Text

Rev. 0 to Inservice Testing Program Plan, Third Ten-Year Inspection Interval (December 13, 2005 Through December 2014)
	ML053270081
Person / Time
Site:	Columbia
Issue date:	10/03/2005
From:	Rana B; Energy Northwest
To:	; Office of Nuclear Reactor Regulation
References
	Download: ML053270081 (186)
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MMMMMMMMMM Columbia Generating Station Inservice Testing Program Plan (Pumps & Valves) 3rd Interval (13 DEC 2005 - 12 DEC 2014)

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INSERVICE TESTING PROGRAM PLAN THIRD TEN-YEAR INSPECTION INTERVAL ENERGY NORTHWEST COLUMBIA GENERATING STATION USNRC DOCKET NO. 50-397 FACILITY OPERATING LICENSE NO. NPF-21 COMMERCIAL OPERATION DATE: DECEMBER 13, 1984

ENERGY NORTHWEST Columbia Generating Station INSERVICE TESTING PROGRAM PLAN Third Ten-Year Interval (13 DEC 2005 through 12 DEC 2014)

Revision 0 Prepared by IST Program Engineer Date Reviewed by Concurrence Reviewing Engineer i

Supervisor, IST ProgramU 8 -Z,3-o Date 10 z/orS Date Approved by Manager, Technical Services I w /at IIDate ii

TABLE OF CONTENTS Pace

1.0 INTRODUCTION

1 1.1 Program Administration........

1.2 Program Database............

1.3 References.................

2.0 QUALITY ASSURANCE PROGRAM 3.0 PIPING AND INSTRUMENT DIAGRAMS 2

3 4

5 6

4.0 PUMP INSERVICE TESTING PROGRAM........................

4.1 Introduction.

4.2 Program Implementation.

4.2.1 Exclusions (ISTB-1200).....

4.2.2 Pump Categories (ISTB-1300).

4.2.3 Preservice Testing (ISTB-3 100)

A I A Inz.nrvrir T-ctunr (ZT1P-'A')0f 4.2.5 4.2.6 4.2.7 4.2.8 4.2.9 4.2.10 4.2.11 4.2.12 4.2.13 Frequency of Inservice Tests (I' Pumps in Systems Out-of-Servic Reference Values (ISTB-3300)

Instrumentation Accuracy (ISTE Inservice Test Parameters (ISTI Allowable Ranges For Test Par, Testing Methods..........

Test Procedure...........

Trending (ISTB-6100)......

7 8

8

........................... 8 9

STB-3400).

9 ce (ISTB-3420).....

9 1-3510(a)).......................

10 k-3500).........................

11 umeters.........................

12

........................... 1 2

........................... 1 3 4.3 Pump Reference List...................

4.4 Pump Inservice Test Table...............

4.5 Proposed Pump Test Flow Paths...........

4.6 Records and Reports of Pumps............

4.7 Technical Positions....................

13 15 17 30 34 4.8 Relief Requests From Certain Subsection ISTB Requirements

..... 35 iii

TABLE OF CONTENTS (Contd.)

Page 5.0 VALVE INSERVICE TESTING PROGRAM.......

64 5.1 Introduction....................................

5.2 Program Implementation............................

5.2.1 Exemptions (ISTC-1200).

5.2.2 Valve Categories (ISTC-1300).

5.2.3 Preservice Testing (ISTC-3100)..

5.2.4 Inservice Testing (ISTC-3200).

5.2.5 Reference Values (ISTC-3300).

5.2.6 Valve Testing Requirements (ISTC-3500).;

5.2.7 Exercising Test Frequency (ISTC-3510).

5.2.8 Valve Obturator Movement (ISTC-3530).

5.2.9 Manual Valves (ISTC-3540).

5.2.10 Fail-Safe Valves (ISTC-3560)....................

5.2.11 Valves in Systems Out of Service (ISTC-3570).........

5.2.12 Valve Seat Leakage Rate Test (ISTC-3600)...........

5.2.13 Position Verification Testing (ISTC-3700)............

5.2.14 Instrumentation (ISTC-3800) 5.2.15 Specific Testing Requirements (ISTC-5000)...........

5.2.16 Check Valve Condition Monitoring Program Implementation 5.2.17 Vacuum Breaker Valves (ISTC-5230)...............

5.2.18 Safety and Relief Valve Tests (ISTC-5240)...........

5.2.19 Rupture Disks (ISTC-5250).....................

5.2.20 Explosively Actuated Valves.....................

5.2.21 Test Procedure..............................

5.2.22 Trending..................................

5.3 Valve Test Tables.........

71 5.4 Inservice Testing Program Notes....

5.5 Records and Reports of Valves.....

5.6 Technical Positions.............

5.7 Cold Shutdown Justifications......

N 5.8 Refueling Outage Justifications.............

5.9 Relief Requests From Certain Subsection ISTC and Mandatory Appendix I Requirements.........

150 168 iv

IST Program Plan Columbia Generating Station Page 1 of 181 3rd 10-Year Interval ou uaLLLo Revision 0

1.0 INTRODUCTION

This Inservice Testing (IST) Program Plan is applicable to Columbia Generating Station. 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 supply system designated as BWR/5. The reactor is contained within an over-under drywell/wetwell containment vessel designated Mark II. The Plant rated electrical output is 1,230 MWe.

This program plan is referenced in the Columbia Generating Station Final Safety Analysis Report (FSAR), Section 3.9.6, and has been prepared as the controlling document governing Pump and Valve Inservice Testing at Columbia Generating Station. This IST Program Plan complies with the requirements of 10 CFR Part 50.55a(b)(3) and Part 50.55a(f). The 2001 edition and the 2002 and 2003 Addenda of the ASME Code for Operation and Maintenance of Nuclear Power Plants (OM Code) was incorporated by reference into Paragraph 50.55a(b) by rulemaking effective on November 1, 2004. This code edition and addenda have been approved for use by the NRC for the IST of pumps and valves subject to certain limitations and modifications. The scope of this plan encompasses the testing of certain safety-related ASME Section III Nuclear Code Class 1, 2 and 3 pumps and valves. The plant safe-shutdown condition is cold shutdown. Where conformance with certain Code requirements 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 (4.0 and 5.0).

IST Program Plan G

Page 2 of 181 3rd 10-Year Interval Columbia Generatg StatLion Revision 0 1.1 Propram Administration Responsibilities for development, maintenance, and implementation of the 1ST Program Plan are detailed in Energy Northwest procedures.

Changes to the IST Program Plan involving a relief request from impractical Code requirements will be accomplished consistent with 10 CFR 50.55a.

Components failing to meet test requirements will be dispositioned by the Plant's Corrective Action program. Specific responsibilities are defined in the Plant procedures.

1.1.1 Code Errata/Editorial changes are defined by ASME-as follows:

Most editions of the ASME Code as published contain a number of editorial changes and perhaps some errata. Errata may include but, are not limited to the following:

Typographical errors or misspelling Grammatical errors Incorrect publication of approved items, omission by staff of approved items, printer errors, or incorrect publication of an item that was not approved.

Neglecting to update table for consistency with revision to corresponding text.

The changes described in Errata apply retroactively.

Generally, editorial changes are non-substantive and do not change the Code requirements in any way. At the Columbia Generating Station, editorial changes/errata are incorporated as applicable as soon as they have been approved by the ASME OM Code committee as being editorial/errata. Errata is also able to be incorporated retroactively.

1.1.2 Regulatory Limitations Regulatory Limitations are additional requirements or conditions that are imposed by the NRC in addition to, or in lieu of, those listed or endorsed in the ASME OM Code. Regulatory limitations may also be specific Code requirements which are NOT endorsed by the NRC, and which are required to be satisfied in order to fully implement regulatory requirements to the satisfaction of the NRC. The NRC may also impose additional or alternate methodology or requirements for IST Programs which are listed in 10 CFR 50.55a.

3ST Program Plan Columbia Generating Station Page3 of 181 3rd 10-Year Interval GeeaigRevision 0

The Columbia Generating Station has fully implemented all applicable regulatory limitations in the update to the 3'd Ten Year Interval IST Program. The specific Regulatory Limitations applicable to the Columbia Generating Station IST Program and, which have been incorporated into the 3rd Ten Year Interval IST Program are listed below:

a.

Motor Operated Valve Testing complies with the provisions for testing motor-operated valves in OM Code ISTC-3500, as applicable and a program (conforming to the requirements of Generic Letter 96-05) has been established to ensure that motor operated valves continue to be capable of performing their design basis safety functions.

b.

Manual valves in the IST Program will be exercised on a 2-year interval rather than the 5-year interval specified in paragraph ISTC-3540 of the OM Code, provided that adverse conditions do not require more frequent testing.

1.2 Program Database The IST Program Plan for the third ten year interval was developed based on a review of pumps and valves at Columbia Generating Station 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 existing IST Program database was reviewed again. The review utilized MEL (Master Equipment List), a database with information on components installed at Columbia Generating Station. 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 requires 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.

3rd 10-YearInterval Columbia Generating Station Page 4 of 181 1.3 References 1.3.1 10 CFR 50.55a, Codes and Standards 1.3.2 Columbia Generating Station Technical Specifications Section 5.5.6 1.3.3 FSAR Section 3.9.6 1.3.4 10 CFR 50, Appendix J, Columbia Generating Station Primary Containment Leakage RateTesting Program 1.3.5 ASME OM Code-2001, Code for Operations and Maintenance of Nuclear Power Plants 1.3.6 ASME OMa Code-2002 Addenda to ASME OM Code-2001, Code for Operations and Maintenance of Nuclear Power Plants 1.3.7 ASME OMb Code-2003 Addenda to ASME OM Code-2001, Code for Operations and Maintenance of Nuclear Power Plants 1.3.8 Generic Letter No. 89-04, Guidance on Developing Acceptable Inservice Testing Program, April 1989 1.3.9 NUREG-1482 Rev 1, Guidelines for Inservice Testing at Nuclear Power Plants, January 2005 1.3.10 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) 1.3.11 Safety Evaluation of Inservice Program Relief Requests for Pumps and Valves

- Washington Public Power Supply System (WPPSS) Nuclear Project NO. 2 (WNP-2) by NRC dated November 27, 1995 (TAC NO. M91159) and March 25, 1999 (TAC NO. MA3813) 1.3.12 Columbia Generating Station Final Safety Analysis Report 1.3.13 SWP-IST-01, ASME Inservice Testing 1.3.14 NEI White Paper Revision 1, Standard Format for Requests from Commercial Reactor Licensees Pursuant to 10 CFR 50.55a, June 2004

3ST Program Plan Columbia Generating Station Page 5 of 181 3rd 10-Year Interval oum a

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2.0 OUALITY ASSURANCE PROGRAM The Columbia Generating Station Pump and Valve Inservice Test Program activities will be conducted in accordance with the Energy Northwest's Operational Quality Assurance Program description (OQAPD).

IST Program Plan Columbia

.a Station Page 6 of 181 3rd 10-Year Interval CTeneralllg Revision 0 3.0 PIPING AND INSTRUMENT DIAGRAMS 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.

Ref.

Title No.

Main & Exhaust Steam System M502 Control & Service Air M510 Diesel Oil & Misc. Systems M512 Demineralized Water M517 Reactor Core Isolation Cooling M519 High/Low Pressure Core Spray M520 Residual Heat Removal M521 Standby Liquid Control M522 Reactor Water Cleanup M523 Standby Service Water M524 Reactor Closed Cooling M525 Fuel Pool Cooling M526 Control Rod Drive M528 Main Steam and Reactor Feedwater M529 Ref.

Title No.

Reactor Recirculation Cooling M530 Equipment Drain Radioactive M537 Floor Drain Radioactive M539 Containment Cooling & Purge M543 Standby Gas Treatment M544 Reactor Building HVAC M545 Containment Atmosphere Control M554 Containment Instrument Air M556 Main Steam Leakage Control M557 Undervessel Neutron Monitoring System M604 Class I Air System for Containment M619 Vacuum Breaker Valves Sh 161 Emergency Chilled Water M775 Post Accident Sampling M896

3ST Program Plan Columbia Generating Station Page7of 181 3rd 1 0-Year Interval

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4.0 PUMP INSERVICE TESTING PROGRAM 4.1 Introduction Highly reliable safety related equipment is a vital consideration in the operation of a nuclear generating station. To help assure operability, the Columbia Generating Station 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 OM Code-2001 and 2002 and 2003 Addenda subsection ISTB, "Inservice Testing of Pumps in Light-Water Reactor Nuclear Power Plants". The Program complies with the specifications of the approved Codes and Regulations. This program includes those ASME pumps which are provided with an emergency power source and perform a specific function in shutting down a reactor to the cold shutdown condition, maintaining the cold shutdown condition, or in mitigating the consequences of an accident.

The Program Plan establishes test intervals, parameters to be measured and evaluated, acceptance criteria, corrective actions, and records requirements. Where conformance with certain Code requirements is impractical, relief requests are included in Section 4.8 with supporting information and proposed alternatives.

3ST Program Plan Columbia Generating Station Page 8 of 181 3rd 10-Year Interval Geeaig&LLolRevision 0 4.2 Program Implementation 4.2.1 Exclusions (ISTB-1200)

The following are excluded from this Subsection:

a.

drivers, except where the pump and driver form an integral unit and the pump bearings are in the driver;

b.

pumps that are supplied with emergency power solely for operating convenience; and

c.

skid-mounted pumps that are tested as part of the major component and are justified by the Owner to be adequately tested.-

4.2.2 Pump Categories (ISTB-1300)

All pumps in the IST program shall be categorized as either a Group A or Group B pump. A pump that meets both Group A and Group B definitions shall be categorized as a Group A pump. Pump categorization is included in the Pump Inservice Test Table, section 4.4.

Group A pumps: pumps that are operated continuously or routinely during normal operation, cold shutdown, or refueling operations.

Group B pumps: pumps in standby systems that are not operated routinely except for testing.

4.2.3 Preservice Testing (ISTB-3100)

During the preservice test period or before implementing inservice testing, an initial set of reference values shall be established for each pump. These tests shall be conducted under conditions as near as practicable to those expected during subsequent inservice testing. Except as specified in section 4.2.7, only one preservice test is required for each pump. A set of reference values shall be established in accordance with section 4.2.7 for each pump required to be tested by this Subsection. Preservice testing shall be performed in accordance with the requirements of the following paragraphs:

a.

centrifugal pump tests (except vertical line shaft centrifugal pumps) in accordance with ISTB-51 10;

b.

vertical line shaft centrifugal pump tests in accordance with ISTB-5210; and

c.

reciprocating positive displacement pump tests in accordance with ISTB-53 10.

IST Program Plan Page 9 of 181 3rd 10-Year Interval Columbia Generating Station Revision 0 4.2.4 Inservice Testing (ISTB-3200)

The Columbia Generating Station Pump Inservice Testing Program is implemented as Part of the Technical Specification required surveillance testing program. Inservice testing of a pump in accordance with Subsection ISTB-3200 shall commence when the pump is required to be operable. Inservice testing shall be performed in accordance with the requirements of the following paragraphs:

a.

centrifugal pump tests (except vertical line shaft centrifugal pumps) in accordance with ISTB-5120;

b.

vertical line shaft centrifugal pump tests in accordance with ISTB-5220; and

c.

reciprocating positive displacement pump tests in accordance with ISTB-5320.

4.2.5 Frequency of Inservice Tests (ISTB-3400)

An inservice test shall be run on each pump as specified in Table ISTB-3400-1.

TABLE ISTB-3400-1 INSERVICE TEST FREQUENCY Pump Group A Group B Comprehensive Group Test Test Test Group A Quarterly N/A Biennially Group B N/A Quarterly Biennially GENERAL NOTE: N/A -Not Applicable 4.2.6 Pumps in Systems Out-of-Service (ISTB-3420)

For a pump in a system declared inoperable or not required to be operable, the test schedule need not be followed. Within 3 months before the system is placed in an operable status, the pump shall be tested and the test schedule resumed.

Pumps that can only be tested during plant operation shall be tested within 1 week following plant startup. NUREG-1482 Rev 1, Section 5.1.2 provides additional guidance.

4.2.7 Reference Values (ISTB-3300)

Reference values are established and maintained in accordance with ISTB-3300 and measured in accordance with ISTB-3500. 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.

IST Program Plan Coumi Stato Page 10 of 181 3rd 10-Year Interval Columbia Generatmg Saio Revision 0 4.2.8 Instrumentation Accuracy (ISTB-3510(a))

Instrumentation accuracy shall be within the limits of Table ISTB-3500-1. If a parameter is determined by analytical methods instead of measurement, then the determination shall meet the parameter accuracy requirement of Table ISTB-3500-1 (e.g., flow rate determination shall be accurate to within +/- 2%

of actual). For individual analog instruments, the required accuracy is percent of full scale. For digital instruments, the required accuracy is over the calibrated range. For a combination of instruments, the required accuracy is loop accuracy.

For further clarification see ASME OM Code Interpretation 01-09.

The Columbia Generating Station instruments used for pump testing meet these requirements except where written relief has been requested.

TABLE ISTB-3500-1 REQUIRED INSTRUMENT ACCURACY Quantity Group A and Comprehensive and Group B Test, %

Preservice Tests, %

Pressure

+/-2

+/- l/2 Flow rate

+2

+/-2 Speed

+/-2

+/-2 Vibration

+/-5

+/-5 Differential pressure

+/-2

+/- 1/2

IST Program Plan Columbia Station Page 11 of 181 3rd 10-Year Interval Generatig Revision 0 4.2.9 Inservice Test Parameters (ISTB-3500)

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

Differential Pressure (0P) - 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. If a meter does not indicate the flow rate directly, the record shall include the method used to reduce the data. Internal recirculated flow is not required to be measured. External recirculated flow is not required to be measured if it is not practical to isolate, has a fixed resistance, and has been evaluated by the Owner to not have a substantial effect on the results of the test.

Vibration (V) -Vibration measurements for centrifugal pumps, vertical line shaft pumps, and reciprocating pumps shall be taken at the locations specified in U

ISTB-3540. If a portable vibration indicator is used, the measurement points shall be clearly identified on the pump to permit subsequent duplication in both location and plane.

TABLE ISTB-3000-1 INSERVICE TEST PARAMETERS Quantity Preservice Group Group Compre-Remarks Test A

B hensive Test Test Test Speed, N X

X X

X If variable speed Differential Pressure, &P X

X X(Note (1))

X Centrifugal pumps, including vertical line shaft pumps Discharge Pressure, P X

X X

Positive displacement pumps Flow Rate, Q X

X X(Note (1))

X Vibration X

X X

Measure either Vd or V, Displacement, Vd Peak-to-peak Velocity, V, Peak NOTE:

2 (1) For positive displacement pumps, flow rate shall be measured or determined; for all other pumps, differential pressure or flow rate shall be measured or determined.

IST Program Plan Columbia Generating Station Page 12 of 181 3rd 10-Year Interval

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4.2.10 Allowable Ranges For Test Parameters ISTB Subsection Table-5100-1, Table-5200-1 and Table-5300-2 provide the allowable ranges for pump testing parameters. When the allowable range is more restrictive in the Technical Specifications, or other design basis document, the more restrictive ranges are used.

4.2.11 Testing Methods During an inservice test, flow rate is normally selected as the independent test parameter and is set to match the reference flow rate. Then other hydraulic and mechanical test parameters are measured in accordance with ISTB-3500. All deviations from the appropriate reference values shall be compared with the appropriate ranges and corrective action taken as specified in ISTB-6200.

All pumps at Columbia Generating Station are capable of being tested at full design flow.

4.2.12 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., test gauges, portable temperature or vibration monitors) is noted.

Identification numbers, range and calibration verification of instrumentation are 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.

Proposed flow paths are illustrated in Section 4.5.

d.

Acceptance Criteria.

The ranges within which test data is considered acceptable is established by the Energy Northwest and included in the test procedure. The method for determining test parameter values that are not directly measured by instruments is specified in the procedure. In the event that the data falls outside the acceptable ranges, corrective actions are taken in accordance with ISTB-6200,

e.

Test Instruments. A description of instruments used.

f.

Reference Values.

IST Program Plan Columbia Station Page 13 of 181 3rd 10-Year Interval Generating Revision 0 4.2.13 Trending (ISTB-6100)

Test parameters shown in Table ISTB-3000-1, except for fixed values, shall be trended.

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

4.3 Pump Reference List This list gives a brief description of each pump identified in-the Pump Inservice Test Table, Section 4.4.

DO-P-IA, 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-lA, 1B The Fuel Pool Cooling (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 above normal reactor operating pressures. The pump can take suction from the Condensate Storage Tank or from the suppression pool.

HPCS-P-2 This motor driven 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 pond.

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

3ST Program Plan Columbia Generating Station Page 14 of 181 3rd 10-Year Interval

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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.

RHR-P-2A, 2B, 2C The Residual Heat Removal pumps are high capacity, low head pumps which have multiple uses during normal and emergency Plant conditions.

In conjunction with other systems, restores and maintains reactor coolant inventory in the event of a LOCA (Pumps 2A, 2B, 2C)

Removes decay heat after shutdown (Pumps 2A, 2B)

Cools the suppression pool (Pumps 2A, 2B)

Can provide cooling spray to upper and lower drywell and to the wetwell (Pumps 2A, 2B)

Can assist in fuel pool cooling (Pump 2B)

Can provide a condensing spray to the reactor head (Pump 2B)

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

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

SW-P-lA, 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 Columbia Generating Station Page 15 of 181 3rd 10-Year Interval GeeaigLLLOIRevision 0 4.4 Pump Inservice Test Table The pumps included in the Columbia Generating Station 1ST Program are listed in the Test Table. The information contained in this table identifies those pumps required to be tested to the requirements of OM Code Subsection ISTB, the testing parameters and frequency of testing, and associated relief requests.

Legend Q

=

Quarterly (92 day interval) test 2Y

=

Biennially (2 Year interval) test CPT

=

Comprehensive Pump test N/A

=

Not applicable. See Relief Requests NR

=

Not required by Code A

=

Group A Pump B

=

Group B Pump

IST Program Plan Page 16 of 181 3rd 10-Year Interval Columbia Generating Station Revision 0 Pump Inservice Test Table Inlet Disch Diff Flow Vib Relief Pump Flow ASME Press Press Press Rate Vel Pump Requests &

Pump Idert Group Diagram Code Pump Type Speed Techical Gop& Coord Class Pi Sped Tehnca DO-P-I CPT CPT M

CPT 3

Q CPT Positions DO-P-1A*

B M512-4 3

Vertical Line Q 2Y Q 2Y Q 2Y NR 2Y NR 2Y NR 2,7,8,TPOI BIO Shaft QI I

DO-P-2B*

B M512-4 Vertical LineQ 2Y Q 2Y Q 2Y NR 2Y NR 2Y NR 2,7,8,TPO0 GIO Shaft M512-4Vertical Line DOF-P-2*

B M52-3 Shaft Q

2Y Q 2Y Q 2Y NR 2Y NR 2Y NR 2,7,8,TPOI FPC-P-1A A

M526-1 3

Centrifugal Q

2Y Q 2Y Q 2Y Q

2Y Q

2Y NR 7

FPC-P-2B A

M526-1 3

Centrifugal Q 2Y Q 2YQ2Y Q 2Y Q

2Y NR 7

C 13 I_

_I HPCS-P-1 B

M520 2

Vertical Line Q 2Y Q 2Y Q 2Y Q 2Y NR 2Y NR 4,5,7 RCIC-P-I6 Shaft I

I HPCS-P-2 A

M524-1 3

Vertical Line Q 2 Q 2Y Q 2 Q 2Y Q

2Y NR 1,3,7 G5 Shaft N/

2Y NA Q

Y0 2Y R

1,7 LPCS-P-2 B

M520 2

Vertical Line Q 2Y 0 W2 Q 2Y Q 2Y NR 2Y NR 4,7 B12 Shaft RCIC-P-1 B

M519 2

Centrifugal Q 2Y Q 2Y Q 2Y Q 2Y NR 2Y QN2Y 4,7 D12 RHR-P-2A A

M521-1 2

Vertical Line Q 2Y Q 2Y N 2Y Q

2Y N

2Y NR 4,5,7 Bi I Shaft RH--B A

M521-2 2

Vertical Line 2Y D6C-P-1B A

D6 2

Shaft Q 2Y Q Q2Y Q2Y Q 2Y NR 4,5,7 RHR-P-2C A

M521-3 2

Vertical Line Q

2Y Q 2Y Q 2Y h

2Y 0

2Y NR 4,5,7 Cs Shaft SLC-P-IA B

M522 2

Reciprocating NR Q 2Y NR Q

2Y NR 2Y NR 6,7

______F6 Positive Disp.

SLC-P-lB B3 M522 2

Reciprocating N-R Q 2Y NR Q

2Y NR 2Y NR 6,7 D6 Positive Disp.___

SW-P-lA A

M524-1 3

Vertical Line N/A Q 2Y N/A Q

2Y Q 2Y NTR 1,3,7 G4 Shaft SW-P-lB A

M524-2 3

Vertical Line N/A Q 2Y N/A Q

2Y Q

2Y NR 1,3,7 FS Shaft

These are fixed resistance systems.

IST Program Plan Columbia Generating Station Page 17 of 181 3rd 10-Year Interval LouuaalnRevision 0

4.5 Proposed Pump 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.

IST Program Plan Columbia Generating Station Page 18 of 181 3rd 10-Year Interval ouma Ial,1Revision 0

DO-P-lA. DO-P-lB. & DO-P-2 PUMP TEST FLOW PATH V-12 V-11 REFERENCES.

P&ID M512 SH 4 IST38 dmwbktie Ai1 1.2005 DIESEL FUEL OIL

IST Program Plan Columbia Station Page 19 of 181 3rd 10-Year Interval Generating Revision 0 FPC-P-lA and FPC-P-1B PUMP TEST FLOW PATH P&ID M526 IST.37 drawing Me January 31. 2005 FUEL POOL COOLING

3STrogram Plan Columbia Generating Station Page 20 of 1 81 3rd 10-Year Interv'al oubaGnrtn tto Revision 0 HPCS-P-1 PUMP TEST FLOW PATH REFERENCES, P&ID M520 BECS-P-1 IST.38 drawing file April 1, 2005 HIGH PRESSURE CORE SPRAY

IST Program Plan 3rd 10-Year Interval Columbia Generating Station HPCS-P-2 PUMP TEST FLOW PATH Page 21 of 181 Revision 0 HPCS-V-28 2 112" cTyp) 3.

IST.39 drawing too V-4C January 31. 2005 HPCS SERVICE WATER

3ST Program Plan Columbia Generating Station Page 22 of 181 3rd 10-Year Interval 3e ra ngRevision 0

LPCS-P-1 PUMP TEST FLOW PATH FE-2 LpQS-P-1 IST.40 drawing file January 31, 2005 LOW PRESSURE CORE SPRAY

IST Program Plan

-lPmag Generating StPagen23 of 181 3rd 10-Year Interval Coumia enrain Station1 Revision 0 RCIC-P-1 PUMP TEST FLOW PATH V-b V-Il1 REACTOR CORE ISOLATION COOLING

1ST Program Plan Columbia Generating Station Page 24 of 181I 3rd 10-Year Interval oum i alflRevision 0

RHR-P-2A PUMP TEST FLOW PATH V.48A RO-5A SHR-P-2A ISTA2 drawing rl Apl 1. 2005 RESIDUAL HEAT REMOVAL

IST Program Plan Columbia Generating Station Page 25 of 181 3rd 10-Year Interval GeeaigLL~olRevision 0 RHR-P-213 PUMP TEST FLOW PATH IST.43 drawing fle January3l,2005 RHR-P2 RESIDUAL HEAT REMOVAL

3ST Program Plan Columbia Generating Station Page 26 of 181 3rd 10-Year Interval Ynea ngRevision 0

RHR-P-2C PUMP TEST FLOW PATH RHRP2r RESIDUAL HEAT REMOVAL

3ST Program Plan Columbia Generating Station Page 27 of 181 3-rd 10-Year Interval

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SLC-P-1A & SLC-P-1B PUMP TEST FLOW PATH IST.45 drawing file MAY24, 1999 STANDBY LIQUID CONTROL

IST Program Plan Columbia Generating Station Page 28 of 181 3rd 10-Year Interval GeeaigRevision 0

SW-P-1A PUMP TEST FLOW PATH 18' 20' PUMP HOUSE WALL 1 20 REFERENCES, P&ID M524 SH I IST.46 drawing file January 31, 2005 SERVICE WATER

0ST Program Plan Columbia Generating Station Page 29 of 181 3rd 10-Year Interval oim a

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SW-P-1B PUMP TEST FLOW PATH REFERENCES, P&ID M524 SH 2 ISTAT7 dowV Bin Jaruary 31, 2005 SERVICE WATER

ST Program Plan Columbia Station Pagee 30 of 181 3rd 10-Year IntervalGe raigRiso0 4.6 Records and Reports of Pumps Records and reports of pumps in the Program will be maintained in accordance with OM Code Subsection ISTB, Paragraph ISTB-9000. The files will contain the following:

4.6.1 Pump records will be maintained in accordance with Paragraph ISTB-9100.

4.6.2 Inservice test plans include pump surveillance test procedures. The inservice testing records for pumps in the Program will be maintained in accordance with Paragraph ISTB-9200.

4.6.3 Records of tests for pumps in the Program will be maintained in accordance with Paragraph ISTB-9300. Completed surveillance test procedures are retained per Plant Administrative Procedures.

4.6.4 Records of corrective actions for pumps in the Program will be maintained in accordance with Paragraph ISTB-9400. Corrective actions are documented on Work Orders (WO) and/or Condition Reports (CRs).

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.

IST Program Plan Columbia Generating Station Page 31 of 181 3rd 10-Year Interval

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SAMPLE DATA SHEET - Group A Test PUMP OPERABILITY DATA SHEET FOR RHR-P-2A Refer Action Lo Alert Lo Action Hi Test Parameters Units Value

(+1)

Measured Value

(+ 1)

Driver Lubrication N/A SAT N/A N/A UNSAT Upper Thrust Bearing OF 152 NIA N/A N/A Temperature per W139 Lower Guide Bearing OF 109 N/A N/A N/A Temperature per W140 Pump Lubrication N/A SAT N/A N/A UNSAT SW Flow per GPM 7

N/A N/A N/A S W~N-FI-17A2 Suction Pressure at Test Flow per PSIG 15.3 9.2 N/A N/A Test Gaupce Discharge Pressure per PSIG 135.87

(+5)

N/A N/A TDAS X155 Diff. Press (Disch. Press. -

PSID 120.57

(+2)

(+3)

(+2)

Suction Press. per Test Gauge)

Indicated Flowrate per GPM 7500

7493 N/A N/A TDAS X163

(+4)

Fluid Temperature per OF 70 N/A NIA N/A CMS-TR-5 or TR-6, PT220 Motor Voltage per SM7 Volts VAC 4140 N/A NIA N/A Motor Current per RHR-P-2A AMP 89 N/A N/A N/A Meter

(+ 1)

For measured values beyond the Alert Value or Action Value refer to Precaution and Limitations 4.5 or 4.6, 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 7493 gpm provides actual flow GT 7450 gpm (Tech. Spec. Limit) for fluid temperature GE 400F.

(+5)

Discharge pressure is required to be GE the corrected discharge pressure for the flow listed in.6

1ST Program Plan Columbia Generating Station Pagev32of 3rd 10-Year Interval

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SAMPLE DATA SHEET VIBRATION DATA SHEET FOR RHR-P-2A MUA PA MUN MUW MLN PN View Lookina South VIBRATION VELOCITY (IN/SEC)

PROBE LOCATION REFER VALUE MEASURED VALUE ALERT HI

(+ 1)

ACTlON HI

(+1)

MUA 0.071 0.178 0.426 ASME MUN 0.152 0.325 0.700 MUW 0.082 0.205 0.492 MLN 0.048 N/A N/A NON-MLW 0.042 NIA NIA ASME PA 0.155 N/A N/A PN 0.082 N/A N/A I

PW 0.037 1

N/A N/A

(+1)

For measured values beyond the Alert Value or Action Value refer Limitations 4.5 or 4.6, respectively.

to Precaution and

IST Program Plan Columbia Generating Station Page 33 of 181 3rd 10-Year Interval GeeaigRevision 0

SAMPLE DATA SHEET - Group A Test RHR-P-2A ACCEPTANCE CRITERIA 0-4 V)-

231

-l 1

l 130---

229-22 7-226-______=-

225 ACTI N R GE 123-.--

122---

21=---

21-1l1- - =

22 112--=

209-4

=

=REF.

' URV1I

=

105----

==

=

_== =

103- -

976-

=

= -

=

96--

1 l

9 irrTr iTiTTTTlT WTT iT3F lTIT ilTT 1Ty 7490 7500 7510 7520 7530 7540 7550 7560 7570 7530 7590 7600 7610 7620 7630 7640 7650 INDICATED FLOW - GPM ALERT RANGE - Arca Inside 3^4-5-6 ACTION RANGE - Area Outside 1.2-34

3ST Program Plan Columbia Ge34vof 181 3rd 10-Year Interval Geeaig~L inRevision 0

4.7 Technical Positions Technical Position -- TPO1 Pump Code Class P&ID Dwg. Number System(s)

DO-P-lA 3

M512, SH 4 DO-P-lB 3

M512, SH 4 Diesel Fuel Oil Transfer DO-P-2 3

M512, SH 4 1

Title Use of tank level to calculate differential pressure of pumps DO-P-lA, DO-P-lB and DO-P-2.

Issue Discussion ISTB-3520(b) 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. NUREG-1482 Rev. 1, 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 determining differential pressure for the pump. The NRC staff recommends use of tank level 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.

Position 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% for group A and B tests and +/- 1/2% for comprehensive pump test. 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 Columbia Station Page 35 of 181 3rd 10-Year Interval Generatig Revision 0 4.8 Relief Requests From Certain Subsection ISTB Requirements Relief Requests either provide alternative to Code requirements in accordance with 10CFR 50.55a(a)(3)(i) or 10CFR 50.55a(a)(3)(ii) or relief from impractical Code requirements in accordance with IOCFR 50.55a(f)(5)(iii). They provide technical justification and propose alternate testing to be performed in lieu of the Code required testing.

IST Program Plan Columbia Generating Station Page 36 of 181 3rd 10-Year Interval oum 1 aL alnRevision 0

Relief Request - RP01 Proposed Alternative in Accordance with 10CFR 50.55a(a)(3)(i)

--Alternative Provides Acceptable Level of Quality and Safety-ASME Code Components Affected P

Code Pump P & ID Dwg. No.

System(s)

C lass G roup SW-P-IA 3

A M524, SH I

. Standby Service Water SW-P-lB 3

A M524, SH 2 Standby Service Water HPCS-P-2 3

A M524, SH 1 Standby Service Water, HPCS

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

Measure pump differential pressure, &P. Vertical line shaft centrifugal pumps preservice and inservice testing (ISTB-5210, ISTB-5220, Table ISTB-3000-1). Relief is required for Group A, Group B and comprehensive and preservice tests.

Reason for Request

There are no inlet pressure gauges installed in the inlet of these vertical line shaft centrifugal pumps, making it impractical to directly measure inlet pressure for use in determining differential pressure for the pump.

Proposed Alternative and Basis for Use Pump discharge pressure will be recorded during the testing of these pumps. Code Acceptance Criteria will be based on discharge pressure instead of differential pressure as specified in the Code Table ISTB-5200-1. 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.

1.

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

2.

Technical Specification SR 3.7.1.1 states minimum allowable spray pond level to assure adequate NPSH and ultimate heat sink capability.

3ST Program Plan Columbia Generating Station Page 37 of 181 3rd 10-Year Interval

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Relief Request -- RPOI1 (Contd.)

3.

The difference between allowable minimum and overflow pond level is only 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.

Acceptable flowrate and discharge pressure will suffice as proof of adequate suction pressure.

5.

These pumps operate with a suction lift. Maximum elevation of spray pond level is 434 feet 6 inches and minimum elevation of discharge piping for these pumps is 442 feet 5/8 inches. Thus discharge pressure for these pumps will always be lower than the calculated differential pressure for the entire range of suction pressures. Thus acceptance criteria based on discharge pressure is conservative. This is further illustrated below.

Differential pressure is defined as discharge pressure minus suction pressure. In the case of a pump with suction lift the suction pressure is negative, thus:

AP I'd - (- Ps)

AP = Pd + Ps This concept is more easily understood when head is used instead of pressure.

CASE 1 CASE 2 Suction Head Suction Lift Discharge Tota itHeadPs d

Hea Toa Discharge Head Suction suctin Pd Head ft i

Hea I

,1~~ L IST.RPOI drawing file Jan 7, 2005

3ST Program Plan Columbia Generating Station Page 38 of 181 3rd 10-Year Interval oum a

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Relief Request -- RPO1 (Contd.)

The ASME Code uses the term differential pressure instead of total head since differential pressure is required to be measured. However, most literature on pumps deals with hydraulic parameters in terms of head and flow. In case 1:

Total Head = Discharge Head - Suction Head But in Case 2 (Service Water Pumps)

Total Head = Discharge Head + Suction Lift When one converts head to pressure, the equivalent formula for differential pressure would be:

AP = Pd + 0.431 (ELpump - EL ater level)

Since pump discharge pipe elevation for these pumps is always more than spray pond water level, discharge pressure is always less than the calculated differential pressure.

Oualitv/Safelv Impact The effect of setting the Code Acceptance Criteria on discharge pressure instead of differential pressure as specified in the Code provides a more conservative test methodology.

Duration of Proposed Alternative Third 10 year interval.

Precedents This relief request was granted for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159) and Supplement to SER letter dated March 25, 1999 (TAC No. MA3813), Relief Request No. RP-01.

1STProg10 Plan Columbia GeneratiPgg Station Page 39 of 181 3rd 10-Year Interval

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Hardship or Unusual Difficulty without Compensating Increase in Level of Quality or Safety --

ASME Code Components Affected Pump Code Class Pump P&ID Dwg. No.

System(s)

P u m p C o e Class G ro u p DO-P-1A 3

B M512, SH 4 DO-P-lB 3

B

1Ml2, SH 4 Diesel Fuel Oil Transfer DO-P-2 3

B M512, SH 4

-I_

I

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

Subsection ISTB-3550. Flow rate shall be measured using a rate or quantity meter installed in the pump test circuit.

Subsection ISTB-5200 (a). For the Group A test and the comprehensive test, after pump conditions are as stable as the system permits, each pump shall be run at least 2 minutes. At the end of this time at least one measurement or determination of each of the quantities required by Table ISTB-3000-1 shall be made and recorded.

Relief is required for Group A, Group B and comprehensive and preservice tests.

Reason for Request

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

As a result of a rate or quantity meter not being installed in the test circuit, it is impractical to directly measure the flow rate for the Diesel Fuel Oil Transfer Pumps. Therefore, the requirement for allowing a 2 minute "hold" time for Pump tests is an unnecessary burden which would provide no additional assurance of determining pump operational readiness.

Proposed Alternative and Basis for Use NUREG-1482, Rev 1 Section 5.5.2 states, "requiring licensees to install a flow meter to measure the flow rate and to guarantee the test tank size, such that the pump flow rate will stabilize in 2 minutes before

IST Program Plan C

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recording the data would be a burden because of the design and installation changes to be made to the existing system. Therefore, compliance with the Code requirements would be a hardship".

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 Code, Table ISTB-3500-1. The pump flow rate calculation is identified on the record of test and ensures that the method for the flow rate calculation yields an acceptable means for the detection and monitoring of potential degradation of the Diesel Fuel Oil Transfer Pumps and therefore, satisfies the intent of the OM Code Subsection ISTB.

In this type of testing, the requirement to maintain a 2 minute hold time after stabilization of the system is unnecessary and provides no additional increase of the ability of determining pump condition.

Quality/Safety Impact The day tanks are horizontal cylindrical tanks with elliptical ends. The tank fluid volume is approximately 3,200 gallons. The average calculated flow rate is 28 gpm. The accuracy of the level reading is +/-1/8 inch. The accuracy of volume change is +1-1/4 inch (1/8 inch at initial level and 1/8 inch at final level).

1/4 inch corresponds to approximately 11 gallons in the range of the day tank level used during the performance of the pump surveillance test. The pump is required to be run a minimum of 25 minutes. This is to ensure that the Code required accuracy for flow rate measurement of +/- 2 percent is satisfied. The test methodology used to calculate pump flow rate will provide results consistent with Code requirements.

This will provide adequate assurance of acceptable pump performance.

Calculation methods are specified in the surveillance procedures for the Diesel Fuel Oil Transfer Pumps, and meet the quality assurance requirements of the Columbia Generating Station.

Duration of Proposed Alternative Third 10 year interval.

Precedents This relief request was granted for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159) and Supplement to SER letter dated March 25, 1999 (TAC No. MA3813), Relief Request No. RP-02.

1ST Program Plan Columbia Generating Station Page 41 of 181 3rd 10-Year Interval GeeaigRevision 0

Relief Request -- RP03 Relief Request in Accordance wvith 10CFR 50.55a(f)(5)(iii)

-- Inservice Testing Impracticality --

ASME Code Components Affected Pump Code Class Group PMID Dwg. Number System(s)

SW-P-lA 3

A M524. SH 1 Standbv Service Water SW-P-lB 3

A M524, SH 2 Standby Service Water HPCS-P-2 3

A M524, SH 1 Standby Service Water, HPCS

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

Subsection ISTB-5221(b) and ISTB-5223(b). The resistance of the system shall be varied until the flow rate equals the reference point. The differential pressure shall thenbe determined and compared to the reference value. Alternatively, the flow rate shall be varied until the differential pressure equals the reference point and the flow rate determined and compared to the reference flow rate value.

Relief is required for Group A, Group B and comprehensive and preservice tests.

Impracticality of Compliance The establishment of specific reference values is impractical for these vertical line shaft centrifugal pumps.

Burden Caused by Compliance

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 flow 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

3ST Program Plan Columbia Generating Station Page 42 of 181 3rd 10-Year Interval ou~aLaInRevision 0

Relief Request -- RP03 (Contd.)

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 (i.e., 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 service 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.

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 flow 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-lA and SW-P-lB pumps and approximately 1,050 - 1,160 gpm for HPCS-P-2 pump. Consequently, the requirement 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., flow balance) as required by Technical Specification.

Proposed Alternative and Basis for Use As discussed above, it is impractical to return to a specific value of flow rate or discharge pressure for testing of these pumps. As stated in NUREG-1482 Rev 1 Section 5.2, some system designs do not allow for testing at a single reference point or a set of reference points. In such cases, it may be necessary to plot pump curves to use as the basis for variable reference points. Code Case OMN-9,"Use of Pump Curves for Testing," is included in RG 1.192,"Operations and Maintenance Code Case Acceptabilty, ASME OM Code." Flow rate and discharge pressure are measured during inservice testing 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 RPO1. The following elements are used in developing and implementing the reference pump curves. These elements follow the guidance of Code Case OMN-9.

This Code Case has been accepted by the NRC staff with the condition that (1) when the repair, replacement, or routine servicing of a pump may have affected a reference curve, the licensee must determine a new reference curve, or reconfirm an existing reference curve, in accordance with Section 3 of Code Case OMN-9; and(2) if it is necessary or desirable, for some reason other than that

IST Program Plan C

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stated in Section 4 of Code Case OMN-9,to establish an additional reference curve or set of curves, the licensee must determine the new curves in accordance with Section 3 of Code Case OMN-9.

1.

A reference pump curve (flow rate vs discharge pressure) has been established for SW-P-lA 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 preoperational test data.

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.

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 required 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 ISTB-5200-1 for applicable test type.

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-lA pump Acceptance Criteria sheet for Group A test. 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.

7.

Similar reference curves will be used for comprehensive pump tests using the applicable acceptance criteria and instrument accuracy and range requirements.

8.

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

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.

1ST Program Plan Columbia Generating Station Page 44 of 1SI 3rd 10-Year Interval

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Relief Request -- RP03 (Contd.)

10.

When the repair, replacement, or routine servicing of a pump may have affected a reference curve, a new reference curve shall be determined, or the existing reference curve reconfirmed, in accordance with Section 3 of Code Case OMN-9.

11.

If it is necessary or desirable, for some reason other than that stated in Section 4 of Code Case OMN-9, to establish an additional reference curve or set of curves, the new curve(s) in accordance with Section 3 of Code Case OMN-9 must be determined.

Qualitv/Safetv Impact Design of the Columbia Generating Station 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 will have no adverse impact on Plant and public safety.

Duration of Proposed Alternative Third 10 year interval.

Precedents This relief request was granted for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159), Relief Request No. RP-03.

IST Program Plan Columbia Generating Station Page 45 of 181 3rd 10-Year Interval

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Relief Request -- RP03 (Contd.)

SAMPLE DATA SHEET - Group A Test SW-P-IA ACCEPTANCE CRITERIA n

LO2 P1.

co)

Ln C:2 w

Pa CL co A_

4'J.

=

__==_=

ACTION R NGE 230 -

220-200 215-190-195-ALERT 9.330 9.430 9.530 9.630 9.730 9.830 9.930 10.030 10.130 10.230 FLOW - GPM (Thousands)

ALERT RANGE = Area Inside 3-4-5-6 ACTION RANGE = Area Outside 1-2-3-4

IST Program Plan Columbia Geeatn Station Page 46 of 181 3rd 10-Year Interval Cb enerating Revision O Relief Request - RP04 Relief Request in Accordance with 10CFR 50.55a(f)(5)(iii)

-- Inservice Testing Impracticality --

ASME Code Components Affected PUMP Code Class Pump Group P&ID Dwg.System(s)

_ _ _N um ber LPCS-P-1 2

B M520 Low Pressure Core Spray RHR-P-2A 2

A M521, SH 1 RHR-P-2B 2

A M521, SH 2 Residual Heat Removal RHR-P-2C 2

A M521, SH 3 HPCS-P-1 2

B M520 High Pressure Core Spray RCIC-P-1 2

B M519 Reactor Core Isolation Cooling

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

RCIC-P-1 (Centrifugal Pump):

Group B Test: Subsection ISTB-5122(a), ISTB-5122(b) and ISTB-5122(c). The pump shall be operated at a speed adjusted to the reference point (+/- 1 %) for variable speed drives. System resistance may be varied as necessary to achieve the reference point. The differential pressure or flow rate shall be determined and compared to its reference value.

Comprehensive Test: Subsection ISTB-5123(a) and ISTB-5123(b). The pump shall be operated at a speed adjusted to the reference point (+/- 1 %) for variable speed drives. The resistance of the system shall be varied until the flow rate equals the reference point. The differential pressure shall then be determined and compared to the reference value. Alternatively, the flow rate shall be varied until the differential pressure equals the reference point and the flow rate determined and compared to the reference flow rate value.

Other Pumps (Vertical line Shaft Centrifugal Pumps):

Group B Test: Subsection ISTB-5222(b) and ISTB-5222(c). System resistance may be varied as necessary to achieve the reference point. The differential pressure or flow rate shall be determined and compared to its reference value.

Group A and Comprehensive Test: Subsection ISTB-5221(b) and ISTB-5223(b). The resistance of the system shall be varied until the flow rate equals the reference point. The differential pressure shall then be determined and compared to the reference value. Alternatively, the flow rate shall be varied until the

IST Program Plan Columbia (ni StiPage 47 of 181 3rd 10-Year Interval Cou bi enerating SainRevision 0

Relief Request - RP04 (Contd.)

differential pressure equals the reference point and the flow rate determined and compared to the reference flow rate value.

Impracticality of Compliance The establishment of specific reference values is impractical for these pumps.

Burden Caused by Compliance 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.

Proposed Alternative and Basis for Use As discussed above, it is impractical to return to a specific value of flow rate, or differential pressure for testing of these pumps. As stated in NUREG-1482 Rev 1 Section 5.2, some system designs do not allow for testing at a single reference point or a set of reference points. In such cases, it may be necessary to plot pump curves to use as the basis for variable reference points. Code Case OMN-9,"Use of Pump Curves for Testing," is included in RG 1.192,"Operations and Maintenance Code Case Acceptabilty, ASME OM Code."

Since the independent reference variable (flow rate) for these pumps is impractical to adjust to a fixed reference value and requires excessive valve manipulation, the maximum variance shall be limited to +/- 2 %

of the reference value. Thus, flow rate shall be adjusted to be within +/- 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 flow 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. 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.

IST Program Plan Columbia Generating Station Page 48 of 81 3rd 10-Year Interval GeeaigkL~~lRevision 0 Relief Request -- RP04 (Contd.)

The following elements are used in developing and implementing the reference pump curves. These elements follow the guidance of Code Case OMN-9. This Code Case has been accepted by the NRC staff with the condition that (1) when the repair, replacement, or routine servicing of a pump may have affected a reference curve, the licensee must determine a new reference curve, or reconfirm an existing reference curve, in accordance with Section 3 of Code Case OMN-9; and(2) if it is necessary or desirable, for some reason other than that stated in Section 4 of Code Case OMN-9,to establish an additional reference curve or set of curves, the licensee must determine the new curves in accordance with Section 3 of Code Case OMN-9.

1.

A reference pump curve (flow 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.

2.

For RCIC-P-1, 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 impracticality of setting speed to a specific reference value.

Additionally, 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 (+/- 12 gpm) in flow rate.

3.

For HPCS-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.

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 applicable Table ISTB-5 100-1 or Table ISTB-5200-1. See the attached sample RHR-P-2A pump Acceptance Criteria sheet for Group A test. 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. A similar sample RCIC-P-1 pump Acceptance Criteria sheet for Group B test is also attached. The acceptance criteria limits do not conflict with Technical Specifications or FSAR operability criteria.

8.

Similar reference curves will be used for comprehensive pump tests using the applicable acceptance criteria and instrument accuracy and range requirements.

IST Program Plan Columbia Generating Station Page 49 of 3rd 10-Year Interval ouma L1OIRevision 0

Relief Request -- RP04 (Contd.)

9.

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

10.

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.

11.

When the repair, replacement, or routine servicing of a pump may have affected a reference curve, a new reference curve shall be determined, or the existing reference curve reconfirmed, in accordance with Section 3 of Code Case OMN-9.

12.

If it is necessary or desirable, for some reason other than that stated in Section 4 of Code Case OMN-9, to establish an additional reference curve or set of curves, the new curve(s) in accordance with Section 3 of Code Case OMN-9 must be determined.

Qualitv/Safety Impact Due to impracticality 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 (+/- 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.

Duration of Proposed Alternative Third 10 year interval.

Precedents This relief request was granted for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159), Relief Request No. RP04.

IST Program Plan Coumi Generating St Page 50 of 181 3rd 10-Year Interval Coiumula Gt atlon Revision 0 Relief Request -- RP04 (Contd.)

SAMPLE DATA SHEET - Group A Test RHR-P-2A ACCEPTANCE CRITERIA 0

cn

_4 w

231_

128-127, _--

-=

=

227-125-

_==ACT1 N RA GE=

124=

1292 118-212 1156'.

122 111 105.

==

208.--

t3

=

==

~ALE iRT===

202-101 ACIN EA GE 100--

99==

97:-

96-

95 rrr rn-1. iri-r ll7T 1ml! Trr-rn-r-r r111 r m11 rr

..! liT

!l-I1 llT 1TVT llT 7490 75W 7520 7520 7530 7540 7550 7560 7570 7s80 7590 7600 761D 7620 7630 714 70 INDICATED FLOW - GPM ALERT RANGE - Area Inside 34-5-6 ACIMON RANGE - Area Outside 1.2-34

lST Program Plan Columbia GenStationPage 51 of 181 3rd 10-Year Interval Colmba enerating SainRevision 0

Relief Request -- RP04 (Contd.)

SAMPLE DATA SHEET - Group B Test RCIC-P-1 ACCEPTANCE CRITERIA zn CLO

('4 13 2 5_

1315-_

1295-12&3-1245-1245-1225-_

1215-1195-1175-~

2155-E__EREN___

____CURVE_

c 3

4410 4430 4450 4470 4490 4510 4530 4550 4570 4590 PUMP/TURBINE SPEED (RPM'S)

ACMION RANGE - Area Outside 1.2-3-4

IST Program Plan Columbia GeeaigStation Page 52 of 181 3rd 10-Year Interval Generating Revision 0 Relief Request - RP05 Proposed Alternative in Accordance with 10CFR 50.55a(a)(3)(i)

Alternative Provides Acceptable Level of Quality and Safety ASME Code Components Affected Pump Code Class Pump Group P&ID Dwg.

System(s)

~~~Number RHR-P-2A 2

A M521, SH 1 RHR-P-2B 2

A M521, SH 2 Residual Heat Removal RHR-P-2C 2

A M521, SH 3 HPCS-P-1 2

B M520 High Pressure Core Spray

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

ISTB-3510(b)(1) Range. The full-scale range of each analog instrument shall be not greater than three times the reference value. Residual Heat Removal (RHR) and High Pressure Core Spray (HPCS) Pumps discharge pressure instruments (RHR-PT-37A, RHR-PT-37B, RHR-PT-37C, and HPCS-PT4), exceed or may exceed (dependent upon measured parameters), the Code allowable range limit of three times the reference value.

Relief is required for Group A, Group B and preservice test only. Temporary test gauges meeting the Code requirements shall be used for comprehensive test.

Reason for Request

Installed test gauges used to measure the pump discharge pressure, which is used to determine differential pressure, do not meet the Code range requirements.

Proposed Alternative and Basis for Use During Group A or Group B pump inservice testing, pump discharge pressure which is used to determine differential pressure shall be measured by respective Transient Data Acquisition Data (TDAS) points listed below for each pump. TDAS data averages 100 readings taken at an interval of each second.

1.

ISTB-3510(a) and ISTB-3510(b)(1) 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.

IST Program Plan Columbia GeeaigSainPage 53 of 181 3rd 10-Year Interval Generating Station Revision 0 Relief Request -- RP05 (Contd.)

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 Value Loop Equivalent Code Pump Parameter I.D.

(PSIG)

Accuracy Accuracy RHR-P-2A Discharge RHR-PT-37A 0-600 136 1%,

[6/(3xl36)]xlOO Pressure TDAS PT 155 060 16

+/-6 psig

=1.47%

RHR-P-2B Discharge RHR-PT-37B 0-600 132

-l1%,

6/(3x132)]xlOO Pressure TDAS PT 076 060 12

+/-6 psig

=1.52%

RHR-P-2C Discharge RHR-PT-37C 0-600 143 i

6 61(3x143)]xlOO HR-P-C Pressure TDAS PT 091 000 1430 6 psig

=1.40%

HPSP1 Discharge H{PCS-PT-4

+/- 10 40

[l1/(3x430)IxlOO HPSP1 Pressure TDAS PT 107 0-50 40

+/-15 psig

=1.16%

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

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.

The range of the pressure transmitters (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 flow, 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 PT were to fail, a like replacement would have to be used due to the above identified reasons of replacing a PT with one not suited for all 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 required by the Code for evaluating pump condition and detecting degradation.

4.

NUREG 1482, Revision 1, Section 5.5.1 states that when the range of a permanently installed analog instrument is greater than three times the reference value, but the accuracy of the instrument is more conservative than that required by the Code, the staff may grant relief when the combination of the range and accuracy yields a reading that is at least equivalent to that achieved using instruments that meet the Code requirements (i.e. up to +/-6 percent for Group A and B tests, and

+ /-.5 percent for pressure and differential pressure instruments for Preservice and Comprehensive tests).

3ST Program Plan Columbia Generating Station Page 54 of 181 3rd 10-Year Interval GeeaigRevision 0

Relief Request -- RP05 (Contd.)

Qualitv/Safetv Impact TDAS data will consistently provide acceptable accuracy to ensure that the pumps are performing at the flow and pressure conditions to fulfill their design function. TDAS data is sufficiently accurate for evaluating pump condition and in detecting pump degradation. The effect of granting this relief request will have no adverse impact on Plant and public safety. Test quality will be enhanced by getting slightly better, more repeatable data.

Duration of Proposed Alternative Third 10 year interval.

Precedents This relief request was granted for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159) and Supplement to SER letter dated March 25, 1999 (TAC No. MA3813), Relief Request No. RP05.

IST Program Plan Page 55 of 181 3rd 10-Year Interval Columbia Generatig Station Revision 0 Relief Request -- RP06 Proposed Alternative in Accordance with 10CFR 50.55a(a)(3)(ii)

-- Hardship or Unusual Difficulty without Compensating Increase in Level of Quality or Safety -

ASME Code Components Affected Pump Code Class Pump Group P&ID Dwg. No.

System(s)

SLC-P-1A 2

B M522 Standby Liquid SLC-P-1B 2

B M522 Control

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code Applicable Code Reguirement Subsection ISTB-3550. Flow rate shall be measured using a rate or quantity meter installed in the pump test circuit.

Subsection ISTB-5200 (a). For the Group A test and the comprehensive test, after pump conditions are as stable as the system permits, each pump shall be run at least 2 minutes. At the end of this time at least one measurement or determination of each of the quantities required by Table ISTB-3000-1 shall be made and recorded.

Relief is required for Group A, Group B and comprehensive and preservice tests.

Reason for Request

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

As a result of a rate or quantity meter not being installed in the test circuit, it is impractical to directly measure the flow rate for the Standby Liquid Control pumps. Therefore, the requirement for allowing a 2 minute "hold" time for Pump tests is an unnecessary burden which would provide no additional assurance of determining pump operational readiness. -

3ST Program Plan Columbia Generating Station Page 56 of 181 3rd 10-Year Interval

~

ouuaoalnRevision 0

Relief Request -- RP06 (Contd.)

Proposed Alternative and Basis for Use NUREG 1482, Rev 1, Section 5.5.2 states, 'requiring licensees to install a flow meter to measure the flow rate and to guarantee the test tank size, such that the pump flow rate will stabilize in 2 minutes before recording the data would be a burden because of the design and installation changes to be made to the existing system. Therefore, compliance with the Code requirements would be a hardship".

Pump flow rate will be determined by measuring the volume of fluid pumped and dividing corresponding pump run time. The volume of fluid pumped will be determined by the difference in fluid level in the test tank at the beginning and end of the pump run (test tank-fluid level corresponds to volume of fluid in the tank). The pump flow rate calculation methodology meets the accuracy requirements of OM Code, Table ISTB-3500-1. The pump flow rate calculation is identified on the record of test and ensures that the method for the flow rate calculation yields an acceptable means for the detection and monitoring of potential degradation of the Standby Liquid Control Pumps and therefore, satisfies the intent of the OM Code Subsection ISTB.

In this type of testing, the requirement to maintain a 2 minute hold time after stabilization of the system is unnecessary and provides no additional increase of the ability of determining pump condition.

K>

Oualitv/Safetv Impact The test tank is a horizontal flat bottomed rectangular tank. The tank fluid volume is approximately 216 gallons. The average calculated flow rate is 42.2 gpm. The accuracy of the level reading is +/- 1/8 inch.

The accuracy of volume change is +/- 1/4 inch (1/8 inch at initial level and 1/8 inch at final level). 1/4 inch corresponds to 1.23 gallons in the range of the test tank level used during the performance of the pump surveillance test. The pump is required to be run for a minimum time to ensure that an 18 inch change of test tank level has occurred. This is to ensure that the Code required accuracy for flow rate measurement of +/-2 percent is satisfied. The test methodology used to calculate pump flow rate will provide results consistent with Code requirements. This will provide adequate assurance of acceptable pump performance.

Calculation methods are specified in the surveillance procedures for the Standby Liquid Control Pumps, and meet the quality assurance requirements for the Columbia Generating Station.

Duration of Proposed Alternative Third 10 year interval.

Precedents A similar relief request RP02, was granted for the Diesel Fuel Oil Transfer pumps for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159) and Supplement to SER letter dated March 25, 1999 (TAC No. MA3813), Relief Request No. RP-02.

IST Program Plan Columbia Generating Station Page 57 of 181 3rd 10-Year Interval Columbia Relief Request -- RP07 Proposed Alternative in Accordance with 10CFR 50.55a(a)(3)(i)

--Alternative Provides Acceptable Level of Quality and Safety-ASMIE Code Components Affected All digital (as applicable) Instrumentation used for pumps in the IST Program.

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

Subsection ISTB-3510(b)(2) Range. Digital Instruments shall be selected such that the reference value does not exceed 70% of the calibrated range of the instrument.

Reason for Request

The ASME OMN-6 Code Case provides alternative range requirements to those specified in ISTB-3510(b)(2). However, the applicability of the OMN-6 Code Case is stated to be "ASME OM Code-1990 Edition through ASME OM Code-1997 Addenda". The Columbia Generating Station IST Program is being revised to include the OM Code 2001 Edition through the 2003 Addenda.

Proposed Alternative and Basis for Use When digital instruments are used for the measurements of parameters required by ASME OM Code Table ISTB-3000-1, the alternative range requirements of OMN-6 Code Case (the reference value does not exceed 90% of the calibrated range of the instrument) will be met.

In addition, in NUREG-1482, Rev 1 Section 5.5 in part; "The NRC has accepted Code Case OMN-6 as specified in RG 1.192, which allows each digital instrument to be such that the reference values do not exceed 90 percent of the calibrated range of the instrument. "

The primary reason for this relief is to provide approval for the Columbia Generating Station to use the ASME OM Code Case OMN-6 for the third ten year interval IST Program. The IST Program for the third ten year interval will use the 2001 edition through the 2003 addenda of the ASME OM Code.

Quality/Safety Impact The use of the OMN-6 Code, approved by the NRC in RG 1.192, will provide at least equivalent instrumentation accuracy requirements for the required parameters to be measured in the IST Program and will provide results consistent with Code requirements. This will provide adequate assurance of acceptable pump performance.

IST Program Plan Columbia Generating Station Page 58 of 181 3rd 10-Year Interval

'.omLa 7aonRevision 0

Relief Request -- RP07 (Contd.)

Duration of Proposed Alternative Third 10 year interval.

Precedents The ASME OMN-6 Code Case for Alternative Rules for Digital Instruments has been accepted for use in Regulatory Guide 1.192 and discussed as acceptable for use in NUREG 1482 Revision 1, Section 5.5.

IST Program Plan Cou baPage 59 of 181I 3rd 10-Year Interval Columbia Generating Station Revision 0 Relief Request - RP08 Proposed Alternative in Accordance with 10CFR 50.55a(a)(3)(i)

Alternative Provides Acceptable Level of Quality and Safety ASM%1E Code Components Affected Pump Code Class Pump Group P&ID Dwg. No.

System(s)

DO-P-lA 3

B M512, SH 4 Diesel Fuel Oil Transfer DO-P-1B 3

B M512, SH 4 DO-P-2 3

B M512,S4

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

Subsection ISTB-5223 (e), and Table ISTB-5200-1, for Comprehensive Pump Testing acceptance criteria.

All deviations from the reference values shall be compared with the ranges of Table ISTB-5200-1 and corrective action taken as specified in ISTB-6200.

At the Columbia Generating Station the Diesel Fuel Oil Transfer pumps are tested using a "fixed resistance" flow path as permitted per OM Code Subsection ISTB-5223 (c) for comprehensive pump testing. This requires that the flow rate and the differential pressure be measured or determined, and compared to the respective reference values for the pumps.

Table ISTB-5200-1 for the Comprehensive Test for pumps list the "Acceptable Range" as 0.95 to 1.03 times the reference flow rate (Q) or the reference differential pressure (DP) for vertical line shaft centrifugal pumps.

Also, the "Required Action Range High" for the Comprehensive Test is listed as greater than 1.03 times the reference flow and/or differential pressure (as applicable).

Reason for Request

The Diesel Fuel Oil Transfer pumps are Vertical Line Shaft centrifugal pumps installed to transfer diesel fuel oil from the subterranean storage tanks to the diesel's day tanks.

As delineated in relief request RP-02 for the Diesel Fuel Oil Transfer pumps, the flow rate of the pumps will be determined by calculating a flow rate from the Diesel Fuel Oil Storage Tanks to the Diesel Fuel Oil Day Tanks using a change in level of the Diesel Fuel Oil Day Tanks over a period of time.

3ST Program Plan Columbia Generating Station Page 60 of 1 81 3rd 10-Year Interval GeeaigRevision 0

Relief Request -- RPO8 (Contd.)

As a result of the Diesel Fuel Oil Transfer Pumps being designed such that a suction pressure gauge is unable to be installed on the suction side of the Diesel Fuel Oil Transfer pumps, a determination of differential pressure will be made as allowed by ISTB-3520(b), which allows that the differential pressure may be determined by using the pressure at a point in the inlet and the pressure at a point in the discharge pipe.

NUREG 1482, Rev 1, Section 5.5.3, states that when the inlet pressure gauges are not installed in the inlet of a vertical line shaft pump, it is impractical to directly measure inlet pressure for determining differential pressure for the pump. The NRC staff recommends use of tank level to determine the suction pressure of vertical line shaft pumps and a relief request is not required. The recommended method is in accordance with a determination of differential pressure allowed by the Code as stated above.

Suction Pressure is determined by measuring the Diesel Fuel Oil Storage Tank level before the pump is started. Diesel Fuel Oil Storage Tank level changes when the pump is running, so accurate suction pressure indication cannot be determined while the pump is running. The calculational method specified in the surveillance procedure for testing the pumps satisfies the Code required accuracy for Group B and Comprehensive pump testing. This methodology provides the required information for determining and monitoring the hydraulic condition of the pumps without the need to install suction (inlet) pressure gauges which would not be practical to install due to design limitations.

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

As a result of the low reference values for the differential pressure and flow rate of the Diesel Fuel Oil transfer pumps, it is extremely difficult to meet the upper acceptance limit of 3 percent for differential pressure and flow rate, now required by the ASME OM Code acceptance criteria for Comprehensive Pump testing.

Proposed Alternative and Basis for Use It is proposed that the Comprehensive Pump testing for the Diesel Generator Fuel Oil Transfer Pumps listed above be allowed to have an extended upper acceptance criteria limit of +10 percent for differential pressure and flow rate measurements, in lieu of the Code required +3 percent as stated on Table ISTB-5200-1, for Pump Acceptance Criteria for Vertical Line Shaft pumps for the Comprehensive Pump testing.

IST Program Plan Generating Page 61 of 181 3rd 10-Year Interval

.oiUmula Il alOn Revision 0 Relief Request -

RLPO8 (Contd.)

A comparison of recent tests is shown below for the Diesel Fuel Oil Transfer Pumps to illustrate the reason for the relief requested for the flow rate and differential pressure upper acceptable limit.

DO-P-lA Reference pump flow rate for DO-P-lA is 27.57 GPM.

Reference pump differential pressure for DO-P-lA is 14.57 PSID.

Date Tank Level Suct Press Disch Press Diff Press (PSID)

Flow Rate (Inches)

(PSIG)

(GPM) 06/16/05 132.2 0.67 14.00 14.67 27.72 03/31/05 132.4 0.66 14.00 14.66 28.11 12/30/04 132.1 0.67 14.00 14.67 28.07 10/07/04 130.7 0.72 13.75 14.47 28.14 07/15/04 132.3 0.67 13.75 14.42 27.97 04/22/04 132.0 0.68 14.00 14.68 27.97 01/30/04 131.0 0.71 14.00 14.71 28.23 11/07/03 130.8 0.71 13.80 14.51 27.61 DO-P-lB Reference pump flow rate for DO-P-lB is 30.58 GPM.

Reference pump differential pressure for DO-P-lB is 17.47 PSID.

Date Tank Level Suction Press Discharge Press Diff Press (PSID)

Flow Rate (Inches)

(PSIG)

(GPM) 07/04/05 132.4 0.66 17.2 17.86 29.50 04/07/05 130.6 0.72 17.5 18.22 29.66 01/13/05 130.7 0.72 17.5 18.22 29.86 10/21/04 134.6 0.60 17.3 17.9 29.58 07/29/04 131.1 0.70 17.3 18.00 29.58 05/06/04 130.6 0.72 17.5 18.22 29.77 02/13/04 132.2 0.67 17.25 17.92 29.97 11/22/03 130.1 0.73 17.25 17.98 29.58

3ST Program Plan Columbia Generating Station Page 62 of 181 3rd 10-Year Interval G nrt g,al Revision 0 Relief Request -- RPO8 (Contd.)

DO-P-2 Reference pump flow rate for DO-P-2 is 28.22 GPM.

Reference pump differential pressure for DO-P-2 is 10.40 PSID.

Date Tank Level Suction Press Discharge Press Diff Press (PSID)

Flow Rate (Inches)

(PSIG)

(GPM) 06/25/05 133.0 0.65 9.75 10.40 30.75 03/24/05 133.0 0.65 9.80 10.45 29.17 01/05/05 132.7 0.65 10.00 10.65 28.39 10/14/04 133.2 0.64 10.00 10.64 28.43 07/22/04 132.8 0.65 10.00 10.65 28.53 04/28/04 133.1 0.64 10.00 10.64 28.74 02/04/04 134.5 0.60 10.00 10.60 29.00 11/13/03 131.2 0.70 9.90 10.60 28.57 As can be seen the differential pressure for the Diesel Fuel Oil Transfer pumps is a very low value.

Complying with the Code and using an average of the most recent test results for differential pressure of 14.60 PSID (DO-P-lA), 18.04 PSID (DO-P-1B), and 10.58 PSID (DO-P-2), the upper limit of 3 percent of reference value as presently required by the OM Code would result in the pumps being declared inoperable at greater than 15.00 PSID (DO-P-lA), 17.99 PSID (DO-P-1B), and 10.71 PSID (DO-P-2),

respectively. Complying with the Code and using an average of the most recent test results for flow rate of 27.98 GPM (DO-P-lA), 29.69 GPM (DO-P-1B), and 28.95 GPM (DO-P-2), the upper limit of 3 percent of reference value as presently required by the OM Code would result in the pumps being declared inoperable at greater than 28.40 GPM (DO-P-lA), 31.50 GPM (DO-P-1B), and 29.07 GPM (DO-P-2),

respectively. This is a very small acceptance band for these pumps, on the order of "Tenths" and in some cases "hundredths" of psi or gpm. As can be seen the imposition of this requirement would be a burden and would NOT result in any "improved" operational readiness determination.

It must be pointed out, that, although on rare occasions the pump upper limit has been used to identify degradation of specific pump hydraulic parameters, the primary reason for the upper limit is for the determination of either instrumentation drift or inaccuracy and, the determination of an incorrect reference value or test flow path.

As a result of the method of the determination of the differential pressure used at the Columbia Generating Station, it is extremely unlikely that either instrument drift or improper determination of reference values or flow path would be a cause of the upper limit being approached. Also, as these pumps do not "improve" with degradation, it is reasonable to assume that the allowance of an additional 7 percent margin being added to the upper limit would not impair the ability for the Columbia Generating Station to make a determination of degradation of the Diesel Fuel Oil transfer pumps.

IST Program Plan Columbia Generating Station Page 63 of 181 3rd 10-Year Interval oumiaStonRevision 0

Relief Request - RP08 (Contd.)

This method does not result in any potential increase of pump degradation going undetected and provides a reasonable alternative to the Code required upper acceptable limits. Imposition of the upper limit of 3 percent for flow rate and differential pressure in this instance is unnecessary and provides no additional increase of the ability of determining pump condition.

Oualitv/Safetv Impact The added increase to the acceptable range of the pumps as stated above does not lessen the ability of the Columbia Generating Station to detect degradation of the Diesel Fuel Oil Transfer pumps and does not "compromise" the ability of the station to provide reasonable assurance of pump operational readiness. The test methodology used to calculate differential pressure and determine flowrate for the Diesel Fuel Oil transfer pumps will provide results consistent with Code requirements. This will provide adequate assurance of acceptable pump performance.

Duration of Proposed Alternative Third 10 year interval.

Precedents This is a new relief request for the 3rd ten year interval.

IST Program Plan C lb G.

Sta Page 64 of 181 3rd 10-Year Interval oumia eneraing btaiofl Revision 0 5.0 VALVE INSERVICE TESTING PROGRAM 5.1 Introduction ASME OM Code requires periodic testing of certain safety related valves in order to verify their operational readiness and leak tight integrity. The Columbia Generating Station 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 OM Code-2001 and 2002 and 2003 Addenda Subsection ISTC, "Inservice Testing of Valves in Light-Water Reactor Nuclear Power Plants". The Program complies with the specifications of the approved Codes and Regulations. 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 Program Plan establishes tests and test intervals, acceptance criteria, corrective actions, and records requirements. Where conformance with certain Code requirements is impractical, relief requests are included in Section 5.9 with supporting information and proposed alternatives.

5.2 Program Implementation 5.2.1 Exemptions (ISTC-1200)

The following are excluded from this Subsection, provided that the valves are not required to perform a specific function as described in ISTA-1 100:

a.

valves used only for operating convenience such as vent, drain, instrument, and test valves;

b.

valves used only for system control, such as pressure regulating valves; and

c.

valves used only for system or component maintenance.

Skid-mounted valves are excluded from this Subsection, provided they are tested as part of the major component and are justified by the Owner to be adequately tested.

External control and protection systems responsible for sensing plant conditions and providing signals for valve operation are excluded from the requirements of this Subsection.

Category A and Category B safety and relief valves are excluded from the requirements of ISTC-3700, Valve Position Verification and ISTC-3500, Valve Testing Requirements.

Nonreclosing pressure relief devices (rupture disks) used in BWR Scram Accumulators are excluded from the requirements of this Subsection.

IST Program Plan Columbia Ge t

Station Page 65 of 181 3rd 10-Year Interval Coubi enerating SainRevision 0

5.2.2 Valve Categories (ISTC-1300)

Valves within the scope of this Subsection shall be placed in one or more of the following categories. When more than one distinguishing category characteristic is applicable, all requirements of each of the individual categories are applicable, although duplication or repetition of common testing requirements is not necessary.

a.

Category A: valves for which seat leakage is limited to a specific maximum amount in the closed position for fulfillment of their required function(s), as specified in ISTA-1100;

b.

Category B: valves for which seat leakage in the closed position is inconsequential for fulfillment of the required-function(s), as specified in ISTA-I 100;

c.

Category C: valves that are self-actuating in response to some system characteristic, such as pressure (relief valves) or flow direction (check valves) for fulfillment of the required function(s), as specified in ISTA-1I00;

d.

Category D: valves that are actuated by an energy source capable of only one operation, such as rupture disks or explosively actuated valves.

5.2.3 Preservice Testing (ISTC-3100)

Each valve shall be tested during the preservice test period. These tests shall be conducted under conditions as near as practicable to those expected during subsequent inservice testing. Only one preservice test of each valve is required with these exceptions.

a.

Any valve that has undergone maintenance that could affect its performance after the preservice test shall be tested in accordance with ISTC-3310.

b.

Safety and relief valves and nonreclosing pressure relief devices shall meet the preservice requirements of Mandatory Appendix I.

5.2.4 Inservice Testing (ISTC-3200)

Inservice testing shall commence when the valves are required to be operable to fulfill their required function(s). 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 resumed.

The Columbia Generating Station 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 Table ISTC-3500-1.

IST Program Plan G

Page 66 of 181 3rd 10-Year Interval Columbia Generati lg Statlon Revision 0 5.2.5 Reference Values (ISTC-3300)

Reference values are determined from the results of preservice testing or from the results of inservice testing. These tests are performed under conditions as near as practicable to those expected during subsequent inservice testing. Reference values are established only when the valve is known to be operating acceptably. Baseline data for stroke 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.

5.2.6 Valve Testing Requirements (ISTC-3500)

Active and passive valves in the categories defined in ISTC-1300 shall be tested in accordance with the paragraphs specified in Table ISTC-3500-1 and the applicable requirements of ISTC-5100 and ISTC-5200.

TABLE ISTC-3500-1 INSERVICE TEST REQUIREMENTS Category (See Valve Leak-age Test Procedure Exercise Test Special Test Position Indication ISTC-1300 Function

& Frequency Procedure &

Procedure Verification &

Frequency

[Note (1)]

Frequency A

Active See ISTC-3600 See ISTC-3510 None See ISTC-3700 A

Passive See ISTC-3600 None None See ISTC-3700 B

Active None See ISTC-3510 None See ISTC-3700 B

Passive None None None See ISTC-3700 C (Safety and Active None See ISTC-5230, None See ISTC-3700 relief) [Note(3)]

[Notes(2),(3)]

ISTC-5240 C (Check) [Note Active None [Note (3)]

See ISTC-3510 None See ISTC-3700 (4)]

D Active None [Note (3)]

None See ISTC-None 5250,ISTC-5260 NOTES:

(1) Note additional requirements for fail-safe valves, ISTC-3500 (2) Leak test as required for Appendix I (3) When more than one distinguishing category characteristic is applicable, all requirements of each of the individual categories are applicable, although duplication or repetition of common testing requirements is not necessary.

(4) If a check valve used for a pressure relief device is capacity certified, then it shall be classified as a pressure or vacuum relief device. If a check valve used to limit pressure is not capacity certified, then it shall be classified as a check valve.

IST Program Plan Columbia Generating Station Page67of 181 3rd 10-Year Interval

..o m1 a aRevision 0

5.2.7 Exercising Test Frequency (ISTC-3510)

Active Category A, Category B, and Category C check valves shall be exercised nominally every 3 months, except as provided by ISTC-3520, ISTC-3540, ISTC-3550, ISTC-3570, ISTC-5221, and ISTC-5222.

5.2.8 Valve Obturator Movement (ISTC-3530)

The necessary valve obturator movement shall be determined by exercising the valve while observing an appropriate indicator, such as indicating lights that signal the required changes of obturator position, or by observing other evidence, such as changes in system pressure, flow rate, level,.or temperature, that reflects change of obturator position.

5.2.9 Manual Valves (ISTC-3540)

Manual valves shall be full-stroke exercised at least once every 2 years, except where adverse conditions may require the valve to be tested more frequently to ensure operational readiness. Any increased testing frequency shall be specified by the Owner. The valve shall exhibit the required change of obturator position.

Valves equipped with remote position indication shall be tested in accordance with ISTC-3700. A two year test frequency is required by the 10CFR50.55a(b)(3)(vi) modification.

5.2.10 Fail-Safe Valves (ISTC-3560)

Valves with fail-safe actuators shall be tested by observing the operation of the actuator upon loss of valve actuating power in accordance with the exercising frequency of ISTC-3510. Fail-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. MSIVs are close stroke timed to satisfy fail-safe testing with the non-safety related instrument air supply isolated.

5.2.11 Valves in Systems Out of Service (ISTC-3570)

For a valve in a system declared inoperable or not required to be operable, the exercising test schedule need not be followed. Within 3 months before placing the system in an operable status, the valves shall be exercised and the schedule followed in accordance with requirements of this Subsection.

IST Program Plan Columbia Generating Station Page 68 of 181 3rd 10-Year Interval

.ue ra ngRevision 0

5.2.12 Valve Seat Leakage Rate Test (ISTC-3600)

The category A valves identified in this program are seat leakage tested in accordance with the requirements of ISTC-3600. See Technical Position TV02.

5.2.13 Position Verification Testing (ISTC-3700)

Valves with remote position indicators shall be observed locally at least once every 2 years to verify that valve operation is accurately indicated. Where practicable, this local observation should be supplemented by other indications such as use of flowmeters or other suitable instrumentation to verify obturator position. These observations need not be concurrent. Where local observation is not possible, other indications shall be used for verification of valve operation.

5.2.14 Instrumentation (ISTC-3800)

Instrumentation accuracy shall be considered when establishing valve test acceptance criteria.

5.2.15 Specific Testing Requirements (ISTC-5000)

Following subsections provide specific valve testing requirements, acceptance criteria and corrective action for various types of valves in addition to valve testing requirements specified in subsection ISTC-3500.

a.

Motor-Operated Valves (ISTC-5120)

In addition to testing motor-operated valves in accordance with the requirements of ISTC-3500, IOCFR50.55a(b)(3)(ii) requires licensees to establish a program to ensure that motor-operated valves continue to be capable of performing their design basis safety functions. This is accomplished through implementation of the GL-96-05 MOV Periodic Verification Program.

b.

Pneumatically Operated Valves (ISTC-5130)

c.

Hydraulically Operated Valves (ISTC-5140)

d.

Solenoid Operated Valves (ISTC-5150)

e.

Manually Operated Valves (ISTC-5210)

f.

Check Valves (ISTC-5220)

The necessary valve obturator movement during exercise testing shall be demonstrated by performing both an open and a close test.

IST Program Plan Coumi Generating Page 69 of 181 3rd 10-Year Interval

'oiumuia lla lI0 Revision 0 5.2.16 Check Valve Condition Monitoring Program Implementation The purpose of the Check Valve Condition Monitoring Program is to both (a) improve check valve performance and to (b) optimize testing, examination, and preventive maintenance activities in order to maintain the continued acceptable performance of a select group of check valves. Columbia may implement this program on a valve or a group of similar valves.

Examples of candidates for (a) improved valve performance are check valves that:

have an unusually high failure rate during inservice testing or operations cannot be exercised under normal operating conditions or during shutdown exhibit unusual, abnormal, or unexpected behavior during exercising or operation the Owner elects to monitor for improved valve performance Examples of candidates for (b) optimization of testing, examination, and preventive maintenance activities are check valves with documented acceptable performance that:

have had their performance improved under the Condition Monitoring Program cannot be exercised or are not readily exercised during normal operating conditions or during shutdowns can only be disassembled and examined the Owner elects to optimize all the associated activities of the valve or valve group in a consolidated program The program shall be implemented in accordance with Appendix II, Check Valve Condition Monitoring Program, of ASME OMb Code-2003.

NOTE: If the Appendix II condition monitoring program for a valve or valve group is discontinued then the requirements of ISTC-3510, ISTC-3520, ISTC-3550, and ISTC-5221 shall be implemented for the applicable check valves.

5.2.17 Vacuum Breaker Valves (ISTC-5230)

Vacuum breakers shall meet the applicable inservice test requirements of ISTC-5220 and Mandatory Appendix I.

5.2.18 Safety and Relief Valve Tests (ISTC-5240)

Safety and relief valves shall meet the inservice test requirements of Mandatory Appendix I.

3ST Program Plan Columbia Generating Station Page 70 of 181 3rd 10-Year Interval GeeaigRevision 0

5.2.19 Rupture Disks (ISTC-5250)

Rupture disks shall meet the requirements for noreclosing pressure relief devices of Mandatory Appendix I.

5.2.20 Explosively Actuated Valves Explosively actuated valves shall be tested in accordance with the requirements of ISTC-5260.

5.2.21 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 recorded.

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 are established per Code requirements for applicable valve type 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.

5.2.22 Trending Stroke times of power-operated valves are trended.

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.

3ST Program Plan Columbia Generating Station Page71 of 181 3rd 10-Year Interval JeeaigRevision 0

5.3 Valve Test Tables The Valve Test Tables provide a concise description of the station's Valve Program for compliance with valve IST requirements.

The tables include active valves which are required to operate in order to safely shutdown the reactor to the cold shutdown condition, maintain it in the cold shutdown condition, or mitigate the consequences of an accident.

Additionally, passive valves which require leak rate testing or 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 (i.e., 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.

CMP -Check Valves which are included in the Check Valve Condition Monitoring Program are designated as CMP. These valves will be tested and examined as required by the specified Condition Monitoring Plan.

(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 subsection ISTC-1300 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 Columbia Station Page 72 of 181 3rd 10-Year Interval CoubaGenerating SainRevision 0

(4b)

VALVE Tkpe - 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.

(5a)

SAFETY Position - Safety position identifies the position(s) the valve must assume to fulfill its safety function(s).

C Closed NA Not Applicable (i.e., overpressure protection devices, valves included at the Owner's discretion, or valves with no required safety position) 0

=

Open O/C

=

Both Open and Closed (5b)

FAILED Position -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 (5c)

NORMAL Position - Normal position identifies the valve position during normal power operation.

LC

=

Locked Close LO

=

Locked Open NC

=

Normally Closed NO

=

Normally Open NT

=

Normally Throttled

3ST Program Plan Columbia Generating Station Pare 73 of 181 3rd 10-Year Interval GeeaigRevision 0

(6a)

TESTS - This column lists a code corresponding to the test requirements applicable to that valve.

Di Disassembly and Inspection G

ISTC-3700 - Verify the accuracy of remote position indicators.

H ISTC-3510 - Full stroke exercise the valve to its required position to fulfill its function.

Hx Stroke exercise to satisfy bidirectional functionality in accordance with Condition Monitoring Plan.

J ISTC-5121, ISTC-5131, ISTC-5141 and ISTC-5151-- Measure the stroke time of power operated valves.

K ISTC-3560 - 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).

L ISTC-3600 - Valve seat leakage rate test.

Nit Non-intrusive Testing P

ISTC-5240 - Safety and relief valve test per OM Code Mandatory Appendix I requirements.

S OM Code Mandatory Appendix I -- Vacuum Relief Setpoint Test V

ISTC-5260 - Explosively actuated valve test.

W ISTC-5250 -

Rupture discs shall meet the requirements for nonreclosing pressure relief devices of OM Code Mandatory Appendix I.

(6b)

FREQUENCY - This column identifies the required testing frequency.

Legend Meaning CMP Test performed in accordance with Condition Monitoring Plan.

CS Test performed during cold shutdowns but not more 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.

3ST Program Plan Columbia Generating Station Page74oflIl 3rd 10-Year Interval Geeaig3alnRevision 0 EX Test explosive valve per ISTC-5260 schedule.

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

N Not Applicable.

Q Test performed once every 92 days.

RD Test rupture disc per OM Code Mandatory Appendix I schedule.

RF Test performed each refueling outage.

RV Test relief valve per OM Code Mandatory Appendix I schedule.

TS Test performed per Technical Specification or Licensee Controlled Specification.

2Y, 4Y, 6Y etc. Test performed once during specified number of years i.e 2, 4, 6 etc.

12M Test performed annually (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. Passive valves are annotated as passive, all other valves are active. Minor changes to the program via change notices may also be identified in this field.

IST Program Plan Coum i Geeatn Stto Page 75 of 181 3rd 10-Year Interval Cou baG nrtgSalnRevision O

Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPAM Reliefs)

Position)

CAC-FCV-IA M554 2

HO C

L i

TSP-CONT-R801 N13 HIl A

GB FC TV02 2.50 NC Passive DESCRIPTION: CAC FCV FROM PENETRATION X99 (CIV)

CAC-FCV-1B MC54 HO L

i TSP-CONT-R801 N13 H6 A

GB FC TV02 2.50 NC Passive DESCRIPTION: CAC FCV FROM PENETRATION X97 (CIV)

CAC-FCV-2A M554 2

HO C

L i

TSP-CONT-R801 1N13 Gl0o A

GB FC TV02 I2.50 NC P1assive DESCRIPTION: CAC FCV TO PENETRATION X96 (CIV)

CAC-FCV-2B M554 2

HO C

L 1

TSP-CONT-R801 N13 G6 A

GB FC TV02 2.50 NC Passive DESCRIPTION: CAC FCV TO PENETRATION X98 (CIV)

CAC-FCV-3A I[554 l

2 HO C

L i

TSP-CONT-R801 ITN13 lD10 lA GB lFC l

TV02 I

I 2.50 I NC I

llPassive DESCRIPTION: CAC FCV FROM PENETRATION X105 (CIV)

CAC-FCV-3B

[M554 2 1 HO C

IL J

TSP-CONT-R801 I

N13 lD6 1 A

_GB FC I

TV02 II I 2.50 I NC IlIPassive DESCRIPTION: CAC FCV FROM PENETRATION X104 (CIV)

CAC-FCV-4A 1554 2

l HO l

C IL i

TSP-CONT-R801 N13 EIA GB l

FC TV02 l

l 2.50 l

NC l

Passive DESCRIPTION: CAC FCV TO PENETRATION X102 (CIV)

CAC-FCV-4B

[M554 I

2 I

HO I

C IL I

TSP-CONT-R801 N13 lE6 A

GB FC TV02 I

I I 2.50_ I NC I

I

_Passive DESCRIPTION: CAC FCV TO PENETRATION X103 (CIV)

CAC-RV-63A IM554 I

2 ISA I

NA P

RV TSP-RV/IST-R701 ITV03 lE12 IMC I

RV NA I

I I IX2 I NC I

DESCRIPTION: SW TO CAC-EV-IA RV CAC-RV-63B lM554 [ 2 J SA I NA P

RV TSP-RV/IST-R701 1

JTV03 IE4 IC I

VINA III II I

1X I

NC III DESCRIPTION: SW TO CAC-EV-IB RV CAC-RV-65A M54 1 2 SA I

RV TSP-RV/IST-R701 1

iTV03 D4 l

C I RV I

NA I

I I

1.5 X3 I NC III DESCRIPTION: CAC-EV-IA DISCH RV CAC-RV-65B M4 2

SA NA P

RV TSP-RV/IST-R701 ITV03 lD4 I

C l

V l NA lII I

15 3 I NC III DESCRIPTION: CAC-EV-IB DISCH RV CAC-V-2 M554 [ 2 I MO I C IL i

TSP-CONT-R801 I

IN13 lGI0O A IGT IFAI I

TV02 I

1 4

I LC IIIPassive DESCRIPTION: CAC ISO TO PENETRATION X-96 (CIV)

CAC-V4 M554 2 I MO J C IL i

TSP-CONT-R801 IN13 I

DEISII A CGT I

FAI P

I lTV02 I

4 ILC l

Passive DESCRIPTION: CAC ISO TO PENETRATION X-102 (CIV)

3rd 10-Year Interval Columbia Generating Station PgRevisosjOn 0 Valve Test Tables T__e Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ1 Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

CAC-V-6 M554 2

MO C

L i

TSP-CONT-R801 N13 H10 A

GT FAI TV02 4

LC Passive DESCRIPTION. CAC ISO FROM PENETRATION X-99 (CIV)

CAC-V-8 M554 2

1MO C

L 1

TSP-CONT-R801 N13 D1G A

T FAI jT V02 DESCRIPTION: CAC ISO FROM PENETRATION X-105 (CIV)

CAC-V-11 2

MO C

J TSP-CONT-R801 N13 A

GT FA.

TV02 DESCRIPTION: CAC ISO TO PENETRATION X-98 (CIV)

CAC-V-13 M554 2

MO C

L J

TSP-CONT-R801 N13 E7 A

G4T FLAl pTaVs0s2 DESCRIPTION: CAC ISO TO PENETRATION X-103 (CIV)

CAC-V-15 lM554 2

1 MO C

1L J

TSP-CONT-R801 1lNI3 1D7 A

GT FAI ______________

TV0 2

l l

4 l

LC l

Passive DESCRIPTION: CAC ISO FROM PENETRATION X-97 (CIV)

CAC-V-17 1lMSS4 l2 MOl C

L J

TSP-CONT-R801 l

N13 l

l 4

l LC l

Passive DESCRIPTION: CAC ISO FROM PENETRATION X-104 (CIV)

CAS-V-29A M510-2A 3

SA I

C IHL RF OSP-MSIVAIST-R701 1ROJ02 THRU D

~

J8 AC jCK INAII l_

l_

_ 1 0.50 NC l

1 DESCRIPTION: CAS TO MS-V-28A,BC,D (MSIV) OPERATOR CHK CAS-V-730 1M510-2 2 1 MA C

1L J

TSP-CONT-R801 1

TV02 lH12 l

A l

GB NA J l

lPassive DESCRIPTION: AIR LINE ISO FOR TESTING WW-DW VACUUM BRKRS (CIV)

CAS-VX-82E lM510-2 l

2 1 MA C

lL i

TSP-CONT-R801 1

TV2 lH12 A

GB NA Passive I

L C DESCRIPTION: AIR LINE ISO FOR TESTING WW-DW VACUUM BRKRS (CIV)

CEP-V-IA lM543-3 l

2 l

AO C

IG 2Y OSP-CONT/IST-Q701 1

TV01,2 lH8 l_A l_BF FC HJK Q

OSP-CONT/IST-Q701 l

l 30 NC lL 2Y TSP-CONT-R801 DESCRIPTION: DRYWELL EXHAUST (CIV)

CEP-V-IB lM543-3 l

2 1

AO C

1G 2Y OSP-CONT/IST-Q701 lTV01,2 lH8 l_A __GB FC HK Q

OSP-CONT/IST-Q701 2

l l_2_l NC IL 2Y TSP-CONT-R801 DESCRIPTION: CEP-V-IA BASS (CIV)

CEP-V-2A lM543-3 2

AO l

C 1G 2Y OSP-CONT/IST-Q701 lTV01,2 lH7 A

BF FC H1K Q

OSP-CONT/IST-Q701 l

l 30 NC lL 2Y TSP-CONT-R801 DESCRIPTION: DRYWELL EXHAUST (CIV)

CEP-V-2B NM543-3 2

AO C

IG 2Y OSP-CONTIIST-Q701 lTV01,2 lH7 l_A GB FC JlK Q

OSP-CONT/IST-Q701 l

l 2

NC IL 2Y TSP-CONT-R801 DESCRIPTION: CEP-V-2A BYPASS (CIV)

3rd 10-Year Interval C lm iGe rangS tonRevisionO0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPAN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

CEP-V-3A M543-3 2

AO C

G 2Y OSP-CONTflST-Q701 TVO.2 G9 A

BF FC RIK Q

OSP-CONT/IST-Q701 24 NC L

2Y TSP-CONT-R801 DESCRIPTION: SUPPRESSION CHAMBER EXHAUST (CIV)

CEP-V-3B M543-3 2

AO C

G 2Y OSP-CONT/IST-Q701 TVO1,2 G9 A lGB FC HJK Q

OSP-CONT/IST-Q701 T 2 NC L

2Y TSP-CONT-R801 DESCRIPTION: CEP-V-3A BYPASS (C_

CEP-V-4A M543-3 2

AO C

G 2Y OSP-CONT/IST-Q701 TV01,2 E9 A

BF FC lHJK Q

OSP-CONT/IST-Q701 24 I

NC L

2Y TSP-CONT-R801 DESCRIPTION: SUPPRESSION CHAMBER EXHAUST (CIV)

CEP-V-4B 1M543-3 2

AO C

G 2Y OSP-CONT/IST-Q701 TV01,2 E9 A

GB FC HJK Q

OSP-CONTRIST-Q701 2

NC L

2Y TSP-CONT-R801 DESCRIPTION: CEP-V-4A BYPASS (CIV)

CIA-RV-5A M556-1 3

SA NA P

RV TSP-RV/IST-R701 ITV03 H11 C

RV NA I

.75X I I NC II

_ I DESCRIPTION: CIA TRAIN 'A' NITROGEN HEADER RV CIA-RV-5B lM556-1 3

SA NA P

RV TSP-RV/IST-R701 TVO3 DID1 ICI RV INA III I

I I 75XI I NC III DESCRIPTION: CIA TRAIN 'B' NITROGEN HEADER RV CIA-SPV-1A lM556-1 3 t SO 0

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I 0.50 I NC III DESCRIPTION: CIA NITROGEN BOTTLE AUTO ISO CIA-SPV-1B M556-1 l

3 SO lHJK CS OSP-CIAIIST-Q702 ]ROJI5 lN03 THRU 19B lB12 IB ISV IFO I

TVOI II I 0.500 I NC I

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0.75 I

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CIA-V-21 M556-1 2

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CIA-V-24A M556-1 2

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I I

I I 0.50 I NC III DESCRIPTION: CIA TO MS-V-22A (MSIV) OPERATOR CHK CIA-V-24C IM556-1I 2

SA I

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I I 0.50 I NC III DESCRIPTION: CIA TO MS-V-22B (MSIV) OPERATOR CHK CIA-V-24C IM556-1 I 2 ISA IC IHL RF OSP-MSIV/IST-R70I IROJ02 I

JI K5 I AC ICK INAIII I

I 0.50 I NC III DESCRIPTION: CIA TO MS-V-22C (MSIV) OPERATOR CHK

3rd 10 Year Interval C lm iGe rangS tonRevision 0

_Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

CIA-V-24D M556-l 2

SA C

HL RF OSP-MSIV/IST-R701 ROJO2 K4 AC CK NA 0.50 NC DESCRIPTION: CIA TO MS -V-22D (MSIV) OPERATOR CHK CIA-V-30A M556-1 2

MO 0/C G

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GB FAI HI CS OSP-CIAtIST-Q701 0.50 NO L

J TSP-CONT-R801 DESCRIPTION: CIA SUPPLY TO 3 ADS ACCUMULATORS ISO (CIV)

CIA-V-30B M556-1 2

MO I/C lG 2Y OSP-CIA/IST-Q701 CSJO3 TV0I,2 F9 A

GB FAI IlJ CS OSP-CIAfIST-Q701-0.50 NO L

J TSP-CONT-R801 DESCRIPTION:_CIA SUPPLY TO 4 ADS ACCUMULATORS ISO (CIV)

CIA-V-31A M556-1 2

SA O/C Hx 8Y OSP-CIA/IST-R701 R0102 TV02 G7 AC CK NA HXL TSP-CONT-R801 CMP-01 0.50 NO I

DESCRIPTION: CIA SUPPLY TO 3 ADS ACCUMULATORS CHK (INBD CIV)

CIA-V-31B M556-1 2

SA O/C lHX 8Y OSP-CIA/IST-R701 R0302 lTV02 F7 I AC CK NA HxL i

TSP-CONT-R801 I

CMP-01 I

0.50 NO I

I I

DESCRIPTION: CIA SUPPLY TO 4 ADS ACCUMULATORS CHK (INBD CIV)

CIA-V-39A M556-1 1 3 AO l

C lG 2Y OSP-CIA/IST-Q702 CSJ04 iTV01 10 B

BA F

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AO C

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I I 0.50 I NO III DESCRIPTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER ISO CIA-V-40M M556-1 2

SA O/C JHL RF OSP-CIAfIST-R701 lROJ02 1

(TYP 7) lB5 1 AC CK NA I

_ I

_ I 0.50 I NO I

I DESCRIPTION: CIA TO ADS ACCUMULATOR CHK CIA-V-41A iM556-1 1 3 1 SA I C 1HX 4Y OSP-CIA/IST-Q702 CSJW J10 C

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I I 0.50 NO I

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I DESCRIPTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER CHK CIA-V-41B IM556-l 3

SA C

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I I 0.50s I NO I

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SA 0

HX 8Y OSP-CRA/IST-Q702 ROJ5 66A lG12 IC ICK INA III CMP-02 I

I I0.50 I NC I

I_

I DESCRIPTION: CIA NITROGEN BOTTLE DISCH CHK CIA-V-52B THRU iM556-1 l

3 SA 0

JHX 8Y OSP-CIA/IST-Q702 iROJ15 70B lC2 IC ICK INA III CMP-02 I

I I0.50 INCIII CIA-V-103A lM556-1 3

SA l0 Hx 8Y OSP-CIA/IST-Q702 lROJIS 1

lH13 IC ICK INAIII CMP-02 I

I 1 0.50 I NC I

I I

DESCRIPTION: CIA NITROGEN BOTTLE DISCH CHK

3rd 10-Year Interval C lm iGe rangS tonRevisionO0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

CIA-V-103B M556-1 3

SA 0

HX 8Y OSP-CIA/IST-Q702 ROJI5 D12 C

CK NA CMP-02 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH CHK CIA-V-104A M556-1 3

MA I

0 H

2Y OSP-CIA/IST-Q702 H13 B

GB NA 10.50 INC DESCRIPTION: CIA NITROGEN BOTTLE DISCH MAN ISO CIA-V-I04B M556-1 3

MA 0

H 2Y OSP-CIA/IST-Q702 D12 B

GB NA 10.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH MAN ISO CRD-V-10 M528-1 2

AO GC G

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}K6 B

GB FC HIK Q

OSP-CRD/IST-Q701 1

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1 AO C

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OSP-CRD/IST-Q701 I

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DESCRIPTION: HCU CONT-ROD WITHDRAWAL WATER SCRAM VLV CRD-V-138 M528-1I D

SA C

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1 AO C

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OSP-CRD/IST-Q701 I

I I

NO I

I I

DESCRIPTION: SCRAM DISCH VOLUME VENT CRD-V-181 1M528-1 2

AO C

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DESCRIPTION: SCRAM DISCH VOLUME DRN CSP-RV-51 lM619-161 2

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DESCRIPTION: BACKUP CONTROL AIR SUPPLY HEADER TO CSP-V-5.6.9 RV

IST Program Plan Coum i Geeatn Stto Page 80 of 181 3rd 10-Year Interval Cou baG nrtgSalnRevisionO0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

CSP-RV-52 M619-161 2

SA NA P

RV TSP-RV/IST-R701 TV03 C

RV NA

.75 X I NC DESCRIPTION: CSP-TK-51 RV (CONTROL AIR TO CSP-V-5,6,9)

CSP-V-1 M543-3 2

AO C

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2Y TSP-CONT-R801 DESCRIPTION: CSP TO CONTAINMENT ISO (CIV)

CSP-V-2 M543-3 2

AO C

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CSP-V-3 M543-3 2

AO C

G 2Y OSP-CONT/IST-Q701 TVO0,2 F3 A

BF FC HIK Q

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CSP-V-4 1

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BF FC lHIK Q

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CSP-V-5 M543-3 l

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CSP-V-6 M543-3 l

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24 NC L

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CSP-V-7 lM543-3 2

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24 NC L

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lHX 8Y OSP-CSPST-R701 ROJ9 II C I K I NA III CMP-03 I

j I

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I I

DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9

3rd 10 Year Interval Columbia Generating Station Raevision 08 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

CSP-V-71 M619-161 2

SA 0

HX 8Y OSP-CSP[IST-R701 ROJO9 C

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NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHIK TO CIVs (CSP-V-5,6,9 CSP-V-72 M619-161 2

SA 0

HX 8Y OSP-CSP/IST-R701 ROJ09 C

CK NA CMP-03 j

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DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-73 M619-161 2

SA r

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SA 0

Hx 8Y OSP-CSPIIST-R701 ROJO9 C

CK NA CMP-03 I

NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-75 M619-161 2

SA 0

HX 8Y OSP-CSPR0ST-R70I iROI09 C ICK INA III CMP-03 C

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SA I

0 lHx 8Y OSP-CSP/IST-R701 lROJO9 II C I CK I NA III CMP-03 I

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DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-77 1M619-161 2

SA O

IHx 8Y OSP-CSP/IST-R701 iROJ09 I

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SA 0

1 HX 8Y OSP-CSP/IST-R701 lROJ09 I

IC ICK INA III CMP-03 I

C I I

NC I I I

DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9 CSP-V-79 lM619-161 2 T SA 0

Hx 8Y OSP-CSP/IST-R701 lROJ09 1

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OSP-CONT/IST-Q701 TV01,2 B5 A

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TSP-CONT-R801 I

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CSP-V-96 M543-3 2

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I_____IL i

TSP-CONT-R801 I

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CSP-V-97 M543-3 2

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TSP-CONT-R801 II DESCRIPTION: CONTAINMENT N2 SUPPLY (CIV)

CSP-V-98 lM543-3 2

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I L

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ISTProra Plaear ntr Columbia Generating Station Page 82 osf l8o1 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

CVB-V-IAB M543-1 2

AO,SA O/C GS 2Y MSP-CVB/IST-B101 RVOI N02 B13 AC CK NA H

Q OSP-CVB/IST-M701 TV04 24 NC L

2Y TSP-CONT-B801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-ICD M543-l 2

AO,SA O/C GS 2Y MSP-CVB/IST-B1101 RVOI N02 B12 AC CK NA H

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AO,SA O/C GS 2Y MSP-CVB/IST-BIOI RVOI N02 BlI AC CK NA H

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[

24 NC L

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l 24 l

NC IL 2Y TSP-CONT-B801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-1LM M543-1 2 [ AO,SA OIC GS 2Y MSP-CVB/IST-B101 lRV01 N02 B9 AC CK NA H

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24 NC L

2Y TSP-CONT-B801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-Y-INP lM543-1.

2 f AO,SA OIC lGS 2Y MSP-CVB/IST-BIO1

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TV04 l

24 NC lL 2Y TSP-CONT-B3801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-IQR M543-1 1

2 f AO,SA l O/C lGS 2Y MSP-CVB/IST-B101 lRV01 N02 B7 AC CK NA IH Q

OSP-CVB/IST-M701 I

TV04 l

l 24 NC lL 2Y TSP-CONT-B801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-IST M543-1 2

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TV04 J

24 NC lL 2Y TSP-CONT-B801 DESCRIPTION: VACUUM RELIEF TO DRYWELL DO-V-IA MS12-4 3

[

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DESCRIPTION: DO-P-RANSFER PUMP) TO day TANK DISCH CHK DO-V-lB M512-4 3

l SA J 0 1H Q

OSP-DOAIST-Q702 lH11 C

lCRK NA l

l l1.50 NC l

DESCRIPTION: DO-P-I RANSFER PUMP) TO day TANK DISCH CHK DO-V-10 M512-4 3

SA Q

OSP-DO/IST-Q703 lDI C

lCK lNA l

1.50 NC I

DESCRIPTION: DO-P-2 (RANSFER PUMP) DISCH CHK DSA-SPV-M512-2 D

SO 0/C lH N

TSP-DSA-B701 I

N06 SAI/2 lFI0 B

3W FAI l

l 2_ _

NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV

IST Program Plan Columbia Generating Station Pae 83 of 18 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwvg &

Class Valve

Failed, (CSJ/ROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

DSA-SPV-M512-2 D

SO O/C H

N TSP-DSA-B701 N06 5AI/4 El0 B

3W FAT 2

NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV_

DSA-SPV-M512-2 D

SO 0/C H

N TSP-DSA-B701 N06 5A2/2 F6 B

3W FAT DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV-M512-2 D

SO O/C IH N

TSP-DSA-B701 N06 5A2/4 E6 B

3W FAT DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV-M512-3 D

SO O/C H

N TSP-DSA-B702 N06 5B1/2 F10 B

W FAI DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV-1M512-3 D

SO [ O/C IT N

TSP-DSA-B702 N06 5131/4 1E10 B

3W FAT

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TSP-DSA-B702 N06 5B2/2 1

1 B

32V FAN 1~~2 IN C DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV-lM512-3 D

SO l

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TSP-DSA-B702 N06 5B2/4 B

3W FAI I 1

1 2 (N C DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV-lM512-1 D

SO 0

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TSP-DSA-B703 N06 5C1/1 IF9 IB I3W IFAI DESCRIPTION: DSA TO EDG START MOTORS ISO DSA-SPV-M512-1 D

SO 0

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TSP-DSA-B703 IN06 5C/ 11 I 1.50 I NC II DESCRIPTION: DSA TO EDG START MOTORS ISO DW-V-156 IM517 2

MA [ C L

i TSP-CONT-R801 ITV02 I

I 2 I LC IllaS~

DESCRIPTION: DEMIN WATER TO CONTAINMENT ISO (OTBD CIV)

DW-V-157 1M517 2

MA C

lL TSP-CONT-R801 ITV02 lG8 1A IGT INA I Passive DESCRIPTION: DEMIN WATER TO CONTAINMENT ISO (INBD CIV)

EDR-V-19

[M537 2

AO C

lG 2Y OSP-EDR/IST-Q701 I

iTV01,2 D9 A

GT FC lHJK Q

OSP-EDRIIST-Q701 I

I I

I 3

I NO lL i

TSP-CONT-R801 I

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EDR-V-20 fM537 2

AO l

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TSP-CONT-R801 DESCRIPTION: EDR ISO FROM DRYWELL SUMP (CIV)

IST Program Plan Columbia Generating Station Paevisiof ISO Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

EDR-V-394 M537 3

AO C

G 2Y OSP-EDRIIST-Q702 TVOI C15 B

GT FC HJK Q

OSP-EDRIIST-Q702 3

N O DESCRIPTION: EDR INBD SECONDARY CTMT ISO EDR-V-395 M537 3

AO C

jG 2Y OSP-EDRIIST-Q702 TVo0 C15 B

GT FC IUK Q

OSP-EDRIIST-Q702 DESCRIPTION: EDR INBD SECONDARY CTMT ISO FDR-V-3 M539 2

AO l

C G

2Y OSP-FDR/IST-Q701 TV01,2 D6 A

BF FC HJK Q

OSP-FDRIIST-Q701 3 1 NO L

i TSP-CONT-R801 DESCRIPTION: FDR ISO FROM DRYWELL FDR-SUMP-3 (CIV)

FDR-V-4 M539 2

AO C

iG 2Y OSP-FDRIIST-Q701 TV01,2 D6 A

BF FC lHJK Q

OSP-FDR/IST-Q701 3

NO lL I

TSP-CONT-R801 DESCRIPTION: FDR ISO FROM DRYWELL FDR-SUMP-3 (CIV)

FDR-V-219 M539 3

AO i

C lG 2Y OSP-FDRIIST-Q702 l

ITVO D14 B

GT FC HJK Q

OSP-FDR/IST-Q702 3

l_NO l

DESCRIPTION: FDR INBD SECONDARY CTMT ISO FDR-V-220 M539 3

AO C

lG 2Y OSP-FDR/IST-Q702 l

lTVOI DlS B

GT FC lHJK Q

OSP-FDR/IST-Q702 3

NO l

DESCRIPTION: FDR INBD SECONDARY CTMT ISO FDR-V-221 M539 3

3 I

C IG 2Y OSP-FDRIIST-Q702 TVOI lD14 l

B GT FC JIUK Q

OSP-FDR/IST-Q702 l

l 3

l NO l

DESCRIPTION: FDR INBD SECONDARY CTMT ISO FDR-V-222 M539 3

l AO I

C lG 2Y OSP-FDR/IST-Q702 l

lTVOI D15 B

l GT j FC lHJK Q

OSP-FDR/IST-Q702 l

3 lNO DESCRIPTION: FDR INBD SECONDARY CTMT ISO FPC-FCV-1 M4526-1 3

l AO l

G 2Y OSP-FPC/IST-Q701 lV01 B8 B

GB FO lHJ Q

OSP-FPCIIST-Q701 l___

4X6 lNC l

DESCRIPTION: FPC DEMINERALIZER BYPASS FCV FPC-RV-117A M526-1 3

SA NA lP RV TSP-RV/IST-R701 l

lTV03 D10 lC RV NA l0.75 lNCl DESCRIPTION: FPC-HX-IA RV FPC-RV-117B M526-1 3

SA NA lP RV TSP-RV/IST-R701 TV03 CHI C

RV NA 0.75 NC l

DESCRIPTION: FPC-HX-1B RV FPC-V-112A lM526-1 3

SA O/C 1H Q

OSP-FPCIIST-Q701 E12 C

l_CK

_NA l

l 6

l NC l

DESCRIPTION: FPC-P-IA DISCH CHK FPC-V-112B M526-1 3

SA O/C lH Q

OSP-FPC/IST-Q701 lC12 IC l

CK J NA S

D l

B6 DINC C DESCRIPTION: FPC-P-1B3 DISCH CHK

ISTd Program Plntra Columbia Generating Station Page 8e5 osfo 181 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

FPC-V-127 M526-1 3

SA O/C HX 4Y OSP-FPCIIST-Q701 E6 C

Cl NA Nit 4Y CMP-19 2

NC DESCRIPTION: SW TO FPC CHK FPC-V-140 M526-1 3

SA C

Hx 4Y OSP-FPC/IST-Q701 C6 C

CK NA Di loY CMP-20 8

NO DESCRIPTION: FPC DEMIN EFF CHKR FPC-V-146A M526-1 3

SA 0

Hx 4Y OSP-FPCIIST-Q701 J10 C

CK NA Di 10Y CMP-20 8 j NO DESCRIPTION: FPC TO FUEL POOL CHK FPC-V-146B M526-1 3

SA 0

Hx 4Y OSP-FPC/IST-Q701 J10 C

CK NA Di loY CMP-20 8

NO DESCRIPTION: FPC TO FUEL POOL CHK FPC-V-149 M526-1 2

MO J C 2Y OSP-FPCIIST-Q701 l

lTVOI 2 C7 A

GT lF~AI HJ Q

OSP-FPC/IST-Q701 6

NC TSP-CONT-R801 DESCRIPTION: FPC TO SUPPRESSION POOL ISO (CIV)

FPC-V-153 M526-1 2

MO l

C lG 2Y OSP-FPCIIST-Q701 l

lTVOI,2 All

_ A __

GT l FAI HJI Q OSP-FPC/IST-Q701 j

l 6

lNC lL 2Y TSP-CONT-B802 I

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

FPC-V-154 M526-1 2 [ MO l

C G

2Y OSP-FPC/IST-Q701 lTV01 AI0 JA GT FAI HJI Q OSP-FPC/IST-Q701 l

6 NC lL 2Y TSP-CONT-B802 I

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

FPC-V-I56 TM526-1 2

[ MO l

C lG 2Y OSP-FPCIIST-Q701 l

lTVO1,2 BIO l

A GT FAI HJI Q OSP-FPC/IST-Q701 I _

1 6

NC l L J

TSP-CON'T-R801 DESCRIPTION: FPC TO SUPPRESSION POOL ISO (CIV)

FPC-V-157A M526-1 3 [ SA 0

lHx CMP OSP-FPC/IST-Q701 N04 110 C

CK l

NA Di CMP CMP-14 1

0.5 1 NC l

DESCRIPTION: FPC TO FUEL POOL VACUUM BKR CHK FPC-V-157B M526-1 3 [ SA l

0 Hx CMP OSP-FPCIIST-Q701 N04 J10 C

CK NA Di CMP tNO CMP-14 l

l 0.5 l

NC l

l l

DESCRIPTION: FPC TO FUEL POOL VACUUM BKR CHK FPC-V-172 M526-1 3

l MO l

C lG 2Y OSP-FPC/IST-Q701 TVO1 B5 B

GT FAI HI Q

OSP-FPC/IST-Q701 I 1

l

_ 1 8 18 NO l

l l

DESCRIPTION: FPC TO SUPPRESSION POOL ISO FPC-V-173 M526-1 3

MO C

1G 2Y OSP-FPCIIST-Q701 TVO1 lBS lB lGT lFAI lHI Q

OSP-FPC/IST-Q701 8

NO l

l l

DESCRIPTION: FPC INFLUENT TO DEMIN ISO FPC-V-175 M526-1 T

3 MO 0

G 2Y OSP-FPC/IST-Q701 lTVO1 lC9 B

lG FAI lHI Q

OSP-FPCIIST-Q701 l

_l 8 L NC BYPAS DESCRIPTION: FPC FLTR DEMIN BYPASS

IST Program Plan Coum i Geeatn Stto Page 86 of 1811 l3rd 10-Year Interval Cou baG nrt gSalnRevision ol Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

FPC-V-181A M526-1 3

MO NA G

2Y OSP-FPC/IST-Q701 Passive E14 B

GT FAI S~

~ ~

N O DESCRIPTION: FPC-P-1A SUCT FPC-V-181B M526-1 3

MO NA G

2Y OSP-FPC/IST-Q701 Passive C14 B IGT FAI 1

1 ~

~8 1

NO DESCRIPTION: FPC-P-IB SUCT FPC-V-184 M526-1 3

MO C

G 2Y OSP-FPC/IST-Q701 TV01 C5 B

ST FAI HIJ Q

OSP-FPC/IST-Q701 1 _

_ 1 8 1 N O

_ J _

DESCRIPTION: FPC FILTER DEMIN EFFLUENT ISO HPCS-RV-14 M520 2

SA INA IP RV TSP-RV/IST-R701 TV02,3 C6 AC RV NA L

I TSP-CONT-C801 N09 DESCRIPTION: HPCS-P-3 SUCT RV (CIV)

HPCS-RV-35 M520 2

SA l

NA P

RV TSP-RVflST-R701 TV02,3 C4 AC RV NA I

TSP-CONT-C801 N09

_ I 1.

X 2 I N C DESCRIPTION: HPCS-P-3 DISCH RV(CIV)

HPCS-V-I

[M520 2

1 MO I

OIC lG 2Y OSP-HPCS/IST-Q701 ITV01 IC7 l

B GT FAI III Q

OSP-HPCSfIST-Q701 DESCRIPTION: CST TO HPCS-P-I SUCr HPCS-V-2 (M520 2

SA O/C H

Q OSP-HPCS/IST-Q701 I

I20 INC I

DESCRIPTION: CST TO HPCS-P-1 SUCT CHK HPCS-V-4 rM520 I

MO O/C 1G 2Y OSP-HPCS/IST-Q701 TVO1,2 lG7 lA lGT lFA]

lHI Q

OSP-HPCS/IST-Q701II 112 NC IL 2Y TSP-RCS-R803 I

I DESCRIPTION: HPCS TO RPV ISO (OTBD CIV)

HPCS-V-5 M52 I

SA O/C 1H RF OSP-HPCS/IST-R701 ROJ08 TV02 H8 AC CK I NA HL RF TSP-RCS-R803 I

II

_ I 12 NC I

I I

DESCRIPTION: HPCS TO RPISO (INBD CIV)

HPCS-V-6 M520 2

SA I C

1HX Q

OSP-HPCS!IST-Q701 N01 5C5 ICISC I

NA Hx 12M OSP-HPCS-A701 CMP-21 11 1.50 NO I

I I

DESCRIPTION: HPCS-P-3 ATER LEG) DISCH STOP CHK HPCS-V-7 M520 2

SA C

lHx Q

OSP-HPCS/IST-Q701 I

[N01 CS C

CK NA HX 12M OSP-HPCS-A701 I

I CMP-21 I

I 1.50 I

NO I

I I

DESCRIPTION: HPCS-P-3 VATER LEG) DISCH CHK HPCS-V-10 lM520 12 lMO lC 1G 2Y OSP-HPCS/IST-Q701 l

TV01 E3 B

GB FAI HJ Q

OSP-HPCS/IST-Q701 IPCV NC10 M

B I

I I

DESCRIPTION: HPCS TO CST ISO HPCS-V-1I M520 2

MO C

1G 2Y OSP-HPCSIIST-Q701 l

1TV01 E3 B

GB FAI HJ Q

OSP-HPCS/IST-Q701 I

I I

I I 10 NC I

I I

DESCRIPTION: HPCS TO CST ISO

IST Program Plan Coum i Geeatn Stto Page 87 of 181 3rd 10-Year Interval Cou baG nrt gSalnRevision O

Valve Test Tables

_ype Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

HPCS-V-I2 M520 2

MO O/C G

2Y OSP-HPCS/IST-Q701 TVOI,2 B5 A

GT FAI HJ Q

OSP-HPCS/IST-Q701 4

NC L

i TSP-CONT-R801 DESCRIPTION: HPCS-P-I MINIMUM FLOW VLV (CIV)

HPCS-V-15 M520 2

MO O/C G

2Y OSP-HPCS/IST-Q701 T1Vr01,2 D7 A

GT FAI HJ Q

OSP-HPCS/IST-Q701 18 NC L

2Y TSP-CONT-B802 DESCRIPTION: SUPPRESSION POOL TO HPCS-P-I SUCT (CIV)

HPCS-V-16 M520 2

SA 0

H Q

OSP-HPCS/IST-Q701 D6 C

CK NA 24 NC DESCRIPTION: SUPPRESSION POOL TO HPCS-P-1 SUCT CHK HPCS-V-23 M520 2

MO G

2Y OSP-HPCS/IST-Q701 lVI01,2 E5 A

GB FAI HJ Q

OSP-HPCS/IST-Q701 I

12 NC L

i TSP-CONT-R801 1

1 DESCRIPTION: HPCS TEST LINE TO SUPPRESSION POOL ISO (CIV)

HPCS-V-24 IM520 2

SA O/C H

Q OSP-HPCS/IST-Q701 4

C CK NA l

16 NC DESCRIPTION: HPCS-P-1 DISCH CHK HPCS-V-28 JM5241 T 3

SA 0

Hx Q

OSP-SW/IST-Q703 1

1 IG6 IC ICK lNA lDi 10Y CMP-23 C

8 l

NC l

--DESCRIPTION: HPCS-P-2 (SERVICE WATER) DISCH CHK HPCS-V-65 lM520 2

MA l C

IL I

TSP-CONT-R801 TTV02 gH7 A

GB NA Passive I

LCl DESCRIPTION: AIR TO HPCS-V-5 OPERATOR (INBD CIV)

HPCS-V-68 lM520 A

2 l

MA C

lL J

TSP-CONT-R801 lTV02 H7 A

GB NA l

Passive I

LC DESCRIPTION: AIR TO HPCS-V-5 OPERATOR (OTBD CIV)

LPCS-FCV-l 1 2Ml MO 0/C G

2Y OSP-LPCS/IST-Q702 lTV01,2 lB13 lA lGB I FAI lHJ Q

OSP-UPCS/IST-Q702 l

l l

3 NC L

J TSP-CONT-R801 DESCRIPTION: LPCS-P-1 MINIMUM FCV (CIV)

LPCS-RV-18 lM520 2

SA r NA lP RV TSP-RV/IST-R701 TV02,3 G12 AC RV NA L

J TSP-CONT-C801 l

lN09 1.5X2 2 NC DESCRIPTION: LPCS-P-1 RV (CIV)

LPCS-RV-31

[M520 2

j SA NA 1P RV TSP-RV/IST-R701 IV02,3 lD12 AC RV NA L

J TSP-CONT-C801 N09 lXl 1 NC DESCRIPTION: LPCS-P-2 SUCT RV (CIV)

LPCS-V-I lM520 2

MO O/C lG 2Y OSP-LPCS/IST-Q702 l

TV01,2 lDI1 l A

GT FAI IH Q

OSP-LPCS/IST-Q702 l

l 24 j

NO jL 2Y TSP-CONT-B802 DESCRIPTION: SUPPRESSION POOL TO LPCS-P-1 SUCT (CIV)

LPCS-V-3 0M20 2

SA O/C TH Q

OSP-LPCS/IST-Q702 B13 C

CK NA 16 NC l DESCRIPTION: LPCS-P-1 DISCH CHK

ITrga anColumbia Generating Station PgR~evi°sfiotn Valve Test Tables T-Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

LPCS-V-5 M520 1

MO O/C G

2Y OSP-LPCS/IST-Q701 CS106 TV01.2 Gil A

GT FAI HI CS OSP-LPCS/IST-Q701 12 NC L

2Y TSP-RCS-R801 DESCRIPTION: LPCS TO RPV ISO (OTBD CIV)

LPCS-V-6 M520 I

SA O/C H

RF OSP-LPCSIIST-R701 ROJ08 TV02

-VlH9 AC CK NA HL RF TSP-RCS-R801 I12 NC DESCRIPTION: LPCS TO RPV ISO CHK (INBD CIV)

LPCS-V-12 M520 2

MO C

G 2Y OSP-LPCS/IST-Q702 TV01,2 1E14 A

GB FAI H1 Q

OSP-LPCS/IST-Q702 12 NC L

J TSP-CONT-R801 DESCRIPTION: LPCS TEST LINE TO SUPPRESSION POOL ISO (CIV)

LPCS-V-33 M520 2

SA C

H Q

OSP-LPCSflST-Q702 N01 C12 C

CK NA Hx 12M OSP-LPCS-A702 CMP-21 1.50 NO DESCRIPTION: LPCS-P-2 ATER LEG) DISCH CHK LPCS-V-34 lM520 2

SA C

lHx Q

OSP-LPCS/IST-Q702 7

IN01 C13 C

SC NA Hx 12M OSP-LPCS-A702 I

I CMP-21 I

I I

1.50 I

NO I

I I

DESCRIPTION: LPCS-P-2 WATER LEG) DISCH STOP CHK LPCS-V-66 IM520 2

MA I

C IL 3

TSP-CONT-R801 ITV02 HI0 A

IGB NA Passve II I

1 I LC III DESCRIPTION: AIR TO LPCS-V-6 OPERATOR (INBD CIV)

LPCS-V-67 IM520 2

MA j C

]L

)

TSP-CONT-R801

[TV02 lH10o A IGB INA I Passive I

II 1 I LC III DESCRIPTION: AIR TO LPCS-V-6 OPERATOR (OTBD CIV)

MS-RV-1A M529 1

AO,SA l NA G

2Y TSP-MSRV/IST-R701 RV04 TV03 11 I

C SR NA P

RV ISP-MS/IST-R101 6 Xl Io NC MSP-MS/IST-RI01

_ I _

ISP-MS/IST-AI01 1,

1 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-1B M529 1

AO,SA NA G

2Y TSP-MSRV/IST-R701 RV04 TV03 D11 C

SR NA P

RV ISP-MS/IST-R101 6X 10I NC MSP-MS/ISTRI01 1

I ______

I I__I IISP-MS/IST-A101 I

._ I DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-1C M529 I

AO,SA NA G

2Y TSP-MSRV/IST-R701 RV04 TV03 F6 C

SR NA P

RV ISP-MS/IST-RO10 6 X 10 NC MSP-MS/IST-RIOI I _

_ I _

_ I

_ I _

I ISP-MS/IST-AI01_I I

DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-1D M529 1

AO,SA NA G

2Y TSP-MSRV/IST-R701 RV04 TV03 E7 C

SR NA P

RV ISP-MSflST-R1OI 6 X 10 NC MSP-MS/IST-RI01

_ I _

ISP-MSflST-AI0I DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-2A M529 1

AOSA I NA G

2Y TSP-MSRV/IST-R701 RV04 TV03 Flo C

SR NA P

RV ISP-MS/IST-R101 6 X 10 NC MSP-MS/IST-R101 I _

_ I _

_ I

_ I I_

ISP-MS/IST-A1O1 I

I DESCRIPTION: MAIN STEAM SAFETY RV

ISTrog0Y rItram ala Columbia Generating Station RevisionO0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

MS-RV-2B M529 I

AO,SA NA G

2Y TSP-MSRV/IST-R701 RV04 TV03 DIO C

SR NA P

RV ISP-MS/IST-R101 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-2C M529 I

AO,SA NA G

2Y TSP-MSRVIIST-R701 RV04 TVo3 F7 C

SR NA P

RV ISP-MS/IST-R101 6 X 10 NC MSP-MS/IST-R101 ISP-MSIIST-A101 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-2D M529 I

AO,SA NA G

2Y TSP-MSRV/IST-R701 RVO4 TVo3 E7 C

SR NA P

RV ISP-MS/IST-R101 6 X 10 NC MSP-MS/IST-R1O1 lSP-MS/IST-AlO1 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-3A M529 I

AO,SA NA G

2Y TSP-MSRV/IST-R701 RV04 TVO3 F9 C

SR NA P

RV ISP-MS/IST-R101 6 X 1A NC MSP-MS/IST-RI01 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-3B M529 1

AO,SA NA G

2Y TSP-MSRV/IST-R701 RV04 TVO3 ED7 C

SR l

NA P

RV ISP-MSIIST-RIO1 6 X 10 NC MSP-MS/IST-RO1 I

I__II _

IISP-MS/IST-A101

-DESCRIPTION:

MAIN STEAM SAFETY RV MS-RV-3C M529 I

AO,SA NA G

2Y TSP-MSRV/IST-R701 RV04 TV03 E7 C

SR NA P

RV ISP-MS/IST-R101 6 X 10 NC MSP-MSIlST-RI01 ISP-MS/1ST-AI01 DESCRIPTION: MAIN STEAM A SAFETY RV MS-RV-3D M529 I

AO,SA I 0 G

RF TSP-MSRV/IST-R701 RV04 N08 E8 C

SR NA P

RV ISP-MS/IST-RIO1 TV03 6X 10 NC MSP-MS/IST-RlO1 ISP-MS/IST-Al10 DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-RV-4A 1M529 I

AO,SA 1 0 G

RF TSP-MSRV/IST-R701 RVO4 N08 F9 C

SR NA P

RV ISP-MS/IST-R101 TV03 6X I10 NC MSP-MS/IST-RIOI ISP-MS/IST-A1O_

DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-RV-41 lM529 1

AO,SA J 0 G

RF TSP-MSRV/IST-R701 RVW4 N08 lD9 lC lSR lNA lP RV ISP-MS/IST-R101 1

TV03 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-RV-4C M529 l1 AOSA 0

G RF TSP-MSRV/IST-R701 RVW4 N08 F8 C

SR NA P

RV ISP-MS/IST-R101 TV03 6X 10 NC MSP-MS/IST-RI01 ISP-MSflST-AI101 DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-RV-4D IM529 I

AO,SA 0 O G

RF TSP-MSRV/IST-R701 lRV04 N08 lE8 C

lSR lNA lP RV ISP-MS/IST-R101 l

TV03 6

l X 10 lNC lMSP-MS/IST-R101 I

I I

IISP-MS/IST-AI01 DESCRIPTION: MAIN STEAM & ADS SAFETY RV

3rd 10-Year Interval C lm i Ge ra ngS tonRevisionO0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dvg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM1 Reliefs)

Position)

MS-RV-5B M529 I

AO,SA 0

G RF TSP-MSRV/IST-R701 RV04 N08 E9 C

SR NA P

RV ISP-MS/IST-RO1 TV03 6 X 10 NC MSP-hlS/IST-R1O1

_____ISP-M S/IST-A101_

DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-RV-5C M529 I

AO,SA 0

G RF TSP-MSRV/IST-R701 RV04 NO8 FS C

SR NA P

RV ISP-MS/IST-R101 TV03 6 X 10 NC MSP-MSIIST-RIO1 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-V-16 A

MO C

G 2Y OSP-MSLC/IST-Q702 CSJ13 TV01,2 B13 A

GT FAI HJ CS OSP-MSLC/IST-Q702 3

NC L

I TSP-CONT-R801 DESCRIPTION: MAIN STEAM DRN ISO (INBD CIV)

MS-V-19 M529 1

MO C

G 2Y OSP-MSLC/IST-Q702 CSJ13 TVO1,2 B14 A

GT FAI HI CS OSP-MSLC/IST-Q702 3

NC L

J TSP-CONT-R80I DESCRIPTION: MAIN STEAM DRN ISO (OTBD CIV)

MS-V-20 1M529 2

MO C

G 2Y OSP-MSLC/IST-Q702 Passive C15 B

JGB FAI l

l 3

lNC l

DESCRIPTION: MS LINE D ISO (MUST CLOSE FOR MSLC OPERATION)

MS-V-22A 1M529 1

AO C

G 2Y OSP-MS/IST-Q701 tCSJO8 TV01,2 F12 l

A GB FC jHJK CS OSP-MS/IST-Q701 l

l 26 NO lL 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-22B lM529 I

AO 1 C lG 2Y OSP-MS/IST-Q701 lCSJ08 lTVOI,2 E12 I

A GB FC IHIK CS OSP-MS/IST-Q701 I

l 26 J NO lL 2Y TSP-MSIV-B1801 DESCRIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-22C 1M529 I

I I

AO 1 C lG 2Y OSP-MS/IST-Q701 1CS108 ITVOl.2 FS A

GB j

FC lIUK CS OSP-MS/IST-Q701 l

l 26 l

NO IL 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-22D

]M529 I

AO 1 C lG 2Y OSP-MS/IST-Q701 lCSJ08 TVO1,2 E

J A

GB FC 1HJ1K CS OSP-MS/IST-Q701 I

l 26 l

NO IL 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-28A lM529 I 1 AO 1

C 2Y OSP-MS/IST-Q701 TCSJ08 TVOI,2 F13 A

GB FC HJK CS OSP-MS/IST-Q701 l

l 26 l

NO IL 2Y TSP-MSIV-BSO I DESCRIPTION: MAIN STEAM ISO VLV (OTBD CIV)I MS-V-28B M529 1 1 AO C

lG 2Y OSP-MS/IST-Q701 lCSJ08 TVO,2 E13 A

l GB FC 1HJK CS OSP-MSIIST-Q701 l

l 26 NO IL 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (OTBD CIV)

MS-V-28C 1M529 1

AO l

C lG 2Y OSP-MS/IST-Q701 lCSJ08 lTV01,2 F4 A

GB FC IHJK CS OSP-MS/IST-Q701 l

l 26 l

NO lL 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (OTBD CIV)

MS-V-28D 1M529 1

AO C

[G 2Y OSP-MS/1ST-Q701

[CSi08 JTVOI,2 E4 A

GB FC ICK CS OSP-MS/IST-Q701 I

I I

26 I

NO IL 2Y TSP-MSIV-B8OI I

I DESCRIPTION: MAIN STEAM ISO VLV (OTBD CIV)

IS PordlY am Planv Columbia Generating Station Page 91 of 181 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJt Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

MS-V-37A M529 3

SA 0

HS RF MSP-MS/IST-R701 ROJ07 TV05 (TYP 18)

Cli C

CK NA 10 N C DESCRIPTION: VACUUM BREAKER ON MSRV TAILPIPE MS-V-38A M29 3

SA 0

HS RF MSP-MSAlST-R701 ROJ07 TV05 (TYP 18)

Cll C

CK NNAC DESCRIPTION: VACUUM BREAKER ON MSRV TAILPIPE MS-V-67A M529 I

MO C

G 2Y OSP-MSLC/IST-Q702 CSJ11 TV01,2 Fl3 A

GT IFAT H

CS OSP-MSLC/IST-Q702 I.S0 INC L

2Y TSP-MSIV-B80l DESCRIPTION: MS-V-28A BODY DRN (OTBD CIV)

MS-V-67B M529

[

MO lC G

2Y OSP-MSLC/IST-Q702 CSI11 TV01,2 D13 A

GT l

Al Hi CS OSP`-MSLCIIST-Q702 1.50 NC 2Y TSP-MSIV-B801 DESCRIPTION: MS-V-28B BODY DRN (OTBD CIV)

MS-V-67C M529 I

MO C

2Y OSP-MSLCAIST-Q702 CSJI1 TV012 F4 A

GT lF I

Cs C

OSP-MSLC/IST-Q702 I

I 1.50 NC L

2Y TSP-MSIV-B801 I

I DESCRIPTION: MS-V-28C BODY DRN (OTBD CM MS-V-67D M529 I 1 MO l

C 1G 2Y OSP-MSLC/IST-Q702 lCSJ lTVO,2 D4 A

GT FAI IHi CS OSP-.MSLC/IST-Q702 I

_I I

I I1.50 I C IL 2Y TSP-MSIV-B801 II DESCRIPTION: MS-V-28D BODY DRN (OTBD CIV)

MS-V-146 M502-1 2

l MO l

C IG 2Y OSP-MSLC/IST-Q702 lCSJI0 ITV01 B7 B

GT FA IHJ CS OSP-MSLCAIST-Q702

[

2 4 N O

_ I _

DESCRIPTION: MS SUPPLY TO AUXILIARIES MSLC-V-1A M557 f 2 rMOl O/C G

2Y OSP-MSLC/IST-Q701 ITV01 C7 lB IGT FAITH1 Q

OSP-MSLC/IST-Q701 I

I I

I 1.50 I NC III DESCRIPTION: MS VENT BYPASS TO REACTOR BUILDING MSLC-V-IB M557 1

2 MO I

O/C lG 2Y OSP-MSLC/IST-Q70l TTV01 CS I B GT FATI HI Q

OSP-MSLC/IST-Q701 I

I 1.50 NC I

I I

DESCRIPTION: MS VENT BYPASS TO REACTOR BUILDING MSLC-V-IC IM557 2

MO O/C G

2Y OSP-MSLC/IST-Q701 I

lTV01 D7 B

GT FAI HI Q

OSP-MSLC/IST-Q701 II II 1-50 I NC I

DESCRIPTION: MS VENT BYPASS TO REACTOR BUILDING MSLC-V-ID

]M557 2

MO O/C G

2Y OSP-MSLC/IST-Q701 TV01 D5 B

GT FAI HJ Q

OSP-MSLCAST-Q701 I

I B I P.S0 I NC HI I

I DESCRIPTION: MS VENT BYPASS TO REACTOR BUILDING MSLC-V-2A CM557 B

GT MO 1

O G

2Y OSP-MSLC/IST-Q702 CSJ09 TV01 C8 lB GT MFAI I

CS OSP-MSLC/IST-Q702 I

I I

I 1.50 I NC III DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING MSLC-V-2B 1M557 I

MO 1 0 TG 2Y OSP-MSLC/IST-Q702 CSJ09 TV01 C8 l

B l

GT j FAT lHJ CS OSP-MSLC/IST-Q702 I

CIPTIO M1.50 V

NC A

U DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING

l3rd 10-Year Interval C lm iGe rangS tonRevision O

Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJAROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

MSLC-V-2C M557 I

MO 0

G 2Y OSP-MSLC/IST-Q702 CSJ09 TV01 E8 B

GT FAT HJ CS OSP-MSLC/IST-Q702 1.50 NC DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING MSLC-V-2D M557

[

MO 0

G 2Y OSP-MSLC/IST-Q702 CSJ09 TV01 E8 B

GT FAT HI CS OSP-MSLC/IST-Q702 1.50 NCI DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING MSLC-V-3A M557 I

MO O/C lG 2Y OSP-MSLC/IST-Q702 CSJ09 TV01,2 C9 A

GT FA_ _HJ CS OSP-MSLC/IST-Q702 1.50 NC IL 2Y TSP-MISIV-13801 DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING (OTBD CM MSLC-V-3B M557 I

MO O/C G

2Y OSP-MSLC/IST-Q702 CSJ09 TV01,2 C8 A

GT FAT HJ CS OSP-MSLC/IST-Q702 I.50 NC I.

2Y TSP-MSIV-B801 DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

MSLC-V-3C MS57 I

MO T O/C G

2Y OSP-MSLC/IST-Q702 lCSJ09 TV01,2 E9 A

GT FAT HI CS OSP-MSLC/IST-Q702 A 1.50 I NC IL 2Y TSP-MSIV-B801 I

I DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING (OTBD CM MSLC-V-3D M557 1

MO l

O/C IG 2Y OSP-MSLC/IST-Q702 fCSJ09 TVOI,2 E8 A

GT I

FAT IHJ CS OSP-NMSLCIIST-Q702 I

I I

I 1.50 I

NC lL 2Y TSP-MSIV-B801 DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

MSLC-V-4 M557 2

I MO I

0 IG 2Y OSP-MSLC/IST-Q702 ICSi09 TVOI J5 B

GT J FAT IHD CS OSP-MSLC/IST-Q702 I

I I

I 1.50 I NC III DESCRIPTION: MS VENT DOWN FROM MSIV'S TO REACTOR BUILDING MSLC-V-5 M557 j

2 [

MO ] 0 IG 2Y OSP-MSLC/IST-Q702 CSJ09 TV01 l15 lB lGT lFAI lHJ CS OSP-MSLC/IST-Q702 II I

I I 1.50 I NC III DESCRIPTION: MS VENT DOWN FROM MSIV'S TO REACTOR BUILDING MSLC-V-9 M557 l

2 l

MO r G

2Y OSP-MSLCAIST-Q702 CSJO9 ITVOI HS B I GT J FAT lHJ CS OSP-MSLC/IST-Q702 I

II I 1.50 I NC III DESCRIPTION: MS DEPRESS VENT DOWN FROM MSIV'S TO SGT ISO MSLC-V-0 1M557 2 2 MO 1 O

G 2Y OSP-MSLC/IST-Q702 CSJ09 TV01 HS B

lGT FAI I

CS OSP-MSLC/IST-Q702 I

I I

I I 1.50 I NC III DESCRIPTION: MS DEPRESS VENT DOWN FROM MSIV'S TO SGT ISO PI-EFC-XI8A 1M557 1

1 SA NA IGH TS ISP-EFC-BI02 RV05 lG9 lC lCK4 NA III I

IC I IX.5 NO I

DESCRIPTION: MAIN STEAM LINE A TO PRESS INST EFC (CM Pl-EFC-XI8B M557 I

SA NA GH TS ISP-EFC-BI02 RV05 G9 C

CK NA I

S I

III I X.5 I NO I

I DESCRIPTION: MAIN STEAM LINE B TO PRESS INST EFC (CIV)

Pl-EFC!-XI8C IM557 11I SA INA IGH TS ISP-EFC-BI02 IRV05 I

lF9 lC lCK NA lII I

I I I X.5 I NO III DESCRIPTION: MAIN STEAM LINE C TO PRESS INST EFC! (CIV)

IST Program Plan Page 93 of 181 3rd 10-Year Interval Columbia Generating Station RevisionO0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

PI-EFC-XI8D M557 1

SA NA GH TS ISP-EFC-BI02 RV05 F9 C

CK NA I X.5 NO DESCRIPTION: MAIN STEAM LINE D TO PRESS INST EFC (CIV)

PI-EFC-X29B M2 SA NA GH FS ISP-EFC-B108 N12 H C CK NA Passive I X.5 NO DESCRIPTION: DRYWELL ATM TO CMS-PT-6 EFC (CIV)

PI-EFC-X29F M543-l 2

SA NA GH FS ISP-EFC-BI08 N12 H7-1 I C CK NA Passive I1 X.5 NO DESCRIPTION: DRYWELL ATM TO CMS-PT-2 EFC (CIV)

PI-EFC-X30A M543- [ 2 SA NA GH FS ISP-EFC-B108 lN12 G13 C

CK NA

_Passive 1 X.5 NOI DESCRIPTION: DRYUELL ATM TO CMS-PT-5 EFC (CIV)

PI-EFC-X30F M543-1 2

SA l

NA GH FS ISP-EFC-B108 N12 F13 C

CK NA Passive II X.5 I NO III DESCRIPTION: DRYWELL ATM TO CMS-PT-I EFC (CIV)

PI-EFC-X37E M521-1 1

1 SA NA GH TS ISP-EFC-B107 jRV05

[

D6 l_C CK NA l

I _I I_

_ I_

_I X.5_ I NO I

I I

DESCRIPTION: RHR SDC A SUPPLY TO DPIS EFC (CIV)

PI-EFC-X37F M521-1I I

SA j NA lGH TS ISP-EFC-BI07 lRV05 1

ID6 lC lCK lNA lII I

I I I X.5 I NO III DESCRIPTION: RHR SDC A SUPPLY TO DPIS EFC (CIV)

PI-EFC-X38A lM529 [ 1 ISA NA IGH TS ISP-EFC-BI01 RV05 C13 C

CK NA I

I X.5 NO

__I I

DESCRIPTION: MAIN STEAM LINE B TO DPIS HI SIDE EFC (CIV)

PI-EFC-X38B M529 I

[SA l

NA GH TS ISP-EFC-BI01 lRV05

[

D13 C

CK NA I

I I IX-5 I NO III DESCRIPTION: MAIN STEAM LINE B TO DPIS LO SIDE EFC (CIV)

PI-EFC-X38C M519 lI SA NA lGH TS ISP-EFC-BI05 lRV05 G6 C

CK NA I I_

I I

I IIX. 5 I NO IGIH DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-7B EFC (CIV)

PI-EFC-X38D M519 I

SA NA lGH TS ISP-EFC-BI05 lRV05 1

IG6 IC ICK INA III I

I I I X.5 I NO III DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-7B EFC (CIV)

Pl-EFC-X38E M519 1 1 NA IGH TS ISP-EFC-BI05 RV05 G6 I _C I

_CK I

NA II I

I I

I IX.5 I NO III DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-13B EFC (CIV)

Pl-EFC-X38F M519 I

SA NA lGH TS ISP-EFC-BI05 R0 I

G6 lC l

CK NA CI IO: CI XS.5 S NO T

I DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-13B EFC (CMV

IST Program Plan Columbia Generating Station Page 94 osf 181~

_Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

PI-EFC-X39A M521-2 1

SA NA GH TS ISP-EFC-B101 RV05 H13 C

CK NA

~ lX.5 N O DESCRIPTION: MAIN STEAM LINE B TO DPIS HI SIDE EFC (CIV)

PI-EFC-X39B M529 1

SA INA GH TS ISP-EFC-B101 RV05 D13 C

CK NA

.5 NO DESCRIPTION: MAIN STEAM1 LINE B TO DPIS LO SIDE EFC (CIV)

PI-EFC-X39D M521-2 I

SA NA GH TS ISP-EFC-B104 RV05 113 C

CK NA

.5 N o DESCRIPTION: RHR LPCI B INJECTION TO DPIS-29B EFC (CIV)

PI-EFC-X39E M521-2 1

SA NA GH TS ISP-EFC-B104 RV05 H13 C

CK NA DESCRIPTION: RHR LPCI C INJECTION TO DPIS-29B EFC (CIV)

PI-EFC-X40C M530-1 I [ SA l

NA GGH TS ISP-EFC-B106 RV05 P12 C

CKj NA F12l X.5 lNO l DESCRIPTION: RRC A TO FT-14A,14B.1IA EFC (CIV)

PI-EFC-X40D M530-1 [

1 lSA NA GGH TS ISP-EFC-B106 lRV05 F12 J C C

NA

_ I _ _

l l1 X.5 l NO l

DESCRIPTION: RRCA TO FT-14A,14B,IIA EFC (CIV)

PI-EFC-X40E M530-l 2

SA NA IGH TS ISP-EFC-B3104 RV05 lC14 lC

_ _]

NA I_

.5 N O DESCRIPTION: RRC A (RRC-P-1A) TO PI-IA,602A EFC (CIV)

PI-EFC-X40F M530-1 l

2 l

SA l

NA lGH TS ISP-EFC-B104 RV05 C14 jC lCK l

NA DESCRIPTION: RRC A (RRC-P-IA) TO PI-2A,603A EFC (CIV)

PJ-EFC-X41C M530-1 I

SA NA lGH TS ISP-EFC-B104 lRV05

[B4 C

CK NA DESCRIPTION: RRC B (C-)

TO DPT-15B EFC (CIV)

PI-EFC-X41D M530-1 I [ SA l

NA lGH TS ISP-EFC-B104 lRV05 C4 lC CK NA DESCRIPTION: RRC B (RRC-P-IB) TO DPT-15B EFC (CIV)

PI-EFC-X41E M530-1 2

SA l

NA IGH TS ISP-EFC-B104 lRV05 B4 lC l CKJ NA DESCRIPTION: RRC B (RRC-P-IB) TO PI-1B,602B EFC (CIV)

PI-EFC-X41F M530-1 l

2 l

SA l

NA lGH TS ISP-EFC-B104 lRV05 C4 IC J CK NA DESCRIPTION: RRC B (RRC-P-1B) TO PI-2B,603B EFC (CIV)

PI-EFC-X42A lM529 I 1 ISA 1 NA IGH TS ISP-EFC-B1101 RV05 DC4 RC MAIx jE NO D T PHIE V

DESCRIPTION: MAIN STEAM LINE D TO DPIS HIl SIDE EFC (CMV

lIST Program Plan Columbia Generating Station Page 9e5 osf 1n80

_Valve Tcst Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

PI-EFC-X42B M529 1

SA NA GH TS ISP-EFC-B101 RV05 C4 C

CK NA 1 1X.5 N O DESCRIPTION: MAIN STEAM LINE D TO DPIS LO SIDE EFC (CIV)

PI-EFC-X42C M543-2 2

SA NA GH FS ISP-EFC-B108 N12 E6 C

C______

Passive DESCRIPTION: 112-02 MONITOR TO DRYWELL ATM SAMPLE EFC (CIV)

PI-EFC-X42F M529 2

SA NA GH FS ISP-EFC-B108 N12 H5 C

Cl NA' Passive

[ 1 5 15 N O J DESCRIPTION: DRYWELL ATM TO PRESS INST EFC (CIV)

Pl-EFC-X44AA M530-1 1 I SA NA GH TS ISP-EFC-BI03 RV05 E2 C

CK NA I

.5 NOI DESCRIPTION: JET PUMP NO 11 TO FLOW INST EFC (CIV)

PI-EFC-X44AB M530-1 I

AI NA GGH TS ISP-EFC-BI03 1RV05 E2 C I NA DESCRIPTION: JET PUMP NO 12 TO FLOW INST EFC (CIV)

PI-EFC-X44AC M530-1 f I

SA NA GGH TS ISP-EFC-BI03 RV05 CE2 l

C l

CK NA T

IX.5 NOJ______________

DESCRIPTION: JET PUMP NO 14 TO FLOW INST EFC (CIV)

PI-EFC-X44AE M530-1 1I SA NA 1GH TS ISP-EFC-BI03 RV05 J6 l

C CK NA DESCRIPTION: JET PUMP NO 15 TO FLOW INST EFC (CIV)

PI-EFC-X44AF M

1

[

I NA GH TS ISP-EFC-B 103 RV05 536-C NA I_

SX 5 NO DESCRIPTION: JET PUMP NO 16 TO FLOW INST EFC (CIV)

PI-EFC-X44AG lM530-1 1

SA NA GH TS ISP-EFC-BI03 RV05 DESCRIPTION: JET PUMP NO 17 TO FLOW INST EFC (CIV)

IE2 lC l

K I

l NA I___ 5 NOII DESCRIPTION: JET PUMP NO 19 TO FLOW INST EFC (CIV)

PI-EFC-X44AJ M530-I I

SA NA lGH TS ISP-EFC-BI03 lRV05 I

E2 I

C I CK I NA DESCRIPTION: JET PUMP NO 18 TO FLOW INST EFC (CIV)

PI-EFC-X44AI M530-1 I

SA NA GH TS ISP-EFC-BI03 RV05 J6

[ CX NA E

DESCRIPTION: JET PUMP NO 20 TO FLOW INST EFC (CIV)

IST Program Plan Coum i Geeatn Stto Page 96 of 181 3rd 10-Year Interval ou baG nrtn tto Revision O Valve Test Tables Tpe Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPAM Reliefs)

Position)

PI-EFC-X44AL M530-1 1

SA NA GH TS ISP-EFC-BI03 RV05 H6 C

CK NA I X.5 NO DESCRIPTION: JET PUMP NO 15 TO FLOW INST EFC (CIV)

PI-EFC-X44AM M530-1 1

SA NA GH TS ISP-EFC-BI03 RV05 1

H6 C

CK NAI I X.5 N

DESCRIPTION: JET PUMP NO 20 TO FLOW INST EFC (CMV)

PI-EFC-X44BA M530-1 1

SA NA GGH TS ISP-EFC-BI03 RV05 F2 C

CK NA I

I X.5 NO I DESCRIPTION: JET PUMP NO 1 TO FLOW INST EFC (CIV)

PI-EFC-X44BB M5301 I

SA NA GH TS ISP-EFC-BI03 lRV05 1

F2 C

CK NAII I X.5 NO I_

I DESCRIPTION: JET PUMP NO 2 TO FLOW INST EFC (CIV)

Pl-EFC-X44BC M530-1 I

SA NA GGH TS ISP-EFC-B103 1RV05 1

lF2 I

CK NA I

I I

_ I _

I X.5 NO I

I I

DESCRIPTION: JET PUMP NO 3 TO FLOW INST EFC (CIV)

Pl-EFC-X44BD lM530-1 I

SA lNA lGH TS ISP-EFC-B103 lRV05 1

CF2 I

C CK NA I

T I

I ~

~

I X.5 INO III DESCRIPTION: JET PUMP NO 4 TO FLOW INST EFC (CIV)

PI-EFC-X44BE M530-1 1I SA NA GGH TS ISP-EFC-B103 RV05 ill.

C CK NA II I

I I IX.5 I NO III DESCRIPTION: JET PUMP NO 5 TO FLOW INST EFC (CIV)

PI-EFC-X44BF M530-1 I

SA NA IGH TS ISP-EFC-B103 lRV05 lF2 I

_C CK [

NA I

I I I 1X.5 I NO III DESCRIPTION: JET PUMP NO 6 TO FLOW INST EFC (CIV_)

PI-EFC-X44BG M530-1 I

SA NA GGH TS ISP-EFC-B103 1RV05 lF23 I

C CK NA I

I 1 1 I X.5 NO I

I I

DESCRIPTION: JET PUMP NO 7 TO FLOW INST EFC (CIV)

PI-EFC-X44BH lM530-1 1

SA NA GGH TS ISP-EFC-B103 1RV05

_F2 IC I CK I NA I

I I

I I 1X.5 I NO III DESCRIPTION: JET PUMP NO 8 TO FLOW INST EFC (CIV)

PI-EFC-X44BJ tM530-I I

SA l

NA lGH TS ISP-EFC-B103 RV05 F2 C

CK NA I_

I I

II X.5 NO DESCRIPTION: JET PUMP NO 9 TO FLOW INST EFC (CIV)

PI-EFC-X44BK M530-1 I

SA NA lGH TS ISP-EFC-B103 RV05 ill C

CK NA I X.5 NO

___I DESCRIPTION: JET PUMP NO 10 TO FLOW INST EFC (CIV)

PI-EFC-X44BL M530-1 SA NA lGH TS ISP-EFC-B103 RV05 IIH IC CK NA I I

_ I 1X.5

-NO I

I I

DESCRIPTION: JET PUMP NO S TO FLOW INST EFC (CIV)

IST Program Plan Columbia Generating Station Pge9 of ision Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPAI Reliefs)

Position)

PI-EFC-X441BM M530-1 I

SA NA GH TS ISP-EFC-BI03 RV05 HIl C

C}

NA I X.5 NO DESCRIPTION: JET PUMP NO 10 TO FLOW INST EFC (CIV)

PI-EFC-X61A M530-]

I SA NA GH TS ISP-EFC-BI06 RV05 F12 C

CIC NAI I X.5 NOI DESCRIPTION: RRC A TO FT-14C.14D EFC (CIV)

PI-EFC-X61B M530-1 SA NA GH TS ISP-EFC-BI06 RV05 F12 C

CK NA I X.5 NO DESCRIPTION: RRC A TO FT-14C.14D EFC (CIV)

PI-EFC-X61C IM529 SA NA GH FS ISP-EFC-B108 N12 G5C CK NA Passive I1 X

.5 NO DESCRIPTION: DRYWELL ATM TO PRESS INST EFC (CIV)

PI-EFC-X62B M529 2 1 SA NA GGH FS ISP-EFC-BI08 N12 H12 C

CK l NA Passive I

I I X1.5 NO DESCRIPTION: DRYWELL ATM TO PRESS INST EFC (CIV)

PI-EFC-X62C lM530-I C ]

SA NA GH TS ISP-EFC-BI06 RV05 F6 IC ICK INA III I II IX.5 I NO III DESCRIPTION: RRC B TO FT-24C.24D EFC (CIV)

PI-EFC-X62D 1M530-I I

SA NA GH TS ISP-EFC-BI06 1RV05 IF6 IC ICK INA III I

]

I IX.5 NO I

I DESCRIPTION: RRC B TO FT-24C,24D EFC (CIV)

PI-EFC-X66 lM543-1 l

2 l1 SA NA GGH FS ISP-EFC-B108 1

_N12 IB6 IC ICK INA I Passive I

I1X.5 NO III DESCRIPTION: WETWELL ATM TO CSP-DPT-5 EFC (CIV)

PI-EFC-X67 1M543-1 1 2 1 SA NA GGH FS ISP-EFC-BI08 1

1N12 lB13 l

C I1C};

NA P

l___assive I

IIX.5 I NO III DESCRIPTION: WETWELL ATM TO CSP-DPT-4 EFC (CIV)

PI-EFC-X69A lM529 1 j I

SA NA GGH TS ISP-EFC-BI01 lRV05 IC4 lC lCICK NA III I I I X.5 I NO III DESCRIPTION: MAIN STEAM LINE D TO DPIS Hl SIDE EFC (CIV)

PI-EFC-X69B M529 I

SA I

NA lGH TS ISP-EFC-BI01 1RV05 lC4 lC ICK INA III I2 1 X.5 NO DESCRIPTION: MAIN STEAM LINE D TO DPIS LO SIDE EFC (CIV)

PI-EFC-X69E lM530 11 SA NA lGH TS ISP-EFC-BI04 RV05 lG6 lC lCICK NA III I

I I X.5 I NO III DESCRIPTION: RRC B TO PS-18B EFC (CIV)

PI-EFC-X69F M529 2

SA NA lGH FS ISP-EFC-B108 N12 H12 IC C

NA Passive I

_ I lI X.5 I NO I

II DESCRIPTION: DRYWELL ATM TO PS-48A,48C,2B EFC (CIV)

IST Program Plan Columbia Generating Station Pae 98 of 18 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PP1M Reliefs)

Position)

PI-EFC-X70A M529 I

SA NA GH TS lSP-EFC-BIOI RV05 E4 C

CK NA I X.5 NO DESCRIPTION: MAIN STEAM LINE C TO DPIS HI SIDE EFC (CIV)

PI-EFC-X70B M529 1

SA NA GH TS ISP-EFC-B3101 RV05 E4 C

CK N

DESCRIPTION: MAIN STEAM LINE C TO DPIS LO SIDE EFC (CIV)

PI-EFC-X70C M529 I

SA NA GH TS ISP-EFC-B101 RVO5 E13 C

CK NA I

I X.5 NO DESCRIPTION: MAIN STEAM LINE A TO DPIS HI SIDE EFC (CIV)

PI-EFC-X70D M529 1

SA NA GH TS ISP-EFC-B101 lRV05 E13 C

CK NA 1 X.S O

DESCRIPTION: MAIN STEAM UNE A TO DPIS LO SIDE EFC (CIV)

Pl-EFC-X70E M3G-1 l

l SA NA GGH TS ISP-EFC-B104 RVO5 B14

C CK NA 1 1 X.51 NO DESCRIPTION: RRC A (RRC-P-IA) TO DPT-15A EFC (CIV)

PI-EFC-X70F lM530-1 1

SA NA GGH TS ISP-EFC-B104 RV05 gB14 C

CK NA I X.5 NO II DESCRIPTION: RRC A (RRC-P-IA) TO DPT-15A EFC (CM_

PI-EFC-X71A M529 I

I SA NA iGH TS ISP-EFC-B101 RV05 E4 C

CK NA I1X.5 NO

__I

_I DESCRIPTION: MAIN STEAM LINE C TO DPIS HI SIDE EFC (CIV)

PI-EFC-X71B lM529 1

SA NA GH TS ISP-EFC-B101 RV05 E4 C

CK NA lI X.5 I NO II DESCRIPTION: MAIN STEAM LINE C TO DPIS LO SIDE EFC (CIV)

P1-EFC-X71C M519 I

SA NA GGH TS ISP-EFC-B105 RV05 G6 C

CK NA

___ _I IX.5_

NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-7A EFC (CIV)

PI-EFC-X71D M519 l

I lSA NA 1Gi TS ISP-EFC-B105 lRV05 lG6 lC lCK lNA lI I X.

N I

I DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-7A EFC (CIV)

Pl-EFC-X71E lM519 I

SA l

NA iGH TS ISP-EFC-B105 RVO0 lG6 l

_C l

_CK_ l NA l

I IEFI~E 1 X.5 N

NO I

IBI DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-13A EFC (CIV)

PI-EFC-X7IF M519 I

SA NA GH TS ISP-EFC-B105 RV05 lG6 lC lCK lNA l

I X.5 NO II DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-13A EFC (CIV)

PI-EFC-X72A

[M529 1

SA NA lGH TS ISP-EFC-B107 IRV05 N6 O

C

__CK

__NA I X.5 NO DESCRIPTION: RPV STEAM DOME TO PRESS INST EFC (CIV)

l3rd 10-Year Interval Columbia Generating Station Revision 0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPAI Reliefs)

Position)

PI-EFC-X73A M520 1

SA NA GH TS ISP-EFC-BI05 RV05 J8 C

CK NA I X.5 NO DESCRIPTION: 1IPCS TO RPV TO DP S-9 EFC (CIV)

Pl-EFC-X74A M530-1 1

SA NA

_GH TS ISP-EFC-BI03 RV05 G12 C

CK NA I X.5 NO DESCRIPTION: SLC INJ BELOW CORE PLATE TO FLOW INSTR EFC (CIV)

Pl-EFC-X74B M521-1 I lSA NA GH TS ISP-EFC-BI04 RY05 HS C ICK NA l I X.5 NO DESCRIPTION: RHR LPCI A INJECTION TO DPIS-29A EFC (CIV)

PI-EFC-X74E lM530-1 II SA NA GH TS ISP-EFC-BI04 RV05 1HII C

CK NA I_

I X1.5 NO DESCRIPTION: RRC A TO RHR PUMPS TO DPIS-12A EFC (CIV)

P-EFC-X74F M530-I SA NA GH TS ISP-EFC-B104 RV05 Hll C

CK NA I X.5 NOIII DESCRIPTION: RRC A TO RHR PUMPS TO DPIS-12A EFC (IRV)

PI-EFC-X75A M530-1 I

rSA I

NA GGH TS ISP-EFC-BI03 1RVO5 1

IG6 I

c CKa NAIII I I X.5 NO II_

DESCRIPTION: SLC INJ BELOW CORE PLATE TO FLOW INSTR EFC (C)M5 PI-EFC-X75B M530-1 I

SA NA 1GH TS ISP-EFC-BI05 RV05 T

lG12 C

lCK NA G

T 1

I I

I IX.5 I NO III DESCRIPTION: SLC INJ ABOVM LIE PLATE TO FLOW INSTR EFC (CIV)

PI-EFC-X75C lM529 1 ISA TS ISP-EFC-1A01 RV05 lE12 lC lCK lN I

I I ~~I X.S5 O

DESCRIPTION: MAIN STEAM LINE A TO DPIS EFC (CIV)

PI-EFC-X75D M529 I

SA l

NA GH TS ISP-EFC-BI01 lRV05 lE2 C

CK NA II I

I X.5 I NO III DESCRIPTION: MAIN STEAM LINE A TO DPIS EFC (CIV)

PI-EFC-X75E M5301 1I SA I NA 1GH TS ISP-EFC-BI06 1RV05 1

lFS I

C CK NA I

I I IX.S5 NOIII DESCRIPTION: RRC B TO FT-24A,24B EFC (CIV)

PI-EFC-X75F M530-1 I

SA l NA 1GH TS ISP-EFC-B106 RV05 FS C

CK NA I

I X.S5 NO III DESCRIPTION: RRC B TO FT-24A,24B EFC (CIV)

PI-EFC-X78A lM43-2 2

SA NA 1GH FS ISP-EFC-BI08 N12 lE14 I

C CK NA IPassve

[

I_ [

I_ 1 X.5 NO I

I 1

DESCRIPTION: L2-02 MONIR TO DRYWELL ATM SAMPLE ISO (CIV)

Pl-EFC-X78B lM520 r11 SA T NA 1GH TS ISP-EFC-BI04 1RV05 lJI0 l

C lCK lNAlII I

I I I X.5 I NO III DESCRIPTION: LPCS TO RPV TO RR-DPS-29A EFC (CIV)

IST Program Plan Page 100 of 181 3rd 10-Year Interval Columbia Generating Station RevisionO0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

PI-EFC-X78C M523 I

SA NA GH TS ISP-EFC-B103 RV05 F12 C

CK NA

_ ~ IX.5 NO DESCRIPTION: RWCU TO RWCU-FT-37 EFC (CIV)

PI-EFC-X78F M530-1 1

SA NA GH TS ISP-EFC-B104 RV05 H12 C

CK NA DESCRIPTION: RRC A (RRC-P-IA SUCM) TO PS-18A EFC (CIV)

PI-EFC-X79A M523 I

SA NA GH TS ISP-EFC-BI05 RV05 F15 C

CKI C~h NA DESCRIPTION: RWCU TO RWCU-FT-36 EFC (CIV)

PI-EFC-X79B M523 1

SA NA GH TS ISP-EFC-BI05 RV05 14 C

CK NA

.5 N O DESCRIPTION: RWCU TO RWCU-FT-36 EFC (CIV)

PI-EFC-X82B M543-1 2

SA NA GH FS ISP-EFC-Bi108 l2 lB6 l_

C l

ChKl NA l

l lPassive B14 J I

X. 5 j N O DESCRIPTION: _VETWELL ATM TO PT-3 EFC (CIV)

P-EFC-X86A lM543-1 2

lSA NA lGH FS ISP-EFC-B108 N12 B6 l

C lCK INA l

l Passive DESCRIPTION: WETWELL ATM TO EFC (CIV)

PI-EFC-X86A M543-1 2

SA NA lGH FS ISP-EFC-BI08 N12 B14 C

CK NA Passive I I

.5 N O DESCRIPTION: WETWELL TO LT-I EFC (CIV)

PI-EFC-X86B M43-1 2

SA NA lGH FS ISP-EFC-BI08 lN12 lB61 l

C l

CK l

NO l

l lPassive DESCRIPTION: WETWELL TO LT-1 EFC (CIV)

Pl-EFC-X87B M543-1 2

[SA T NA lGH FS ISP-EFC-BI08 N12 B6 C

CK NA Passive DESCRIPTION: WETWELL TO LT-2 EFC (CIV)

Pl-EFC-X10 lM529 2

SA NA GH ES ISP-EFC-B107 l0 N12 1

C

[CK NA Passive I__

NO I____________

DESCRIPTION: WETWELL TO LT-2 EFC (CIV)

PI-EFC-X106 M29 SA NA GH TS ISP-EFC-BI07 RV05 H12 C

CK NA N O DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X107 M529 I

SA t NA lGH TS ISP-EFC-B107 lRV05 1H12 C

CK NA I I

(

I 1 1 5 NO II_

DESCRIPTION: RPV TO PRESS INST EEC (CMV PI-EEC-XI08 1M529 JI SA NA GOH TS ISP-EEC-B 107

~

RV05 DESCRIPTION: RPV TO PRESS INST EEC (CI-V)

IST Program Plan Coum i Geeatn Stto Page 101 of 181 3rd 10-Year Interval C l m l elrt g

tlO RevisionO0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

PI-EFC-X109 M529 I

SA NA GH TS ISP-EFC-B107 RV05 15 C

CK NA I X.5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X110 M529 I

SA NA GH TS ISP-EFC-B107 RV05 H5 C

CK NA I X.5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-XI 1 M529 1

SA NA I GH TS ISP-EFC-B107 RV05 H5 C

CK lNA I X.5 l NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-XI 12 M529 I

SA NA GH TS ISP-EFC-B107 RV05 H5 C

CK NA X.5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X113 M529 SA NA IGH TS ISP-EFC-B107 RV05 H5 C

l CK l_NA_l l

l I X.5 NO l

DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X114 M529 I

I

[

SA NA 1GH TS ISP-EFC-B107 RV05 529 lR 5

_1X_5 l

NO_l DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-XI15 lM529

[

SA l

NA lGH TS ISP-EFC-B107 1H12 C

R CK l_NA_l I

l X.5 l NO Il____

DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-XI19 M

1 543-1 2

SA NA GH FS ISP-EFC-B108 lNI2 lB6 lC lCK lNA l

Passive l

1 X.5 NO DESCRIPTION: WETWELL ATM TO CSP-DPT-6 EFC (CIV)

PI-V-X42D M521-1 2

1 MA 1 C IL 1

TSP-CONT-R801 TV02 F5

_A l GB l_NA l

l Passive I

I LC DESCRIPTION: AIR TO RHR-V-50A OPERATOR (INBD CIV)

PI-V-X54BF lM521-2 I

2 1 MA 1 C IL J

TSP-CONT-R801

[

TV02 1H13 l

A GB JNA l I lPassive I

LC DESCRIPTION: AIR TO RHR-V-4IB OPERATOR (INBD CIV)

PI-V-X61F 1M521-1 I 2

7 MA 1 C IL J

TSP-CONT-R801

[

TVO2 G5 l

A l

GB ] NA Passive I

LC l

DESCRIPTION: AIR TO RHR-V-41A OPERATOR (INBD CIV)

PI-V-X62F M521-3 2

MA C

L J

TSP-CONT-R801 j

TV02 lD12 lA lGB lNA l

Passive lI l

I I LC lI DESCRIPTION: AIR TO RHR-V-41C OPERATOR (INBD CIV)

PI-V-X69C lM521.2 l

2 l

MA l

C lL J

TSP-CONT-R801 I

TV02 lF13 lA l

GB NA l

l Passive P -V-X69C I

L-C ITSCOT DESCRIPTION: AIR TO RHR-V-50B OPERATOR (INBD CIV)

Pl-V-X72F/1 M543-I 2

l SA C

HX 4Y OSP-CONT/IST-R701 ROJ04 TV02 1F13 AC CK NA lHxL J

TSP-CONT-R801 CMP-13 I 1 NO l

DESCRIPTION: DRYWELL ATM TO RAD-RE-12A CHK (CIV)

3rd Program Plntra Columbia Generating Station Page 10e2 o~f 1n8 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

PI-V-X73E/1 M543-1 2

SA C

Hx 4Y OSP-CONT/IST-R701 R0104 TV02 F7 AC CK NA HxL i

TSP-CONT-R801 CMP-13 1

NO DESCRIPTION: DRYWVELL ATM TO RAD-RE-12B CHK (CIV)

PI-VX-216 M521-1 2

MA C

L I

TSP-CONT-R801 TV02 G6 A

GB NA Passive 1

LC DESCRIPTION: AIR TO RHR-V-50A OPERATOR (OTBD CIV)

PI-VX-218 M521-2 2

MA C

L i

TSP-CONT-R801 TV02 H13 A

GB NA O PassDe 1

LC I

DESCRIPTION: AIR TO RHR-V-41B OPERATOR (OTBD CIVM PI-VX-219 M521-1 1 2 MA L

J TSP-CONT-R801 1

lTV02 H6 A

GB NA j _

Passive DESCRIPTION: AIR TO RHR-V-41A OPERATOR (OTBD CIV)

PI-VX-220 M521-3 2

MA C

IL i

TSP-CONT-R801 1

TV02 DII A

GB NA J____Passive I

1I LC I

DESCRIPTION: AIR TO RHR-V-41C OPERATOR (OTBD CIV)

Pl-VX-221 M521-2 l

2 MA C

l TSP-CONT-R801 7 TV02 G12 A

l VGB F NA TPCNRPassive l

lI NO IC L

I IS~OTSi___

DESCRIPTION: AIR TO R ATR-V-5OB OPERATOR (OTBD CIV)

PI-VX-250 M543-1 2

SO C

lG 2Y OSP-CONT/IST-Q703 TV01,2 F13 A

SV FC lG 2Y TSP-CONT-R801 I

NO 1HUK Q

OSP-CONT/IST-Q703 I __IIL J

TSP-CONT-R801 1_

1 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-251 M543-1 2

SO C

G 2Y OSP-CONT/IST-Q703 TV01,2 F13 A

SV FC G

2Y TSP-CONT-R801 I

NO HIHK Q

OSP-CONT/IST-Q703 IL i

TSP-CONT-R801 1_

1 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-253 M%1543-1 2

SO C

G 2Y OSP-CONT/IST-Q703 TVO1,2 FI3 A

SV FC G

2Y TSP-CONT-R801 1

NO lHUK Q

OSP-CONT/IST-Q703 l

IL i

TSP-CONT-R801 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-256 M543-1 2

SO C

G 2Y OSP-CONT/IST-Q703 TVO1,2 F7 A

SV FC G

2Y TSP-CONT-R801 I

NO IHJK Q

OSP-CONT/IST-Q703 l

_L i

TSP-CONT-R801 1

1 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-257 M543-1 2

SO C

G 2Y OSP-CONT/IST-Q703 TVO1,2 F7 A

SV FC G

2Y TSP-CONT-R801 1

NO lHUK Q

OSP-CONT/IST-Q703 l

l L i

TSP-CONT-R801 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

Pl-VX-259 lM543-1 l2 lSO l

C lG 2Y OSP-CONT/IST-Q703 l

TV01,2 IF7 A

SV FC IG 2Y TSP-CONT-R801 l

l I

lNO IHIJK Q

OSP-CONT/IST-Q703 l

L I

TSP-CONT-R801 1

DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CMV

IST Program Plan Coum i Geeatn Stto Page 103 of 181 3rd 10-Year Interval Cou baG nrt gSalnRevision O

Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

PI-VX-262 M543-2 2

SO NA G

2Y OSP-CONTIIST-Q703 Nil G13 B

SV PC HJK Q

OSP-CONTIIST-Q703 Passive I

N O DESCRIPTION: DRYWELL TO 112-02 MONITOR ISO (CIV)

PI-VX-263 1M543-2 2

SO NA G

2Y OSP-CONT/IST-Q703 NIl1 F13 B

SV FC H1JK Q

OSP-CONT/IST-Q703 Passive DESCRIPTION: DRYWELL TO 112-02 MONITOR ISO (CIV)

PI-VX-264 M543-2 2 J SO I

NA G

2Y OSP-CONTIIST-Q703 Nil F13 B

SV FC 1 HlK Q

OSP-CONTIIST-Q703 Passive DESCRIPTION: DRYWELL TO 112-02 MONITOR ISO (CIV)

PI-VX-265 M543-2 2 J SO NA lG 2Y OSP-CONTIIST-Q703 NI1 B14 B

SV FC 11K Q

OSP-CONTIIST-Q703 Passive DESCRIPTION: DRYWELL TO H2-02 MONITOR ISO (CIV)

PI-VX-266 M543-2 2 T SO NA lG 2Y OSP-CONT/IST-Q703 T

1NI1 F7 B

SV FC 111K Q

OSP-CONT/IST-Q703 l

Passive I

I NO l

DESCRIPTION: DRYWELL TO 112-02 MONITOR ISO (CIV)

PI-VX-268 IM543-2 r 2

1 so I

NA TG 2Y OSP-CONTIIST-Q703 r

Nil F7 JB!

SV FC lHJK Q

OSP-CONTIIST-Q703 Passive DESCRIPTION: DRYWELL TO H2-02 MONITOR ISO (CIV)

PI-VX-269 IM543-2 1 2 I

SO I

NA IG 2Y OSP-CONTIIST-Q703 I

lN1l B6 B

SV PC 11JK Q

OSP-CONT/IST-Q703 Passive 1

jNO DESCRIPTION: DRYWELL TO H2-02 MONITOR ISO (CM V)

PSR-V-003/A lM896 2

SO C

G 2Y CSP-PSR/IST-Q701 lTVO lE12 lB lSV l

C lHJ Q

CSP-PSR/IST-Q701 I

NC DESCRIPTION: RHR LOOP A SAMPLE ISO PSR-V-003/B lM896 2

l SO l

C G

2Y CSP-PSR/IST-Q701 lTVO D12 B

SV FC 11J Q

CSP-PSR/IST-Q701 I1 I

NC DESCRIPTION: RHR LOOP B SAMPLE ISO PSR-V-X73/1 lM896 2

SO l

C G

2Y TSP-CONT-R801 RVO3 lTV0I,2 lJ14 A

GB FC lHJK Q

CSP-PSR/IST-Q70I I

NC lL 1

TSP-CONT-R801 DESCRIPTION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X7312 M896 2

I C

G 2Y TSP-CONT-R801 I

iTVOI,2 lJ12 A__

GB l_PC l}DK Q

CSP-PSRJIST-Q701 I

NC lL J

TSP-CONT-R801 DESCRIPTION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X77A/1 M9 I

l SO0 I

-C IG 2Y TSP-CONT-R801 lRV03 lTV01,2 A

GB PC 1HJK Q

CSP-PSRIIST-Q701 I I NC L

1 TSP-CONT-R801 DESCRIPTION: JET PUMP SAMPLE ISO (CIV)

PSR-Y-X77A/2 lM896 I

SO C

G 2Y TSP-CONT-R801

]

lTV01,2 lE12 lA lGB l

C lHJK Q

CSP-PSR/IST-Q70I II NC lL J

TSP-CONT-R801 DESCRIPTION: JET PUMP SAMPLE ISO (CIV)

PSR-V-X77A13 M896 1

SO I

C lG 2Y TSP-CONT-R80I lRV03 lTV01,2 F14 A

GB NC 11UK Q

CSP-PSR/IST-Q701 0

DSIPITION NC PL P TSP-CONT-R801 I

DESCRIPTION: JET PUMP SAMPLE ISO (CMV

3rd 10-Year Interval C lm i Ge rangS tonRevision O

Valve Test Tables T'pe Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

PSR-V-X77A/4 M896 1

SO C

G 2Y TSP-CONT-R801 TV01,2 F12 A

GB FC HI1K Q

CSP-PSRIIST-Q701 1

NC L

i TSP-CONT-R801 DESCRIPTION: JET PUMP SAMPLE ISO (CIV)

PSR-V-X80/1 M896 SO o G

2Y TSP-CONT-R801 RV03 TV01.2 K14 A

GB FC H1K Q

CSP-PSR/IST-Q701 I

NC L

i TSP-CONT-R801 DESCRIPTION: DRYWELL ATM SAM PLE ISO (CIV)

PSR-V-X80/2 M896 2

SO C

G 2Y TSP-CONT-R801 TV01,2 1K12 A

GB FC HIK Q

CSP-PSR/lST-Q701 I

NC L

J TSP-CONT-R801 DESCRIPTION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X8211 M896 2

SO C

G 2Y TSP-CONT-R801 RV03 TV01,2 B12 A

GB FC H1K Q

CSP-PSR/IST-Q701 I

NC L

J TSP-CONT-R801 DESCRIPTION: SAMPLE RETURN TO SUPP POOL ISO (CIV)

PSR-V-X8212 M896 2

s O5 C

G 2Y TSP-CONT-R801 TV01,2 lBI I A __GB FC HJK Q

CSP-PSR/IST4Q701 l

I lNC lL I

TSP-CONT-R801 DESCRIPTION: SAMPLE RETURN TO SUPP POOL ISO (CIV)

PSR-V-X82/7 1M896 j

2 s0 O C

G 2Y TSP-CONT-R801 RV03 TVO0,2 lG12 A

GB FC l11K Q

CSP-PSR/IST-Q701 lI8 1

NC GL J

TSP-CONT-R801 l

l DESCRIPTION: SAMPLE RETURN TO DRYWELL ISO (CIV)

PSR-V-X82/8 M896 1

2 0

SO I

C lG 2Y TSP-CONT-R801 lTVO0,2 G113 A

GB FC H1K Q

CSP-PSRIIST-Q701 I

l 1

NC L

1 TSP-CONT-R801 DESCRIPTION: SAMPLE RETURN TO DRYWELL ISO (CIV)

PSR-V-X8311 lM896 2

SO C

G 2Y TSP-CONT-R801 RW3 lTVOI,2 (13 l_A __GB__

FC lJ 1-K Q

CSP-PSR/IST-Q701 I__

I l

l I

lNC IL 1

TSP-CONT-R801 ll DESCRIPTION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X8312 M896 2

SO C

lG 2Y TSP-CONT-R801 l

lTVOI2 JI2 A

GB FC l1 Q

CSP-PSR/IST-Q701 I

I 1 Il NC lL J

TSP-CONT-R801 DESCRIPTION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X84/1 M896 2

SO C

G 2Y TSP-CONT-R801 RV03 TV01,2 H12 A

GB FC H1K Q

CSP-PSRIIST-Q701 I

l_NC lL I

TSP-CONT-R801.

DESCRIPTION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X84/2 M896 2

SO G

2Y TSP-CONT-R801 TV01,2 lHII lA lGB lFC lH1K Q

CSP-PSR/IST-Q701 I

l_

I NC IL 1

TSP-CONT-R801 DESCRIPTION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X8811 t1896 2

SO C

lG 2Y TSP-CONT-R801 RV03 TV01,2 ID13 l

A GB FC lHIK Q

CSP-PSRIIST-Q701 I

I I I 1 NC L

i TSP-CONT-R801 DESCRIPTION: SUPP POOL SAMPLE ISO (CIV)

PSR-V-X88/2 lM896 l2 lSO l

C lG 2Y TSP-CONT-R801 l

TVOI,2 lDII lA lGB lFC lHK Q

CSP-PSRIST-Q701 l

1 NC IL J

TSP-CONT-R801 DESCRIPTION: SUPP POOL SAMPLE ISO (CIV)

tIST Program Plan Columbia Generating Station Pae 105 of 18 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dvvg &

Class Valve

Failed, (CSJ/ROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

RCC-RV-34A M525-2 3

SA NA P

RV TSP-RV/IST-R701 TV03 J7 C

RV NA

.75 X 1 N C DESCRIPTION: FPC-HX-IA SHELL SIDE RV RCC-RV-34B M525-2 3

SA NA P

RV TSP-RV/IST-R701 TV03 G7 C

RV NA

.75 X 1 NC DESCRIPTION: FPC-HX-IB SHELL SIDE RV RCC-V-5 M525-1 2

MO G

2Y OSP-RCCIIST-Q702 ROJ13 TVO1,2 E4 A

GB FAI Hi RF OSP-RCC/IST-Q702 10 NO L

I TSP-CONT-R801 DESCRIPTION: RCC TO DRYWELL COOLING LOADS (IST OTBD CIV)

RCC-V-21 M525-1 2

MO C

G 2Y OSP-RCC/IST-Q702 R0113 TV01,2 D3 A

GT FAI HI RF OSP-RCC/IST-Q702 A

10 NO L

i TSP-CONT-R801 DESCRIPTION: RCC FROM DRYWELL COOLING LOADS (OTBD CIV)

RCC-V-40 lM525-1 2

M MO l

C G

2Y OSP-RCCIIST-Q702 ROJ13 TV01,2 D4 1

A GT FAI HI RF OSP-RCC/IST-Q702 I

l l

10 NO L

I TSP-CONT-R801 DESCRIPTION: RCC FROM DRYWELL COOLING LOADS (INBD CMV)

RCC-V-104 1M525-1 2

MO C

G 2Y OSP-RCCIIST-Q702 1ROJ13 TV01,2 E4 A

GT FAI IHI RF OSP-RCC/IST-Q702 l _

10 NO L

I TSP-CONT-R801 l_

l DESCRIPTION: RCC TO DRYWELL COOLING LOADS (2ND OTBD CIV)

RCC-V-129 M525-2 3

MO C

1G 2Y OSP-RCC/IST-Q701 lTV01 E6 B

GT FAI HI Q

OSP-RCC/IST-Q701 l 8 NO l

DESCRIPTION: RCC TO FPC-HX-IA & IB ISO RCC-V-130 lM525-2 3

l MO l

C 1G 2Y OSP-RCC/IST-Q701 1

lTVOI E8 B

GT I FAI HI Q

OSP-RCC/IST-Q701 l_

B 8

NO l

l l

DESCRIPTION: RCC FROM FPC-HX-IA & IB ISO RCC-V-131

[M525-2 3

MO C

1G 2Y OSP-RCCIIST-Q701 1

TV01 lE8 B

GT FAI HI Q

OSP-RCCAIST-Q701 I

I 8

-NO J l

I DESCRIPTION: RCC FROM FPC-HX-IA & IB ISO RCC-V-133A M525-2 3

SA C

H Q

OSP-FPC/IST-Q701 1J6 IC CK l

NA l

6 l

NO

__l I

DESCRIPTION: RCC TO FPC-HX-IA CHK RCC-V-133B M525-2 3

SA C

lH Q

OSP-FPC/IST-Q701 G6 C

CK NA l

6 lNO l

I DESCRIPTION: RCC TO FPC-HX-IB CHK RCC-V-219 M525 1 2

SA O/C Hx 4Y OSP-RCCIIST-R701 1 ROJ05 C4 IAC C

NA HxL I

TSP-CONT-R801 CMP-04 2

l

'h l

NC Di lOY l_

I DESCRIPTION: PRESSURE RELIEF AROUND RCC-V-40 CHK (INBD CIV)

RCIC-RD-I IN519 2

SA NA lW RD MMP-RCIC/IST-F701 10

_NC DESCRIPTION: RCIC TURBINE EXHAUST LINE RUPTURE DISC

IST Program Plan Coum i Geeatn Stto Page 106 of 181 3rd 10-Year Interval C lm a e rtngS to Revision 0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJlROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

RCIC-RD-2 M519 2

SA NA W

RD MMP-RCIC/IST-F701 C12 D

RD NA DESCRIPTION: RCIC TURBINE EXHAUST LINE RUPTURE DISC RCIC-RV-3 M519 J

2 SA NA P

RV TSP-RV/IST-R701 TVO3 D13 C

RV NA N09 I_

3/4 X I NC DESCRIPTION: RCIC PUMP DISCHARGE THERMAL RELIEF RCIC-RV-17 M519 SA NA P

RV TSP-RV/IST-R701 TV03 C13 C lRV NA N09 DESCRIPTION: RCIC PUMP SUCT RV RCIC-RV-19T M519 2

SA NA P

RV TSP-RVIST-R701 TV03 D9 C

RV NA DESCRIPTION: RCIC-P-1 DISCH TO LO COOLER RV RCIC-V-I 1M519 NA MO 1 C lG 2Y OSP-RCIC/IST-Q702 l

TV01 Ell B

GB FA3 HI Q

OSP-RCIC/IST-Q702 I _ _

3 1

N O j

DESCRIPTION: RCIC TURBINE TRIPITHROTTLE VLV (SUPPLIED AS RCIC-DT-1 SID)

RCIC-V-2 1M519 J NA HO 0

GH Q

OSP-RCICflST-Q701 N1O lE11l B lGT lFO III I I I 3 I NT III DESCRIPTION: RCIC TURBINE GOVERNOR VLV (SUPPLIED AS RCIC-DT-1 SKID)

RCIC-V-4 M519 2

AO 1 C iH.K Q

OSP-RCIC/IST-Q702 I

N07 BIO B

DI FC lG 2Y OSP-RCIC/IST-Q702 TV01 I1 NO I

I DESCRIPTION: RCIC-P-4 DISCH TO EDR ISO RCIC-V-5 1M519 1 2 AO C

[HJK Q

OSP-RCIC/IST.Q702 N07 BIO l

B lD FC 2Y OSP-RCIC/IST-Q702 ITV0I I

I I

1 I

N C I

_I__

_I_

DESCRIPTION: RCIC-P-4 DISCH TO EDR ISO RCIC-V-8 1M519 I

MO l

C G

2Y OSP-RCIC/IST-Q702 T

TVOl,2 F6 A IGTI FAI IV Q

OSP-RCICIIST-Q702 I

II4 NO L

i TSP-CONT-R801 I_

I DESCRIPTION: RCIC TURBINE STEAM SUPPLY (OTBD CIV)

RCIC-V-10 1M519 2 IMO1 C

G 2Y OSP-RCICIIST-Q702 T

TV01 B14 1 B lGT FAI IH Q

OSP-RCIC/IST-Q702 I

1 I

I_ 1 8 1 NO I

I DESCRIPTION: CST TO RCIC-P-1 SUCT RCIC-V-II 1M519 2

SA 0

H Q

OSP-RCIClIST-Q701 I

B13 1 C

CK NA I

I I_

I 8

NC I

I DESCRIPTION: CST TO RCIC-P-I SUCT CHK RCIC-V-13 M519 I

MO O/C G

2Y OSP-RCIC/IST-Q703 CS0S 01O,2 IH6 A

GT FAI HI CS OSP-RCICIIST-Q703 6

NC L

2Y TSP-RCS-R802 DESCRIPTION: RCIC TO RPV HEAD SPRAY ISO (OTBD CIV)

RCIC-V-19 1M519 2 1 MO 1 O/C G

2Y OSP-RCICIIST-Q702 TV01,2 IF7 1

A GB FAI HI Q

OSP-RCIC/IST-Q702 I

I I

2 NC L

1 TSP-CONT-R801 I

I DESCRIPTION: RCIC-P-I MINIMUM FLOW TO SUPP POOL (OTBD CIV)

l3rd 10 Year Interval Columbia Generating Station Revision 01 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJl Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMt Reliefs)

Position)

RCIC-V-21 M519 2

SA 0

Hx Q

OSP-RCIC/IST-Q701 F8 C

CK NA Nit 8Y CMP-05 2

NC DESCRIPTION: RCIC-P-I MINIMUM FLOW TO SUPP POOL CHK RCIC-V-22 M519 2

MO C

G 2Y OSP-RCICIIST-Q702 TV01 18 B

GB FAI HJ Q

OSP-RCIC/IST-Q702 DESCRIPTION: RCIC-P-1 DISCH TO CST ISO RCIC-V-25 M519 2

AO C

HJK Q

OSP-RCIC/IST-Q702 N07 E9 B

DlI FC G

2Y OSP-RCIC/IST-Q702 TV01

_ _Ii NO DESCRIPTION: RCIC TURBINE STM SUPPLY STM TRAPS TO MAIN COND ISO RCIC-V-26 M519 2

AO C

HJK Q

OSP-RCIC/IST-Q702 N07 D9 B

DI FC G

2Y OSP-RCIC/IST-Q702 TV01 1

11 NO jI DESCRIPTION: RCIC TURBINE STM SUPPLY STM TRAPS TO MAIN COND ISO RCIC-V-28 M519 2

SA O/C lHx Q

OSP-RCIC/IST-Q702 TV02 D8 AC CRK NA HxL J

TSP-CONT-R801 CMP-06 1.50 1 NC Nit 4Y DESCRIPTION: AUX COOLING TO SUPP POOL CHK (CIV)

RCIC-V-30 M519 2

[SA o

lHx 2Y OSP-RCIC/IST-B501 I ROJ12 C7 C

CK NA Hx Q

OSP-RCIC/IST-Q701 CMP-07

_ 8 [

NC Di 8Y DESCRIPTION: SUPP POOL TO RCIC-P-1 SUCT CHK RCIC-V-31 M519 2

MO O/C G

2Y OSP-RCIC/IST-Q702 lTV01,2 C7 A

GT FAI lH Q

OSF(-RCIC/IST-Q702 l

l8 NC I.

2Y TSP-CONT-B802 DESCRIPTION: SUPPRESSION POOL TO RCIC-P-I SUCT (OTBD CIV)

RCIC-V-40 M519 2 1 SA I

O/C IHx Q

OSP-RCIC/IST-Q701

[TV02 E8 J AC l

CK NA lHXL I

TSP-CONT-R801 CMP-08 l

10 lNC lNit 8Y DESCRIPTION: RCIC TURBINE EXHAUST TO SUPP POOL CHR (CIV)

RCIC-V-45 MM519 l

2 l

MO O/C lG 2Y OSP-RCIC/IST-Q702 TVOI FIl B

GB FAI HI Q

OSP-RCIC/IST-Q702 I

4 NC DESCRIPTION: RCIC TURB STM SUPPLY ISO (MAIN TURBINE TRIP IlL)

RCIC-V-46 2M519 j

B MO j O/C G

2Y OSP-RCIC/IST-Q702 TVO1 lFI lB lGB lFAI lHI Q

OSP-RCIC/IST-Q702 2

NC l

DESCRIPTION: RCIC AUXILIARY COOLING TO LO COOLER ISO RCIC-V-47 M519 2

SA O/C lHx Q

OSP-RCIC/IST-Q701 BIO C

CK NA lHx 4Y OSP-RCICIIST-Q702 CMP-09 2

NC lNit 4Y DESCRIPTION: RCIC-P-4 (CONDENSATE PUMP) DISCH CHK RCIC-V-50 M519 l2 MO C

G 2Y OSP-RCIC/IST-Q702 TVOI lF10 A

GB FAI HJ Q

OSP-RCIC/IST-Q702 l

_l_2 LO L

2Y TSP-CONT-B802 DESCRIPTION: RCIC-HX-2 CW SUPPLY ISO RCIC-V-59 M519 2

MO C

G 2Y OSP-RCIC/IST-Q702 lTV01 lJ8i l

B GT FAI HJ Q

OSP-RCIC/IST-Q702 DECIPN l6 T

NC l

DESCRIPTION: RCIC-P-I TO CSTs ISO

lIST Program Plan Columbia Generating Station Pge 108 sof 18 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

RCIC-V-63 M519 I

MO C

G 2Y OSP-RCIC/IST-Q702 TV01,2 H3 A

GT FAI HJ Q

OSP-RCIC/IST-Q702 10 NO L

I TSP-CONT-R801 DESCRIPTION: RCIC TURBINE STEAM SUPPLY TO RHR STM-COND (CIV)

RCIC-V-64 M519 I

MO C

L J

TSP-CONT-R801 TV02 G6 A

GT NA lPassive 10 LC I

DESCRIPTION: RCIC TURBINE STEAM SUPPLY TO RHR STM-COND CIV)

RCIC-V-65 M519 1

SA 1 G

2Y OSP-RCIC/IST-R701 ROJ08 H6 C

CK NA H

RF OSP-RCIC/IST-R701 6

NC DESCRIPTION: RCIC-P-1 DISCH TO RPV HEAD SPRAY CHK RCIC-V-66 M519 1

SA O/C H

RF OSP-RCICIIST-R701 ROJO8 TV02 J4 AC CK NA HL RF TSP-RCS-R803 1

6 NCl DESCRIPTION: RCIC TO RPV HEAD SPRAY CHK (INBD CIV)

RCIC-V-68 M519 2

MO C

G 2Y OSP-RCIC/IST-Q702 TV01,2 E7 A

GT FAI l H Q

OSP-RCIC/IST-Q702 10 NO L

J TSP-CONT-R801 DESCRIPTION: RCIC TURBINE EXHAUST TO SUPP POOL (OTBD CIV)

RCIC-V-69 M519 2

IMO C

1G 2Y OSP-RCICIIST-Q702 l

fTVO,2 D7 l

A lGTl FAI HJ Q

OSP-RCICIIST-Q702 l

1.50 NO lL i

TSP-CONT-R801 DESCRIPTION: RCIC VACUUM PUMP TO SUPP POOL (OTBD CIV)

RCIC-V-76 1M519 1

M NO C

G 2Y OSP-RCICIIST-Q702 TV0I,2 lEI3 T

A GB FAI HJ Q

OSP-RCICIIST-Q702 I

l NC L

J TSP-CONT-R801 DESCRIPTION: RCIC-V-63 BYPASS (INBD CIV)

RCIC-V-90 lM519 l

2 lSA I_

C lH Q

OSP-RCIC/IST-Q701 ji lH7 lC lCK lNA l

I 6

l NC IlI DESCRIPTION: RCIC DISCHARGE HEADER CHK RCIC-V-110 MI 9 2

2Y OSP-RCICIIST-Q702 Passive lE7 lB lGTlFA l

DESCRIPTION: RCIC TURB EXH TO SUPP POOL VAC REL ISO RCIC-V-111 1M519 T

2 SA O/C lHx 4Y OSP-RCIC/IST-Q702 NW lE7 C J CK NA

]Di 1oY CMP-I I 2

NCIII DESCRIPTION: RCIC TURBINE EXHAUST VACUUM BREAKER ISO RCIC-V-12 1MS19 T 2 SA O/C 1H 4Y OSP-RCICIST-Q702 N04 E7 C

CK NA Di 10Y CMP-I_

I_

I 2

NC III DESCRIPTION: RCIC TURBINE EXHAUST VACUUM BREAKER ISO RCIC-V-113 1M519 2

r MO NA 1G 2Y OSP-RCIC/IST-Q702 Passive lE7 B

GT FAI l

I 2 INO DESCRIPTION: RCIC TURB EXH TO SUPP POOL VAC REL ISO RCIC-V-2W iMSI9 2 l SA l

O/C lHX Q

OSP-RCICIIST-Q701 B14 C

J CKI NA Hx 4Y OSP-RCICIIST-Q702 CMP-12 J

8 l

NC Di 8Y DESCRIPTION: RCIC PUMP SUCT FROM CST CHK

IIST PrOgram Plan Coum i Geeatn Stto Page 109 of Is I l3rd 1O-Year InterVal C

1 m

aGe rtngS tlnRevision 0

K)J Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

RCIC-V-742 M519 1

MA C

L 2Y TSP-RCS-R802 TV02 J6 A

GB NA Passive 0.75 LC DESCRIPTION: SAMPLE PROBE 19B MAN ISO (CIV)

REA-V-1 M545-3 3

AO C

G 2Y OSP-CONT/IST-Q702 TV01 Hi B

BF FC HJK Q

OSP-CONT/IST-Q702 72 NO DESCRIPTION: REACTOR BUILDING EXHAUST REA-V-2 M545-3 3

AO C

G 2Y OSP-CONTIIST-Q702 TV01 H1 B

BF FC H1K Q

OSP-CONT/IST-Q702 72 NO DESCRIPTION: REACTOR BUILDING EXHAUST RFWV-V-IOA M529 l1 SA C

H RF OSP-RFW/IST-Q701 ROJO6 TV02 G12 AC CR NA HL 2Y TSP-CONT-R801 24 NO DESCRIPTION: RFW TO VCHK (IND CIV)

RFW-V-IOB M529 I

SA C

H RF OSP-RFW/IST-Q701 ROJ06 TV02 G5 AC CR NA HL 2Y TSP-CONT-R801 1

24 I

NO DESCRIPTION: RFW TO RPV CHK (INBD CIV)

RFIV-V-32A M529 T 1 I AOSA C

H RF OSP-RFW/IST-Q701 ROJ06 N02 K

G13 AC l CK NA HL 2Y TSP-CONT-R801 TV02 I

24 NO I

DESCRIPTION: RFW TO RPV CHK (I ST OTBD CIV)

RFW-V-32B M529 1 1 l AO,SA l C

H RF OSP-RFWIIST.Q701 ROJO6 N02 G5 AC CK NA HL 2Y TSP-CONT-R801 TV02 24 NO DESCRIPTION: RFW TO RPV CHK (1ST OTBD CIV)

RFW-V-65A M529 1

MO C

G 2Y OSP-RFWIIST-Q701 CSJO2 TV01,2 G13 A

lGT FAI I1 CS OSP-RFW/IST-Q701 l

24 NO L

2Y TSP-CONT-R801 DESCRIPTION: RFWV TO RPV ISO (2ND OTBD CI RFW-V-65B 1M529 1 I MO C

G 2Y OSP-RFV/IST-Q701 CSJO2 TVO0,2 lG4 1

A GT FAI HI CS OSP-RFWIIST-Q701 24 NO L

2Y TSP-CONT-R801 DESCRIPTION: RFW TO RPV ISO (2ND OTBD CIV)

RHR-FCV-64A M521-1 2 1 MO T o/C G

2Y OSP-RHRIIST-Q702 l

TVOI,2 B12 1 A

GB FAI HJ Q

OSP-RHRIIST-Q702 l

l 3

NO L

i TSP-CONT-R801 DESCRIPTION: RHR-P-2A MINIMUM FCV (CIV)

RHR-FCV-64B M521.2 2 1 MO 0/C G

2Y OSP-RHRIIST-Q703 T

TVO0,2 lB5 A

GB l

FAI lH Q

OSP-RHR/IST-Q703 l

l 3

NO L

I TSP-CONT-R801 l

I DESCRIPTION: RHR-P-2B MINIMUM FCV (CIVIV RHR-FCV-64C M521-3 2

MO I O/C G

2Y OSP-RHR/IST-Q704 1TV01,2 E4 1 A GB FAI ID Q

OSP-RHRIIST-Q704 l

1 3

NO L

I TSP-CONT-R801 DESCRIPTION: RHR-P-2C MINIMUM FCV (CIV)

RHR-RV-IA 1M521-1 2 1 SA NA P

RV TSP-RV/IST-R701 lTV023 U

HI3 lAC lRV lNA IL J

TSP-CONT-C801 I.75XX NC

__I

_I DESCRIPTION: RHR-HX-1A SHELL SIDE RV (CIV)

13rd 10-Year Interval Columbia Generating Station Revision 0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

RHR-RV-IB M521-2 2

SA NA P

RV TSP-RV/IST-R701 TV02,3 HS AC RV NA L

J TSP-CONT-C80I

.75 X I NC DESCRIPTION: RHR-HX-IB SHELL SIDE RV (CIV)

RHR-RV-5 M521-1 2

SA NA P

RV TSP-RVIIST-R701 TV02,3 C8 AC RV NA L

J TSP-CONT-C801 N09 I X2 NC DESCRIPTION: RHR SHUTDOWN COOLING SUCT RV ICIV)

RHR-RV-25A M521-l1 2 T SA NA P

RV TSP-RV/IST-R701 TV02,3 Dl0 AC J RV NA L

J TSP-CONT-C801 -

N09 IIX2 NC DESCRIPTION: RHR LOOP A TEST LINE RV (CIV)

RHR-RV-25B M521-2 l

2 SA NA P

RV TSP-RV/IST-R701 TV02,3 C

I AC RV NA L

i TSP-CONT-C801 N09 II X2 NC DESCRIPTION: RHR LOOP B TEST LINE RV CIV)

RHR-RV-25C M521-3 2

SA NA P

RV TSP-RV/IST-R701 l

TV02,3 E8 AC RV NA L

I TSP-CONT-C801

[

N09 I X2-NC III DESCRIPTION: RHR LOOP C TEST LINE RV (CIV)

RHR-RV-30 1M521-2 2

SA NA P

RV TSP-RV/IST-R701 l

TV02,3 D8 AC I NA L

I TSP-CONT-C801 N09 I

I I.75 X I I NC lII DESCRIPTION: RHR FLUSH LINE RV C RHR-RV-88A M521-1 SA NA P

RV TSP-RV/IST-R701 l

TV02,3 IC7 I AC RV NA L

1 TSP-CONT-C801 IN09 I

I I.75 X I I NC III DESCRIPTION: RHR-P-2A SUCT RV CV RHR-RV-88B M521-2 1

2 1 SA I NA P

RV TSP-RV/IST-R701 I

TV02,3 B9 AC J RV NC lL J

TSP-CONT-C801 N09 I

.75 X I C III DESCRIPTION: RHR-P-2B SUCT RV (CIV)

RHR-RV-88C M521-3 1 2 1SA NA P

RV TSP-RVIIST-R701 l

TV02,3 D8 AC IRV NA L

i TSP-CONT-C801 N09 I

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

RHR-V-3A 1M521-I1 2

1 MO O/C G

2Y OSP-RHR/IST-Q702 TVOI lHI0 1 B IGT FAI HI Q

OSP-RHRnST-Q702 I

I__I_

18 I

NO I

I DESCRIPTION: RHR-HX-1A OUTLET ISO RHR-V-3B 1M521-2 2

1 MO O/C lG 2Y OSP-RHR/IST-Q703 l

TVOI 19 l

B GT I FAI HJ Q

OSP-RHRJIST-Q703 I

I I

I Is NO I

I I

DESCRIPTION: RHR-HX-IB OUTLET ISO RHR-V-4A 1M521-1 2

MO l

O/C G

2Y OSP-RHR/IST-Q702 7

TVo0,2 C7 A 1 GT FAI HI Q

OSP-RHRfIST-Q702 I

I I

I 24 NO L

2Y TSP-CONT-B802 I

DESCRIPTION: SUPPRESSION POOL TO RHR-P-2A SUCT (OTBD C__)

RHR-V-4B 1M521-2 2

1 MO l

O/C G

2Y OSP-RHRIIST-Q703 lTV01,2 IBII 1 A

IGT FAI HI Q

OSP-RHR/IST-Q703 I

I I

I 1 24 NO L

2Y TSP-CONT-B802 I

I DESCRIPTION: SUPPRESSION POOL TO RHR-P-2B SUCT (OTBD CIV)

IST Program Plan Coum i Geeatn Stto Page III of 181 l3rd 10-Year Interval Co~baG~eall ttOlRevision 0

K>J Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

RHR-V-4C M521-3 2

MO O/C G

2Y OSP-RHR/IST-Q704 TV01,2 Bll A

GT FAI HJ Q

OSP-RHR/IST-Q704 24 NO L

2Y TSP-CONT-B802 DESCRIPTION: SUPPRESSION POOL TO RHR-P-2C SUCT (OTBD CIV)

RHR-V-6A M521-1 2

MO O/C G

2Y OSP-RHR/lST-Q702 TV01 B8 B

GT FAI HJ Q

OSP-RHRIIST-Q702 18 NC DESCRIPTION: RPV TO RHR-P-2A SUCT (SDC MODE)

RHR-V-6B M521-1 2

MO O/C G

2Y OSP-RHR/IST-Q703 TV01 B7 B

GT FAI HJ Q

OSP-RHRIIST-Q703 18 NC DESCRIPTION: RPV TO RHR-P-2B SUCT (SDC MODE)

RHR-V-8 M521-1 1

MO OIC G

2Y OSP-RHR/IST-R704 ROJI0 TV01,2 E6 A

GT FAI HI RF OSP-RHR/IST-R704 20 NC L

2Y TSP-RCS-R802 DESCRIPTION: RHR SDC MODE SUPPLY FOR A & B FROM RPV (OTBD CIV)

RHR-V-9 lM521-1I 1I MO OIC G

2Y OSP-RHRJST-R704 lROJI0 TV01.2 ID5 A

GT FAI HI RF OSP-RHR/IST-R704 20 I

2 20 NC L

2Y TSP-RCS-R802 DESCRIPTION: RHR SDC MODE SUPPLY FOR A & B FROM RPV (INBD CIV)

RHR-V-11IA lM521-1 T2 IMO 1 C

lL J

TSP-CONT-R801 I

TV02 K>

IEl [ A f C

I Passive II I

4 I LC III DESCRIPTION: RHR STM-COND TO SUPP POOL ISO (CIV)

RHR-V-11B

[M521 2 l

2 MO j CL J

TSP-CONT-R801 TV02 ICil l l A I GT I

A lllPassive II I 4 I LC III DESCRIPTION: RHR B STM-COND TO SUPP POOL ISO (CIV)

RHR-V-16A

[M521-1

[

2 MO o/C 1G 2Y OSP-RHRIIST-Q705 1CS112 lTVOI,2 IH7 IA IGT IFAI HIH CS OSP-RHR/IST-Q705 II A 116 NC IL I

TSP-CONT-R801 I

I DESCRIPTION: RHR TO DRYWELL SPRAY HEADER (2ND OTBD CIV)

RHR-V-16B

[M521-2 2

MO I

O/C G

2Y OSP-RHR/IST-Q706 CSJI2 TVO1,2 lDII A

GT'I FAI HJ CS OSP-RHR/IST-Q706 I

I I

I 16 NC IL i

TSP-CONT-R801 I

I DESCRIPTION: RHR TO DRYWELL SPRAY HEADER (2ND OTBD CIV)

RHR-V-17A lM521-1 2

MO O/C G

2Y OSP-RHR/IST-Q705 lCSJ12 TV01,2 H6 A

GT FAI HJ CS OSP-RHR/IST-Q705 I

l l

16 NC L

i TSP-CONT-R801 I

T DESCRIPTION: RHR TO DRYWELL SPRAY HEADER (IST OTBD CIV)

RHR-V-17B M521-2 2

MO I

O/C lG 2Y OSP-RHRIIST-Q706 tCSJl2 TV01,2 DII A I GT I FAI lHJ CS OSP-RHRfIST-Q706 I _ I I

I I16 INC IL J

TSP-CONT-R801 II DESCRIPTION: RHR TO DRYWELL SPRAY HEADER (1ST OTBD CNV)

RHR-V-21 M521-3 2

MO C

1G 2Y OSP-RHR/IST-Q704 I

TVI01,2 E7 A

GB FAI J

Q OSP-RHR/1ST-Q704I II

_I_

18 NC lL J

TSP-CONT-R801

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

RHR-V-23 M521-2 I

MOI C

G 2Y OSP-RHR/IST-Q706 lCSJ01 TV01,2 RIKI3 A

AI GB I FIHJ CS OSP-RHRIST-Q706 I

I DSI IR6 T

NC IL 2Y TSP-RCS-RB02 DESCRIPTION: RHR TO RCIC RPV HEAD SPRAY (OTBD CMV

IST Program Plan Coum i Geeatn Stto Page 112 of 1811 l3rd 10-Year Interval C lm a e rtngS to Revision ol Valve Test Tables Tipe Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM%

Reliefs)

Position)

RHR-V-24A M521-1 2

MO O/C G

2Y OSP-RHR/IST-Q702 TVOI,2 E9 A

GB FAT HJ Q

OSP-RHR/IST-Q702 18 NC L

J TSP-CONT-R801 DESCRIPTION: RHR LOOP A TEST LINE TO SUPP POOL (OTBD CIV)

RHR-V-24B M521-2 2

MO O/C G

2Y OSP-RHR/IST-Q703 TV01,2 C1 A

GB FAT HJ Q

OSP-RHR/IST-Q703 I

18 NC L

3 TSP-CONT-R801 I

DESCRIPTION: RHR LOOP B TEST LUNE TO SUPP POOL (OTBD CIV)

RHR-V-27A M521-1 2

MO O/C G

2Y OSP-RHR/IST-Q702 TVO1,2 D7 A

GT FAT HJ Q

OSP-RHR/1ST-Q702 6

NC L

J TSP-CONT-R801 DESCRIPTION: RHR TO SUPPRESSION CHAMBER SPRAY HEADER (OTBD CIV)

RHR-V-27B 1M521-2 2

MO O/C G

2Y OSP-RHRIIST-Q703 TV01,2 CI0 A

GT FAT HJ Q

OSP-RHR/IST-Q703 6

NC L

I TSP-CONT-R801 DESCRIPTION: RHR TO SUPPRESSION CHAMBER SPRAY HEADER (OTBD CIV)

RHR-V-31A M521-1 2

SA H

Q OSP-RHR/IST-Q702 I

C14 C

CK I NA I

18 I

NC I

I I

DESCRIPTION: RHR-P-2A DISCH CHK RHR-V-31B lM521-2 ( 2 f SA J O/C IH Q OSP-RHRIIST-Q703 I

lC3 C

CK lINA I

I I I I

18 NC I

I I

DESCRIPTION: RHR-P-2B DISCH CHK RHR-V-31C M521-3 2

SA I

O/C IH Q

OSP-RHR/IST-Q704 t

I lC3 IC ICK INA III I

I 18 I NC III DESCRIPTION: RHR-P-2C DISCH CHK RHR-V-40 M521-2 l

2 MO T C

lG 2Y OSP-RHR/IST-Q703 TV01 G4 B l GB FAT lHJ Q

OSP-RHR/IST-Q703 I

I I 4 I NC III DESCRIPTION: RHR LOOP B TO EDR (SDC WARMUP LINE) ISO RHR-V-41A M521-1 I

1 SA O/C lH RF OSP-RHR/IST-R701 lROJ08 TV02 G5 1 AC CK I

NA HL RF TSP-RCS-R801 I I

_ 1 14 I

NC I

I I

DESCRIPTION: RHR A LPCI TO RPV CHK (INBD CIV)

RHR-V-41B M521-2 I 1 l

SA T 0/C lH

-RF OSP-RHR/IST-R702 lROJO8 TV02 G13 1 AC I

CK NA HL RF TSP-RCS-R802 1 4 DESCRIPTION: RHR B LPCI TO RPV (INBD CIV)

RHR-V-41C M521-3 I

SA 1 0/C lH RF OSP-RHR/IST-R703 lROJ08 TV02 E13 1 AC CK NA HL RF TSP-RCS-R802 I

1 I

_ 1 14 I

NC I I

DESCRIPTION: RHR C LPCI TO RPV (INBD CIV)

RHR-V-42A M521-1 I

l MO O/C G

2Y OSP-RHR/IST-Q705 lCSJO6 lTV0,2 G7 A

I GT FAT lH CS OSP-RHR/IST-Q705 I

I I I

14 I

NC IL 2Y TSP-RCS-R801 DESCRIPTION: RHR A LPCI MODE TO RPV (OTBD CIV)

RHR-V-42B M521-2 1I MO OIC lG 2Y OSP-RHR/IST-Q706

[CSJ06 TVOI,2 G12 A

GT FAT IHI CS OSP-RHRJIST-Q706

]

DSIP14 TONC RL 2Y TSP-RCS-R802 M

T DESCRIPTION: RHR B LPCI MOD TO RPV (OTBD CIV)

3rd 10-Year Interval Cou baG nrtn tto aeRe~visifon 0

_Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

RHR-V-42C M521-3 I

MO O/C G

2Y OSP-RHRfIST-Q707 CSJ06 TV01,2 Ell A

GT FAI HJ CS OSP-RHR/IST-Q707

_ 14 NC L

2Y TSP-RCS-R802 DESCRIPTION: RHR B LPCI MODE TO RPV (OTBD CIV)

RHR-V-48A 1M521-1 2

MO 0/C G

2Y OSP-RHR/IST-Q702 TV01 Jll B

GB FA Q

OSP-RHR/IST-Q702 DESCRIPTION: RHR-HX-1A BYPASS RHR-V-48B 1M521-2 2

MO O/C G

2Y OSP-RHR/IST-Q703 TV01

/KS B

GB FAI HI Q

OSP-RIHR/IST-Q703 18 NO DESCRIPTION: RHR-HX-IB BYPASS RHR-V-49 M521-2 2

MC0 C

G 2Y OSP-RHRIIST-Q703 1TV01 G4 B

GT FAI HJ Q

OSP-RHRIIST-Q703 I

4 NCI DESCRIPTION: RHR LOOP B TO EDR (SDC WARMUP LINE) ISO RHR-V-50A iM521-1 I

SA O/C H

RF OSP-RHR/IST-R701 iR0108 TV02 IE5 AC I CK I NA lHL RF TSP-RCS-R801 I

I I

_12 NC I

I DESCRIPTION: RHR A SDC TO RPV CHK (INBD CIV)

RHR-V-50B M521-2 I

SA O/C H

RF OSP-RHR/IST-R702 lROJO8 TV02 F13 AC CK NA HL RF TSP-RCS-R802 12 NC___

DESCRIPTION: RHR B SDC TO RPV (INBD CM RHR-V-53A M521-1 I

MO O/C G

2Y OSP-RHR/IST-Q705 lCSJ01 TV01,2 E6 GT FAI HJ CS OSP-RHR/IST-Q705 I I I_ 12 NC

'L 2Y TSP-RCS-R801 DESCRIPTION: RHR A SDC MODE TO RPV (OTBD CIV)

RHR-V-53B M521-2 I

MO O/C G

2Y OSP-RHRJIST-Q706 lCS101 TV01,2 Fli A

GT FAI IHI CS OSP-RHR/IST-Q706 I

12 NC lL 2Y TSP-RCS-R802 I

I DESCRIPTION: RHR B SDC MODE TO RPV (OTBD CIV)

RHR-V-60A lM521-1 I 2 I SO J C

G 2Y OSP-RHRIST-Q702 TV01 GIGI l

B f SV j FC lHJK Q

OSP-RHRJIST-Q702 I

I 0.75 I NC III DESCRIPTION: RHR A SAMPLE PROBE 22A ISO RHR-V-60B lM521-2 32 s O I C

jG 2Y OSP-RHR/IST-Q703 TV01 H9 B

SV FC lJK Q

OSP-RHR/IST-Q703 I

I I__0.75 NC I

_II DESCRIPTION: RHR B SAMPLE PROBE 22B ISO RHR-V-68A M524-1 3

MO 0

IG 2Y OSP-SW/IST-Q701 TV01 E14 B

GT FAI HJ Q

OSP-SW/IST-Q701 I

I I

16 NO II DESCRIPTION: SW FROM RHR-HX-IA ISO RHR-V-68B iM524-2 3

MO l

G 2Y OSP-SW/ST-Q702 TV01 lGI4 IB IGT IFAI I HJ Q

OSP-SWIIST-Q702 II II I

16 I NO III DESCRIPTION: SW B FROM RHR-HX-1B ISO RHR-V-73A lM521-1 2 lMO lC lG 2Y OSP-RHR/IST-Q702 l

TV01 2 lHI4 A

GB I FAI lHI Q

OSP-RHR/IST-Q702 I T I

I I

2 NC IL i

TSP-CONT-R801 I

I DESCRIPTION: RHR-IHX-IA SHELL SIDE VENT (OTBD CIV)

IST Program Plan Coum i Geeatn Stto Page 114 of 181 3rd 10-Year Interval C lm a e rtngS to RevisionO0 Valve Test Tables Te Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJI Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

RHR-V-73B M521-2 2

MO C

G 2Y OSP-RHR/IST-Q703 TVOI,2 H4 A

GB FAI Hi Q

OSP-RHR/IST-Q703 2

NC L

i TSP-CONT-R801 DESCRIPTION: RHR-HX-IB SHELL SIDE VENT (OTBD CIV)

RHR-V-75A M521-1 C

G 2Y OSP-RHR/IST-Q702 TV0I Gl l B2 FC HJK Q

OSP-RHRfIST-Q702 I

0.7S5 C

DESCRIPTION: RHR A SAMPLE PROBE 22A ISO RHR-V-75B M521-2 2

SO C

G 2Y OSP-RHR/IST-Q703 TVo1 H8 B

SV FC HJK Q

OSP-RHR/IST-Q703 0.75 NC DESCRIPTION: RHR B SAMPLE PROBE 22B ISO RHR-V-84A

[M521-1 2

SA C

Hx Q

OSP-RHR/IST-Q702 N01 D15 C

CK NA Hx 12M OSP-RHR-A701 CMP-22 l

1.50 NC DESCRIPTION: LPCS-P-2 (WATER LEG) TO RHR A CHK RHR-V-84B M521-2 2

SA C

lHX Q

OSP-RHR/IST-Q703 N01 B4 C

CK NA Hx 12M OSP-RHR-A702 I

CMP-22 1 1.50IN I

NC DESCRIPTION: RHR-P-3 ATER LEG DISCH TO RHR B CHK RHR-V-84C M521-3 2

l SA C

lHx Q

OSP-RHR/IST-Q704

[

NOI C5 C

CK NA Hx 12M OSP-RHR-A704 CMP-22 I

I I 1.50 NC I

DESCRIPTION: RHR-P-3 (WATER LEG) DISCH TO RHR C CHK RHR-V-85A M521-1 2

SA C

HX Q

OSP-RHR/IST-Q702 N01 D14 C

SC NA Hx 12M OSP-RHR-A701 I

CMP-22 I

I _

_I 1.50IN I INC DESCRIPTION: LPCS-P-2 (WATER LEG) TO RHR A STOP CHK RHR-V-85B M521-2 2

l SA I C lHx Q

OSP-RHR/IST-Q703

[

N01 B3 j

C I SC j NA lHx 12M OSP-RHR-A702 I

CMP-22 II I 1.50 I NC III DESCRIPTION: RHR-P-3 3 ATER LEG) DISCH TO RHR B STOP CHK RHR-V-85C M521-3 2

SA C

Hx Q

OSP-RHR/IST-Q704 N01 lC4 l

C T SC l

NA lHx 12M OSP-RHR-A704 I

I CMP-22 I

I 1 1.50 I NC DESCRIPTION: RHR-P-3 (WATER LEG) DISCH TO RHR C STOP CHK RHR-V-120 M521-1 j 2

MA C

L 1

TSP-CONT-R801 j

lTV02 lCII A lGT lNA l Passive II I

3 I LC III DESCRIPTION: RHR A TO FDR SYS MAN ISO (CIV)

RHR-V-121 M521-1 2

l L

i TSP-CONT-R801 l

TV02 CHI A J GT l

NA l

l Passive III 3

I C III DESCRIPTION: RHR A TO FDR SYS MAN ISO (CIV)

RHR-V-123A M521-1 l

MO C

G 2Y OSP-RHR/IST-R704 ROJII lTVOI,2 E5 A

GT FAI HJ RF OSP-RHR/IST-R704 I

I III NC lL 2Y TSP-RCS-R801II DESCRIPTION: RHR-V-50A BYPASS INBD CIV) (MOTOR DEENERGIZED)

RHR-V-123B M521-2 MO C

G 2Y OSP-RHR/IST-R704 ROill lTV01,2 EI3 1A IGT FAI HI RF OSP-RHR/IST-R704 II DSIPION:

I NC IL 2Y TSP-RCS-R802GIED DESRPTION: RHR-V-50B BYPASS INBD CIV) (MOTOR DEENERGIZED)

IST Program Plan Columbia Generating Station Paevisi of O8 Valve Test Tables T.pe Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

RHR-V-124A M521-1 2

MO C

L i

TSP-CONT-R801 TV02 C14 A

GB NA Passive 1.50 LC DESCRIPTION: RHR STM-COND DRN TO SUPP POOL (CIV)

RHR-V-124B M521-1 2

MO C

L J

TSP-CONT-R801 TV02 C12 A

GB NA Passive I

1.50 LC DESCRIPTION: RHR STM-COND DRN TO SUPP POOL (CIV)

RHR-V-125A M5214 2

MO C

L i

TSP-CONT-R801 TV02 E5 A

GB NA l-Passive 1.50 LC I

DESCRIPTION: RHR STM-COND DRN TO SUPP POOL (CIV)

RHR-V-125B M521-4 2

MO C

L i

TSP-CONT-R801 TV02 E4 A

GB NA Passive 1.50 LC DESCRIPTION: RHR STM-COND DRN TO SUPP POOL (CIV)

RHR-V-134A M521-1 2

MO I C

L J

TSP-CONT-R801 N13 E14 A

GB FAI TV02 E1 2 I LC

_lPassive DESCRIPTION: CAC TIE TO RHR (OTBD CI RHR-V-134B M521-2 2

MO I

C L

J TSP-CONT-R801 N13 lE6 A

GB FAI TV02 I I I 21 LC I

.Passive DESCRIPTION: CAC TIE TO RHR (OTBD CIV)

RHR-V-209 M521-1 I

SA O/C HX 4Y OSP-RHR/IST-R701 ROJ03 N04 DS

]AC I

CK I

NA HxL 2Y TSP-RCS-R802 TV02 CMP-18 I

I I0.75 INCIII DESCRIPTION: THERMAL RELIEF CHK BETWEEN RHR-V-8 AND 9 (CIV)

RHR-V-503 M21-l 2

ISA C

lHx 4Y OSP-RHRJIST-Q702 SA C

CK NA Di 1oY CMP-10 I

I I 0.50 I

NC I

I I

DESCRIPTION: RHR-V-6A LEAK BY-PASS CHK ROA-V-1 M545-3 3

AO C

G 2Y OSP-CONTnIST-Q702 lTV01 DI B

BF FC HIK Q

OSP-CONT/IST-Q702 II I

I I

84 NO I

II DESCRIPTION: REACTOR BUILDING ISO ROA-V-2 M545-3 3 1 AO l

C G

2Y OSP-CONT/IST-Q702 1

lTV01 D2 1 B

BF FC lHJK Q

OSP-CONT/IST-Q702 I

I 1

I

_ 184 NO I

I DESCRIPTION: REACTOR BUILDING ISO RRC-V-13A 1M530-1 2

SA C

HX 4Y OSP-RRC/IST-Q702 RoJ14 TV02 lC13 l_AC l

CK NA HxL I

TSP-CONT-R801 CMP-15 I

-5INO lNit SYII DESCRIPTION: RRC PUMP SEAL PURGE INLET CHK (INBD CIV)

RRC-V-13B 1M530-l 1 2 1 SA C

HX 4Y OSP-RRC/IST-Q702 ROJI4 TV02 BI3 AC CK NA HxL i

TSP-CONT-R801 CMP-15 I

I I 0.75 NO Nit 8Y DESCRIPTION: RRC PUMP SEAL PURGE INLET CHK (INBD CM)

RRC-V-16A M530-1 2 1 MO C

G 2Y OSP-RRC/IST-Q702 0RJI4 TVOI,2 C14 A

GT FAI HJ RF OSP-RRC/IST-Q702 0.75 NO L

I TSP-CONT-R801 DESCRIPTION: RRC PUMP SEAL PURGE INLET (OTBD CIV)

IST Program Plan Page 116 of 181 3rd 10-Year Interval Columbia Generating Station Revision O Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

RRC-V-16B M530-l 2

MO C

G 2Y OSP-RRC/IST-Q702 ROJ14 TV01,2 B14 A

GT FAI HI RF OSP-RRC/IST-Q702 0.75 NO L

i TSP-CONT-R801 DESCRIPTION: RRC PUMP SEAL PURGE INLET (OTBD CIV)

RRC-V-19 M530-1 1

SO C

G 2Y OSP-RRC/IST-Q701 TV01,2 F1l lAF I GB FC HJK Q

OSP-RRC/IST-Q701 I 1 NO L

J TSP-CONT-R801 DESCRIPTION: RRC SAMPLE PROBE 1 ISO (CM RRC-V-20 M530-1 so C

G 2Y OSP-RRCIIST-Q701 TV01,2 F12 A

GB FC HJK Q

OSP-RRC/IST-Q701 I

NO L

J TSP-CONT-R801 DESCRIPTION: RRC SAMPLE PROBE I ISO (CIV)

RWCU-V-1 M523-1 I

MO C

G 2Y OSP-RWCU/IST-Q701 CSJ07 TV01,2 F14 A

GT FAI HJ CS OSP-RWCU/IST-Q701 6

NO L

C TSP-CONT-R801 DESCRIPTION: RWCU FROM RPV ISO (INBD CIV)

RWCU-V-4 M523-1 1

l MO 1 C G

2Y OSP-RWCU/IST-Q701 ICSJO7 TV01,2 E15 A __GT _j FAI _HJ CS OSP-RWCUIST-Q701 I I

I I 6 INO IL J

TSP-CONT-R801 II DESCRIPTION: RWCU FROM RPV ISO (OTBD CIV)

RWCU-V-40 M523-1 I

MO 1 C lG 2Y OSP-RWCU/IST-Q701 lCSJ07 TV01,2 lHI0 J A GT l

FAI HU CS OSP-RWCU/IST-Q701 I

I _____

6 NO IL 2Y TSP-CONT-R801 I

I DESCRIPTION: RWCU TO RFW ISO (OTBD CIV)

SA-V-109 M510-3 2

MA 1 C lL i

TSP-CONT-R801 TV02 H8 A

GB NA l

Passive I

I I

2 LC III DESCRIPTION: AIR LINE ISO USED FOR MAINT (CAPPED IN DW) (CIV)

SGT-V-IA M544 l

2 l

MO C

lG 2Y OSP-SGT/IST-Q701 I

TV01 G14 B

BF FAI IT Q

OSP-SGTIIST-Q701 I

I I

18 I

NC I

I I

DESCRIPTION: SGT INLET SGT-V-IB M544 l

2 l

MO 1 C IG 2Y OSP-SGT/IST-Q702 ITV01 E14 j

B BF FAI T HJ Q

OSP-SGT/IST-Q702 I

I I

I I_ 18 I NC I

I I

DESCRIPTION: SGT INLET SGT-V-2A M544 3

l AO 1 0 lG 2Y OSP-SGT/IST-Q701 TV01 HI4 B

BF FO lHJK Q

OSP-SGT/IST-Q701 I I I

18 1 NO III DESCRIPTION: SGT-FU-IA INLET SGT-V-2B M544 3 1 AO I

0 lG 2Y OSP-SGT/IST-Q702 TV01 D14 B

BF l

FO H11K Q

OSP-SGT/IST-Q702 I

I I I

_ 1 18 NO I

I I

DESCRIPTION: SGT-FU-IB INLET SGT-V-3A1 M544 l

2 l

MO l

0 lG 2Y OSP-SGT/IST-Q701 TV01 G7 B

BF l

FAI HJ Q

OSP-SGT/IST-Q701 I I I18 NO DESCRIPTION: SGT-FN-IA1 DISCH SGT-V-3A2 M544 2

MO O/C G

2Y OSP-SGT/IST-Q701 TV01 J7 B

BF FAI lH Q

OSP-SGT/IST-Q701 I

I I I

18 I NO 1

1 DESCRIPTION: SGT-FN-IAI DISCH

3rd 10-YearlInterval C lm i Ge rangS tonRevisionC0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

SGT-V-3BI M544 2

MO OIC G

2Y OSP-SGT/IST-Q702 TV01 E7 B

BF FAX HI Q

OSP-SGT/IST-Q702 18 N O DESCRIPTION: SGT-FN-IAI DISCH SGT-V-3B2 M544 2

MO 0

G 2Y OSP-SGT/IST-Q702 TV01 C7 B

BF FAX!

Hi Q

OSP-SGT/IST-Q702 DESCRIPTION: SGT-FN-IAI DISCH SGT-V-4AI M544 2 1 MO O/C G

2Y OSP-SGT/IST-Q701 TV01 J5 B

BF FjAXI Hi Q

OSP-SGT/IST-Q701 DESCRIPTION: SGT-FN-IAI DISCH SGT-V-4A2 M544 2

MO 0O/C G

2Y OSP-SGT/IST-Q701 TV01 G5 B

BF FAX Hi Q

OSP-SGT/IST-Q701

_ 1 1 8i I N C I _

I _

_ I DESCRIPTION: SGT-FN-IA2 DISCH SGT-V-4B1 M544 2

MO 7

O/C 1G 2Y OSP-SGT/IST-Q702 lTVO1 C5 lB BF FAI jlW1 Q

OSP-SGT/IST-Q702 DESCRIPTION: SGT-FN-IBI DISCH SGT-V-4B2 M544 l

2 MO l

O/C 1G 2Y OSP-SGT/IST-Q702 lTVOI D5 B

BF FAX jH Q

OSP-SGT/IST-Q702 DESCRIPTION: SGT-FN-IB2 DISCH SGT-V-5AI M544 2

MO O/C 1G 2Y OSP-SGT/IST-Q70I l

lTVOI l5 l

BB F

j FAX j}U Q

OSP-SGT/IST-Q701 DESCRIPTION: SGT-FN-IAI OUTLET SGT-V-5A2 M544 2

MO j O/C lG 2Y OSP-SGT/IST-Q701 TVOI

[G5 lB lBF lFAX l}U Q

OSP-SGT/IST-Q701 DESCRIPTION: SGT-FN-IA2 OUTLET SGT-V-5BI M544

[ 2 MO l

O/C 1G 2Y OSP-SGT/IST-Q702 l

TVOI C5

[ B BF j

FAX jH Q

OSP-SGT/IST-Q702 DESCRIPTION: SGT-FN-IBI OUTLET SGT-V-5B2 M544 l

2 [ MO O/C 1G 2Y OSP-SGT/IST-Q702 TVOI E5 B

BF lFAX lJ Q

OSP-SGT/IST-Q702 DESCRIPTION: SGT-FN-IB2 OUTLET SLC-RV-29A M522 l

2 SA l

NA P

RV TSP-RV/IST-R701 l

1TV03 F6 C

RV NA l

IX2 I NC DESCRIPTION: SLC-P-IA DISCH RV

3rd 10-YearlInterval C lm i Ge rangS tonRevisionO0 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMN Reliefs)

Position)

SLC-RV-29B M522 2

SA NA P

RV TSP-RV/IST-R701 TV03 D6 C

RV NA I X2 NC DESCRIPTION: SLC-P-IB DISCH RV SLC-V-IA M522 2

MO 0

G 2Y OSP-SLC/IST-Q701 TV01 E4 B

GB FAI HI Q

OSP-SLC/IST-Q701 4

NC DESCRIPTION: SLC-TK-1A (STORAGE TANK) TO SLC-P-1A SUCT ISO SLC-V-IB M522 2

MO 0

G 2Y OSP-SLC/IST-Q701 TV01 D4 B

GB FAI HJ Q

OSP-SLCIIST-Q701 4

NC DESCRIPTION: SLC-TK-lB (STORAGE TANK) TO SLC-P-1B SUCT ISO SLC-V-4A 1M522 1

SO O/C L

i TSP-CONT-R801 RV06 TV02 F8 AD EX NA V

EX OSP-SLC-B701 1.50 NC DESCRIPTION: SLC-P-1A DISCH TO RPV ISO (EXPLOSIVE OTBD CIV)

SLC-V-4B 1M522 1

s C 1 L

I TSP-CONT-R801 RV06 TV02 lD8 l

AD EX NA V

EX OSP-SLC-B702 1.50 NC DESCRIPTION: SLC-P-IB DISCH TO RPV ISO (EXPLOSIVE OTBD CIV)

SLC-V-6 1M522 1 1 SA I

0 Hx RF OSP-SLC-B701, B702 ROJO lF1I C

CK NA Nit 4Y I

CMP-25 1

1 1

1.50 NC I

DESCRIPTION: SLC TO RPV CHK SLC-V-7 1M522 1 1 SA l

O/C 1Hx RF OSP-SLC-B701, B702 ROJO lTV02 H13 l

AC l

C l

NA HxL I

TSP-CONT-R801 CMP-25 J

l 1.50 l

NC jNit 4Y DESCRIPTION: SLC TO RPV CHK (INBD CIV)

SLC-V-33A 1M522 2

SA O/C 1Hx Q

OSP-SLC/IST-Q701 lF7 C

CK j NA INit 4Y OSP-SLC/IST-Q701 CMP-16 l

11.50 NC DESCRIPTION: SLC-P-IA DISCH CHK SLC-V-33B M522 2

SA O/C HX Q

OSP-SLC/IST-Q701 D7 C

CK NA Nit 4Y OSP-SLC/IST-Q701 CMP-16 I

1.50 j NC DESCRIPTION: SLC-P-1B DISCH CHK SMW-RV-OlA lM524-1 l

3 l

SA NA IP RV TSP-RV/IST-R701 TV03 lD14 C

RV NA l

I l

l.75 X 1Il NC DESCRIPTION: RHR-HX-IA TUBE SIDE RV SW-RV-O0lB M524-2 3

SA I

A P

RV TSP-RV/IST-R701 1

ITVO3 FP14 C

RV NA l

.75 X I NC DESCRIPTION: RHR-HX-IB TUBE SIDE RV SW-TCV-11A lM775 l3 lHO Il O

lHK; Q

ESP-SW/IST-Q701 lRV02 lG5 B

GB l

FO 2.50 NT T

DESCRIPTION: EMERGENCY CHILLED WATER FROM WMA-CC-5IA-1 TCV SU'-TCV-lB lM775 3

HO 0

HK Q

ESP-SW/IST-Q702 lRV02 lC5 B

GB FO II l

B 2.50 l

NT l

DESCRIPTION: EMERGENCY CHILLED WATER FROM WMA-CC-51B-1 TCV

lIST Program Plan C lm iGe rangS tonPage 119 of 181l K.)

\\Valve Test Tables Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJ/ROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

SW-V-1A M524-1 3

SA 0

Hx Q

OSP-SW/IST-Q701 H5 C

CK NA Nit 4Y CMP-24 20 NC Di 10Y DESCRIPTION: SW-P-lA DISCH CHK SW-V-1B M524-2 3

SA 2

Hx Q

OSP-SW/IST-Q702 F5 C

CK NA Nit 4Y CMP-24 20 NC Di 10Y DESCRIPTION: SW-P-IB DISCH CHK SW-V-2A M524-1 3

MO 1 O/C G

2Y OSP-SW/IST-Q701 TVOI H6 B

BF FAI HJ Q

OSP-SW/IST-Q701-I _____________ [20 JNC j____________________

_____L______

DESCRIPTION: SW'-P-IA DISCH ISO SW-V-2B M524-2 3

MO O/C G

2Y OSP-SW/IST-Q702 TV01 F6 B

BF FAI HJ Q

OSP-SW/IST-Q702

_ _ _ _ _ _ _ ( 20 N C DESCRIPTION: SW-P-lB DISCH ISO SW-V-12A M524-1 3

MO O/C G

2Y OSP-SW/IST-Q701 TVOI G3 B

GT FAI HI Q

OSP-SW/IST-Q701 DESCRIPTION: SW A RETURN TO SPRAY POND B ISO SW-V-12B NM524-2 l

3 l

MO l

O/C lG 2Y OSP-SW/IST-Q702 I

lTVOI lG3 B J GT FAI Hi Q

OSP-SW/IST-Q702 18 N C DESCRIPTION: SW B RETURN TO SPRAY POND A ISO SW-V-29

[M524-1 [ 3 MO O/C IG 2Y OSP-SW/IST-Q703 l

lTVOI G6

(

B BF FAI HI Q

OSP-SW/IST-Q703 DESCRIPTION: HPCS-P-2 DISCH ISO SW-V-34 lM524-2 3

s0 O

0 G

2Y OSP-SU'/IST-Q702 TVOI lCII

[ B GB FO HIK Q

OSP-SW/IST-Q702 1 __ ___

_ 1 ___

_ 1 1.50 J N O DESCRIPTION: SW FROM RCIC-P-1 ROOM RRA-CC-6 ISO SW-V-75A lM524-1 3 J MO O/C G

2Y OSP-FPC/IST-Q701 l

JTVOI lB12 B

GB FAI Hi Q

OSP-FPC/IST-Q701 DESCRIPTION: SW TIE TO FPC LOOP A SW-V-75AA lM5241 I3 MA I O/C H

2Y OSP-FPC/IST-Q701 l

l 2

l NC l

DESCRIPTION: SW CROSSTIE TO FPC MAN ISO SW-V-75B M524-2 3

MO O/C G

2Y OSP-FPC/IST-Q701 TVOI A14 B

GB FAI HJ Q

OSP-FPC/IST-Q701 DESCRIPTION: SW TIE TO FPC LOOP B SW-V-75BB M524 2 3

MA I O/C H

2Y OSP-FPC/IST-Q701 1

l 2

NC l

DESCRIPTION: SW CROSSTIE TO FPC MAN ISO 0/C H

2Y OSP-SW/IST-Q701 1

K>

S--6A E3 B IBF INA 1is NO1_

DESCRIPTION: SW A RETURN TO SPRAY POND B SPRAY RING HDR BYPASS

IST Program Plan Columbia Generating Station Paevisi ofnO Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJlROJt Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPMI Reliefs)

Position)

SW-V-165B M524-2 3

MA O/C H

2Y OSP-SW/IST-Q702 K3 B

BF NA 18 N O DESCRIPTION: SW B RETURN TO SPRAY POND A SPRAY RING HDR BYPASS SW-V-170A M524-1 3

MA O/C H

2Y OSP-SW/lST-Q701 E3 B

BF NA DESCRIPTION: SW A RETURN TO SPRAY POND B SPRAY RING HDR MAN ISO SW-V-170B M524-2 3

MA O/C H

2Y OSP-SW/IST-Q702 K3 B

1F NA 0

DESCRIPTION: SW B RETURN TO SPRAY POND A SPRAY RING HDR MAN ISO SW-V-187A DM524-1 3

MO 0

G 2Y OSP-FPCjIST-Q701 TV01 H14 B lGT FNAI HJ Q

OSP-FPC/IST-Q701 DESCRIPTION: SW TO FPC-HX-1A INLET SW-V-187B M524-2 I3

_MO 1

_G 2Y OSP-FPC/ST-Q701

[TV01 C13 lB lGT lFAI IHJ Q

OSP-FPC/IST-Q701 DESCRIPTION: SW TO FPC-HX-1B INLET SW-V-188A M524-1I 3

r MO 1 ° IG 2Y OSP-FPC/IST-Q701 1

lTV01 313 B I GT IFAI I

Q OSP-FPC/IST-Q701 DESCRIPTION: SW FROM FPC-HX-1A OUTLET SW-V-188B M524-2 3

MO I

0 lG 2Y OSP-FPC/IST-Q701 TV01 I1 1 6T FI HC I

Q OSP-FPC/IST-Q701 DESCRIPTION: SW FROM FPC-HX-1B OUTLET SW-V-226A 1M775 f 3 j SA I

C lH Q

OSP-CCH/IST-M701 f

I I

3 I NC I

DESCRIPTION: CCH-EV-1A (EVAPORATOR) OUTLET CHK}

SW-V-226B 1M775 l

3 j SA C

H Q

OSP-CCH/IST-M702 I

I 3

I NC I

DESCRIPTION: CCH-EV-IB (EVAPORATOR) OUTLET CHKH SW-V-227A fM775 l

3 J MA C

lH 2Y OSP-CCH/IST-M701 1

1 I

I 3

I -NC I

DESCRIPTION: CCH-P-IA SUCT MAN ISO SW-V-227B M775 3

MA I

C IIH 2Y OSP-CCHIIST-M702 I

3 NO DESCRIPTION: CCH-P-IB SUCT MAN ISO SW-V-822A M75 l3 MA I

H 2Y OSP-CCHIIST-M70I I

I 3

I NO I

DESCRIPTION: SW TO WMA-CC-51A-I (CR CHILLER) MAN ISO SW-V-822B M775 3 j MA 0

H 2Y OSP-CCHIIST-M702 DESCRIPTION: SW TO WMA-CC-51B-1 (CR CHILLER) MAN ISO

3ITrd 0-era Inevla Columbia Generating Station Raevislio~i~n81 Valve Test Tables Type Position Testing Remarks

Actuat, Safety, Exceptions (Notes &

Dwg &

Class Valve

Failed, (CSJIROJ/

Technical Valve EPN Coord

& Cat

& Size Normal Tests, Frequency & PPM Reliefs)

Position)

SW-V-823A M775 3

MA 0

H 2Y OSP-CCH/IST-M701 J5 B

GT NA 3

NO DESCRIPTION: SW FROM UMA-CC-51A-1 (CONTROL RM CHILLER) MAN ISO SW-V-823B M775 3

MA J H 2Y OSP-CCH/IST-M702 1

E5 B

GT lNAI 3

lNCI DESCRIPTION: SW FROM WMA-CC-5 IB-I (CONTROL RM CHILLER) MAN ISO TIP-V-I M604 2

SO C

G 2Y OSP-CONTnIST-Q703 TV01,2 G13 A

BA FC G

2Y TSP-CONT-R801 -

0.375 NC H1K Q

OSP-CONT/IST-Q703 L

J TSP-CONT-R801 I

DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (I ST OTBD CIV)

TIP-V-2 M604 2

SO C

G 2Y OSP-CONT/IST-Q703 TV01,2 G13 A

BA FC G

2Y TSP-CONT-R801 0.375 NC HJK Q

OSP-CONT/IST-Q703 L

i TSP-CONT-R801 DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (IST OTBD CIV)

TIP-V-3 M604 2

SO C

G 2Y OSP-CONT/IST-Q703 TV01,2 G12 A

BA FC G

2Y TSP-CONT-R801 0.375 NC lHJK Q

OSP-CONT/IST-Q703 I

I I

I L

I TSP-CONT-R801 I

I DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (IST OTBD CIV)

TIP-V-4 M1604 2

SO C

G 2Y OSP-CONTIIST-Q703 TVOI,2 H12 A

BA FC G

2Y TSP-CONT-R801 0.375 NC HJK Q

OSP-CONT/IST-Q703 I

I I

I L

i TSP-CONT-R801 I

I DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (IST OTBD CIV)

TIP-V-5 1M604 2

SO C

G 2Y OSP-CONT/IST-Q703 TV01,2 1H12 A

BA FC G

2Y TSP-CONT-R801 j 0.375 NC 1HJK Q

OSP-CONT/IST-Q703

[

I I

I IL i

TSP-CONT-R801 I

I DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (IST OTBD CIV)

TIP-V-6 lM604 2

SA 1

C lHx 4Y OSP-TIP/IST-R701 1ROJO4 lTV02 FI2 AC CK NA HxL I

TSP-CONT-R801 I

I CMIP-26

[

I I 0.375 I NO Di 10Y I

DESCRIPTION: TIP PURGE LINE CHI (INBD CIV)

TIP-V-15 1M604 2

l SO C

G 2Y OSP-CONT/IST-Q703 TV01,2 lGI3 A

SV FC G

2Y TSP-CONT-R801 I

I_

I___I NO 1HJK Q OSP-CONT/IST-Q703 DS IPION:L T TSP-CONT-R801 C

DESCRIPTION: TIP PURGE LINE CHK (OTBD CIV)

IST Program Plan G

Page 122 of 181 3rd 10-Year Interval Columbia Generating Statlon Revision 0 5.4 Inservice Testing Program 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.

NOTE N01 Per Subsection ISTC-5223 Series Valves in Pairs, if two check valves are in series configuration without provisions to verify individual reverse flow closure (e.g., keepfill pressurization valves) and the plant safety analysis assumes closure of either valve (but not both), the valve pair may be operationally tested closed as a unit. If the plant safety analysis assumes that a specific valve or both valves of the pair close to perform the safety function(s), the required valve(s) shall be tested to demonstrate individual valve closure.

Per Subsection ISTC-5224 Corrective Action, Series valve pairs tested as a unit in accordance with ISTC-5223 that fail to prevent reverse flow shall be declared inoperable, and both valves shall be either repaired or replaced.

The following series check valve pairs are being tested in accordance with ISTC-5223 and ISTC-5224 requirements as stated above. 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 requiring NRC approval. 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.

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.

Each pair of series check valves is exercise tested during the quarterly surveillance by some positive means (measurement or observation of an operational parameter such as pressure or flow) to verify the closure capability of at least one of the valves to prevent reverse flow and open capability of both valves.

Acceptance criteria to verify closure of each pair of check valves is provided in the implementing surveillance procedures. If closure 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.

LPCS-V-33, 34 HPCS-V-6, 7 RHR-V-84A, 85A RHR-V-84B, 85B Qk RHR-V-84C, 85C

IST Program Plan Columbia Generating Station Page 123 of 1 3rd 10-Year Interval GeeaigRevision 0

NOTE 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 ISTC-5131(a) (stroke-time measurement) and ISTC-3560 (operation of fail-safe actuators) requirements.

CSP-V-7, 8, 10 CVB-V-lAB, CD, EF, GH, JK, LM, NP, QR, ST RFW'-V-32A, 32B NOTE N03 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 de-energize 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 de-energized 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 de-energized 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 ISTC-3700. 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 NOTE N04 The following check valves do not serve as ASME over pressure protection devices and as such are outside the scope of OM Code Mandatory Appendix I. However, these valves are tested per Subsection ISTC.

FPC-V-157A and FPC-V-157B RCIC-V-111 and RCIC-V-112 RHR-V-209

IST Program Plan Columbia Generating Station Page 124 of 181 3rd 10-Year Interval

'enaiIgRevision 0

NOTE 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 10 CFR 50.55a or by GL 89-04. These valves are being tested per Columbia Generating Station Technical Specifications or FSAR applicable to each valve. This alternate testing complies with position 7 of GL 89-04.

Tested Per Technical Valve Category Function Specifications or FSAR CRD-V-114 C

Check Valve to SCRAM Header SR 3.1.3.4 CRD-V-1 15 C

Charging Water Check Valve FSAR 4.6.1 CRD-V-126 B

Drive Water AOV SR 3.1.3.4 CRD-V-127 B

Withdraw AOV SR 3.1.3.4 CRD-V-138 C

Cooling Water Check Valve SR 3.1.3.2 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 not required to meet the testing requirements of OM Code Subsection ISTC. 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.

Valve DSA-SPV-5A1/2 DSA-SPV-5A1/4 DSA-SPV-5A2/2 DSA-SPV-5A2/4 DSA-SPV-5B 1/2 DSA-SPV-5B 1/4 DSA-SPV-5B2/2 DSA-SPV-5B2/4 DSA-SPV-5Cl/l DSA-SPV-5C1/2

IST Program Plan Columbia Generating Station Page 125 of 181 3rd 10-Year Interval Ge eaigRevision 0

NOTE N07 Affected Valves Class Cat.

Function System(s)

RCIC-V-4 2

B RCIC-P4 Discharge to EDR Isolation Reactor Core Isolation Cooling RCIC-V-5 2

B RCIC-P-4 Discharge to EDR Isolation Reactor Core Isolation Cooling RCIC-V-25 2

B RCIC Turbine Steam Supply Steam Reactor Core Isolation Cooling Traps to Main Condenser Isolation RCIC-V-26 2

B RCIC Turbine Steam Supply Steam Reactor Core Isolation Cooling Traps to Main Condenser Isolation ReactorCoreIolationCoolin The close function to close off equipment drain path during RCIC system operation can be accomplished by either valve RCIC-V-4 or RCIC-V-5 (CCERs C97-0139, Rev 0 and CCER C97-0010, Rev 1).

Similarly the close function to close off the steam drip pot drain path during RCIC system operation can be accomplished by either valve RCIC-V-25 or RCIC-V-26 (CCER C92-0128, Rev 2). However all four valves are being maintained with an active function of close to increase reliability of the RCIC system to meet its design requirements. Failure of one of the valves in each pair to meet its acceptance criteria specified in the surveillance procedure OSP-RCIC/IST-Q702 will not affect RCIC system operability.

NOTE N08 Per ISTC-1200, Category B safety and relief valves are excluded from the requirements of ISTC-3700, Valve Position Verification and ISTC-3500, Valve Testing Requirements.

NOTE N09 These relief valves have been installed for thermal relief application. Their only overpressure protection function is to protect the applicable ECCS system from fluid expansion caused by changes in fluid temperature. Per calculation 5.19.15, these valves are installed for thermal relief, i.e. requiring flows of 1 gpm or less.

HPCS-RV-14, HPCS-RV-35 LPCS-RV-18, LPCS-RV-31 RCIC-RV-3, RCIC-RV-17 RHR-RV-5, RHR-RV-25A/B/C, RHR-RV-30, RHR-RV-88A/B/C NOTE N10 Affected Valves lClass I Cat.

l Function l

System(s)

RCIC-V-2 2

1 B

l RCIC Turbine Governor Valve Reactor Core Isolation Cooling This valve is skid mounted and regulates steam flow to the RCIC Turbine. Proper operation of the valve is verified during quarterly pump test per surveillance procedure OSP-RCIC/IST-Q701.

IST Program Plan

.m Generating Page 126 of 161 3rd 10-Year Interval Coiumuia J La Lof Revision 0 NOTE Nl 1 The following solenoid operated H1202 monitoring isolation valves per FSAR Table 6.2.16 must remain open during normal operation, shutdown and post LOCA accidents. Therefore these valves perform no active safety function and are classified as "B passive". Only test requirements for these valves per OM Code Subsection ISTC is 2 year VPI. Valves will be stroke timed at the Owner's discretion.

PI-VX-262, PI-VX-263, PI-VX-264, PI-VX-265, PI-VX-266, PI-V X-268 and PI-VX-269.

NOTE N12 These containment atmosphere and suppression pool instrument line EFCVs have been deleted from the Technical Specifications testing requirements and are now tested per FSAR Section 6.2.4.4

(

Reference:

Technical Specification SR 3.6.1.3.8 Amendment #170, GI2-01-017, February 20, 2001.)

These valves have no active safety function and are included in the IST program at Owner's discretion and will be periodically tested per FSAR Section 6.2.4.4.

NOTE N13 CAC system has been deactivated per PDC 3539. The primary containment penetration lines have been isolated from the CAC skids by closing the isolation valves. The breakers have been opened and the control fuses removed. The inboard motor operated containment isolation valves have been chained and locked closed. Outboard hydraulically operated containment isolation valves have been de-energized.

Valve position indications have also been de-energized. PDC 3539 is consistent with the Safety Evaluation Report (SER) for Columbia Generating Station License Amendment 189/GI2-05-033, issued March 03,2005.

IST Program Plan C

S Page 127 of 181 3rd 10-Year Interval Columbia Generating Station Revision 0 5.5 Records and Reports of Valves Records and reports pertaining to valves in the Program will be maintained in accordance with OM Subsection ISTC-9000. The files will contain the following:

1.

Valve records will be maintained in accordance with Paragraph ISTC-9100.

2.

Inservice test plans include valve surveillance test procedures. The inservice testing records for valves in the Program will be maintained in accordance with Paragraph ISTC-9200.

3.

Records of tests for valves in the Program will be maintained in accordance with Paragraph ISTC-9120. Completed surveillance test procedures are retained per Plant administrative procedures.

4.

Records of corrective actions for valves in the Program will be maintained in accordance with Paragraph ISTC-9130. Corrective actions are documented on WOs and/or CRs.

Records and reports pertaining to pressure relief devices in the Program will also be maintained in accordance with OM Code Mandatory Appendix 1, Paragraph I-5000 requirements.

The Valve Inservice Test Program, associated surveillance test procedures and results, and corrective actions are retained per Plant Administrative Procedures.

IST Program Plan Columbia GenratngStation Page 128 of 181 3rd 10-Year Interval Cbeneratilg Revision 0 SAMPLE VALVE STROKE DATA SHEET

OPENING TIME IN SECONDS

CLOSING TIME IN SECONDS Ref.

Alen Lo Alert Hi Action Hi Ref.

Alert Lo Alert Hi l Action Hi VALVE EPN Value (+1)(+2)

Measured Value

(+l)(+2) (+1)(+2) Valuel (+1)(+2)

Measured Value

(+1)(+2)

RHR-V-4A t 111 94 128 144 109 93 125 142 RHR-V-6A t 102 87 117 133 100 85 115 130 RHR-V-3A t 106 90 122 138 105 89 121 137 RHR-V48A t 86 73 99 112 85 72 -

98 111 RHR-FCV-64A t 13 11 15 17 13 11 15 17 RHR-V-27A t 29 25 33 38 29 25 33 S (+3)

RHR-V-84A/85A N/A N/A NIA N/A N/A N/A N/A Not Closed RHR-V-31A N/A N/A N/A Not N/A N/A N/A Not Closed Open1 RHR-V-24A t 88 75 101 114 86 73 99

(+6)

RHR-V-60A N/A N/A N/

N/A N/A N/A N/A 2

RHR-V-75A N/A N/A N/A N/A N/A N/A N/A 2

10 RHR-V-73A t I

NM N/A N/A 10 8

13 15 RHIR-V-503 N/A N/A N/A N/A N/A N/A N/A N/A Not Closed

(+I)

For measured values beyond the Alert Value or Action Value refer to Precaution and Limitations 4.5 or 4.6, respectively.

(+2)

When comparing measured values to Alert and Action limits round all measured Stroke Times to the nearest second.

Use standard rounding techniques, e.g., 10.49 rounds to 10 and 10.5 rounds to 11 seconds.

(+3)

Limiting stroke time per LCS.

(+4)

If the valves are found not closed, repair or replace both valves RHR-V-84A and RHR-V-85A.

(+5)

Use listed stroke time as limiting even though a higher limit is specified in RHR system design specification data sheet, CVI 02E12-03,6

(+6)

Use listed stroke time as limiting even though a higher limit is specified in Licensee Control Specifications.

(+7)

Measure until motion stops (GT 95%) as indicated on RHR-POI-608A.

t Motor operated valve

C C

C

Verif ed Open

Verified Closed Valve Remote Remote Conditio Local Indication Indication Indication Local Indication n

As Valve Inspected Initial Found Sat Unsat Sat Unsat Initial As Found Ope ration Valve No.

7.3.1 7.3.2 7.3.3 7.3.4 7.3.4 7.3.4 7.3.4 7.3.2 7.3.3 7.3.5 7.3.7 RHR-V-4A

(+1)

RHR-V-6A RHR-V-3A RHR-V-48A RHR-FCV-64A #(+1)

RHR-V-27A

(+I)

RHR-V-24A

(+1)

RIIR-V-73A

(+1) tj 3

Hn M~

Mz H

w WW-d.

oIQ o C n"

0 F=

n rPO 0-On C/.

r-t xSD~

0:

o

(+ 1) These valves require channel calibration in addition to two year VPI. VPI verification satisfies both requirements.

IST Program Plan Columbia Generating Station Page 130 of 181 3rd 10-Year Interval I,~L~lRevision 0

5.6 Technical Positions Technical Position - TV01 Title Limiting Values of Full-stroke Times for Power Operated Valves Issue Discussion OM Code subsection ISTC requires that an initial reference value be established for each valve or group of valves. The acceptance criteria is a percentage +/- of the reference value. Subsection ISTC recognizes that operating characteristics of electric motor operated valves are more consistent than those of other power operated valves.

Subsection ISTC specifies stroke time acceptance criteria in Paragraphs ISTC-5122, ISTC-5132, ISTC-5142 and ISTC-5152. The limiting values of stroke time testing are to be established by the Owner according to Paragraphs ISTC-5121, ISTC-5131, ISTC-5141 and ISTC-5151.

Position The following criteria shall be used to establish Acceptance Criteria and Limiting Value ranges for power operated valves:

Acceptance Criteria Limiting Value Type (Alert)

(Action)

MOVs

10 seconds

+/-.25 Tref*

1.50 Tref**

MOVs > 10 seconds

+/-.15 Tref 1.30 Tref SOVs/AOVs/HOVs - 10 seconds

+/-.50 Tref 2.00 Tref SOVs/AOVs/HOVs > 10 seconds

+/-.25 Tref 1.50 Tref or +/- 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

IST Program Plan G

S Page 131 of 181 3rd 10-Year Interval Columbia Generating Station Revision 0 Technical Position -- TV01 (Contd.)

NOTES:

1.

Tref is the reference or average stroke value in seconds for an individual valve or valve grouping.

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 second.

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 acceptance criteria, if the maximum limiting valve stroke time is set at 2 seconds (ISTC-5122(c), ISTC-5132(c), ISTC-5142(c) and ISTC-5152(c)).

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 will be considered acceptable if the measured stroke time (rounded to the nearest second) remains at 2 seconds or less.

Corrective action will be required when a "Fast Acting Valve" rounded stroke time is 3 seconds or greater.

8.

Per OM Code ((ISTC-5121(c), ISTC-5131(c), ISTC-5141(c) andISTC-5151(c))), stroke times shall be measured to at least the nearest second. Thus rounding technique for measurements and reference values meets the Code requirements

9.

When valve stroke time measuring techniques other than stop watches provide more precise measurements, rounding technique will not be used.

3ST Program Plan Columbia Generating Station Page 132 of 181 3rd 10-Year Interval Geeatn Revision 0 Technical Position - TV02 Title Seat Leakage Testing per 10 CFR 50, Appendix J., Option B Issue Discussion Category A containment isolation valves are to be tested as required by OM Code, ISTC-3620 in accordance with 10 CFR 50, Appendix J, Option B program. Containment isolation valves with a leakage requirement based on other functions shall be tested in accordance with ISTC-3630. Examples of these other functions are reactor coolant system pressure isolation valves and certain Owner-defined system functions such as inventory preservation, system protection, or flooding protection.

Position Category A containment isolation valves are tested in accordance with 10 CFR 50, Appendix J, as approved by the NRC in WNP-2 Safety Evaluation Reports. Certain exceptions to Appendix J testing requirements are detailed in the Columbia Generating Station FSAR and Technical Specifications where the associated basis is documented.

All PIVs are tested per Technical Specification SR 3.4.6.1. These valves are reactor coolant pressure boundary pressure isolation valves and are hydraulically leak tested at Reactor Coolant System pressure of 1035 psig during refueling outages in lieu of a type C test. Per technical specification, the actual test pressure shall be greater than or equal to 935 psig. Maximum allowable leakage rate for these valves as specified in Paragraph ISTC-3630(e) shall be less than or equal to 0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at function differential pressure. When leakage rates are measured using pressures lower than function maximum pressure differential, the observed leakage shall be adjusted to the function maximum differential value in accordance with the formula in Paragraph ISTC-3630(b)(4).

Valves or valve combination with leakage rates exceeding the value specified by the Owner per ISTC-3630(e) shall be declared inoperable and either repaired or replaced. A retest demonstrating acceptable operation shall be performed following any corrective action before the valve is returned to service. During refueling outages valves exceeding specified leakage limits are declared inoperable for containment isolation function but considered operable for system operability during Mode 4 and 5.

Valves are repaired or replaced before Plant startup.

3ST Program Plan Columbia Generating Station Page 133 of 181 3rd 10-Year Interval GeeaigRevision 0

Technical Position -- TV03 Title Inservice Performance Testing of Pressure Relief Valves Issue Discussion Subsection ISTC-5240 requires testing of safety and relief valves in accordance with mandatory Appendix I.

Position The following clarifications will be used when implementing testing requirements for safety and relief valves.

Replacement valve (I-2000): New valves not previously used at Columbia Generating Station.

Spare class 1 Main Steam relief valves, which have been set-pressure tested after repair and refurbishment prior to new 10 year interval implementation date, in accordance with the Code in effect for 2nd 10 year interval, will not be retested prior to installation in the Plant provided they were tested LT 5 years before installation. These valves will be considered operable based on this previous test. Next test for these valves shall occur before 5 years from the previous test.

Testing of valve accessories is not dependent on operating conditions and will be performed at normal ambient condition (1-1120(a)).

Test sequence in Paragraph I-3310 is not applicable for refurbishments.

Reduced system pressure for valve actuation includes zero pressure (Paragraph 1-3410(d)).

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.

IST Program Plan

.lm i Generating Page 134 of 181 3rd 10-Year Interval Coiumula

,Latlon Revision 0 Technical Position - TV04 Title Inservice Testing of Vacuum Relief Valves, suppression chamber-to-drywell vacuum breakers (CVB Valves)

Issue Discussion Per OM Code Subsection ISTC-5230, vacuum breakers shall meet the applicable inservice test requirements of ISTC-5220 and Mandatory Appendix I.

OM Code, Mandatory Appendix 1, Paragraph 1-3370 specifies the following testing requirements for Class 2 and 3 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 shall be determined.

Per Paragraph 1-1380, all Class 2 and 3 vacuum relief valves shall be tested every 2 years, unless K>

performance data suggests the need for a more appropriate test interval.

Position At Columbia Generating Station these vacuum relief valves are operability tested in accordance with Technical Specification 3.6.1.7. Technical Specification testing detailed below meets or exceeds the testing requirements of ISTC-5220 and Mandatory Appendix I. As such these valves will continue to be tested in accordance with the Columbia Generating Station Technical Specifications. Leakage testing of these valves is performed by conducting a drywell-to-suppression chamber bypass leak test (Relief Request RV0l). These testing requirements will also apply to replacement and refurbished valves, as applicable.

SURVEILLANCE REQUIREMENTS:

1.

SR 3.6.1.7.1, verify each vacuum breaker is closed every 14 days.

2.

SR 3.6.1.7.2, perform a functional test of each required vacuum breaker every 31 days and within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after any discharge of steam to the suppression chamber from the safety/relief valves.

3.

SR 3.6.1.7.3, verify the full open setpoint of each required vacuum breaker is less than or equal to 0.5 psid every 24 months.

Position indicators are verified operable during the performance of above surveillances.

IST Program Plan G

Page 135 of 181 3rd 10-Year Interval Columbia Generati lg Statlon Revision 0 Technical Position -- TV05 Title Inservice Testing of Vacuum Relief Valves, Main Steam vacuum breaker valves (MS 37 and 38 Series)

Issue Discussion Per OM Code Subsection ISTC-5230, vacuum breakers shall meet the applicable inservice test requirements of ISTC-5220 and Mandatory Appendix 1.

OM Code, Mandatory Appendix I, Paragraph 1-3370 specifies the following testing requirements for Class 2 and 3 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 shall be determined.

Per Paragraph 1-1380, all Class 2 and 3 vacuum relief valves shall be tested every 2 years, unless performance data suggests the need for a more appropriate test interval.

Position The vacuum breaker system allows MSRV downcomer pressure to equalize with drywell pressure 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 force) range. Short duration steam leakage into the drywell 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 per Appendix I are to verify valve open and close capability and set pressure determination. The safety function of these valves is to open only. This testing is performed every refueling outage (ROJ07). These testing requirements meet the testing requirements of ISTC-5220 and Mandatory Appendix I. These testing requirements will also apply to replacement and refurbished valves, as applicable.

3ST Program Plan Columbia Generating Station Page 136 of 181 3rd 10-Year Interval

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5.7 Cold Shutdown Justifications ISTC-3510 states that all Active category A, category B, and category C check valves shall be tested nominally every 3 months, except as provided by ISTC-3520, ISTC-3540, ISTC-3550, ISTC-3570, ISTC-5221, and ISTC-5222.

ISTC-3521 states that category A and B valves shall be full-stroke tested or exercised during operation at power to the position(s) required to fulfill its function(s).

If full-stroke exercising during operation at power is not practicable, it may be limited to part-stroke during operation at power and full-stroke during cold shutdowns.

Valves full-stroke exercised at cold shutdowns shall be exercised during each cold shutdown, except as specified in ISTC-3521(g). Such exercise is not required if the time period since the previous full-stroke exercise is less than 3 months. During extended shutdowns, valves that are required to perform their intended function shall be exercised every 3 months, if practicable.

ISTC-3522 states that category C check valves shall be exercised during operation at power in a manner that verifies obturator travel by using the methods in ISTC-5221. If exercising is not practicable during operation at power, it shall be performed during cold shutdowns.

Valves exercised at cold shutdowns shall be exercised during each cold shutdown, except as specified in ISTC-3522(e). Such exercise is not required if the interval since the previous exercise is less than 3 months. During extended shutdowns, valves that are required to perform their intended function shall be exercised every 3 months, if practicable.

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 operation at 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 required to be tested during cold shutdown will be tested before or as part of plant startup. However, it is not the intent of the Code to keep the plant in cold shutdown to complete 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 3 months. If an outage lasts beyond 3 months, all cold shutdown testing shall be completed within the last 3 months 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.

The following valves are identified as being impracticable to exercise during Plant operations and will therefore be exercised during cold shutdowns. All of 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.

IST Program Plan Columbia Generating Station Page 137 of 181 3rd 10-Year Interval GeeaigRevision 0

Cold Shutdown Justification -- CSJ01 Description 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 1

A RHR supply to vessel head spray RHR-V-53A B I

A Loop A, B outboard isolation valve for shutdown Residual Heat Removal IH-

-5A I

cooling return

__L 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. Opening these valves during plant operation or bypassing the interlocks associated with the reactor coolant systems could result in over pressurization of the discharge line of the RHR system and may cause the loss of shutdown RHR cooling capability. Interlocks cannot be bypassed with normal control circuits.

In addition as stated in NUREG 1482 Rev1 Sections 3.1.1(2) and (3), all valves when cycled that could either result in a loss of containment integrity or could subject a system to pressures in excess of their design pressures, would be acceptable to test only during cold shutdown outages.

Alternative Frequency These valves will be full stroke exercised during cold shutdown.

IST Program Plan Generating Page 138 of 181 3rd 10-Year Interval Columbia Station Revision 0 Cold Shutdown Justification -

CSJO2 Description It is not practicable to full or partial stroke exercise the following RFW valves during normal Plant operation.

Affected Valves l Class Cat.

Function I

System(s)

RFW-V-65A, B I

A Reactor feedwater isolation valves IReactor Feedwater Justification Closure of either of these Category A valves during normal plant operation would isolate the feed water to the reactor and would result in a loss of flow to the reactor vessel. This could cause a significant reduction of reactor coolant inventory and potentially cause several of the safety systems to initiate.

Alternative Freguencv These valves will be full stroke exercised during cold shutdown.

IST Program Plan Plag Generating SPg139tof 181 3rd 10-Year Interval C.olumb~ia GeertngSation Revision 0 Cold Shutdown Justification -

CSJO3 Description 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)

CIA-V-30A, B 2

A Nitrogen supply to ADS accumulators (outboard CIV)

Containment Instrument CIA-V-20 2

A Instrument air supply to inboard MSIVs and Air MSRVs (outboard CIV)

Justification

1.

Testing CIA-V-30A and 30B at power requires securing the safety related nitrogen supply to the ADS valve accumulators. Thus closing these valves renders ADS MSRVs inoperable. This is operationally undesirable to do while the Plant is operating.

2.

Testing CIA-V-20 at power isolates instrument supply air from the inboard MSIVs. Excessive system leakage downstream of this valve can result in closure of inboard MSIVs and Plant SCRAM.

Monitoring downstream header pressure during valve closure requires installation of a local test gauge in a high radiation area. Reduced exercising frequency is also justified by ALARA.

3.

In addition as stated in NUREG 1482 Rev1 Sections 3.1.1(2), all valves when cycled that could either result in a loss of containment integrity, would be acceptable to test only during cold shutdown outages.

The risks associated with challenging these protective systems during power operations is not considered prudent, and therefore alternative cold shutdown testing frequency is warranted.

Alternative Frequency These valves will be full stroke exercised during cold shutdown.

3ST Program Plan Columbia Generating Station Page 140 of 181 3rd 10-Year Interval oumi aoRevision 0

Cold Shutdown Justification -- CSJO4 (INACTIVE-FOR CHECK VALVES CIA41A & 41B TESTED I.A.W. CONDITION MONITORING PLAN)

Description It is not practicable to full or partial stroke exercise category B CIA valves during normal Plant operation, nor full stroke exercise category C CIA valves during normal Plant operation.

Affected Valves Class Cat.

Function System(s)

These valves cross connect the normal nitrogen CIA-V-39A, B 3

B supply for the Main Steam Isolation Valves and Main Steam Relief Valves (including the 7 ADS Containment Instrument Valves) accumulators to the backup nitrogen Air supply for the 7 ADS valves.

CIA-V41 A, B 3

C Justification Testing these valves requires securing the backup nitrogen supply to the ADS valve accumulators.

Isolating the backup nitrogen supply to the ADS and/or MSIVs during normal power operations is undesirable to do while the Plant is operating at power.

Alternative Frequency These valves will be full stroke exercised during cold shutdown.

3ST Program Plan Columbia Generating Station Page 141 of 181 3rd 10-Year Interval

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Cold Shutdown Justification - CSJO5 Description It is not practicable to full or partial stroke exercise open the following RCIC valve during normal Plant operation.

Affected Valves Class Cat.

Function System(s)

RCIC pump discharge isolation, and containment Reactor Core Isolation RCIC-V-13 1

A isolation, and reactor coolant pressure isolation Cooling valve.

Justification This valve is the isolation valve from the RCIC pump discharge to the Reactor Pressure Vessel Head Spray. This Category A valve is an outboard Containment Isolation Valve as well as a Reactor Coolant Pressure Isolation Valve. Opening this valve during normal power operations increases the possibility of over pressurizing a low pressure system with the higher pressure from the Reactor system.

In addition as stated in NUREG 1482 Rev1 Sections 3.1.1(2) and (3), all valves when cycled that could either result in a loss of containment integrity or could subject a system to pressures in excess of their V.

design pressures, would be acceptable to test only during cold shutdown outages.

Alternative Frequency This valve will be full stroke exercised during cold shutdown.

IST Program Plan C

S Page 142 of 181 3rd 10-Year Interval Columbia Generating Station Revision 0 Cold Shutdown Justification -

CSJO6 Description It is not practicable to full or partial stroke exercise open the following LPCS or RHR valves during normal Plant operation.

Affected Valves Class Cat.

Function System(s)

LPCS-V-5 I

A LPCS discharge isolation to the reactor vessel.

Low Pressure Core Spray RHR-V-42A, B, C 1

A RHR discharge isolation to the reactor vessel.

Residual Heat Removal Justification The risk of injuring Plant personnel, over pressurizing the associated pump and piping, or causing an intersystem LOCA makes the opening of these valves imprudent during power operations. This cold shutdown testing is recommended by NUREG-1482, Rev 1, section 3.1.1(3).

Alternative Frequencv These valves will be full stroke exercised during cold shutdown.

IST Program Plan Clb GeneratingPage 143 of 181 3rd 10-Year Interval Columbia GeeaigSainRevision 0

Cold Shutdown Justification -

CSJO7 Description It is not practicable to full or partial stroke exercise the following RWCU valves during normal Plant operation.

Affected Valves Class Cat.

Function System(s)

RWCU-V-1 1

A Containment Iso., RWCU Pump Suction Iso.

RWCU-V-4 1

A Containment Iso., RWCU Pump Suction Iso.

Reactor Water Cleanup RWCU-V-40 I

A Containment Iso., RWCU Pump Discharge Iso.

I Justification Testing these valves during power operations requires system shutdown which imposes thermal stresses on the pumps and heat exchangers, significantly increasing the potential for equipment damage. In addition as stated in NUREG 1482 Revl Sections 3.1.1(2) and (3), all valves when cycled that could either result in a loss of containment integrity or could subject a system to pressures in excess of their design pressures, would be acceptable to test only during cold shutdown outages.

Alternative Frequency These valves will be full stroke exercised during cold shutdown.

IST Program Plan G

Page 144 of 181 3rd 10-Year Interval Columbia Generati lg Statlon Revision 0 Cold Shutdown Justification -

CSJO8 Description It is not practicable to full or partial stroke exercise the Main Steam Isolation Valves (MSIVs) during normal Plant operation.

Affected Valves Class Cat.

Function System(s)

MS-V-22A I

A Main Steam Line A Inboard Isolation Valve MS-V-22B I

A Main Steam Line B Inboard Isolation Valve MS-V-22C 1

A Main Steam Line C Inboard Isolation Valve MS-V-22D I

A Main Steam Line D Inboard Isolation Valve M

MS-V-28A A

Main Steam Line A Outboard Isolation ValveSteam MS-V-28B 1

A Main Steam Line B Outboard Isolation Valve MS-V-28C I

A Main Steam Line C Outboard Isolation Valve MS-V-28D I

A Main Steam Line D Outboard Isolation Valve Justification 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 could result in a reactor trip or safety system actuation and is therefore not considered prudent. The MSIVs will be full stroked exercised during cold shutdown outages when the MSIVs are able to be isolated..

In addition, close stroke testing of MSIVs requires isolation of non-safety related air, which is not accessible during plant operation.

The implementation of the alternate frequency will contribute to the reduction of the relief valve challenge and failure rate as specifically recommended in NUREG-0626.

Alternative Frequencv These valves will be full stroke exercised and stroke timed during cold shutdown conditions.

IST Program Plan Columbia Generating Station Page 145 of 181 3rd 10-Year Interval

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Cold Shutdown Justification -

CSJO9 Description It is not practicable to full or partial stroke exercise open the following MSLC valves during normal Plant operation.

Affected Valves Class Cat.

Function System(s)

MSLC-NV-2A, B, C, D 1

B Prevent Radioactive Material Release MSLC-V-3A, B. C, D 1

A CIV, Prevent Radioactive Material Release Control MSLC-V-4, 5, 9, 10 2

B Prevent Radioactive Material Release I

_I Justification 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 if the inboard MSIV fails to close.

The valves (MSLC-V-2A/B/C/D and 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 will be required to open or close with only 38 psi across them in case of an accident, the potential of having to shut the Plant down if they 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 Frequencv These valves will be full stroke exercised during cold shutdown.

IST Program Plan Columbi Generating Stto Page 146 of 181 3rd 10-Year Interval Columbia G r n atio Revision 0 k")

Cold Shutdown Justification -- CSJ10 Description It is not practicable to full or partial stroke exercise the following MS valve during normal Plant operation.

Plant Affected Valves Class Cat.

Function System(s)

MS-V-146 2

B Isolation Valve, Main Steam Supply to Auxiliary Main Steam Equipment Justification 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 result 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.

Closing this valve at normal power operations would result in the isolation of steam to the equipment as listed above and could result in the initiation of safety systems or equipment.

Alternative Frequencv This valve will be full stroke exercised during cold shutdown.

1ST Program Plan Columbia Page 147 of 181 3rd 10-Year Interval Cou baGenerating StLation Revision 0 Cold Shutdown Justification - CSJ 1I Description It is not practicable to full or partial stroke exercise open the following MS valves during normal Plant operation.

l Affected Valves j Class I Cat. I Function l

System(s)

MS-V-67A, B, C, D 1

l A I Outboard MSIV drain valve (MS-V-28A, B, C, D)

Main Steam Justification These Category A 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 result 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. (NUREG-1482 Rev 1 Section 3.1.1(2)).

3.

Cycling of these valves during normal Plant operation could increase the fatigue usage of the superpipe between the MSIV and the MS-V-67 valve above acceptable limits, i.e., Usage > 0.1.

Alternative Frequency These valves will be full stroke exercised during cold shutdown.

1ST Program Plan Columbia Generating Station Page 148 of 181 3rd 10-Year Interval GeeaigRevision 0

Cold Shutdown Justification -- CSJ12 Description 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-16A, B 2

A Dr1'well Spray Header (2nd outboard CIV)

Residual Heat Removal RHR-V-17A, B 2

A Drywell Spray Header (1st outboard CIV)

Justification These Category A 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 ALARA.

3.

Each time these valves are exercised, there is a risk of spraying/wetting down safety related equipment in the drywell (Ref. OER 82083F-INPO SER41-85, Containment Spraying Events, OER 890401-7, INPO RSEN 91-01 Recurring Significant Events).

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.

5.

In addition as stated in NUREG 1482 Revision 1 Sections 3.1.1(1) and (2) all valves that when cycled could either cause a loss of system function if they were to fail in a non-conservative position or could result in a loss of containment integrity during the cycling test, would be acceptable to test only during cold shutdown outages.

Alternative Frequency These valves will be full stroke exercised during cold shutdown.

IST ProgramPlan Columbia Generating Station Page 149 of 18 3rd 10-Year Interval

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Cold Shutdown Justification -- CSJ13 Description 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 1

A Containment Isolation Main Steam MS-V-19 1

A Containment Isolation Justification

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.

5.

In addition as stated in NUREG 1482 Revision I Sections 3.1.1(1) and (2) all valves that when cycled could either cause a loss of system function if they were to fail in a non-conservative position or could result in a loss of containment integrity during the cycling test, would be acceptable to test only during cold shutdown outages.

Alternative Frequency These valves will be full stroke exercised during cold shutdown.

IST Program Plan Columbia Generating Station Page 150 of 181 3rd 10-Year Interval

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5.8 Refueling Outage Justifications ISTC-3510 states that all Active category A, category B, and category C check valves shall be tested nominally every 3 months, except as provided by ISTC-3520, ISTC-3540, ISTC-3550, ISTC-3570, ISTC-5221, and ISTC-5222.

ISTC-3521 states that category A and B valves shall be full-stroke tested or exercised during operation at power to the position(s) required to fulfill its function(s). If exercising is not practicable during operation at power or cold shutdowns, it may be limited to full-stroke during refueling outages.

ISTC-3522 states that category C check valves shall be exercised during operation at power in a manner that verifies obturator travel by using the methods in' ISTC-5221. If exercising is not practicable during operation at power and cold shutdowns, it shall be performed during refueling outages.

All valve testing required to be performed during a refueling outage shall be completed before returning the plant to operation at power.

The following valves are identified as being impractical to exercise during Plant operations and cold shutdowns and will therefore 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.

3ST Program Plan Columbia Generating Station Page 151 of 181 3rd 10-Year Interval GeeaigLL~~lRevision 0 Refueling Outage Justification - ROJMl (INACTIVE-CHECK VALVES TESTED I.A.W. CONDITION MONITORING PLAN)

Description It is not practicable to exercise the following SLC check valves during normal Plant operation or cold shutdown.

Affected Valves Class Cat.

Function System(s)

SLC-V-6 1

C Standby Liquid Control discharge to reactor Standby Liquid Control SLC-V-7 I

AC vessel Justification

1.

Valves have no operator with which they may be 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 reactor 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 ISTC-5260(c) requires testing of one explosive charge every 2 years.

3.

NUREG-1482 Rev 1,' 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 SLC-V-7).

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 Frequency During each refueling outage:

1.

One of the Standby Liquid Control system loops, including the associated explosive valve, will be initiated. A flow path to the Reactor Vessel will be verified by pumping demineralized water to the vessel, this verifies valve opening.

2.

Valve closure capability will be verified in conjunction with 10 CFR 50 Appendix J (Type C) testing or by other positive means.

3ST Program Plan Columbia Generating Station Page 152 of 181 3rd 1 0-Year Interval GeeaigRevision 0

Refueling Outage Justification -- ROJM2 (INACTINE-FOR CHECK VALVES CIA-V-21, 31A & 31B TESTED I.A.W. CONDITION MONITORING PLAN)

Description It is not practicable to exercise the following CIA check valves during normal Plant operation or cold shutdown.

Affected Valves Class Cat.

Function System(s)

CIA-V-21 2

AC Instrument air supply to containment (inside

_ _ _containment)

CIA-V-31AB 2

AC

~Instrument air supply to ADS valves (inside CIA--3 AB AC containment)

CIA-V-40M,N,P, 2

AC Instrument air to ADS Accumulators (inside Containment Instrument RSUV 2

containment)

Air CIA V-24AB. CD 2

AC Instrument air to Accumulators for inboard 2MSIVs (inside containment)

CAS-V-29ABCD 3

AC (Control air to Accumulators for outboard MSIVs CAS-V-29ABCD 3

AC (inside steam tunnel)

Justification

1.

NUREG-1482 Rev 1, Section 4.1.6 allows extension of test interval to refueling outage for check valves verified closed by leak testing. (Applies to CIA-V-21, 31A and 31B.)

2.

NUREG-1482 Rev 1, 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.)

The CIA-V-24 and CIA-V40 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 requires reconfiguring the system, hook-up and disconnection of leak test apparatus. (Applies to all referenced valves.)

IST Program Plan Columbia Generating Station Page 153 of 181 3rd 10-Year Interval oumaa Revision 0 Refueling Outage Justification -- ROJM2 (Contd.)

(INACTIVE-FOR CHECK VALVES CIA-V-21, 31A & 31B TESTED I.A.W. CONDITION MONITORING PLAN)

4.

Due to system design, no practical method exists to perform this testing during power operations and during cold shutdowns when the containment is inerted. (Applies to all referenced valves.)

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 effectively 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 Frequency During each refueling outage:

1.

Pressure decay or flow make up leakage 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 10 CFR 50, Appendix J (Type C) testing.

lST Program Plan Columbia Generating Station Page 154 of 181 3rd 10-Year Interval Revision 0 Refueling Outage Justification -- ROJO3 (INACTIVE-CHECK VALVE TESTED I.A.W. CONDITION MONITORING PLAN)

Description It is not practicable to exercise the following RHR check valve 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 for Residual Heat Removal piping between valves RHR-V-8 and 9.

Justification

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 Columbia Generating Station Technical Specification 3.4.10). Additionally, containment may 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 Rev 1, 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 Frequency This check valve will be exercised during each refueling outage.

IST Program Plan G

Page 155 of 181 3rd 10-Year Interval ColumbLia Generatng Statlon Revision 0 Refueling Outage Justification -- ROJM4 (INACTIVE-CHECK VALVES TESTED I.A.W. CONDITION MONITORING PLAN)

Description It is not practicable to exercise the following check valves during normal Plant operation or cold shutdown.

Affected Valves Class Cat.

Function System(s)

PI-V-X72f/1 2

AC Containment Isolation Process Instrumentation PJ-V-X73e/1 2

AC Containment Isolation ProcessInsrumentatio TIP-V-6 2

AC Containment Isolation Traversing Incore Probe Justification

1.

These check valves are located on the discharge of the radiation leak detection monitors and on the purge system 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 Rev 1, 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 Fr6auencv These valves will be exercised during each refueling outage.

3ST Program Plan tra C

m Generating S Page 156 of 181 3rd 10-Year Interval C..olumbiPa Geea ingSation Revision 0 Refueling Outage Justification -- ROJO5 (INACTIVE-CHECK VALVE TESTED I.A.W. CONDITION MONITORING PLAN)

Description It is not practicable to exercise the following RCC check valve during normal Plant operation or cold shutdown.

Justification

1.

This check valve is located around the inboard isolation valve on the RCC return line. The valve is located inside containment and is inaccessible during power operation and during cold shutdowns when the containment is inerted. Therefore, it is impractical to test this check valve quarterly during power operations or during cold shutdowns when containment remains inerted.

2.

NUREG-1482 Rev 1, 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 Frequency This check valve will be exercised during each refueling outage.

lST Program Plan Columbia Generating Station Page 157 of 181 3rd 10-Year Interval L~lmjaRevision 0

Refueling Outage Justification -

ROJO6 It is not practicable to exercise the following RFW check valves during normal Plant operation or cold shutdown.

Affected Valves Class Cat.

Function System(s)

RFW-V-IOA. B 1

AC Reactor feedwater inboard check valve RFW-V-32A, B I

AC Reactor feedwater outboard check valve Reactor Feedwater Justification

1.

NUREG-1482 Rev 1, Section 4.1.6, allows extension of test interval to refueling outage for check valves verified closed by leak testing.

2.

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 requires reconfiguring the system, hook-up and disconnection of leak test apparatus.

3.

These valves are held open by feedwater flow and cannot be closed during power operation.

Alternative Frequencv These valves will be verified close by leak-rate testing during each refueling outage. These valves are open during the plant operation to supply water to the reactor.

IST Program Plan Columbia Generating Station Page 158 of 181 3rd 10-Year Interval GeeaigRevision 0

Refueling Outage Justification -- ROJ07 Description It is not practicable to exercise the following MS check valves during normal Plant operation or cold shutdown.

Affected Valves Class Cat.

Function System(s)

MS-V-37 Series 3

C Open: To break vacuum in the downcomers of (Typ 18) the main steam relief valves.

MS-V-38 Series Close: To direct steam to the quenchers in the Main Steam (Typ 18) 3 C

wetwell.

Justification

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 inerted as this testing requires personnel entry into the containment building.

2.

NUREG-1482 Rev 1, 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 Frequency 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 measured. The valves are also manually operated and visually verified to open and reseat. The safety function of these valves is to open only.

IST Program Plan Colu bi Generating Stto Page 159 of 181 3rd 10-Year Interval Roum ia G r nation Revision 0 Refueling Outage Justification -- ROJO8 Description It is not practicable to exercise the following check valves during normal Plant operation or cold shutdown.

Affected Valves Class Cat.

Function System(s)

RCIC-V-66 I

AC RCIC discharge to the reactor vessel head Cooling RCIC-V-65 I

C RCIC discharge to the reactor vessel head Reactor Core Isolation Cooling LPCS-V-6 1

AC LPCS discharge to the reactor vessel Low Pressure Core Spray HPCS-V-5 I

AC HPCS Discharge to the reactor vessel High Pressure Core Spray RHR-V-41A, B, C I

AC RHR Loop A, B, C discharge to the reactor Residual Heat Removal RHR-V-SOA, Aphvessel RHR-V-50A, B 1

AC RHR Loop A, B discharge to the recirculating Reiual Heat Removal I

I___

I_

pum p discharge Justification

1.

These valves (except RCIC-V-65) 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 Specification SR 3.4.6.1 requires seat leakage testing of these valves at IST program frequency.

Each pressure isolation valve is individually leak tested in accordance with the differential pressure requirements of the Code. 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 position indications (except RCIC-V-65), the other positive means of verifying these valves fully open is by passing the required accident condition flow through these valves. This is an acceptable full-stroke per position 1 of Attachment 1 of Generic Letter 89-04.

Position indication of RCIC-V-65 is not reliable.

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.

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.

IST Program Plan Cou baPage 160 of 181 3rd 10-Year Interval Columbia Generating Station Revision 0 K.)

Refueling Outage Justification - ROJO8 (Contd.)

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 Rev 1, 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.

9.

NUREG-1482 Rev 1, Section 4.1.6 allows extension of the test interval to refueling outage for check valves verified closed by leak testing.

Alternative Frequency During each refueling outage:

1.

Closure ability of these valves (except RCIC-V-65 which does not have a closed safety function) shall be demonstrated by leakage test as required by Technical Specification SR 3.4.6.1.

2.

Opening ability of these valves shall be demonstrated by passing the maximum required accident condition flow through these valves.

3.

Verify closure of RCIC-V-65 based on valve position indication.

3ST Program Plan Columbia Generating Station Page 161 of 181 3rd 10-Year Interval

~~im~

LLolRevision 0

Refueling Outage Justification - ROJM9 (INACTIVE-FOR CHECK VALVES CSP-V70 THROUGH CSP-V-79 TESTED I.A.W.

CONDITION MONITORING PLAN)

Description It is not practicable to exercise the following CSP check valves during normal Plant operation or cold shutdown.

Affected Valves Class Cat.

Function System(s)

Close: To provide isolation for safety related CSP-V-65 2

AC control air to containment isolation valves CSP-V-5, 6 and 9.

Containment Supply and Open: To provide safety related control air to Purge CSP-V-70 through 2

C containment isolation valves CSP-V-5, 6 CSP-V-79 and 9.

Justification

1.

There is no local or remote position indication for these check valves. Testing these valves requires K->

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-5, 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 CSP-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 requires the system to be breached and the safety related supply header depressurized and would be 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 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 pertaining to Probabilistic Risk Assessment core melt frequency indicates a negligible increase in containment failure frequency.

Alternative Frequency During each refueling outage, each of these check valves will be exercised per Subsection ISTC requirements.

IST Program Plan Colmbi Generating Page 162 of 181 3rd 10-Year Interval Coiumula kLatlon Revision 0 Refueling Outage Justification - ROJ10 Description 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-8 I

A Isolate RHR shutdowxn cooling suction line from 1

AResodual Heat Removal RHR-V-9 I

A reactor recircul ation l oop A 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.

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 (Technical Specification 3.4.10). 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 Frequency During each refueling outage, each of these valves will be exercised per Subsection ISTC requirements.

IST Program Plan Columbia Page 163 of 181 3rd 10-Year Interval Generating,La iOn Revision 0 Refueling Outage Justification -- ROJB Description 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. I Function System(s)

RHR-V-123A, B I

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. The MOVs are deenergized during Modes 1, 2 or 3.

Columbia Generating Station Technical Specification SR 3.6.1.3.5 requires verification of isolation time of these valves per IST Program.

Alternative Freguencv During each refueling outage, each of these valves will be exercised per ISTC Code requirements.

IST Program Plan Coum iaPage 164 of 181 3rd 10-Year Interval Columbia Generating StatLon Revision 0 Refueling Outage Justification - ROJ12 (INACTIVE-CHECK VALVE TESTED I.A.W. CONDITION MONITORING PLAN)

Description It is not practicable to full stroke exercise the following RCIC check valve during normal Plant operation or cold shutdown.

Affected Valves Class Cat.

Function System(s)

RCIC-V-30 2

Suppression pool to RCIC-P-1 suction check Reactor Core Isolation C POOCooling Justification

1.

This check valve is located on the suction piping from suppression pool for RCIC-P-1. Normal quarterly testing of RCIC system is with suction from Condensate Storage Tank (CST) and the pump discharge to CST.

2.

Section 4.1.6 of NUREG-1482 Rev 1, states the need to set up test equipment is adequate justification to defer reverse flow testing of check valves to a refueling outage frequency. This position is also stated in response to question 2.3.19 in, "Summary of Public Workshops held in NRC Regions on Inspection Procedure (IP) 73756, "Inservice Testing of Pumps and Valves", and Answers to Panel Questions on Inservice Testing issues."

3.

Verifying RCIC-V-30 full open by passing the required accident flow through the check valve will require pumping suppression pool water into the CST. Because of the differences in water chemistry, frequent injections of suppression pool water into the CST is undesirable. Thus, full flow testing should be limited to refueling outages only.

Alternative Frequency Each refueling outage, during startup after refueling the valve will be verified full open by passing the maximum required accident condition flow through the valve per procedure OSP-RCIC/IST-B501. As an alternate, Non-Intrusive Testing Technique may also be used to verify the valve full open. Valve will also be verified closed.

3ST Program Plan Columbia Generating Station Page 165 of 181 3rd 10-Year Interval LaLoIRevision 0

Refueling Outage Justification - ROJ13 Description It is not practicable to full or partial stroke exercise open the following RCC valves during normal Plant operation or cold shutdown outages.

Affected Valves Class Cat.

Function System(s)

RCC-V-5 2

A Isolation valves for reactor closed cooling Reactor Closed water lines penetrating the primary Cooling Water RCC-V-21 2

A containment.

RCC-V-40 2

A RCC-V-104 2

A Justification Closure of any isolation valve will interrupt cooling water flow to the Reactor Recirculation (RRC) Pump seals, to the RRC pump motor coolers and to the Drywell Air Coolers possibly causing failure of this equipment. Stopping the RRC Pumps for the sole purpose of performing testing of the above listed RCC valves could extend the Cold Shutdown period.

As stated in NUREG 1482 Revision 1 Section 3.1.1.4, Subsection ISTC of the OM Code allows licensees to extend the test interval to defer testing to refueling outages when it is not practical to perform the tests during power operation or cold shutdown outages. The NRC staff has determined that licensees need not schedule valve testing that requires stopping and restarting reactor coolant pumps during each cold shutdown solely to allow for the testing of such valves. This repetitive cycling would increase pump wear and stress, as well as the number of cycles of related plant equipment, and could extend the length of cold shutdown outages.

Alternative Frequency These valves will be exercised each refueling outage.

IST Program Plan Columbia Page 166 of 181 3rd 10-Year Interval Generating StaLon Revision 0 Refueling Outage Justification - ROJ14 (INACTIVE-FOR CHECK VALVES RRC- '-13A & 13B TESTED I.A.W. CONDITION MONITORING PLAN)

Description It is not practicable to full or partial stroke exercise the following RRC valves during normal Plant operation or cold shutdowns.

Affected Valves Class Cat.

Function System(s)

RRC-V-13A,B 2

AC Inboard and outboard isolation valves-for Reactor Recirculation I RR-V-6AB2 Athle recirculation pumps seal purge line IR--6, I

IA Justification Closure of the Category A isolation valves (RRC-V-16A/B) during power operations or cold shutdowns when the RRC pumps are operating is not permitted as this will interrupt seal purge water flow to the Reactor Recirculation (RRC) Pumps. Loss of purge flow may result in excessive seal wear and possibly failure of the pump seals, to the RRC pump.

Category AC valves (RRC-V-13A/B) are held open by purge water flow and cannot be closed during power operations or cold shutdowns when the RRC pumps are operating as this would isolate seal purge water flow to the RRC pumps and could result in excessive wear and possible failure of the seals possibly causing failure of this equipment. Stopping the RRC Pumps for the sole purpose of performing testing of the above listed RRC valves could extend the Cold Shutdown period.

As stated in NUREG 1482 Revision 1 Subsection 3.1.1.4, Subsection ISTC of the OM Code allows licensees to extend the test interval to defer testing to refueling outages when it is not practical to perform the tests during power operation or cold shutdown outages. The NRC staff has determined that licensees need not schedule valve testing that requires stopping and restarting reactor coolant pumps during each cold shutdown period solely to allow for the testing of such valves. This repetitive cycling would increase pump seal wear and stress, as well as the number of cycles of related plant equipment, and could extend the length of cold shutdown outages.

Alternative Frequency The above listed valves will be exercised at each refueling outage.

IST Program Plan Coumi Generating Station Page 167 of 181 3rd 10-Year Interval ColUmla Revision 0 Refueling Outage Justification -- ROJ15 (INACTIVE-FOR CHECK VALVES CIA-V-52A TO 66A, CIA-52B TO 70B, CIA-V-103A &

103B TESTED I.A.W. CONDITION MONITORING PLAN)

Description It is not practicable to full or partial stroke exercise open the following CIA valves during normal Plant operation or cold shutdown outages.

Affected Valves Class Cat.

Function System(s)

CIA-SPV-B to 19B 3

B-Containment CIA nitrogen bottle auto isolation valve.

Instrument Air CIA-SPV-IA to 15A 3

B CIA-V-52A to 66A 3

C CIA nitrogen bottle discharge check valves.

CIA-V-52B to 70B 3

C CIA-V-103A, B 3

C CIA remote nitrogen bottle discharge check valves.

Justification Valve 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. Performing the valve testing during normal cold shutdowns could result in the expending of emergency nitrogen tanks and depleting the supply of the emergency nitrogen system.

In order to perform bi-directional testing of the check valves as required by OM Code Subsection ISTC, this would required the nitrogen supply to be depleted in order to verify forward flow thru the check valve and then isolated for reverse closure verification. As a result of the necessity to re-pressurize the emergency nitrogen due to the depletion caused by the testing of the check valves, this could result in a potential delay in startup from a cold shutdown condition.

As stated in NUREG 1482 Revision 1 Sections 3.1. 1, Subsection ISTC of the OM Code allows licensees to extend the test interval to defer testing to refueling outages when it is not practical to perform the tests during power operation or cold shutdown outages. The NRC staff has determined that licensees need not schedule valve testing that requires excessive manipulation of plant equipment or other activities during each cold shutdown period solely to allow for the testing of such valves. This depletion of nitrogen supply and the requirement to resupply the nitrogen, could extend the length of cold shutdown outages.

Alternative Frequency These valves will be full stroke exercised during refueling outages.

IST Program Plan

.lmia Generating Station Page 168 of 181 3rd 10-Year Interval Lo mula Revision 0 5.9 Relief Requests From Certain Subsection ISTC and Mandatory Appendix I Requirements Relief Requests either provide alternative to Code requirements in accordance with IOCFR 50.55a(a)(3)(i) or relief from impractical Code requirements in accordance with 10CFR 50.55a(f)(5)(iii). They provide technical justification and propose alternate testing to be performed in lieu of the Code required testing.

1ST Program Plan Cou baPage 169 of 181 3rd 10-Year Interval Columbia Generating Station Revision O Relief Request - RV01 Relief Request in Accordance with 10CFR 50.55a(f)(5)(iii)

-- Inservice Testing Impracticality --

ASME Code Components Affected Affected Valves Class Cat.

Function System(s)

CVB-V-lAB, CD, To break vacuum on the drywell to suppression Primary Containment EF, GH, JK, LM, 2

AC chamber downcomers and to limit steam leakage Cngand Purge NP, QR, ST from the downcomer to the wetwell gas space, g

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

OM Subsection ISTC-3630, Leakage Rate for Other Than Containment Isolation Valves.

Impracticality of Compliance These check valves cannot be tested individually therefore, assigning a limiting leakage rate for each valve or valve combination is not practical..

Burden Caused by Compliance Subsection ISTC-3630 requires Category A valves, other than containment isolation valves, to be individually leak tested. Each vacuum relief valve assembly consists of two independent testable check valves in series with no instrument located between them to allow testing of each of the two check valves.

Therefore, leak testing in accordance with the Code is impractical. Modifications to allow individual testing of these valves would require a major system redesign and be burdensome.

3ST Program Plan Columbia StationnPage 170 of 181 3rd 10-Year Interval CoubaGenerating SainRevision 0

Relief Request -

RVYO (Contd.)

Proposed Alternative and Basis for Use These valves will be leak tested according to Columbia Generating Station Technical Specification SR 3.6.1.1.2 during outages by conducting a drywell-to-suppression chamber bypass leak rate test. 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. Maintaining the pressure suppression function of primary containment requires limiting the leakage from the drywell to the suppression chamber. Thus, if an event were to occur that pressurized the drywell, the steam would be directed through the downcomers into the suppression pool. This surveillance measures drywell to suppression chamber differential pressure during a 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months period to ensure that the leakage paths that would bypass the suppression pool are within allowable limits. Satisfactory performance of this surveillance is achieved by establishing a known differential pressure (GE 1.5 psid) between the drywell and the suppression chamber and verifying that the bypass leakage is equivalent to that through an area GE 0.005 ft2. The leakage test is performed every 24 months. Two consecutive test failures, however, would indicate unexpected primary containment degradation and would require increasing the frequency to once every 12 months until the situation is remedied as evidenced by passing two consecutive tests. This leakage test complies with the requirements of Paragraph ISTC-3630(c) for the valve assembly. These valves are verified-closed by position indicators, tested in the open direction using a torque wrench, and each valve seat is visually inspected per Technical Specification SR 3.6.1.7.1, SR 3.6.1.7.2, and SR 3.6.1.7.3.

Oualitv/Safetv Impact The leakage criteria and corrective actions specified in the Columbia Generating Station Technical Specification SR 3.6.1.1.2 combined with visual examination of valve seats every refuel outage should provide adequate assurance of the relief valve assembly's ability to remain leak tight and to prevent a suppression pool bypass. Thus, proposed alternative provides adequate assurance of material quality and public safety.

Duration of Proposed Alternative Third 10 year interval.

Precedents This relief request was granted for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159), Relief Request No. RVOI.

IST Program Plan Columbi Generating Statin Page 171 of 181 3rd 10-Year Interval Columbia Gtato Revision 0 Relief Request - RV02 Relief Request in Accordance with 10CFR 50.55a(f)(5)(iii)

-- Inservice Testing Impracticality --

ASME Code Components Affected Affected Valves Class Cat.

Function System(s)

SW-TCV-I 1A, B 3

B Throttle flow to control temperature of the Standby Service Water Control Room

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

1.

OM Subsection ISTC, Paragraph ISTC-5141, Hydraulically Operated Valves Stroke Testing

2.

OM Subsection ISTC, Paragraph ISTC-5142, Stroke Test Acceptance Criteria

3.

OM Subsection ISTC, Paragraph ISTC-5143(b), Stroke Test Corrective Action Impracticality of Compliance It is difficult to accurately measure the stroke time of these hydraulically actuated control valves. These valves are not provided with any form of override that would allow them to be manually cycled.

Additionally, they are 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.

Burden Caused by Compliance

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. SW-TCV-1 IA & 1lB are controlled by thermostats which regulate main control room air temperature.

1ST ProgramPln Columbia Generating Station Page172iof 181 3rd 10-Year Interval Cou baeeeatnvtainsion 0

Relief Request - RV02 (Contd.)

2.

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 3.7.4 and Licensee Controlled Specification 1.7.2 required systems be taken out of service.

3.

Modification of the existing valves or installation of new valves to provide manual control and position indication would be burdensome and costly.

Proposed Alternative and Basis for Use

1.

In general, control valves that respond to system conditions are exempt from IST per Subsection ISTC-1200. However, these control valves perform a fail-safe function (fail open), and must be tested in accordance with the Code provisions to monitor the valve for degrading conditions. ASME Code Case OMN-8 states that stroke-time testing need not be performed for these valves when the only safety-related function of the valves is to fail safe. Code Case OMN-8, as accepted in RG 1.192 is only applicable through OM Code-1995. OM Code Committee is in the process of revising the applicability of this Code Case to the later approved OM Code editions and addenda.

2.

These valves shall be exercised quarterly in accordance with the Subsection ISTC requirements and K.

the failsafe position on a loss of power (OPEN) shall be verified. Any abnormality or erratic action experienced during valve exercising shall be evaluated per the Corrective Action Program.

Quality/Safety Impact The alternative testing to be performed will verify proper operation of the valve to meet its design function. Adequate assurance of material quality and maintenance of public safety will be provided.

Duration of Proposed Alternative Third 10 year interval.

Precedents Similar relief request was granted for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159), Relief Request No. RV03.

1ST Program Plan Columbia GeeaigStation Page 173 of 181 3rd 10-Year Interval Generating Revision 0 Relief Request - R%03 Proposed Alternative in Accordance with 10CFR 50.55a(a)(3)(i)

-Alternative Provides Acceptable Level of Quality and Safety--

ASME Code Components Affected Affected Valves Class Cat.

Function System(s)

PSR-V-X73-1 2

A PSR-V-X8S01 2

A PSR-V-X83-1 2

A PSR-V-X77A1 I

A PSR-V-X82-1 2

A Containment Isolation Post Accident Sampling PSR-V-X84-1 2

A PSR-V-X77A3 I

A PSR-V-X82-7 2

A PSR-V-X88-1 2

A

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

OM Subsection ISTC-5150, Solenoid-Operated Valves, Stroke Testing

Reason for Request

Subsection ISTC-5 151 requires the stroke time of all solenoid-operated valves be measured to at least the nearest second. These nine PSR solenoid valves are the inboard Containment Isolation Valve for nine different penetrations and are operated from a single keylock control switch. It is impractical to measure the individual valve stroke times. To do so would require repetitive cycling of the control switch causing unnecessary wear on the valves and control switch with little compensating benefit.

Proposed Alternative and Basis for Use 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 will be measured by terminating the stroke 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 stroke time of the slowest valve exceeds the acceptance criteria (2 seconds), all 9 valves will be declared inoperable and corrective actions in accordance with Subsection ISTC-5153 taken.

1ST Program Plan Columbia Generating Station Page 174 of 181 3rd 10-Year Interval GeeaigRevision 0

Relief Request - RV03 (Contd.)

Oualitv/Safetv Impact The proposed alternate testing will verify 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.

Duration of Proposed Alternative Third 10 year interval.

Precedents This relief request was granted for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159) and Supplement to SER Dated March 25, 1999 (TAC No. MA3813), Relief Request No. RV04.

IST Program Plan Columbia Generating S Page 175 of 181 3rd 10-Year Interval Revision 0 Relief Request - RV04 Proposed Alternative in Accordance with 10CFR 50.55a(a)(3)(i)

--Alternative Provides Acceptable Level of Quality and Safety--

ASMIE Code Components Affected Affected Valves Class Cat.

Function System(s)

MS-RV-IA, B, C, D 1

C MS-RV-2A, B, C, D 1

C Overpressure Protection MS-RV-3A, B, C 1

C MS-RV-3D 1

C Overpressure Protection and Auto Main Steam MS-RV-4A, B, C, D I

C Depressurization System to lower reactor pressure sufficient to allow initiation of Low MS-RV-SB, C I

C Pressure Coolant Injection (RHR, LPCI mode)

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

Mandatory Appendix !, Paragraph 1-3310: Sequence of Periodic Testing of Class 1 Main Steam Pressure Relief Valves with Auxiliary Actuating Devices.

Reason for Request

1.

Remote set point verification devices (SPVD) have been permanently installed on all eighteen MSRVs to allow set point testing at low power operation, typically during shutdown for refueling outage and on startup if necessary. Crosby's SPVD incorporate a nitrogen powered, metal bellows assembly that adds a quantified lifting force on the valve stem until the MSRV's popping pressure is reached. During normal power operation, these heads remain deenergized and do not interfere with normal safety or relief valve functions. Removal and replacement of the MSRVs is normally used only for valve maintenance and normally not for the purpose of As-Found set pressure determination. MSRVs are removed and replaced for maintenance purposes (e.g., seat. leakage, refurbishment ) 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 are separated from the valve and remain in place when MSRVs are removed and replaced for maintenance.

IST Program Plan Columbia Generating Station Page 176 of 181 3rd 10-Year Interval

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Relief Request - RV04 (Contd.)

If MSRV periodic set pressure testing could not be performed at power during shutdown for refueling outage due to reactor scram it will required to be performed during power ascension from refueling outage. This will require Paragraphs 1-3310(d), (e), (f), (g) and (h) tests to be performed during outage prior to Paragraphs 1-3310(a), (b), (c) and (i) tests. Paragraph 1-3310(g) is not applicable to these valve designs.

2.

'Valves" and "accessories" (actuators, solenoids, etc.) have different maintenance and test cycles due to the methods used for maintenance and testing at Columbia Generating Station 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 Owner's seat tightness criteria, in accordance with Paragraphs 1-3310 (a), (b), (c) and (i)) are independent of and can be separate from testing of "accessories" (i.e., solenoids, actuator, position indicators and pressure sensing element, in accordance with Paragraphs 1-3310 (d), (e), (f), and (h)). Paragraph 1-3310 states that tests before maintenance or set-pressure adjustment, or both, shall be performed for 1-3310(a), (b), and (c) in sequence. The remaining shall be performed after maintenance or set pressure adjustments. Valve maintenance or set pressure adjustment does not affect "accessories" testing; likewise, maintenance on "accessories" does not affect valve set pressure or seat leakage. Therefore, the MSRVs and the "accessories" may be tracked separately for the purpose of satisfying the Paragraph 1-1320 test frequency requirements.

3.

Paragraph I-3310(f) requires determination of operation and electrical characteristics of position indicators, and Paragraph 1-3310(h) 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 elements (pressure switches) are all checked and calibrated nominally every 24 months. Although the existing tests 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 Subsection, and far exceed the required test frequency and testing requirements.

3ST Program Plan Columbia Generating Station Page 177 of 181 3rd 10-Year Interval ouma a101Revision 0

Relief Request - RV04 (Contd.)

Proposed Alternative and Basis for Use

1.

"Valves" and "accessories" (actuators, solenoids, etc.) shall be tested separatelyand meet Paragraph I-1320 test frequency requirements. 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.

MSRV periodic set pressure testing will normally be performed at power during shutdown for refueling outage. If MSRV periodic set pressure testing could not be performed at power during shutdown for refueling outage due to reactor scram it will be performed during power ascension from refueling outage. This will require Paragraphs 1-33 10(d) and (e) tests to be performed during outage prior to Paragraphs 1-33 10 a), (b), (c) and (i) tests.

The actuators and solenoids will be 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 will continue to be tested in accordance with existing surveillance procedures for monthly channel checks, and for channel calibration and channel functional testing on nominally 24 month frequency during shutdowns. These tests will be credited for satisfying the requirements of Paragraph 1-3310(f).

3.

All auxiliary actuating device sensing elements (pressure switches) will continue to be tested and calibrated on a 24 month frequency. These tests will be credited for satisfying the requirements of paragraph I-3310(h).

Qualitv/Safetv Impact 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 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 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.

1ST Program Plan IST Program PlanCo 3rd 10-Year Interval CO}

Relief Request - RV04 (Contd.)

Duration of Proposed Alternative lumbia Generating Station Page 178 of 181 Revision 0 Third 10 year interval.

Precedents This relief request was granted for the previous 10 year interval.

SER letter dated November 27, 1995 (TAC No. M91159) and Supplement to SER Dated March 25, 1999 (TAC No. MA3813), Relief Request No. RV05.

IST Program Plan Columbia G Station Page 179 of 181 3rd 10-Year Interval Cb enerating Revision 0 Relief Request - RVO5 Proposed Alternative in Accordance with 10CFR 50.55a(a)(3)(i)

--Alternative Provides Acceptable Level of Quality and Safety-ASME Code Components Affected Affected Valves Class l Cat.

System(s) / Function PI-EFC-X18A. B. C. D I

C PI-EFC-X37E, F 1

C PI-EFC-X38A,B,C,D,E,F 1

C PI-EFC-X39A, B, D, E 1

C PI-EFC-X40C, D 1

C PI-EFC-X40E, F 2

C P1-EFC-X41C, D 1

C PI-EFC-X41E, F 2

C PI-EFC-X42A, B 1

C PI-EFC-X44A Series (Typ 12) 1 C

PI-EFC-X44B Series (Typ 12) 1 C

PI-EFC-X61A, B 1

C PI-EFC-X62C, D 1

C PI-EFC-X69A, B, E I

C PI-EFC-X70A, B, C, D, E, F 1

C PI-EFC-X71A, B, C, D, E, F I

C PI-EFC-X72A I

C PI-EFC-X73A 1

C PI-EFC-X74A, B, E, F 1

C PI-EFC-X75A, B, C, D, E, F 1

C PI-EFC-X78B, C, F I

C PI-EFC-X79A, B 1

C PI-EFC-X106 1

C PI-EFC-X107 1

C PI-EFC-X108 1

C PI-EFC-X109 1

C PI-EFC-X IO 1

C PI-EFC-X 1I I

C PI-EFC-X1 12 1

C PI-EFC-X1 13 1

C PI-EFC-X114 1

C System(s):

Process Instrumentation for various systems connected to RPV Function:

Excess flow check valves are provided in each instrument process line that is Part of the reactor coolant pressure boundary. Design and installation of the excess flow check valves at Columbia Generating Station conform to Regulatory Guide 1.11.

Close:

The reactor instrument line excess flow check valves close to limit the flow in the respective instrument lines in the event of an instrument line break downstream of the EFCVs outside containment.

PI-EFC-X115 I

C PI-EFC-X1 15 1

C

3ST Program Plan Columbia Generating Station Page 180 of 181 3rd 10-Year Interval GeertigRevision 0

Relief Request -- RV05 (Contd.)

Applicable Code Edition and Addenda

The 2001 Edition and the 2002 and 2003 Addenda of the ASME OM Code

Applicable Code Requirement

OM Subsection ISTC-3522(c), Category C Check Valves. If exercising is not practicable during operation at power and cold shutdowns, it shall be performed during refueling outages.

OM Subsection ISTC-3700, Valve Position Verification. Valves with remote position indicators shall be observed locally at least once every 2 years to verify that valve operation is accurately indicated.

Reason for Request and Basis for Use OM Code Subsection ISTC requires testing of active or passive valves that are required to perform a specific function in shutting down a reactor to the cold shutdown condition, in maintaining the cold shutdown condition, or in mitigating the consequences of an accident. The EFCVs are not required to perform a specific function for shutting down or maintaining the reactor in a cold shutdown condition.

Additionally, the reactor instrument lines are assumed to maintain integrity for all accidents except for the Instrument Line Break Accident (ILBA) as described in FSAR, Subsection 15.6.2. The reactor instrument lines at Columbia Generating Station have a flow-restricting orifice upstream of the EFCV to limit reactor coolant leakage in the event of an instrument line rupture. Isolation of the instrument line by the EFCV is not credited for mitigating the ILBA. Thus, a failure of an EFCV is bounded by the Columbia Generating Station safety analysis. These EFCVs close to limit the flow of reactor coolant to the secondary containment in the event of an instrument line break and as such are included in the IST program at the Owner's discretion and are tested in accordance with the amended Technical Specification SR 3.6.1.3.8.

The GE Licensing Topical Report, NEDO-32977-A (Reference 2), and associated NRC safety evaluation, dated March 14, 2000, provides the basis for this relief. The report provides justification for relaxation of the testing frequency as described in the amended Technical Specification SR 3.6.1.3.8. The report demonstrates the high degree of EFCV reliability and the low consequences of an EFCV failure. Excess flow check valves have been extremely reliable throughout the industry. Based on 15 years of testing (up to year 2000) with only one (1) failure, the Columbia Generating Station revised Best Estimate Failure Rate is 7.9E-8 per hour; less than the industry average of 1.01E-7 per hour. There have been no failure since year 2000. Technical Specification amendment request for SR 3.6.1.3.8 was reviewed by the NRC staff in safety evaluation (SE) dated February 20, 2001 (Reference 3).

Failure of an EFCV, though not expected as a result of the amended Technical Specification change, is bounded by the Columbia Generating Station safety analysis. Based on the GE Topical report and the analysis contained in the FSAR, the proposed alternative to the required exercise frequency and valve indication verification frequency for EFCVs provide an acceptable level of quality and safety. In Reference 3, the NRC staff concluded that the increase in risk associated with the relaxation of EFCV testing is sufficiently low and acceptable.

IST Program Plan Columbia Generating Station Page 181 of 181 3rd 10-Year Interval

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Relief Request -- RY05 (Contd.)

Proposed Alternative Energy Northwest requests relief pursuant to 10 CFR 50.55a(a)(3)(i) to test reactor instrument line excess flow check valves in accordance with the amended Technical Specification SR 3.6.1.3.8. This SR requires verification every 24 months that a representative sample of reactor instrument line EFCVs actuate to the isolation position on an actual or simulated instrument line break signal. The representative sample consists of an approximately equal number of EFCVs such that each EFCV is tested at least once every 10 years (nominal). Valve position indication verification of the representative sample will also be performed during valve testing. Any EFCV failure will be evaluated per the Columbia Generating Station Corrective Action Program.

Duration of Proposed Alternative Third 10 year interval.

Precedents This relief request was granted for the previous 10 year interval.

SE letter dated April 5, 2001 (TAC No. MB0422), Relief Request No. RV06.

References

1.

FSAR 15.6.2

2.

Letter BWROG-00069, dated June 14, 2000, from W.G. Warren, (BWR Owners Group) to Office of Nuclear Reactor Regulation, "Transmittal of Approved GE Licensing Topical Report NEDO-32977-A, Excess Flow Check Valve Testing Relaxation", dated November 1998 3

Letter GI2-01-017, dated February 20, 2001, Jack Cushing (NRC) to JV Parish (EN), "Columbia Generating station -Issuance of Amendment RE: Technical Specifications Surveillance Requirement 3.6.1.3.8 (TAC NO. MB0421)"

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