 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes tk Valve EPN Actuat, Safety, Tests, Frequency tk PPM Coord tk Cat (CSJ/ROJ/ Technical Valve Failed, Sc Sub Normal ReMs) Position)

CAS-VX-82E M510-2 2 MA C L J 7.4.6.1.2.4 TV02 H12 A GB NA I LC DESCRIPIMN: AIR LINE ISO FOR TESTING WW-DW VACUUM BRKRS (CIV)

CCH-RD-IA M775 3 SA NA N08 G8 D RD NA 3 NC DESCRIPTION: CCH PUMP SUCT LINE OVERPRESS PROTECTION CCH-RD-IB M775 3 SA NA N08 C7 D RD NA 3 NC DESCRIPTION: CCH PUMP SUCT LINE OVERPRESS PROTECTION CCH-RD-2A M775 3 SA NA N08 J13 D RD NA 2 NC DESCRIPIMN: RUPIURE DISC CCH-CU-IA REFRIGERANT CCH-RD-2B M775 3 SA NA N08 D13 D RD NA 2 NC DESCRIPTION: RUPTURE DISC CCH-CU-IB REFRIGERANT CEP-V-IA M543-I 2 AO C G 2Y 7.4.6.3.3 TV01,2 J13 A BF 30 'CFC , HJK L

DESCRIPTION: DRYWELL EXHAUST (CIV) 2Y 7.4.6.3.3 7.4.6.1.2.4 CEP-V-IB M543-I 2 AO C G 2Y 7.4.6.3.3 TV01,2 J13 A GI' FC HJK Q 7.4.6.3.3 2 NC L 2Y 7.4.6.1.

2.4 DESCRIPTION

CEP-V-IA BYPASS (CIV)

CEP-V-2A M543-I 2 AO C G 2Y 7.4.6.3.3 TV01,2 J13 A BF FC HJK Q 7.4.6.3.3 30 NC L 2Y 7.4.6.1.

2.4 DESCRIPTION

DRYWELL EXHAUST (CIV)

CEP-V-2B M543-I 2 AO C G 2Y 7.4.6.3.3 TV01,2 J13 A GT FC HJK Q 7.4.6.3.3 2 NC L 2Y 7.4.6.1.

2.4 DESCRIPTION

CEP-V-2A BYPASS (CIV)

CEP-V-3A M543-I 2 AO C G 2Y 7.4.6.3.3 TV01,2 C14 A BF FC HJK Q 7.4.6.3.3 24 NC L 2Y 7.4.6.1.2.4 SUPPRESSION CHAMBER EXHAUST (CIV) 'ESCRIPTION:

CEP-V-3B M543-I 2 AO C G 2Y 7.4.6.3.3 TV01,2 C14 A GT FC HJK Q

, 7.4.6.3.3 2 NC L 2Y 7.4.6. 1.

2.4 DESCRIPTION

CEP-V-3A BYPASS (CIV)

IST Program Plan 2nd 10- Year Interval WNP-2 Page 63 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testmg Remarks Valve EPN Dwg /k Chss Actuat, Safety, Tests, Frequency & PPM Exceptions (Notes 4 Coord h Cat Valve (CSJ/ROJ/ Technical Failed, Reliefs) Position) 4 Size Normal CEP-VAA M543-I 2 AO C G 2Y 7.4.6.3.3 TV01,2 C14 A BF FC HJK Q 7.4.6.3.3 24 NC L 2Y 7.4.6.1.

2.4 DESCRIPTION

SUPPRESSION CHAMBER EXHAUST (CIV)

CEP-V-4B M543-I 2 AO C G 2Y 7.4.6.3.3 TV01,2 C14 A GT FC HJK Q 7.4.6.3.3 2 NC L 2Y 7.4.6.1.2.4 DESCRIFI'ION: CEP-VAA BYPASS (CIV)

CIA-RV-SA M556-I 3 SA NA P RV 7.4.0.5.20 TV03 Hi I C RV NA

.75 X I NC DESCRIFHON: CIA TRAIN A NITROGEN HEADER RV CIA-RV-5B M556-I 3 SA NA P RV 7.4.0.5.20 TV03 Dl I C RV NA

.75 X I NC DESCRIFfION: CIA TRAIN B'ITROGEN HEADER RV CIA-SPV-IA M556-I 3 SO 0 HJK CS 7.4.0.5.23 CSJ09 N03 THRU 15A G12 B SV FO TVOI 0.50 NC DESCRIFIMN: CIA NITROGEN BOTI'LE AUTO ISO CIA-SPV- I B M556-I SO 0 HJK CS 7.4.0.5.23 CSJ09 N03 THRU 19B B12 SV FO TVOI 0.50 NC DESCRIFHON: CIA NITROGEN BOTILE AUTO ISO CIA-V-20 M556-I 2 MO C G 2Y 7.4.0.5.15 TV01,2 KS A GB FAI HJ Q 7.4.0.5.15 0.75 NO L J 7.4.6.1.

2.4 DESCRIPTION

NORMAL CIA SUPPLY TO CONTAINMENT(OTBD CIV)

CIA-V-21 M556-I 2 SA 0/C H RF 7.4.0.5.53 ROJ02 TV02 K6 AC CK NA HL RF 7.4.6.1.2.4 0.75 NO DESCRIFfION: NORMAL CIA SUPPLY TO CONTAINMENT CHK (INBD CIV)

CIA-V-24A M556-I 2 SA C HL RF 7.4.0.5.60 ROJ02 J5 AC CK NA 0.50 NC DESCRIFfiON: CIA TO MS-V-22A (MSIV) OPERATOR CHK CIA-V-24B M556-I 2 SA C HL RF 7.4.0.5.60 ROJ02 J4 AC CK NA 0.50 NC DESCRIFHON: CIA TO MS-V-22B (MSIV) OPERATOR CHK CIA-V-24C M556-I 2 SA C HL RF 7.4.0.5.60 ROJ02 KS AC CK NA 0.50 NC DESCRIPTION: CIA TO MS-V-22C (MSIV) OPERATOR CHK CIA-V-24D M556-I 2 SA C HL RF 7.4.0.5.60 ROJ02 K4 AC CK NA 0.50 NC DESCRIFHON: CIA TO MS-V-22D (MSIV) OPERATOR CHK

bl IST Program Plan 2nd 10-Year Interval WNP-2 Page 64 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg tk Class Exceptions (Notes tk Valve EPN Actuat, Safety, Tests, Frequency tk PPM Coord tk Cat (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position) tk Size Normal CIA-V-30A M556-I 2 MO 0/C G 2Y 7.4.0.5.15 TV01,2 G9 A GB FAI HJ Q 7.4.0.5.15 0.50 NO L J 7.4.6.1.

2.4 DESCRIPTION

CIA SUPPLY TO 3 ADS ACCUMULATORS ISO (CIV)

CIA-V-30B M556-I 2 MO 0/C G 2Y 7.4.0.5.15 TV01,2 F8 A GB FAI HJ Q 7.4.0.5.15 0.50 NO L J 7.4.6.1.2.4 DESCRIFflON: CIA SUPPLY TO 4 ADS ACCUMULATORS ISO (CIV)

CIA-V-31A M556-I 2 SA 0/C H RF 7.4.0.5.53 ROJ02 TV02 G7 AC CK NA HL RF 7.4.6.1.2.4 0.50 NO DESCRIPTION: CIA SUPPLY TO 3 ADS ACCUMULATORS CHK (INBD CIV)

CIA-V-31B M556-I 2 SA 0/C H RF 7.4.0.5.53 ROJ02 TV02 F7 AC CK NA HL RF 7.4.6.1.2.4 0.50 NO DESCRIPTION: CIA SUPPLY TO 4 ADS ACCUMULATORS CHK (INBD CIV)

CIA-V-39A M556-I - 3 AO C G 2Y 7.4.0.5.23 CSJ05 TVOI JIO B BA FC HJK CS 7.4.0.5.23 0.50 NO DESCRIPTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER ISO CIA-V-39B M556-I 3 AO C G 2Y 7.4.0.5.23 CSJ05 TVOI EIO B BA FC HJK CS 7.4.0.5.23 0.50 NO DESCRIFTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER ISO CIA-VENOM M556-I 2 SA 0/C HL RF 7.4.0.5.53 ROJ02 (TYP 7) B5 AC CK NA 0.50 NO DESCRIFriON: CIA TO ADS ACCUMULATOR CHK CIA-V-41A M556-I 3 SA C H CS 7.4.0.5.23 CSJ05 JIO C CK NA 0.50 NO DESCRIPTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER CHK CIA-V<I B M556-I 3 SA C H CS 7.4.0.5.23 CSJ05 DIO C CK NA 0.50 NO DESCRIPTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER CHK CIA-V-52A M556- I 3 SA 0 H CS 7.4.0.5.23 CSJ09 THRU 66A G12 C CK NA 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH CHK CIA-V-52B M556-1 3 SA 0 H CS 7.4.0.5.23 THRU 70B C12 C CK NA 0.50 NC DESCRIFfION: CIA NITROGEN BOTTLE DISCH CHK CIA-V-103A M556-I 3 SA 0 H CS 7.4.0.5.23 CSJ09 H13 C CK NA 0.50 NC DESCRIFHON: CIA NITROGEN BOTI'LE DISCH CHK

'l gl

IST Program Plan 2nd 10- Year Interval WNP-2 Page 65 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Valve EPN Dwg & Class Exceptions (Notes &

Actuat, Safety, Tests, Frequency & PPM Coord & Cat (CSJ/ROJ/ Technical Valve Failed, ReBefs) Position)

& Size Normal CIA-V-103B M556-I SA 0 H CS 7.4.0.5.23 D12 CK NA O.SO NC DESCRIPTION: CIA NITROGEN BOTILE DISCH CHK CIA-V-104A M556-I 3 MA 0 H CS 7.4.0.S.23 H13 B GB NA O.SO NC DESCRIPTION:- CIA NITROGEN BOTILE DISCH MAN ISO CIA-V-104B M556-I 3 MA 0 H CS 7.4.0.5.23 D12 B GB NA 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH MAN ISO CRD-V-10 M528-1 2 AO C G 2Y 7.4.1.3.1.1B TVOI K6 B GB FC HJK Q 7.4.1.3.1.1B 1

I NO DESCRIPflON: SCRAM DISCH VOLUME VENT CRD-V-11 M528-I 2 AO C G 2Y 7.4.1.3.1.1B TVOI F7 B GB FC'JK Q '.4.1.3.1.1B 2 NO DESCRIPTION: SCRAM DISCH VOLUME DRN CRD-V-114 M528-I D SA 0 H TS 7.4.1.3.2 NOS (TYP 185) B13 C CK NA 0.75 NC DESCRIPrlON: HCU TO SCRAM DISCH HEADER CHK CRD-V-115 M528-1 D SA C H TS 7.4.1.3.5 3 NOS (TYP 185) B14 C CK NA I NC DESCRIPTION: CHARGING WATER TO HCU CHK CRD-V-126 M528-I D AO 0 H TS 7.4.1.3.2 NOS (TYP 185) C4 B DI FO I NC DESCRIPTION: HCU CONT-ROD INSERT WATER SCRAM VLV CRD-V-127 M528-1 D AO 0 H TS 7.4.1.3.2 NOS (TYP 185) C3 B DI FO 0.75 NC DESCRIPTION: HCU CONT-ROD WITHDRAWALWATER SCRAM VLV CRD-V-138 M528-1 D SA C H Q 7.4.1.3.1.2 NOS (TYP 185) C4' CK NA 0.75 NO DESCRIPTION: COOLING WATER TO HCU CHK CRD-V-180 M528-I 2 AO C G 2Y 7.4.1.3.1.1B TVOI K6 B GB FC HJK Q 7.4.1.3.1.1B I NO DESCRIPTION: SCRAM DISCH VOLUME VENT CRD-V-181 M528-1 'AO C G 2Y 7.4.1.3.1.1B TVOI F6 GB FC HJK Q 7.4.1.3.1. IB 2 NO DESCRIPTION: SCRAM DISCH VOLUME DRN

IST Program Plan 2nd 10-Year Interval WNP-2 Page 66 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Valve EPN Dwg & Chss Exceptions (Notes &

Coord & Cat Actuat, Safety, Tests, Frequency & PPM (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position)

& Size Normal CSP-RV-51 M619- 2 SA NA . P RV 7.4.0.5.20 TV03 161 C RV NA

.75 X I NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY HEADER TO CSP-V-5,6,9 RV CSP-RV-52 M619- 2 SA NA P RV 7.4.0.5.20 TV03 161 C RV NA

& Size Normal CSP-V-10 M543-I 2 AOISA 0/C G 6M 7.4.6.4.2.6 N02

'C6 AC CK NA H 7.4.6.4.2.6 TV02 Q

24 NC L 2Y 7.4.6.1.2.4 S 6M 7.4.6.4.2.3 DESCRIPfiON: VACUUM RELIEF (CIV)

CSP-V-65 M619- 2 SA C HL RF 7.4.0.5.61 ROJ09 161 AC CK NA 1.50 NC DESCRIPfiON: CONTROL AIR CHK TO CIVs, ISOLATES SR FROM NSR AIR CSP-V-70 M619- 2 SA 0 H RF 7.4.0.5.61 ROJ09 161 C CK NA I NC DESCRIPfION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-71 M619- 2 SA 0 H RF 7.4.0.5.61 ROJ09 161 C CK NA 1 NC DESCRIPflON: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-72 M619- 2 SA 0 H RF 7.4.0.5.61 ROJ09 161 C CK NA I NC DESCRIPIMN: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-73 M619- 2 SA 0 H RF 7.4.0.5.61 ROJ09 161 C CK NA I NC DESCRIPfiON: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-74 M619- 2 SA 0 H RF 7.4.0.5.61 ROJ09 161 C CK NA I NC DESCRIPfiON: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-75 M619- 2 SA 0 H RF 7.4.0.5.61 ROJ09 161 C CK NA I NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-76 M619- ~ 2 SA 0 H RF ~

7.4.0.S.61 ROJ09 161 C CK NA I NC DESCRIPfION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-77 M619- 2 SA 0 H RF 7.4.0.5.61 ROJ09 161 C CK NA I NC DESCRIPIMN: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-78 M619- 2 SA 0 H RF 7.4.0.5.61 ROJ09 161 C CK NA I NC DESCRIPIMN: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-79 M619- 2 SA 0 H RF 7.4.0.5.61 ROJ09 161 C CK NA I NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-S,6,9

IST Program Plan 2nd 10- Year Interval WNP-2 Page 68 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Valve EPN Dwg 4 Class 4 PPM Exceptions (Notes 4 Coord 4 Cat Actuat, 'Safety, Tests, Frequency (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position) h Sixe Normal CSP-V-93 M783 2 SO C HJK Q 7.4.6.3.3 TV01,2 FS A SV FC GL TS 7.4.6.1.2.4 I NO DESCRIFHON: CONTAINMENTN2 SUPPLY (CIV)

CSP-V-96 M783 2 SO C HJK Q 7.4.6.3.3 TV01,2 H4 A SV FC GL TS 7.4.6.1.2.4 I NO DESCRIFHON: CONTAINMENT N2 SUPPLY (CIV)

CSP-V-97 M783 2 SO C HJK Q 7.4.6.3.3 TV01,2 H4 A SV FC GL TS 7.4.6.1.2.4 I NO DESCRIFrION: CONTAINMENTN2 SUPPLY (CIV)

CSP-V-98 M783 2 SO C HJK Q 7.4.6.3.3 TV01,2 FS A SV FC GL TS 7.4.6.1.2.4 1 NO DESCRIFIMN: CONTAINMENTN2 SUPPLY (CIV)

CVB-V-IAB M543-I 2 AO,SA OIC GS 2Y 7.4.6.4.1.3 RVOI N02 B13 AC CK NA H Q 7.4.6.4.1.2 TVOS 24 NC L 2Y 7.4.6.2.1 DESCRIFI'ION: VACUUM RELIEF TO DRYWELL CVB-V-ICD M543-I 2 AO,SA 0/C GS 2Y 7.4.6.4.1.3 RVOI N02 C12 AC CK NA H ~

Q 7.4.6.4.1.2 TVOS 24 NC L 2Y 7.4.6.2.1 DESCRIFHON: VACUUM RELIEF TO DRYWELL CVB-V-IEF M543-1 B12 'C 2 AO,SA CK OIC GS NA H 2Y Q

7.4.6.4.1.3 7.4.6.4.1.2 RVOI N02 TVOS 24 NC L 2Y 7.4.6.2.1 DESCRIFIION: VACUUM REUEF TO DRYWELL CVB-V-IGH M543-I 2 AO,SA OIC GS 2Y 7.4.6.4.1.3 RVOI N02 Bl I AC CK NA H Q 7.4.6.4.1.2 TVOS 24 NC L 2Y 7.4.6.2.1 DESCRIFfiON: VACUUM RELIEF TO DRYWELL CVB-V-IJK M543-I 2 AO,SA 0/C GS 2Y 7.4.6.4.1.3 RVOI N02 B9 AC CK NA H Q 7.4.6.4.1.2 TVOS 24 NC L 2Y 7.4.6.2.1 DESCRIFI'ION: VACUUM RELIEF TO DRYWELL CVB-V-ILM M543-I 2 AO,SA 0/C GS 2Y 7.4.6.4.1.3 RVOI N02 B8 AC CK NA H Q 7.4.6.4.1.2 TVOS 24 NC L 2Y 7.4.6.2.1 DESCRIFI10N: VACUUM RELIEF TO DRYWELL CVB-V-INP M543-I 2 AO,SA 0/C GS 2Y 7.4.6.4.1.3 RVOI N02 B8 AC CK NA H Q 7.4.6.4.1.2 TVOS 24 NC L 2Y 7.4.6.2.1 DESCRIFI'ION: VACUUM RELIEF TO DRYWELL CVB-V-1QR M543-I 2 AO,SA 0/C GS 2Y 7.4.6.4.1.3 RVOI N02 B7 AC CK NA H Q 7.4.6.4.1.2 TVOS 24 NC L 2Y 7.4.6.2.1 DESCRIFIION: VACUUM RELIEF TO DRYWELL

IST Program Plan 2nd 10-Year Interval WNP-2 Page 69 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Coord & Cat (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position)

& Size Normal CVB-V-1ST M543-I 2 AO,SA 0/C GS 2Y 7.4.6.4.1.3 RVOI N02 B7 AC CK NA H Q 7.4.6.4.1.2 TVOS 24 NC L 2Y 7.4.6.

2.1 DESCRIPTION

VACUUM RELIEF TO DRYWELL DO-V-IA M512< 3, SA 0 H Q 7.4.0.5.1 J12 C CK NA 1.50 NC DESCRIPIMN: DO-P-IA (TRANSFER PUMP) TO DAY TANK DISCH CHK DO-V-IB M512< 3 -

SA 0 H Q 7.4.0.5.2 F12 C CK NA 1.50 NC DESCRIPTION: DO-P-IB (TRANSFER PUMP) TO DAY TANK DISCH CHK DO-V-10 MS 12< 3 SA 0 H Q 7.4.0.5.3 Dl C CK NA 1.50 NC DESCRIPTION: DO-P-2 (TRANSFER PUMP) DISCH CHK DSA-SPV- M512-2 D SO 0/C H N 8.3.126 N06 5AI/2 FIO B 3W FAI 2 NC DESCRIPIMN: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA4P- M512-2 D SO 0/C H N 8.3.126 N06 VSA/4 EIO B 3W FAI 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV- M512-2 D SO OIC H N 8.3.126 N06 SA2I2 F6 B 3W FAI 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV- M512-2 D SO OIC H N 8.3.126 SA2/4 E6, B 3W FAI 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SP- M512-3 D SO 0/C H N 8.3.128 N06

,VSB/2 FIO B 3W FAI 2 NC DESCRIPriON: DSA TO EDG START MOTORS BYPASS/VENT VLV DSASPV- M512-3 D SO 0/C H N 8.3.128 N06 SBI/4 EIO B 3W FAI 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPY- M512-3 D SO 0/C H N 8.3.128 N06 SB2I2 F6 B 3W FAI 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV- M512-3 D 'SO 0/C H N 8.3.128 N06 SB2I4 E6 B 3W FAI 2 NC DESCRIPHON: DSA TO EDG START MOTORS BYPASS/VENT VLV

IST Program Plan 2nd 10- Year Interval WNP-2 Page 70 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Chss Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Coord & Cat (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position)

& Size Normal DSA-SPV- M512-1 D SO 0 H N 8.3.129 N06 SCI/I F9 B 3W FAI I.SO NC DESCRIPTION: DSA TO EDG START MOTORS ISO DSA-SPV- M512-1 D SO 0 H N 8.3.129 N06 5C1/2 F9 B 3W FAI 1.50 NC DESCRIPTION: DSA TO EDG START MOTORS ISO DW-V-156 M517 2 MA C L J 7.4.6.1.2.4 TV02 G8 A GT NA 2 LC DESCRIPTION: DEMIN WATER TO CONTAINMENTISO (OTBD CIV)

DW-V-157 M517 2 MA C L J 7.4.6.1.2.4 G8 A GT NA 2 LC DESCRIPTION: DEMIN WATER TO CONTAINMENTISO (INBD CIV)

EDR-V-19 M537 2 AO C G 2Y 7.4.0.5.6A TV01,2 D9 A GT FC HJK Q 7.4.0.5.6A 3 NO L J 7.4.6.1.

2.4 DESCRIPTION

EDR ISO FROM DRYWELL SUMP (CIV)

EDR-V-20 M537 2 AO C G 2Y 7.4.0.5.6A TV01,2 D9 A GT FC HJK Q 7.4.0.5.6A 3 NO L J 7.4.6.1.

2.4 DESCRIPTION

EDR ISO FROM DRYWELL SUMP (CIV)

FDR-V-3 M539 2 AO C G 2Y 7.4.0.5.6B TV01,2 D6 A BA FC HJK Q 7.4.0.5.6B 3 NO L J 7.4.6.1.

2.4 DESCRIPTION

FDR ISO FROM DRYWELL FDRNUMP-3 (CIV)

FDR-V-4 M539 2 AO C G 2Y 7.4.0.5.6B TV01,2 D6 A BA FC HJK Q 7.4.0.5.6B 3 NO L J 7.4.6.1.2.4 DESCRIPI1ON: FDR ISO FROM DRYWELL FDRSUMP-3 (CIV)

FPC-FCV-I M526 3 AO 0 G 2Y 7.4.0.5.4 TVOI C9 B GB FO HJK Q 7.4.0.5.4 4X6 NC DESCRIP110N: FPC DEMINERALIZERBYPASS FCV FPC-RV-117A M526 3 SA NA P RV 7.4.0.S.20 TV03

, Dll C RV NA 0.75, NC DESCRIFfION: FPC-HX-IA RV FPC-RV-117B M526 3, SA NA P RV 7.4.0.S.20 TV03 Cl I C RV NA 0.75 NC DESCRIPTION: FPC-HX-1B RV FPC-V-112A M526 3 'A 0/C H Q 7.4.0.5.4 D13 C CK NA 6 NC DESCRIPTION: FPC-P-1A DISCH CHK

IST Program Plan 2nd 10-Year Interval WNP-2 Page 71 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Coord & Cat (CSJ/ROJ/ Technical Valve Failed,

' Reliefs) Position)

Slee Normal FPC-V-112B M526 3 SA 0/C H Q 7.4.0.5.4 C13 C CK NA 6 NC DESCRIPTION: FPC-P-IB DISCH CHK FPC-V-127 M526 3 SA 0/C H Q 7.4.0.5.4 E9 C CK NA 2 NC DESCRIFriON: SW TO FPC CHK FPC-V-140 M526 3 SA C H Q 7.4.0.5.4 C9 C CK NA 8 NO DESCRIPTION: FPC DEMIN EFF CHK FPC-V-146A M526 3 SA 0 H Q 7.4.0.5.4 Jl I C CK NA 8 NO DESCRIPTION: FPC TO FUEL POOL CHK FPC-V-146B M526 3 SA 0 H Q 7.4.0.5.4 JIO C CK NA 8 NO DESCRIPTION: FPC TO FUEL POOL CHK FPC-V-149 M526 2 MO C G 2Y 7.4.0.5.4 TV01,2 D9 A GT FAI HJ =

Q 7.4.0.5.4 6 NC L J 7.4.6.1.2.4 DESCRIFHON: FPC TO SUPPRESSION POOL ISO (CIV)

FPC-V-153 M526 2 MO C G 2Y 7.4.0.5.4 TV01,2 Bl I A GT FAI HJ Q 7.4.0.5.4 6 NC L 2Y 7.4.6.1.

2.9 DESCRIPTION

SUPPRESSION POOL TO FPC-P-3 SUCT (CIV)

FPC-V-154 M526 2 MO C G 2Y 7.4.0.5.4 TV01,2 Bl 1 A GT FAI HJ Q 7.4.0.5.4 6 NC L 2Y 7.4.6.1.2.9 DESCRIPriON: SUPPRESSION POOL TO FPC-P-3 SUCT (CIV)

FPC-V-IS6 MS26 2 MO C G 2Y 7.4.0.5.4 TV01,2 CI I A GT FAI HJ Q 7.4.0.5.4 6 NC L J 7.4.6.1.2.4 DESCRIPIION: FPC TO SUPPRESSION POOL ISO (CIV)

FPC-V-172 MS26 MO C G 2Y 7.4.0.5.4 TVOI C9 FAI HJ Q 7.4.0.5.4 8 NO DESCRIFrlON: FPC TO SUPPRESSION POOL ISO FPC-V-173 M526 MO C G 2Y 7.4.0.5.4 TV01 C8 GT FAI HJ Q 7.4.0.S.4 8 . NO DESCRIPTION: FPC INFLUENT TO DEMIN ISO FPC-V-175 0 M526 CIO B 3

Gl'AI MO 8 NC G

HJ 2Y Q

7.4.0.5.4 7.4.0.5.4 TVOI DESCRIFfiON: FPC FLTR DEMIN BYPASS

IST Program Plan 2nd 10- Year Interval WNP-2 Page 72 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Coord & Cat (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position)

& Sixe Normal FPC-V-181A M526 3. MO 0 G 2Y 7.4.0.5.4 TVOI E14 B GT FAI Passive 8 NO DESCRIPllON: FPC-P-I A SUCT FPC-V-181B M526 3 MO 0 G 2Y 7.4.0.5.4 TV01 D14 B GT FAI Passive 8 NO DESCRIPTION: FPC-P-IB SUCI'O FPC-V-184'526 3 C G 2Y 7.4.0.5.4 TVOI C9 B GT FAI HJ Q 7.4.0.5.4 8 NO DESCRIFIlON: FPC FILTER DEMIN EFFLUENT ISO HPCS-RV-14 M520 2 SA NA P RV 7.4.0.5.20 TV02,3

'6 AC RV NA L J 7.4.6.1.2.1 I X1 NC DESCRIPTION: HPCS-P-3 SUCT RV (CIV)

H PCS-RV-35 M520 2 ,SA NA P RV 7.4.0.5.20 TV02,3 CS AC RV NA L J 7.4.6.1.2.1 I.5 X 2 NC DESCRIPTION: HPCS-P-3 DISCH RV (CIV)

HPCS-V-I M520 2 MO 0/C G 2Y 7.4.5.1.11 TVOI C7 B GT FAI HJ Q 7.4.5.1.11 14 NO DESCRIPTION: CST TO HPCS-P-I SUCT HPCS-V-2 M520 2 SA 0/C H Q 7.4.5.1.11 C6 C CK NA 20 NC DESCRIPTION: CST TO HPCS-P-I SUCT CHK H PCS-VA M520 I MO 0/C G 2Y 7.4.5.1.11 TV01,2 G7 A GT FAI HJ Q 7.4.S.I. I I 12 NC L 18M 7.4.4.3.

2.2 DESCRIPTION

HPCS TO RPV ISO (OTBD CIV)

HPCS-V-5 M520 I SA 0/C H RF 7.4.0.5.7E ROJ08 TV02 H8 AC CK NA HL RF 7.4.4.3.2.2 12 NC DESCRIPTION: HPCS TO RPV ISO (INBD CIV)

HPCS-V-6 M520 2 SA,MA C H Q 7.4.5.1.11 RV02 CS C SC NA 1.50 NO DES CRIFilON: HPCS-P-3 (WATER LEG) DISCH STOP CHK HPCS-V-7 M520 2 SA C H Q 7.4.5.1.11 RV02 CS C CK NA 8 1.50 NO DESCRIPTION: HPCS-P-3 (WATER LEG) DISCH CHK HPCS-V-10 M520 2 MO C G 2Y 7.4.5.1.11 TV01 E3 B GB FAI HJ Q 7.4.5.1.11 10 NC DES CRIFrION: HPCS TO CST ISO

IST Program Plan 2nd 10-Year Interval WNP-2 Page "73 of 171'evision 1

WNP-2 Valve Test Tables Type PosMon Testmg Remarks Valve EPN Dwg & Class Exceptions (Notes &

Actuat, Safety, Tests, Frequency & PPM Coord & Cat (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position)

& Sixe Normal HPCS-V-11 M520 2 MO C G 2Y 7.4.5.1.1 I TVOI E3 B GB FAI HJ Q 7.4.5.1.11 10 NC DESCRIFI10N: HPCS TO CST ISO HPCS-V-12 M 520 2 MO 0/C G 2Y 7.4.5.1.11 TV01,2 BS A GT FAI HJ Q 7.4.5.1.11 4 NC L J 7.4.6.1.2.4 DES CRIPI10N: HPCS-P-1 MINIMUMFLOW VLV (CIV)

HPCS-V-15 M520 2 MO 0/C G 2Y 7.4.5.1.11 TV01,2 D7 A GT FAI HJ Q 7.4.5.1.11 18 NC L 2Y 7.4.6.1.2.9 DES CRIFI10N: SUPPRESSION POOL TO HPCS-P-I SUCT (CIV)

HPCS-V-16 M520 2 SA 0 H Q 7.4.5.1.11 D6 C CK NA 24 NC DES CRIF110N SUPPRESSION POOL TO HPCS-P-1 SUCT CHK HPCS-V-23 M520 2 MO ES A GB 'AI C G HJ 2Y Q

7.4.5.1.11 7.4.5.1.11 TV01,2 12 NC L J 7.4.6.1.

2.4 DESCRIPTION

HPCS TEST LINE TO SUPPRESSION POOL ISO (CIV)

H PCS-V-24 M520 2 SA 0/C H 7.4.5.1.11 Q

B4 C CK NA 16 NC DESCRIPTION: HPCS-P-1 DISCH CHK HPCS-V-28 MS24-1 3 SA 0 H 7.4.0.5.18 Q

G6 C CK NA 8 NC DES CRIPriON: HPCS-P-2 (SERVICE WATER) DISCH CHK HPCS-V-65 M520 2 MA C L J 7.4.6.1.2.4 TV02 H7 A GB NA I LC DES CRIF110N: AIR TO HPCS-V-5 OPERATOR (INBD CIV)

H PCS-V-68 M520 2 MA C L J 7.4.6.1.2.4 TV02 H7 A GB NA I LC DESCRIF110N: AIR TO HPCS-V-5 OPERATOR (OTBD CIV)

LPCS-FCV-11 M520 2 MO 0/C G 2Y 7.4.5.1.7 TV01,2 B13 A GB FAI HJ Q 7.4.5.1.7 3 NC L J 7.4.6.1.2.4 DES CRIPI10N: LPCS-P-I MINIMUMFCV (CIV)

LPCS-RV-18 M520, 2 SA NA P RV 7.4.0.5.20 TV02,3 G12 AC RV NA L J 7.4.6.1.2.1 I 5X2 NC DES CRIPI10N: LPCS-P-I RV (CIV)

LPCS-RV-31 M520 2 SA NA P RV 7.4.0.S.20 TV02,3 C12 AC RV NA L J 7.4.6.1.2.1 IXI NC DES CRIFIMN: LPCS-P-2 SUCT RV (CIV)

74 of 171 IST Program Plan 2nd 10- Year Interval WNP-2 Page Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, Reliefs) Position)

& Size Normal LPCS-V-I M520 2 MO 0/C G 2Y 7.4.5.1.7 TV01,2 Dl I A GT FAI HJ Q 7.4.5.1.7 24 NO L 2Y 7.4.6.1.2.9 DESCRIFHON: SUPPRESSION POOL TO LPCS-P-I SUCT (CIV)

LPCS-V-3 M520 2 SA 0/C H Q 7.4.5.1.7 B13 C CK NA 16 NC DESCRIPTION: LPCS-P-I DISCH CHK LPCS-V-5 M520 I MO 0/C G 2Y 7.4.0.5.8B CSJ08 TV01,2 Gl I A GT FAI HJ CS 7.4.0.5.8B 12 NC L 18M 7.4.4.3.

2.2 DESCRIPTION

LPCS TO RPV ISO (OTBD CIV)

LPCS-V-6 M520 I SA 0/C H RF 7.4.0.5.7D ROJ08 TV02 G9, AC CK NA HL RF 7.4.4.3.2.2 12 NC DESCRIPTION: LPCS TO RPV ISO CHK (INBD CIV)

LPCS-V-12 M520 2 MO C G 2Y 7.4.5.1.7 TV01,2 E14 A GB FAI HJ Q 7.4.5.1.7 12 NC L J 7.4.6.1.2.4 DESCRIFI'ION: LPCS TEST LINE TO SUPPRESSION POOL ISO (CIV)

LPCS-V-33 M520 2 SA C H Q 7.4.5.1.7 RV02 C12 C CK NA 1.50 NO DESCRIFHON: LPCS-P-2 (WATER LEG) DISCH CHK LPCS-V-34 M520 2 SA,MA C H Q 7.4.5.1.7 RV02 C13 C SC NA 1.50 NO DESCRIPTION: LPCS-P-2 (WATER LEG) DISCH STOP CHK LPCS-V-66 M520 2 MA C L J 7.4.6.1.2.4 TV02 HIO A GB NA I LC DESCRIPTION: AIR TO LPCS-V-6 OPERATOR (INBD CIV)

LPCS-V-67 M520 2 MA C L J 7.4.6.1.2.4 HIO A GB NA I LC DESCRIPTION: AIR TO LPCS-V-6 OPERATOR (OTBD CIV)

MS-RV-IA M529 AO,SA NA G 2Y 7.4.4.2.1.3 RV05 TV03 FI I SR NA P RV 7.4.0.5.55 6X 10 NC 7.4.0.5.62 7.4.0.5.63 DESCRIPTION MAIN S TEAM SAFETY RV MS-RV-IB M529 I AO,SA NA G 2Y 7.4.4.2.1.3 RV05 TV03 Dl I C SR NA P RV 7.4.0.5.55 6X 10 NC 7.4.0.5.62 7.4.0.5.63 DESCRIPTION: MAIN STEAM SAFETY RV

4 of IST,Program Plan 2nd 10-Year Interval WNP-2 Page 7S Revision 1'?1 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, ReIiefs) Position)

& Sixe Normal MS-RV-1C MS29 1 . AO,SA NA G 2Y 7.4.4.2.1.3 RVOS TV03 F6 C SR NA P RV 7.4.0.5.55 6X 10 NC 7.4.0.5.62 7.4.0.5.63 DESC RIPTION: MAIN S RV MS-RV-1D MS29 AO,SA NA G 2Y 7.4.4.2.1.3 RVOS TV03 E7 SR NA P RV 7.4.0.5.55 6X 10 NC. . 7.4.0.5.62 7.4.0.5.63 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-2A = M529 1 AO,SA NA G 2Y 7.4.4.2.1.3 RVOS TVQ3 FIO C SR NA P RV 7.4.0.5.55 6 X 1Q NC 7.4.0.5.62 7.4.0.5.63 DES CRIP11ON MAIN S TEAM SAFETY RV MS-RV-2B M529 I AO,SA NA G 2Y 7.4.4.2.1.3 RVOS TV03 DIO C SR NA P RV 7.4.0.5.55 6X 10 NC 7.4.0.5.62 7.4.0.5.63 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-2C M529 1 AOISA NA G 2Y 7.4.4.2.1.3 RVOS TV03 F? C SR NA P RV 7.4.0.5.55 6X 10 NC 7.4.0.5.62 7.4.0.5.63 DESCRIPTION MAIN S TEAM SAFETY RV MS-RV-2D M529 I AO,SA NA G 2Y 7.4.4.2.1.3 RVOS TV03 E? C SR NA P RV 7.4.0.5.55 6X 10 NC 7.4.0.5.62 1.4.0.5.63 DESCRIPTION MAIN S TEAM SAFETY RV MS-RV-3A M529 I AO,SA NA G 2Y 7.4.4.2.1.3 RVOS TV03 F9 C SR NA P RV 7.4.0.5.55 6 X 10 NC 7.4.0.5.62 7.4.0.5.63 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-3B M529 1 AO,SA NA G 2Y 7.4.4.2.1.3 RVOS TV03 D10 C SR NA P RV 7.4.0.5.55 6 X 10 NC 7.4.0.5.62 7.4.0.5.63 DESCRIPTION MAIN S RV MS-RV-3C MS29 I AO,SA NA G 2Y 7.4A.2.1.3 RVOS TV03 E7 C SR NA P RV 7.4.0.5.55 6X 10 NC 7.4.0.5.62 7.4.0.5.63 DESCRIPI1ON: MAIN STEAM SAFETY RV

IST Program Plan 2nd 10- Year Interval WNP-2 Page 76 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Valve EPN Dwg tk Class Actuat, Safety, Tests, Frequency tk PPM Exceptions (Notes 4 Coord a Cat Valve (CSJ/ROJ/ Technical Failed,

& Size Normal Rehefs) Position)

MS-RV-3D M529 I AO,SA 0 GHJ RF 7.4.4.2.1.2 ROJOS TV01,3 E8 BC SR NA P RV 7.4.0.5.55 RVOS 6X 10 NC 7.4.0.5.62 7.4.0.5.63 DESC RIFfION MAIN S ADS SAFETY RV MS-RV-4A M529 I AO,SA 0 GHJ RF 7.4.4.2.1.2 ROJOS TV01,3 F9 BC SR NA P RV 7.4.0.5.55 RVOS 6 X 10 NC 7.4.0.5.62 7.4.0.5.63 DESC RIPfiON: MAIN S TEAM & ADS SAFEIY RV MS-RVAB M529 I AO,SA 0 GHJ RF . 7.4.4.2.1.2 ROJOS TV01,3 D9 BC SR NA P RV 7.4.0.5.55 RVOS 6 X 10 NC 7.4.0.5.62 7.4.0.5.63 DESC RIPTION MAIN S ADS SAFEIY RV MS-ROC M529 I AO,SA 0 GHJ RF 7.4.4.2.1.2 ,ROJOS TV01,3 F8 BC SR NA P RV 7.4.0.5.55 RVOS 6X IO NC 7.4.0.5.62 7.4.0.5.63 DESCRIPTION MAIN STEAM 8c ADS SAFETY RV MS-RVAD M529 I AO,SA 0 GHJ RF 7.4:4.2.1.2 ROJOS TV01,3 E8 BC SR NA P ~ RV 7.4.0.5.55 RVOS 6 X 10 NC 7.4.0.5.62 7.4.0.5.63 DESC RIFfION MAIN STEAM ADS SAFETY RV MS-RV-SB M529 I AO,SA 0 GHJ RF 7.4.4.2.1.2 ROJOS TV01,3 E9 BC SR NA P RV 7.4.0.5.55 RVOS 6X 10 NC 7.4.0.5.62 7.4.0.5.63 DESC RIPfiON MAIN S ADS SAFETY RV MS-RV-SC M529 I AO,SA 0 GHJ RF 7.4.4.2.1.2 ROJOS TV01,3 F8 BC SR NA P RV 7.4.0.5.55 RVOS 6X 10 NC 7.4.0.5.62 7.4.0.5.63 DESCRIPTION: MAIN STEAM &, ADS SAFETY RV MS-V-16 M529 I MO C G 2Y 7.4.6.1.4.2B CSJ16,TV01,2 B13 A GT FAI HJ CS 7.4.6.1.4.2B 3 NC L J 7.4.6.1.2.4 DESCRIFfiON: MAIN STEAM DRN ISO (INBD CIV)

MS-V-19 M529 I MO C G 2Y 7.4.6.1.4.2B CSJ16 TV01,2 B14 A Gf FAI HJ CS 7.4.6.1.4.2B NC NC L J 7.4.6.1.2.4 DESCRIFfION: MAIN STEAM DRN ISO (OTBD CIV)

MS-V-20 M529 2 MO C G 2Y 7.4.6.1.4.2B Passive CIS B GB FAI 3 NC DESCRIPfION: MS LINE DRN ISO (MUST CLOSE FOR MSLC OPERATION)

1I 77 of 171.

IST Program Plan 2nd 10-Year Interval WNP-2 Page Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CS3IRO3I Valve Failed, Reliefs) Position)

& Size Normal MS-V-22A M529 I AO C G 2Y 7.4.4.7 CSJ I I TV01,2 F12 A GB FC H Q 7.4.3.1.1.9 26 NO HJK CS 7.4.4.7 L 2Y 7.4.6.1.2.7 DES C RIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-22B M529 I AO C G 2Y 7.4.4.7 CSJ11 TV01,2 E12 A GB FC H Q 7.4.3.1.1.9 26 NO HJK CS 7.4.4.7 L 2Y 7.4.6.1.2.7 DESC RIPTION MAIN STEAM ISO,VLV (INBD CIV)

MS-V-22C M529 1 AO C G 2Y ~ 7.4.4.7 CSJ I I TVOI)2 FS A GB FC H Q 7.4.3.1.1.9 26 NO HJK CS 7.4.4.7 L 2Y 7.4.6.1.2.7 DESC RIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-22D M529 I AO C G 2Y 7.4.4.7 CSJ11 TV01,2 ES A 'GB FC H Q 7.4.3.1.1.9 26 NO" HJK CS 7.4.4.7 L 2Y 7.4.6.1.2.7 DESC RIFIMN: MAIN STEAM ISO VLV (INBD CIV)

MS-V-28A M529 I AO C G 2Y 7.4.4.7 CSJI I TV01,2 F13 A GB FC H Q 7.4.3.1.1.9 26 NO HJK CS 7.4.4.7 L 2Y 7.4.6.1.2 7 DESC RIFI1ON: MAIN STEAM ISO VLV (OTBD CIV)

MS-V-28B M529 1 AO C G 2Y 7.4.4.7 CSJ II TV01,2 E13 A GB FC H Q 7.4.3.1.1.9 26 NO HJK CS 7.4.4.7 L 2Y 7.4.6.1.2.7 DESC RIFTIONr MAIN STEAM ISO VLV (OTBD CIV)

MS-V-28C M529 I AO C G .2Y 7.4.4.7 CSJ11 TV01,2 F4 A GB FC H Q 7.4.3.1.1.9 26 NO HJK CS 7.4.4.7 L 2Y '.4.6.1.2.7 DESC RIPTION: MAIN S TEAM ISO VLV (OTBD CIV)

MS-V-28D M529 I AO C G 2Y 7.4.4.7 CSJ11 TV01,2 E4 A GB FC H Q 7.4.3.1.1.9 26 NO HJK CS 7.4.4.7 L 2Y 7.4.6.1.

2.7 DESCRIPTION

MAIN STEAM ISO VLV (OTBD CIV)

MS-V-37A M529 3 SA 0 HS RF 7.4.0.5.11 ROJ07 TV06 (TYP 18) Cl 1DESCRIPTION C CK NA 10 NC.,

DES CRIPfiON: VACUUM BREAKER ON MSRV TAILPIPE MS-V-38A M529 3 SA 0 HS RF 7.4.0.5.1 I ROJ07 (TYP 18) Cl I C CK NA 10 NC VACUUM BREAKER ON MSRV TAILPIPE

IST Program Plan 2nd 10- Year Interval WNP-2 Page 78 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Iheg & Class Exceptions (Notes tk Valve EPN Actuat, Safety, Tests, Freliuency A PPM Coord 4 Cat Valve Failed, (CSJ/ROJ/ Technical Reliefs) Position) tk Sixe Normal MS-V-67A M529 1 MO C G 2Y 7.4.6.1.4.2B CSJ14 TV01,2 F13 A GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC L 2Y 7.4.6.1.2.7 DESCRIPfiON: MS-V-28A BODY DRN (OTBD CIV)

MS-V-67B M529 I MO, C G 2Y 7.4.6.1.4.2B CSJ14 TV01,2 D13 A GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC L 2Y 7.4.6.1.

2.7 DESCRIPTION

MS-V-28B BODY DRN (OTBD CIV)

Il MS-V-67C M529 I MO C G 2Y 7.4.6.1.4.2B CSJ14 TV01,2 F4 A GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC L 2Y 7.4.6.1.2.7 DESCRIPI'ION: MS-V-28C BODY DRN (OTBD CIV)

MS-V-67D M529 1 MO C G 2Y 7.4.6.1.4.2B CSJ14 TV01,2 D4 A GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC L 2Y 7.4.6.1.2.7 DESCRIFfION: MS-V-28D BODY DRN (OTBD CIV)

MS-V-146 M502-1 2 MO C G 2Y 7.4.6.1.4.2B CSJ13 B7 B GT FAI HJ CS 7.4.6.1.4.2B 24 NO DESCRIPTION: MS SUPPLY TO AUXILIARIES MS LC-V-IA M557 2 MO 0/C G 2Y - 7.4.6.1.4.2A TVOI C7 B GT FAI HJ Q 7.4.6.1.4.2A 1.50 NC DESCRIPflON: MS VENT BYPASS TO REACTOR BUILDING MSLC-V-IB M557 2 MO 0/C G 2Y 7.4.6.1.4.2A TVOI C5 B GT FAI HJ Q 7.4.6.1.4.2A 1.50 NC DESCRIPfiON: MS VENT BYPASS TO REACI'OR BUILDING MSLC-V-IC M557 2 MO 0/C G 2Y 7.4.6.1.4.2A TVOI D7 B GT FAI HJ Q 7.4.6.1.4.2A 1.50 NC DESCRIPf ION: MS VENT BYPASS TO REACI'OR BUILDING MSLC-V-ID M557 2 MO 0/C G 2Y 7.4.6.1.4.2A TV01 D5 B GT FAI HJ Q 7.4.6.1.4.2A 1.50 NC DESCRIPTION: MS VENT BYPASS TO REACTOR BUILDING MS LC-V-2A M557 I MO 0 G 2Y 7.4.6.1.4.2B CSJ12 TVOI C8 B GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC DESCRIPflON: MS VENT TO SGT AND REACTOR BUILDING MSLC-V-2B M557 1 MO 0 G 2Y 7.4.6.1.4.2B CSJ12 TV01 C8 B GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC DESCRIFfiON: MS VENT TO SGT AND REACfOR BUILDING MS LC-V-2C M557 1 MO 0 G 2Y 7.4.6.1.4.2B CSJ12 TVOI E8 B GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC DESCRIFfION: MS VENT TO SGT AND REACI'OR BUILDING

I' of IST Program Plan 2nd 10-Year Interval WNP-2 Page 79 171 1 'evision WNP-2 Valve Test Tables Type Position Testing Remarks Dwg 4 Class Exceptions (Notes h Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord A Cat (CSJ/ROJ/

Valve Failed, Reliefs) Position) 8c Size Normal MS LC-V-2D M557 I MO 0 G 2Y 7.4.6.1.4.2B CSJ12 TVOI E8 B GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC DES CRIPHON: MS VENT TO SGT AND REACfOR BUILDING MS LC-V-3A M557 I MO 0/C G 2Y 7.4.6.1.4.2B CSJ12 TV01,2 C9 A GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC L 2Y 7.4.6.1.

2.7 DESCRIPTION

MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

MS LC-V-3B M557 I MO 0/C G 2Y 7.4.6.1.4.2B CSJ12 TV01,2 C8 A GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC L 2Y . 7.4.6.1.

2.7 DESCRIPTION

MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

MSLC-V-3C M557 1 MO OIC G 2Y 7.4.6.1.4.2B CSJ12 TV01,2 DE9 A GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC L 2Y 7.4.6.1.2,7 DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

MS LC-V-3D M557 E8 I

A MO GT 1.50 0/C FAI NC

'JG L

2Y CS 2Y 7.4.6.1.4.2B 7.4.6.1.4.2B 7.4.6.1.2.7 CSJ12 TV01,2 DESCRIPIMN: MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

MS LG.V-4 M557 2 MO 0 G 2Y 7.4.6.1.4.2B CSJ12 TVOI JS B GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC DESCRIPfION: MS VENT DOWN FROM MSIV'S TO REACTOR BUILDING MS LC-V-5 M557 2 MO 0 G 2Y 7.4.6.1.4.2B CSJ12 TVOI J5 B GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC DESCRIPI'ION: MS VENT DOWN FROM MSIV'S TO REACTOR BUILDING MSLC-V-9 M557 2 MO 0 G 2Y 7.4.6.1.4.2B CSJ12 TVOI H5 B GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC DESCRIPTION: MS DEPRESS VENT DOWN FROM MSIV'S TO SGT ISO MS LC-V-10 M557 2 MO 0 G 2Y 7.4.6.1.4.2B CSJ12 TVOI H5 B GT FAI HJ CS 7.4.6.1.4.2B 1.50 NC DESCRIPTION: MS DEPRESS VENT DOWN FROM MSIV'S TO SGT ISO Pl-EFC-X18A M557 I SA 0/C GH RF 7.4.6.3.4.1B ROJ06 TV02 G9 AC CK NA 1 X.S NO DESCRIPI'ION: MAIN STEAM LINE A TO PRESS INST EFC (CIV)

PI-EFC-X18B M557 1 SA OIC GH RF 7.4.6.3.4.1B ROJ06 TV02 G9 AC CK NA 1 X.S NO DESCRIPfION: MAIN STEAM LINE B TO PRESS INST EFC (CIV)

PI-EFC-X18C MS57 I SA 0/C GH RF 7.4.6.3.4.1B ROJ06 G9 AC CK NA I X.5 NO DESCRIPTION: MAIN STEAM LINE C TO PRESS INST EFC (CIV)

IST Program Plan, 2nd 10- Year Interval WNP-2 Page 80 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Valve EPN Dwg & Chss Actuat, Safety, Tests, Frequency 4 PPM Exceptions (Notes h Coord h Cat Valve Failed, (CSJ/ROJ/ Technical Reliefs) Position) h Sixe Normal PI-EFC-X18D M557 I . SA 0/C GH RF 7.4.6.3.4. I B ROJ06 TV02 F9 AC CK NA I X.S NO DESCRIFfION: MAIN STEAM LINE D TO PRESS INST EFC (CIV)

PI-EFC-X29B M543-I 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 H8 AC CK NA I X.S NO DESCRIFfION: DRYWELL ATM TO CMS-PI'-6 EFC (CIV)

PI-EFC-X29F MS43-I 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 Hj AC CK NA I X.S NO DESCRIPI'ION: DRYWELL ATM TO CMS-FI'-2 EFC (CIV)

Pl-EFC-X30A MS43-I 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 G13 AC CK NA I X.S NO DESCRIPTION: DRYWELL ATM TO CMS-PI'-5 EFC (CIV)

PI-EFC-X30F MS43-I F13 2

AC SA CK I X.S

'A0/C NO GH RF 7.4.6.3;4.2 ROJ06 TV02 DESCRIFHON: DRYWELL ATM TO CMS-Pl'-I EFC (CIV)

PI-EFC-X37E M521- I I SA 0/C GH RF 7.4.6.3.4.1G ROJ06,. TV02 D6 AC CK NA I X.S NO DESCRIPTION: RHR SDC A SUPPLY TO DPIS EFC (CIV)

PI-EFC-X37F M521-I I SA 0/C GH RF 7.4.6.3.4.1G ROJ06 TV02 D6 AC CK NA I X.S NO DESCRIPTION: RHR SDC A SUPPLY TO DPIS EFC (CIV)

PI-EFC-X38A M529 I SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 C13 AC CK NA I X.5 NO DESCRIFHON: MAIN STEAM LINE B TO DPIS HI SIDE EFC (CIV)

PI-EFC-X38B MS29 I SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 D13 AC CK NA I X.S NO DESCRIPTION: MAIN STEAM LINE B TO DPIS LO SIDE EFC (CIV)

PI-EFC-X38C M519 I SA 0/C -

GH RF 7.4.6.3.4.1E ROJ06 TV02 G6 AC CK NA I X.S NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-7B EFC (CIV)

Pl-EFC-X38D M519 I SA 0/C GH RF 7.4.6.3.4. IE ROJ06 TV02 G6 AC CK NA I X.S NO DESCRIPI'ION: RCIC STEAM SUPPLY TO DPIS-7B EFC (CIV)

Pl-EFC-X38E M519 I 'SA OIC GH RF 7.4.6.3.4.1E ROJ06 TV02 G6 AC CK NA I X.S NO DESCRIPI10N: RCIC STEAM SUPPLY TO DPIS-13B EFC (CIV)

of ISY Program Plan 2nd 10- Year Interval WNP-2 Page 81 Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg 4 Class 4 PPM Exceptions (Notes h Valve EPN Actuat, Safety, Tests, Frequency Technical Coord tk Cat (CSJ/ROJ/

Valve Failed, -Reliefs) Poslon) tk Size Normal PI-EFC-X38F M519 I SA 0/C GH RF 7.4.6.3.4.1E ROJ06 TV02 G6 AC CK NA I X.S NO DESCRIPTION RCIC STEAM SUPPLY TO DPIS.13B EFC (CIV)

PI-EFC-X39A M521-2 I SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 H13 AC CK NA I X.S NO DESCRIPTION: MAINSTEAM LINE B TO DPIS Hl SIDE EFC (CIV)

Pl-EFC-X39B M529 I SA 0/C GH RF 7.4.6.3.4.1A ROJ06 D13 AC CK NA I X.S NO DESCRIFTION: MAIN STEAM LINE B TO DPIS LO SIDE EFC (CIV)

PI-EFC-X39D M521-2 I SA C GH RF 7.4.6.3.4.1D ROJ06 TV02 H13 AC CK NA I X.S NO DESCRIFTION: RHR LPCI B INJECTION TO DPIS-29B EFC (CIV)

Pl-EFC-X39E MS21-2 I SA C GH RF 7.4.6.3.4.1D ROJQ6 TVQ2 H13 AC CK NA I X.S NO DESCRIPTION: RHR LPCI C INJECTION TO DPIS-29B EFC (CIV)

PI-EFC-X40C M530-I I SA 0/C GH RF 7.4.6.3.4.1F ROJ06 TV02 F12 AC CK NA I X.S NO DESCRIFIMN: RRC A TO FT-14A,14B, I IA EFC (CIV)

PI-EFC-X40D M530-I I SA 0/C GH RF 7.4.6.3.4.1F ROJ06 TV02 F12 AC CK -NA I X.S NO DESCRIFTION: RRC A TO FT-14A, 14B, I IA EFC (CIV)

PI-EFC-X40E M530-I 2 SA C GH RF 7.4.6.3.4.1D ROJ06 TV02 C14 AC CK NA I X.S. NO DESCRIFTION: RRC A (RRC-P-IA) TO PI-IA,602A EFC (CIV)

Pl-EFC-X40F M530-I 2 SA C GH RF 7.4.6.3.4.1D ROJ06 TV02 C14 AC CK NA 1 X.S NO DESCRIFTION: RRC A (RRC-P-IA) TO PI-2A,6Q3A EFC (CIV)

Pl-EFC-X41C M530-I I SA C GH RF 7.4.6.3.4.1D ROJ06 TV02 B4 AC CK NA I X.S NO DESCRIFTION: RRC B (RRC-P-IB) TO DFf-ISB EFC (CIV)

Pl-EFC-X41D M530-I I SA C GH RF 7.4.6.3.4.1D ROJ06 TV02 C4 AC CK NA I X.S NO DESCRIFTION: RRC B (RRC-P-IB) TO DFf-ISB EFC (CIV)

Pl-EFC-X41E M530-I 2 SA C GH RF 7.4.6.3.4.1D ROJ06 TV02 B4 AC CK NA I X.S NO DESCRIPTION: RRC B (RRC-P-IB) TO PI-IB,602B EFC (CIV)

82 of 171 IST Program Plan 2nd 10- Year Interval WNP-2 Page Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, Reilefs) Position)

& Size Normal PI-EFC-X41F MS30-1 2 SA C GH RF 7.4.6.3.4.1D ROJ06, TV02 C4 AC CK NA I X.S NO DESCRIPTION: RRC B (RRC-P-I B) TO PI-2B,603B EFC (CIV)

PI-EFC-X42A M529 1 'SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 C4 AC CK NA I X.S NO DESCRIPTION: MAIN STEAM LINE D TO DPIS Hl SIDE EFC (CIV)

PI-EFC-X42B MS29 1 SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 C4 AC CK NA I X.S NO DESCRIFI'ION: MAINSTEAM LINE D TO DPIS LO SIDE EFC (CIV)

M543-2 2 SA 0/C GH RF 7.4.6.3.4.2 'I-EFC-X42C ROJ06 TV02 E6 AC CK NA 1 X.S NO DESCRIPTION: H2-02 MONITOR TO DRYWELL ATM SAMPLE EFC (CIV)

Pl-EFC-X42F M529 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 HS AC CK NA I X.S NO DESCRIPTION: DRYWELL ATM TO PRESS INST EFC (CIV)

PI-EFC-X44AA M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 E2 AC CK NA I X.S NO DESCRIF110N: JEI'UMP NO 11 TO FLOW INST EFC (CIV)

PI-EFC-X44AB M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 E2 AC CK NA I X.S NO DESCRIFI10N: JET PUMP NO 12 TO FLOW INST EFC (CIV)

PI-EFC-X44AC M530-I 1 SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 AC CK NA 1 X.S NO DESCJUFIION: JET PUMP NO 13 TO FLOW INST EFC (CIV)

Pl-EFC-X44AD M530-1 1 SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 E2 AC CK NA I X.S NO DESCRIPTION: JET PUMP NO 14 TO FLOW INST EFC (CIV)

PI-EFC-X44AE M530-I I SA 0/C GH RF 7.4.6.3.4.1C ROJ06 TV02 J6 AC CK NA I X.S NO DESCRIFfION: JET PUMP NO 15 TO FLOW INST EFC (CIV)

PI-EFC-X44AF M530- I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 E2 AC CK NA I X.S NO DESCRIPTION: JEI'UMP NO 16 TO FLOW INST EFC (CIV)

PI-EFC-X44AG M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 E2 AC CK NA 1 X.S NO DESCRIPTION: JEI'UMP NO 17 TO FLOW INST EFC (CIV)

1 of IST Program Plan 2nd 10- Year Interval WNP-2 Page 83 Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg 4 Class Exceptions 'Notes 4 Valve EPN Actuat, Safety, Tests, Frequency tk PPM Technical Coord tk Cat (CSJ/ROJI Valve Failed, Reliefs) Position) 4 She Normal PI-EFC-X44AH M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 E2 AC CK NA I X.S NO DESCRIPTION: JET PUMP NO 19 TO FLOW INST EFC (CIV)

PI-EFC-X44AJ M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 E2 AC CK NA I X.5 NO DESCRIFfiON: JET PUMP NO 18 TO FLOW INST EFC (CIV)

PI-EFC-X44AK M530-1 I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 J6 AC CK NA I X.5 NO DESCRIFfION: JET PUMP NO 20 TO FLOW INST EFC (CIV)

PI-EFC-X44AL M530-I I SA 0/C GH RF 7.4.6.3.4.1C ROJ06 TV02 H6 AC CK NA I X.S NO DESCRIFIMN: JET PUMP NO 15 TO FLOW INST EFC (CIV)

PI-EFC-X44AM M530-I I SA C GH RF 7.4.6.3.4. I C ROJ06 TV02 H6 AC CK NA I X.5 NO DESCRIPfION: JET PUMP NO 20 TO FLOW INST EFC (CIV)

PI-EFC-X44BA M530- I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 F2 AC CK NA I X.5 NO DESCRIFfiON: JET PUMP NO ITO FLOW INST EFC (CIV)

PI-EFC-X44BB M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 F2 AC CK NA 1 X.5 NO DESCRIFfION: JET PUMP NO 2TO FLOW INST EFC (CIV)

PI-EFC-X44BC M530-I I SA C r GH RF 7.4.6.3.4.IC ROJ06 TV02 F2 AC CK NA I X.5 NO DESGRIF11ON: JEI'UMP NO 3TO FLOW INST EFC (CIV)

PI-EFC-X44BD M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 F2 AC CK NA I X.S. NO DESCRIFfION: JET PUMP NO 4TO FLOW INST EFC (CIV)

PI-EFC-X44BE M530-I I SA 0/C GH RF 7.4.6.3.4.1C ROJ06 TV02 JI I AC CK NA I X.S NO DESCRIFfiON: JET PUMP NO STO FLOW INST EFC (CIV)

Pl-EFC X44BF M530-I I SA C GH RF 7A.6.3.4.1C ROJ06 TV02 F2 AC CK NA I X.S NO DESCRIFI1ON: JET PUMP NO 6TO FLOW INST EFC (CIV)

PI-EFC-X44BG MS30-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 F2 AC CK NA I X.S NO DESCRIPIMNt JEI'UMP NO 7TO FLOW INST EFC (CIV)

1 J

n

IST Program Plan 2nd 10- Year Interval WNP-2 Page 84 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg 4 Class Exceptions (Notes h Valve EPN Coord h Cat Actuat, Safety, Tests, Frequency 4 PPM (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position) 4 Size Normal PI-EFC-X44BH M530-I 1 SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 F2 AC CK NA 1 X.S NO DESCRIPTION: JET PUMP NO 8TO FLOW INST EFC (CIV)

PI-EFC-X44BJ M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 F2 AC CK NA I X.S NO DESCRIPTION: JET PUMP NO 9TO FLOW INST EFC (CIV)

PI-EFC-X44BK M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 Jl I AC CK NA I X.S NO DESCRIPTION: JET PUMP NO 10 TO FLOW INST EFC (CIV)

PI-EFC-X44BL M530-I I SA 0/C GH RF 7.4.6.3.4.1C ROJ06 TV02 Hl I AC CK NA I X.S NO DESCRIPTION: JET PUMP NO STO FLOW INST EFC (CIV)

PI-EFC-X44BM M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 Hi I AC CK NA I X.S NO TV02'ESCRIPTION:

JET PUMP NO 10 TO FLOW INST EFC (CIV)

PI-EFC-X61A M530-1 I SA 0/C GH RF 7.4.6.3.4.1F ROJ06 TV02 F12 AC CK NA I X.S NO DESCRIPTION: RRC A TO FT-14C,14D EFC (CIV)

PI-EFC-X61B M530-1, 1 SA 0/C GH RF 7.4.6.3.4.1F ROJ06 TV02 F12 AC CK NA I X.S NO DES CRIPHON: RRC A TO FT-I4C, 14D EFC (CIV)

PI-EFC-X61C MS29 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 GS AC CK NA I X.S NO DESCRIPTION: DRYWELL ATM TO PRESS INST EFC (CIV)

PI-EFC-X62B M529 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 H12 AC CK NA I X.S NO DESCRIPTION DRYWELL ATM TO PRESS INST EFC (CIV)

PI-EFC X62C M530-1 1 SA 0/C GH RF 7.4.6.3.4.1F ROJ06 TV02 F6 AC CK NA I X.S NO DESCRIPTION: RRC B TO FT-24C,24D EFC (CIV)

PI-EFC-X62D M530- I I SA 0/C GH RF 7.4.6.3.4.1F ROJ06 F6 AC CK. NA I X.S NO DESCRIPTION: RRC B TO Fi'-24C,24D EFC (CIV)

PI-EFC-X66 M543-I 2 'SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 B6 AC CK NA I X.S NO DES CRIPfiON: WETWELL ATM TO CSP-DPI'-5 EFC (CIV)

I 4

IST Program Plan 2nd 10-Year Interval WNP-2 Page 85 of Revision 171 1,

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg 4 Class Exceptions (Notes tk Valve EPN Coord 4 Cat Actuat, Safety, Tests, Frequency 4 PPM (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position) tk Size Normal PI-EFC-X67 M543-I 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 B13 AC CK NA I X.S NO DESCRIPTION: WETWELL ATM TO CSP-DPf< EFC (CIV)

Pl-EFC-X69A M529 I SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 C4 AC CK NA I X.S NO DESCRIFfiON: MAIN STEAM LINE D TO DPIS HI SIDE EFC (CIV)

PI-EFC-X69B M529 I SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 C4 AC CK NA I X.S NO DESCRIFfION: MAIN STEAM LINE D TO DPIS LO SIDE EFC (CIV)

PI-EFC-X69E M530 I SA 0/C GH RF 7.4.6.3.4.1D ROJ06 TV02 G6 AC CK NA I X.S NO DESCRIPfION: RRC B TO PS-18B EFC (CIV)

PI-EFC-X69F M529 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 H12 AC CK NA I X.S NO DESCRIPfiON: DRYWELLATM TO P&48A,48C,2B EFC (CIV)

PI-EFC-X70A M529 I SA OIC GH RF 7.4.6.3.4.1A ROJ06 TV02 E4 AC CK NA I X.S NO DESCRIPTION: MAIN STEAM LINE C TO DPIS HI SIDE EFC (CIV)

PI-EFC-X70B MS29 1 SA OIC GH RF 7.4.6.3.4.1A ROJ06 TV02 E4 AC CK NA I X.S NO DESCRIPTION: MAIN STEAM LINE C TO DPIS LO SIDE EFC (CIV)

PI-EFC-X70C M529 I SA 0/C GH RF 7.4.6.3.4.1A ROJ06 E13 AC CK NA I X.S NO DESCRIPfION: MAIN STEAM LINE A TO DPIS Hl SIDE EFC (CIV)

PI-EFC-X70D M529 I SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 E13 AC CK NA I X.S NO DESCRIFfION: MAIN STEAM LINE A TO DPIS LO SIDE EFC (CIV)

Pl-EFC-X70E M530-I I SA C GH RF 7.4.6.3.4.1D ROJ06 TV02 B14 AC CK NA I.X .5 NO DESCRIFfiON: RRC A (RRC-P-IA) TO DFf-15A EFC (CIV)

PI-EFC-X70F M530-I I SA C GH RF 7.4.6.3.4.1D ROJ06 TV02 B14 AC CK NA I X.S NO DESCRIPfiON: RRC A (RRC-P-IA) TO DFf-ISA EFC (CIV)

PI-EFC-X71A M529 I SA OIC GH RF 7.4.6.3.4.1A ROJ06 TV02 E4 AC CK NA I X.S NO DESCRIFfION: MAIN STEAM LINE C TO DPIS HI SIDE EFC (CIV)

I of IST Program Plan 2nd 10- Year Interval WNP-2 Page 86 Revision 171 1

WNP-2 Valve Test Tables Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, Reliefs) Position)

& Size Normal PI-EFC-X71B M529 I . SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 E4 AC CK NA I X.S NO DESCRIPTION MAIN STEAM LINE C TO DPIS LO SIDE EFC (CIV)

PI-EFC-X71C M519 I SA 0/C GH RF 7.4.6.3.4.1E ROJ06 TV02 G6 AC CK NA I X.S NO DESCRIPIION: RCIC STEAM SUPPLY TO DPIS-7A EFC (CIV)

PI-EFC-X71D MS 19 G6 I

AC

"'A CK 0/C NA GH RF 7.4.6.3.4.1E ROJ06 TV02 I X.S NO DESCRIFIION: RCIC STEAM SUPPLY TO DPIS-7A EFC (CIV)

PI-EFC-X71E M519 I SA 0/C GH RF 7.4.6.3.4.1E ROJ06 TV02 G6 AC CK NA I X.S NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-13A EFC (CIV)

Pl-EFC-X71F M519 1 SA 0/C GH RF 7.4.6.3.4.1E ROJ06 TV02 G6 AC CK NA 1 X.S NO DESCRIFflON: RCIC STEAM SUPPLY TO DPIS-13A EFC (CIV)

Pl-EFC-X72A M529 I SA 0/C GH RF 7.4.6.3.4.1G ROJ06, TV02 J6 AC CK NA 1 X.S NO DESCRIPTION: RPV STEAM DOME TO PRESS INST EFC (CIV)

Pl-EFC-X73A M520 1 SA OIC GH RF 7.4.6.3.4.1E ROJ06 TV02 JS AC CK NA I X.S NO DESCRIPIION: HPCS TO RPV TO DPIS-9 EFC (CIV)

PI-EFC-X74A M530-I I SA 0/C GH RF 7.4.6.3.4.1C ROJ06 TV02 G12 AC CK NA I X.S NO DESCRIPTION: SLC INJ BELOW CORE PLATE TO FLOW INSTR EFC (CIV)

PI-EFC-X74B M521-1 1 SA C GH RF 7.4.6.3.4.1D ROJ06 TV02 HS AC CK NA I X.S NO DESCRIFfION: RHR LPCI A INJECTION TO DPIS-29A EFC (CIV)

Pl-EFC-X74E M530-I I SA 0/C GH RF 7.4.6.3.4.1D ROJ06 TV02 Hl I AC CK NA I X.S NO DESCRIPTION: RRC A TO RHR PUMPS TO DPIS-12A EFC (CIV)

PI-EFC-X74F M530-1 SA OIC GH RF 7A.6.3.4.1D ROJ06 TV02 Hl 1 AC CK NA I X.S NO DESCRIPTION: RRC A TO RHR PUMPS TO DPIS-12A EFC (CIV)

Pl-EFC-X75A M530-I I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 G6 AC CK NA I X.S NO DESCRIFfION: SLC INJ BELOW CORE PLATE TO FLOW INSTR EFC (CIV)

II>

t

IST Program Plan 2nd 10-Year Interval WNP-2 Page 87 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg tk Class Exceptions (Notes tk Valve EPN Actuat, Safety, Tests, Frequency Sr PPM Coord 4 Cat Valve Failed, (CSJ/ROJ/ Technical Reliefs) Position) 8c Size Normal PI-EFC-X75B M530-1 I SA 0/C, GH RF 7.4.6.3.4.1E ROJ06 TV02 G12 AC CK NA I X.5 NO DESCRIPTION: SLC INJ ABOVE CORE PLATE TO FLOW INSTR EFC (CIV)

PI-EFC-X75C M529 1 SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 E12 AC CK NA 1 X.S NO DESCRIFTION: MAIN STEAM LINE A TO DPIS EFC (CIV)

PI-EFC-X7SD M529 I SA 0/C GH RF 7.4.6.3.4.1A ROJ06 TV02 E12 AC CK NA 1 X.5 NO DESCRIFTION: MAIN STEAM LINE A TO DPIS EFC (CIV)

PI-EFC-X7SE M530-1 I SA 0/C GH RF 7.4.6.3.4.1F ROJ06 TV02 F5 AC CK NA I X.S NO DESCRIFTION: RRC B TO FT-24A,24B EFC (CIV)

PI-EFC-X75F M530-I I SA 0/C GH RF 7.4.6.3.4.1F ROJ06 TV02 FS AC CK " NA I X.S NO DESCRIFTION: RRC B TO FI'-24A,24B EFC (CIV)

PI-EFC-X78A M543-2 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 E13 AC CK NA I X.S NO DESCRIFIMN: H2-02 MONITOR TO DRYWELL ATM SAMPLE ISO (CIV)

PI-EFC-X78B M520 I SA C GH RF 7.4.6.3.4'. ID ROJ06 TV02 Jlo AC CK NA I X.S NO DESCRIPTION: LPCS TO RPV TO RHR-DPS-29A EFC (CIV)

PI-EFC-X78C M523 I SA C GH RF 7.4.6.3.4.1C ROJ06 TV02 F12 AC CK NA I X.S NO DESCRIPTION: RWCU TO RWCU-FT-37 EFC (CIV)

PI-EFC-X78F M530- I I SA 0/C GH RF 7.4.6.3.4.1D ROJ06 TV02 H12 AC CK NA I X.S NO DESCRIFI'ION: RRC A (RRC-P-IA SUCF) TO PS-18A EFC (CIV)

Pl-EFC-X79A M523 I SA 0/C GH RF 7.4.6.3.4.1E ROJ06 TV02 FIS AC CK NA I X.S NO DESCRIPTION: RWCU TO RWCU-FT-36 EFC (CIV)

PI-EFC-X79B M523 I SA 0/C GH RF 7.4.6.3.4.1E ROJ06 TV02 FIS AC CK NA I X.S NO DESCRIFTION: RWCU TO RWCU-FT-36 EFC (CIV)

PI-EFC-X82B M543-1 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 B14 AC CK NA $ I 1 X.S NO DESCRIFTION: WETWELL ATM TO FI'-3 EFC (CIV)

~ r ~

~ l

IST Program Plan 2nd 10- Year Interval WNP-2 Page 88 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testhlg Remarhs Dwg 4 Class Exceptions (Notes 8c Valve EPN Coord A Cat Actuat, Safety, Tests, Frequency 4 PPM (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position) 4 Size Normal PI-EFC-X84A M543-I 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 B6 AC CK NA I X.S NO DESCRIPTION: WEI'WELL ATM TO FT-4 EFC (CIV)

PI-EFC-X86A M543-1 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 B14 AC CK NA 1 X.5 NO DESCRIPTION: WEI'WELL TO LT-I EFC (CIV)

PI-EFC-X86B M543-I 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 B14 AC CK NA I X.S NO DESCRIPTION: WETWELL TO LT-I EFC (CIV)

PI-EFC-X87A MS43-I 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 B6 AC CK NA I X.S NO DESCRIFTION: WETWELL TO LT-2 EFC (CIV)

Pl-EFC-X87B M543-I 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 B6 AC CK NA 1 X.S NO DESCRIPTION: WETWELL TO LT-2 EFC (CIV)

PI-EFC-X 106 M529 I SA 0/C GH RF 7.4.6.3.4.1G ROJ06 H12 AC CK NA I X.S NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC X107 MS29 I SA 0/C GH RF 7.4.6.3.4.1G ROJ06 TV02 H12 AC CK NA I X.S NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X108 M529 1 SA 0/C GH RF 7.4.6.3.4.1G ROJ06 'V02 G12 AC CK NA I X.S NO DESCRIFTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X109 M529 I SA 0/C GH RF 7.4.6.3.4.1G ROJ06 TV02 HS AC CK NA I X.S NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X110 MS29 SA 0/C GH RF 7.4.6.3.4.1G ROJ06 TV02 HS AC CK NA I X.S NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-Xl 1 I MS29 I SA 0/C GH RF 7.4.6.3.4.1G ROJ06 TV02 HS AC CK NA 1 X.S NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

Pl-EFC-X112 M529 I 'SA 0/C GH RF 7.4.6.3.4.1G ROJ06 TV02 H5 AC CK NA 1 X.S NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

IST Program Plan 2nd 10- Year Interval WNP-2 Page 89 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg 4 Class Exceptions (Notes h Valve EPN Coord 4 Cat Actuat, Safety, Tests, Frequency 4 PPM (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position) 4 Size Normal PI-EFC-X113 M529 I SA 0/C GH RF 7.4.6.3.4.1G ROJ06 TV02 HS AC CK NA I X.S NO DESCRIFfION: RPV TO PRESS INST EFC (CIV)

Pl-EFC-X114 M529 I SA 0/C GH RF 7.4.6.3.4.1G ROJ06 TV02 H12 AC CK NA I X.S NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-Xl 15 M529 I SA 0/C GH RF 7.4.6.3.4.1G ROJ06 TV02 H12 AC CK NA I X.S NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X119 M543-I 2 SA 0/C GH RF 7.4.6.3.4.2 ROJ06 TV02 B6 AC CK NA I X.S NO DESCRIFfION: WETWELL ATM TO CSP-DPI'-6 EFC (CIV)

PI-V-X42D M521-I 2 MA C L J 7.4.6.1.2.4 TV02 FS A GB ~ NA I LC DESCRIPTION: AIR TO RHR-V-SOA OPERATOR (INBD CIV)

PI-V-X54BF M521-2 2 MA C L J 7.4.6.1.2.4 H13 A GB NA I LC DESCRIPTION: AIR TO RHR-VAIBOPERATOR (INBD CIV)

PI-V-X61F M521-I 2 MA C L J 7.4.6.1.2.4 TV02 GS A GB NA I LC DESCRIFI'ION: AIR TO RHR-V< I A OPERATOR (INBD CIV)

PI-V-X62F M521-2 2 MA C L J 7.4.6.1.2.4 TV02 D12 A GB NA I LC DESCRIFfION: AIR TO RHR-VAIC OPERATOR (INBD CIV)

PI-V-X69C M521-2 2 MA C L J 7.4.6.1.2.4 TV02 F13 A GB NA I LC DESCRIPTION: AIR TO RHR-V-SOB OPERATOR (INBD CIV)

PI-V-X72F/I M543-I 2 SA C H RF 7.4.0.5.7G ROJ04 TV02 F13 AC CK NA L J 7.4.6.1.2.4 I 'NO DESCRIFHON: DRYWELL ATM TO RAD-RE-12A EFC(CIV)

PI-V-X73E/I M543-I 2 SA C H RF 7.4.0.5.7G ROJ04 TV02 F7 AC CK NA L J 7.4.6.1.2.4 I NO DESCRIPTION: DRYWELL ATM TO RAD-RE-12B EFC (CIV)

PI-VX-216 M521-1 2 MA C L J 7.4.6.1.2.4 TV02 G6 A GB NA I LC DESCRIPTION: AIR TO RHR-V-SOA OPERATOR (OTBD CIV)

IST Program Plan 2nd 10-Year Interval WNP-2 Page 90 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Coord ,& Cat (CSJ/ROJ/ Technical Valve Failed,

& Sis4 Normal Reliefs) Position)

PI-VX-218 M521-2 2 MA C L J 7.4.6.1.2.4 'TV02 H13 A GB NA I LC DESCRIPTION: AIR TO RHR-VAIBOPERATOR (OTBD CIV)

PI-VX-219 M521-I 2 MA C L J 7.4.6.1.2.4 TV02 H6 A GB NA I LC DESCRIPTION: AIR TO RHR-V-41A OPERATOR (OTBD CIV)

PI-VX-220 M521-2 2 MA C L J 7.4.6.1,2.4 D12 A GB NA I LC DESCRIPTION: AIR TO RHR-V-41C OPERATOR (OTBD CIV)

PI-VX-221 M521-2 2 MA C L J 7.4.6.1.2.4 TV02 G13 A GB NA I LC DESCRIPTION: AIR TO RHR-V-50B OPERATOR (OTBD CIV)

PI-VX-250 M543-I 2 SO C G 2Y 7.4.0.5.13 TV01,2 F13 A SV FC HJK Q 7.4.0.5.13 I NO GL 18M 7.4.6.1.

2.4 DESCRIPTION

DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-251 M543-I 2 SO C G 2Y 7.4.0.5.13 TV01,2 F13 A SV FC HJK 7.4.0.5.13 I " NO GL ISM 7.4.6.1.2.4 DESCRIFfiON: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-253 M543-I 2 SO C G 2Y 7.4.0.5.13 TV01,2 F13 A SV FC ~

HJK Q 7.4.0.5.13 I NO GL 18M 7.4.6.1.2.4 DESCRIFHON: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-256 M543-I 2 SO C G 2Y 7.4.0.5.13 TV01,2 F7 A SV FC HJK Q 7.4.0.5.13 I NO GL 18M 7.4.6.1.2.4 DESCRIFfiON: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-257 M543-I 2 SO C G 2Y 7.4.0.5.13 TV01,2 F7 A SV FC HJK Q 7.4.0.5.13 I NO GL 18M 7.4.6.1.2.4 DESCRIFI'ION: DRYWELL TO RADIATION MONITOR ISO (CIV)

Pl-VX-259 M543-I 2 SO '

G 2Y 7.4.0.5.13 TV01,2 F7 A SV FC HJK Q 7.4.0.5.13 I NO GL 18M 7.4.6.1.2.4 DESCRIFI1ON: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-262 M543-2 2 SO C G 2Y 7.4.0.5.13 TV01,2 G13 A SV FC HJK Q 7.4.0.5.13 I NO DESCRIFfION: DRYWELL TO H2-02 MONITOR ISO (CIV)

PI-VX-263 M543-2 2 SO C G 2Y 7.4.0.5.13 TV01,2 G13 A SV FC HJK Q 7.4.0.5.13 I NO DESCRIFfiON: DRYWELL TO H2-02 MONITOR ISO (CIV)

of IST Program Plan 2nd 10-Year Interval WNP-2 Page 91 Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg 4 Class 4 PPM Exceptions (Notes h Valve EPN Actuat, Safety, Tests, Frequency Coord a Cat Valve Failed, (CSJ/ROJ/ Technical Reliefs) Position) 4 Size Normal PI-VX-264 M543-2 2 SO C G 2Y 7.4.0.5.13 TV01,2 FI3 A SV FC HJK Q 7.4.0.5.13

, I NO DES CRIPI'ION DRYWELLTO H2-02 MONITOR ISO (CIV)

PI-VX-265 M543-2 2 SO C G 2Y 7.4.0.5.13 TV01,2 C14 A SV FC HJK Q 7.4.0.5.13 h I NO DESCRIPTION: DRYWELLTO H2-02 MONITOR ISO (CIV)

PI-VX-266 M543-2 2 SO C G 2Y 7.4.0.5.13 TV01,2 F6 A SV FC HJK Q 7.4.0.5. 13 I NO DESCRIPfiON: DRYWELLTO H2-02 MONITOR ISO (CIV)

PI-VX-268 M543>>2 2 SO C G 2Y 7.4.0.5.13 TV01,2 F6 A SV FC HJK Q 7.4.0.5.13 I NO DESCRIPfiON: DRYWELLTO H2-02 MONITOR ISO (CIV)

Pl-VX-269 M543-2 2 SO C G 2Y 7.4.0.5.13 TV01,2 CS A SV FC HJK Q 7.4.0.5.13 I NO DESCRIPfiON: DRYWELLTO H2-02 MONITOR ISO (CIV)

PSR-V~3/A M&96 2 SO C G 2Y 7.4.0.5.51 TVOI E12 B SV FC HJ Q 7.4.0.5.51 I NC DESCRIPfION: RHR LOOP A SAMPLE ISO PSR-V~3/B'&96 2 SO C G 2Y 7.4.0.5.SI TVOI D12 B SV FC HJ 'Q 7.4.0.5.51 I NC DESCRIPfiON: RHR LOOP B SAMPLE ISO PSR-V-X73/I M&96, 2 SO C GL 1&M 7.4.6.1.2.4 RV04 TV01,2 J14 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIFfiON: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X73/2 M&96 2, SO C GL 18M 7.4.6.1.2.4 TV01,2 J12 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIFfION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X77A/I M&96 I SO C GL 18M 7.4.6.1.2.4 RV04 TV01,2 E14 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIFfiON: JET PUMP SAMPLE ISO (CIV)

PSR-V-X77A/2 M&96 I SO C GL 18M 7.4.6.1.2.4 TV01,2 E12 A GB FC HJK Q 7.4.0.5.SI I NC DESCRIFfION: JET PUMP SAMPLE ISO (CIV)

PSR-V-X77A/3 M&96 I 'SO C GL 18M 7.4.6.1.2.4 RV04 TV01,2 F14 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIFfION: JET PUMP SAMPLE ISO (CIV)

"J IST Program Plan 2nd 10- Year Interval WNP-2 Page 92 of 171 Revision 1 WNP-2 Valve Test Tables Type Position Testing Remarks Valve EPN Dwg tk Class Actuat, Safety, Tests, Frequency 4 PPM Exceptions (Notes h Coord 4 Cat Valve Failed, (CSJ/ROJ/ Technical Reliefs) Position) tk Size Normal PSR-V-X77A/4 M896 1 SO C GL I8 M 7.4.6.1.2.4 TV01,2 F12 A GB, FC HJK Q 7.4.0.5.51 I NC DESCRIFHON: JET PUMP SAMPLE ISO (CIV)

PSR-V-X80/I M896 2 SO C GL I SM 7.4.6.1.2.4 RV04 TV01,2 K14 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIPTION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-XSO/2 M896 2 SO C GL 18M 7.4.6.1.2.4 TV01,2 K12 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIFI'ION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X82/1 M896 2 SO C GL 18M 7.4.6.1.2.4 RV04 TV01,2 B13 "

A GB FC HJK Q 740551 I NC DESCRIFHON: SAMPLE REHJRN TO SUPP POOL ISO (CIV)

PSR-V-X82/2 M896 2 SO C GL 18M 7.4.6.1.2.4 TV01,2 Bl 1 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIFHON: SAMPLE REI'URN TO SUPP POOL ISO (CIV)

PSR-V-X82/7 M896 2 SO C GL 18M 7.4.6.1.2.4 RV04 TV01,2 F13 A GB. FC HJK Q 7.4.0.5.51 I NC DESCRIFHON: SAMPLE REHJRN TO DRYWELL ISO (CIV)

PSR-V-X82/8 M896 2 SO C GL 18M 7.4.6.1.2.4 TV01,2 F12 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIFHON: SAMPLE REHJRN TO DRYWELL ISO (CIV)

PSR-V-X83/I M896 2 SO C GL ISM 7.4.6.1.2.4 RV04 TV01,2 J13 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIFI'ION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X83/2 M896 2 SO C GL ISM 7.4.6.1.2.4 TV01,2 J12 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIFHON: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X84/1 M896 2 SO C GL 18M 7.4.6.1.2.4 RV04 TV01,2 H12 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIPTION: WEI'WELL ATM SAMPLE ISO (CIV)

PSR-V-X84/2 M896 2 SO C GL I SM 7.4.6;1.2.4 TV01,2 Hl 1 A GB FC HJK Q 7.4.0.5.51 I NC DESCRIPTION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-XS8/1 M896 2 SO C GL I SM 7.4.6.1.2.4 RV04 TV01,2 D13 A GB FC HJK Q 7.4.0.5.51 NC DESCRIFHON: SUPP POOL SAMPLE ISO (CIV)

IST Program Plan 2nd 10- Year Interval WNP-2 Page 93 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Valve EPN Dwg /k Class Actuat, Safety, Tests, Frequency h PPM Exceptions (Notes 4 Coord 4 Cat Valve Failed, (CSJ/ROJ/ Technical Regefs) Position)

/k She Normal PSR-V-X88/2 M896 2 SO C GL ISM 7.4.6.1.2.4 TV01,2 Dl I A GB FC HJK Q 7.4.0.5.51 I NC DESCRIPTION: SUPP POOL SAMPLE ISO (CIV)

RCC-RV-34A M52S 3 SA NA P RV 7.4.0.5.20 TV03 HOS C RV NA

.75 X 1 NC DESCRIPTION: FPC-HX-IA SHELL SIDE RV RCC-RV-34B M525 3 SA NA P RV 7.4.0.5.20 TV03 GOS C RV NA

.75 X I NC DESCRIPI1ON: FPC-HX-IB SHELL SIDE RV RCC-V-5 MS25 2 MO C G 2Y 7.4.0.5.9C CSJ02 TV01,2 Elo A GB FAI HJ CS 7.4.0.5.9C 10 NO L J 7.4.6.1.

2.4 DESCRIPTION

RCC TO DRYWELL COOLING LOADS (IST OTBD CIV)

RCC-V-21 M525 2 MO C G 2Y 7.4.0.5.9C CSJ02 TV01,2 Dlo A GT FAI HJ CS 7.4.0.5.9C 10 NO L J 7.4.6.1.2.4 DESCRIPI'ION: RCC FROM DRYWELL COOLING LOADS (OTBD CIV)

RCC-VAO M525 2 MO C G 2Y 7.4.0.5.9C CSJ02 TV01,2 Dl I A GT FAI HJ CS 7.4.0.5.9C 4

, 10 NO L J 7.4.6.1.

2.4 DESCRIPTION

RCC FROM DRYWELL COOLING LOADS (INBD CIV)

RCC-V-104 2 MS25 EIO A MO GI'AI C G HJ 2Y CS 7.4.0.5.9C 7.4.0.5.9C CSJ02 TV01,2 10 NO L J 7.4.6.1.

2.4 DESCRIPTION

RCC TO DRYWELL COOLING LOADS (2ND OTBD CIV)

RCC-V-129 MS25 3 MO C G 2Y 7.4.0.5.6D TVOI ES B GT FAI HJ Q 7.4.0.5.6D 8 NO DESCRIPTION: RCC TO FPC-HX-IA &, IB ISO RCC-V-130 MS25 . MO C G 2Y 7.4.0.5.6D TVOl E6 GT FAI HJ Q 7.4.0.5.6D 8 NO DESCRIFHON: RCC FROM FPC-HX-IA 8c IB ISO RCC-V-131 MS25 3 MO C G 2Y 7.4.0.5.6D TVOI E6 B GT FAI HJ Q 7.4.0.5.6D 8 NO DESCRIPTION: RCC FROM FPC-HX-IA 8c IB ISO RCC-V-133A M525 3 SA C H Q 7.4.0.5.16 HOS C CK NA 6 NO DESCRIPTION: RCC TO FPC-HX-IA CHK RCC-V-133B M525 3 SA C H Q 7.4.0.5.17 GOS C CK 'NA 6 NO DESCRIPTION: RCC TO FPC-HX-IB CHK

,l d

IST Program Plan 2nd 10- Year Interval WNP-2 Page 94 of 171 1 'evision WNP-2 Valve Test Tables Type Position Testmg Remarks Bwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Coord & Cat ,

(CSJ/ROJ/ Technical Valve Failed, Reliefs) Position)

& Size Normal RCIC-RD- I M519 2 SA NA NOS D12 D RD NA 10 NC DESCRIFI1ON: RCIC TURBINE EXHAUST LINE RUPHJRE DISC RCIC-RD-2 M519 2 SA NA NOS C12 D RD NA 10 NC DESCRIPTION: RCIC TURBINE EXHAUST LINE RUFfURE DISC RCIC-RV-17 M519 2 SA NA P RV 7.4.0.5.20 TV03 C13 C RV NA I X I NC, DESCRIFI'ION: RCIC PUMP SUCT RV RCIC-V-I M519 2 MO C G 2Y 7.4.7.3.3C TVOI El I B GB FAI HJ Q 7.4.7.3.3C 3 NO DESCRIPTION: RCIC TURBINE TRIP/THROTILE VLV RCIC-V-8 M519 I MO C G 2Y 7.4.7.3.3C TV01,2 F6 A GT FAI HJ Q 7.4.7.3.3C 4 NO L J 7.4.6.1.2.4 DESCRIPIION: RCIC TURBINE STEAM SUPPLY (OTBD CIV)

RCIC-V-10 MS19 2 MO C G 2Y 7.4.7.3.3C TVOI B14 B GT FAI HJ Q 7.4.7.3.3C 8 NO DESCRIFIMN: CST TO RCIC-P- I SUCT RCIC-V-13 M519 I MO C G 2Y 7.4.0.5.8C CSJ07 TV01,2 H7 A GT FAI HJ CS 7.4.0.5.8C 6 NC L 18M 7.4.4.3.2.2 DESCRIFIMN: RCIC TO RPV HEAD SPRAY ISO (OTBD CIV)

RCIC-V-19 M519 2 MO C G 2Y 7.4.7.3.3C TV01,2 F7 A GB FAI HJ Q 7.4.7.3.3C 2 NC L J 7.4.6.1.2.4 DESCRIPIMN: RCIC-P-1 MINIMUMFLOW TO SUPP POOL (OTBD CIV)

RCIC-V-22 M519 2 MO C G 2Y 7.4.7.3.3C TVOI JS B GB FAI HJ Q . 7.4.7.3.3C 6 NC DESCRIPfiON: RCIC-P-I DISCH TO CST ISO RCIC-V-28 M519 2 SA C H Q 7.4.7.3.3C TV02 D8 AC CK NA H Q 7.4.7.3.3B 1.50 NC L J 7.4.6.1.2.4 DESCRIPIION: AUX COOLING TO SUPP POOL CHK (CIV)

RCIC-V-30 M519 2 SA NA H Q 7.4.7.3.3B NOI C7 C CK NA H TS 7.4.7.3.6 8 NC DESCRIFIMN: SUPP POOL TO RCIC-P-I SUCT CHK RCIC-V-31 M519 2 MO C G 2Y 7.4.7.3.3C TV01,2 C7 A GT FAI HJ Q 7.4.7.3.3C 8 NC L 2Y 7.4.6.1.2.9 DESCRIPIION: SUPPRESSION POOL TO RCIC-P-1 SUCT (OTBD CIV)

Interval'NP-2 IST Program Plan 2nd 10-Year Page 95 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, Reliefs) Position)

& Sixe Normal RCIC-VAO M519 2 SA C H Q 7.4.7.3.3B TV02 E8 AC CK NA H Q 7.4.7.3.3C 10 NC 'L J 7.4.6.1.2.4 DESCRIFfION: RCIC TURBINE EXHAUST TO SUPP POOL CHK (CIV)

RCIC-VMS M519 2 MO NA G 2Y 7.4.7.3.3C NOI Fl I B GB FAI HJ Q 7.4.7.3.3C TVOI 4 NC DESCRIFfION: RCIC TURB STM SUPPLY ISO (MAIN TURBINE TRIP I/L)

RCIC-V46 M519 2 MO C G 2Y 7.4.7.3.3C TVOI Pl I B GB FAI HJ '

7.4.7.3.3C 2 NC DESCRIFfION: RCIC AUXILIARYCOOLING TO LO COOLER ISO RCIC-VA7 M519 2 SA C H Q 7.4.7.3.3C BIO C CK NA 2 NC DESCRIFfiON: RCIC-PP (CONDENSATE PUMP) DISCH CHK RCIC-V-50 M519 2 MO C G 2Y 7.4.7.3.3C TVOI F9 A GB FAI HJ Q 7.4.7.3.3C 2 LO L 2Y 7.4.6.1.2.9 DESCRIFflON: RCIC-HX-2 CW SUPPLY ISO RCIC-V-63 M519 1 MO C G 2Y 7.4.7.3.3C TV01,2 H3 A GT FAI HJ Q 7.4.7.3.3C 10 NO L J 7.4.6.1.2.4 DESCRIFfION: RCIC TURBINE STEAM SUPPLY (INBD CIV)

RCIC-V-64 M519 I MO C L J 7.4.6.1.2.4 TV02 G6 A GT NA r

10 LC DESCRIFfION: RCIC TURBINE STEAM SUPPLY TO RHR STM-COND (CIV)

RCIC-V-65 M519 I SA NA G 2Y 7.4.0.S.7F Nol H6 C CK NA H RF 7.4.0.5.7F 6 NC DESCRIPTION: RCIC-P-I DISCH TO RPV HEAD SPRAY CHK RCIC-V-66 M519 I SA C G 2Y 7.4.0.5.7F ROJ08 N02 J4 AC CK NA H RF 7.4.0.5.7F TV02 6 NC HL RF 7.4.4.3.2.2 DESCRIFfiON: RCIC TO RPV HEAD SPRAY CHK (INBD CIV)

RCIC-V-68 MS19 2 MO C G 2Y 7.4.7.3.3C TV01,2 E7 A GT FAI HJ Q 7.4.7.3.3C 10 NO L J 7.4.6.1.2.4 DESCRIFfiON: RCIC TURBINE EXHAUST TO SUPP POOL (OTBD CIV)

RCIC-V-69 M519 2 MO C G 2Y 7.4.7.3.3C TV01,2 D7 A Gf PAI HJ Q 7.4.7.3.3C 1.50 NO L J 7.4.6.1.2.4 DESCRIFfiON: RCIC VACUUM PUMP TO SUPP POOL (OTBD CIV)

RCIC-V-76 M519 I MO C G 2Y 7.4.7.3.3C TV01,2 H3 A GB FAI HJ Q 7.4.7.3.3C I NC L J 7.4.6.1.

2.4 DESCRIPTION

RCIC-V-63 BYPASS (INBD CIV)

11 of IST Program Plan 2nd 10-Year Interval WNP-2 Page 96 Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes tk Valve EPN Actuat, Safety, Tests, Frequency 8c PPM Coord tk Cat (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position) h Size Normal RCIC-V-110 M519 MO 0 G 2Y 7.4.7.3.3C TVOl E7 GT FAI HJ Q 7.4.7.3.3C 2 NO DESCRIPTION: RCIC TURBINE EXH TO SUPP POOL VAC REL ISO RCIC-V-111 M519 2 SA 0/C H Q 7.4.7.3.3B N04 E7 C CK NA 2 NC DESCRIPTION: RCIC TURBINE EXHAUST VACUUM BREAKER ISO RCIC-V-112 MS19 2 SA 0/C H Q 7.4.7.3.3B N04 E7 C CK NA 2 NC DESCRIFIION: RCIC TURBINE EXHAUST VACUUM BREAKER ISO RCIC-V-113 MS19 2 MO 0 G 2Y , 7.4.7.3.3C TVOI E7 B GT FAI HJ Q 7.4.7.3.3C 2 NO DESCRIFIION: RCIC TURB EXH TO SUPP POOL VAC REL ISO RCIC-V-184 M519 2 MA C L J 7.4.6.1.2.4 M H6 A GB NA I LC DESCRIPTION: AIR TO RCIC-V-66 OPERATOR MAN ISO (OTBD CIV)

RCIC-V-204 M519 2 SA C H Q 7.4.7.3.3C B14 C CK NA H ~

Q 7.4.7.3.3B 8 NC DESCRIFIION: RCIC PUMP SUCT FROM CST CHK RCIC-V-740 M519 2 MA C L J 7.4.6.1.2.4 TV02 H6 A GB NA'C DESCRIFFION: AIR TO RCIC-V-66 OPERATOR MAN ISO (INBD CIV)

RCIC-V-742 M519 I MA C L 18M 7.4.4.3.2.2 TV02 J6 A GB NA 0.75 LC DESCRIFHON: SAMPLE PROBE 19B MAN ISO (CIV)

REA-V-I M545-3 3 AO C G 2Y 7.4.3.7.5.1A TV01 Hl B BF FC HJK Q 7.4.6.5.2.1 72 NO DESCRIFriON: REACTOR BUILDINGEXHAUST REA-V-2 M545-3 3 AO C G 2Y 7.4.3.7;S.IA TVOI Hl B BF FC HJK Q . 7.4.6.5.2.1 72 NO DESCRIFrlON: REACTOR BUILDING EXHAUST RFW-V-IOA M529 I SA C GH CS 7.4.0.5.9D CSJ03 TV02 G12 AC CK NA GL 2Y 7.4.6.1.2.4 24 NO DESCRIFHON: RFW TO RPV CHK (INBD CIV)

RFW-V-IOB . M529 I 'SA C GH CS 7.4.0.5.9D CSJ03 TV02 G6 AC CK NA GL 2Y 7.4.6.1.2.4 24 NO DESCRIFHON: RFW TO RPV CHK (INBD CIV)

if f

of IST Program Plan 2nd 10-Year Interval WNP-2 Page 97 Revision 171 1

%NP-2 Valve Test Tables Type Position Testing Remarks Dwg h Class 1

Tests, Frequency A PPM Exceptions (Notes 4 Valve EPN Actuat, Safety, Coord 4 Cat Valve Failed, (CSJ/ROJ/ Technical Reliefs) Position) tk Sixe Normal RFW-V-32A M529 l. AO,SA C GH CS 7.4.0.5.9D CSJ03 N02 G13 AC CK NA GL 2Y 7.4.6.1.2.4 TV02 24 NO RFW-V-32B'529 GS DESCRIPTION: RFW TO RPV CHK (IST OTBD CIV)

I AC AO,SA CK C

NA GH GL CS 2Y 7.4.0.5.9D 7.4.6.1.2.4 CSJ03 '02 TV02 24 NO DESCRIPTION: RFW TO RPV CHK (IST OTBD CIV)

RFW-V-65A M529 I MO C G 2Y 7.4.0.5.9D CSJ03 TV01,2 G13 A GT FAI HJ CS 7.4.0.5.9D 24 NO L 2Y 7.4.6.1.2.4 DESCRIF11ON: RFW TO RPV ISO (2ND OTBD CIV)

RFW-V-65B M529 I MO C G 2Y 7.4.0.5.9D CSJ03 TV01,2 G4 A GT FAI HJ CS 7.4.0.5.9D 24 NO L 2Y 7.4.6.1.2.4 DESCRIFfION: RFW TO RPV ISO (2ND OTBD CIV)

RHR-FCV-64A M521-I 2 MO OIC G 2Y 7.4.5.1.8 TV01,2 B12 A GB FAI HJ Q 7.4.5.1.8 3 NO L J 7.4.6.1.

2.4 DESCRIPTION

RHR-P-2A MINIMUMFCV (CIV)

RHR-FCV-64B M521-2 2 MO 0/C G 2Y 7.4.5.1.9 TV01,2 B6 A GB FAI HJ

' 7.4.5.1.9 3 NO L J 7.4.6.1.

2.4 DESCRIPTION

RHR-P-2B MINIMUMFCV (CIV)

RHR-FCV44C M521-2 2 MO OIC G 2Y 7.4.5.1.10 TV01,2 D6 A GB ~

FAI HJ Q 7.4.5.1.10 3 NO L J 7.4.6.1.

2.4 DESCRIPTION

RHR-P-2C MINIMUMFCV (CIV)

RHR-RV-IA M521-I 2 SA NA P RV 7.4.0.5.20 TV02,3 H13 AC RV NA L J 7.4.6.1.2.1

.75X I NC RHR-RV-IB M HS 521-2 2 AC SA RV NA NA P,

DESGRIFHON: RHR-HX-IASHELL SIDE RV (CIV)

L RV J

7.4.0.5.20 7.4.6.1.2.1 TV02,3 75 X 1 NC DESCRIPTION: RHR-HX-IB SHELL SIDE RV (CIV)

RHR-RV-S M521-I 2 SA NA P RV 7.4.0.5.20 TV02,3 C8 AC RV NA L J 7.4.6.1.2.1 I X2 NC DESCRIPTION: RHR SHUTDOWN COOLING SUCT RV (CIV)

RHR-RV-25A M521-I 2 SA NA P RV 7.4.0.5.20 TV02,3 DIO AC RV NA L J 7.4.6.1.2.1 I X2 NC DESCRIFflON: RHR LOOP A TEST LINE RV (CIV)

RHR-RV-25B M521-2 2 SA NA P RV 7.4.0.5.20 TV02,3 CIO AC RV NA L J 7.4.6.1.2.1 I X2 NC DESCRIFI'ION: RHR LOOP B TEST LINE RV (CIV)

't Nf IK tl

IST Program Plan 2nd 10- Year Interval WNP-2 Page 98 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg tk Class Exceptions (Notes tk Valve EPN Actuat, Safety, Tests, Frequency tk PPM Technical Coord tk Cat (CSJ/ROJ/

Valve Failed, Reliefs) Position) tk Size Normal RHR-RV-25C M521-2 2 SA NA P RV 7.4.0.5.20 TV02,3 ES AC RV NA L J 7.4.6.1.2.1 IX2 NC DESCRIFIMN: RHR LOOP C TEST LINE RV (CIV)

RHR-RV-30 M521-2 2 SA NA P RV 7.4.0.S.20 TV02,3 C4 ~AC RV NA ' J 7.4.6.1.2.1

.75 X I NC DESCRIFI'ION: RHR FLUSH LINE RV (CIV)

RHR-RV-88A M521-I 2 SA NA P RV 7.4.0.S.20 TV02,3 C7 AC RV NA L J 7.4.6.1.2.1

.75X I NC DESCRIPTION: RHR-P-2A SUCT RV (CIV)

RHR-RV-8SB M521-2 2 SA NA P RV 7.4.0.S.20 TV02,3 B9 AC RV NA L J 7.4.6.1.2.1

.75 X I,NC DESCRIF11ON: RHR-P-2B SUCT RV (CIV)

RHR-RV-8 8C M521-2 2 SA NA P RV 7.4.0.S.20 TV02,3 CS AC RV NA' J 7.4.6.1.2.1

.75X I NC DESCRIF11ON: RHR-P-2C SUCT RV (CIV)

RHR-V-3A M521-I 2 MO 0/C G 2Y 7.4.5.1.8 TV01 GIO B GT FAI HJ Q 7.4.S.I.S 18 NO DES CRIF11ON: RHR-HX-IA OUTLET ISO RHR-V-3B J9, M521-2 2 B

MO GT 18 OIC FAI NO G

HJ 2Y Q

7.4.5.1.9 7.4.5.1.9 TV01 DESCRIFI'ION: RHR-HX-IB OUTLET ISO RHR-VAA M521-I 2 MO 0/C G 2Y 7.4.5.1.8 TV01,2 C7 A GT FAI HJ Q 7.4.5.1.8 24 NO L 2Y 7.4.6.1.2.9 DESCRIFI1ON: SUPPRESSION POOL TO RHR-P-2A SUCT (OTBD CIV)

RHR-VAB M521-2 2 MO OIC G 2Y 7.4.5.1.9 TV01,2 Bl 1 A GT FAI HJ Q 7.4.5.1.9 24 NO L 2Y 7.4.6.1.

2.9 DESCRIPTION

SUPPRESSION POOL TO RHR-P-2B SUCI'OTBD CIV)

99 of 171 IST Program Plan 2nd 10-Year Interval WNP-2 Page Revision 1

%NP-2 Ualve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJIROJI Valve Failed, Reiiefs) Position)

& Slxe Normal RHR-VAC M521-2 .2 MO 0/C G 2Y 7.4.5.1.10 TV01,2 Bl 1 A GT FAI HJ Q 7.4.5.1.10 24 NO L 2Y 7.4.6.1.2.9 DESCRIFfION: SUPPRESSION POOL TO RHR-P-2C SUCT (OTBD CIV)

RHR-V-6A M521-I 2 MO 0/C G 2Y 7.4.5.1.8 TVOl BS B GT FAI HJ Q 7.4.5.1.8 18 NC DESCRIPTION: RPV TO RHR-P-2A SUCT (SDC MODE)

RHR-V-6B M521-I 2 MO 0/C G 2Y 7.4.5.1.9 TVOI C7 B GT FAI HJ Q 7.4.5.1.9 18 NC DESCRIFfiON: RPV TO RHR-P-2B SUCf (SDC MODE)

RHR-V-8 M521-I 1 MO 0/C G 2Y 7.4.0.5.&D ROJ10 TV01,2 E6 A GT FAI HJ RF 7.4.0.5.&D 20 NC L 18M 7.4.4.3.2.2 DESCRIFfION: RHR SDC MODE SUPPLY FOR A & B FROM RPV (OTBD CIV)

RHR-V-9 M521-I D6 A I MO GT OIC FAI G,

HJ 2Y RF 7.4.0.5.&D 7.4.0.5.&D ROJIO TV01,2 20 NC L 18M '7.4.4.3.2.2 DESCRIPflON: RHR SDC MODE SUPPLY FOR A 8'c B FROM RPV (INBD CIV)

RHR-V-IIA MS21-I El I A 2

GI'A MO 4

C LC L J 7.4.6.1.2.4 TV02 DESCRIPflON: RHR STM-COND TO SUPP POOL ISO (CIV)

RHR-V-I IB M521-2 Cl I 2

A GI'A MO 4

C LC L J 7.4.6.1.2.4 TV02 DES CRIFfION: RHR B STM-COND TO SUPP POOL ISO (CIV)

RHR-V-16A M521-I 2 MO 0/C 6 2Y 7.4.0.5.&A CSJI 5 TV01,2 H7 A GT FAI HJ CS 7.4.0.5.8A 16 NC L J 7.4.6.1.2.4 DESCRIPflON: RHR TO DRYWELLSPRAY HEADER (2ND OTBD CIV)

RHR-V-16B M521-2 2 MO 0/C G 2Y 7.4.0.5.&A CSJ 1 5 TV01,2 DIO A GT FAI HJ CS 7.4.0.5.&A 16 NC L J 7.4.6.1.2.4 DESCRIPIMN: RHR TO DRYWELL SPRAY HEADER (2ND OTBD CIV)

RHR-V-17A M521-I 2 MO 0/C 6 2Y 7.4.0.5.8A CSJIS TV01,2 HS A GT FAI HJ CS 7.4.0.S.SA 16 NC L J 7.4.6.1.2.4 DES CRIFflON: RHR TO DRYWELL SPRAY HEADER (IST OTBD CIV)

RHR-V-17B M521-2 2 MO OIC G 2Y 7.4.0.5.&A CSJ 1 5 TV01,2 Dl 1 A GT FAI HJ CS 7.4.0.S.SA 16 NC L J 7.4.6.1.2.4 DES CRIFfION: RHR TO DRYWELL SPRAY HEADER (IST OTBD CIV)

RHR-V-21 M521-2 2 MO C G 2Y 7.4.5.1.10 TV01,2 E8 A GB FAI HJ Q 7.4.5.1.10 18 NC L J 7.4.6.1.

2.4 DESCRIPTION

RHR LOOP C TEST LINE TO SUPP POOL (OTBD CIV)

IST Program Plan 2nd 10- Year Interval WNP-2 Page 100 of 171 1 'evision WNP-2 Valve Test Tables Type Position Testing Remarks Dwg 4 Class Exceptions (Notes h Valve EPN Coord 4 Cat Actuat, Safety, Tests, Frequency 4 PPM (CSJ/ROJ/ Technical Valve Failed, Reliefs) Position) 8c Size Normal RHR-V-23 M521-2 I MO C G 2Y 7.4.0.5.8A CSJOI TV01,2 J13 A GB FAI HJ CS 7.4.0.5.8A 6 NC L 18M 7.4.4.3.

2.2 DESCRIPTION

RHR TO RCIC RPV HEAD SPRAY (OTBD CIV)

RHR-V-24A M521-1 2 MO 0/C G 2Y 7.4.5.1.8 TV01,2 E9 A GB FAI HJ Q 7.4.5.1.8 18 NC L J 7.4.6.1.2.4 DESCRIFriON: RHR LOOP A TEST LINE TO SUPP POOL (OTBD CIV)

RHR-V-24B M521-2 2 MO 0/C G 2Y 7.4.5.1.9 TV01,2 Cl I A GB FAI HJ Q 7.4.5.1.9 18 NC L J 7.4.6.1.2.4 DESCRIFHON: RHR LOOP B TEST, LINE TO SUPP POOL (OTBD CIV)

RHR-V-27A M521-1 2 MO 0/C G 2Y 7.4.5.1.8 TV01,2 D7 A GT FAI HJ Q 7.4.5.1.8 6 NC L J 7.4.6.1.2.4 DES CRIFI1ON: RHR TO SUPPRESSION CHAMBER SPRAY HEADER (OTBD CIV)

RHR-V-27B M521-2 2 MO 0/C G 2Y 7.4.5.1.9 TV01,2 Cl I A GT FAI HJ Q 7.4.5.1.9 6 NC L J 7.4.6.1.2.4 DESCRIF110N: RHR TO SUPPRESSION CHAMBER SPRAY HEADER (OTBD M521-1 2 SA 0 H Q 7.4.5.1.8 CIV)'HR-V-31A C14 C CK NA /

18 NC DES CRIFHON: RHR-P-2A DISCH CHK RHR-V-31B MS21-2 2 SA 0 H Q 7.4.5.1.9 C3 C CK NA 18 NC DES CRIFHON RHR-P-2B DISCH CHK RHR-V-3 1C MS21-2 2 SA 0 H Q 7.4.5.1.10 CS C CK NA

/ 18 NC DES CRIFHON: RHR-P-2C DISCH CHK RHR-V-40 M521-2 2 MO C G 2Y 7.4.5.1.9 TVOI G4 B GB FAI HJ Q 7.4.5.1.9 4 NC DESCRIPTION: RHR LOOP B TO EDR (SDC WARMUP LINE) ISO RHR-VAI A M521-I I SA 0/C H RF 7.4.0.5.7A ROJ08 TV02 FS AC CK NA HL RF 7.4.4.3.2.2 14 NC DES CRIFHON: RHR A LPCI TO RPV CHK (INBD CIV)

RHR-BIB M521-2 I SA 0/C H RF 7.4.0.5.7B ROJ08 TV02 G13 AC CK NA HL RF 7.4.4.3.2.2 14 NC DES cRIFfioN:

'HR B LPCI TO RPV (INBD CIV)

RHR-VAI C M521-2 I SA 0/C H RF 7.4.0.5.7C ROJ08 TV02 D13 AC CK NA HL RF 7.4.4.3.2.2 14, NC DES CRIFHON: RHR C LPCI TO RPV (INBD CIV)

of IST Program Plan 2nd 10-Year Interval WNP-2 Page 101 Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, Reliefs) Position)

& She Normal RHR-V-42A M521-I l. ~

MO 0/C G 2Y 7.4.0.5.8A CSJ08 TV01,2 G7 A GT FAI HJ CS 7.4.0.5.8A 14 NC L 18M 7.4.4.3.2.2 DESCRIPI10N: RHR A LPCI MODE TO RPV (OTBD CIV) 0/C 7.4.0.5.8A TV01,2 RHR-V-42B M521-2 F12 1

A GI'AI MO 14 NC G

HJ L

2Y CS 18M

'.4.0.5.8A 7.4.4.3.2.2 CSJ08 DESCRIFI'ION: RHR B LPCI MODE TO RPV (OTBD CIV)

RHR-V42C M521-2 I MO 0/C G 2Y 7.4.0.5.8A CSJOS TV01,2 E12 A GT FAI HJ CS 7.4.0.5.8A 14 NC L I SM 7.4.4.3.2.2 DESCRIPriON: RHR B LPCI MODE TO RPV (OTBD CIV) 0 RHR-V-47A M521-I J13 2

B Gl'AI MO 18 NO G

HJ 2Y Q

7.4.5.1.8 7.4.5.1.8 TVOI DESCRIPTION: RHR-HX-IAINLET ISO RHR-V47B M521-2 2 MO 0 2Y 7.4.5.1.9 TVOI J3 B GT 'AI G HJ Q 7.4.5.1.9 18 NO DESCRIPTION: RHR-HX-IB INLET ISO RHR-VISA M521-I 2 MO 0/C G 2Y 7.4.5.1.8 TVOI Jll B GB FAI HJ Q 7.4.5.1.8 18 NO DESCRIPIION: RHR-HX-1A BYPASS RHR-VASB M521-2 2 MO 0/C G 2Y 7.4.5.1.9 TVOI

,JS B GB PAI HJ Q 7.4.5.1.9 18 NO DESCRIPTION: RHR-HX-IB BYPASS RHR-V-49 M521-2 2 MO C G 2Y 7.4.5.1.9 TV01 G4 B GT FAI HJ Q 7.4.S.1.9 4 NC DESCRIPTION: RHR LOOP B TO EDR (SDC WARMUP LINE) ISO 0/C RHR-V-SOA M521-1 FS I

AC SA CK NA H

HL 'FRF 7.4.0.5.7A 7.4.4.3.2.2 ROJ08 TV02 12 NC DESCRIPTION: RHR A SDC TO RPV CHK (INBD CIV)

RHR-V-SOB M521-2 1 SA OIC H RF 7.4.0.5.7B ROJ08 TV02 F13 AC CK NA HL RF 7.4.4.3.2.2 12 NC DESCRIPTION: RHR B SDC TO RPV (INBD CIV)

RHR-V-53A M521- I I MO 0/C G 2Y 7.4.0.5.8A CSJOI TV01,2 F6 A GT FAI HJ CS 7.4.0.5.8A 12 NC L 18M 7.4.4.3.

2.2 DESCRIPTION

RHR A SDC MODE TO RPV (OTBD CIV)

RHR-V-53B M521-2 I MO OIC G 2Y 7.4.0.5.8A CSJOI TV01,2 Fl 1 A GT PAI HJ CS 7.4.0.5.8A 12 NC L 18M 7.4.4.3.

2.2 DESCRIPTION

RHR B SDC MODE TO RPV (OTBD CIV)

I' of 1ST Program Plan 2nd 10-Year Interval WNP-2 Page 102 Revision 171 1

WNP-2 Valve Test Tables Position Testing Remarks Dug & Chss Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, RHR-V-60A M521-1 Gl I B 2

& Size SO SV Normal C

FC G 'Y HJK Q 7.4.5.1.8 7.4.5.1.8 Reiiefs) Position)

TVOI 0.75 NC DESCRIPTION: RHR A SAMPLE PROBE 22A ISO RHR-V-60B M521-2 2 SO C G 2Y 7.4.5.1.9 TVOI H9 B SV FC HJK Q 7.4.5.1.9 0.75 NC DESCRIPTION: RHR B SAMPLE PROBE 22B ISO RHR-V-68A M524-1 3 MO 0 G 2Y 7.4.0.5.16 TVOI D14 B GT FAI HJ Q 7.4.0.5.16 16 NO DESCRIPTION: SW FROM RHR-HX-IAISO RHR-V 68B M524-2 3 MO 0 G 2Y 7.4.0.5.17 TVOI G14 B GT FAI HJ Q 7.4.0.5.17 16 NO DESCRIPTION: SW B FROM RHR-HX-IB ISO RHR-V 73A M521-I 2 MO C G 2Y 7.4.5.1.8 TV01,2 H14 A GB FAI HJ Q 7.4.5.1.8 2 NC L J 7.4.6.1.

2.4 DESCRIPTION

RHR-HX-lASHELL SIDE VENT (OTBD CIV)

RHR-V-73B M521-2 2 MO C G 2Y 7.4.5.1.9 TV01 i2 H4 A GB FAI HJ Q 7.4.5.1.9 2 NC L J 7.4.6.1.

2.4 DESCRIPTION

RHR-HX-IB SHELL SIDE VENT (OTBD CIV)

RHR-V-75A M521-I 2 SO C G 2Y 7.4.5.1.8 TV01 Gl I B SV FC HJK Q 7.4.5.1.8 0.75 NC DESCRIPTION: RHR A SAMPLE PROBE 22A ISO RHR-V-75B MS21-2 2 SO C G 2Y 7.4.5.1.9 TV01 HS B SV FC HJK Q 7.4.5.1.9 NC '.75 DESCRIPTION: RHR B SAMPLE PROBE 22B ISO RHR-V-84 A M 521-I 2 SA C H Q 7.4.5.1.8 RV02 DIS C CK NA 1.SO NC DESCRIPTION: LPCS-P-2 (WATER LEG) TO, RHR A CHK RHR-V-84B MS21-2 2 SA C H Q 7.4.5.1.9 RV02 B4 C CK NA 1.50 NC DESCRIPTION: RHR-P-3 (WATER LEG) DISCH TO RHR B CHK RHR-V-84C M521-2 2 , SA C H Q 7.4.5.1.10 RV02 C6 C CK NA 1.50 NC DESCRIPTION: RHR-P-3 (WATER LEG) DISCH TO RHR C CHK RHR-V-SSA M521-I 2 SA,MA, C H Q 7.4.5.1.8 RV02 C14 C SC NA I.SO NC, DESCRIPTION: LPCS-P-2 (WATER LEG) TO RHR A STOP CHK

of IST Program Plan 2nd 10- Year Interval WNP-2 Page 103 Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Chss Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, ReHefs) Position)

& Size Normal RHR-V-85B M521-2 SA,MA C H Q 7.4.5.1.9 RV02 C4 SC NA I.SO NC DESCRIFfION: RHR-P-3 (WATER LEG) DISCH To RHR B STOP CHK RHR-V-85C M521-2 2 SA,MA C H Q 7.4.5.1.10 RV02 C6 C SC NA I.SO NC DESCRIFfioN: RHR-P-3 (WATER LEG) DISCH To RHR C STOP CHK RHR-V-120 M521-1 2 MA C L J 7.4.6.1.2.4 TV02 Cl 1 A GT NA 3 LC DESCRlpfION: RHR A To FDR SYS MAN ISO (CIV)

RHR-V-121 M521-1 2 MA C L J 7.4.6.1.2.4 TV02 Cl I A GT NA 3 LC DESCRIPfloN: RHR A To FDR SYS MAN ISO (CIV)

RHR-V-123A MS21-I I MO C G 2Y 7.4.0.5.8D ROJ I I TV01,2 ES A GT FAI HJ RF 7.4.0.5.8D 1 NC L 18M 7.4.4.3.2.2 DESCRIFfioN: RHR-V-SOA BYPASS (INBD CIV) (MOTOR DEENERGIZED)

RHR-V-123 B M521-2 I Mo C G 2Y 7.4.0.5.8D ROJI I TV01,2 E13 A Gf FAI HJ RF, 7.4.0.5.8D I NC L 18M 7.4.4.3.2.2 DESCMFfiON: RHR-V-SOB BYPASS (INBD CIV) (MOTOR DEENERGIZED)

RHR-V-124A MS21-1 2 MO C L J 7.4.6.1.2.4 TV02 B13 A GB NA 1.50 LC DESCRIFfioN: RHR STM-COND DRN To SUPP POOL (CIV)

RHR-V-124B M521-1 2 Mo C L J 7.4.6.1.2.4 TV02 C13 A GB NA 1.50 LC DES CRIPfioN: RHR STM-COND DRN TO SUPP POOL (CIV)

RHR-V-125A M521-2 2 MO C L J 7.4.6.1.2.4 D4 A GB NA 1.50 LC DESCMFfiON: RHR STM-COND DRN TO SUPP POOL (CIV)

RHR-V-125B M521-2 2 Mo C L J 7.4.6.1.2.4 TV02 D4 A GB NA 1.50 LC DES CMPfION RHR STM-COND DRN To SUPP POOL (CIV)

RHR-V-134A M521-1 2 Mo 0/C G 2Y '.4.0.5.14A TV01,2 E14 A GB FAI HJ Q 7.4.0.5.14A 2 NC L J 7.4.6.1.2.4 DESCMPfioN: CAC TIE TO RHR (OTBD CIV)

RHR-V-134B MS21-2 2 MO 0/C G 2Y 7.4.0.5.14B TV01,2 ES A GB FAI HJ Q 7.4.0.S.14B 2 NC L J 7.4.6.1.2.4 DES CRIFfioN: CAC TIE TO RHR (OTBD CIV)

IST Program Plan 2nd 10-Year Interval WNP-2 Page 104 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Valve EPN Dwg & Class Actuat, Safety, Tests, Frequency A PPM Exceptions (Notes 4 Coord a Cat Valve (CSJ/ROJ/ Technical Failed, Reliefs) Position) 4 Size Normal RHR-V-209 M521-I I SA 0/C H RF 7.4.0.5.7A ROJ03 DS AC CK NA L I SM 7.4.4.3.2.2 0.75 NC DES CRIPHON THERMAL RELIEF CHK BETWEEN RHR-V-8 AND 9 (CIV)

RHR-V-503 M521- I 2 SA C H Q 7.4.5.1.8 A8 C CK NA 0.50 NC DESCRIPTION: RHR-V-6A LEAK BY-PASS CHK ROA-V-I M545-3 3 AO C G 2Y 7.4.3.7.5.1A TVOI Dl B BF FC HJK Q 7.4.6.5.2.1 84 NO DESCRIPTION: REACTOR BUILDINGISO ROA-V-2 M545-3 3 AO C G 2Y 7.4.3.7.5.1A TVOI DESCRIPTION: '2

,B BF FC HJK Q 7.4.6.5.2.1 84 NO REACI'OR BUILDING ISO RRC-V-13A M530-I 2 SA C H CS 7.4.0.5.9B C13 AC CK NA L J 7.4.6.1.2.4 0.75 NO DESCRIPTION: RRC PUMP SEAL PURGE INLET CHK (INBD CIV)

WNP-2 Valve Test Tables Position Testmg Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, Reliefs) Position)

& Site Normal SGT-V-5B I M544 MO OIC G 2Y 7.4.3.7.5.1A 'TVOI CS BF FAI HJ Q 7.4.0.S.5SB 18 NC DESCRIPTION: SGT-FN-IBI OUTLET SGT-V-5B2 M544 2 MO OIC G 2Y 7.4.3.7.5.1A TVOI ES B BF FAI HJ Q 7.4.0.5.58B 18 NC DESCRIPTION: SGT-FN-IB2 OUTLET SLC-RV-29A M522 2 SA NA P RV 7.4.0.5.20 TV03 F6 C RV NA I X2 NC DESCRIPTION: SLC-P-IA DISCH RV SLC-RV-29B M522 2 SA NA P RV 7.4.0.5.20 TV03 D6 C RV NA I X2 NC DESCRIPTION: SLC-P-IB DISCH RV SLC-V-IA M522 2 MO 0 G 2Y 7.4.1.5.3 TVOI E4 B GB FAI HJ Q 7.4.1.5.3 4 NC DESCRIPFION: SLC-TK-IA (STORAGE TANK) TO SLC-P-I A SUCT ISO SLC-V-IB M522 2 MO 0 G 2Y 7.4.1,5.3 TVOI D4 B GB FAI HJ Q 7.4.1.5.3 4 NC DESCRIPriON: SLC-TK-IB (STORAGE TANK) TO SLC-P-IB SUCT ISO SLC-VAA M522 I SO OIC L J 7.4.6.1.2.4 TV02 FS AD EX NA V EX 7.4.1.5A I.SO, NC SLC-VAB M522 DS I

AD SO EX

'/C DESCRIPIION: SLC-P-IA DISCH TO RPV ISO (EXPLOSIVE OTBD CIV)

NA L

V J

EX 7.4.6.1.2.4 7.4.1.5B TV02 1.50 NC DESGRIPI10N: SLC-P-IB DISCH TO RPV ISO (EXPLOSIVE OTBD CIV)

SLC-V-6 M522 I . SA 0 H RF 7.4.1.5A, B ROJOI Fll C CK NA~

1.50 NC DESCRIPTION: SLC TO RPV CHK SLC-V-7 M522 I SA 0/C H RF 7.4.1.5A, B ROJOI . TV02 H13 AC CK NA HL RF 7.4.6.1.2.4 1.50 NC DESCRIPIMN: SLC TO RPV CHK (INBD CIV)

SLC-V-33A M522 2 SA 0/C H Q 7.4.1.5.3 F7 C CK NA I.SO NC DESCRIPTION: SLC-P-IA DISCH CHK 8LC-V-33B M522 2 'SA 0/C H Q 7.4.1.S.3 D7 C CK NA'.50 NC DESCRIPfiON: SLC-P>>IB DISCH CHK

4l of 1ST Program Plan 2nd 10- Year Interval WNP-2 Page 107 Revision 171 1

WNP-2, Ualve Test Tables Type Position Testing Remarks Dwg Ec Class Exceptions (Notes tk Valve EPN Actuat, Safety, Tests, Frequency tk PPM Coord tk Cat (CSJ/ROJ/ Technical Valve Failed, Reilefs) Position) tk Size Normal SW-RV~IA M524-1 SA NA P RV 7.4.0.5.20 TV03 C14 RV NA

.75 X I NC DESCRIPTION: RHR-HX-IATUBE SIDE RV SW-RVMIB M524-2 3 SA NA P RV 7.4.0.5.20 TV03 F14 C RV NA

.75 X 1 NC DESCRIPTION: RHR-HX-IB TUBE SIDE RV SW-TCV-I IA M775 HO 0 HK RF 7.4.0.5.52 RV03 HS GB FO 2.50 NT EMERGENCY CHILLED WATER FROM WMA-CC-51A-1 TCV 'ESCRIFIION:

SW-TCV-I IB M775 3 HO O HK RF 7.4.0.5.52 RV03 CS B GB FO 2.50 NT DESCRIPTION: EMERGENCY CHILLED WATER FROM WMA-CC-51B-I TCV SW-V-IA MSMI SA 0 H Q 7.4.0.5.16 H5 CK NA 20 NC DESCRIPTION: SW-P-IA DISCH CHK SW-V-IB M524-2 3 SA 0 H Q 7.4.0.5.17 G5 C CK NA 20 NC DESCRIPTION: SW-P-IB DlSCH CHK SW-V-2A M524-I 3 MO 0/C G 2Y 7.4.0.5.16 TVOI H6 B BF FAI HJ Q 7.4.0.5.16 20 NC DESCRIPI'ION: SW-P-IA DISCH ISO SW-V-2B M524-2 3 MO O/C G 2Y 7.4.0.5.17 TVOI G6 B BF FAI HJ Q 7.4.0.5.17 20 NC DESCRIPI'ION: SW-P-IB DISCH ISO SW-V-12A M524-1 3 MO 0/C G 2Y 7.4.0.5.16 TVOI G3 B GT FAI HJ Q 7.4.0.5.16 18 NC DESCRIFfION: SW A RETURN TO SPRAY POND B ISO SW-V-12B M524-2 3 MO 0/C G 2Y 7.4.0.5.17 TVOI G3 B GT FAI HJ Q 7.4.0.5.17 18 NC DESCRIPTION: SW B RETURN TO SPRAYPOND A ISO SW-V-29 M524-I 3 MO 0/C G 2Y 7.4.0.5.18 TVOI G6 B BF FAI HJ Q 7.4.0.5.18 8 NC DESCRIPTION: HPCS-P-2 DISCH ISO SW-V-34 M524-2 3 SO 0 G 2Y 7.4.0.5.17 TVOI Cl I B GB FO HJK Q 7.4.0.5.17 1.50 NO DESCRIPTION: SW FROM RCIC-P-I ROOM RRA-CC-6 ISO

)P IST Program Plan 2nd 10-Year Interval WNP-2 Page 108 of Revision 171 1

WNP-2 Valve Test Tables Type Position Testing Remarks Dwg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Coord & Cat (CSJ/ROJ/ . Technical Valve Failed, Reliefs) Position)

& Size Normal SW-V-75A M524-I MO 0/C G 2Y 7.4.0.5.16 TVOI B13 GB FAI HJ Q 7.4.0.5.16 2 NC DESCRIPTION: SW TIE TO FPC LOOP A SW-V-75AA M524-1 3 MA 0/C H Q 7.4.0.5.16 A13 B GB FAI 2 NC DESCRIPI10N: SW CROSSTIE TO FPC MAN ISO SW-V-75B M524-2 3 MO 0/C G 2Y 7.4.0.5.17 TVOI B14 B GB FAI HJ Q 7.4.0.5.17 2 NC DESCRIPfION: SW TIE TO FPC LOOP B SW-V-75BB M524-2 3 MA 0/C H Q 7.4.0.5.17 B14 B GB FAI 2 NC DESCRIPIMN: SW CROSSTIE TO FPC MAN ISO SW-V-165A M524-1 3 MA 0/C H Q 7.4.0.5.16 D3 B BF NA'8 NO DESCRIPTION: SW A RETURN TO SPRAY POND B SPRAY RING HDR BYPASS SW-V-165B M524-2 3 MA 0/C H Q 7.4.0.5.17 K3 B BF NA 18 NO DESCRIPTION: SW B REI'URN TO SPRAY POND A SPRAY RING HDR BYPASS SW-V-170A M524-I 3 MA 0/C H Q 7.4.0.5.16 D3 B BF NA 18 NC DESCRIPTION: SW A RETURN TO SPRAY POND B SPRAY RING HDR MAN ISO SW-V-170B M524-2 3 MA 0/C H Q 7.4.0.5.17 K4 B BF NA 18 NC DESCRIPfiON: SW B RETURN TO SPRAY POND A SPRAY RING HDR MAN ISO SW-V-187A M524-I 3 MO 0 G 2Y 7.4.0.5.16 TVOI G14 B GT FAI HJ Q 7.4.0.5.16 6 NC DESCRIPIION: SW TO FPC HX-IA INLET SW-V-187B M524-2 3 MO 0 G 2Y 7.4.0.5.17 TV01 C13 B GT FAI HJ Q 7.4.0.5.17 6 NC DESCRIPrION: SW TO FPC-HX-IB INLET SW-V-1SSA M524-1 3 MO 0 G 2Y 7.4.0.5.16 TVOI H13 B GT FAI HJ Q 7.4.0.5.16 6 NC DESCRIPTION: SW FROM FPC-HX-IA OUTLET SW-V-188B M524-2 3 MO 0 G 2Y 7.4.0.5.17 TV01 D12 B GT FAI HJ Q 7.4.0.5.17 6 NC DESCRIPTION: SW FROM FPC-HX-1B OUTLET

of IST Program Plan 2nd 10- Year Interval WNP-2 Page 109 Revision 171 1

1 WNP-2 Valve Test Tables Type Position Testing Remarks Ihvg & Class Exceptions (Notes &

Valve EPN Actuat, Safety, Tests, Frequency & PPM Technical Coord & Cat (CSJ/ROJ/

Valve Failed, Reliefs) Position)

& Size Normal SW-V-226A M775 3 SA C H Q 7.4.0.5.52 F6 C CK NA.

3 ~NC DESCRIFfION: CCH-EV-IA (EVAPORATOR) OUTLET CHK SW-V-226B M775 3 SA C H Q 7.4.0.5.52 B6 C CK NA 3 NC DESCRIPTION: CCH-EV-IB (EVAPORATOR) OUTLET CHK SW-V-227A M775 3 MA C H Q 7.4.0.S.52 H7 B GT NA 3 NC DESCRIFIlON: CCH-P-IA SUCT MAN ISO SW-V-227B M775 3 MA C H Q 7.4.0.5.52 C7 B, GT NA 3 NO DESCRIFfiON: CCH-P-1B SUCT MAN ISO SW-V-822A M77S 3 MA 0 H Q 7.4.0.5.S2 JS B GT NA 3 NO DESCRIFTION: SW TO WMA-CC-S1 A-I (CR CHILLER) MAN ISO SW-V-822B M775 3 MA 0 H Q 7.4.0,5.52 ES B GT NA 3 NC DESCRIFfiON SW TO WMA-CC-51B-I (CR CHILLER) MAN ISO SW-V-823A M775 3 MA 0 H Q 7.4.0.S.52 JS B GT NA 3 NO DESCRIPTION: SW FROM WMA-CC-SIA-I (CONTROL RM CHILLER) MAN ISO SW-V-823 B M775 3 MA 0 H Q 7.4.0.5.52 ES B GT NA 3 NC DESCRIFfiON: SW FROM WMA-CC-SIB-1 (CONTROL RM CHILLER) MAN ISO TIP-V-I M604 2 SO C G 2Y 7.4.0.5.13 TV01,2 G13 A BA FC HJK Q 7.4.0.5.13 0.375 NC GL 18M 7.4.6.1.2.4 DESCRIFI'ION: TIP LINE BALL-TYPE ISO VLV (1ST OTBD CIV)

TIP-V-2 M604 2 SO C G 2Y 7.4.0.5.13 TV01,2 G13 A BA FC HJK Q 7.4.0.5.13 0.375 NC GL ISM 7.4.6.1.2.4 DESCRIFFION: TIP L1NE BALDTYPE 1SO VLV (1ST OTBD CIV)

TIP-V-3 M604 2 SO C G 2Y 7.4.0.5.13 TV01,2 G12 A BA FC HJK Q 7.4.0.5.13 0.375 NC GL 18M 7.4.6.1.

2.4 DESCRIPTION

TIP LINE BALL-TYPE ISO VLV (1ST OTBD CIV)

TIP-V-4 M604 2 SO C G 'Y 7.4.0.5.13 TV01,2 H12 A BA FC HJK Q 7.4.0.5.13 0.375 NC GL 18M 7.4.6.1.2.4 DESCRIFIMN: TIP LINE BALL-TYPE ISO VLV (IST OTBD CIV)

of IST Program Plan 2nd 10- Year Interval WNP-2 Page 110 Revision 171 1

%NP-2 Valve Test Tables Type Position Testing Remarks Dwg h Class Tests, Frequency 4 PPM Exceptions (Notes 4 Valve EPN Actuat, Safety,

- Coord a Cat Valve Failed, (CSJ/ROJ/ Technical Reliefs) Position) 4 Size Normal TIP-V-5 M604 2 SO C G 2Y 7.4.0.5.13 TV01,2 H12 A BA FC HJK Q 7.4.0.5.13 0.375 NC GL ISM 7.4.6.1.2.4 DESCRIFHON: TIP LINE BALL-TYPE ISO VLV (IST OTBD CIV)

TIP-V-6 M604 2 SA C H RF, 7.4.0.5.7H ROJ04 TV02 F12 AC CK NA L J 7.4.6.1.2.4 0.375 NO DESCRIFI'ION: TIP PURGE LINE CHK (INBD CIV)

TIP-V-7 M604 D SO C V EX 7.4.6.3.5.2 NIO G13 AD EX FAI TV02 0.375 NO TIP-V-8 DES CR1FHON:

M604 G13 D

AD

'O TIP LINE SHEAR-TYPE ISO VLV (2ND OTBD CIV)

EX C

FAI V EX 7.4.6.3.5.2 NIO TV02 0.375 NO DESCRIPTION: TIP LINE SHEAR-TYPE ISO VLV (2ND OTBD CIV)

TIP-V-9 M604 D SO C V EX 7.4.6.3.5.2 N 10 H12 AD EX FAI TV02 0.375 NO DESCRIFI1ON: TIP LINE SHEAR-TYPE ISO VLV (2ND OTBD CIV)

TIP-V-10 M604 D SO C V EX 7.4.6.3.5.2 NIO H12 AD EX FAI TV02 0.375 NO DESCRIPTION: TIP LINE SHEAR-TYPE ISO VLV (2ND OTBD CIV)

TIP-V-11 M604 D SO C V EX 7.4.6.3.5.2 NIO

,HI2 AD EX FAI TV02 0.375 NO DESCRIFI'ION: TIP LINE SHEAR-TYPE ISO VLV (2ND OTBD CIV)

TIP-V-15 M604 2 SO C G 2Y 7.4.0.5.13 TV01,2 G13 A SV FC HJK Q 7.4.0.5.13 I NO GL 18M 7.4.6.1.2A DESCRIPTION: TIP PURGE LINE CHK (OTBD CIV)

I,

~ t

IST Program Plan 2nd 10-Year Interval WNP-2 Page 111 of Revision 171 1

4.4 In ervice Testin Pro m Notes The following additional information/methodologies are provided as Notes to the Valve Inservice Testing Program. The Note numbers correspond to the notes listed throughout the valve test tables.

N TEN1 Only those valves which are required to perform a specific function in shutting down the reactor to the cold shutdown condition, in maintaining the cold shutdown condition, or in mitigating the consequences of an accident are required to be tested per OM Part 10. Using this criteria the following valves are not requhed to be tested per OM Part 10, but due to their functional importance ae included in the valve list at the Owner's discretion.

RCIC-V-30, 45, 65 RCIC-V-65 is verified open only during refueling outages.

RCIC-V-30 will be partial-stroke exercised quarterly and full-stroke exercised during outages at Technical Specification frequency. A relief request is not required for this valve since it is not required to be included in the IST program.

N TE N02 The valve actuator was installed to facilitate stroke testing of the valve. It is not intended for use in normal system operations and is therefore, exempt from paragraph 4.2.1.4 (stroke-time measurement) and paragraph 4.2.1.6 (operation of fail-safe actuators) requirements.

RCIC-V-66 RFW-V-32A, 32B CVB-V-1AB, CD, EF, GH, JK, LM, NP, QR, ST CSP-V-7, 8, 10

of IST Program Plan 2nd 10- Year Interval WNP-2 Page 112 Revision 171 1

These valves are operated by a programmer with an index wheel. The programmer is activated by logic which trips on low header pressure or on header isolation combined with low header pressure. The programmer rotates one position to deenergize a solenoid and open a nitrogen bottle isolation valve. If the low pressure condition persists, in 30,seconds, the programmer rotates and another solenoid is deenergized to open another nitrogen bottle isolation valve. The index wheel is equipped with a window through which a number 1 through 20 may be seen.

Each number corresponds to the number of solenoids deenergized in its rotational sequence which corresponds directly with the number of valves that are open.

It is the Owner's position that this is not a "Valve Position Indicator" as used in paragraph 4.1.

At best it is an indicator of whether or not specific solenoids should be energized or not.

CIA-SPV-1A through 15A CIA-SPV-1B through 19B N~TB N04

=

The following valves do not serve as ASME over pressure protection devices and as such are outside the scope of OM Part 1.

RCIC-V-111 and RCIC-V-112 RHR-V-209

, ~NTB N05 The following CRD valves (typical of 185 valves) perform a function important to safety. These valves are non-ASME and as such are not required to be included in the IST program by 10CFR50.55a or by GL 89-04. These valves are being tested per WNP-2 Technical Specifications referenced against each valve. This alternate testing complies with position 7 of GL 89-04.

Tested Per Technical Valve Category Function Specifications Check Valve to SCRAM CRD-V-114 C 4.1.3.2 (a, b, & c)

Header CRD-V-115 Charging Water Check Valve 4.1.3.5.b.2 CRD-U-126 Drive Water AOV 4.1.3.2(a, b, & c)

CRD-V-127 B Withdraw AOV 4.1.3.2 (a, b, &'c)

CRD-V-138 C Cooling Water Check Valve 4.1.3.1.2.a .

>I J

UI

of IST Program Plan 2nd 10- Year Interval WNP-2 Page 113 Revision 171 1

C NOTE N06 The following emergency diesel generator air start system valves perform a function important to safety. These valves are non-ASME and as such are n'ot required to meet the testing requirements of OM Part 10. These valves will be tested during DG Air Starter Motor Testing as part of post maintenance testing and prior to return to service. Note that two valves will be tested at a time but a failure of a single valve would be detected.

Ualve DSA-SPU-5A1/2 DSA-SPV-5A1/4 DSA-8PV-5A2/2 DSA-SPY-5A2/4 DSA-SPV-5B1/2 DSA-SPV-5B1/4 DSA-SPV-5B2/2 DSA-SPV-5B2/4 DSA-SPV-5C1/1 DSA-SPV-5C1/2 N TEN7 Affected Valves Class Cat. Function System(s)

CAC-V-3A, B CAC-MS-1A Drain Valve (skid mounted)

Containment SW to CAC-EV-lA temperature control Atmosphere Control CAC-TCV-4A, B valve (skid mounted)

Each valve is skid mounted and is provided with an electro-hydraulic actuator that is normally de-energized unless the CAC skid is energized. These valves are not provided with control switches with which'to cycle the valve. CAC-V-3A (B) opens during skid operation when a high level in CAC-MS-1A (B) is detected by CAC-LS-1A (B). CAC-TCV-4A (B) controls flow to CAC-EV-1A (B) so as to control system temperature at its setpoint value. Technical Specification 4.6.6.1 specifies skid operability surveillance requirements at a 18 month frequency. These valves will be tested at least once every 18 months during a system outage coincident with testing of the associated instrument loop. The valves will be exercised and verified fully open and fully closed as requhed by OM Part 10. No problems have been identified with these valves as a result of periodic inservice testing since the start of commercial operation.to the time of this writing (11/96)

IST Program Plan 2nd 10-Year Interval WNP-2 Page 114 of Revision 171 1

NOTE N08 The following rupture discs are on portions of systems which do not perform a required function in shutting down a reactor to the cold shutdown condition, maintaining the cold shutdown condition, or mitigating the consequences of an accident. As such, they are outside the scope of testing per OM Part 1.

CCH-RD-1A, 1B CCH-RD-2A, 2B RCIC-RD-1, 2 N TENO The following rupture discs are not designed as pressure relief devices required for overpressure protection, and as such are excluded from the requirements of OM Part 1 per paragraph 1.1.2(b).

CAC-RD-1A, 1B N TEN1 The following shear explosive valves are exempt from Type C leakage testing per FSAR Table 6.2-16, Note 29, because they have explosive squibs and require testing to destruction.

TIP-V-7,.TIP-V-8, TIP-V-9, TIP-V-10 and TIP-V-11

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of IST Program Plan 2nd 10- Year Interval WNP-2 Page 115 Revision 171 1

4.5 Technical Positions Technical Position - TV01 Title Limiting Values of Full-stroke Times for Power Operated Valves Issue Di cussion OM Part 10 requires that an initial reference vaIue be established for each valve or group of valves. The acceptance criteria is a percentage + of the reference value. Part 10 recognizes that operating characteristics of electric motor operated valves are more consistent than those of other power operated valves.

Part 10 specifies stroke time acceptance criteria in paragraph 4.2.1.8. The limiting values of stroke time testing are to be established by the Owner according to paragraph 4.2.1.4.

~Positi n The following criteria shall be, used to establish Acceptance Criteria and Limiting Value ranges for power operated valves:

Acceptance Criteria Limiting Value (Alert) (Action)

MOVs ~ 10 seconds + .25 Tref 1.50 Tref ~

MOVs > 10 seconds + .15 Tref 1.30 Tref SOVs/AOVs/HOVs M 10 seconds + .50 Tref 2.00 Tref SOVs/AOVs/HOVs > 10 seconds + .25 Tref 1.50 Tref or J a 1.0 second change in stroke time, whichever is greater when compared to the Reference value or + a 1.0 second change in stroke time, whichever is greater when compared to the Alert Hi value

ll IST Program Plan 2nd 10-Year Interval WNP-2 Page 116 of Revision 171 1

Technical Position TV01 (Continued)

Notes:

1) Tref is the reference or average stroke value in seconds for an individual valve or valve groupmg.

2) Standard rounding techniques are used when rounding measured stroke times during valve stroke timing (e.g. 10.49 rounds to 10 and 10.5 is rounded to 11 seconds).

Measured stroke times are rounded to the nearest second when comparing measured values to Acceptance Criteria and Limiting value.

3) When establishing new reference values by taking the average of previous values, use measured values without rounding off. The new reference values will then be rounded off to the nearest second.

4) The Acceptance Criteria and the Limiting Value will be rounded off to the nearest secoild.

5) When reference stroke values or average stroke values are affected by other parameters or conditions, then these parameters or conditions must be analyzed and the above factors adjusted.

6) If the above calculated values exceed a TS (Technical Specification), FSAR value or other design basis limit, then the TS, FSAR or design basis value must be used for the limiting value of full-stroke.

7) Valves with stroke times of less than 2 seconds are exempt from the above if the maximum limiting valve stroke time is set at 2 seconds (Part 10, paragraph 4.2.1.8 (e)).

Standard rounding techniques will be used when rounding off readings during stroke timing (e.g. 2.49 seconds rounds to 2 and 2.5 rounds to 3 seconds). Specific valves with normal stroke times less than 2 seconds will be identified as "Fast Acting Valves" and willbe considered acceptable ifthe measured stxoke time (rounded to the nearest second) remains at 2 seconds or less. Corrective action will be required when a "Fast Acting Valve" stroke time is 3 seconds or greater.

This criteria meets the guidelines of Part 10 and Position 6 of GL 89-04.

I

8) When valve stmke time measuring techniques provide more precise measurements, rounding technique will not be used.

of 1ST Program Plan 2nd 10- Year Interval WNP-2 Page 117 Revision 171 1

Technical Position TV02 Title Seat Leakage Testing per 10CFR50 Appendix J Issue Discussion

'r Category A containment isolation valves are to be tested as required by OM Part 10 Paragraph 4.2.2.2 in accordance with 10CFR50, Appendix J. Containment isolation valves which also provide a icactor coolant system pressure isolation function (PIVs) shall additionally be tested in accordance with paragraph 4.2.2.3.

coition Category A containment isolation valves an: tested in accordance with 10CFR50, Appendix J as approved by the NRC in WNP-2 Safety Evaluation Reports. Certain exceptions to Appendix J testing ~uirements are detailed in the WNP-2 FSAR and Technical Specifications where the associated basis is documented, I

WNP-2 will specify a permissible leakage limitbased on valve type, size and equipment history for those valves being Type C leak tested. Valves or valve combination exceeding their leakage limits will be declared inoperable and repaired or replaced. During refueling outages valves exceeding specified leakage limits are declaied inoperable for containment isolation function but considered operable for system operability during Mode 4 and 5. Valves are iepaircd or replaced before plant startup.

All PIVs are tested per Technical Specification 4.4.3.2.2. These valves are ieactor coolant pressure boundary pressure isolation valves and are hydraulically leak tested at 950 (+ 10) psig during refueling outages in lieu of a type C test. Maximum allowable leakage rate for these

~

valves is specified in Technical Specification 3.4.3.2.e which is much more restrictive than the permissible leakage allowed by paragraph 4.2.2.3(e). Function maximum pressure differential pressures for these valves under most conservative conditions will result in insignificant (about 4%) adjustment to observed leakage per paragraph 4.2.2.3(b)(4) requirements. Since Technical Specification limits are more conservative than the Code, no adjustment will be applied to observed leakages for PIVs.

l IST Program Plan 2nd 10- Year Interval WNP-2 Page 118 of Revision 171 1

Technical Position TV03 Title Inservice Performance Testing of Prcssure Relief Valves Issue Discussion OM Part 10 requires testing of safety and relief valves in accordance with OM Part 1.

~Psition Additional clarifications have been provided in ASME OMc Code-1994, Appendix I and certain inquiries to the OM Code committee, NUREG-1482, Section 4.3.9, allows use of certain clarifications provided in the 1994 addenda and can be used without further NRC approval.

Other clarifications may also be used without further NRC approval if it is determined to be clarification only and is documented in the IST program or test procedures. The following clarifications will be used when implementing testing requirements for safety and relief valves.

~ >>

Replacement valve (Para. 2.1(c) and (d)): New valves not previously used at WNP-2.

~ 'alve group: valves of the same manufacturer, type, system application and service media.

~ 's-found set-pressure means first test actuation.

Spare class 1 Main Steam relief valves, which have been set-pressure tested after repair and refurbishment prior to December 13, 1994, in accordance with the Code in effect for 1st 10 year interval, will not be retested prior to installation in the plant and will be considered operable based on this previous test.

During disposition after testing, maintenance or repair (Para. 3.4), valves and accessories that do not comply with their respective acceptance criteria, whether the problem is associated with the component, the system, or associated equipment, shall be evaluated to determine the ability of the valve to perform its intended function until the next testing interval or maintenance opportunity. Corrective action's shall be taken, as appropriate, to ensure valve operability.

Testing of valve accessories is not dependent on operating conditions and will be performed at normal ambient condition (paragraph 1.1.2(a)).

IST Program Plan 2nd 10-Year Interval WNP-2 Page 119 of Revision 171 1

Technical Position TV03 (Continued)

Additional valves from the same valve group wiU be tested only if the as-found set pressure exceeds the greater of either the +/- tolerance limit of the owner established set-pressure acceptance criteria or +/- 3% of valve nameplate set-pressure.

Set pressure adjustment is an acceptable corrective action. If the out-of-specification condition can be corrected by adjusting the setpoint, a Code repair or replacement activity is unwarranted (5KJREG-1482, Section 4.3.6).

Return to service will mean resumption of electric power generation.

Test sequence in paragraph 3.3.1.1 is not applicable for refurbishments.

Reduced system pressure for valve actuation includes zero pressure (paragraph 3.4.1.1(d))

"Code tolerance" for set pressure testing implies Owner's acceptance criteria.

Verification of thermal equilibrium is not required for valves which are tested at ambient temperature using a test medium at ambient temperature (SE dated ll/27/95, TER Section 3.5) ~

~ For set-pressure testing, the volume of the accumulator drum and the pressure source flow rate shall be sufficient to determine the valve set-pressure. Valves may have their lifts restricted during set-pressure testing.

~ Each installed class 1 pressure relief valve shall be as-found tested at least once every 5 years. The test interval for any installed valve shall not exceed 5 years. When as-found test requirements have been satisfied for a given 24 month or 5 year test interval; additional valves removed for maintenance do not require as-found set-pressure testing prior to disassembly for maintenance.

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IST Program Plan 2nd 10- Year Interval WNP-2 Page 120 of Revision 171 1

Technical Position TV04 DELETED Primary Containment Vacuum Relief Valves (Valves CSP-V-S, 6, 7, 8, 9, 10) are being tested in accordance with OM Part 1.

1

1ST Program Plan 2nd 10-Year Interval WNP-2 Page 121 of

'evision 171 1

Technical Position TVOS Title Inservice Testing of Vacuum Relief Valves, suppression chamber - drywell vacuum breakers (CVB Valves)

I~i Para. 3.3.2.3 of OM Part 1 specifies the following testing requirements for vacuum relief valves (a) The valves shall be actuated to verify open and close capability, set pressure, and performance of any pressure and position sensing accessories.

(b),Compliance with the Owner's seat tightness criteria.

Part 1 does not specify any test frequency for class 2 and 3 vacuum relief valves. NUREG-1482 I recommends using the test frequency specified for class 2 and 3 pressure relief valves in para.

1.3.4.1. Para. 1.3.4.1(b) requires testing of these valves once every 10 years, with a minimum of 20% of the valves tested within any 48 months.

Position At WNP-2 these vacuum relief valves are operability tested in accordance with Technical Specification 4.6.4.1. Technical Specification testing detailed below meets or exceeds the testing requirements of OM Part I and as such these valves will continue to be tested in accordance with the WNP-2 Technical Specifications. Leakage testing of these valves is performed by conducting a dhywell-to-suppression chamber bypass leak test (Relief Request RV01). These testing requirements will also apply to replacement and refurbished valves, as applicable.

C Each suppression chamber - drywell vacuum breaker shall be:

a. Verified closed at least once per 7 days (regardless of operability).

b. Demonstrated OPERABLE:

1. At least once per 31 days and within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after any discharge of steam to the suppression chamber from the safety/relief valves, by cycling each vacuum breaker through at least one complete cycle of full travel.

IST Program Plan 2nd 10-Year Interval WNP-2 Page 122 of Revision 171 1

't Technical Position TV05 (Continued)

2. least once per 31 days by verifying both position indicators OPERABLE by observing expected valve movement during the cycling test.

3. At least once per 18 months by; a) Verifying the opening setpoint, from the closed position, to be less than or equal to 0.5 psid, and b) Verifying both position indicators OPERABLE by performance of CHANNEL CALIBRATION.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 123 of Revision 171 1

'echnical Position TV06

~ ~ ~

Title Inservice Testing of Vacuum Relief Valves, Main Steam vacuum breaker valves (MS 37 and 38 series)

Para. 3.3.2.3 of OM Part 1 specifies the following testing requirements for vacuum relief valves (a) The valves shall be actuated to verify 'open and close capability, set pressure, and performance of any pressure and position sensing accessories.

(b) Compliance with the Owner's seat tightness criteria.

Part 1 does not specify any test frequency for class 2 and 3 vacuum relief valves. NUREG-1482 I recommends using the test frequency specified for class 2 and 3 pressure relief valves in para.

1.3.4.1. Para. 1.3.4.1(b) requires testing of these valves once every 10 years, with a ininimum of 20% of the valves tested within any 48 months.

PoOi~ti n The vacuum breaker system allows MSRV downcomer pressure to equalize with drywell pzessure as downcomer steam is condensed in the suppression pool. These valves have no defined leakage (seat tightness) criteria for their specified normal set pressure (seating fozce) range. Short duration steam leakage into the dzywell is not desirable, but such leakage does not pose a challenge to containment function or integrity. These valves also have no pressure and position sensing accessories. Thus, operability test requirements are to verify valve open and close capability and set pressure determination. The safety function of these valves is to open I only. This testing is performed every refueling outage (ROJ07). These testing requizcments exceed the testing requirements of OM Part 1. These testing requirements will also apply to replacement and refurbished valves, as applicable.

4 of IST Program Plan 2nd 10-Year Interval WNP-2 Page 124 Revision 171 1

4.6 Cold Shutdown Ju tific tions OM Part 10 paragraph 4.2.1.1 states that all Active category A and B valves shall be tested nominally every 3 months, except as provided by paras. 4.2.1.2, 4.2.1.5, and 4.2.1.7.

J OM Part 10 paragraph 4.3.2.1 states that all check valves shaH'be exercised nominally every 3 months, except as provided by paras. 4.3.2.2, 4.3.2.3, 4.3.2.4 and 4.3.2.5.

Paragraph 4.2.1.2 and paragraph 4.3.2.2 state that valves shall be full-stroke tested or exercised during plant operation to the position(s) required to fulfillits function(s). If full-stroke exercising during plant operation is not practicable, it may be limited to part-stroke during plant operation and full-stroke during cold shutdowns. Valves full-stroke exercised at cold shutdowns shall be exercised during each cold shutdown, except as given below per paragraph 4.2.1.2(g) and paragraph 4.3.2.2(g).

Valve exercising during cold shutdown shall commence within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months of achieving cold shutdown, and continue until all testing is complete or the plant is ready to return to power. For extended outages, testing need not be commenced in 48 hour5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months provided all valves rcqubed to be tested during cold shutdown will be tested prior to plant startup.

However, it is not the intent of the Code to keep the plant in cold shutdown in order to complete cold shutdown testing. Such exercising is not ~uiicd ifthe time period since the previous full-stroke exercise is less than 92 days.

NUIREG-1482 Section 3.1.1.1 further clarifies cold shutdown testing. All valves tested during cold shutdown outages shall also be tested before startup from refueling outages, unless testing has been completed within the previous 92 days. Ifan outage lasts beyond 92 days, all cold shutdown testing shall be completed. within the last 92 days of the shutdown.

Cold shutdown valves are tested in groups by several different procedures. The decision whether to start cold shutdown testing on any particular procedure will depend on the estimated length of the cold shutdown period; system outages/conditions; time interval from the last cold shutdown testing; or other particular conditions.'he following valves are identified as being impracticable to exercise during plant operations and wiU therefore be full-stroke exercised during cold shutdowns. Allof these valves will be tested during each refueling outage. The valves are identified by unique valve numbers and Code identification as to Code Class and Valve Category.

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of IST Program Plan 2nd 10-Year Interval WNP-2 Page 125 Revision 171 1

Cold Shutdown Justification CSJ01

~De cri tioo It is not practicable to full or partial stroke exercise open the following RHR valves during normal plant operation.

Affected Valves Class Cat. Function System(s)

RHR-V-23 A RHR supply to vessel head spray Loop A, B outboard isolation valve for Residual Heat Removal RHR-V-53A, B shutdown cooling return Justification Valves are interlocked with reactor coolant system pressure such that valves automatically close to protect the RHR pump discharge line from elevated reactor coolant system pressures.

Opening circuit is disabled by the same pressure interlocks. Overpressurization of the discharge line may cause the loss of shutdown RHR cooling capability. Interlocks cannot be bypassed with normal control circuits, Alternative F uenc These valves will be full stroke exercised during cold shutdown.

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IST Program Plan 2nd 10- Year Interval WNP-2 Page 127 of Revision 171 1

Cold Shutdown Justification CS J03

~De cri tion It is not practicable to, fuH or partial stroke exercise the foHowing RFW valves during normal plant operation.

Affected Valves Class Function System(s)

RFW-V-10A, B AC Reactor feedwater inboard check valves RFW-V-32A, B AC Reactor feedwater outboard check valves Reactor Feedwater RFW-VISA, B A Reactor feedwater isolation valves J~utification

1) Closure of either Category A valve (RFW-V-65A, 65B) would result in a loss of flow to the reactor vessel and cause a significant mduction of actor coolant inventory.

2) Category AC valves are held open by feedwater flow and cannot be closed during power operations, Iternative F uenc These valves wiH be fuH stroke exercised during cold shutdown

IST Program Plan 2nd 10-Year Interval WNP-2 Page 128 of Revision 171 1

Cold Shutdown Justification CSJ04 DELETED BDC 94-0057-OA removed the hydraulic lines to the actuator of flow control valves RRC-V-60A and 60B including the HY valves as part of the design modification.

IST Program Plan 2nd 10-Year Interval WNP-2 Page 129 of Revision 171 1

Cold Shutdown Justification CSJOS Qe~~cri )tion It is not practicable to full or partial stroke exercise the following CIA valves during normal plant operation.

Affected Valves Class Cat. Function System(s)

These'valves cross connect the normal CIA-V-39A, B B nitrogen supply for the Main Steam Isolation Valves and Main Steam Relief Valves Containment Instrument the 7 ADS Valves) accumulators Air

'including CIA-V<1A, B to the backup nitrogen supply for the 7 ADS valves.

3'ustification Testing these valves requires securing the backup nitrogen supply to the ADS valve accumulators. This is operationally undesirable to do while the plant is operating.

Alternative F uenc These valves will be full stroke exercised during cold shutdown

of I'l IST Program Plan.

2nd 10- Year Interval WNP-2 Page 130 Revision 1 Cold Shutdown Justi6cation CSJ06 DcocDri tion It is not practicable to full or partial stroke exercise the following RRC valves during normal plant operation.

Affected Valves Class Cat. Function System(s)

RRC-V-13A, B 2 AC Inboard and outboard isolation valves for the Reactor Recirculation RRC-V-16A, B recirculation pumps seal purge line J~uification

1) Closure of Category A valves (RCC-V-16A, B) would terminate seal purge water flow to recirculation Pump 1A or 1B, respectively. Loss of purge flow may result in excessive seal wear and possibly failure of the seal.

2) Category AC valves (RRC-V-13A, B) are held open by purge water flow and cannot be closed during power operations.

Alternative F uenc These valves will be full stmke exercised during cold shutdown

IST Program Plan 2nd 10-Year Interval WNP-2 Page 131 of Revision 171 1

Cold Shutdown Justification CSJ07 D~escri sion It is not practicable to full or partial stmke exercise open the following RCIC valve during normal plant operation.

Affected Ualves Class Cat. Function System(s)

RCIC pump discharge isolation, and Reactor Core Isolation RCIC-V-13 containment isolation, and reactor coolant Cooling pressure isolation valve.

Justification Opening this valve during normal power operations increases the possibility of an intersystem LOCA.

Alternative F uenc

'his valve will be full stroke exercised during cold shutdown

IST Program Plan 2nd 10- Year Interval WNP-2 Page 132 of Revision 171 1

Cold Shutdown Justification CSJOS

~Descri tioo It is not practicable to full or partial stroke exercise open the following LPCS or RHR valves during normal plant operation.

Affected Valves Class Function System(s)

LPCS discharge isolation to the reactor Low Pressure Core LPCS-V-5 vessel. Spray RHR-V42A, B, C RHR discharge isolation to the reactor vessel. Residual Heat Removal Luutificgttin 1

The risk of injuring plant personnel, overpmssurizing the associated pump and piping, or causing an intersystem LOCA makes the opening of these valves imprudent during power operations.

Altern tive F uenc These valves will be full stroke exercised during cold shutdown

5 h

IST Program Plan 2nd 10- Year Interval WNP-2 Page 133 of Revision 171 1

~Descri tion It is not practicable to full or partial stroke exercise open the following CIA valves during normal plant operation.

Affected Valves Class Cat. Function System(s)

CIA-SPV-1B to B

19B Emergency nitrogen supply isolation valve.

CIA-SPV-1A to B

15A CIA-V-52A to 66A Containment Instrument Emergency nitrogen supply check valve.

CIA-V-52B to 70B Air Remote Emergency nitrogen supply check CIA-V-103A, B valve.

Remote Emergency nitrogen supply isolation CIA-V-104A, B valve.

Justification Ualve testing requires overriding valve control circuitry, isolating or expending emergency nitrogen supply tanks, and venting the system. This would inhibit the system from performing its designed safety function in case of an emergency.

Alternative P uenc These valves will be full stroke exercised during cold shutdown

IST Program Plan 2nd 10- Year Interval WNP-2 Page 134 of Revision 171 1

Cold Shutdown Justification CSJ10 D~csctt ti n It is not practicable to full or partial stroke exercise the following RWCU valves during normal

'lant operation.

Affected Valves Class Function System(s)

RWCU-V-1 Containment Iso., RWCU Pump Suction Iso.

RWCU-VA Containment Iso., RWCU Pump Suction Iso.

Reactor Water Cleanup RWCU-VA Containment Iso., RWCU Pump Discharge A

Iso.

J~ntticati n Testing these valves during power operations leads to overheating of the pumps, significantly increasing the potential for equipment damage.

Alternative F uenc These valves will be full stroke exercised during cold shutdown

1 IST Program Plan 2nd 10-Year Interval WNP-2 Page 135 of Revision 171 1

CSJ11

'old Shutdown Justification t

D~ecri tion It is not practicable to full stroke exercise the Main Steam Isolation Valves (MSIVs) during normal plant operation.

Affected Valves Class Function System(s)

MS-V-22A A Main Steam Line A Inboard Isolation Valve MS-V-22B A Main Steam Line B Inboard Isolation Valve MS-V-22C A Main Steam Line C Inboard Isolation Valve MS-V-22D A Main Steam Line D Inboard Isolation Valve Main Steam MS-V-2&A A Main Steam Line A Outboard Isolation Valve MS-V-2&B A Main Steam Line B Outboard Isolation Valve MS-V-28C A Main Steam Line C Outboard Isolation Valve MS-V-28D A Main Steam Line D Outboard Isolation Valve J~nificntion

.Full stroke testing each MSIV during normal reactor operation requires isolating the respective main steam line. These isolations are conducted with the plant at reduced power, however, the evolution still results in primary system pressure spikes, reactor power fluctuations, and increased flow in the unisolated steam lines. Each of these reactor pressure transients or power excursions'has the potential to induce an automatic SCRAM and actuation of the safety relief valves. The risks of challenging these protective systems during power operations is not considered prudent, and therefore the alternative cold shutdown testing frequency is warranted.

The implementation of the alternate frequency will contribute to the reduction of the relief valve challenge and failure rate as specifically recommended in M3REG-0626.

Itemative F uenc These valves will be full stroke exercised and stroke timed during cold shutdown conditions.

WNP-2 will continue to perform partial MSIV stroke testing (in accordance with PPM 7,4.3.1.1.9) on a quarterly frequency. The partial stroke test demonstrates the functional capability-of each MSIV and the associated RPS logic.

p l of ISI'rogram Plan 2nd 10-Year Interval WNP-2 Page 136 Revision 171 1

Cold Shutdown Justification CS J12

~Dcscri tion It is not practicable to fuH or partial stroke exercise open the foHowing MSLC valves during normal plant operation.

Affected Valves Class Cat. Function System(s)

MSLC-V-ZA, B, B Prevent Radioactive Material Release C,D MSLC-V-3A, B, C,D A'IV,Prevent Radioactive Material Release Main Steam Leakage Control MSLC-V-4, S, 9, B Prevent Radioactive Material Release 10 l~utiTication Testing the valves quarterly during normal plant operation subjects the valves to operation with 1020 psi across the seat. While the, valves and operators are designed for the 1020 psi differential, this results in excessive wear and tear on the valves that may affect their performance when required to operate to allow the MSLC System to operate or maintain isolation ifthe inboard MSIV fails to close.

The valves (MSLC-U-2A/B/C/Dand MSLC-V-3A/B/C/D)perform two functions: (1) isolation during normal plant operation and in case of failure of the inboard MSIV to close adequately for the MSLC system to operate and (2) open to allow the inboard MSLC to operate. The valves (MSLC-V-4/5/9/10) perform two functions: (1) isolation during normal plant operation and in case of failure of the outboard MSIV to close adequately for the MSLC system to operate and (2) open to allow the outboard MSLC to operate. Since the valves are normally in the closed

,position during plant operation and wiH be required to open or close with only 35 psi across them in case of an accident, the potential of having to shut the plant down ifthey don't seat after, a test, and subjecting the valve to severe duty compared to what it normally operates against, is not considered prudent.

Alternative F uenc These valves will be fuH,stroke exercised during cold shutdown

IST Program Plan 2nd 10-Year Interval WNP-2 Page 137 Revision of 171 1

Cold Shutdown Justification CSJ13

~ecr~ition It is not practicable to full or partial stroke exercise the following MS valve during normal plant operation.

Affected Valves Class Function System(s)

MS-V-146 Isolation Valve, Main Steam Supply to B Main Steam Auxiliary Equipment

'ustification This valve is normally open at power. Closing this valve at power would isolate steam from the following equipment.

1) Reactor Feed Water Pumps and moult in loss of RPV level and a reactor scram,

2) Main Steam Bypass Valves and result in equipment inoperability,

3) Main Steam Air Ejectors and result in loss of Main Condenser vacuum.

Alternative F uenc These valves will be full stroke exercised during cold shutdown

V IST Program Plan 2nd 10-Year Interval WNP-2 Page 138 of Revision 171 1

Cold Shutdown Justification CSJ14

~Descri tion It is not practicable to full or partial stroke exercise open the following MS valves during normal plant operation.

Affected Valves Class Cat. Function System(s)

MS-V<7A, B, C, Outboard MSIV drain valve (MS-V-28A, B, D Main Steam C, D)

Justification These valves are normally closed during power operation

1) Failure 'of these valves in a non-conservative position (open) during the surveillance testing at normal plant operation could insult in an unacceptable iodine release in the event of an accident, e.g. 26" main steam line break.

2) Failure to close during surveillance testing could result in a loss of containment integrity, because the inboard MSIV is open during normal plant operation.

3) Cycling of these valves during normal plant operation could increase the fatigue usage of the superpipe between the MSIV and the 67 valve above acceptable limits, i.e. Usage

> 0.1.

Iternative F uenc These valves will be full stroke exercised during cold shutdown

of IST Program Plan 2nd 10- Year Interval WNP-2 Page 139 Revision 171 1

Cold Shutdown Justification CSJ15 D~escri tion It is not practicable to full or partial stroke exercise open the following RHR valves during normal plant operation.

Affected Valves Class Function System(s)

RHR-V-16A, B A Drywell Spray Header (2nd outboard CIV)

Residual Heat Removal RHR-V-17A, B A Drywell Spray Header (1st outboard CIV)

Justification These valves are normally closed during power operation

1) Valve exercising during power operation increases the possibility that a containment boundary valve will not be fully closed, thus resulting in loss of containment integrity.

2) These valves are located in relatively high radiation areas and require operators to attach test hoses to supplement the testing of these valves. Reduced exercising frequency is justified by ~~.

3) Each time these valves are exercised, there is a risk of spraying/wetting down safety related equipment in the diywell (Ref. OER 82083F-INPO SER 41-85, Containment Spraying Events, OER 89040I-7, INPO RSEN 91-01, Recurring Significant Events) ..

i

4) During exercising of outboard valves, piping between the valves is filled and pressurized.

Inadequate filling of piping before exercising the outboard valve can result in water hammer damage to the RHR system.

Alternative F uenc These valves will be full stroke exercised during cold shutdown

CI IST Program Plan 2nd 10-Year Interval WNP-2 Page 140 of Revision 171 1

.~Dcscri ticn It is not practicable to full or partial stroke exercise open the following Main Steam valves during normal plant operation.

Affected Valves Class Cat. Function System(s)

MS-V-16 A Containment Isolation MS-V-19 Main Steam A Containment Isolation J~us ificati n 1), These valves are normally closed above 5% power operation

2) Valve exercising during power operation increases the possibility that a containment boundary valve will not be fully closed,'thus resulting in loss of containment integrity.

3) Cycling these valves during power operation produces severe thermal cycles and stress on the drain line piping (reference calculation ME-02-94-37). Each thermal cycle is an unnecessary challenge to piping integrity and plant safety overall.

4) Valves are inaccessible during power operation. MS-V-16 is inside primary containment and MS-V-19 is in the steam tunnel.

Alternative F uenc These valves will be full stroke exercised during cold shutdown

IST Program Plan Page 141 of 171 2nd 10-Year Interval Revision 1 OM Part 10 paragraph 4.2.1.1 states that all Active category A and B valves shall be tested nominally every 3 months, except as provided by paras. 4.2.1.2, 4.2.1.5, and 4.2.1.7.

OM Part 10 paragraph 4.3.2.1 states that all check valves shall be exercised nominally every 3 months, except as provided by paras. 4.3.2.2, 4.3.2.3, 4.3.2.4 and 4.3.2.5.

Paragraph 4.2.1.2 and paragraph 4.3.2.2 state that valves shall be full-stroke tested or, exercised during plant operation to the position(s) required to fulfillits function(s). If full-stroke exercising during plant operation and cold shutdowns is not practicable, it may be limited to part-stroke during cold shutdowns and full-stroke during refueling outages.

If exercising is not practicable during plant operation or cold shutdowns, it may be limited to full-stroke during refueling outages.

The following valves are identified as being, impractical to exercise during plant operations and cold shutdowns and willtherefore be full-stroke exercised during refueling outages. The valves are identified by unique valve numbers and Code identification as to Code Class and Valve Category.

h

of IST Program Plan 2nd 10-Year Interval WNP-2 Page 142 Revision 171 1

Refueling Outage Justification ROJ01 D~escri tion n

It is not practicable to full or partial stroke exercise open the following SLC check valves during normal plant operation or cold shutdown.

Affected Valves Class Cat. Function System(s)

SLC-VW Standby Liquid Control discharge to reactor Standby Liquid Control SLC-V-7 AC vessel Justification

1) Valves have no operator with which they may he stroked and are located in the primary containment.

2) Exercising the valves require the initiation of the SLC system and full flow injection into the reactor vessel. Initiation of SLC flow involves the discharge of Category D explosively activated valves. This involves destroying the valve and is an impractical evolution to perform during reactor operation or cold shutdowns since it could result in the addition of chemical poison to the reactor vessel. During power operation, the injection of chemical poison would necessitate shutting down the reactor. Poison injection during cold shutdown would require extensive cleanup of the mactor coolant to remove the poison. Furthermore, it would require frequent replacement of the explosive charges in the explosively activated valves, which is costly and burdensome. Paragraph 4.4.1(c) requires replacement of explosive charge every 2 years.

3) NUREG-1482 Section 3.1.1.3 states that valves may be tested during refueling outages if they flow path would otherwise be tested during cold shutdown outages that require the containment to be de-inerted for performance of valve testing.

4) These valves are not frequently cycled and should not experience a high rate of degradation associated with cycling, such as hinge or seating surface wear.

Alternative F uenc During each refueling outage,

1. One of the Standby Liquid Control system loops, including the associated explosive valve, will be initiated. A t the Reactor Vessel wiH be verified bypumping demineralinxi water to the vessel, this verifies valve opening.

2. Valve closure capability for SLC-V-7 will be verified in conjunction with 10CFR50 Appendix J (Type C) testing or by other positive means.

of 1'll IST Program Plan 2nd 10- Year Interval WNP-2 Page 143 Revision 1 Refueling Outage Justification ROJ02

~Descri tion It is not practicable to full or partial stroke exercise open the following CIA valves during normal plant operation or cold shutdown.,

1 Affected Valves Class Cat. Function System(s)

Instrument air supply to containment (inside CIA-V-21 2 AC containment)

Instrument air supply to ADS valves CIA-V-31A,B 2 AC (inside containment)

CIA-V~M,N,P, 2 AC Instrument air to ADS Accumulators Containment Instrument R,S,U,V (inside containment) Air Instrument air to Accumulators for inboard CIA-V-24A,B,C,D 2 AC MSIVs (inside containment)

Control air to Accumulators for outboard CAS-V-29A,B,C,D 3 AC MSIVs (inside steam tunnel)

Justification

1) NUTMEG-1482 Section 4.1.4 allows extension of test interval to refueling outage for l check valves verified closed by leak testing. [Applies to CIA-V-21, 31A and 31B.]

2) NUREG-1482 Section 3.1.1.3 states that valves may be tested during refueling outages if they would otherwise be tested during cold shutdown outages that require the containment to be de-inerted for performance of valve testing. [Applies to CIA-V-24 series and CIA-V-40 series.]

a) The CIA-V-24 and CIA-V-40 series check valves are located inside the containment and are inaccessible during power operations and during cold shutdowns when the containment is inerted. There is no way to remotely isolate the valves and observe the pressure decay of the accumulators.

3) There is no local or remote position indication for these check valves. These valves can be verified closed only by performing a leak-rate test. This acquires zcconfiguring the system, hook-up and disconnection of leak test apparatus. [Applies to all referenced valves.]

IST Program Plan 2nd 10- Year Interval WNP-2 Page 144 of Revision 171 1

Refueling Outage Justification ROJ02 (Continued)

4) Due to system design, no prictical method exists to perform this testing during power operations and during cold shutdowns when the containment is inerted. [Applies to all referenced valves.]

a) The CAS-V-29 series check valves are located in an area inaccessible during power operation, but accessible during cold shutdown conditions with containment inerted. The testing requires disassembly of mechanical connections which challenges the integrity/functionality of the system. The testing also requires the depressurization of the Reactor Building Service Air header. The risk of inducing a system fault due to disassembly and reassembly of system parts is increased with the frequency of occurrence and thus renders this approach impractical for a cold shutdown test frequency. In this case, the increased risk of system malfunction due to testing exceeds the benefit of testing these check valves on a cold shutdown test frequency.

5) Each time an MSIV is exercised, the corresponding accumulator check valve is exercised. This testing effectivel demonstrates there is no blockage in the air supply lines to the MSIV, but does not effectively demonstrate check valve closure and hence does,not effectively detect a stuck open check valve. [Applies to CIA-V-24 series and CAS-V-29 series.]

Alternative F uenc During each refueling outage,

1) Pressure decay tests will be performed on the accumulators in order to verify closure of CAS-V-29 series, CIA-V-24 and 40 series check valves and opening ability of CIA-V-21, 31A and 31B.

2) Closure of CIA-V-21, 31A, and 31B will be verified by normal 10CFRSO, Appendix J (Type C) testing.

It I

I

1ST Program Plan 2nd 10-Year Interval WNP-2 Page 145 of Revision 171 1

Refueling Outage Justification ROJ03

~Descri tion It is not practicable to full or partial stroke exercise open the following RHR valves during normal plant operation or'cold shutdown.-

Affected Valves Class Cat. Function System(s)

Containment isolation and Reactor Coolant RHR-V-209 1 AC System Pressure Boundary and pressure relief Residual Heat Removal for piping between valves RHR-V-8 and 9.

3 J~ustificati n

1) This check valve is located inside the containment and does not have valve position indication or an operator of any type. It cannot be tested without interrupting RHR shutdown cooling flow. During power operations, access is prohibited. During cold shutdown conditions, RHR cannot be out of service more than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per an 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

interval (per WNP-2 Technical SpeciTication). Additionally, containment will not be de-inerted during all cold shutdowns.

2) This valve is normally closed and is verified to be adequately seated by leak tests during each refueling outage. This valve performs the passive safety functions of containment isolation and reactor coolant system pressure isolation. Its active function of relieving pressure between valves RHR-V-8 and RHR-V-9 is a very unlikely situation and could only occur during time periods where both RHR-V-8 and 9 are shut and containment temperature is significantly above normal (i.e., LOCA condition). The proposed alternate testing avoids extraordinary testing efforts.

3) NUREG-1482 Section 3.1.1.3 states that valves may be tested during refueling outages if they would otherwise be tested during cold shutdown outages that require the containment to be de-inerted for performance of valve testing.

Alternative F uenc This check valve will be exercised during each refueling outage.

IST Program Plan 2nd 10- Year Interval WNP-'2 Page 146 of Revision 171 1

~

Refueling Outage Justification

~ ~

ROJ04

~

~Detctt tion It is not practicable to full or partial stroke exercise open the following valves during normal plant operation, or cold shutdown.

Affected Valves Class Cat. Function System(s)

PI-V-X72f/I 2 ~ AC Containment Isolation Process Instrumentation PI-V-X73e/1 2 AC Containment Isolation Traversing Incore TIP-VW 2 AC Containment Isolation Probe J~ntificetion

1) These check valves are located on the discharge of the radiation leak detection monitors and on the purge systl:m. for the TIP. These containment isolation valves are located inside the containment and are inaccessible during power operation and during cold shutdowns when the containment is inerted. Therefore, it is impractical to test these check valves quarterly during power operations or during cold shutdowns when containment remains inerted.

2) NUREG-1482 Section 3.1.1.3 states that valves may be tested during refueling outages I if they would otherwise be tested during cold shutdown outages that require the containment to be de-inerted for performance of valve testing.

Alternative F uen These valves will be fuH stroke exercised during each refueling outage.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 147 of Revision 171 1

Refueling Outage Justification ROJOS

~Descri tion It is not practicable to full or partial stroke exercise open the following MS relief valves during normal plant operation or cold shutdown.

Affected Valves Class Cat. Function System(s)

'Ihese valves form the Auto-Depressurization MS-RV-3D, 4A, System and, as such, function to relieve 4B, 4C, reactor vessel pressure to the extent that the BC Main Steam 4D, SB, low pressure coolant injection system could 5C be brought on line and perform its safety function.

Justification

1) It is impractical to test these ADS valves quarterly for their Category B power-operated function during power operation as this would result in the release of steam from the main steam lines causing power fiuctuations and possibly resulting in a xcactor shutdown.

Exercising these valves during cold shutdowns would result in excessive wear on valve seating surfaces and an increased number of challenges to these valves, which is undesirable.

2) In NUREG-1482 Section 4.3.4, the NRC staff mcommends reducing the number of I challenges to the dual function ADS valves in order to reduce their failure rate, 'because failure in the open position is equivalent to a small break LOCA. Therefore, the period between refueling outages is a reasonable alternate frequency for verifying the category B function of theses valves.

Alternative F uenc

1) Category B function of these valves will be verified during each refueling outage in I accordance with WNP-2 Technical Specification.

2) Category C function of these valves will be performed in accordance with OM Part 1.

1 of IST Program Plan 2nd 10-Year Interval WNP-2 Page 148 Revision 171 1

~Descri tion It is not practicable to full or partial stroke exercise the following excess flow check valves during normal plant operation or cold shutdown.

Affected Valves Class Cat. Function System(s)

PI-EFC-X18A, B, C, D AC Containment Isolation Process Instrumentation PI-EFC-X29B AC Containment Isolation Process Instrumentation PI-EFC-X29F AC Containment Isolation Process Instrumentation PI-EFC-X30A, F AC Containment Isolation Process Instrumentation PI-EFC-X37E, F AC Containment Isolation Process Instrumentation PI-EFC-X38A, B, C, D, E, F AC Containment Isolation Process Instrumentation PI-EFC-X39A, B, D, E AC Containment Isolation Process Instrumentation PI-EFC-X40C, D AC Containment Isolation Process Instrumentation PI-EFC-X40E, F AC Containment Isolation Process Instrumentation PI-EFC-X41C, D AC Containment Isolation Process Instrumentation PI-EFC-X41E, F AC Containment Isolation Process Instrumentation PI-EFC-X42A, B AC Containment Isolation Process Instrumentation PI-EFC-X42C, F AC Containment Isolation Process Instrumentation PI-EFC-X44A Series (Typ 12) AC Containment Isolation Process Instrumentation PI-EFC-X44B Series gyp 12) AC Containment Isolation Process Instrumentation PI-EFC-X61A, B AC Containment Isolation Process Instrumentation PI-EFC-X61C AC Containment Isolation Process Instrumentation PI-EFC-X62B AC Containment Isolation Process Instrumentation PI-EFC-X62C, D AC Containment Isolation Process Instrumentation PI-EFC-X66 AC Containment Isolation Process Instrumentation.

PI-EFC-X67 AC Containment Isolation Process Instrumentation PI-EFC-X69A, B, E AC Containment Isolation Process Instrumentation PI-EFC-X69F 2 AC Containment Isolation Process Instrumentation PI-EFC-X70A, B, C, D, E, F AC Containment Isolation Process Instrumentation PI-EFC-X71A, B, C, D, E, F AC Containment Isolation Process Instrumentation PI-EFC-X72A AC Containment Isolation Process Instrumentation PI-EFC-X73A AC Containment Isolation Process Instrumentation PI-EFC-X74A, B, E, F AC Containment Isolation Process Instrumentation PI-EFC-X75A, B, C, D, E, F AC Containment Isolation Process Instrumentation PI-EFC-X78A AC Containment Isolation Process Instrumentation PI-EFC-X78B, C, F AC Containment Isolation Process Instrumentation PI-EFC-X79A, B AC Containment Isolation Process Instrumentation

H r

IST Program Plan Page 149 of 171 2nd 10- Year Interval Revision 1 Affected Valves Class Cat. Function System(s)

PI-EFC-X82B AC Containment Isolation Process Instrumentation PI-EFC-X84A AC Containment Isolation Process Instrumentation PI-EFC-X86A, B AC Containment Isolation Process Instrumentation PI-EFC-X&7A, B AC Containment Isolation Process Instrumentation PI-EFC-X106 AC Containment Isolation Process Instrumentation PI-EFC-X 107 AC Containment Isolation Process Instrumentation PI-EFC-X 108 AC Containment Isolation Process Instrumentation PI-EFC-X 109 AC Containment Isolation Process Instrumentation PI-EFC-X110 AC Containment Isolation Process Instrumentation PI-EFC-X111 AC Containment Isolation Process Instrumentation PI-EFC-X112 AC Containment Isolation Process Instrumentation PI-EFC-X113 AC Containment Isolation Process Instrumentation Pl-EFC-X114 AC Containment Isolation Process Instrumentation PI-EFC-X115 AC Containment Isolation Process Instrumentation PI-EFC-X119 AC Containment Isolation Process Instrumentation Justification I} These are excess fiow check valves on instrument sensing lines which penetrate the primary containment. Their function is to close in case of excessive flow to perform a containment isolation function. The testing specified by WNP-2 Technical Specifications is a modified leak test which is performed once each refueling outage. Performance of valve closure verification on a quarterly or cold shutdown basis is impractical since this would isolate various instruments and could result in loss of control signals to vital

'nstrumentation and subsequent unnecessary initiation of automatic safety systems or lack of initiation when required.

2) It is not possible to test these valves at normal operating conditions because of the thermal stresses this places on the containment penetrations. Calculations have shown that repeated testing with such thermal induced stresses could lead to failure of the penetration.

Alternative F 'uenc These valves willbe exercised during each refueling outage per WNP-2 Technical Specifications. I

IST Program Plan 2nd 10-Year interval WNP-2 Page 150 of Revision 171 1

Refueling Outage Justification ROJ07 D~escti ti n It is not practicable to full or partial stroke exercise open the following MS valves during normal plant operation or cold shutdown.

Affected Valves Class Cat. Function System(s)

MS-V-37 Series Open: To break vacuum in the downcomers

%'p 18) of the main steam relief valves.

Main Steam MS-V-38 Series Close: To direct steam to the quenchers in

%p 18) the wetwell.

~ustificati n

1) The vacuum breaker system allows MSRV downcomer pressure to equalize with drywell pressure as downcomer steam is condensed in the suppression pool. The 36 normally closed check valves (2 on each downcomer) are not equipped with an external means of actuation for exercising the valve. Testing these valves is impractical with the reactor operating or the containment inserted as this testing zcquires personnel entry into the containment building.

2) NUREG-1482 Section 3.1.1.3 states that valves may be tested during refueling outages I if they would otherwise be tested during. cold shutdown outages that require the containment to be de-inerted for performance of valve testing.

Alternative F uenc These valves will be exercised when the reactor is shutdown and the containment de-inerted during each refueling outage. Breakaway force required to move the valve disc off its seat is I measured. The valves are also manually operated and visually verified to open and reseat. The safety function of these valves is to open only. I

t

II Qi

IST Program Plan 2nd 10- Year Interval WNP-2 Page 151 of Revision 171 1

Refueling Outage Justification ROJOS D~escri tion It is not practicable to full or partial stroke exercise open the following check valves during "normal plant operation or cold shutdown.

Affected Valves Class Cat. Function System(s)

RCIC-V-66 AC RCIC discharge to the reactor vessel head Reactor Core Isolation Cooling LPCS-V4 1 AC LPCS discharge to the reactor vessel Low Pressure Core Spray HPCS-V-5 1 AC HPCS Discharge to the reactor vessel High Pressure Core Spray RHR-V<1A, B, C RHR Loop A, B, C discharge to the reactor 1 AC Residual Heat Removal vessel RHR-V-SOA, B RHR Loop A, B discharge to the 1 AC Residual Heat Removal recirculating pump discharge J~utifi tion

1) These valves function as Reactor Coolant System Pressure Boundary Isolation valves.

This requires the check valve disc to properly seat, and achieve a relatively leak-tight seal. Technical Specifications require seat leakage testing of these valves each refueling outage. Seat leakage must be less than 1 gpm at a differential pressure of 950 psig. Seat leakage as a method of showing valve closure testing is labor and dose intensive and as such impractical to perform during each cold shutdown and should be tested during refueling outages only.

2) These check valves have exhibited excellent leak-tight integrity since commercial operation.

3) Due to lack of reliable position indications, the other positive means of verifying these valves fully open is by passing the requimi accident condition flow through these valves.

This is an acceptable full-stmke per position 1 of Attachment 1 of Generic Letter 89-04.

4) With flow rates on the order of 7500 gpm (ECCS), vessel level rises at a rate of 38 inches per minute. Operating ranges for RPV level provides a narrow band in which to work, making any such injection a challenge to plant Technical Specification limits and can result in flooding of main steam lines. Full flow testing of these valves should be performed only during rtefueling outages, when such testing can occur during refueling cavity flood-up.

j. I 1ST Program Plan 2nd 10-Year Interval WNP-2 Page 152 of Revision 171 1

Refueling Outage Justification ROJ08 (Continued)

5) Because of the differences in water chemistry, frequent injections of Suppression Pool water into the RPV is undesirable and can lead to additional crud accumulations in the crevices of piping nozzles, etc., thus resulting in higher dose rates in the containment.

6) The subject valves have been inspected internally and have exhibited no signs of wear which could affect the ability of the valves to stroke full open or closed. These check valves do not exhibit signs of back-seat tapping or hinge pin wear, nor have they shown indication that internal fastener retention methods are inadequate.

7) During normal plant operation, these valves are normally closed and do not open,

8) NUREG-1482 Section 3.1.1.3 states that valves may be tested during refueling outages I if they would otherwise be tested during cold shutdown outages that require the containment to be de-inerted for performance of valve testing,

9) NUTMEG-1482 Section 4.1.4 allows extension of the test interval to refueling outage for I check valves verified closed by leak testing.

Alternative F uenc During each refueling outage,

1) Closure ability of these valves shall be demonstrated by leakage test as required by Technical Specifications.

2) Opening ability of these valves shall be demonstiated by passing the maximum required accident condition flow through these valves.

of IST Program Plan 2nd 10- Year Interval WNP-2 Page 153 Revision 171 1

Refueling Outage Justification ROJ09

~Descri ti n It is not practicable to full or partial stroke exercise open the following CSP valves during normal plant operation or cold shutdown.

Affected Valves Class Function System(s)

Close to provide isolation for safety related CSP-V%5 AC control air to containment isolation valves CSP-V-S, 6 and 9.

Containment Supply Open to provide safety related control air to and Purge CSP-V-70 through containment isolation valves CSP-V-79 CSP-V-S, 6 and 9.

Justification

-1) There is no local or remote position indication for these check valves. Testing these valves requires partial depressurization of the supply header. Although, only partial depressurization is expected, full depressurization could easily occur due to leaky boundary valves, operator error, or check valve failure. Depressurization of the supply header to CSP-V-S, 6 and 9 will cause these containment isolation valves to fail open.

2) Due to system design, no practical method exists to perform this testing during power operations or during cold shutdowns. CSP-V-65 can only be verified closed by performing a special pressure decay leak-rate test. This requires reconfiguring the system and hook-up and disconnection of leak test apparatus. This requires the system to be breached and a portion depressurized.

3) To verify C$ P-V-70 through 79 open, flow from each of the 10 Nitrogen bottles and thus through each of these check valves must be demonstrated. -This riequires the system to be breached and the safety related supply header depressurized and would be I performed in conjunction with the pressure decay test to verify closure of CSP-V-65.

This testing will deplete safety related nitrogen inventory and will require replacement I of depleted nitrogen bottles after the test.

4) Review of the maintenance history for CSP-V-65 reveals that no failures have been observed. Failure of CSP-V-65 to close and its effects pertaii6ng to PRA (Probabalistic Risk Assessment) core melt frequency indicates a negligible increase in containment failure frequency.

Alternative F uenc During each refueling outage, each of these valves willbe exercised per the requirements of OM I Part 10.

A IST Program Plan 2nd 10-Year Interval WNP-2 Page 154 of Revision 171 1

Refueling Outage Justification ROJ10

~Descri tion It is not practicable to full or partial stroke exercise open the following RHR valves during normal plant operation or cold shutdown.

Affected Valves Class Function System(s)

RHR-V-8 A Isolate RHR shutdown cooling suction line RHR-V-9 from reactor recirculation loop A Residual Heat Removal Justification

1) Valves are interlocked with reactor coolant system pressure such that these valves automatically close to protect the RHR pump suction line from elevated reactor coolant system pressures. Opening circuit is disabled by the same pressure interlocks.

Overpressurization of the suction line may cause the loss of RHR shutdown cooling capability. Interlocks cannot be bypassed with normal control circuits.

I

2) Full stroke testing at cold shutdown frequency degrades the outage safety plan because the RHR shutdown cooling function is lost. RHR-V-8 and 9 should be stroked at refueling outage frequency when testing can be scheduled for minimal impact to the plant. With shutdown cooling unavailable, it puts the plant in the yellow band of the outage safety plan, and in a 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months LCO. If tested at refueling outage frequency, the testing can be scheduled at the end of the outage when decay heat load is lowest.

3) Valves are exercised during every outage when the RHR shutdown cooling function is initiated.

Alternative F uenc During each refueling outage, each of these valves willbe exercised per the requirements of OM Part 10.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 155 of Revision 171 1

Refue1ing Outage Justification ROJ11

~Descri tion It is not practicable to full or partial stroke exercise open the'following RHR valves during normal plant operation or cold shutdown, Affected Valves Class Cat. Function System(s)

RHR-V-123A, B 1 A CIV, HI-LO Pressure Isolation Residual Heat Removal Justification

1) These valves are normally closed with the motor operator deenergized during power operations and function as Reactor Coolant Pressure Boundary/Containment Isolation Valves. Opening the valves for the sole purpose of verifying the ability to close is not prudent, as it presents an unnecessary challenge to the containment and increases the potential for an intersystem LOCA.

2) These valves have no active safety function. %NP-2 Technical Specification 4.6.3.1 requires the valve to be stroked following repair and maintenance.

Alternative F uenc During each refueling outage, each of these valves willbe exercised per the requirements of OM I Part 10.

Lp IST Program Plan 2nd 10-Year Interval WNP-2 Page 156 of Revision 171 1

4.8 Relief R ue from Certain M Part 1 and Part 10 R uirements Relief Requests are presented to document, differences between the Code and WNP-2's Valve Test Program. The requests include technical justification for the differences and, where appropriate, propose alternate testing.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 157 of Revision 171 1

Relief Request RV01 Affected Valves Class Cat. Function System(s)

CVB-V-1AB, CD, To break vacuum on the dtywell to EF, GH, JK, LM, 2 'AC suppression chamber downcomers and to Primary Containment NP, QR, limit steam leakage from the downcomer to Cooling and Purge the wetwell gas space.

ST Code R uirement for Which Relief is R uested OM Part 10, Paragraph 4.2,2, Valve Seat Leakage Rate Test Basis for Relief These check valves cannot'be tested individually therefore, assigning a limiting leakage rate for each valve is not practical. The purpose of this leak rate test is to assure that the leakage from the drywell to the suppression pool chamber does not exceed Technical Specification limits. The WNP-2 Technical Specifications specify conservative corrective actions commensurate with the of the safety function being performed by these valves. 'mportance Alternate T tin to be Performed These valves will be leak tested according to WNP-2 Technical Specifications during refueling outages by conducting a drywell-to-suppression chamber bypass leak rate test. These valves are verified-closed by position indicators, tested in the open direction using a torque wrench, and each valve seat is visually inspected. Corrective actions will be as specified in the Technical Specifications.

ualit Safet Im act The leakage criteria and corrective actions specified in the WNP-2 Technical Specifications is the most practical approach to assessing the adequacy of these valves in performing their specified safety function. Following the WNP-2 Technical Specification requirements provides adequate assurance of material quality and public safety.

NRC Acc tance SHR Dated November 27 1 Relief granted as requested.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 158 of Revision 171 1

Relief Request RV02 Affected Valves Class Function System(s)

LPCS-V-33, 34 Open: To permit the water leg pump to fill Low Pressure Core the system with water and maintain Spray HPCS-V-6, 7 it pressurized. High Pressure Core Close: To prevent bypass flow from the Spray RHR-V-84A, 85A applicable ECCS pump and maintain the ECCS injection flow path RHR-V-84B, SSB integrity. Also to prevent Residual Heat Removal overpressurization of the waterleg RHR-V-84C, SSC 'C pump and associated piping.

R uirement for Which Relief is R t'ode uested Part 10 Paragraph 4.3.2, Exercising Tests for Check Valves B~if R li f These in series valves cannot be verified to be closed individually without either installing a test connection or dismantling the valve and inspecting the internals (which requires grinding out the seal weld). The associated stop-check valve is located in series with the check valve and performs the same function as the check valve. Closure of the stop-check is verified quarterly.

The oveipressure protection function is provided by the two valves and in addition a low pressure relief valve is installed should both the check and stop-check valves fail or leak excessively.

Paragraph 4.1.1 of NUTMEG-1482 states, " the licensee has no practical means for verifying If the ability of each valve in a series to close, it may review the plant safety analysis to determine ifboth valves are required to function. only one of the two valves is credited in the safety If analysis (that is, if one valve could be removed without creating an unrcviewed safety question or creating a conflict with regulatory or license requirements), then verification that the pair of valves is capable of closing is acceptable for IST."

A review of the License Basis Documents indicates that these valves are not credited individually for any safety related function. Therefore, one valve could be removed without creating an unreviewed safety question. The safety related function for these check valves is to close, which prevents bypass flow from the applicable ECCS pump and maintains the ECCS injection flow path integrity. As long as one of the check valves in the series pair is capable of closure, then the intended design function for the check valves is met.

III C

IST Program Plan Page 159 of 171 2nd 10-Year Interval Revision 1 Relief Request RV02 (Continued)

The operability of these valves in the open direction, (non safety function) is demonstrated continuously during normal power operation. Failure to open would become apparent by the decay of system pressure to a point where a Control Room Annunciator would turn on, indicating low system pressure.

Al ernate T tin to be Performed Each pair of series check valves willbe exercise tested during the quarterly surveillance by some positive means (measurement or observation of an operational parameter such as prcssure or flow) to verify the closure capability of at least one of the valves to prevent reverse flow. In addition, the stop-check valve will be cycled manually to ensure no binding exists. Acceptance criteria to verify closure of each pair of" check valves is provided in the implementing surveillance procedures. Ifclosure capability of the pair of valves is questionable, both valves shall be declared inoperable and both valves shall be repaired or replaced as necessary before the return to service.

uali /Safe Im act The proposed alternate testing verifies operability of the pressure isolation function shared by these valves. The required testing would be a hardship on WNP-2 with little compensating benefits. The alternate testing will provide adequate assurance of material quality and public safety.

NRC Ac tance/SER Dated November 27 1 5 Interim relief granted until November 26, 1996. Relief request revised to include safety function information and the acceptance criteria. See above.

of IST Program Plan 2nd 10-Year Interval WNP-2 Page 160 Revision 171 1

Relief Request RV03 Affected Valves Class Cat. Function System(s)

'Ihrottle flow to control temperature of the SW-TCV-11A, B B Standby Service V/ater Control'Room Code R uirement for Which Relief is R uested

1) Part 10 Paragraph 4.2.1.1, Exercising Test Frequency

2) Part 10 Paragraph 4.2.1.4, Power-Operated Valve Stroke Testing.

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1) These hydraulically actuated valves serve as regulating thermostatic control valves. The valves do not function to rapidly isolate or de-isolate the piping into which. they are installed. Rather, their function is to slowly regulate throughout their entire stroke range to control the outlet temperatures of the components they serve in response to a 4-20 mA.

control signal provided by their respective instrument control loops. The valves are spring-to-open/oil-to-close; recirculating oil pumps inside the actuators for the valves constantly apply a source of oil.to a piston that acts against the spring. The 4-20 mA control signal varies the amount of oil constantly bled from the operating piston (back to the internal actuator reservoir). In this fashion the valves are regulated ariywhere within the enthe stroke length. SW-TCV-11A & 11B are controHed by thermostats which regulate main control room air temperature.

2) It is difficultto accurately measure the stroke time of these valves. These valves are not provided with any form of override that would allow them to be manually cycled.

Additionally, they an: not provided with position indication. Partial stroking of these valves can be verified by observing system operational parameter changes, but accurate timing of full stroke for trending purposes is impractical.

3) Manual control of these valves can only be obtained by lifting the 4-20 mA control leads to inject a test signal to the hydraulic actuator. This in turn requires that the Technical Specification required systems they serve be taken out of service. The systems they serve are required to remain in service at all times.

4) Modification of the existing valves or installation of new valves to provide manual control and position, indication would be burdensome and costly.

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of IST Program Plan WNP-2 Page 161 171 t

2nd 10- Year Interval Revision 1 Relief Request RV03 (Continued)

Alternate Testin to be Performed

1) During each refueling outage perform a full calibration verification of the actuator for each of these valves per instructions provided by the valve vendor ITT General Controls Division. Each calibration verification is performed with the actuator coupled to its valve. A variable 4-20 mA test signal is applied to the actuator, and the actuator is verified to respond to stroke the valve in a linear fashion throughout its entire stroke length (i.e. from full open to full closed). Full stroke length of the valve is measured and verified that it is within acceptable range. Stroke length outside the acceptable range will indicate valve degradation requiring corrective action.

2) Concurrently with the testing described in (1) above, the failsafe position on a loss of power (OPEN) shall be verified.

The alternative testing to be performed (actuator. calibration verification) will verify proper operation of the valve to meet its design function. These valves are designed to operate as slow moving'regulating valves and must be able to achieve and maintain any position called for by its control instrumentation. Inability to meet the tolerances of the calibration throughout the entire range of motion wiU require further investigation (e.g. valve maintenance) to coaect the problem to produce a satisfactory calibration check. Because the valves cannot be tested without the adverse affect of taking the associated required safety related systems out of service, testing will be at, refueling outages versus quarterly. However, this form of testing is more rigorous than a quarterly stroke time test of the valves. Consequently, lengthening the time interval will not preclude timely evaluation of valve operability. Adequate assurance of material quality and maintenance of public safety will be provided.

NRC Ac e nce/SER Dated Novem er 27 l Relief granted as requested.

J IST Program Plan Page 162 of 171 2nd 10- Year Interval Revision 1 Relief Request RV04 Affected Valves Class Function System(s)

PSR-V-X73-1 PSR-V-X80-1 PSR-V-X83-1 PSR-V-X77A1 PSR-V-X82-1 A Containment Isolation Post Accident Sampling PSR-V-X 84-1 PSR-V-X77A3 A PSR-V-X82-7 PSR-V-X88-1 A 4

Code R uirement for Which Relief is R uested Part 10 Paragraph 4.2.1.4, Power-Operated Valve Stroke Testing B~if R Ii f These nine PSR solenoid valves are the inboard Containment Isolation Valve for nine different penetrations and axe operated from a single keylock control switch. It is impractical to measure the individual valve stroke times. To do so would requue repetitive cycling of the contxol switch causing unnecessaxy wear on the valves and control switch with little compensating benefit.

Alternate Te tin to be Performed These solenoid valves stroke under 2 seconds and are considered rapid-acting valves. Their safety function is to close to provide containment isolation. The stroke time of the slowest valve willbe measured by terminating the stmke time measurement when the last of the nine indicating lights becomes illuminated. If the stroke time of the slowest valve is in the acceptance range (less than or equal to 2 seconds), then the stroke times of all valves will be considered acceptable. However, if the stxoke time of the slowest valve exceeds the acceptance criteria (2 seconds), all 9 valves willbe declaxcd inoperable and corrective actions in accordance with Part 10 paragraph 4.2.1.9 taken, uali Safet Im ac The proposed alternate testing willverify that the valves respond in a timely manner and provide information for'monitoring signs of material degradation. This provides adequate assurance of material quality and public safety.

NRC Acc tance SER Dated November 27 19 5 Relief granted with provisions. Relief request revised to include information on the actions taken ifthe slowest valve is unacceptable and the rapid-acting characteristic of these valves, See above.

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IST Program Plan 2nd 10- Year Interval WNP-2 Page 163 of Revision 171 1

Relief Request RV05 Affected Valves Class Cat. Function System(s)

MS-RV-1A, B, C, D

MS-RV-2A, B, C, Overpressure Protection D

MS-RV-3A, B, C Main Steam MS-RV-3D BC Overpressure Protection and Auto Depressurization System to lower reactor MS-RV-4A, B, C, BC pressure'sufficient to allow initiation of Low D

'ressure Coolant Injection (RHR, LPCI MS-RV-SB, C BC mode)

Code R uirement for Which Relief is R u ted

1. Part 1, Paragraph 3.3.1.1: Sequence of Testing Main Steam Pressure Relief Valves with Auxiliary Actuating Devices, f i f MSRV periodic set pressure testing is performed on-line. Removal and replacement of the MSRVs is used only for valve maintenance and not for the purpose of as-found set pressure determination. MSRV's are removed and replaced for maintenance purposes (e.g., seat leakage) nominally each refueling outage. The valves which are required to be as-found set pressure tested, as part of the Code required periodic testing, do not necessarily correspond to those required to be replaced for maintenance. Actuators and solenoids remain in place when MSRV's are removed and replaced for maintenance.

'Actuator and solenoid tests are required by the Code for both the periodic tests as well as for the replaced valves, and the actuator and solenoid tests required after valve replacement are identical to those required for periodic actuator and solenoid tests. The actuator and solenoid tests require challenging the MSRV's by stroking and potentially degrading seat integrity by MSRV actuation. Since the actuator and solenoid tests for periodic testing and valve post-replacement are identical, the post-replacement test should be credited as satisfying the periodic tests, to reduce challenges to the MSRV's and to reduce risk of subsequent seat leakage, provided that no maintenance is performed on the actuator or solenoids (other than reinstallation on the replaced valve) prior to the actuator and solenoid tests.

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of IST Program Plan 2nd 10-Year Interval WNP-2 Page 164 Revision 171 1

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2. "Valve's" and "accessories" (actuators, solenoids, etc.) have different maintenance and test cycles due to the methods used for maintenance and testing at WNP-2 as discussed in item 1., and should be considered separately for the purposes of meeting the required test frequency and testing requirements. Valve testing (i.e., visual examination, seat tightness, set pressure determination and compliance with seat tightness criteria, in accordance with Code paragraphs 3.3.1.1 (a), (b), (c) and (d)) are independent of and can be separate from testing of "accessories" (i.e., solenoids, actuator, position indicators and pressure sensing element, in accordance with Code paragraphs 3.3.1.1 (e), (f), (g) and (i)). Valve maintenance or set pressure adjustment does not affect "accessories" testing; likewise, maintenance on "accessories" does not affect valve set pressure or seat leakage, Since the "accessories" remain in place when MSRUs are removed for maintenance, the testing of the "accessories" after MSRV replacement satisfies the periodic testing requirements for the actuators and solenoids, provided no maintenance is performed on the "accessories" prior to the tests on accessories which would affect their as-found status or that could affect the valve's future set pressure determination.

Therefore, the MSRVs and the "accessories" may be tracked separately for the purpose of satisfying the Code test frequency requirements.

Testing the accessories (actuators, solenoids, etc.) after valve maintenance or set pressure adjustment is complete is consistent with OMc Code-1994 Appendix I, paragraph I 3.3.1.

3. OM Code Part 1 requires testing of accessories in a prescribed sequence. Paragraph 3.3.1.1(g) requires determination of operation and electrical characteristics of position indicators, and paragraph 3.3.1.1(i) requires determination of actuating pressure of auxiliary actuating device sensing element and electrical continuity. These tests are required to be performed at the same frequency as the valve set pressure and auxiliary actuating device testing.

The position indicators are all calibrated and functional tested during outages; the sensing I elements (pressure switches) are all checked and calibrated nominally every 24 months.

Although the existing tests are not in the prescribed sequence,, and they do not have a one-to-one correspondence to the valve or actuator tests, these calibrations and functional tests meet all testing requirements of this Part, and far exceed the rcquued test frequency and testing requirements.

4 ASME OMa Code-1996 Addenda removes the requirement to perform the accessories and seat tightness tests in a'specific sequence. There was no technical basis for requiring the specific sequence.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 165 of Revision 171 1

Relief Request RVOS (Continued)

Alternate Testin to be Performed a) Valves: As clarified in OMc Code-1994 Appendix I, paragraph I 1.3.3 (a),

as-found set pressure determination, seat leakage determination and compliance, and visual examination of MSRVs will be performed at least once every 5 years; the test interval for any individual valve will not exceed 5 years; a minimum of 20% of the valves will be tested within any 24 month interval, and this 20% will be previously untested if they exist. Valves will be tracked to assure that the Code required test frequency is met.

I b) Actuators and Solenoids: The required tests will be performed on a minimum of 20% of the actuators with solenoids in any 24 month interval. The actuators will I be tracked to assure that each is tested at least once every 5 years and within an interval not to exceed 5 years. Since the valve and actuator test and maintenance cycles are different, the plant positions of the actuators selected, or due, for periodic testing may not match the plant positions of the MSRVs selected, or due, for as-found set pressure testing. The actuators and solenoids willbe tested at the end of the outage after other maintenance is complete, and the tests will be credited as satisfying the Code periodic test requirements provided that no actuator or solenoid maintenance (other than actuator assembly re-installation on a replaced valve) is performed that would affect their as-found status prior to testing or that could affect the valve's future set pressure determination,

2. All MSRV position indicators wiH continue to be tested in accordance with existing surveillance procedures for monthly channel checks, and for channel calibration and channel functional testing on nominally 18 month frequency during shutdowns. These tests will be credited for satisfying the requirements of paragraph 3.3.1.1(g) of OM Code Part 1,

3. All auxiliary actuating device sensing elements (pressure switches) will continue to be tested and calibrated on a 24 month frequency during shutdowns. These tests will be credited for satisfying the requirements of paragraph 3.3.1 1(i) of OM Code Part 1.

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IST Program Plan 2nd 10- Year Interval WNP-2 Page 166 of Revision 171 1

ualit /Safet Im act Due to different maintenance and test cycles of valves and accessories and also due to .

methods used for testing and maintenance, it is impractical to meet the Code required testing requirements without subjecting the valves to unnecessary challenges and increased risk of seat degradation. The requirement for testing actuators and accessories I in a specific sequence does not enhance system or component operability,'or in any way improve nuclear safety. The proposed alternate testing adequately evaluates the I operational readiness of these valves commensurate with their safety function, This will help reduce the number of challenges and failures of safety relief valves and still provide timely information regarding operability and degradation. This will provide adequate assurance of material quality and public safety.

NRC Ac tance/SER Dated November 27 I 5 Relief granted with provisions. Relief request revised to clarify that the 1994 Addenda testing frequency requirements will be complied with. Valves and accessories will be tested independently and on a different schedule and no maintenance or set pressure adjustments will be made prior to set pressure determination.

IST Program Plan 2nd 10- Year Interval WNP-2 Page 167 of Revision 171 1

4.9 Records and Re orts of Valves Records and reports pertaining to valves in the Program willbe maintained in accordance with OM Part 10 paragraph 6. The files will contain the foHowing:

1) Valve records will be maintained in accordance with paragraph 6.1.

2) Inservice test plans are issued as valve surveillance test procedures. The inservice testing records for valves in the Program will be maintained in accordance with paragraph 6.2.

3) Records of tests for valves in the Program will be maintained in accordance with paragraph 6.3. Completed surveillance test procedures are retained per plant administrative procedures.

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Records of corrective actions for valves in the Program will be maintained in accordance with paragraph 6.4. Corrective actions are documented on Work Orders and/or Problem Evaluation Requests (PERs).

Records and reports pertaining to pressure relief'devices in the Program will also be maintained in accordance with OM Part 1 paragraph 5 requirements.

The Valve Inservice Test Program, associated'urveillance test procedures and results, and corrective actions are retained per plant administrative procedures.

of IST Program Plan 2nd 10- Year Interval WNP-2 Page 168 Revision 171 1

SAMPLE VALVESTROKE DATA SHEET OPENING TME IN SECONDS CLOSING TIME IN SECONDS Ref. Alert Lo Measured Value Alert Hi Action Hi Ref. Alert Lo Measured Value Ale t A ti Hi (+I)

Value (+1) (+2) (+ 1) (+1) alu (+1) (+2) (+1)

HPCS-V-1 56 48 73 56 48 73 NOT N/A N/A N/A NOT CLOSED HPCS-V-2 N/A N/A N/A OPEN NOT CLOSED HPCS-V-6 N/A N/A .N/A N/A N/A N/A N/A

(+6)

NOT CLOSED HPCS-V-7 N/A N/A N/A N/A N/A N/A N/A

(+6)

HPCS-V-10 l 49 N/A N/A NIA 37 51 57 HPCS-V-11 50 N/A N/A N/A 50 43 57 65 HPCS-V-12 11 (+3)

HPCS-V-15 18 13 15 (+8) 16 14 12 16

(+4)

HPCS-V-16 NIA N/A NOT N/A N/A N/A N/A N/A OPEN HPCS-V-23 47 N/A N/A N/A 47 40 54 61 (+5)

HPCS-V-24 N/A N/A N/A NOT N/A N/A N/A NOT CLOSED OPEN HPCS-V4 N/A 10 12 (+7) 13 14 (+3)

(+1) For measured values beyond the ALERT Value or ACTION Value refer to Precaution 4.8 or 4.9, respectively.

(+2) Round all measured Stroke Times to the nearest second when comparing measured values to Alert and Action limits. Use standard rounding techniques e.g. 10.49 rounds to 10 and 10.5 rounds to 11 seconds.

(+3) Use listed closing stroke time as limiting even though a higher'imit is specified in FSAR.

(+4) Limiting stroke time per FSAR.

(+5) Use listed closing stroke time as limiting even though a higher limit is specified in Technical Specification.

(+6) if the valves are found not closed, repair or replace both HPCS-V4 and HPCS-V-7.

,~ (+7) For measured values GE 12 seconds, review the data obtained from PPM 7.4.8.1.1.2.8 for the effect on overall systemgesponse time.

(+8) Limiting stroke time per Eng. Calculation C106-92W3.02 is 15.8 seconds. Notify Plant Support Engineering if this value is exceeded.

Motor operated valve.

SAMPLE TWO YEAR VPI VERIFICATIONAND ANNUALCHANNEL CALIBRATIONDATA SHEET VERIFIED OPEN VERIFIED CLOSED

, Valve REMOTE REMOTE % Full Condition LOCAL INDICATION LOCAL INDICATION Valve Cycle INDICATION INDICATION Open Valve No. Operation MOV Inspected (+2)

Initial As Full SAT UNSAT SAT UNSAT initial (+1) As Full Found Open Found Close STEP 1 STEP 2 STEP 3 STEP 5 STEP 4 STEP 4 STEP 4 STEP 4 STEP 2 STEP 3 STEP 5 STEP 6 STEP 8 STEP 7 STEP 9 HPCS-V-1 HPCS-V4 HPCS-V-10 HPCS-V-11 HPCS-V-12 HPCS-V-15 HPCS-V-23

(+1) Ifthe valve in its As Found condition is not fully closed, write a PER. For throttle valves, verify the valve cannot be further closed from its control switch. For HPCS-V4, enter 0%'if the stem movement indicator on the SB unit reads GT 1/8" (See Attachment 9.7)

(+2) Ifthe valve is less than 85% Full Open as calculated below, write a PER.

Calculate % Full Open in accordance with obtained values and the following examples:

% FULL OPEN = [(As Found Open) - (Full Closed)] : [(Full Open) - (Full Closed)] x 100 Local Position Indicator 5% at Full Closed Stem Di lacement 0" at Full Closed 95% at Full Open 6.0" at Full Open 90% As Found Open 5.5" As Found Open

% Full Open = (90 - 5) = (95 - 5) x 100 = 94.4% % FULL OPEN = (5.5 - 0) : (6.0 - 0) x 100 = 91.7%

Number of Handwheel Revolutions 0 at Full Closed De ree of Stem Rotation 45't Full Closed 12.5 at, Full Open 275't Full Open 11.5 As Found Open 235's Found Open

% Full Open = (11.5 - 0) : (12.5 - 0) x 100 = 92.0% % FULL OPEN = (235 - 45) : (275 - 45) x 100 = 82.6%

(+3) These valves require annual channel calibration in addition to two year VPI. VPI verification satisfies both requirements.

(+4) Step 5 does not require manual closure of HPCS-V4. Enter 0% ifthe stem movement indicator on the SB unit (motor operator ty~used on HPCS-V4) reads GT 1/8". See Attachment 9.7.

4 IST Program Plan Page 170 of 171 2nd 10- Year Interval Revision 1 5.0 ualit A surance Pro ram The WNP-2 Pump and Valve Inservice Test Program activities will be conducted in accordance with Topical Report WPPSS-QA-004, the Supply System's Operational Quality Assurance Program description.

r, IST Program Plan 2nd 10- Year Interval WNP-2 Page 171 of Revision 171 1

The Piping and Instrument Diagrams used to generate this Program are listed below.

Subsequent changes to system design shall be evaluated for impact on the IST Program Plan and new revisions to this Program shall be issued accordingly.

Title Ref. No. Title Ref. No.

Main Sc Exhaust Steam System M502 Reactor Recirculation Cooling M530 Control &, Service Air M510 Equipment Drain Radioactive M537 Diesel Oil 8c Misc. Systems M512 Floor Drain Radioactive M539 Demineralized Water M517 Containment Cooling & Purge M543 Reactor Core Isolation Cooling M519 Standby Gas Treatment High/Low Pressure Core Spray M520 Reactor Building HVAC M545 Containment Atmosphere Residual Heat Removal M521 M554 Control Standby Liquid Control M522 Containment Instrument Air M556 Reactor Water Cleanup M523 Main Steam Leakage Control M557 Undervessel Neutron Monitoring Standby Service Water M524 M604 System Reactor Closed Cooling M525 Class I Air System for M619 Containment Vacuum Breaker Fuel Pool Cooling M526 Emergency Chilled Water M77S Control Rod Drive Prinuuy Containment Nitrogen M528 M783 Inerting Main Steam and Reactor M529 Post Accident Sampling M896 Feedwater

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