ML13249A160

Submittal of Revision 1 of the Third Ten-Year Interval Pump and Valve Inservice Testing (IST) Program Plan

ML13249A160
Person / Time
Site:	Columbia
Issue date:	08/28/2013
From:	Gregoire D Energy Northwest
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
G02-13-124
Download: ML13249A160 (192)

Text

Donald W. Gregoire ENERGY Columbia Generating Station P.O. Box 968, PE20 NORTHWEST Richland, WA 99352-0968 Ph. 509-377-8616 1F. 509-377-4317 dwgregoire@energy-northwest.com August 28, 2013 10 CFR 50.55a G02-13-124 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555-0001

Subject:

COLUMBIA GENERATING STATION, DOCKET NO. 50-397 SUBMITTAL OF REVISION I OF THE THIRD TEN-YEAR INTERVAL PUMP AND VALVE INSERVICE TESTING (IST) PROGRAM PLAN

Dear Sir or Madam:

Energy Northwest is herewith submitting, attached to this letter, Revision 1 of the "Inservice Testing Program Plan Third Ten-Year Inspection Interval" for the Columbia Generating Station (CGS). This periodic submittal to the Nuclear Regulatory Commission (NRC) will update information in the Docket for Columbia's IST Program Plan.

Changes reflected in the current revision have been made in conformance with approved Energy Northwest Engineering and IST Program processes and do not require NRC review and approval.

There are no commitments being made to the NRC by this letter.

Should you have any questions or require additional information pertaining to this report, please contact Ms. LL Williams at (509) 377-8148.

Respectfully, 1{ DW Gregoire Manager, Regulatory Affairs Attachment 1: Inservice Testing Program Plan Third Ten-Year Inspection Interval, Energy Northwest - Columbia Generating Station, Revision 1 cc: NRC Region IV Administrator AJ Rapacz - BPN 1399 NRC NRR Project Manager WA Horin - Winston & Strawn NRC Sr. Resident Inspector - 988C

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IST Program Plan Columbia GeneratingeStation 3rd 10-Year Interval Revision 1 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

IST Program Plan 3rd 10-Year Interval Columbia Generating Station Revision ENERGY NORTHWEST Columbia Generating Station INSERVICE TESTING PROGRAM PLAN Third Ten-Year Interval (13 DEC 2005 through 12 DEC 2014)

Revision 1 Prepared by 01 -if. _2013 IST Program Engineer ( zVA (- e (f-f'Jp- Date Reviewed by 02 -- // - 2.G t3 Reviewing Eng deer C s" 5u-,Sw*.*-L, Date Concurrence Supervisor, IST/e0rogram Date

",,,d I-Approved by Man aý e h i l Serv-ic.srO Date ii

IST 10-Year 3rd ProgramInterval Plan Columbia Generatin Station Revision 1 DESCRIPTION OF CHANGES Justification (required for major revision).."...

Incorporate previous minor changes and converted IST Program plan from word perfect to word document.

Page(s). Description (including summary, reason, initiating document, if applicable) 110,111 Valves RHR-V-60A, 60B, 75A and 75B deleted per design change EC 11109.

Added manual valves RHR-V-731 and 732 to valves test table due to deletion of valves RHR-V-60A, 60B, 75A and 75B.

Added Columbia Generating Station Technical Position TP02 on Vertical Line Shaft pumps Added SW-V-69A, 69B, 70A and 70B manual valves to the Valve Test Table (Ref. CR 2-06-05849).

75 Corrected Test Frequency for CIA-SPV valves from CS to RF.

51,56,60,178,182,185 Updated relief requests RP04, RP05, RP07, RV03, RV04 and RV05 by annotating NRC approval.

Updated relief requests RP01, RP03, RP06, RV01, RV02 by annotating NRC 41,46,58,174,176 approval.

Diesel Fuel Oil Transfer pumps and pump discharge check valves qualify for classification as skid-mounted pumps and valves as defined in ISTA-16,34 to 37,42,61, 2000 and therefore exclusion from ISTB and ISTC pursuant to ISTB-1 200 80,124 and ISTC-1200. Relief Requests RP02 and RP08 were withdrawn and are being deleted. Technical Position TP03 and Note N15 have been added.

Technical Position TP01 has been deleted.

Deleted CAC valves. CAC system has been permanently isolated and deactivated per PDC 4533 and PDC 3539.

Deleted CSJ09 and added note N14. MSLC system has been deactivated per 89,124,149, EC 97-0045-1 C.

Deleted excess flow check valves, PI-EFC-X18A through PI-EFC-X18D from 90,183 valve test table and RV05. These valves have been deactivated per EC 97-0045-3E.

131,132 Updated Technical Position TV03.

Deleted lock-closed valves RHR-V-1 1A, 11 B, 120, 121, 124A, 124B, 125A, 125B, 134A and 134B per LDCN LCS-08-027 and LDCN FSAR-08-028. These 108,111,124 Primary Containment valves no longer require seat leak rate testing per Appendix J program since they are not airborne pathways and are in closed systems outside of the Primary Containment.

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IST PlanCou ProgramInterval 3rd 10-Year C lm baG iGe nrtrangS gSain tonRevision 1 Changed valve category from 'A' to 'B' for valves HPCS-V-1 2, 15, 23, LPCS-FCV-11, LPCS-V-1, 12, RCIC-V-19, 28, 31, 50, 69, RHR-FCV-64A, 64B, 64C, RHR-V-4A, 4B, 4C, 21, 24A, 24B, 73A and 73B per LDCN LCS-08-027 and 85,86,103 to 110,124 LDCN FSAR-08-028. These Primary Containment valves no longer require seat leak rate testing per Appendix J program since they are not airborne pathways and are in closed systems outside of the Primary Containment.

Deleted CMP-1 8 for testing of RHR-V-209 (AR 188338-06). Activated ROJO3 to test this valve every refueling outage.

Changed valve category from 'A' to 'B' for valve RCIC-V-50. This valve no 104 longer requires seat leak rate testing per Appendix J program since it is not airborne pathway and is in closed system outside of the Primary Containment.

Added Technical Position TV06 for preconditioning of structures, systems and components.

Various Editorial and procedure number changes.

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IST Program Plan Columbia Generating Station i 3rd 10-Year Interval Revision 1 TABLE OF CONTENTS Page

1.0 INTRODUCTION

.................................................... 1 1.1 Program Administration ........................................................................................................ 2 1.2 Program Database ........................................................................................................... 3 1 .3 R efe re n ce s ............................................................................................................................... 4 2.0 QUALITY ASSURANCE PROGRAM .................................................................................... 5 3.0 PIPING AND INSTRUMENT DIAGRAMS ............................................................................. 6 4.0 PUMP INSERVICE TESTING PROGRAM .......................................................................... 7 4 .1 Intro d u ctio n ............................................................................................................................... 7 4.2 Program Implementation ..................................................................................................... 8 4.2.1 Exclusions (ISTB-1200) ............................................................................................ 8 4.2.2 Pump Categories (ISTB-1300) ................................................................................. 8 4.2.3 Preservice Testing (ISTB-3100) ............................................................................... 8 4.2.4 Inservice Testing (ISTB-3200) ................................................................................. 9 4.2.5 Frequency of Inservice Tests (ISTB-3400) ............................................................... 9 4.2.6 Pumps in Systems Out-of-Service (ISTB-3420) ........................................................ 9 4.2.7 Reference Values (ISTB-3300) ................................................................................. 9 4.2.8 Instrumentation Accuracy (ISTB-3510(a)) ............................................................... 10 4.2.9 Inservice Test Parameters (ISTB-3500) ................................................................. 11 4.2.10 Allowable Ranges For Test Parameters ................................................................. 12 4.2.11 Testing Methods ..................................................................................................... 12 4.2.12 Test Procedure ..................................................................................................... 12 4.2.13 Trending (ISTB-6100) ............................................................................................ 13 4.3 Pump Reference List .............................................................................................................. 13 4.4 Pump Inservice Test Table ................................................................................................. 15 4.5 Proposed Pump Test Flow Paths ..................................................................................... 17 4.6 Records and Reports of Pumps ........................................................................................ 30 4.7 Technical Positions ................................................................................................................. 34 4.8 Relief Requests From Certain Subsection ISTB Requirements .......................................... 38 5.0 VALVE INSERVICE TESTING PROGRAM ........................................................................ 62 5 .1 Intro d u ctio n ............................................................................................................................. 62 5.2 Program Implementation ................................................................................................... 62 5.2.1 Exemptions (ISTC-1200) ........................................................................................ 62 5.2.2 Valve Categories (ISTC-1 300) ............................................................................... 63 5.2.3 Preservice Testing (ISTC-31 00) ............................................................................ 63 5.2.4 Inservice Testing (ISTC-3200) .............................................................................. 63 5.2.5 Reference Values (ISTC-3300) ............................................................................... 64 5.2.6 Valve Testing Requirements (ISTC-3500) ............................................................. 64 5.2.7 Exercising Test Frequency (ISTC-3510) ................................................................. 65 5.2.8 Valve Obturator Movement (ISTC-3530) ............................................................... 65 5.2.9 Manual Valves (ISTC-3540) ................................................................................... 65 5.2.10 Fail-Safe Valves (ISTC-3560) ................................................................................. 65 5.2.11 Valves in Systems Out of Service (ISTC-3570) ...................................................... 65 v

IST Program Plan Columbia Generating Station 3rd 10-Year Interval Revision 1 TABLE OF CONTENTS (Contd.)

Page 5.2.12 Valve Seat Leakage Rate Test (ISTC-3600) .......................................................... 66 5.2.13 Position Verification Testing (ISTC-3700) ............................................................... 66 5.2.14 Instrumentation (ISTC-3800) ................................................................................. 66 5.2.15 Specific Testing Requirements (ISTC-5000) .......................................................... 66 5.2.16 Check Valve Condition Monitoring Program Implementation ................................. 67 5.2.17 Vacuum Breaker Valves (ISTC-5230) ................................................................... 67 5.2.18 Safety and Relief Valve Tests (ISTC-5240) ............................................................. 67 5.2.19 Rupture Disks (ISTC-5250) ................................................................................... 68 5.2.20 Explosively Actuated Valves ................................................................................... 68 5.2.21 Test Procedure ..................................................................................................... 68 5 .2 .2 2 T re nd ing ..................................................................................................................... 68 5.3 Valve Test Tables ................................................................................................................... 69 5.4 Inservice Testing Program Notes .......................................................................................... 120 5.5 Records and Reports of Valves ............................................................................................ 125 5.6 Technical Positions ............................................................................................................... 128 5.7 Cold Shutdown Justifications ................................................................................................ 140 5.8 Refueling Outage Justifications ............................................................................................ 154 5.9 Relief Requests From Certain Subsection ISTC and Mandatory Appendix I R e q u ire m e nts ....................................................................................................................... 172 vi

IST Program Plan Columbia StationPage 1 of 185 3rd 10-Year Interval Generating Revision 1

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 C uia h. Gin Page 2of 185 3rd 10-Year Interval eneran Station Revision 1 1.1 Program Administration Responsibilities for development, maintenance, and implementation of the IST 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.

IST Program Plan Columbia StationPage 3of 185 3rd 10-Year Interval Generating Revision 1 The Columbia Generating Station has fully implemented all applicable regulatory limitations in the update to the 3rd 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.

IST Program PIl an Page 4 of 185 3rd 10-Year Interrval Columbia Generating Station Revision 1 1.3 Reference8s 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

IST Program Plan Page 5 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 2.0 QUALITY 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 Generating Station Page 6 of 185 3rd 10-Year Interval Revision 1 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. Ref.

Title No. Title No.

Main & Exhaust Steam System M502 Reactor Recirculation Cooling M530 Control & Service Air M510 Equipment Drain Radioactive M537 Diesel Oil & Misc. Systems M512 Floor Drain Radioactive M539 Demineralized Water M517 Containment Cooling & Purge M543 Reactor Core Isolation Cooling M519 Standby Gas Treatment M544 High/Low Pressure Core Spray M520 Reactor Building HVAC M545 Residual Heat Removal M521 Containment Atmosphere Control M554 Standby Liquid Control M522 Containment Instrument Air M556 Reactor Water Cleanup M523 Main Steam Leakage Control M557 Undervessel Neutron Monitoring M604 Standby Service Water M524 System Reactor Closed Cooling M525 Class I Air System for Containment M619 Vacuum Breaker Valves Sh 161 Fuel Pool Cooling M526 Emergency Chilled Water M775 Control Rod Drive M528 Post Accident Sampling M896 Main Steam and Reactor Feedwater M529

IST Program Plan Columbia StationPage 7of 185 3rd 10-Year Interval Generating Revision 1 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.

IST Program Plan Columbia Generating Station8 of 185 3rd 10-Year Interval Revision 1 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 5310.

IST Program Plan Columbia Station Page 9 of 185 3rd 10-Year Interval CiGenerating Revision 1 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-320.

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 When a Group A test is required, a Comprehensive test may be substituted. When a Group B test is required, a Group A or Comprehensive test may be substituted. A preservice test may be substituted for any inservice test (ISTB-5000).

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 Columbia Station Page 10 of 185 3rd 10-Year Interval Generating Revision 1 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 Group A and Comprehensive and Quantity Group B Test, % Preservice Tests, %

Pressure +2 +/-1/2 Flow rate +2 +/-2 Speed +2 +/-2 Vibration +5 +/-5 Differential pressure +2 +/-1/2 NOTE: Refer to PER 297-1048, Columbia response to NRC Information Notice 97-90 for effect of instrument uncertainty on the acceptance criteria.

IST Program Plan Columbia Generating Station Page 11 of 185 3rd 10-Year Interval Revision 1 4.2.9 Inservice Test Parameters (ISTB-3500)

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

Differential Pressure (AP) - 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 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, AP 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, Vv ...... ............ ...... Peak NOTE:

(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 Station12 of 185 3rd 10-Year Interval Revision 1 4.2.10 Allowable Ranges For Test Parameters ISTB Subsection Table-51 00-1, 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 185 3rd 10-Year Interval CiGenerating Revision 1 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-1A, 1B, 2 These pumps transfer diesel generator fuel oil from the subterranean storage tanks to the diesel's day Tanks. Pump 2 is dedicated to the HPCS Diesel. The discharge lines of Pump 1A and 1B are cross tied, and each pump can supply fuel to either Diesel 1 A or 1B.

FPC-P-1A, 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-1 takes suction from the suppression pool.

IST Program Plan Generati Page 14 of 185 3rd 10-Year Interval Columbia Station Revision 1 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.

0 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) 0 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-1A, 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-1A, 1B The Standby Service Water pumps supply cooling water to separate trains of safety related equipment. The pumps take suction on their respective spray ponds but discharge to the opposite pond. The two spray ponds constitute the ultimate heat sink.

ST Program Plan StPage 15 of 185 3rd 10-Year Interval Columbia G Revision 1 4.4 Pump Inservice Test Table The pumps included in the Columbia Generating Station IST Program are listed in the Test Table. The information contained in this table identifies those pumps required to be tested to the requirements of 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 PogramPlanPage 16 of 185 3rdlS1Prgrm-Year Intervala Columbia Generating Station Revision 1 Pump Inservice Test Table Inlet Disch Diff Flow Vib Press Press Press Rate Vel Relief Flow ASME Requests &

Pump Diagram Code Pi P AP Pump Technical Pump Ident Group & Coord Class Pump Type Q CPT Q CPT Q CPT Q CPT Q CPT Speed Positions DO-P-lA. M512-4 Vertical Line TP03 B10 Shaft DO-P-1B* M512-4 Vertical Line TP03 Gl10 Shaft M512-4 Vertical Line C2 Shaft FPC-P-1A A M526-1 3 Centrifugal Q 2Y 0 2Y Q 2Y 0 2Y Q 2Y NR 7 El13 I__ I _I M526-1 FPC-P-1B A C13 3 Centrifugal Q 2Y Q 2Y 0 2Y Q 2Y Q 2Y NR 7 HPCS-P-1 B M520 2 Vertical Line Q 2Y Q 2Y Q 2Y Q 2Y NR 2Y NR 4,5,7,TP02

______ _ __ B6 ShaftI HPCS-P-2 A M524-1 Vertical Line N/A Q 2Y N/A Q 2Y Q 2Y NR 1,3,7,TP02

__ _ _ _ _ G5 Shaft IIII_

LPCS-P-1 B M520 2 Vertical Line Q B12 Shaft Q 2Y 0 2Y Q2Y 2Y NR 2Y NR 4,7,TP02 M51 9 RCIC-P-1 B D12 2 Centrifugal Q 2Y Q 2Y 0 2Y Q 2Y NR 2Y Q/2Y 4,7 RHR-P-2A A M521-1 Vertical Line Q 2Y Q 2Y Q 2Y Q 2Y Q 2Y NR 4,5,7,TP02 u

B11 Shaft ____

M521-2 Vertical Line RHR-P-2B A D6 2 Shaft Q 2Y Q 2Y Q 2Y Q 2Y Q 2Y NR 4,5,7,TP02 RHR-P-2C A M521-3 2 Vertical Line Q 2Y Q 2Y Q 2Y Q 2Y Q 2Y NR 4,5,7,TP02

__ __ __ __ _ C5 ShaftI SLC-P-lA B M522 Reciprocating NR Q 2Y NR 0 2Y NR 2Y NR 6,7 SLC-P-1A_ B____ F6 2 Positive Disp. NR QR R SLC-P-1B B M522 Reciprocating NR Q 2Y NR Q 2Y NR 2Y NR 6,7 SLC-P-1B B D6 2 Positive Disp. NR IN SW-P-1A A M524-1 Vertical Line N/A Q 2Y N/A Q 2Y Q 2Y NR 1,3,7,TP02 G4 _ _ Shaft __ __ _ _ _ _ _

A S-B M524-2 Vertical Line N/A Q 2Y N/A 0 2Y Q 2Y NR l,3,7,TPO2 SW-P-1B _A F5 Shaft N/A I

• Tested as skid mounted components.

ST Program Plan CoPage 17 of 185 3rd 1-Year Interval Columbia Generating Station Revision 1 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 Page 18 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 DO-P-1 A, DO-P-1 B, & DO-P-2 PUMP TEST FLOW PATH V-12 V-11 N

I)

REFERENCES, P&ID M512 SH 4 IST.383

&Biw4nfOB 2M0 ApU1, DIESEL FUEL OIL

ST Program Plan CoPage 19 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 FPC-P-1 A and FPC-P-1 B PUMP TEST FLOW PATH

REFERENCE:

V-1\11-V-6A V-173 P&ID M526 IST,37 drawing file Jan 2013 FUEL POOL COOLING

IST Program Plan Page 20 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 HPCS-P-1 PUMP TEST FLOW PATH 20" REFERENCES, P&ID HPCS-P-1 M520 IST.38 drawing file FEB, 2013 HIGH PRESSURE CORE SPRAY

IST Program Plan Page 21 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 HPCS-P-2 PUMP TEST FLOW PATH 2 1/2" (TYP)

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

ST Program Plan CoPage 22 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 LPCS-P-1 PUMP TEST FLOW PATH ROA4 l2 V-60

" P1

~j~i~] REFERENCES, FE-2 P&ID LI] 24" M520 V-32I LPCS-P-1 IST.40 drawing file January 31, 2005 LOW PRESSURE CORE SPRAY

Page 23 of 185 IST Program Plan 3rd 10-Year Interval Columbia Generating Station Revision 1 RCIC-P-1 PUMP TEST FLOW PATH FE-1 6"

-~ RCI-P-i REFERENCES, P&ID M519 16I IST.41 drawing file V-10 V-11 Feb 2013 REACTOR CORE ISOLATION COOLING

IST Program Plan Page 24 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 RHR-P-2A P1 MP TERT FLOW PATH RESIDUAL HEAT REMOVAL

IST Program Plan Page 25 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 RHR-P-2B PUMP TEST FLOW PATH FE-14B 18" 18" REFERENCES, P&ID 5-M521 SH 2 14" IST.43 drawing file RO-58 -L V-31 B V-1I lOB January 31, 2005 RHR-PE-2B RESIDUAL HEAT REMOVAL

ST Program Plan CoPage 26 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 RHR-P-2C PUMP TEST FLOW PATH IF 18"

-L V-21 V-4C V-729C VENT--/

STRAINER

-FE-14iC V-728C PT V-705C '

REFERENCES, P&ID M521 SH 3 I R" V-110C V-31C RO-5C IST.44 drawing file January 31, 2005 RHPR-E2C RESIDUAL HEAT REMOVAL

IST Program Plan Page 27 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 SLC-P-1A & SLC-P-1 B PUMP TEST FLOW PATH DEMIN WATER SUPPLY "

REACTOR VESSEL.

SUP$_ ESSON IST.45 drawing file MAY 24, 1999 V-2B STANDBY LIQUID CONTROL

IST Program Plan Page 28 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 SW-P-1A PUMP TEST FLOW PATH V-2A RKRM:X*XA 18" 20V 20" 4,I RO-2A REFERENCES, P&ID IST.46 drawing file M524 SH I January 31, 2005 SERVICE WATER

IST Program Plan Columbia Generating Station Page 29 of 185 3rd 10-Year Interval Revision 1 SW-P-1 B PUMP TEST FLOW PATH PUMP HOUSE WALL 12" PCV-38B V-1 2B V-165B 4--H

.. I1 I-PUMP T F SPRAY IIOUSE-A PON DA REFERENCES, IST.47 drawing file P& I D January 31, 2005 M524 SH 2 SERVICE WATER

IST Program Plan Columbia Generating Station30 of 185 3rd 10-Year Interval Revision 1 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 Station Page 31 of 185 3rd 10-Year Interval CiGenerating Revision 1 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) (+1) Measured Value (+1)

Driver Lubrication N/A SAT N/A N/A UNSAT Upper Thrust Bearing OF 152 N/A N/A N/A Temperature per Wi139 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 SW-FI-17A2 Suction Pressure at Test Flow PSIG 15.3 9.2 N/A N/A per Test Gauge 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 X1 63 (+4)

Fluid Temperature per OF 70 N/A N/A N/A CMS-TR-5 or TR-6, PT220 Motor Voltage per SM7 Volts VAC 4140 N/A N/A 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 40OF.

(+5) Discharge pressure is required to be GE the corrected discharge pressure for the flow listed in Attachment 9.6.

ST Program Plan CoPage 32 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 SAMPLE DATA SHEET VIBRATION DATA SHEET FOR RHR-P-2A MUA MUN MUW MIN PA PN VIBRATION VELOCITY (IN/SEC)

PROBE REFER MEASURED ALERT HI ACTION HI LOCATION VALUE VALUE (+1) (+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 MLW 0.042 N/A N/A NON-ASM PA 0.155 N/A N/A ASME PN 0.082 N/A N/A PW 0.037 N/A N/A

1. (+1) For measured values beyond the Alert Value or Action Value refer to Precaution and Limitations 4.5 or 4.6, respectively.

IST Program Plan Page 33 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 SAMPLE DATA SHEET - Group A Test RHR-P-2A ACCEPTANCE CRITERIA 129 ---- - - - - - - - - - - -

121- - -- - - - - - - - - - - - -

1 22-- -- - - -- - - -- - -

125--ACtINRAPGE P#2 114----

112-111--

114--

21 0 9- -2 1007-104 -----------------------------

103 - _AN 7E

93. - -CT -N -A - -

7490 7500 7510 7520 753 7S40 755D 7W60 7570 7580 7590 7600 7610 7620 7630 7640 7650 INDICATED FLOW - G1PM ALERT RANGE =Area Inside 3-4-5-6 AMfON RANGE - Area Outside 1-2-34

IST Program Plan Columbia Generating StationPage 34 of 185 3rd 10-Year Interval Revision 1 4.7 Technical Positions Technical Position - TP01 (DELETED)

IST Program Plan Generating Page 35 of 185 3rd 10-Year Interval Columbia Station Revision 1 Technical Position - TP02 Pump Code Class P&ID Dwg. Number System(s)

HPCS-P-1 2 M520 High Pressure Core Spray HPCS-P-2 3 M524, SH 1 Standby Service Water HPCS LPCS-P-1 2 M520 Low Pressure Core Spray RHR-P-2A 2 M521 SH 1 Residual Heat Removal RHR-P-2B 2 M521 SH 2 Residual Heat Removal RHR-P-2C 2 M521 SH 3 Residual Heat Removal SW-P-1A 3 M524 SH 1 Standby Service Water SW-P-1 B 3 M524 SH 2 Standby Service Water Title Vertical Line Shaft Pumps (Listed Above).

Issue Discussion ISTB-2000, Supplemental Definitions. Defines a vertical line shaft pump as a vertically suspended pump where the pump driver and pump element are connected by a line shaft within an enclosed column.

Position Traditionally a vertical line shaft (VLS) pump as defined by the OM Code, Subsection ISTB-2000, is a vertically suspended pump where the pump driver and pump element are connected by a line shaft within an enclosed column. The primary concern associated with a VLS pump in regards to inservice testing is the inability to perform vibration measurements near the pump end of the component.

Typically, many VLS pumps have 20 or 30 foot shafts connecting the driver to the pump and therefore vibration measurements and, in many cases, hydraulic measurements are difficult and not representative of the condition of the machine. As a means to "compensate" for this weakness in IST, the OM Code has developed guidance along with more conservative measurement criteria and parameters to provide additional methods in ascertaining the operational readiness of VLS pumps. The acceptance criteria for VLS pumps is also more restrictive to allow for action to be taken conservatively regarding the degradation or potential degradation of the VLS pumps.

At the Columbia Generating Station, there are several pumps designated as VLS (as shown above),

which may not satisfy, in the traditional sense, the definition of a VLS pump. However, upon review and evaluation of the design of the pumps with regards to the "IST concern" associated with Code defined VLS pumps, it has been determined at the Columbia Generating Station, to consider all of the pumps listed above as VLS pumps. All of the above listed pumps have a discharge head which supports the pumping element that is inaccessible to vibration measurements. As such, the above listed pumps meet the VLS testing methodology and acceptance criteria as stated in the OM Code.

The Pump Inservice Test Table provides a complete listing of the pumps and their designations.

IST Program Plan Columbia Station Page 36 of 185 3rd 10-Year Interval Generating Revision 1 Technical Position - TP03 Pump Code Class P&ID Dwg. Number System(s)

DO-P-1A 3 M512, SH 4 DO-P-1B 3 M512, SH 4 Diesel Fuel Oil Transfer DO-P-2 3 M512, SH 4 Title Classification of diesel fuel oil transfer pumps as skid mounted components.

Issue Discussion ASME OM Code 2001 Edition through 2003 addenda, Section ISTA-2000, defines skid mounted pumps and valves as follows:

"Pumps and valves integral to or that support operation of major components, even though these pumps and valves may not be located directly on the skid. In general, these pumps and valves are supplied by the manufacturer of the major component. Examples include:

(a) diesel fuel oil pumps and valves; (b) steam admission and trip throttle valves for high-pressure coolant injection turbine-driven pumps; (c) steam admission and trip throttle valves for auxiliary feedwater turbine-driven pumps; (d) solenoid-operated valves provided to control an air-operated valve."

Per ISTB-1200(c), skid mounted pumps that are tested as part of the major component and are justified by the Owner to be adequately tested, can be excluded from the testing requirements of subsection ISTB.

NUREG-1 482 Rev. 1, Section 3.4 states that the NRC staff has determined that the testing of the major component is an acceptable means for verifying the operational readiness of the skid-mounted and component subassemblies if the licensee documents this approach in the IST Program. This is acceptable for both Code class components and non-Code class components that are tested and tracked by the IST Program.

Position Thus these pumps are classified as skid mounted pumps and are adequately tested as a part of the diesel generator system and are exempt from the testing requirements of subsection ISTB.

Technical Specification surveillance SR 3.8.1.6 demonstrates that each required fuel oil transfer pump operates and automatically transfers fuel oil from its associated storage tank to its associated day tank.

This quarterly surveillance provides assurance that the fuel oil transfer pump is operable, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control system for automatic fuel transfer systems are operable. Technical Specification surveillance SR 3.8.1.4 monthly verifies that each day tank contains GE 1400 gallons of fuel oil. This SR provides verification that the level of fuel oil in the day tank is at or above the level at which the low level alarm is annunciated.

During the 24-hour DG run surveillance (SR 3.8.1.14) the fuel oil transfer pump cycles between the low and high day tank levels to keep up with the fuel consumption. These tests provide reasonable assurance that any mechanical or electrical deficiency will be detected and corrected before it can result in failure of an emergency power supply to respond when called upon to function.

IST Program Plan Columbia Station Page 37 of 185 3rd 10-Year Interval CiGenerating Revision 1 Technical Position - TP03 (Contd.)

The actual flow rate for the diesel fuel oil transfer pumps is several times the maximum engine consumption rate and is automatically controlled by level switches activated by the day tank fuel level.

The maximum fuel oil consumption rate for diesel generator 1 and 2 is 340 gallons per hour and for the HPCS diesel generator is 200 gallons per hour. Even a large reduction in a pump flow rate will not affect system operability.

Additional testing for these pumps will be performed at the Owner's discretion.

References

1. FSAR 9.5.4, Diesel Generator Fuel Oil Storage and Transfer System

2. G02-07-052. Proposed relief requests RP02 and RP08 for third ten-year interval were withdrawn after discussion with the NRC staff. It was agreed to classify diesel fuel oil transfer pumps as skid mounted pumps.

3. OSP-DO/IST-Q701, Q702, Q703.

4. OSP-ELEC-M701, 702, 703.

5. TSP-DG1 -B502, TSP-DG2-B502, TSP-DG3-B502.

IST Program Plan Columbia Generating Station Page 38 of 185 3rd 10-Year Interval Revision 1 4.8 Relief Requests From Certain Subsection ISTB Requirements Relief Requests either provide alternative to Code requirements in accordance with 10 CFR 50.55a(a)(3)(i) or 10 CFR 50.55a(a)(3)(ii) or relief from impractical Code requirements in accordance with 10 CFR 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 39 of 185 3rd 10-Year Interval Revision 1 Relief Request - RP01 Proposed Alternative in Accordance with 10 CFR 50.55a(a)(3)(i)

- Alternative Provides Acceptable Level of Quality and Safety -

ASME Code Comlonents Affected Code Pump PumpPump Class Cup Group P & ID Dwg. No. System(s)

SW-P-1A 3 A M524, SH 1 Standby Service Water SW-P-1 B 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, AP. 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-1 A, 1 B, 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.

IST Program Plan Columbia Generating Station Page 40 of 185 3rd 10-Year Interval Revision 1 Relief Request - RPO1 (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 = Pd -(-Ps)

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

CASE 1 CASE 2 Suction Lift Suction Head A

Discharge Head i

-- (-. -1\

Total KPs (Fd)

Discharge Head Suction Suction Head Lift Head 6*'lvý 1 7ý IST.RPO1 drawing file Jan 7, 2005

IST Program Plan Page 41 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RP01 (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 water 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.

Quality/Safety 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.

NRC Acceptance/SER Dated May 15, 2007 Relief granted as requested (G12-07-087).

IST Program Plan Columbia Station Page 42 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RP02 (DELETED)

Relief request withdrawn. Diesel Fuel Oil Transfer pumps qualify for classification as "skid mounted pumps" as defined in ISTA-2000 and therefore exclusion from ISTB pursuant to ISTB-1200.

(G02-07-052).

ST Program Plan CoPage 43 of 185 3rd 1P0-Year Interval Columbia Generating Station Revision 1 Relief Request - RP03 Relief Request in Accordance with 10 CFR 50.55a(f)(5)(iii)

- Inservice Testing Impracticality -

ASME Code Components Affected Pump Code Pump P&ID Dwg. Number System(s)

Class Group SW-P-1 A 3 A M524, SH 1 Standby Service Water SW-P-1 B 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 ADDlicable Code Reluirement 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 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

IST Program Plan Page 44 of 185 3rd 10-Year Interval Generating Revision 1 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-1 A and SW-P-1 B 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 RP01. 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.

IST Program Plan Columbia StationPage 45 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RP03 (Contd.)

1. A reference pump curve (flow rate vs discharge pressure) has been established for SW-P-1A and SW-P-1iB 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-1 A pump Acceptance Criteria sheet for Group A test. Area 1 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.

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.

IST Program Plan Columbia Generating Station46 of 185 3rd 10-Year Interval Revision 1 Relief Request - RP03 (Contd.)

Quality/Safety 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.

NRC Acceptance/SER Dated May 15, 2007 Relief granted as requested (G12-07-087).

IST Program Plan Columbia Station Page 47 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RP03 (Contd.)

SAMPLE DATA SHEET - GrouD A Test SW-P-1A ACCEPTANCE CRITERIA 10

"*'* ACTION RJGE 0-4 CA, REF. CURN 220-20D 195 ALER R NG6 190-IR.S 9.330 9.430 933M 9.630 9.730 9.330 9.930 10.03 10.130 10.230 FLOW - GPM (ThnA)

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

IST Program Plan Generating 48 of 185 Paemba 3rd 10-Year Interval Station Revision 1 Relief Request - RP04 Relief Request in Accordance with 10 CFR 50.55a(f)(5)(iii)

- Inservice Testing Impracticality -

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

Number 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 (Centrifuaal PumDo:

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 PumDs (Vertical line Shaft Centrifuaal PumDs):

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

IST Program Plan Columbia Generating Station49 of 185 3rd 10-Year Interval Revision 1 Relief Request - RP04 (Contd.)

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 C Genertin S Page 50 of 185 3rd 10-Year Interval olumba neran Revision 1 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 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-5100-1 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 _enerating Page 51 of 185 3rd 10-Year IntervalCaG Station Revision 1 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.

Quality/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.

NRC Acceptance/SER Dated March 23, 2007 Relief granted as requested (G12-07-053).

IST Program Plan Columbia Station Page 52 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RP04 (Contd.)

SAMPLE DATA SHEET - Group A Test RHR-P-2A ACCEPTANCE CRITERIA 129- - - - - - - - - - - - -

127: - - - - - - - - - - -

126- AMPN(RA 1GEI 1234 - -- ---------

121:0 117 cjn 1186 116 --------

114:

2 113---- ---

1102- - - - - - -

107--:-

102 - - - - - - -

102----------------------

7490 7300 7510 7320 7330 7340 735D 7560 7570 7380 730 7600 7610 7620 7630 7640 7650 INDICATED FLOW - GPM ALERT RANGE - Area Inside 34-5-6 ACTON RANGE - Ame Outside.1-2-34

ST Program Plan CoPage 53 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 Relief Request - RP04 (Contd.)

SAMPLE DATA SHEET - GrouD B Test RCIC-P-1 ACCEPTANCE CRITERIA 2

1325-_________________ ________

1315 iŽ-it 1305-1295-12153 1275$

U4 1215-120$_ _ _

19-r - _ F __T __ F _F T__ T __ TT_ T _

3 4410 4430 4450 4470 4490 4510 4530 45*50 45M7 4590 PUMP/TURBINE SPEED (RPM'S)

ACTION RANGE - Area Outside 1-2-3-4

IST Program Plan Page 54 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RP05 Proposed Alternative in Accordance with 10 CFR 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 ApDlicable Code Reauirement 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-PT-4),

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 Generating Station Page 55 of 185 3rd 10-Year Interval Revision 1 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 1.D. (PSIG) (PSIG) Accuracy Accuracy RHR-P-2A Discharge RHR-PT-37A 0-600 136 +/- 1%, [6/(3x136)]x100 Pressure TDAS PT 155 +/- 6 psig =1.47%

RHR-P-2B Discharge RHR-PT-37B 0-600 132 +/- 1%, [6/(3x132)]x1OO Pressure TDAS PT 076 +/- 6 psig =1.52%

RHR-P-2C Discharge RHR-PT-37C 0-600 143 +/- 1%, [6/(3x143)]xlOO Pressure TDAS PT 091 +/- 6 psig =1.40%

HPCS-P-1 Discharge HPCS-PT-4 0-1500 430 + 1%, [15/(3x430)]xlOO Pressure TDAS PT 107 +/- 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 +/-1.5 percent for pressure and differential pressure instruments for Preservice and Comprehensive tests).

IST Program Plan Columbia StationPage 56 of 185 3rd 10-Year Interval Revision 1 Relief Request - RP05 (Contd.)

Quality/Safety 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.

NRC Accentance/SER Dated March 23, 2007 Relief granted as requested (G12-07-053).

IST Program Plan Gene tin Page 57 of 185 3rd 10-Year Interval Columbia Station Revision 1 Relief Request - RP06 Proposed Alternative in Accordance with 10 CFR 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 ADDlicable 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 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.

IST Program Plan Columbia Station Page 58 of 185 3rd 10-Year Interval m Generating Revision 1 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.

Quality/Safety 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.

NRC AcceDtance/SER Dated May 15.2007 Relief granted as requested (G12-07-087).

IST Program Plan Columbia StationPage 59 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RP07 Proposed Alternative in Accordance with 10 CFR 50.55a(a)(3)(i)

- Alternative Provides Acceptable Level of Quality and Safety -

ASME 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 Station Page 60 of 185 3rd 10-Year Interval Generating Revision 1 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.

NRC Acceptance/SER Dated March 23, 2007 Relief granted as requested (G12-07-053).

IST Program Plan Columbia StationPage 61 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request- RP08 (DELETED)

Relief request withdrawn. Diesel Fuel Oil Transfer pumps qualify for classification as "skid mounted pumps" as defined in ISTA-2000 and therefore exclusion from ISTB pursuant to ISTB-1200.

(G02-07-052).

IST Program Plan Page 62 of 185 3rd 10-Year Interval Generating Revision 1 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 Page 63 of 185 3rd 10-Year Interval Generating Revision 1 5.2.2 Valve Categories (ISTC-1 300)

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-1 100;

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- 1100;

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-1 100;

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 Page 64 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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 Leakage Test Exercise Test Special Test Position Indication ISTC-1 300 Function Procedure & Procedure & Procedure [Note Verification &

Frequency Frequency (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 Station Page 65 of 185 3rd 10-Year Interval m Generating Revision 1 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 ISTO-3700. A two year test frequency is required by the 10 CFR50.55a(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-351 0. 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 fail-safe tested 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 Page 66 of 185 3rd 10-Year Interval Columbia Station Revision 1 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, 10 CFR 50.55a(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 Columbia StationPage 67 of 185 3rd 10-Year Interval Generating Revision 1 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.

IST Program Plan ColGeneratin Page 68 of 185 3rd 10-Year Interval CStation Revision 1 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.

IST Program Plan Page 69 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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 G e tin Station Page 70 of 185 3rd 10-Year Interval Generating Revision 1 (4b) VALVE Type - 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)

O = 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

IST Program Plan Page 71 of 185 3rd 10-Year Interval Columbia Station Revision 1 (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 <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after cold shutdown is achieved and continue until complete or until the Plant is ready to return to power.

IST Program Plan Columbia StationPage 72 of 185 3rd 10-Year Interval Generating Revision 1 EX Test explosive valve per ISTC-5260 schedule.

FS Test performed per FSAR Commitment 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.a. 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 Page 73 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 Valve Test Tables CAC System Valves DELETED, CAC System Deactivated per PDC 4533 and PDC 3539 I

IST Program Plan Columbia Generating Station Page 74 of 185 3rd 10-Year Interval Revision 1 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)

CAS-V-29A M510-2A 3 SA C HL RF OSP-MSIV/IST-R701 ROJO2 THRU D J8 AC CK NA 0.50 NC DESCRIPTION: CAS TO MS-V-28A,B,C,D (MSIV) OPERATOR CHK CAS-V-730 M510-2 2 MA C L J TSP-CAS/X82e-C801 TV02 H12 A GB NA Passive I LC DESCRIPTION: AIR LINE ISO FOR TESTING WW-DW VACUUM BRKRS (CIV)

CAS-VX-82E M510-2 2 MA C L J TSP-CAS/X82e-C801 TV02 H12 A GB NA Passive 1 LC DESCRIPTION: AIR LINE ISO FOR TESTING WW-DW VACUUM BRKRS (CIV)

CEP-V-1A M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 H8 A BF FC HJK Q OSP-CONT/IST-Q701 30 NC L 2Y TSP-CEP/X3-R801 DESCRIPTION: DRYWELL EXHAUST (CIV)

CEP-V-1B M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 H8 A GB FC HJK Q OSP-CONT/IST-Q701 2 NC L 2Y TSP-CEP/X3-R801 DESCRIPTION: CEP-V-1A BYPASS (CIV)

CEP-V-2A M543-3 2 AO C G 2Y OSP-CONT/IST-0701 TV01,2 H7 A BF FC HJK Q OSP-CONT/IST-Q701 30 NC L 2Y TSP-CEP/X3-R801 DESCRIPTION: DRYWELL EXHAUST (CIV)

CEP-V-2B M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 H7 A GB FC HJK Q OSP-CONT/IST-Q701 2 NC L 2Y TSP-CEP/X3-R801 DESCRIPTION: CEP-V-2A BYPASS (CIV)

CEP-V-3A M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TI01,2 G9 A BF FC HJK Q OSP-CONT/IST-Q701 24 NC L 2Y TSP-CEP/X67-R802 DESCRIPTION: SUPPRESSION CHAMBER EXHAUST (CIV)

CEP-V-3B M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 G9 A GB FC HJK Q OSP-CONT/IST-Q701 2 NC L 2Y TSP- CEP/X67-R802 DESCRIPTION: CEP-V-3A BYPASS (CIV)

CEP-V-4A M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 E9 A BF FC HJK Q OSP-CONT/IST-Q701 24 NC L 2Y TSP- CEP/X67-R802 DESCRIPTION: SUPPRESSION CHAMBER EXHAUST (CIV)

[1ST Program Plan (a.m iGe rtngPage 75 of 185 3rd 1P0-Year Interval Columbia Generating Station Revision 1 Valve Test Tables Type Position Actuat Safety, Testing Remarks Failed, Exceptions (Notes &

Dwg & Class Valve Normal (CSJ/ROJ/ Technical Valve EPN Coord & Cat & Size Tests, Frequency & PPM Reliefs) Position)

CEP-V-4B M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 E9 A GB FC HJK Q OSP-CONT/IST-Q701 2 NC L 2Y TSP-CEP/X67-R802 DESCRIPTION: CEP-V-4A BYPASS (CIV)

CIA-RV-5A M556-1 3 SA NA P RV TSP-RV/IST-R701 TV03 H11 C RV CT

.75 X 1 NC DESCRIPTION: CIA TRAIN "A"NITROGEN HEADER RV CIA-RV-5B M556-1 3 SA NA P RV TSP-RV/IST-R701 TV03 D1l C RV NA

.75 X 1 NC DESCRIPTION: CIA TRAIN "B" NITROGEN HEADER RV CIA-SPV-lA M556-1 3 so 0 HJK RF OSP-CIA/IST-R702 ROJ15 N03 THRU 15A G12 B SV FO TV01 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE AUTO ISO CIA-SPV-1B M556-1 3 so 0 HJK RF OSP-CIA/IST-R702 ROJ15 N03 THRU 19B B12 B SV FO TV01 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE AUTO ISO CIA-V-20 M556-1 2 MO C G 2Y OSP-CIA/IST-Q701 CSJ03 TV01,2 K8 A GB FAI HJ CS OSP-CIA/IST-Q701 0.75 NO L J TSP-CIA/X56-C801 DESCRIPTION: NORMAL CIA SUPPLY TO CONTAINMENT (OTBD CIV)

CIA-V-21 M556-1 2 SA O/C Hx 8Y OSP-CIA/IST-R701 ROJO2 TV02 K6 AC CK NA HxL J TSP- CIA/X56-C801 CMP-01 0.75 NO DESCRIPTION: NORMAL CIA SUPPLY TO CONTAINMENT CHK (INBD CIV)

CIA-V-24A M556-1 2 SA C HL RF OSP-MSIV/IST-R701 ROJO2 J5 AC CK NA 0.50 NC DESCRIPTION: CIA TO MS-V-22A (MSIV) OPERATOR CHK CIA-V-24B M556-1 2 SA C HL RF OSP-MSIV/IST-R701 ROJO2 J4 AC CK NA DESCRIPTION: CIA0.50 NC (MSIV) OPERATOR CHK TO MS-V-22B CIA-V-24C M556-1 2 SA C HL RF OSP-MSIV/IST-R701 ROJI2 K5 AC CK NA 0.50 NC DESCRIPTION: CIA TO MS-V-22C (MSIV) OPERATOR CHK CIA-V-24D M556-1 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

IST Program Plan Page 76 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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)

CIA-V-30A M556-1 2 MO O/C G 2Y OSP-CIA/IST-Q701 CSJ03 TV01,2 G9 A GB FAI HJ CS OSP-CIA/IST-Q701 0.50 NO L J TSP-CIA/X89B-C801 DESCRIPTION: CIA SUPPLY TO 3 ADS ACCUMULATORS ISO (CIV)

CIA-V-30B M556-1 2 MO O/C G 2Y OSP-CIA/IST-Q701 ]CSJ03 TV01,2 F9 A GB FAI HJ CS OSP-CIA/IST-Q701 0.50 NO L J TSP-CIA/X91-C801 DESCRIPTION: CIA SUPPLY TO 4 ADS ACCUMULATORS ISO (CIV)

CIA-V-31A M556-1 2 SA O/C Hx 8Y OSP-CIA/IST-R701 ROJO2 TV02 G7 AC CK NA HxL J TSP-CIA/X89B-C801 CMP-01 0.50 NO DESCRIPTION: CIA SUPPLY TO 3 ADS ACCUMULATORS CHK (INBD CIV)

CIA-V-31B M556-1 2 SA O/C Hx 8Y OSP-CIA/IST-R701 ROJO2 TV02 F7 AC CK NA HxL J TSP-CIA/X91-C801 CMP-01 0.50 NO DESCRIPTION: CIA SUPPLY TO 4 ADS ACCUMULATORS CHK (INBD CIV)

CIA-V-39A M556-1 3 AO C G 2Y OSP-CIA/IST-Q702 CSJ04 TV01 J10 B BA FC HJK CS OSP-CIA/IST-Q702 0.50 NO DESCRIPTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER ISO CIA-V-39B M556-1 3 AO C G 2Y OSP-CIA/IST-Q702 CSJ04 TV01 E10 B BA FC HJK CS OSP-CIA/IST-Q702 0.50 NO DESCRIPTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER ISO CIA-V-40M M556-1 2 SA O/C H RF OSP-CIA/IST-R701 ROJ02 (TYP 7) B5 AC CK NA 0.50 NO DESCRIPTION: CIA TO ADS ACCUMULATOR CHK CIA-V-41A M556-1 3 SA C Hx 4Y OSP-CIA/IST-R702 CSJ04 JC10 C CK NA Di 8Y CMP-17 0.50 NO DESCRIPTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER CHK CIA-V-41B M556-1 3 SA C Hx 4Y OSP-CIA/IST-R702 CSJ04 D10 C CK NA Di 8Y CMP-17 0.50 NOII DESCRIPTION: CIA NORMAL SUPPLY TO BACKUP SUPPLY HEADER CHK CIA-V-52A M556-1 3 SA 0 Hx 8Y OSP-CIA/IST-R702 ROJ15 THRU 66A G12 C CK NA CMP-02 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH CHK CIA-V-52B M556-1 3 SA 0 Hx 8Y OSP-CIA/IST-R702 ROJ15 THRU 70B C12 C CK NA CMP-02 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH CHK CIA-V-103A M556-1 3 SA 0 Hx 8Y OSP-CIA/IST-R702 ROJ15 H13 C CK NA CMP-02 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH CHK

IST Program Plan Columbia Generating Station Page 77 of 185 3rd 10-Year Interval Revision 1 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)

CIA-V-103B M556-1 3 SA 0 Hx 8Y OSP-CIA/IST-R702 ROJ15 D12 C CK NA CMP-02 1 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH CHK CIA-V-104A M556-1 3 MA O H 2Y OSP-CIA/IST-R702 H13 B GB NA 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH MAN ISO CIA-V-104B M556-1 3 MA 0 H 2Y OSP-CIA/IST-R702 D12 B GB NA 0.50 NC DESCRIPTION: CIA NITROGEN BOTTLE DISCH MAN ISO CRD-V-10 M528-1 2 AO C G 2Y OSP-CRD/IST-Q701 TV01 K6 B GB FC HJK Q OSP-CRD/IST-Q701 1 NO DESCRIPTION: SCRAM DISCH VOLUME VENT CRD-V-1 1 M528-1 2 AO C G 2Y OSP-CRD/IST-0701 TV01 F7 B GB FC HJK Q OSP-CRD/IST-Q701 2 NO DESCRIPTION: SCRAM DISCH VOLUME DRN CRD-V-114 M528-1 D SA 0 H TS TSP-CRD-C101 N05 (TYP 185) C4 C CK NA 0.75 NC DESCRIPTION: HCU TO SCRAM DISCH HEADER CHK CRD-V-115 M528-1 ID I SA C H RF OSP-CRD-R701 N05 (TYP 185) B7 C CK 1 NA NC DESCRIPTION: CHARGING WATER TO HCU CHK CRD-V-126 M528-1 D AO 1 0 H TS TSP-CRD-C101 N05 (TYP 185) B6 B DI FO 1 NC DESCRIPTION: HCU CONT-ROD INSERT WATER SCRAM VLV CRD-V-127 M528-1 D AO 10 H TS TSP-CRD-C101 N05 (TYP 185) C4 B DI I FO 0.75 NC DESCRIPTION: HCU CONT-ROD WITHDRAWAL WATER SCRAM VLV CRD-V-138 M528-1 D SA C tH 0 OSP-CRD-W701 N05 (TYP 185) B6 C CK NA

= 0.75 _ _NO DESCRIPTION: COOLING WATER TO HCU CHK CRD-V-180 M528-1 2 AO C G 2Y OSP-CRD/IST-Q701 TV01 K6 B GB FC HJK Q OSP-CRD/IST-Q701 1 NO DESCRIPTION: SCRAM DISCH VOLUME VENT CRD-V-181 M528-1 2 AO C G 2Y OSP-CRD/IST-Q701 TV01 F6 B GB FC HJK Q OSP-CRD/IST-Q701 2 NO CSP-RV-51 M619-161 2 C

I DESCRIPTION: SCRAM DISCH VOLUME DRN SA RV NA NA P RV TSP-RV/IST-R701 TV03

.75 X 1 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY HEADER TO CSP-V-5,6,9 RV

ST Program Plan CoPage 78 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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)

CSP-RV-52 M619-161 2 SA NA P RV TSP-RV/IST-R701 TV03 C RV NA 1 _ 1 _ 1.75 X 1 NC I DESCRIPTION: CSP-TK-51 RV (CONTROL AIR TO CSP-V-5,6,9)

CSP-V-1 M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 G4 A BF FC HJK Q OSP-CONT/IST-Q701 30 NC L 2Y TSP-CSP/X53-R802 DESCRIPTION: CSP TO CONTAINMENT ISO (CIV)

CSP-V-2 M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 G5 A BF FC HJK Q OSP-CONT/IST-Q701 30 NC L 2Y TSP-CSP/X53-R802 DESCRIPTION: CSP TO CONTAINMENT ISO (CIV)

CSP-V-3 M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 F3 A BF FC HJK Q OSP-CONT/IST-Q701 24 NC L 2Y TSP-CSP/X66-R803 DESCRIPTION: CSP TO CONTAINMENT ISO (CIV)

CSP-V-4 M543-3 2 AO C G 2Y OSP-CONT/IST-Q701 TV01,2 E3 A BF FC HJK Q OSP-CONT/IST-Q701 1 1 24 NC L 2Y TSP-CSP/X66-R803 DESCRIPTION: CSP TO CONTAINMENT ISO (CIV)

CSP-V-5 M543-3 2 AO O/C GS 2Y ISP-CSP/IST-B 101 TV01,2 C2 A BF FO HJK Q OSP-CONT/IST-0701 24 NC L 2Y TSP-CSP/X66-R802 DESCRIPTION: CSP TO CONTAINMENT ISO (CIV)

CSP-V-6 M543-3 2 AO O/C FGS 2Y ISP-CSP/IST-B101 TV01,2 C9 A BF FO HJK 0 OSP-CONT/IST-Q701 1 24 NC L 2Y TSP-CSP/X67-R801 DESCRIPTION: CSP TO CONTAINMENT ISO (CIV)

CSP-V-7 M543-3 2 AO,SA 1 O/C tGS 2Y ISP-CSP/IST-B101 N02 C2 AC CK NA H Q ISP-CSP/IST-Q101 TV02 24 NC L 2Y TSP-CSP/X66-R802 DESCRIPTION: VACUUM RELIEF TO SUPPRESSION CHAMBER (CIV)

CSP-V-8 M543-3 2 AO,SA O/C GS 2Y ISP-CSP/IST-B101 N02 C10 AC CK NA H Q ISP-CSP/IST-Q101 TV02 24 NC L 2Y TSP-CSP/X67-R801 DESCRIPTION: VACUUM RELIEF (CIV)

CSP-V-9 M543-3 2 AO O/C IGS 2Y ISP-CSP/IST-B101 TV01,2 C5 A BF FO HJK Q OSP-CONT/IST-Q701 1 24 NC L 2Y TSP-CSP/X119-R801 DESCRIPTION: VACUUM RELIEF TO SUPPRESSION CHAMBER (CIV)

CSP-V-10 M543-3 2 AO,SA O/C GS 2Y ISP-CSP/IST-B101 N02 C4 AC CK NA H Q ISP-CSP/IST-Q101 TV02 24 NC L 2Y TSP-CSP/X119-R801 DESCRIPTION: VACUUM RELIEF (CIV)

CSP-V-65 M619-161 2C SA HL RF OSP-CSP/IST-R701 ROJO9 AC CK N 1.50 N DESCRIPTION: CONTROL AIR CHK TO CIVs, ISOLATES SR FROM NSR AIR CSP-V-70 M619-161 2 SA O Hx 8Y OSP-CSP/IST-R701 ROJ09 C CK NA CMP-03 1 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9

ST Program Plan CoPage 79 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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)

CSP-V-71 M619-161 2 SA 0 Hx 8Y OSP-CSP/IST-R701 ROJO9 C CK NA CMP-03 1 1 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9)

CSP-V-72 M619-161 2 C SACK 0 NA jHx 8Y OSP-CSP/IST-R701 ROJO9 CMP-03 1 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9)

CSP-V-73 M619-161 2 SA 0 Hx 8Y OSP-CSP/IST-R701 ROJ09 C CK NA CMP-03 1 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs CSP-V-5,6,9)

CSP-V-74 M619-161 2 SA 0 Hx 8Y OSP-CSP/IST-R701 ROJ09 C CK NA CMP-03 1 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6 9)

CSP-V-75 M619-161 2 SA 1 0 [Hx 8Y OSP-CSP/IST-R701 ROJO9 C CK NA CMP-03 1 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9)

CSP-V-76 M619-161 2 SA 0 Hx 8Y OSP-CSP/IST-R701 ROJO9 C CK NA CMP-03 1 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9)

CSP-V-77 M619-1611 2 SA{ 0 ýHx 8Y OSP-CSP/IST-R701 ROJO9 C CK NA CMP-03 11 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9)

CSP-V-78 M619-161 2 SA C O Hx 8Y OSP-CSP/IST-R701 ROJ09 C CK NA CMP-03 1 NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,9)

CSP-V-79 M619-161 2 SA 0 Hx 8Y OSP-CSP/IST-R701 ROJT9 C CK NA CMP-03 A NC DESCRIPTION: BACKUP CONTROL AIR SUPPLY CHK TO CIVs (CSP-V-5,6,9)

CSP-V-93 M543-3 2 so C HJK Q OSP-CONT/IST-Q701 TV01,2 B5 A SV FC G 2Y OSP-CONT/IST-Q701 or 1 NC TSP-CSP/X66-C801 L J TSP-CSP/X66-C801 DESCRIPTION: CONTAINMENT N2 SUPPLY (CIV)

CSP-V-96 M543-3 2 so C HJK Q OSP-CONT/IST-0701 TV01,2 F5 A SV FC G 2Y OSP-CONT/IST-Q701 or 1 NC TSP-CSP/X53/C801 L J TSP-CSP/X53/C801 DESCRIPTION: CONTAINMENT N2 SUPPLY (CIV)

CSP-V-97 M543-3 2 so C HJK Q OSP-CONT/IST-Q701 TV01,2 F4 A SV FC G 2Y OSP-CONT/IST-Q701 or 1 NC TSP-CSP/X53/C801 IL J TSP-CSP/X53/C801 DESCRIPTION: CONTAINMENT N2 SUPPLY (CIV)

CSP-V-98 M543-3 2 SO C HJK Q OSP-CONT/IST-Q701 TV01,2 B4 A SV FC G 2Y OSP-CONT/IST-Q701 or 1 NC TSP-CSP/X66-C801 L J TSP-CSP/X66-C801

IST Program Plan Columbia Station Page 80 of 185 3rd 10-Year Interval Generating Revision 1 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)

CVB-V-1AB M543-1 2 AO,SA O/C GS 2Y MSP-CVB/IST-B101 RV01 N02 B13 AC CK NA H a OSP-CVB/IST-M701 TV04 24 NC L 2Y TSP-CONT-B801 I I_ TSP-CVB-R801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-1CD M543-1 2 AO,SA O/C GS 2Y MSP-CVB/IST-B101 RV01 N02 B12 AC CK NA H Q OSP-CVB/IST-M701 TV04 24 NC L 2Y TSP-CONT-B801 TSP-CVB-R801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-1EF M543-1 2 AO,SA O/C GS 2Y MSP-CVB/IST-B101 RV01 N02 B11 AC CK NA H Q OSP-CVB/IST-M701 TV04 24 NC L 2Y TSP-CONT-B801 TSP-CVB-R801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-1GH M543-1 2 AO,SA O/C GS 2Y MSP-CVB/IST-B101 RV01 N02 B11 AC CK NA H Q OSP-CVB/IST-M701 TV04 24 NC L 2Y TSP-CONT-B3801 TSP-CVB-R801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-1JK M543-1 2 AO,SA O/C GS 2Y MSP-CVB/IST-B101 RV01 N02 B9 AC CK NA H Q OSP-CVB/IST-M701 TV04 24 NC L 2Y TSP-CONT-B801 TSP-CVB-R801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-1LM M543-1 2 AO,SA O/C GS 2Y MSP-CVB/IST-B101 RV01 N02 B9 AC CK NA H Q OSP-CVB/IST-M701 TV04 24 NC L 2Y TSP-CONT-B3801 TSP-CVB-R801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-1NP M543-1 2 AO,SA O/C GS 2Y MSP-CVB/IST-B101 RV01 N02 B8 AC CK NA H Q OSP-CVB/IST-M701 TV04 24 NC L 2Y TSP-CONT-B801 TSP-CVB-R801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-1QR M543-1 2 AO,SA O/C GS 2Y MSP-CVB/IST-B101 RV01 N02 B7 AC CK NA 'H Q OSP-CVB/IST-M701 TV04 24 NC L 2Y TSP-CONT-B801 II [TSP-CVB-R801 DESCRIPTION: VACUUM RELIEF TO DRYWELL CVB-V-IST M543-1 2 AO,SA O/C GS 2Y MSP-CVB/IST-B101 RV01 N02 B7 AC CK NA H Q OSP-CVB/IST-M701 TV04 24 NC L 2Y TSP-CONT-BB01 TSP-CVB-R801 DESCRIPTION: VACUUM RELIEF TO DRYWELL DO-V-1A M512-4 3 F SA [ 0 OSP-DO/IST-Q701 N15 C11 C CK NA 1.50 NC I DESCRIPTION: DO-P-1A TRANSFER PUMP) DISCH CHK DO-V-1B M512-4 3 SA 0 OSP-DO/IST-Q702 N15 H11iC C CK NA 1.50 NC DESCRIPTION: DO-P-1 B TRANSFER PUMP) DISCH CHK DO--l Mi24 1SA 0 1OSP-DO/IST-Q703 [Ni15 D1 CK NA II

____1.50 NC JL____

DESCRIPTION: DO-P-2 (TRANSFER PUMP) DISCH CHK DSA-SPV- M512-2 D I SO O/C H N TSP-DSA-B701 N06 5A1/2 F10 B 3W FAI 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV

3ST Program Plan IST PogramPlanPage Generating Station Columbia Revision 81 of 1851 3rd 10-Year Interval Rvso 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)

DSA-SPV- M512-2 D so O/C H N TSP-DSA-B701 N06 5A1/4 E10 B 3W FAI

_ 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV- M512-2 D SO O/C [H N TSP-DSA-B701 N06 5A2/2 6 B 3W FAI 2 NC DSA-SPV-5A2/4 M512-2 E6 I B D [ SO 3W 2

0/C FAI NC j_

DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV H N TSP-DSA-B701 N06 DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV- M512-3 D SO 1 O/C [H N TSP-DSA-B702 N06 5B1/2 F10 B 3W FAI 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV- M512-3 D SO 3W 0/C FAI H N TSP-DSA-B702 N06 El0 B 5B1/4 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV- M512-3 D SO O/C IH N TSP-DSA-B702 N06 5B2/2 F6 I B 3W FAI 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV- M512-3 D I SO 0/C H N TSP-DSA-B702 N06 5B2/4 E6 B 3W FAI 2 NC DESCRIPTION: DSA TO EDG START MOTORS BYPASS/VENT VLV DSA-SPV- M512-1 D 1 SO 0 H N TSP-DSA-B703 N06 5C1/1 F9 B 3 FAI 1.50 NoC DSA-SPV- [M512-1 D SO [

DESCRIPTION: DSA TO EDG START MOTORS ISO 0 H N TSP-DSA-B703 N06 5C1/2 F9 B 3W FAI 1.50 NC DESCRIPTION: DSA TO EDG START MOTORS ISO DW-V-156 M517 2 MA C J TSP-DW/X92-C801 TV02 G8 A GT NA Passive 2 LC DESCRIPTION: DEMIN WATER TO CONTAINMENT ISO (OTBD CIV)

DW-V-157 M517 2 MA C L J TSP-DW/X92-C801 TV02 G8 A GT NA Passive 2 LC DESCRIPTION: DEMIN WATER TO CONTAINMENT ISO (INBD CIV)

EDR-V-19 M537 2 AO C G 2Y OSP-EDR/IST-Q701 TV01,2 D9 A GT FC HJK Q OSP-EDR/IST-Q701 3 NO L J TSP-EDR/X23-C801 DESCRIPTION: EDR ISO FROM DRYWELL SUMP (CIV)

EDR-V-20 M537 2 AO C [G 2Y OSP-EDR/IST-0701 1 TV01,2 D9 LA GT FC HJK Q OSP-EDR/IST-Q701 3 NO D PJ TSP-EDR/X23-C801 DESCRIPIN EDR ISO FROM DRYWELL SUMP (CIV)

IST Program Plan Columbia Station Page 82 of 185 3rd 10-Year Interval Revision 1 Valve Test Tables Type Position Testing Remarks Actuat, Safety, Exceptions (Notes &

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EDR-V-394 M537 3 AO C G 2Y OSP-EDR/IST-Q702 TV01 C15 B GT FC HJK Q OSP-EDR/IST-Q702 1 3 NO DESCRIPTION: EDR INBD SECONDARY CTMT ISO EDR-V-395 M537 3 AO C G 2Y OSP-EDR/IST-Q702 TVo1 C15 B GT FC HJK Q OSP-EDR/IST-Q702 3 NO DESCRIPTION: EDR INBD SECONDARY CTMT ISO FDR-V-3 M539 2 1 AO C G 2Y OSP-FDR/IST-Q701 TV01,2 D6 A BF FC HJK Q OSP-FDR/IST-Q701 13 NO J TSP-FDR/X24-C801 DESCRIPTION: FDR ISO FROM DRYWELL FDR-SUMP-3 (CIV)

FDR-V-4 M539 2 AO C [G 2Y OSP-FDR/IST-Q701 TV01,2 D6 A BF FC HJK Q OSP-FDR/IST-Q701 3 NO L J TSP-FDR/X24-C801 DESCRIPTION: FDR ISO FROM DRYWELL FDR-SUMP-3 (CIV)

FDR-V-219 M539 3 AO C G 2Y OSP-FDR/IST-Q702 TV01 D14 B GT FC HJK Q OSP-FDR/IST-Q702 3 NO DESCRIPTION: FDR INBD SECONDARY CTMT ISO FDR-V-220 M539 3 AO C G 2Y OSP-FDR/IST-Q702 TV01 D15 B GT FC HJK Q OSP-FDR/IST-Q702 3 NO DESCRIPTION: FDR INBD SECONDARY CTMT ISO FDR-V-221 M539 3 AO C G 2Y OSP-FDR/IST-Q702 TV01 D14 B GT FC HJK Q OSP-FDR/IST-Q702 3 No DESCRIPTION: FDR INBD SECONDARY CTMT ISO FDR-V-222 M539 3 AO C G 2Y OSP-FDR/IST-Q702 TV01 D15 B GT FC HJK Q OSP-FDR/IST-Q702 3 NO DESCRIPTION: FDR INBD SECONDARY CTMT ISO M526-1 3 AO 0 G 2Y OSP-FPC/IST-Q701 TV01 B8 B GB FO HJK Q OSP-FPC/IST-Q701 P RV TSP-RV/IST-R701 TV03 H Q OSP-FPC/IST-Q701 H Q OSP-FPC/IST-Q701

IST Program Plan Columbia Station Page 83 of 185 3rd 10-Year Interval Generating Revision 1 Valve Test Tables Type Position Testing Remarks Actuat, Safety, Exceptions (Notes &

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FPC-V-127 M526-1 3 SA O/C Hx 4Y OSP-FPC/IST-Q701 E6 C CK NA Nit 4Y CMP-1 9 1 1 _ 1_ 2 NC I I _ I DESCRIPTION: SW TO FPC CHK FPC-V-140 M526-1 3 SA C Hx 4Y OSP-FPC/IST-Q701 C6 C CK NA Di 10Y CMP-20 8 NO DESCRIPTION: FPC DEMIN EFF CHK FPC-V-146A 1M526-1 ý 3 SA 1 0 Hx 4Y OSP-FPC/IST-Q701 J10 C CK NA Di 10Y CMP-20 8 NO DESCRIPTION: FPC TO FUEL POOL CHK FPC-V-146B ýM526-1 13 SA 0 ýHx 4Y OSP-FPC/IST-Q701 J10 C CK NA Di 10Y CMP-20 8 NO DESCRIPTION: FPC TO FUEL POOL CHK FPC-V-149 M526-1 C7 2A MO GT C FAI GHJ 2Y 0 OSP-FPC/IST-Q701 OSP-FPC/IST-Q701 TV01,2 6 NC L J TSP-FPC/X101-C801 DESCRIPTION: FPC TO SUPPRESSION POOL ISO (CIV)

FPC-V-153 M526-1 2 MO C G 2Y OSP-FPC/IST-Q701 TV01,2 All A GT FAI HJ Q OSP-FPC/IST-Q701 6 NC L 2Y TSP-CONT-B802 DESCRIPTION: SUPPRESSION POOL TO FPC-P-3 SUCT (CIV)

FPC-V-154 M526-1 2 MO C iG 2Y OSP-FPC/IST-0701 TV01,2 A10 A GT FAI HJ Q OSP-FPC/IST-Q701 6 NC L 2Y TSP-CONT-B3802 DESCRIPTION: SUPPRESSION POOL TO FPC-P-3 SUCT CIV)

FPC-V-156 M526-1 2 MO C G 2Y OSP-FPC/IST-Q701 TV01,2 B10 A GT FAI HJ Q OSP-FPC/IST-Q701 6 NC L J TSP-FPC/X1 01 -C801 DESCRIPTION: FPC TO SUPPRESSION POOL ISO CIV)

FPC-V-157A M526-1 3 1SA Hx CMP OSP-FPC/IST-Q701 N04 J10 C CK NA Di CMP CMP-14 0.5 NC DESCRIPTION: FPC TO FUEL POOL VACUUM BKR CHK FPC-V-157B M526-1 3 SA 0 Hx CMP OSP-FPC/IST-Q701 N04 J1o C CK NA Di CMP CMP-14 1O0.5 NC DESCRIPTION: FPC TO FUEL POOL VACUUM BKR CHK FPC-V-172 M526-1 E3 MO C G 2Y OSP-FPC/IST-Q701 TVo B5 B GT FAI HJ Q OSP-FPC/IST-Q701 8 NO DESCRIPTION: FPC TO SUPPRESSION POOL ISO FPC-V-173 IM526-1 3 1MO IC IG 2Y OSP-FPC/IST-Q701 TV01 B5 B GT FAI HJ Q OSP-FPC/IST-Q701 8 NO DESCRIPTION: FPC INFLUENT TO DEMIN ISO FPC-V-175 ýM526-1 3 MO C G 2Y OSP-FPC/IST-Q701 TVo1 C9 B GT FAI HJ Q OSP-FPC/IST-Q701 8 NC DECIPftIN FPC FLTR DEMIN BYPASS

ST Program Plan CoPage 84 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 Valve Test Tables Type Position Testing Remarks Actuat, Safety, Exceptions (Notes &

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FPC-V-181A M526-1 3 MO NA G 2Y OSP-FPC/IST-Q701 Passive E14 B GT FAI I _ 1 _ _ 8 NO I II DESCRIPTION: FPC-P-1 A SUCT FPC-V-181B M526-1 3 MO NA G 2Y OSP-FPC/IST-Q701 Passive C14 B GT FAI 8 NO DESCRIPTION: FPC-P-1 B SUCT FPC-V-184 M526-1 3 MO C G 2Y OSP-FPC/IST-Q701 TV01 C5 B GT FAI HJ Q OSP-FPC/IST-Q701 8 NO DESCRIPTION: FPC FILTER DEMIN EFFLUENT ISO HPCS-RV-14 IM520 2 SA NA P RV TSP-R/IST-R701 TV02,3 C6 AC RV NA ýL J TSP-CONT-C801 N09 1X1 NC DESCRIPTION: HPCS-P-3 SUCT RV (CIV)

HPCS-RV-35 M520 2 SA NA P RV TSP-RV/IST-R701 TV02,3 C4 AC RV NA L J TSP-CONT-C801 N09 1.5 X 2 NC DESCRIPTION: HPCS-P-3 DISCH RV (CIV)

HPCS-V-1 M520 2 MO O/C G 2Y OSP-HPCS/IST-Q701 TV01 C7 B GT FAI HJ Q OSP-HPCS/IST-Q701 14 NO DESCRIPTION: CST TO HPCS-P-1 SUCT HPCS-V-2 M520 2 SA O/C H Q OSP-HPCS/IST-Q701 C6 C CK NA 1 20 NC DESCRIPTION: CST TO HPCS-P-1 SUCT CHK HPCS-V-4 M520 1 M G 2Y OSP-HPCS/IST-Q701 TV01,2 G7 A GT FAI HJ Q OSP-HPCS/IST-Q701 12 NC L 2Y TSP-RCS-R803 DESCRIPTION: HPCS TO RPV ISO (OTBD CIV)

HPCS-V-5 [M520 EH8 1AC SA C/CNA 0/C H HL RF RF OSP-HPCS/IST-R701 TSP-RCS-R803 ROJT8 V02 12 NC DESCRIPTION: HPCS TO RPV ISO (INBD CIV)

HPCS-V-6 M520 2 SA C Hx Q OSP-HPCS/IST-Q701 N01 C5 C SC NA Hx 12M OSP-HPCS-A701 CMP-21 1.50 NO DESCRIPTION: HPCS-P-3 (WATER LEG) DISCH STOP CHK HPCS-V-7 M520 2 1 SA C Hx Q OSP-HPCS/IST-Q701 N01 C5 C CK NA IHx 12M OSP-HPCS-A701 CMP-21 1.50 NO DESCRIPTION: HPCS-P-3 (WATER LEG) DISCH CHK HPCS-V-10 M520 2 MO C G 2Y OSP-HPCS/IST-Q701 TV01 E3 B GB FAI HJ Q OSP-HPCS/IST-Q701 10 NC DESCRIPTION: HPCS TO CST ISO HPCS-V-1 1 M520 2 MO C G 2Y OSP-HPCS/IST-Q701 TV01 E3 B GB FAI HJ Q OSP-HPCS/IST-Q701 10 NC DESCRIPTION: HPCS TO CST ISO

IST Program Plan Columbia Station Page 85 of 185 3rd 10-Year Interval Generating Revision 1 Valve Test Tables Type Position Testing Remarks Actuat, Safety, Exceptions (Notes &

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HPCS-V-12 M520 2 MO O/C G 2Y OSP-HPCS/IST-Q701 TV01, N16 B5 B GT FAI HJ Q OSP-HPCS/IST-Q701 1 4 NC DESCRIPTION: HPCS-P-1 MINIMUM FLOW VLV (CIV)

HPCS-V-15 M520 2 1 MO 0/C G 2Y OSP-HPCS/IST-Q701 ITV01, N16 D7 B GT FAI HJ Q OSP-HPCS/IST-Q701 18 NC DESCRIPTION: SUPPRESSION POOL TO HPCS-P-1 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 C G 2Y OSP-HPCS/IST-Q701 TV01, N16 E5 B GB FAI HJ Q OSP-HPCS/IST-Q701 112 NC DESCRIPTION: HPCS TEST LINE TO SUPPRESSION POOL ISO (CIV)

HPCS-V-24 M520 B4 2

C fSA CK O/C NA H OSP-HPCS/IST-0701 16 NC DESCRIPTION: HPCS-P-1 DISCH CHK HPCS-V-28 M524-1 G6C 3 SA CK j0NA Hx Di Q

10OY OSP-SW/IST-Q703 CMP-23 8 NC DESCRIPTION: HPCS-P-2 'SERVICE WATER) DISCH CHK HPCS-V-65 M520 2 MA C L J TSP-HPCS/X78E-C801 TV02 H7 A GB NA Passive 1 LC DESCRIPTION: AIR TO HPCS-V-5 OPERATOR (INBD CIV)

HPCS-V-68 M520 2 MA C L J TSP-HPCS/X78E-C801 TV02 H7 A GB NA Passive 1 LC DESCRIPTION: AIR TO HPCS-V-5 OPERATOR (OTBD CIV)

LPCS-FCV-1 1 M520 2 MO O/C G 2Y OSP-LPCS/IST-Q702 TV01, N16 B13 B GB FAI HJ Q OSP-LPCS/IST-Q702 3 NC DESCRIPTION: LPCS-P-1 MINIMUM FCV (CIV)

LPCS-RV-18 M520 2 1 SA NA P RV TSP-RV/IST-R701 TV02,3 G12 AC RV NA L J TSP-CONT-C801 N09 15 X 2 NC DESCRIPTION: LPCS-P-1 RV (CIV)

LPCS-RV-31 M520 2 SA NA P RV TSP-RV/IST-R701 TV02,3 D12 AC RV NA L J TSP-CONT-C801 N09 1X1 NC DESCRIPTION: LPCS-P-2 SUCT RV (CIV)

LPCS-V-1 M520 1 2 MO O/C G 2Y OSP-LPCS/IST-Q702 TV01, N16 D11 B GT FAI HJ Q OSP-LPCS/IST-Q702

_ 24 NO DESCRIPTION: SUPPRESSION POOL TO LPCS-P-1 SUCT (CIV)

LPCS-V-3 M520 2 SA O/C H Q OSP-LPCS/IST-Q702 B13 C CK NA 1_16 NC DESCRIPTION: LPCS-P-1 DISCH CHK

IST Program Plan Columbia Generating Station Page 86 of 185 3rd 10-Year Interval Revision 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)

LPCS-V-5 M520 1 MO O/C 'G 2Y OSP-LPCS/IST-Q701 CSJ06 TV01,2 Gil A GT FAI HJ CS OSP-LPCS/IST-Q701 12 NC L 2Y TSP-RCS-R801 DESCRIPTION: LPCS TO RPV ISO (OTBD CIV)

LPCS-V-6 M520 1 SA O/C H RF OSP-LPCS/IST-R701 ROJ08 TV02 H9 AC CK NA HL RF TSP-RCS-R801 12 NC DESCRIPTION: LPCS TO RPV ISO CHK (INBD CIV)

LPCS-V-12 M520 2 MO C IG 2Y OSP-LPCS/IST-Q702 TV01, N16 E14 B GB FAI HJ Q OSP-LPCS/IST-Q702 12 NCI DESCRIPTION: LPCS TEST LINE TO SUPPRESSION POOL ISO (CIV)

LPCS-V-33 M520 1 2 1SA C Hx Q OSP-LPCS/IST-Q702 INl01 C12 C CK NA Hx 12M OSP-LPCS-A702 CMP-21 1.50 NO DESCRIPTION: LPCS-P-2 (WATER LEG) DISCH CHK LPCS-V-34 M520 2 SA C 1Hx Q OSP-LPCS/IST-Q702 N01 C13 C SC NA Hx 12M OSP-LPCS-A702 CMP-21 1.50 NO DESCRIPTION: LPCS-P-2 (WATER LEG) DISCH STOP CHK LPCS-V-66 M520 2 MA C ]L J TSP-LPCS/X78d-C801 TV02 H10 A GB NA Passive 11 LCI DESCRIPTION: AIR TO LPCS-V-6 OPERATOR (INBD CIV)

LPCS-V-67 [M520 2 1 MA C JL TSP-LPCS/X78d-C801 ITV02 H10 A GB NA Passive 1 LC DESCRIPTION: AIR TO LPCS-V-6 OPERATOR (OTBD CIV)

MS-RV-1A M529 1 AO,SA NA G 2Y TSP-MSRV/IST-R701 RV04 TV03 Fl C SR NA P RV ISP-MS/IST-R101 6 X 10 NC MSP-MS/IST-R101 I IISP-MS/IST-A101 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-1B M529 1 AO,SA NA G 2Y TSP-MSRV/IST-R701 RV04 TV03 Di 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-1C M529 1 AO,SA NA G 2Y TSP-MSRV/IST-R701 RV04 TV03 F6 C SR NA P RV ISP-MS/IST-RiO1 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A1 01 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-MS/IST-R101 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-Al01 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-2A M529 1 AO,SA NA *G 2Y TSP-MSRV/IST-R701 RV04 TV03 Flo C SR NA P RV ISP-MS/IST-R1Ol 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A1 01 DESCRIPTION: MAIN STEAM SAFETY RV

IST Program Plan Page 87 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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 1 AO,SA NA G 2Y TSP-MSRV/IST-R701 RV04 TV03 D10 C SR NA P RV ISP-MS/IST-R101 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A1 01 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-2C M529 1 AO,SA NA G 2Y TSP-MSRV/IST-R701 RV04 TV03 F7 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-2D M529 1 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-MS/IST-R101 ISP-MS/IST-A1 01 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-3A M529 1 AO,SA NA G 2Y TSP-MSRV/IST-R701 RV04 TV03 F9 C SR NA P RV ISP-MS/IST-R101 6X10 NC MSP-MS/IST-R101 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-3B M529 1 AO,SA NA G 2Y TSP-MSRV/IST-R701 RV04 TV03 D10 C SR NA P RV ISP-MS/IST-R101 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A1 01 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-3C M529 1 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-MS/IST-R101 ISP-MS/IST-A1 01 DESCRIPTION: MAIN STEAM SAFETY RV MS-RV-3D 1 AO,SA 0 G RF TSP-MSRV/IST-R701 RV04 N08 E8 C SR NA P RV ISP-MS/IST-R101 TV03 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-RV-4A M529 1 AO,SA 0 G RF TSP-MSRV/IST-R701 RV04 N08 F9 C SR NA P RV ISP-MS/IST-R101 TV03 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-RV-4B 9 1 AOSA 0 G RF TSP-MSRV/IST-R701 RV0 N08 C SR NA P RV ISP-MS/IST-R101 TV03 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-RV-4C M529 1 AO,SA 0 G RF TSP-MSRV/IST-R701 RV04 N08 F8 C SR NA P RV ISP-MS/IST-R101 TV03 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM &ADS SAFETY RV MS-RV-4D M529 1 AO,SA 0 G RF TSP-MSRV/IST-R701 RV04 N08 E8 C SR NA P RV ISP-MS/IST-R101 TV03 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A101 DESCRIPTION: MAIN STEAM & ADS SAFETY RV

IST Program Plan Columbia Generating Station Page 88 of 185 3rd 10-Year Interval Revision 1 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-5B M529 1 AO,SA 0 G RF TSP-MSRV/IST-R701 RV04 N08 E9 C SR NA P RV ISP-MS/IST-R101 TV03 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A1 01 DESCRIPTION: MAIN STEAM & ADS SAFETY RV MS-RV-5C M529 1 AO,SA 0 G RF TSP-MSRV/IST-R701 RV04 N08 F8 C SR NA P RV ISP-MS/IST-R101 TV03 6 X 10 NC MSP-MS/IST-R101 ISP-MS/IST-A1 01 DESCRIPTION: MAIN STEAM &ADS SAFETY RV MS-V-16 M529 1 MO C G 2Y OSP-MSLC/IST-Q702 CSJ13 TV01,2 B13 A GT FAI HJ CS OSP-MS/IST-Q702 3 NC L J TSP-MS/X22-C801 DESCRIPTION: MAIN STEAM DRN ISO (INBD CIV)

MS-V-19 M529 1 MO C G 2Y OSP-MSLC/IST-Q702 CSJ13 TV01,2 B14 A GT FAI HJ CS OSP-MS/IST-Q702 113 NC L J TSP-MS/X22-C801 DESCRIPTION: MAIN STEAM DRN ISO OTBD CIV)

MS-V-20 M529 2 MO C G 2Y OSP-MS/IST-Q702 Passive C15 B GB FAI 3 NCII DESCRIPTION: MS LINE DRN ISO (MUST CLOSE FOR MSLC OPERATION)

MS-V-22A M529 1 AO C G 2Y OSP-MS/IST-Q701 CSJ08 TV01,2 F12 A GB FC HJK CS OSP-MS/IST-Q701

_______ 26 NO L 2Y TSP-MSIV-B801 j____

DESCRIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-22B [M529 1 AO C G 2Y OSP-MS/IST-Q701 CSJ08 TV01,2 E12 A GB FC HJK CS OSP-MS/IST-Q701 26 NO L 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-22C M529 1 AO C G 2Y OSP-MS/IST-Q701 CSJ08 TV01,2 F5 A GB FC HJK CS OSP-MS/IST-Q701 26 NO L 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-22D M529 1 AO C G 2Y OSP-MS/IST-Q701 CSJ08 TV01,2 E5 A GB FC HJK CS OSP-MS/IST-Q701 1_26 NO L 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (INBD CIV)

MS-V-28A M529 1 AO C [G 2Y OSP-MS/IST-Q701 CSJ08 TV01,2 F13 A GB FC HJK CS OSP-MS/IST-Q701 26 NO L 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (OTBD CIV)

MS-V-28B M529 1 [ AO C G 2Y OSP-MS/IST-Q701 CSJ08 TV01,2 E13 A GB _ FC HJK CS OSP-MS/IST-Q701 126 NO L 2Y TSP-MSIV-8801 DESCRIPTION: MAIN STEAM ISO VLV (OTBD CIV)

MS-V-28C M529 F4 A1 AO GB C FC G HJK 2YCS OSP-MS/IST-Q701 OSP-MS/IST-Q701 CSJ08 TV01,2 26 NO L 2Y TSP-MSIV-B801 DESCRIPTION: MAIN STEAM ISO VLV (OTBD CIV)

MS-V-28D M529 1 AO 2G Y OSP-MS/IST-Q701 CSJ08 TV01,2 E4 A GB FC HJK CS OSP-MS/IST-Q701 26 NO L TSP-MSIV-B801 DECIPTION: MAIN STEAM ISO VLV (OTBD CIV)

IST Program Plan Page 89 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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-V-37A M529 3 SA 0 HS RF MSP-MS/IST-R701 ROJO7 TV05 (TYP 18) C11 C CK NA I 1 10 NC DESCRIPTION: VACUUM BREAKER ON MSRV TAILPIPE MS-V-38A M529 3 SA 0 HS RF MSP-MS/IST-R701 ROJ07 TV05 (TYP 18) C11 C CK NA 10 NC DESCRIPTION: VACUUM BREAKER ON MSRV TAILPIPE MS-V-67A M529 1 MO C G 2Y OSP-MS/ST-Q702 CSJ1 1 TV01,2 F13 A GT FAI HJ CS OSP-MS/IST-Q702 1.50 NC L 2Y TSP-MSIV-B801 DESCRIPTION: MS-V-28A BODY DRN (OTBD CIV)

MS-V-67B M529 1 MO C G 2Y OSP-MS/IST-Q702 CSJ1 1 TV01,2 D13 A GT FAI HJ CS OSP-MS/IST-Q702

_ 1.50 j NC L 2Y TSP-MSIV-B801 DESCRIPTION: MS-V-28B BODY DRN (OTBD CIV)

MS-V-67C M529 1 MO C G 2Y OSP-MS/IST-Q702 CSJ1 1 TV01,2 F4 A GT FAI HJ CS OSP-MS/IST-Q702 1.50 NC L 2Y TSP-MSIV-B801 DESCRIPTION: MS-V-28C BODY DRN (OTBD CIV)

MS-V-67D M529 1 MO C G 2Y OSP-MS/IST-Q702 CSJ 11 TV01,2 D4 A GT FAI HJ CS OSP-MS/IST-Q702

_ 1.50 NC L 2Y TSP-MSIV-B801 DESCRIPTION: MS-V-28D BODY DRN (OTBD CIV)

MS-V-146 M502-1 2 MO C G 2Y OSP-MS/IST-Q702 CSJ10 TV01 B7 B GT FAI HJ CS OSP-MS/IST-Q702 24 NO DESCRIPTION: MS SUPPLY TO AUXILIARIES MSLC-V-3A M557 1 MA C L 2Y TSP-MSIV-B801 N14 C9 A GT NA TV02 1.50 LC Passive DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

MSLC-V-3B M557 1 MA C L 2Y TSP-MSIV-B801 N14 C8 A GT NA TV02

_ 1.50 LC Passive DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

MSLC-V-3C M557 1 MA C L 2Y TSP-MSIV-B801 N14 E9 A GT NA TV02 1.50 LC Passive DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

MSLC-V-3D M557 1 MA C L 2Y TSP-MSIV-B801 N14 E8 A GT NA TV02 1.50 LC Passive DESCRIPTION: MS VENT TO SGT AND REACTOR BUILDING (OTBD CIV)

IST ProgramInterval 3rd 10-Year Plan Columbia Generating Station 90 of 1851 PageRevision 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-X29B M543-1 2 SA NA GH FS ISP-EFC-B108 N12 H8 C CK NA Passive 1 1 X.5 NO DESCRIPTION: DRYWELL ATM TO CMS-PT-6 EFC (CIV)

PI-EFC-X29F M543-1 2 SA NA GH FS ISP-EFC-B108 N12 H7 C CK NA Passive 1 X .5 NO DESCRIPTION: DRYWELL ATM TO CMS-PT-2 EFC (CIV)

PI-EFC-X30A M543-1 2 SA NA GH FS ISP-EFC-B108 N12 G 13 C CK NA Passive 1 X .5 NO DESCRIPTION: DRYWELL ATM TO CMS-PT-5 EFC (CIV)

PI-EFC-X30F M543-1 2 SA NA GH FS ISP-EFC-B108 N12 F13 C CK NA Passive 1 X1.5 NO DESCRIPTION: DRYWELL ATM TO CMS-PT-1 EFC (CIV)

PI-EFC-X37E M521-1 1 S NA GH TS ISP-EFC-B107 RV05 D6 C CK NA 1 XE.5 No DESCRIPTION: RHR SDC A SUPPLY TO DPIS EFC (CIV)

PI-EFC-X37F M521-1 1 SA NA GH TS ISP-EFC-B1107 RV05 D6 C CK NA 1 X .5 NO DESCRIPTION: RHR SDC A SUPPLY TO DPIS EFC (CIV)

PI-EFC-X38A M529 1 SA NA GH TS ISP-EFC-B101 RV05 C13 C CK NA 1 X.5 NO DESCRIPTION: MAIN STEAM LINE B TO DPIS HI SIDE EFC (CIV)

PI-EFC-X38B M529 1 SA NA GH TS ISP-EFC-B101 RV05 D13 C CK NA 1 X .5 NO DESCRIPTION: MAIN STEAM LINE B TO DPIS LO SIDE EFC (CIV)

PI-EFC-X38C M519 1 SA [ GH TS ISP-EFC-B105 RV05 G6 C CK 1 X.5 NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-713B EFC (CIV)

PI-EFC-X38D M519 1 SA [ NA GH TS ISP-EFC-B105 RV05 G6 C CK NA 1X.5 NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-713B EFC (CIV)

PI-EFC-X38E M519 1 SA N7A GH TS ISP-EFC-B3105 RV05 G6 C CK INA 1 X .5 NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-13B EFC (CIV)

PI-EFC-X38F M519 1 SA NA ,GH TS ISP-EFC-B3105 RV05 G6 C CK NA 1 X .5 NO IECRPTION RCIC STEAM SUPPLY TO DPIS-1 3B EFC (CIV)

IST Program Plan Columbia Station Page 91 of 185 3rd 10-Year Interval Generating Revision 1 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-X39A M521-2 1 SA NA GH TS ISP-EFC-B101 RV05 H13 C CK NA I 1_ 1 X.5 NO DESCRIPTION: MAIN STEAM LINE B TO DPIS HI SIDE EFC (CIV)

PI-EFC-X39B M529 1 SA NA GH TS ISP-EFC-B1o01 RV05 D13 C CK NA 1 X .5 NO DESCRIPTION: MAIN STEAM LINE B TO DPIS LO SIDE EFC (CIV)

PI-EFC-X39D M521-2 1 SA NA GH TS ISP-EFC-B104 RV05 H13 C CK NA 1 X .5 NO DESCRIPTION: RHR LPCI B INJECTION TO DPIS-29B EFC (CIV)

PI-EFC-X39E fM521-2 j 1 SA NA IGH TS ISP-EFC-B104 RV05 H13 C CK NA 1 X .5 NO DESCRIPTION: RHR LPCI C INJECTION TO DPIS-29B EFC (CIV)

PI-EFC-X40C M5 3 0 - 1 1 1 SA NA ýGH TS ISP-EFC-B106 RV05 F12 C CK NA 1X .5 NO DESCRIPTION: RRC A TO FT-14A,14B,11A EFC (CIV)

PI-EFC-X40D M53 0 - 1 111 SA [GH NA TS ISP-EFC-B106 RV05 F12 C CK N 1 X .5 N DESCRIPTION: RRC A TO FT-14A,14B,11A EFC (CIV)

PI-EFC-X40E 1M530-1 C14 2

C SA CK NA NA jGH TS ISP-EFC-B104 RV05 1X.5 NO DESCRIPTION: RRC A (RRC-P-1A) TO PI-1A,602A EFC (CIV)

PI-EFC-X40F M530-1 2 SA NA GH TS ISP-EFC-R1i04 RV05 C14 C CK NA 1X .5 No DESCRIPTION: RRC A (RRC-P-1A) TO PI-2A,603A EFC (CIV)

PI-EFC-X41C M530-1 1 SA [ NA GH TS ISP-EFC-1i 04 RV05 B4 C CK NA 1X .5 NO DESCRIPTION: RRC B (RRC-P-B) TO DPT-15B EFC (CIV)

PI-EFC-X41D M530-1 1 SA NA GH TS ISP-EFC-B104 RV05 C4 C CK NA 14XC.5 NO DESCRIPTION: RRC B (RRC-P-1B) TO DPT-15B EFC (CIV)

PI-EFC-X41E M530-1 2 SA NA GH TS ISP-EFC-B104 RV05 B4 C CK NA 1 X_.5 NO DESCRIPTION: RRC B (RRC-P-1B) TO PI-1 B,602B EFC (CIV)

PI-EFC-X41F M530-1 2 SA NA GH TS ISP-EFC-B104 RV05 C4 C CK NA 1 X .5 No DESCRIPTION: RRC B (RRC-P-1B) TO PI-2B,603B EFC (CIV)

PI-EFC-X42A M529 1 SA NA IGH TS ISP-EFC-B101 RV05 C4 C CK NA DESCP MAIN DECIPTIN:

1 X STEAM

.5 NO LINE D TO DPIS HI SIDE EFC (CIV)

ST Program Plan CoPage 92 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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-X42B M529 1 SA NA GH TS ISP-EFC-B101 RV05 C4 C CK NA 1 X .5 NO DESCRIPTION: MAIN STEAM LINE D TO DPIS LO SIDE EFC (CIV)

PI-EFC-X42C [M543-2[ 2 SA 5 NA IGH FS ISP-EFC-B108 N12 E6 C CK NA Passive 1X .5 NoII DESCRIPTION: H2-02 MONITOR TO DRYWELL ATM SAMPLE EFC (CIV)

PI-EFC-X42F [M529 2 1SAI NA GH FS ISP-EFC-B108 N12 H5 C CK NA Passive 1X .5 NOI DESCRIPTION: DRYWELL ATM TO PRESS INST EFC (CIV)

PI-EFC-X44AA M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 E2 C CK NA 11 X .5 NO DESCRIPTION: JET PUMP NO 11 TO FLOW INST EFC (CIV)

PI-EFC-X44AB M53 0 - 1 1 SA NA GH TS ISP-EFC-B103 RV05 E2 C CK NA 11 X .5 NO DESCRIPTION: JET PUMP NO 12 TO FLOW INST EFC (CIV)

PI-EFC-X44AC IM530-1 1 1GH NA TS ISP-EFC-B103 RV05 E2 C CK NA 1 X .5 NO DESCRIPTION: JET PUMP NO 13 TO FLOW INST EFC (CIV)

PI-EFC-X44AD M530-1 1 SA NA GH TS ISP-EFC-B103 RV0 5 E2 C CK NA I_ 1 1 X.5 NO DESCRIPTION: JET PUMP NO 14 TO FLOW INST EFC (CIV)

PI-EFC-X44AE M530-1 1 1 SA NA GH TS ISP-EFC-B103 RV05 J6 C CK NA 11 X .5 NO DESCRIPTION: JET PUMP NO 15 TO FLOW INST EFC (CIV)

PI-EFC-X44AF M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 E2 C CK NA 1 XC.5 NO DESCRIPTION: JET PUMP NO 16 TO FLOW INST EFC (CIV)

PI-EFC-X44AG M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 E2 C CK NA 1 X .5 NO DESCRIPTION: JET PUMP NO 17 TO FLOW INST EFC (CIV)

PI-EFC-X44AH M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 E2 C CK NA 1 1 X.5 NO DESCRIPTION: JET PUMP NO 19 TO FLOW INST EFC (CIV)

PI-EFC-X44AJ ýM530-1 11 SA FNA ýGH TS ISP-EFC-B3103 RV05 E2 C CK NA 1X .5 NO DESCRIPTION: JET PUMP NO 18 TO FLOW INST EFC (CIV)

PI-EFC-X44AK M530-1 1 SA NA GH TS ISP-EFC-B3103 RV05 J6 C CK NA I X .5 NO DESCRIPTION: JET PUMP NO 20 TO FLOW INST EFC (CIV)

IST Program Plan Columbia Generating Station Page 93 of 1851 3rd 10-Year Interval Revision 1 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-X44AL M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 H6 C CK NA 1 X1.5 NO DESCRIPTION: JET PUMP NO 15 TO FLOW INST EFC (CIV)

PI-EFC-X44AM M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 H6 C CK NA 1 XJ.5 NO DESCRIPTION: JET PUMP NO 20 TO FLOW INST EFC (CIV)

PI-EFC-X44BA M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 F2 C CK NA 1 X .5 1 NO DESCRIPTION: JET PUMP NO 1 TO FLOW INST EFC (CIV)

PI-EFC-X44BB M530-1 SGH NA TS ISP-EFC-B103 RV05 F2 C 1 CK X.5 NO NA H DESCRIPTION: JET PUMP NO 2 TO FLOW INST EFC (CIV)

PI-EFC-X44BC M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 F2 C CK NA 1 X .5 NO DESCRIPTION: JET PUMP NO 3 TO FLOW INST EFC (CIV)

PI-EFC-X44BD M530-1 11 F NA GH TS ISP-EFC-B103 RV05 F2 C CK NA 1 X,. NO DESCRIPTION: JET PUMP NO 4 TO FLOW INST EFC (CIV)

PI-EFC-X44BE M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 ill C CK NA 1 X.5 NO DESCRIPTION: JET PUMP NO 5 TO FLOW INST EFC (CIV)

PI-EFC-X44BF M530-1 1 SA NA GH TS ISP-EFC-IB103 RV05 F2 C CK NA 1 X .5 NO DESCRIPTION: JET PUMP NO 6 TO FLOW INST EFC (CIV)

PI-EFC-X44BG M530-1 1 SA NA GH TS ISP-EFC-B3103 RV05 F2 C CK NA 11 X .5 NO DESCRIPTION: JET PUMP NO 7 TO FLOW INST EFC (CIV)

PI-EFC-X44BH IM530-1 1 ý SA NA GH TS ISP-EFC-B1 03 RV05 F2 C CK NA 1 X .5 NO DESCRIPTION: JET PUMP NO 8 TO FLOW INST EFC (CIV)

PI-EFC-X44BJ M530-1 1 SA NA GH TS ISP-EFC-B1 03 RV05 F2 C CK NA 1 X .5 NO DESCRIPTION: JET PUMP NO 9 TO FLOW INST EFC (CIV)

PI-EFC-X44BK M530-1 1 SA NA ýGH TS ISP-EFC-B3103 RV05 ill C CK NA 1 X .5 NO DESCRIPTION: JET PUMP NO 10 TO FLOW INST EFC (CIV)

PI-EFC-X44BL M530-1 1 SA NA :GH TS ISP-EFC-B1 03 RV05 H11 C CK NA 1 X .5 NO DSRIPTION: JET PUMP NO 5 TO FLOW INST EFC (CIV)

IST Program Plan Page 94 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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-X44BM M530-1 1 SA NA GH TS ISP-EFC-B103 RV05 H1l C CK NA 1 X1.5 NO DESCRIPTION: JET PUMP NO 10 TO FLOW INST EFC (CIV)

PI-EFC-X61A M530-1 1 SA NA GH TS ISP-EFC-B106 RV05 F12 C CK NA 11 X .5 NO DESCRIPTION: RRC ATO FT-14C,14D EFC (CIV)

PI-EFC-X61B M530-1 F12 1

C 1 SA CK 1 X .5

[

[ NA NA NO JGH TS ISP-EFC-B106 RV05 DESCRIPTION: RRC A TO FT-14C,14D EFC (CIV)

PI-EFC-X61 C M529 2 SA NA GH FS ISP-EFC-B108 N12 G5 C CK NA Passive 1X .5 NO DESCRIPTION: DRYWELL ATM TO PRESS INST EFC (CIV)

PI-EFC-X62B IM529 2 1 SA NA jGH FS ISP-EFC-B108 N12 H12 C CK NA Passive 1 X .5 NO DESCRIPTION: DRYWELL ATM TO PRESS INST EFC (CIV)

PI-EFC-X62C M530-1 1 SA NA GH TS ISP-EFC-B106 RV05 F6 C CK NA 1 X_.5 NO DESCRIPTION: RRC B TO FT-24C,24D EFC (CIV)

PI-EFC-X62D M530-1 11 SA NA GH TS ISP-EFC-B106 RV05 F6 C CK NA 1 X .5 NO DESCRIPTION: RRC B TO FT-24C,24D EFC (CIV)

PI-EFC-X66 M543-1 2 SA NA GH FS ISP-EFC-B108 N12 B6 C CK NA Passive 1 X .5 NO DESCRIPTION: WETWELL ATM TO CSP-DPT-5 EFC (CIV)

PI-EFC-X67 M543-1 2 SA NA GH FS ISP-EFC-B108 N12 B13 C CK NA Passive 1 X .5 NO DESCRIPTION: WETWELL ATM TO CSP-DPT-4 EFC (CIV)

PI-EFC-X69A M529 1 SA NA GH TS ISP-EFC-B101 RV05 C4 C CK NA 1 X .5 NO DESCRIPTION: MAIN STEAM LINE D TO DPIS HI SIDE EFC (CIV)

PI-EFC-X69B M529 1 SA NA GH TS ISP-EFC-B101 RV05 C4 C CK NA 1X .5 NO DESCRIPTION: MAIN STEAM LINE D TO DPIS LO SIDE EFC (CIV)

PI-EFC-X69E M530 1 SA NA GH TS ISP-EFC-B104 RV05 G6 C CK NA 1X .5 NO DESCRIPTION: RRC B TO PS-18B EFC (CIV)

PI-EFC-X69F M529 2 SA 1 NA [GH FS ISP-EFC-B108 N12 H12 C CK NA Passive RXI.5 NO DESCRIPTION: DRYWELL ATM TO PS-48A,48C,2B EFC (CIV)

IST 10-Year 3rd ProgramInterval Plan Columbia Generating Station PageRevision 95 of 1851 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-X70A M529 1 SA NA GH TS ISP-EFC-B101 RV05 E4 C CK NA I X1.5 NO DESCRIPTION: MAIN STEAM LINE C TO DPIS HI SIDE EFC (CIV)

PI-EFC-X70B M529 1 SA NA [GH TS ISP-EFC-B101 RV05 E4 C CK NA 1 X[.5 NO DESCRIPTION: MAIN STEAM LINE C TO DPIS LO SIDE EFC (CIV)

PI-EFC-X70C M529 1 SA NA GH TS ISP-EFC-B101 RV05 E13 C CK NA 1 1 X.5 NO DESCRIPTION: MAIN STEAM LINE A TO DPIS HI SIDE EFC (CIV)

PI-EFC-X70D M529 1 SA NA IGH TS ISP-EFC-B101 RV05 E13 C CK NA 1 X.5 NO DESCRIPTION: MAIN STEAM LINE A TO DPIS LO SIDE EFC (CIV)

PI-EFC-X70E M530-1 1 SA NA GH TS ISP-EFC-B104 RV05 B14 C CK NA 11 X .5 NO DESCRIPTION: RRC A (RRC-P-1A) TO DPT-15A EFC (CIV) _ _

PI-EFC-X70F fM530-1 1 SA NA NA GH TS ISP-EFC-B104 RV05 B14 C CK I X .5 N DESCRIPTION: RRC A (RRC-P-1A) TO DPT-15A EFC (CIV)

PI-EFC-X71A tM529 E4 C 1 SA CK NA NA ___

GH TS ISP-EFC-B101 RV05 1 X .5 N DESCRIPTION: MAIN STEAM LINE C TO DPIS HI SIDE EFC (CIV)

PI-EFC-X71B M529 1 SA NA iGH TS ISP-EFC-B101 RV05 E4 C CK NA 1X .5 NO DESCRIPTION: MAIN STEAM LINE C TO DPIS LO SIDE EFC (CIV)

PI-EFC-X71C M519 1 SA NA GH TS ISP-EFC-B105 RV05 G6 C CK NA 11 X .5 NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-7A EFC (CIV)

PI-EFC-X71D 1M519 1 1 SA NA GH TS ISP-EFC-B105 RV05 G6 C CK NA 1 X .5 NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-7A EFC (CIV)

PI-EFC-X71E 1M519 1 1 1 SA NA GH TS ISP-EFC-B105 RV05 G6 C CK NA 1X .5 NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-13A EFC (CIV)

PI-EFC-X71F M519 1 SA NA GH TS ISP-EFC-B105 RV05 G6 C CK NA I 1 1 X .5 NO DESCRIPTION: RCIC STEAM SUPPLY TO DPIS-13A EFC (CIV)

PI-EFC-X72A M529 1 SA NA GH TS ISP-EFC-B107 RV05 J6 C CK NA 1 X .5 NO DESCRIPTION: RPV STEAM DOME TO PRESS INST EFC (CIV)

IST Program Plan Columbia Station Page 96 of 185 3rd 10-Year Interval Generating Revision 1 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-X73A M520 1 SA NA GH TS ISP-EFC-B105 RV05 J8 C CK NA 1 X1.5 NO DESCRIPTION: HPCS TO RPV TO DPIS-9 EFC (CIV)

PI-EFC-X74A M530-1 1 1SA NA tGH TS ISP-EFC-B103 RV05 G 12 C CK NA 1X .5 No DESCRIPTION: SLC INJ BELOW CORE PLATE TO FLOW INSTR EFC (CIV PI-EFC-X74B 1M521-1 j 1 1SA NA ýGH TS ISP-EFC-B104 RV05 H5 C CK NA 1X .5 NO DESCRIPTION: RHR LPCI A INJECTION TO DPIS-29A EFC (CIV)

PI-EFC-X74E M530-1 1 SA NA [GH TS ISP-EFC-B104 RV05 H11 C CK NA 1 X.5 NO DESCRIPTION: RRC A TO RHR PUMPS TO DPIS-12A EFC (CIV)

PI-EFC-X74F M5 3 0- 1 j 1 SA NA ýGH TS ISP-EFC-B104 RV05 H11 C CK NA 1X .5 NO DESCRIPTION: RRC A TO RHR PUMPS TO DPIS-12A EFC (CIV)

PI-EFC-X75A M530-1 1 SA NA 1GH TS ISP-EFC-B103 RV05 G6 C CK NA 1 X .5 NO DESCRIPTION: SLC INJ BELOW CORE PLATE TO FLOW INSTR EFC (CIV 5 PI-EFC-X75B [M530-1 1 SA NA GH TS ISP-EFC-B1i05 RV05 IC CK NA 11 X .5 NO DESCRIPTION: SLC INJ ABOVE CORE PLATE TO FLOW INSTR EFC (CIV)

PI-EFC-X75C M529 1 SA NA GH TS ISP-EFC-B101 RV05 E12 C 1CKX.5 NA NO DESCRIPTION: MAIN STEAM LINE ATO DPIS EFC (CIV)

PI-EFC-X75D M529 1 SA NA GH TS ISP-EFC-B101 RV05 E12 C CK NA 1 X.5 NO DESCRIPTION: MAIN STEAM LINE A TO DPIS EFC (CIV)

PI-EFC-X75E M530-1 1 SA NA GH TS ISP-EFC-B106 RV05 F5 C CK NA 1X .5 NO DESCRIPTION: RRC B TO FT-24A,24B EFC (CIV)

PI-EFC-X75F M530-1 1 11 SA NA GH TS ISP-EFC-B106 RV05 F5 C CK NA 1X .5 NO DESCRIPTION: RRC B TO FT-24A,24B EFC (CIV)

PI-EFC-X78A M543-2 2 1SA NA GH FS ISP-EFC-B108 N12 E14 C CK NA Passive 1 X.5 NO DESCRIPTION: 1-2-02 MONITOR TO DRYWELL ATM SAMPLE ISO (CIV)

PI-EFC-X78B M520 1 1 1 SA NA ýGH TS ISP-EFC-B104 RV05 J10 C CK NA 1X .5 NO DESRIPTION: LPCS TO RPV TO RHR-DPS-29A EFC (CIV)

IST Program Plan Page 97 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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-X78C M523 1 SA NA GH TS ISP-EFC-B103 RV05 F12 C CK NA 1 X1.5 NO DESCRIPTION: RWCU TO RWCU-FT-37 EFC (CIV)

PI-EFC-X78F M530-1 1 SA NA NA GH TS ISP-EFC-B104 RV05 C CK H12 1 X.5 NO DESCRIPTION: RRC A (RRC-P-1A SUCT) TO PS-18A EFC (CIV)

PI-EFC-X79A M523 1 SA NA NA GH TS ISP-EFC-B105 RV05 C CK F15 1 X.5 NOI DESCRIPTION: RWCU TO RWCU-FT-36 EFC (CIV)

PI-EFC-X79B M523 1 SA I NA IGH TS ISP-EFC-B105 RV05 F15 C CK NA 1 X .5 NO DESCRIPTION: RWCU TO RWCU-FT-36 EFC (CIV)

PI-EFC-X82B 1M543-1 2 SA NA GH FS ISP-EFC-B108 N12 B14 C CK NA Passive 1 X .5 NO DESCRIPTION: WETWELL ATM TO PT-3 EFC (CIV)

PI-EFC-X84A M543-1 2 SA NA GH FS ISP-EFC-B108 N12 B6 C CK NA Passive 1 X .5 NO DESCRIPTION: WETWELL ATM TO PT-4 EFC (CIV)

PI-EFC-X86A M543-1 2 SA NA GH FS ISP-EFC-B108 N12 B14 C CK NA Passive 11 X .5 NO DESCRIPTION: WETWELL TO LT-1 EFC (CIV)

PI-EFC-X86B M543-1 2 SA NA GH FS ISP-EFC-B108 N12 B14 C CK NA Passive 11 X .5 NO DESCRIPTION: WETWELL TO LT-1 EFC (CIV)

PI-EFC-X87A M543-1 2 SA NA GH FS ISP-EFC-B108 N12 B6 C CK NA Passive 1 X .5 ý NO DESCRIPTION: WETWELL TO LT-2 EFC (CIV)

PI-EFC-X87B M543-1 2 SA NA GH FS ISP-EFC-B108 N12 B6 C CK NA Passive 1 X .5 NO DESCRIPTION: WETWELL TO LT-2 EFC (CIV)

PI-EFC-X106 M529 1 SA NA [GH TS ISP-EFC-B107 RV05 H12 C CK NA 1 X.5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-Xl07 M529 1 SA NA GH TS ISP-EFC-B107 RV05

ýH12 C CK NA 11 X .5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X108 M529 1 SA NA IGH TS ISP-EFC-B107 RV05 G12 C CK NA D RXI.5 NO DESCRIPTION: RPV TO PRESS INT EFC (CIV)

IST Program Plan Columbia Station Page 98 of 185 3rd 10-Year Interval Generating Revision 1 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 1 SA NA GH TS ISP-EFC-B107 RV05 H5 C CK NA 1 X1.5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X1 10 M529 1 1 SA NA GH TS ISP-EFC-B107 RV05 H5 C 1 NA IGH T PI-EFC-X1 11 FM5 2 H5 9

1 C

[

DESCRIPTION: RPV TO PRESS INST EFC (CIV)

SA CK 1X .5 NA NA NO I GH TS ISP-EFC-B107 R0 RV05 DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X1 12 M5 2 9 1 SA NA jGH TS ISP-EFC-B 107 RV05 H5 C CK NA 11 X .5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X113 M529 1 SA NA 1GH TS ISP-EFC-B107 RV05 H5 C CK NA 1 X.5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-Xl 14 M529 1 SA NA GH TS ISP-EFC-B107 RV05 H12 C CK NA 1 X .5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

PI-EFC-X115 M529 12 1 GH TS ISP-EFC-B107 RV05 H12 C CK NA SX.5 NO DESCRIPTION: RPV TO PRESS INST EFC (CIV)

I PI-EFC-X119 M543- 1 2 SA NA GH FS ISP-EFC-B1 08 N 12 B6 C CK NA Passive 1 X .5 NOII PI-V-X42D M521-1 F5 11 2

A j

DESCRIPTION: WETWELL ATM TO CSP-DPT-6 EFC (CIV)

MA GB C

NA LC L J TSP-PI/X42D-C801 TV02 Passive DESCRIPTION: AIR TO RHR-V-50A OPERATOR (INBD CIV)

PI-V-X54BF M521-2 2 MA I C IL J TSP-CONT-R801 TV02 H13 A GB NA Passive 11 LC DESCRIPTION: AIR TO RHR-V-41B OPERATOR (INBD CIV)

PI-V-X61F M521-1 2 MA I C HxL J TSP-PI/X61 F-C801 TV02 G5 A GB NA Passive D P1 LC DESCRIPTION: AIR TO RHR-V-41 A OPERATOR (INBD CIV)

PI-V-X62F M521-31 2 1MA C ýL J TSP-PI/X62F-C80 TV02 D12 A GIB NA ,Passive 11 LC DESCRIPTION: AIR TO RHR-V-41 C OPERATOR (INBD CIV)

PI-V-X69C M521-21 2 1MA C IL J TSP-PI/X69C-C801 TV02 F13 A GB NA Passive 11 LCII DESCRIPTION: AIR TO RHR-V-50B OPERATOR (INBD CIV)

PI-V-X72F/1 M543-1 12 SA C ýHx 4Y OSP-CONT/IST-R701 ROJ04 T0 F13 AC CK NA HxL J TSP-PI/X72F-R801 CMP-13 11 NOII DESCRIPTION: DRYWELL ATM TO RAD-RE-1 2A CHK (CIV)

IST Program Plan Page 99 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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-V-X73E/1 M543-1 2 SA C Hx 4Y OSP-CONT/IST-R701 ROJO4 TV02 F7 AC CK NA HxL J TSP-PI/X73E-R801 CMP-13 1 NO DESCRIPTION: DRYWELL ATM TO RAD-RE-12B CHK (CIV)

PI-VX-216 M521-1 2 MA C IL J TSP-PI/X42D-C801 TV02 G6 A GB NA Passive 1 LCI DESCRIPTION: AIR TO RHR-V-50A OPERATOR (OTBD CIV)

PI-VX-218 M521-2 2 MA C L J TSP-CONT-R801 TV02 H13 A GB NA Passive 1 LC DESCRIPTION: AIR TO RHR-V-41 B OPERATOR (OTBD CIV)

PI-VX-219 M521-1 2 MA C L J TSP-PI/X61 F-C801 TV02 H6 A GB NA Passive 11 LC II DESCRIPTION: AIR TO RHR-V-41A OPERATOR (OTBD CIV)

PI-VX-220 M521-3 2 MA C L J TSP-PI/X62F-C801 TV02 D11 A GB NA Passive 1 LC II DESCRIPTION: AIR TO RHR-V-41C OPERATOR (OTBD CIV)

PI-VX-221 M521-2 2 MA C JL TSP-PI/X69C-C801 TV02 G12 A GB NA Passive G11 LC I DESCRIPTION: AIR TO RHR-V-50B OPERATOR (OTBD CIV)

PI-VX-250 M543-1 2 SO C G 2Y OSP-CONT/IST-0703 TV01,2 F13 A SV FC G 2Y TSP-CONT-R801 1 NO HJK Q OSP-CONT/IST-Q703 L J TSP-P2/X85A/C-R801 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 1 NO HJK Q OSP-CONT/IST-Q703 L J TSP-P2/X85A/C-R801 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-253 M543-1 2 SO C G 2Y OSP-CONT/IST-Q703 TV01,2 F13 A SV FC G 2Y TSP-CONT-R801 1 NO HJK Q OSP-CONT/IST-Q703 L J TSP-P2/X72F-R801 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-256 M543-1 2 SO C G 2Y OSP-CONT/IST-Q703 TV01,2 F7 A SV FC G 2Y TSP-PI/X29A/C-R801 1 NO HJK Q OSP-CONT/IST-Q703 L J TSP-PI/X29A/C-R801 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-257 M543-1 2 SO C G 2Y OSP-CONT/IST-Q703 TV01,2 F7 A SV FC G 2Y TSP-PI/X29A/C-R801 1 NO HJK Q OSP-CONT/IST-Q703 L J TSP-PI/X29A/C-R801 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

PI-VX-259 M543-1 2 SO C G 2Y OSP-CONT/IST-Q703 TV01,2 F7 A SV FC G 2Y TSP-CONT-R801 1 NO HJK Q OSP-CONT/IST-Q703 L J TSP-PI/X73E-R801 DESCRIPTION: DRYWELL TO RADIATION MONITOR ISO (CIV)

IST Program Plan Columbia Station Page 100 of 185 3rd 10-Year Interval Generating Revision 1 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-VX-262 M543-2 2 so NA G 2Y OSP-CONT/IST-Q703 N11 G13 B SV FC HJK Q OSP-CONT/IST-Q703 Passive 1 NO DESCRIPTION: DRYWELL TO H2-O2 MONITOR ISO (CIV)

PI-VX-263 M543-2 2 SO NA G 2Y OSP-CONT/IST-Q703 [ [N1 1 F13 I B SV FC HJK 0 OSP-CONT/IST-Q703 Passive 1 1 NO DESCRIPTION: DRYWELL TO H2-02 MONITOR ISO (CIV)

PI-VX-264 M543-2 2 1 SO NA G 2Y OSP-CONT/IST-Q703 N11 F13 B SV FC HJK 0 OSP-CONT/IST-Q703 Passive 11 NO DESCRIPTION: DRYWELL TO H2-02 MONITOR ISO (CIV)

PI-VX-265 M543-2 2 SO NA G 2Y OSP-CONT/IST-Q703 N1 B14 B SV FC ýHJK Q OSP-CONT/IST-0703 Passive 1 1 NO DESCRIPTION: DRYWELL TO H2-02 MONITOR ISO (CIV)

PI-VX-266 JM543-2 F7 1N 2

B SO S7 SV NA FC G

HJK Q 2Y OSP-CONT/IST-Q703 OSP-CONT/IST-Q703 1 Nil Passive 1 NO DESCRIPTION: DRYWELL TO H2-02 MONITOR ISO (CIV)

PI-VX-268 M543-21 2 1 SO NA G 2Y OSP-CONT/IST-Q703 N11 F7 B SV FC HJK Q OSP-CONT/IST-Q703 Passive 1 NO DESCRIPTION: DRYWELL TO H2-02 MONITOR ISO (CIV)

PI-VX-269 M543-2 2 SO NA G 2Y OSP-CONT/IST-Q703 N11 B6 _ B SV FC HJK Q OSP-CONT/IST-Q703 Passive I 11 NO DESCRIPTION: DRYWELL TO H2-02 MONITOR ISO (CIV)

PSR-V-003/A M896 2 SO C G 2Y CSP-PSR/IST-Q701 TV01 E12 B SV FC HJ Q CSP-PSR/IST-Q701 11 NC DESCRIPTION: RHR LOOP A SAMPLE ISO PSR-V-003/B M896 ý 2 [ SO C [G 2Y CSP-PSR/IST-Q701 TV01 D12 B SV FC HJ Q CSP-PSR/IST-Q701 1 NC DESCRIPTION: RHR LOOP B SAMPLE ISO PSR-V-X73/1 M896 A

2 [ SO GB C

FC IG HJK Q 2Y TSP-CONT-R801 CSP-PSR/IST-Q701 RV03 TV01,2 J14 1 NC L J TSP-PSR-R801 DESCRIPTION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X73/2 [M896 [ 2 SO C G 2Y TSP-CONT-R801 TV01,2 J12 A GB FC HJK Q CSP-PSR/IST-Q 701 1 NC L J TSP-PSR-R801 DESCRIPTION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X77A/1 [M896 1lSO C G 2Y TSP-CONT-R801 RV03 TV01,2 El4 A GB FC HJK Q CSP-PSR/IST-Q701 1 NC L J TSP-PSR-R801 DESCRIPTION: JET PUMP SAMPLE ISO (CIV)

PSR-V-X77A/2 1M896 1 50 C G 2Y TSP-CONT-R801 TV01,2 E12 A GB FC HJK Q CSP-PSR/IST-Q701 1 NC L J TSP-PSR-R801 DESCRIPTION: JET PUMP SAMPLE ISO (CIV)

PSR-V-X77A/3 M896 1 SO C iG 2Y TSP-CONT-R801 RV03 TV01,2 So FC HJK Q CSP-PSR/IST-Q701 F1 4 Al __ GB __ FC0 __ _ C-SRSTQ0__I_

1 NC L J TSP-PSR-R801 DESCRIPTION: JET PUMP SAMPLE ISO (CIV)

IST 10-Year 3rd ProgramInterval Plan Columbia Generating Station Page 101 of 1851 Revision 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)

PSR-V-X77A/4 M896 1 SO C G 2Y TSP-CONT-R801 TV01,2 F12 A GB FC HJK Q CSP-PSR/IST-Q701 1 1 NC L J TSP-PSR-R801 DESCRIPTION: JET PUMP SAMPLE ISO (CIV)

PSR-V-X80/1 M896 2 SO C G 2Y TSP-CONT-R801 RV03 TV01,2 K14 A GB FC HJK Q CSP-PSR/IST-Q701 1 NC L J TSP-PSR-R801 DESCRIPTION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X80/2 M896 2 So C G 2Y TSP-CONT-R801 TV01,2 K12 A GB FC HJK Q CSP-PSR/IST-Q701 1_1 NC L J TSP-PSR-R801 DESCRIPTION: DRYWELL ATM SAMPLE ISO (CIV)

PSR-V-X82/1 jM896 2 SO C G 2Y TSP-CONT-R801 RV03 TV01,2 B12 A GB FC HJK 0 CSP-PSR/IST-Q701 1 NC L J TSP-PSR-R801 DESCRIPTION: SAMPLE RETURN TO SUPP POOL ISO (CIV)

PSR-V-X82/2 M896 2 SO C G 2Y TSP-CONT-R801 TV01,2 B1l A GB FC HJK Q CSP-PSR/IST-Q701 1 _1 _ NC L TSP-PSR-R801 DESCRIPTION: SAMPLE RETURN TO SUPP POOL ISO (CIV)

PSR-V-X82/7 M896 2 SO C G 2Y TSP-CONT-R801 RV03 TV01,2 G12 A GB FC HJK Q CSP-PSR/IST-Q701 1 NC L J TSP-PSR-R801 DESCRIPTION: SAMPLE RETURN TO DRYWELL ISO (CIV)

PSR-V-X82/8 M896 2 SO C G 2Y TSP-CONT-R801 TV01,2 G11 A GB FC HJK Q CSP-PSR/IST-Q701 1 1 NC J TSP-PSR-R801 DESCRIPTION: SAMPLE RETURN TO DRYWELL ISO (CIV)

PSR-V-X83/1 M896 A2 SO C G 2Y TSP-CONT-R801 RV03 TV01,2 J13 A GB FC HJK Q CSP-PSR/IST-Q701 1 NC L J TSP-PSR-R801 DESCRIPTION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X83/2 1M896 J12 A2 SB CC G HJK 2Y Q TSP-CONT-R801 CSP-PSR/IST-Q0 TV01,2 1 NC L J TSP-PSR-R801 DESCRIPTION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X84/1 M896 12 1SO I C IG 2Y TSP-CONT-R801 RV03 TV01,2 H12 A GB FC HJK Q CSP-PSR/IST-Q701 1 NC L J TSP-PSR-R801 DESCRIPTION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X84/2 M896 2 SO C G Y TSP-CONT-R801TV01,2 H11 A GB FC HJK Q CSP-PSR/IST-Q701 1 1 NC L J TSP-PSR-R801 DESCRIPTION: WETWELL ATM SAMPLE ISO (CIV)

PSR-V-X88/1 M896 21 SO C G 2Y TSP-CONT-R801 RV03 TV01,2 D13 A GB FC HJK 0 CSP-PSR/IST-Q701 1 NC L J TSP-PSR-R801 DESCRIPTION: SUPP POOL SAMPLE ISO (CIV)

PSR-V-X88/2 M896 2 SO C [G 2Y TSP-CONT-R801 TV01,2 D11 A GB FC HJK Q CSP-PSR/IST-Q701 1 NC L J TSP-PSR-R801 DESCRIPTION: SUPP POOL SAMPLE ISO (CIV)

IST Program Plan Columbia Generating Station Page 102 of 185 3rd 10-Year Interval Revision 1 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)

RCC-RV-34A M525-2 3 SA NA P RV TSP-RV/IST-R701 TV03 J7 C RV NA

.75 X1 NC DESCRIPTION: FPC-HX-1A SHELL SIDE RV RCC-RV-34B IM525-2 3 SA NA P RV TSP-RV/IST-R701 TV03 G7 C RV NA

.75 X 1 NC DESCRIPTION: FPC-HX-1B SHELL SIDE RV RCC-V-5 M525-1 2 MO C G 2Y OSP-RCC/IST-R701 ROJ13 TV01,2 E4 A GB FAI HJ RF OSP-RCC/IST-R701 10 NO L J TSP-RCC/X5-C801 DESCRIPTION: RCC TO DRYWELL COOLING LOADS (1ST OTBD CIV)

RCC-V-21 M525-1 2 MO C G 2Y OSP-RCC/IST-R701 ROJ13 TV01,2 D3 A GT FAI HJ RF OSP-RCC/IST-R701 10 NO L J TSP-RCC/X46/C801 DESCRIPTION: RCC FROM DRYWELL COOLING LOADS (OTBD CIV)

RCC-V-40 M525-1 2 MO I C IG 2Y OSP-RCC/IST-R701 ROJ13 D4 A GT FAI HJ RF OSP-RCC/IST-R701 C10 NO L TSP-RCC/X46/C8 [

DESCRIPTION: RCC FROM DRYWELL COOLING LOADS (INBD CIV)

RCC-V-104 M525-1 2 MO C G 2Y OSP-RCC/IST-R701 ROJ13 TV01,2 E4 A GT FAI HJ RF OSP-RCC/IST-R701 10 NO JL TSP-RCC/X5-C801 DESCRIPTION: RCC TO DRYWELL COOLING LOADS (2ND OTBD CIV)

RCC-V-129 M525-2 3 MO C IG 2Y OSP-RCC/IST-Q701 ITV01 B M6 GT FAI HJ Q OSP-RCC/IST-0701 8 NO DESCRIPTION: RCC TO FPC-HX-1A & 1B ISO RCC-V-130 M525-2 3 MO C G 2Y OSP-RCC/IST-Q701 TV01 E8 B GT FAI HJ Q OSP-RCC/IST-Q701 8 NO DESCRIPTION: RCC FROM FPC-HX-1A & 1B ISO RCC-V-131 M525-2 3 MO I C G 2Y OSP-RCC/IST-0701 TV01 E8 B GT FAI HJ Q OSP-RCC/IST-Q701 8 NO I DESCRIPTION: RCC FROM FPC-HX-1A & 1B ISO RCC-V-133A M525-2 3 SA C H Q OSP-FPC/IST-Q701 J6 C CK NA 6 NO DESCRIPTION: RCC TO FPC-HX-lA CHK RCC-V-133B M525-2 3 SA C H Q OSP-FPC/IST-Q701 G6 C CK NA 6 NO DESCRIPTION: RCC TO FPC-HX-1B CHK RCC-V-219 M525-1 2 SA O/C Hx 4Y OSP-RCC/IST-R701 ROJO5 C4 AC CK NA HxL J TSP-RCC/X46-C801 CMP-04 1/2 NC Di 1OY DESCRIPTION: PRESSURE RELIEF AROUND RCC-V-40 CHK (INBD CIV)

RCIC-RD-1 M519 2 SA NA W RD MMP-RCIC/IST-F701 D12 D RD NA 10 NC DESCRIPTION: RCIC TURBINE EXHAUST LINE RUPTURE DISC

IST ProgramInterval 3rd 10-Year Plan Columbia Generating Station Page 103 of 1851 Revision 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-RD-2 M519 2 SA NA W RD MMP-RCIC/IST-F701 012 D RD NA 10 NC DESCRIPTION: RCIC TURBINE EXHAUST LINE RUPTURE DISC RCIC-RV-3 rM519 D)13 C 2 SA RV 3/4 X 1 NA NA NC P RV TSP-RV/IST-R701 IN09 ITV03 DESCRIPTION: RCIC PUMP DISCHARGE THERMAL RELIEF RCIC-RV-17 M519 C13 C 2 SA RV 1 X1I NA NA NC P RV TSP-RV/IST-R701 IN09 TV03 DESCRIPTION: RCIC PUMP SUCT RV RCIC-RV-19T M519 2 SA NA P RV TSP-RV/IST-R701 ITV03 D9 C RV NA 2 X3 NC DESCRIPTION: RCIC-P-1 DISCH TO LO COOLER RV RCIC-V-1 M519 NA MO C G 2Y OSP-RCIC/IST-Q701 TV01 El1 B GB FAI HJ Q OSP-RCIC/IST-Q701 3 NO DESCRIPTION: RCIC TURBINE TRIP/THROTTLE VLV (SUPPLIED AS RCIC-DT-1 SKID)

RCIC-V-2 EM519 NAT HOGT 0 rGH Q OSP-RCIC/IST-Q701 N10 Ell B j GT J FO __ _ _ _ _ _ _ _ _ _ _I_ _ _ _

DESCRIPTION: RCIC TURBINE GOVERNOR VLV (SUPPLIED AS RCIC-DT-1 SKID)

RCIC-V-4 M519 12 AO [ C HJK Q OSP-RCIC/IST-0702 1ooN07 B10 B j DI 1

FC NO G 2Y OSP-RCIC/IST-Q702 TV01 DESCRIPTION: RCIC-P-4 DISCH TO EDR ISO RCIC-V-5 M519 2 AO C HJK Q OSP-RCIC/IST-Q702 N07 B10 B DI NcFC G 2Y OSP-RCIC/IST-Q702 TV01 DESCRIPTION: RCIC-P-4 DISCH TO EDR ISO RCIC-V-8 M519 1 1 1 MO C G 2Y OSP-RCIC/IST-Q702 TV01,2 F6 A GT FAI HJ Q OSP-RCIC/IST-Q702 4 NO L J TSP-RCIC/X21 -C801 RCICV-1 [M519 12tMO B14 B GT I

DESCRIPTION: RCIC TURBINE STEAM SUPPLY (OTBD CIV)

T C FAI

'G HJQ 2Y S-C/ITQ0IV1 OSP-RCIC/IST-Q702 iTVO1 8 NO DESCRIPTION: CST TO RCIC-P-1 SUCT RCIC-V-11 M519 B13 2

C SA CK 0

NA

ýH 0 OSP-RCIC/IST-0701 I 8 NC DESCRIPTION: CST TO RCIC-P-1 SUCT CHK RCIC-V-13 M519 1 MO O/C G 2Y OSP-RCIC/IST-Q703 CSJ05 TV01,2 H6 A GT FAI HJ CS OSP-RCIC/IST-Q703 6 NC L 2Y TSP-RCS-R802 DESCRIPTION: RCIC TO RPV HEAD SPRAY ISO (OTBD CIV) acIc-v-19 M519 2 MO21 O/C G 2Y OSP-RCIC/IST-Q702 TNV0 F7 B j B FAI HJ Q OSP-RCIC/IST-Q702 N16 DESCRIPTION: RCIC-P-1 MINIMUM FLOW TO SUPP POOL (OTBD CIV)

IST Program Plan Columbia Station Page 104 of 185 3rd 10-Year Interval Generating Revision 1 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-21 M519 2 SA 0 Hx Q OSP-RCIC/IST-Q701 F8 C CK NA Nit 8Y CMP-05 1 2 NC DESCRIPTION: RCIC-P-1 MINIMUM FLOW TO SUPP POOL CHK RCIC-V-22 M519 2 MO C G 2Y OSP-RCIC/IST-Q702 TV01 J8 B GB FAI HJ Q OSP-RCIC/IST-Q702 6 NC DESCRIPTION: RCIC-P-1 DISCH TO CST ISO RCIC-V-25 M519 2 AO C HJK Q OSP-RCIC/IST-Q702 N07 E9 B DI FC G 2Y OSP-RCIC/IST-Q702 TV01 1 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 TVO1 1 NO DESCRIPTION: RCIC TURBINE STM SUPPLY STM TRAPS TO MAIN COND ISO RCIC-V-28 M519 2 SA O/C Hx Q OSP-RCIC/IST-Q702 N16 D8 BC CK NA Nit 4Y CMP-06 1.50 NC Di lOY DESCRIPTION: AUX COOLING TO SUPP POOL CHK (CIV)

RCIC-V-30 M519 2 SA 0 Hx 2Y OSP-RCIC/IST-B501 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 /C G 2Y OSP-RCIC/IST-Q702 TV01 C7 B GT FAI HJ Q OSP-RCIC/IST-Q702 N16 8 NC DESCRIPTION: SUPPRESSION POOL TO RCIC-P-1 SUCT (OTBD CIV)

RCIC-V-40 M519 2 SA O/C IHx Q OSP-RCIC/IST-Q701 TV02 E8 AC CK NA HxL J TSP-RCIC/X4-C801 CMP-08 10 NC Nit 8Y DESCRIPTION: RCIC TURBINE EXHAUST TO SUPP POOL CHK (CIV)

RCIC-V-45 M519 2 MO O/C 2Y OSP-RCIC/IST-Q701 [V01 FG1 B GB FAI HJ Q OSP-RCIC/IST-Q701 4 NC DESCRIPTION: RCIC TURB STM SUPPLY ISO (MAIN TURBINE TRIP I/L)

RCIC-V-46 M59 2 MO O/C ýG 2Y OSP-RCIC/IST-Q702 TV01 G BGFAI B HJ Q OSP-RCIC/IST-Q702 B2 NC DESCRIPTION: RCIC AUXILIARY COOLING TO LO COOLER ISO RCIC-V-47 M519 2 SA O/C Hx Q OSP-RCIC/IST-Q701 B10 C CK NA Hx 4Y OSP-RCIC/IST-Q702 CMP-09 2 NC Nit 4Y DESCRIPTION: RCIC-P-4 (CONDENSATE PUMP) DISCH CHK RCIC-V-50 M519 2 MO IC ýG 2Y OSP-RCIC/IST-Q702 TV01 F10 B GB FAI HJ 0 OSP-RCIC/IST-Q702 2 LO DESCRIPTION: RCIC-HX-2 CW SUPPLY ISO RCIC-V-59 M519 2 MO C G 2Y OSP-RCIC/IST-Q702 TV01 J8 B GT FAI HJ Q OSP-RCIC/IST-Q702 6 NC DESCRIPTION: RCIC-P-1 TO CST ISO

IST Program Plan Columbia Generating Station Page 105 of 185 3rd 10-Year Interval Revision 1 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-63 M519 1 MO C G 2Y OSP-RCIC/IST-Q702 TV01,2 H3 A GT FAI HJ Q OSP-RCIC/IST-Q702 1 10 NO L J TSP-RCIC/X21-C801 DESCRIPTION: RCIC TURBINE STEAM SUPPLY TO RHR STM-COND (CIVI RCIC-V-64 M519 1 MO C L J TSP-RCIC/X21-C801 TV02 G6 A GT NA Passive 10 LC DESCRIPTION: RCIC TURBINE STEAM SUPPLY TO RHR STM-COND (CIV)

RCIC-V-65 M519 1 C

SA CK 1 NA G

H 2Y RF OSP-RCIC/IST-R701 OSP-RCIC/IST-R701 ROJO8 H6 6 NC DESCRIPTION: RCIC-P-1 DISCH TO RPV HEAD SPRAY CHK RCIC-V-66 M519 J4 1 SA CK

[/C N/AC H

HL RF RF OSP-RCIC/IST-R701 TSP-RCS-R803 ROJo8 TV02 6 NC DESCRIPTION: RCIC TO RPV HEAD SPRAY CHK (INBD CIV)

RCIC-V-68 M519 E7 2

A MO GT C

FAI G

HJ 2Y Q

OSP-RCIC/IST-Q702 OSP-RCIC/IST-Q702

[TV01,2 10 NO L J TSP-RCIC/X4-C801 DESCRIPTION: RCIC TURBINE EXHAUST TO SUPP POOL (OTBD CIV)

RCIC-V-69 M519 2 MO C G 2Y OSP-RCIC/IST-Q702 TV01 D7 B GT FAI HJ Q OSP-RCIC/IST-Q702 N16 1.50 NO DESCRIPTION: RCIC VACUUM PUMP TO SUPP POOL (OTBD CIV)

RCIC-V-76 M519 1 MO C G 2Y OSP-RCIC/IST-Q702 TV01,2 H3 A GB FAI HJ Q OSP-RCIC/IST-Q702 1 NC L J TSP-RCIC/X21-C801 DESCRIPTION: RCIC-V-63 BYPASS (INBD CIV)

RCIC-V-90 M519 2 SA O/C [H Q OSP-RCIC/IST-Q701 H7 C CK NA 6 NC DESCRIPTION: RCIC DISCHARGE HEADER CHK RCIC-V-110 M519 2 MO NA ýG 2Y OSP-RCIC/IST-Q702 Passive E7 B GT FAI 2 NO DESCRIPTION: RCIC TURB EXH TO SUPP POOL VAC REL ISO RCIC-V-111 M519 2 SA O/C Hx 4Y OSP-RCIC/IST-Q702 N04 E7 C CK ON/AC Di 10Y CMP-1 1 1 2 1 NC DESCRIPTION: RCIC TURBINE EXHAUST VACUUM BREAKER ISO RCIC-V-112 M519 ý 2 SA O/C 1Hx 4Y OSP-RCIC/IST-Q702 N04 E7 C CK NA Di 1OY CMP-1 1 2 NC DESCRIPTION: RCIC TURBINE EXHAUST VACUUM BREAKER ISO RCIC-V-113 M519 1 2 MO NA ýG 2Y OSP-RCIC/IST-Q702 Passive E7 B GT FAI 2 NO DESCRIPTION: RCIC TURB EXH TO SUPP POOL VAC REL ISO RCIC-V-204 M519 2 SA O/C Hx Q OSP-RCIC/IST-Q701 B14 C CK NA Hx 4Y OSP-RCIC/IST-Q702 CMP-1D2 8 NC Di 8Y DESCRIPTIN RCIC PUMP SUCT FROM CST CHK

IST Program Plan Page 106 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1]

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 H1 B BF I Fg HJK Q OSP-CONT/IST-Q702 72 NO DESCRIPTION: REACTOR BUILDING EXHAUST REA-V-2 M545-3 H1 3

B AO BF C

FC 1G2Y HJK Q OSP-CONT/IST-Q702 OSP-CONT/IST-Q702 TV01 72 NO DESCRIPTION: REACTOR BUILDING EXHAUST RFW-V-10 A 2 C H RF OSP-RFW/IST-Q701 ROJ06 TV02 G12 AC CK NA HL 2Y TSP-RFW/X17A-R801 124 NO DESCRIPTION: RFW TO RPV CHK INBD CIV)

RFW-V-10B M529 1 SA C H RF OSP-RFW/IST-Q701 ROJO6 TV02 G5 AC CK NA HL 2Y TSP-RFW/X17B-R801 124 NO DESCRIPTION: RFW TO RPV CHK INBD CIV)

RFW-V-32A M529 1 SA C H RF OSP-RFW/IST-Q701 ROJO6 N02 G13 AC CK NA HL 2Y TSP-RFW/X17A-R803 TV02 124 NOI DESCRIPTION: RFW TO RPV CHK 1ST OTBD CIV)

RFW-V-32B 1M529 1 SA M C IH RF OSP-RFW/IST-Q701 CROJ06 N02 G5 AC CK NA HL 2Y TSP-RFW/XT7B-R802 TV02 I 1 1 24 NO DESCRIPTION: RFW TO RPV CHK (1ST OTBD CIV)

RFW-V-65A M529 1 MO C G 2Y OSP-RFW/IST-Q701 CSJ02 TV01,2 G13 A GT FAI [HJ CS OSP-RFW/IST-Q701 124 NO L 2Y TSP-RFW/X1 7A-R802 DESCRIPTION: RFW TO RPV ISO (2ND OTBD CIV)

RFW-V-65B M529 1 MO 1 C fG 2Y OSP-RFW/IST-0701 CSJ02 TV01,2 G4 A GT FAI HJ CS OSP-RFW/IST-Q701 24 NO L 2Y TSP-RFW/XN7A-R802 DESCRIPTION: RFW TO RPV ISO (2ND OTBD CIV)

RHR-FCV-64A M521-1 2 MO 0/C G 2Y OSP-RHR/IST-Q702 TV01 B1 B MGB O/C F HJ Q OSP-RHR/IST-Q702 N16 3 NO DESCRIPTION: RHR-P-2A MINIMUM FCV (CIV)

RHR-FCV-64B M521-2 2 MO O/C IG 2Y OSP-RHR/IST-Q703 TV01 B5 B GB FAI HJ Q OSP-RHR/IST-Q703 N16 3 NO DESCRIPTION: RHR-P-2B MINIMUM FCV (CIV)

RHR-FCV--64C ýM521-31 2 1MO O/C G 2Y OSP-RHR/IST-Q704 TV01 E4 B GB FAI HJ Q OSP-RHR/IST-Q704 N16 3 NO DESCRIPTION: RHR-P-2C MINIMUM FCV (CIV)

RHR-RV-1A M521 2 SA NA P RV TSP-RV/IST-R701 TV02,3 H13 AC RV NAC L TSP-CONT-CS01 S .75RX 1 NC DESCRIPTION: RHR-HX-1A SHELL SIDE RV (CIV)

IST Program Plan Columbia Generating Station Page 107 of 185 3rd 10-Year Interval Revision 1 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)

RHR-RV-1B M521-2 2 SA NA P RV TSP-RV/IST-R701 TV02,3 H5 AC RV NA L J TSP-CONT-C801

.75 X 1 NC DESCRIPTION: RHR-HX-1B SHELL SIDE RV (CIV)

RHR-RV-5 IM521-1 C8 2

AC11 SA RV T NA NA P RV J

TSP-RV/IST-R701 TSP-CONT-C801 TV02,3 N09 X2 NC ý DESCRIPTION: RHR SHUTDOWN COOLING SUCT RV (CIV)

RHR-RV-25A [M521-1 2 SA NA P RV TSP-RV/IST-R701 TV02,3 D10 AC RV NA jL J TSP-CONT-C801 N09 1X2 NC DESCRIPTION: RHR LOOP A TEST LINE RV (CIV)

RHR-RV-25B M521-2 2 SA NA P RV TSP-RV/IST-R701 TV02,3 C10 AC RV NA L J TSP-CONT-C801 N09 I1 X2 NC DESCRIPTION: RHR LOOP B TEST LINE RV (CIV)

RHR-RV-25C IM521-3 2 SA NA P RV TSP-RV/IST-R701 TV02,3 E8 AC RV NA IL J TSP-CONT-C801 N09 1X2 NC DESCRIPTION: RHR LOOP C TEST LINE RV (CIV)

RHR-RV-30 M521-2 2 SA NA P RV TSP-RV/IST-R701 TV02,3 D8 AC RV NA J TSP-CONT-C801 N09

.75S 7X1 NC DESCRIPTION: RHR FLUSH LINE RV (CIV)

RHR-RV-88A IM521-1 1 2 SA 1 NA P RV TSP-RV/IST-R701 TV02,3 C7 AC RV NA [L J TSP-CONT-C801 N09 1.75 X 1 NC DESCRIPTION: RHR-P-2A SUCT RV (CIV)

RHR-RV-88B M521-2 2 SA 1 NA [P RV TSP-RV/IST-R701 TV02,3 D9 AC RV NA JL TSP-CONT-C801 N09 1.75 X 1 NC DESCRIPTION: RHR-P-2B SUCT RV (CIV)

RHR-RV-88C M521-31 2 MSA ]NA C P RV TSP-RV/IST-R701 TV02,3 D8 AC RV NA I J TSP-CONT-C801 N09

.75 1X NC DESCRIPTION: RHR-P-2C SUCT RI (CIV)

RHR-V-3A M521-1 2 MO O/C IG 2Y OSP-RHR/IST-Q702 TV01 H10 B GT FAI HJ Q OSP-RHR/IST-Q702 DESCRIPTION: RHR-HX-I A OUTLET ISO RHR-V-3B M521-2 2__ [181 MO NO O/C j__

IG 2Y _ _ _ _

OSP-RHR/IST-Q703 I_ _I TV01 1 I HJ Q OSP-RHR/IST-Q703 CJ9 B GT DESCRIPTION: RHR-HX-E B OUTLET ISO RHR-V-4A M521-1 I2 __ j28 MO NO O/C J__

G 2Y _ _ _

OSP-RHR/IST-Q702 _j TVo1 C7 B GT FAI HJ Q OSP-RHR/IST-Q702 N16 24 NO DESCRIPTION: SUPPRESSION POOL TO RHR-P-2A SUCT (OTBD CIV)

RHR-V-4B M521-2 2 1MO O/C ýG 2Y OSP-RHR/IST-Q703 TV01 B11 B GT FAI HJ Q OSP-RHR/IST-Q703 N16 124 NO DESRIPTION: SUPPRESSION POOL TO RHR-P-2B SUCT (OTBD CIV)

IST Program Plan Columbia Station Page 108 of 185 3rd 10-Year Interval Generating Revision 1 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)

RHR-V-4C M521-3 2 MO O/C G 2Y OSP-RHR/IST-Q704 TV01 B11 B GT FAI HJ Q OSP-RHR/IST-Q704 N16 1_ _ 1_ 24 NO I I _I DESCRIPTION: SUPPRESSION POOL TO RHR-P-2C SUCT (OTBD CIV)

RHR-V-6A M521-1 2 MO O/C G 2Y OSP-RHR/IST-Q702 TV01 B8 B GT FAI HJ Q OSP-RHR/IST-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-RHR/IST-Q703 18 NC DESCRIPTION: RPV TO RHR-P-2B SUCT (SDC MODE)

RHR-V-8 M521-1 1 MO O/C G 2Y OSP-RHR/IST-R704 ROJ10 TV01,2 E6 A GT FAI HJ 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 M521-1 1 MO O/C G 2Y OSP-RHR/IST-R704 ROJ10 TV01,2 D5 A GT FAI HJ RF OSP-RHR/IST-R704 20 NC L 2Y TSP-RCS-R802 DESCRIPTION: RHR SDC MODE SUPPLY FOR A & B FROM RPV (INBD CIV)

RHR-V-16A M521-1 2 MO O/C G 2Y OSP-RHR/IST-Q705 CSJ12 TV01,2 H7 A GT FAI HJ CS OSP-RHR/IST-Q705 116 NC L J TSP-RHR/Xl 1A-C801 DESCRIPTION: RHR TO DRYWELL SPRAY HEADER (2ND OTBD CIV)

RHR-V-16B M521-2 2 MO O/C G 2Y OSP-RHR/IST-Q706 CSJ12 01,2 D1l A GT FAI HJ CS OSP-RHR/IST-Q706 16 NC L J TSP-RHR/X1 1 B-C801 DESCRIPTION: RHR TO DRYWELL SPRAY HEADER (2ND OTBD CIV)

RHR-V-17A M521-1 2 MO T 0/C G 2Y OSP-RHR/IST-Q705 CSJ12 TV01,2 H6 A GT FAI HJ CS OSP-RHR/IST-Q705 16 NC L J TSP-RHR/Xl 1A-C801 DESCRIPTION: RHR TO DRYWELL SPRAY HEADER (1ST OTBD CIVL RHR-V-17B M521-2 2 MO O/C IG 2Y OSP-RHR/IST-Q706 CSJ12 TV01,2 D11 A GT FAI HJ CS OSP-RHR/IST-Q706 16 NC L J TSP-RHR/X1 1B-C801 DESCRIPTION: RHR TO DRYWELL SPRAY HEADER (1ST OTBD CIV)

RHR-V-21 M521-3 2 MO C G 2Y OSP-RHR/IST-Q704 TV01 E7 B GB FAI HJ Q OSP-RHR/IST-Q704 N16 18 NC DESCRIPTION: RHR LOOP C TEST LINE TO SUPP POOL (OTBD CIV)

RHR-V-23 M521-2 1 MO C G 2Y OSP-RHR/IST-Q706 CSJ01 TV01,2 K13 A GB FAI HJ CS OSP-RHR/IST-Q706 6 NC JL 2Y TSP-RCS-R802 DESCRIPTION: RHR TO RCIC RPV HEAD SPRAY (OTBD CIV)

IST Program Plan Columbia Generating Station Page 109 of 185 3rd 10-Year Interval Revision 1 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)

RHR-V-24A M521-1 2 MO O/C G 2Y OSP-RHR/IST-Q702 TV01 E9 B GB FAI HJ Q OSP-RHR/IST-Q702 N16 1 18 NC DESCRIPTION: RHR LOOP A TEST LINE TO SUPP POOL (OTBD CIV)

RHR-V-24B [M521-2[ 2 MO I O/C IG 2Y OSP-RHR/IST-Q703 TV01 C11 B GB FAI HJ Q OSP-RHR/IST-Q703 N16 1 1 18 NC DESCRIPTION: RHR LOOP B TEST LINE TO SUPP POOL (OTBD CIV)

RHR-V-27A fM521-1 2 MO I O/C IG 2Y OSP-RHR/IST-Q702 TV01,2 D7 A GT FAI HJ Q OSP-RHR/IST-Q702 I 1 1 6 NC L J TSP-RHR/X25A-C801 DESCRIPTION: RHR TO SUPPRESSION CHAMBER SPRAY HEADER (OTBD CIV)

RHR-V-27B M521-2 2 MO O/C G 2Y OSP-RHR/IST-Q703 TV01,2 C10 A GT FAI HJ Q OSP-RHR/IST-Q703 16 NC L J TSP-RHR/X25B-C801 DESCRIPTION: RHR TO SUPPRESSION CHAMBER SPRAY HEADER (OTBD CIV)

RHR-V-31A M521-1 2 SA O/C 1H Q OSP-RHR/IST-Q702 C14 C CK NA 18 NC DESCRIPTION: RHR-P-2A DISCH CHK RHR-V-31B M521-2 2 SA O/C H Q OSP-RHR/IST-Q703 C3 C CK NA 18 NC DESCRIPTION: RHR-P-2B DISCH CHK RHR-V-31C M521-3 2 SA O/C H Q OSP-RHR/IST-Q704 C3 C CK NA 18 NC DESCRIPTION: RHR-P-2C DISCH CHK RHR-V-40 M521-2 2 MO C G 2Y OSP-RHR/IST-Q703 TV01 G4 B GB FAI HJ Q OSP-RHR/IST-Q703 4 NC DESCRIPTION: RHR LOOP B TO EDR (SDC WARMUP LINE) ISO RHR-V-41A 1M521-1 1 1 SA O/C H RF OSP-RHR/IST-R701 ROJ08 TV02 G5 A CK NA HL RF TSP-RCS-R801 14 NCI DESCRIPTION: RHR A LPCI TO RPV CHK (INBD CIV)

RHR-V-41B M521-2I 1 SA O/C H RF OSP-RHR/IST-R702 ROJo8 TV02 G13 AC CK NA HL RF TSP-RCS-R802 14 NC DESCRIPTION: RHR B LPCI TO RPV (INBD CIV)

RHR-V-41C M521-3 1 SA O/C H RF OSP-RHR/IST-R703 ROJO8 TV02 E13 AC CK NA HL RF TSP-RCS-R802 14 NC DESCRIPTION: RHR C LPCI TO RPV (INBD CIV)

RHR-V-42A M521-1 [ 1 MO O/C G 2Y OSP-RHR/IST-Q705 CSJ06 V01,2 G7 A GT FAI HJ CS OSP-RHR/IST-Q705 14 NRC L 2Y TSP-RCS-R801 DESCRIPTION: RHR A LPCI MODE TO RPV (OTBD CIV)

RHR-V-42B IM521-2 1 M O/C G 2Y OSP-RHR/IST-Q706 CSJ06 TV01,2 1 MA GT =FA I HJ CS OSP-RHR/IST-Q706 14 NC L 2Y TSP-RCS-R802 DSRIPTIN RHR B LPCI MODE TO RPV (OTBD CIV)

IST Program Plan Columbia Station Page 110 of 185 3rd 10-Year Interval Generating Revision 1 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)

RHR-V-42C M521-3 1 MO O/C G 2Y OSP-RHR/IST-Q707 CSJ06 TV01,2 El1 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 M521-1 2 MO O/C G 2Y OSP-RHR/IST-Q702 TV01 J11 B GB FAI HJ Q OSP-RHR/IST-Q702 118 NO DESCRIPTION: RHR-HX-1A BYPASS RHR-V-48B M521-2 2 MO 1 /C G 2Y OSP-RHR/IST-Q703 TV01 K8 B GB FAI HJ Q OSP-RHR/IST-Q703 1 18 NO DESCRIPTION: RHR-HX-1B BYPASS RHR-V-49 M521-2G4 2B MOT CAIHJ G 2Y Q OSP-RHR/IST-Q703 OSP-RHR/IST-Q703 TV01 I I GT FAd DESCRIPTION: RHR LOOP B TO EDR (SDC WARMUP LINE) ISO RHR-V-50A M521-1 1 1 1 SA I O/C H RF OSP-RHR/IST-R701 IROJ08 ITV02 E5 AC CK NA HL RF TSP-RCS-R801 12 NC DESCRIPTION: RHR A SDC TO RPV CHK (INBD CIV)

RHR-V-50B M521-2 1 SA 0/C H RF OSP-RHR/IST-R702 IROJ08 ITV02 F13 AC CK NA HL RF TSP-RCS-R802 112 NC DESCRIPTION: RHR B SDC TO RPV (INBD CIV)

RHR-V-53A M521O 0/C G 2Y OSP-RHR/IST-Q705 CSJ01 TV01,2 A___GT_ FAI [HJ CS OSP-RHR/IST-Q705 112 NC L 2Y TSP-RCS-R801 DESCRIPTION: RHR A SDC MODE TO RPV (OTBD CIV) 1 RHR-V-53B M521-2 1 MO O/C [G 2Y OSP-RHR/IST-Q706 CSJ01 TV01,2 Eli A GT FAI HJ CS OSP-RHR/IST-Q706 1 112 NC L 2Y TSP-RCS-R802 DESCRIPTION: RHR B SDC MODE TO RPV (OTBD CIV)

RHR-V-68A M524-1 1 3 MO [ 0 ýG 2Y OSP-SW/IST-Q701 TV01 E14 B GT FAI HJ Q OSP-SW/IST-Q701 16 NO DESCRIPTION: SW FROM RHR-HX-IA ISO RHR-V-68B M524-21 3 MO O G 2Y OSP-SW/IST-Q702 TV01 G14 B GT FA I HJ Q OSP-SW/IST-Q702 116 NO DESCRIPTION: SW B FROM RHR-HX-IB ISO RHR-V-73A M521-1 1 2 MO J C G 2Y OSP-RHR/IST-Q702 TVo1 H14 B GB FAI HJ Q OSP-RHR/IST-0702 N16 12 NC DESCRIPTION: RHR-HX-1A SHELL SIDE VENT (OTBD CIV)

RHR-V-73B M521-2 2 MO C G 2Y OSP-RHR/IST-Q703 TV01 H4 B GB FAI HJ Q OSP-RHR/IST-Q703 N16 2 NC DESCRIPTION: RHR-HX-IB SHELL SIDE VENT (OTBD CIV)

RHR-V-84A M521-1 2 SA C Hx 0 OSP-RHR/IST-Q702 N01 D15 C CK NA Hx 12M OSP-RHR-A701 CMP-22 1.50 NC DESCRIPTION: LPCS-P-2 (WATER LEG) TO RHR A CHK RHR-V-84B M521-2 2 SA C Hx Q OSP-RHR/IST-Q703 N01 B4 C CK NA Hx 12M OSP-RHR-A702 CMP-22 1.50 NC DESCRIPTION: RHR-P-3 (WATER LEG) DISCH TO RHR B CHK

IST Program Plan Columbia Station Page 111 of 185 3rd 10-Year Interval CoubaGenerating SainRevision 1J Vnlhw Tg=*t T2Nhl 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)

RHR-V-84C M521-3 2 SA C Hx Q OSP-RHR/IST-Q704 N01 C5 C CK NA Hx 12M OSP-RHR-A704 CMP-22 1_1_1.50 NC I I _I DESCRIPTION: RHR-P-3 (WATER LEG) DISCH TO RHR C CHK RHR-V-85A [M521-1 2 SA C Hx Q OSP-RHRIIST-Q702 Nol D14 C SC NA Hx 12M OSP-RHR-A701 CMP-22 1.50 NC DESCRIPTION: LPCS-P-2 (WATER LEG) TO RHR A STOP CHK RHR-V-85B MP2 CMP-22 fM521-2

[B3 2

C SA S

1.50 J JHxC NA NC IHx Q 12M OSP-RHRIIST-Q703 OSP-RHR-A702 J N01 DESCRIPTION: RHR-P-3 (WATER LEG) DISCH TO RHR B STOP CHK RHR-V-85C M521-3 C4 2

C SA SC

[C NA Hx Hx 12M OSP-RHR/IST-704N OSP-RHR-A704 CMP-22 1.50 NC I I DESCRIPTION: RHR-P-3 (WATER LEG) DISCH TO RHR C STOP CHK RHR-V-123A M521-1 1 MO C iG 2Y OSP-RHR/IST-R704 ROJ11 TV01,2 E5 A GT FAI HJ RF OSP-RHR/IST-R704

_D R1 NC L 2Y TSP-RCS-R801 DESCRIPTION: RHR-V-50A BYPASS (INBD CIV) (MOTOR DEENERGIZED)

RHR-V-123B M521-2 1 MO C G 2Y OSP-RHR/IST-R704 ROJ11 01,2 E13 A GT FAI HJ RF OSP-RHR/IST-R704 1 NC L 2Y TSP-RCS-R802 DESCRIPTION: RHR-V-50B BYPASS (INBD CIV) (MOTOR DEENERGIZED)

RHR-V-209 RH--0 M521-1 0

D5 1AC I __ __

1 SA CK 0.75 jNCI_

O/C NA H

HL 2Y RF OSP-RHR/IST-R701 TSP-RCS-R802 R03

__I_

rROJ03 NO4 TV02 DESCRIPTION: THERMAL RELIEF CHK BETWEEN RHR-V-8 AND 9 (CIV)

RHR-V-503 M521-1 2 SA C Hx 4Y OSP-RHR/IST-Q702 A8 C CK NA Di 10Y CMP-10 0.50 NC RHR-V-731 M521-1 Hil

_____j B

1 IGB DESCRIPTION: RHR-V-6A LEAK BY-PASS CHK 0MA 0.75 C

NA NC H

DESCRIPTION: RHR A SAMPLE PROBE 22A ISO 2Y OSP-RHR/IST-Q702 RHR-V-732 M521-1 1 MA C H 2Y OSP-RHR/IST-Q703 H8 B GB NA 0.75 NC DESCRIPTION: RHR B SAMPLE PROBE 22B ISO

IST Program Plan Columbia Station Page 112 of 185 3rd 10-Year Interval Generating Revision 1 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)

ROA-V-1 M545-3 3 AO C G 2Y OSP-CONT/IST-Q702 TV01 D1 B BF FC HJK Q OSP-CONT/IST-Q702 1_ _ 1_ 84 NO I I _I DESCRIPTION: REACTOR BUILDING ISO ROA-V-2 M545-3 3 AO C G 2Y OSP-CONT/IST-Q702 TV01 D2 B BF FC HJK Q OSP-CONT/IST-Q702 84 NO DESCRIPTION: REACTOR BUILDING ISO RRC-V-13A M530-1 2 SA C Hx 4Y OSP-RRC/IST-R701 ROJ14 TV02 C13 AC CK NA HxL J TSP-RRC/X43A-C801 CMP-15 0.75 NO Nit 8Y DESCRIPTION: RRC PUMP SEAL PURGE INLET CHK (INBD CIV)

RRC-V-13B IM530-1 2 SA C Hx 4Y OSP-RRC/IST-R701 ROJ14 TV02 B13 AC CK NA HxL J TSP-RRC/X43B-C801 CMP-15 10.75 NO Nit 8YI DESCRIPTION: RRC PUMP SEAL PURGE INLET CHK (INBD CIV)

RRC-V-16A M530-1 2 MO C G 2Y OSP-RRC/IST-R701 ROJ14 TV01,2 C14 A GT FAI HJ RF OSP-RRC/IST-R701 0.75 NO L J TSP-RRC/X43A-C801 DESCRIPTION: RRC PUMP SEAL PURGE INLET (OTBD CIV)

RRC-V-16B M530-1 2 MO C G 2Y OSP-RRC/IST-R701 ROJ14 TV01,2 B14 AA GT FAI HJ RF OSP-RRC/IST-R701 0.75 NO L J TSP-RRC/X43B-C801 DESCRIPTION: RRC PUMP SEAL PURGE INLET (OTBD CIV)

RRC-V-19 M530-1 1 So C G 2Y OSP-RRC/IST-Q701 TV01,2 F11 A GB FC HJK Q OSP-RRC/IST-Q701 1 1 NO L J TSP-RRC/X77Aa-C801 DESCRIPTION: RRC SAMPLE PROBE 1 ISO (CIV)

RRC-V-20 M530-1 F12 1_A SO GB C

FC G

HJK Q 2Y OSP-RRC/IST-Q701 OSP-RRC/IST-Q701 TV01,2 D I1 N RRC SAMPLENOPROBEL TSP-RRC/X77Aa-C801 DESCRIPTION: 1 ISO (CIV)

IST Program Plan Page 113 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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)

RWCU-V-1 M523-1 1 MO C G 2Y OSP-RWCU/IST-0701 CSJ07 TV01,2 F14 A GT FAI HJ CS OSP-RWCU/IST-Q701 6 NO L J TSP-CONT-R801 DESCRIPTION: RWCU FROM RPV ISO (INBD CIV)

RWCU-V-4 M523-1 1 MO C G 2Y OSP-RWCU/IST-Q701 CSJ0 7 TV01,2 E15 A GT FAI HJ CS OSP-RWCU/IST-Q701 6 NO L J TSP-CONT-R801 DESCRIPTION: RWCU FROM RPV ISO (OTBD CIV)

RWCU-V-40 M523-1 I MO. C G 2Y OSP-RWCU/IST-Q701 TCSJ 0 7 TV01,2 HiM0 ACGT FA HJ CS OSP-RWCU/IST-Q701 6 NO L 2Y TS P- RFW/X 17A- R802 DESCRIPTION: RWCU TO RFW ISO (OTBD CIV)

SA-V-109 M510-3 2 MA C IL J TSP-SA/X93-C801 TV02 H8 A GB NA Passive 1 2 LCI DESCRIPTION: AIR LINE ISO USED FOR MAINT (CAPPED IN DW) (CIV)

SGT-V-1A M544 1 2 MO C G 2Y OSP-SGT/IST-Q701 1TV01 G14 B BF FAI HJ Q OSP-SGT/IST-0701 18 NC DESCRIPTION: SGT INLET SGT-V-1 B M544 2 MO C G 2Y OSP-SGT/IST-Q702 TV01 E14 B BF FAI HJ Q OSP-SGT/IST-Q702 118 NC DESCRIPTION: SGT INLET SGT-V-2A M544 1 3 AO 0 G 2Y OSP-SGT/IST-Q701 TV01 H14 B BF FO HJK Q OSP-SGT/IST-Q701 118 NO DESCRIPTION: SGT-FU-1A INLET SGT-V-2B M544 3 AO 1 0 G 2Y OSP-SGT/IST-Q702 TV01 D14 B BF FO 1HJK Q OSP-SGT/IST-Q702 18 NO DESCRIPTION: SGT-FU-1B INLET SGT-V-3A1 M544 2 [ MO 0 JG 2Y OSP-SGT/IST-Q701 ITV01 G7 B BF FAI HJ Q OSP-SGT/IST-Q701 118 NO DESCRIPTION: SGT-FN-1A1 DISCH SGT-V-3A2 M544 2 MO O/C G 2Y OSP-SGT/IST-0701 TV01 J7 B BF FAI HJ Q OSP-SGT/IST-Q701

_ 18 NO DESCRIPTION: SGT-FN-1A1 DISCH

IST 10-Year 3rd ProgramInterval Plan Columbia Generating Station Page Revision 114 of 1851 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)

SGT-V-3B1 M544 2 MO O/C G 2Y OSP-SGT/IST-0702 TV01 E7 B BF FAI HJ Q OSP-SGT/IST-Q702 I_ _ 1_ 18 NO I I I DESCRIPTION: SGT-FN-1A1 DISCH SGT-V-3B2 M544 2 MO 0 G 2Y OSP-SGT/IST-Q702 TV01 C7 B BF FAI HJ Q OSP-SGT/IST-Q702 118 NO DESCRIPTION: SGT-FN-1A1 DISCH SGT-V-4A1 M544 2 MO O/C IG 2Y OSP-SGT/IST-0701 TV01 J5 B BF FAI HJ Q OSP-SGT/IST-Q701 18 NC DESCRIPTION: SGT-FN-1A1 DISCH SGT-V-4A2 M544 2 MO O/C G 2Y OSP-SGT/IST-Q701 TV01 G5 B BF FAI HJ Q OSP-SGT/IST-Q701 18 NC DESCRIPTION: SGT-FN-1A2 DISCH SGT-V-4B1 M544 2 O/C G 2Y OSP-SGT/IST-Q702 TV01 C5 B MBOF FAI HJ Q OSP-SGT/IST-Q702 118 NC DESCRIPTION: SGT-FN-1B1 DISCH SGT-V-4B2 M544 2 MO O/C G 2Y OSP-SGT/IST-Q702 TV01 D5 B BF FAI HJ Q OSP-SGT/IST-Q702 18 NC DESCRIPTION: SGT-FN-1B2 DISCH SGT-V-5A1 M544 2 MO O/C fG 2Y OSP-SGT/IST-Q701 TV01 J5 B BF FAI HJ Q OSP-SGT/IST-Q701 118 NC DESCRIPTION: SGT-FN-1A1 OUTLET SGT-V-5A2 M544 2 MO O/C G 2Y OSP-SGT/IST-Q701 TV01 G5 B BF FAI HJ Q OSP-SGT/IST-Q701 18 NC DESCRIPTION: SGT-FN-1A2 OUTLET SGT-V-5B1 M544 2 MO O/C G 2Y OSP-SGT/IST-Q702 TV01 C5 B FAI HJ Q OSP-SGT/IST-Q702 18 NC DESCRIPTION: SGT-FN-1B1 OUTLET SGT-V-5B2 M544 2 MO O/C G 2Y OSP-SGT/IST-Q702 TV01 E5 B BF FAI HJ Q OSP-SGT/IST-Q702 18 NC DESCRIPTION: SGT-FN-1B2 OUTLET SLC-RV-29A M522 2 SA NA P RV TSP-RV/IST-R701 TV03 F6 C RV NA 1 X2 NC DESCRIPTION: SLC-P-1A DISCH RV

IST Program Plan Columbia Generating Station Page 115 of 185 3rd 10-Year Interval Revision 1 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)

SLC-RV-29B M522 2 SA NA P RV TSP-RV/IST-R701 TV03 D6 C RV NA 1 X2 NC DESCRIPTION: SLC-P-1B DISCH RV SLC-V-1A M522 2 MO 0 IG 2Y OSP-SLC/IST-Q701 TV01 E4 B GB FAI HJ Q OSP-SLC/IST-Q701 4 NC DESCRIPTION: SLC-TK-1A (STORAGE TANK) TO SLC-P-1A SUCT ISO SLC-V-1B M522 2 [ MO 0 ýG 2Y OSP-SLC/IST-Q701 TV01 D4 B GB FAI HJ Q OSP-SLC/IST-Q701 4 NC DESCRIPTION: SLC-TK-1B (STORAGE TANK) TO SLC-P-1B SUCT ISO SLC-V-4A M522 1 SO O/C L J TSP-SLC/X13-R801 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 M522 111 SO O/C IL J TSP-SLC/X13-R801 TV02 D8 AD EX NA V EX OSP-SLC-B702 1.50 NC L SLC-V-6 M522 F11 C 11 C SA CK O/C NA IHx DESCRIPTION: SLC-P-1 B DISCH TO RPV ISO (EXPLOSIVE OTBD CIV)

Nit RF 4Y OSP-SLC-B701, B702 ROJ01 CMP-25 1.50 NC DESCRIPTION: SLC TO RPV CHK SLC-V-7 M522 1 SA O/C Hx RF OSP-SLC-B701, 8702 ROJ01 TV02 H13 AC CK NA HxL J TSP-SLC/X13-R801 CMP-25 [ 1.50 NC Nit 4Y DESCRIPTION: SLC TO RPV CHK (INBD CIV)

SLC-V-33A M522 2 C

SA CK

[/C NA

/7 Hx Nit Q

4Y OSP-SLC/IST-Q701 OSP-SLC/IST-Q701 CMP-16 _ 1.50 NC DESCRIPTION: SLC-P-1A DISCH CHK SLC-V-33B M522 2 SA O/C 1Hx 0 OSP-SLC/IST-Q701 D7 C CK NA Nit 4Y OSP-SLC/IST-Q701 CMP-16 1.50 NC DESCRIPTION: SLC-P-1 B DISCH CHK SW-RV-001A M524-1 3 SA NA P RV TSP-RV/IST-R701 TV03 D14 C RV NA 1 .75 X 1 NC SW-RV-001B M524-2 [3 DESCRIPTION: RHR-HX-1A TUBE SIDE RV SA 1 NA P RV TSP-RV/IST-R701 TV03 F14 C RV NA

.75 X1 NC DESCRIPTION: RHR-HX-1 B TUBE SIDE RV SW-TCV-11A IM775 3 HO O HK Q ESP-SW/IST-Q701 RV02 G5 B GB FO 2.50 NT DESCRIPTION: EMERGENCY CHILLED WATER FROM WMA-CC-51A-1 TCV SW-TCV-1 1B M775 3 HO 0 HK Q ESP-SW/IST-Q702 RV02 C5 B GB FO 2.50 NT DESCRIPTION: EMERGENCY CHILLED WATER FROM WMA-CC-51 B-1 TCV

IST Program Plan Page 116 of 185 3rd 10-Year Interval Columbia Generating Station Revision 1 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)

SW-V-1A M524-1 3 SA 0 Hx Q OSP-SW/IST-Q701 H5 C CK NA Nit 4Y CMP-24 1 1 20 NC Di 10Y DESCRIPTION: SW-P-1A DISCH CHK SW-V-1B M524-2 3 SA 0 Hx Q OSP-SW/IST-Q702 F5 C CK NA Nit 4Y CMP-24 20 NC Di 10OY DESCRIPTION: SW-P-1B DISCH CHK SW-V-2A M524-1 3 MO O/C G 2Y OSP-SW/IST-Q701 TV01 H6 B BF FAI HJ Q OSP-SW/IST-Q701 20 NC DESCRIPTION: SW-P-1A 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 NC DESCRIPTION: SW-P-1B DISCH ISO SW-V-12A M524-1 3 MO I O/C G 2Y OSP-SW/IST-Q701 TV01 G3 B GT FAI HJ Q OSP-SW/IST-Q701 18 NC DESCRIPTION: SW A RETURN TO SPRAY POND B ISO SW-V-12B M524-2 3 MO O/C G 2Y OSP-SW/IST-Q702 TV01 G3 B GT FAI HJ Q OSP-SW/IST-Q702 18 NC DESCRIPTION: SW B RETURN TO SPRAY POND A ISO SW-V-29 M524-1 3 MO O/C G 2Y OSP-SW/IST-Q703 TV01 G6 B BF FAI HJ Q OSP-SW/IST-Q703 8 NC DESCRIPTION: HPCS-P-2 DISCH ISO SW-V-34 M524-2 3 so O G 2Y OSP-SW/IST-Q702 TV01 C11 B GB FO HJK Q OSP-SW/IST-Q702 1.50 NO DESCRIPTION: SW FROM RCIC-P-1 ROOM RRA-CC-6 ISO SW-V-69A M524-1 3 MA O/C H 2Y OSP-SW/IST-Q701 G3 B GT NA 18 LC DESCRIPTION: SW TO COOLING TOWER CROSSTIE ISO (OPERATED VIA MOV HANDWHEEL)

SW-V-69B M524-2 3 MA O/C H 2Y OSP-SW/IST-Q702 F2 B GT NA 18 LCI SW-V-70A M52 4 -1 G2 J

DESCRIPTION: SW TO COOLING TOWER CROSSTIE ISO (OPERATED VIA MOV HANDWHEEL) 3 B

MA GT 18 O/C NA LCI H 2Y OSP-SW/IST-Q701 DESCRIPTION: SW TO COOLING TOWER CROSSTIE ISO (OPERATED VIA MOV HANDWHEEL)

SW-V-70B M5 24 -2 3 MA O/C H 2Y OSP-SW/IST-Q702 F2 B GT NA 11 18 LCII DESCRIPTION: SW TO COOLING TOWER CROSSTIE ISO (OPERATED VIA MOV HANDWHEEL)

SW-V-75A M524-1 3 MO O/C G 2Y OSP-FPC/IST-Q701 TV01 B12 B GB FAI HJ 0 OSP-FPC/IST-Q701 2 NC DESCRIPTION: SW TIE TO FPC LOOP A

IST Program Plan Columbia Station Page 117 of 185 3rd 10-Year Interval Generating Revision 1 V2lv* Tact T~hlI 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)

SW-V-75AA M524-1 3 MA O/C H 2Y OSP-FPC/IST-Q701 B13 B GB NA 2 NC DESCRIPTION: SW CROSSTIE TO FPC MAN ISO SW-V-75B M524-2 3 MO O/C G 2Y OSP-FPC/IST-Q701 TV01 A14 B GB FAI HJ Q OSP-FPC/IST-Q701 2 NC DESCRIPTION: SW TIE TO FPC LOOP B SW-V-75BB M524-2 3 MA O/C H 2Y OSP-FPC/IST-Q701 B14 B GB NA

_ 2 NC DESCRIPTION: SW CROSSTIE TO FPC MAN ISO SW-V-165A M524-1 3 MA O/C H 2Y OSP-SW/IST-Q701 E3 B BF NA 18 NO DESCRIPTION: SW A RETURN TO SPRAY POND B SPRAY RING HDR BYPASS SW-V-165B M524-2 3 MA O/C H 2Y OSP-SW/IST-Q702 K3 B BF NA 18 NO 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/IST-Q701 E3 B BF NA 18 NC DESCRIPTION: SW A RETURN TO SPRAY POND B SPRAY RING HDR MAN ISO SW-V-1 70B M524-2 3 MA O/C H 2Y OSP-SW/IST-Q702 K3 B BF NA 18 NC DESCRIPTION: SW B RETURN TO SPRAY POND A SPRAY RING HDR MAN ISO SW-V-187A M524-1 3 MO 0 G 2Y OSP-FPC/IST-Q701 TVo1 H14 B GT FAI HJ Q OSP-FPC/IST-Q701 6 NC DESCRIPTION: SW TO FPC-HX-1A INLET SW-V-187B M524-2 3 MO 0 G 2Y OSP-FPC/IST-Q701 TV01 C13 B GT FAI HJ Q OSP-FPC/IST-Q701 6 NC DESCRIPTION: SW TO FPC-HX-1B INLET SW-V-188A M524-1 1 3 MO 0 G 2Y OSP-FPC/IST-0701 Vol J13 B GT FAI HJ 0 OSP-FPC/IST-Q701 6 1NC DESCRIPTION: SW FROM FPC-HX-IA OUTLET SW-V-188B M524-2 3 MO 0 G 2Y OSP-FPC/IST-Q701 TV01 D12 B GT FAI HJ Q OSP-FPC/IST-Q701 6 NC DESCRIPTION: SW FROM FPC-HX-1 B OUTLET SW-V-226A M775 F7 C

_3 1 SA CCK C

NA H Q OSP-CCH/IST-M701 3 NC DESCIPTION: CCH-EV-IA (EVAPORATOR) OUTLET CHK

[IST 3rd 10-Year ProgramInterval Plan Columbia Valve Test Tables Station Revision Page 118 of 1851 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)

SW-V-226B M775 3 SA C H Q OSP-CCH/IST-M702 B6 C CK NA S3 NC DESCRIPTION: CCH-EV-1 B (EVAPORATOR) OUTLET CHK SW-V-227A M775 3 MA C H 2Y OSP-CCH/IST-M701 H7 B GT NA 3 NC DESCRIPTION: CCH-P-1A SUCT MAN ISO SW-V-227B M775 3 MA C H 2Y OSP-CCH/IST-M702 C7 B GT NA 3 NO DESCRIPTION: CCH-P-1B SUCT MAN ISO SW-V-822A M775 3 MA 0 H 2Y OSP-CCH/IST-M701 J5 B GT NA 3 NO DESCRIPTION: SW TO WMA-CC-51A-1 (CR CHILLER) MAN ISO SW-V-822B M775 3 MA 0 H 2Y OSP-CCH/IST-M702 E5 B GT NA 3 NC DESCRIPTION: SW TO WMA-CC-51 B-1 (CR CHILLER) MAN ISO SW-V-823A M775 3 MA 0 H 2Y OSP-CCH/IST-M701 J5 B GT NA 3 NO DESCRIPTION: SW FROM WMA-CC-51A-1 (CONTROL RM CHILLER) MAN ISO SW-V-823B M775 3 MA 0 H 2Y OSP-CCH/IST-M702 E5 B GT NA 3 NC DESCRIPTION: SW FROM WMA-CC-51 B-1 (CONTROL RM CHILLER) MAN ISO TIP-V-1 M604 2 so C G 2Y OSP-CONT/IST-Q703 TV01,2 G13 A BA FC G 2Y TSP-TIP/X27-R801 0.375 NC HJK Q OSP-CONT/IST-R703 L J TSP-TIP/X27-R801 DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (1ST OTBD CIV)

TIP-V-2 M604 2 so C G 2Y OSP-CONT/IST-Q703 TV01,2 G13 A BA FC G 2Y TSP-TIP/X27-R801 0.375 NC HJK Q OSP-CONT/IST-Q703 L J TSP-TIP/X27-R801 DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (1ST OTBD CIV)

TIP-V-3 M604 2 so C G 2Y OSP-CONT/IST-Q703 TV01,2 G12 A BA FC G 2Y TSP-TIP/X27-R801 0.375 NC HJK Q OSP-CONT/IST-Q703 JL TSP-TIP/X27-R801 DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (1ST OTBD CIV)

IST Program Plan Columbia Station Page 119 of 185 3rd 10-Year Interval Generating Revision 1 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)

TIP-V-4 M604 2 SO C G 2Y OSP-CONT/IST-Q703 TV01,2 H12 A BA FC G 2Y TSP-TIP/X27-R801 0.375 NC HJK Q OSP-CONT/IST-Q703 I I I I IL J TSP-TIP/X27-R801 DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (1ST OTBD CIV)

TIP-V-5 M604 2 so C G 2Y OSP-CONT/IST-Q703 TV01,2 H12 A BA FC G 2Y TSP-TIP/X27-R801 0.375 NC HJK Q OSP-CONT/IST-Q703 L J TSP-TIP/X27-R801 DESCRIPTION: TIP LINE BALL-TYPE ISO VLV (1ST OTBD CIV)

TIP-V-6 M604 2 SA C Hx 4Y OSP-TIP/IST-R701 ROJO4 TV02 F12 AC CK NA HxL J TSP-TIP/X27F-R801 CMP-26 0.375 NO Di 10Y DESCRIPTION: TIP PURGE LINE CHK (INBD CIV)

TIP-V-15 M604 2 so C G 2Y OSP-CONT/IST-Q703 TV01,2 G13 A SV FC G 2Y TSP-TIP/X27F-R801 1 NO HJK Q OSP-CONT/IST-Q703 L J TSP-TIP/X27F-R801 DESCRIPTION: TIP PURGE LINE CHK (OTBD CIV)

IST Program Plan Columbia Station Page 120 of 185 3rd 10-Year Interval Generating Revision 1 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 RHR-V-84C, 85C

IST Program Plan Columbia Station Page 121 of 185 3rd 10-Year Interval Generating Revision 1 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-IAB, CD, EF, GH, JK, LM, NP, QR, ST 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-i A through 15A CIA-SPV-I B 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-1 57A and FPC-V-1 57B RCIC-V-111 and RCIC-V-112 RHR-V-209

1ST Program Plan (I k Ge raigPage 122 of 185 3rd 10-Year Interval Station Revision 1 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-1 14 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-1 38 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-5B1/2 DSA-SPV-5B1/4 DSA-SPV-5B2/2 DSA-SPV-5B2/4 DSA-SPV-5C1/1 DSA-SPV-5C1/2

IST Program Plan Columbia Station Page 123 of 185 3rd 10-Year Interval Generating Revision 1 NOTE N07 Affected Valves Class Cat. Function System(s)

RCIC-V-4 2 B RCIC-P-4 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

__CIC-V-2____

2 2

B B

RCIC Turbine Steam Supply Steam Traps to Main Condenser Isolation Reactor Core Isolation Cooling RCIC-V-26 2 B RCIC Turbine Steam Supply Steam Reactor Core Isolation Cooling Traps to Main Condenser Isolation 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-1 200, 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 Class Cat. Function System(s)

RCIC-V-2 2 B RCIC Turbine Governor Valve Reactor Core Isolation Coolinq 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 Columbia Generating Station Page 124 of 185 3rd 10-Year Interval Revision 1 NOTE N11 The following solenoid operated H202 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 IST( 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-VX-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, G12-01-017, 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 permanently isolated and deactivated per PDC 4533 and PD0 3539.

NOTE N14 MSLC system has been deactivated per EC 97-0045-1 C. The breakers have been opened and the control fuses removed. The containment isolation valves (3A thru 3D) have been chained and locked closed. Their safety function has been changed to passive to maintain primary containment integrity.

Excess flow check valves, PI-EFC-X18A through PI-EFC-X18D has been deactivated per EC 97-0045-3E.

NOTE N15 Affected Valves Class Cat. Function System(s)

DO-V-1A 3 C DO-P-1A Discharge Check Diesel Fuel Oil Transfer DO-V-1 B 3 C DO-P-1 B Discharge Check Diesel Fuel Oil Transfer DO-V-10 3 C DO-P-2 Discharge Check Diesel Fuel Oil Transfer These valves are classified as skid mounted valves per ASME OM Code 2001 Edition through 2003 addenda, Section ISTA-2000. They are adequately tested as a part of the diesel generator system and are exempt from the testing requirements of subsection ISTC per ISTC-1 200(c). See Technical Position TP03 for additional information.

NOTE N16 Primary Containment Valve no longer requires leak rate testing per Appendix J program since it is not an airborne pathway and is in closed system outside of the Primary Containment. See LDCN LCS-08-027 and LDCN FSAR-08-028 for additional information.

IST Program Plan Columbia Station Page 125 of 185 3rd 10-Year Interval Generating Revision 1 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-91 00.

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 I, Paragraph 1-5000 requirements.

The Valve Inservice Test Program, associated surveillance test procedures and results, and corrective actions are retained per Plant Administrative Procedures.

IST ProgramInterval 3rd 10-Year Plan Columbia Generating Station Page 126 of 1851 Revision SAMPLE VALVE STROKE DATA SHEET

1. OPENING TIME IN SECONDS # CLOSING TIME IN SECONDS Ref. Alert Lo Alert Hi Action Hi Ref. Alert Lo Alert Hi Action Hi VALVE EPN Value (+1)(+2) Measured Value (+1)(+2) (+1)(+2) Value (+1)(+2) Measured Value (+1)(+2) (+1)(+2)

RHR-V-4A 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-V-48A t 86 73 99 112 85 72 98 111 17 17 RHR-FCV-64A t 13 11 15 (5) 13 11 15 (+5) 29 25 33 38 29 25 33 36 RHR-V-27A "

Not RHR-V-84A/85A N/A N/A N/A N/A N/A N/A N/A Closed I_ 1 1 (+4)

Not Not RHR-V-31A N/A N/A N/A op N/A N/A N/A Cos Open Closed 99 112

(+

RHR-V-24A t 88 75 101 114 86 73

(+6)

RHR-V-60A N/A N/A N/A 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 RHR-V-73A t 10 N/A N/A N/A 10 8 13 15

___________ (+7)

Not Cos RHR-V-503 N/A N/A N/A N/A N/A N/A N/A N/A Closed

1. (+1) 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.

1. (+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 02E1 2-03,6

(+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

IST Program Plan Page 127 3rd 10-Year Interval Columbia Generating Station Rev SAMPLE TWO YEAR VALVE POSITION INDICATION (VPI) VERIFICATION AND CHANNEL CALIBRATION DATA SHEET

1. Verified Open # Verified Closed Remote Remote Valve Local Indication Indication Indication Local Indication Condition Valve Inspected Initial As Found Sat Unsat Sat Unsat Initial As Found Operation 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 #(+1)

RHR-V-24A #(+1)

RHR-V-73A #(+1)

(+1) These valves require channel calibration in addition to two year VPI. VPI verification satisfies both requirements.

IST Program Plan Columbia Station Page 128 of 185 3rd 10-Year Interval Generating Revision 1 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 Tret 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 Columbia Generating Station Page 129 of 185 3rd 10-Year Interval Revision 1 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) and ISTC-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.

IST Program Plan Columbia Station Page 130 of 185 3rd 10-Year Interval Generating Revision 1 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.

IST Program Plan Columbia Station Page 131 of 185 3rd 10-Year Interval Generating Revision 1 Technical Position - TV03 Title Inservice Performance Testing of Pressure Relief Devices Issue Discussion Subsection ISTC-5240 requires testing of safety and relief devices in accordance with Mandatory Appendix I. The devices subject to this testing and/or replacements are those included in the Valve Test Tables.

Position The following clarifications will be used when implementing testing requirements for safety and relief devices.

Acceptance criteria (1-1300(e)) is specified on Relief Valve Set Point Data Sheets for each specific valve.

Replacement valves (1-2000): Valves meeting the required testing acceptance criteria of Mandatory Appendix I may be used as replacements.

Thermal relief replacement valves (1-1390): New valves not previously used at Columbia Generating Station or previously used valves which have been refurbished and satisfactorily tested.

Spare Class 1 Main Steam relief valves, which have been set-pressure tested after repair and refurbishment prior to new 10 year interval implementation dates, in accordance with the Code in effect for 2nd 10-year interval, may 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 (Paragraph 1-1120(a)).

Test sequence in Paragraph 1-3310 is not applicable for refurbishment.

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. The test interval is defined from test to test date. 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 Columbia Station Page 132 of 185 3rd 10-Year Interval Generating Revision 1 Technical Position - TV03 (Contd.)

Each installed Class 2 or Class 3 pressure relief valve shall be as-found tested at least once every 10 years. The test interval for any installed valve shall not exceed 10 years. The test interval is defined from test to test date. When as-found test requirements have been satisfied for a given 48-month or 10-year test interval, additional valves removed for maintenance do not require as-found set-pressure testing prior to disassembly for maintenance.

Pressure relief devices, meeting the requirements of Mandatory Appendix I by replacement, shall be replaced in the interval specified by Appendix I without a grace period. The service period is from installation to removal from service. This clarification applies to Class 2 and Class 3 rupture discs (I-1360) and Class 2 and Class 3 thermal relief valves (I-1390).

Visual inspection prior to installation is met during the refurbishment process or by QC receipt inspection for new valves.

IST Program Plan Columbia Generating Station Page 133 of 185 3rd 10-Year Interval Revision 1 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 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 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 in accordance with Technical Specifications SR 3.6.1.1.2, SR 3.6.1.1.3, and SR 3.6.1.1.4 (Relief Request RV01). These testing requirements will also apply to replacementI 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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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 Columbia Generating Station Page 134 of 185 3rd 10-Year Interval Revision 1 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 I.

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.

IST Program Plan Columbia Station Page 135 of 185 3rd 10-Year Interval Generating Revision 1 Technical Position - TV06

Title:

Preconditioning of Structures, Systems and Components System: Various Components: Pumps and Valves within the IST Program Plan Code Class: Various Code Requirement: The ASME OM Code does not specifically require licensees to test components in the as-found condition (except for safety and relief valves). However degradation mechanisms might not be identified unless as-found testing is performed. The NRC expects inservice testing to be performed in a manner that generally represents the condition of a standby component if it were actuated in the event of an accident, i.e., no preconditioning prior to actuation.

Position: This technical position is based upon guidance contained in NUREG 1482, Rev. 1, section 3.5 "Pre-Conditioning of Pumps and Valves", NRC Inspection Manual Part 9900 Technical Guidance, "Maintenance - Preconditioning of Structures, Systems, and Components Before Determining Operability," Inservice Testing Owners Group "Position on Component Preconditioning" and industry benchmarking through the Inservice Testing Owners Group. preconditioning concerns.

Technical Specification Surveillances and/or ASME OM Code Inservice Testing (IST) shall be performed in the as found condition when possible.

Preconditioning should not be performed unless safety prudence and sound engineering practice are involved and an evaluation is performed to document the disposition of the as found condition of the component. Technical decisions that result in or involve conditions of maintenance that prevent preconditioning, such as timing/sequence of activities, should be documented on the controlling work control document (i.e., WORK ORDER or procedure).

The NRC expects surveillance and testing processes of SSCs to be evaluated in an "as-found" condition.

As Found The physical state of a component after a period of normal service without repairs or adjustments that could affect its operation. Normal service includes component operation when required by an operating procedure or non-routine operation of the component to establish required system conditions for corrective maintenance activities.

IST Program Plan Columbia Generating Station Page 136 of 185 3rd 10-Year Interval Revision 1 Technical Position - TV06 (Contd.)

Preconditioning, acceptable preconditioning and unacceptable preconditioning actions are described below. When unacceptable conditions are found, the Corrective Action Program should be used.

Preconditioning of SSCs The alteration, variation, manipulation, or adjustment of the physical condition of an SSC before Technical Specification surveillance or ASME Code testing.

Unacceptable Preconditioninq Unacceptable preconditioning is the alteration, variation, manipulation, or adjustment of the physical condition of an SSC before or during testing that alters one or more attributes of one or more SSCs, which results in acceptable test results.

Any activity performed prior to or during an inservice test which results in acceptable test results, but may have adversely affected the ability to monitor the component for degradation.

This could include activities such as cycling, cleaning, lubricating, agitating, or other specific activities performed prior to or during an inservice test that could mask component degradation.

Acceptable Preconditioning Any activity which has the potential to affect the ability to detect a degrading performance trend but for which factors are involved that would justify the preconditioning; or, an activity performed prior to IST that has no potential to mask component degradation. This could include activities such as cycling, cleaning, lubricating, agitating, or other specific activities performed prior to or during an inservice test that would not mask component degradation. A documented evaluation of the non-adverse impact upon the component's as-found condition should be performed in advance of the preconditioning activity.

The alteration, variation, manipulation, or adjustment of the physical condition of an SSC before Technical Specification surveillance or ASME Code testing for the purpose of protecting personnel or equipment or to meet the manufacturer's recommendations is acceptable.

Preconditioning for the purposes of personnel protection or equipment preservation should outweigh the benefits gained by testing only in the as-found condition. This preconditioning may be based on the equipment manufacturer's recommendations or on industry-wide operating experience to enhance equipment and personnel safety. This preconditioning should be evaluated and documented.

Quarterly (or more frequent) IST Care should be taken to ensure that procedures, surveillances, or tasks are not scheduled such that "unacceptable" preconditioning of a component prior to the IST occurs. Where unacceptable preconditioning would occur, the procedure/task should specify that an as-found test be performed. No as-found test is required prior to corrective maintenance for components which are tested quarterly as long as the test history trends indicate that the component is not vulnerable to failure prior to the performance of the work.

IST Program Plan Columbia Station Page 137 of 185 3rd 10-Year Interval Generating Revision 1 Technical Position - TV06 (Contd.)

Infrequently Performed IST (cold shutdown or refueling frequency)

Cold Shutdown and Refueling outage surveillances, to the extent practical, should be performed prior to any event which may unacceptably precondition the SSC.

Timing of Maintenance and IST Where it can be shown that an activity to be performed either has no effect on the testing results, or can detect component degradation better than the IST (e.g., certain preventive and corrective maintenance activities), or where the maintenance is so extensive that it will result in an essentially new component (i.e., one having new operating characteristics), an evaluation may be made that the timing of the IST is inconsequential. The evaluation should include considerations of whether a common mode failure may be detected by the IST.

Evaluation of Unacceptable Preconditioning It is recognized that certain events (e.g., an emergency shutdown, errors in initial test performance, discovery of required maintenance in a mode where the as-found test cannot be performed, etc.) may result in preconditioning prior to IST. This does not represent a violation of IST Technical Specification requirements since preconditioning is not a Code requirement.

When preconditioning questions or concerns arise, such events should be evaluated to determine if unacceptable preconditioning has occurred by evaluating the following questions:

o Does the practice performed ensure that the pump or valve will meet its testing acceptance criteria?

o Would the pump or valve have failed the test without the preconditioning?

o Does the practice bypass or mask the as-found condition of the pump or valve?

o Is preventive maintenance routinely performed on the pump or valve just before testing?

o Is preventive maintenance on the pump or valve performed only for scheduling convenience?

Any affirmative answers to the above questions will indicate unacceptable preconditioning has occurred and should be addressed per the corrective action program.

Examples of Acceptable Preconditioning

1. The minimal manipulation of a system to allow for control or isolation of components for surveillance testing or maintenance such as:

• Operating MOV's/AOV's for a normal system operation or test configuration

• Cycling breakers to allow removal from service

• Racking breakers in or out and installing on a test stand

• Installing jumpers or hydraulic/pneumatic connections

IST Program Plan Columbia Generating Station Page 138 of 185 3rd 10-Year Interval Revision 1 Technical Position - TV06 (Contd.)

2. Pressurizing/Depressurizing to setup for required tests and leak checking.

3. Recovery activities to regain operable status for an SSC in an LCO.

4. A preventive maintenance activity that instead of sending a component off-site for a regular calibration, replaces it with one that has already been tested and calibrated.

5. A surveillance test that follows preventive maintenance is acceptable preconditioning if the test is performed more frequent than the PM, e.g., a quarterly test that follows an annual PM.

6. A surveillance test that follows corrective maintenance or preventive maintenance is acceptable preconditioning if the component's test results would indicate that it was not vulnerable to fail prior to the work.

7. Venting a system prior to running the system for a pump capacity check provided that the venting operation has proper controls. Venting does not enhance pump capacity but does prevent transients on the system.

8. Lubricating AC MOV valve stems prior to stroke time testing has been evaluated to be insignificant with regard to detecting degradation.

9. Wetting valve seat/disc prior to stroking to meet manufacturer's recommendations and to simulate accident conditions. (e.g,. MSIVs tested with steam present)

10. Cycling breakers in consecutive sections of a procedure.

11. Manually cycling a new switch prior to installation to remove any possible "set" in the contacts or mechanism.

12. Multiple components being affected by data collection on other instruments.

13. A transmitter is removed from service, test equipment installed, and the transmitter and test equipment vented to remove air introduced during test equipment installation.

14. Instrument & Control PM's that check instrument loop control, alarm, or indication functions downstream of an isolator, prior to an upstream device calibration or tests.

Examples of Unacceptable Preconditioning 1 Scheduling or performance of consecutive tests ifone test preconditions the other.

2. The scheduling of maintenance work activities immediately prior to the performance of Tech Spec surveillances with the intent of ensuring favorable test results (i.e., activities are known to influence a test outcome).

3. Removing electrical loads prior to breaker load surveillance testing.

4. Manually cycling a breaker prior to testing when it is known that cycling results in influencing a test outcome.

5. Exercising a Motor Operated Valve (MOV) or Air Operated Valve (AOV), other than for test configurations or normal system operation, prior to a surveillance test on the valve.

IST Program Plan Columbia Station Page 139 of 185 3rd 10-Year Interval Generating Revision 1 Technical Position - TV06 (Contd.)

6. Manually seating a check valve prior to check valve seat leakage testing. (check valve seating methodology that simulates the expected design bases condition is acceptable.)

7. Performing multiple strokes of multiple valves operated from a single switch to obtain individual stroke times when a means exists to obtain the stroke times simultaneously.

8. Routine electrical grooming such as tightening connectors, burnishing contacts, etc., just before or during testing. (When done as a regular schedule PM for the purpose of maintaining the system in its optimum condition and not performed before every test, then it would be acceptable.)

9. Filling and venting an instrument prior to testing unless the instrument has just undergone maintenance that requires this action.

10. Filling floor/equipment drain loop seals just prior to testing a ventilation systems capability to maintain pressure conditions in a given space.

11. Procedures that contain instructions requiring inspection, cleaning, and lubrication of breakers before performing surveillance testing of the breaker functions.

12. Procedures or work order task instructions that contain steps requiring component manipulation or unnecessary enhancement to the as found conditions before performing surveillance testing.

References:

1. ASME OM Code for Operation and Maintenance of Nuclear Power Plants.

2. NUREG-1482, Revision 1, Guidelines for Inservice Testing at Nuclear Power Plants, Final Report, Published January 2005, Prepared by S. M. Unikewicz, NRC Project Manager, Division of Engineering, Office of Nuclear Reactor Regulation, U.S. Nuclear Regulatory Commission.

3. NRC Inspection Manual Part 9900 Technical Guidance, "Maintenance - Preconditioning of Structures, Systems, and Components Before Determining Operability."

4. USNRC Information Notice, IN 97-16, Preconditioning of Plant Structures, Systems, and Components Before ASME Code Inservice Testing or Technical Specification Surveillance Testing.

5. Inservice Testing Owners' Group Position on Preconditioning, Rev 0, dated July 11, 2006.

IST Program Plan Columbia G n a, Station Page 140 of 185 3rd 10-Year Interval Revision 1 5.7 Cold Shutdown Justifications ISTC-351 0 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, ifpracticable.

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 <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> 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 <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> 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 Station Page 141 of 185 3rd 10-Year Interval Generating Revision 1 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 1 A Loop A, B outboard isolation valve for Residual Heat Removal shutdown cooling return Justification Valves are interlocked with reactor coolant system pressure such that valves automatically close to protect the RHR pump discharge line from elevated reactor coolant system pressures. Opening circuit is disabled by the same pressure interlocks. 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 Rev 1 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 Columbia Station Page 142 of 185 3rd 10-Year Interval Generating Revision 1 Cold Shutdown Justification - CSJ02 Description It is not practicable to full or partial stroke exercise the following RFW valves during normal Plant operation.

Affected Valves Class Cat. Function System(s)

RFW-V-65A, B 1 A Reactor feedwater isolation valves Reactor 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 Frequency These valves will be full stroke exercised during cold shutdown.

IST Program Plan Columbia Generating Page 143 of 185 3rd 10-Year Interval Station Revision 1 Cold Shutdown Justification - CSJ03 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 Rev 1 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.

IST Program Plan Columbia Station Page 144 of 185 3rd 10-Year Interval Generating Revision 1 Cold Shutdown Justification - CSJ04 (INACTIVE- FOR CHECK VALVES CIA-41 A & 41 B 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)

CIA-V-39A, B 3 B These valves cross connect the normal nitrogen supply for the Main Steam Isolation Valves and Main Steam Relief Valves Containment Instrument (including the 7 ADS Valves) accumulators to Air the backup nitrogen supply for the 7 ADS CIA-V-41A, B 3 C valves.

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.

ST Program Plan olumbia Station Page 145 of 185 3rd 10-Year Interval Generating Revision 1 Cold Shutdown Justification - CSJ05 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-V-13 1 A RCIC pump discharge isolation, and Reactor Core Isolation containment isolation, and reactor coolant Cooling pressure isolation 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 Rev 1 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 This valve will be full stroke exercised during cold shutdown.

IST Program Plan Columbia Station Page 146 of 185 3rd 10-Year Interval Generating Revision 1 Cold Shutdown Justification - CSJ06 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 1 A LPCS discharge isolation to the reactor Low Pressure Core vessel. 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 Frequency These valves will be full stroke exercised during cold shutdown

IST Program Plan Columbia Generating Station Page 147 of 185 3rd 10-Year Interval Revision 1 Cold Shutdown Justification - CSJ07 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 1 A Containment Iso., RWCU Pump Discharge Iso.

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 Rev 1 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 Generatin Page 148 of 185 3rd 10-Year Interval Columbia Station Revision 1 Cold Shutdown Justification - CSJ08 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 1 A Main Steam Line A Inboard Isolation Valve MS-V-22B 1 A Main Steam Line B Inboard Isolation Valve MS-V-22C 1 A Main Steam Line C Inboard Isolation Valve MS-V-22D 1 A Main Steam Line D Inboard Isolation Valve Main Steam MS-V-28A 1 A Main Steam Line A Outboard Isolation Valve MS-V-28B 1 A Main Steam Line B Outboard Isolation Valve MS-V-28C 1 A Main Steam Line C Outboard Isolation Valve MS-V-28D 1 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 Frequency These valves will be full stroke exercised and stroke timed during cold shutdown conditions.

IST Program Plan Columbia Station Page 149 of 185 3rd 1O-Year Interval Generating Revision 1 Cold Shutdown Justification - CSJ09 DELETED

IST Program Plan Columbia Station Page 150 of 185 3rd 10-Year Interval Generating Revision 1 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 Main Steam Auxiliary 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 Frequency This valve will be full stroke exercised during cold shutdown.

IST Program Plan Columbia Generating Station Page 151 of 185 3rd 10-Year Interval Revision 1 Cold Shutdown Justification - CSJ11 Description It is not practicable to full or partial stroke exercise open the following MS valves during normal Plant operation.

Affected Valves Class Cat. Function System(s)

MS-V-67A, B, C, D 1 A 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.

IST Program Plan Columbia Station Page 152 of 185 3rd 10-Year Interval Generating Revision 1 Cold Shutdown Justification - CSJ12 Description It is not practicable to full or partial stroke exercise open the following RHR valves during normal Plant operation.

Function System(s)

Drywell Spray Header (2nd outboard CIV)

Residual Heat Removal 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 SER 41-85, 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 Program Plan Columbia Station Page 153 of 185 3rd 10-Year Interval Generating Revision 1 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-1 6 1 A Containment Isolation Main Steam MS-V-1 9 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-1 9 is in the steam tunnel.

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 Program Plan Columbia Station Page 154 of 185 3rd 10-Year Interval Generating Revision 1 5.8 Refueling Outage Justifications ISTC-351 0 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.

IST Program Plan Columbia Station Page 155 of 185 3rd 10-Year Interval Generating Revision 1 Refueling Outage Justification - ROJ01 (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 vessel Standby Liquid Control SLC-V-7 1 AC 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.

IST Program Plan Columbia Generatin Station Page 156 of 185 3rd 10-Year Interval Revision 1 Refueling Outage Justification - ROJO2 (INACTIVE- 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-31A,B 2 AC Instrument air supply to ADS valves (inside containment)

CIA-V-40M,N,P, 2 AC Instrument air to ADS Accumulators (inside Containment Instrument R,S,U,V containment) Air CIA-V-24A,B,C,D 2 AC Instrument air to Accumulators for inboard MSIVs (inside containment)

CAS-V-29A,B,C,D 3 AC Control air to Accumulators for outboard MSIVs (inside steam tunnel)

Justification

1. NUREG-1 482 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-1 482 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-V-40 Series check valves are located inside the containment and are inaccessible during power operations and during cold shutdowns when the containment is inerted. There is no way to remotely isolate the valves and observe the pressure decay of the accumulators.

3. There is no local or remote position indication for these check valves. These valves can be verified closed only by performing a leak-rate test. This requires reconfiguring the system, hook-up and disconnection of leak test apparatus. (Applies to all referenced valves.)

IST Program Plan Columbia Station Page 157 of 185 3rd 10-Year Interval Generating Revision 1 Refueling Outage Justification - ROJO2 (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, 31B and 40 series.

2. Closure of CIA-V-21, 31A, and 31B will be verified by normal 10 CFR 50, Appendix J (Type C) testing.

IST Program Plan Columbia Station Page 158 of 185 3rd 10-Year Interval Generating Revision 1 Refueling Outage Justification - ROJO3 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)

RHR-V-209 1 AC Containment isolation and Reactor Coolant System Pressure Boundary and pressure relief Residual Heat Removal for 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> per an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 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-1 482 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 Columbia Station Page 159 of 185 3rd 10-Year Interval Generating Revision 1 Refueling Outage Justification - ROJO4 (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 PI-V-X73e/1 2 AC Containment Isolation 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 Frequency These valves will be exercised during each refueling outage.

IST Program Plan Columbia Station Page 160 of 185 3rd 10-Year Interval Generating Revision 1 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.

Affected Valves Class Cat. Function System(s)

RCC-V-219 2 AC Pressure relief around RCC-V-40 check Reactor Closed Cooling Water 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.

IST Program Plan Columbia G e tin Station Page 161 of 185 3rd 10-Year Interval Cb enerating Revision 1 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-10A, B 1 AC Reactor feedwater inboard check valve RFW-V-32A, B 1 AC Reactor feedwater outboard check valve Reactor Feedwater Justification

1. NUREG-1 482 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 Frequency 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 Station Page 162 of 185 3rd 10-Year Interval Generating Revision 1 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 (Typ 18) downcomers of the main steam relief valves. Main Steam MS-V-38 Series 3 C Close: To direct steam to the quenchers (Typ 18) in the 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-1 482 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 Columbia Station Page 163 of 185 3rd 10-Year Interval Generating Revision 1 Refueling Outage Justification - ROJ08 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 1 AC RCIC discharge to the reactor vessel Reactor Core Isolation head Cooling RCIC-V-65 1 C RCIC discharge to the reactor vessel Reactor Core Isolation head Cooling LPCS-V-6 1 AC LPCS discharge to the reactor vessel Low Pressure Core Spray HPCS-V-5 1 AC HPCS Discharge to the reactor vessel High Pressure Core I_ Spray RHR-V-41A, B, C 1 AC RHR Loop A, B, C discharge to the Residual Heat reactor vessel Removal RHR-V-50A, B 1 AC RHR Loop A, B discharge to the Residual Heat recirculating pump discharge Removal 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 containment.

IST Program Plan Columbia Station Page 164 of 185 3rd 10-Year Interval Generating Revision 1 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-1 482 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.

IST Program Plan Columbia Station Page 165 of 185 3rd 10-Year Interval Generating Revision 1 Refueling Outage Justification - ROJO9 (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 CSP-V-65 2 AC related control air to containment isolation valves CSP-V-5, 6 and 9. Containment Supply and Purge CSP-V-70 through Open: To provide safety related control CSP-V-79 2 C air to containment isolation valves CSP-V-5, 6 and 9.

Justification

1. There is no local or remote position indication for these check valves. Testing these valves requires partial depressurization of the supply header. Although, only partial depressurization is expected, full depressurization could easily occur due to leaky boundary valves, operator error, or check valve failure. Depressurization of the supply header to CSP-V-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 Columbia Station Page 166 of 185 3rd 10-Year Interval Generating Revision 1 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 1 A Isolate RHR shutdown cooling suction line Residual Heat RHR-V-9 1 A from reactor recirculation loop A Removal Justification

1. Valves are interlocked with reactor coolant system pressure such that these valves automatically close to protect the RHR pump suction line from elevated reactor coolant system pressures. Opening circuit is disabled by the same pressure interlocks. Overpressurization of the suction line may cause the loss of RHR shutdown cooling capability. Interlocks cannot be bypassed with normal control circuits.

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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 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 Station Page 167 of 185 3rd 10-Year Interval Generating Revision 1 Refueling Outage Justification - ROJ11 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)

Residual Heat 1 A CIV, HI-LO Pressure Isolation Removal RHR-V-123A, B 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 Frequency During each refueling outage, each of these valves will be exercised per ISTC Code requirements.

IST Program Plan Columbia Station Page 168 of 185 3rd 10-Year Interval Generating Revision 1 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 C Suppression pool to RCIC-P-1 suction Reactor Core Isolation check Cooling 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.

IST Program Plan Columbia Station Page 169 of 185 3rd 10-Year Interval Generating Revision 1 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 RCC-V-21 2 A Isolation valves for reactor closed Reactor Closed cooling water lines penetrating the Cooling Water RCC-V-40 2 A primary containment.

RCC-V-1 04 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 Ge . Station Page 170 of 185 3rd 10-Year Interval Revision 1 Refueling Outage Justification - ROJ14 (INACTIVE- FOR CHECK VALVES RRC-V-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 Reactor for the recirculation pumps seal Recirculation RRC-V-16A,B 2 A purge line Justification Closure of the Category A isolation valves (RRC-V-1 6A/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 Columbia Station Page 171 of 185 3rd 10-Year Interval Generating Revision 1 Refueling Outage Justification - ROJ15 (INACTIVE- FOR CHECK VALVES CIA-V-52A TO 66A, CIA-52B TO 70B, CIA-V-1 03A & 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-1B to 19B 3 B Containment CIA-SPV-1A to i5A 3 B CIA nitrogen bottle auto isolation valve. Instrument Air 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 Columbia Generating Station Page 172 of 185 3rd 10-Year Interval Revision 1 5.9 Relief Requests From Certain Subsection ISTC and Mandatory Appendix I Requirements Relief Requests either provide alternative to Code requirements in accordance with 10 CFR 50.55a(a)(3)(i) or relief from impractical Code requirements in accordance with 10 CFR 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 Station Page 173 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RV01 Relief Request in Accordance with 10 CFR 50.55a(f)(5)(iii)

- Inservice Testing Impracticality -

ASME Code Components Affected Affected Valves Class Cat. Function System(s)

CVB-V-1AB, CD, 2 AC To break vacuum on the drywell to suppression Primary Containment EF, GH, JK, LM, chamber downcomers and to limit steam leakage Cooling and Purge NP, QR, ST from the downcomer to the wetwell gas space.

Applicable Code Edition and Addenda

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

Proposed Alternative and Basis for Use These valves will be leak tested in accordance with Columbia Generating Station Technical Specifications SR 3.6.1.1.2, SR 3.6.1.1.3, and SR 3.6.1.1.4 during refueling outages.

Technical Specifications SR 3.6.1.1.2 drywell-to-suppression chamber bypass leakage test monitors the combined leakage of three types of pathways: (1) the drywell floor and downcomers, (2) piping externally connected to both the drywell and suppression chamber air space, and (3) the suppression chamber-to-drywell vacuum breakers. The test frequency is 120 months and 48 months following one test failure and 24 months if two consecutive tests fail until two consecutive tests are less than or equal to the bypass leakage limit.

IST Program Plan Columbia Generating Station Page 174 of 185 3rd 10-Year Interval Revision 1 Relief Request - RV01 (Contd.)

Proposed Alternative and Basis for Use Technical Specifications SR 3.6.1.1.3 establishes a leak rate test frequency of 24 months for each suppression chamber-to-drywell vacuum breaker pathway, except when the leakage test of SR 3.6.1.1.2 has been performed (Note to SR 3.6.1.1.3). Thus, each suppression chamber-to-drywell vacuum breaker pathway will have a leak test frequency of 24 months by either SR 3.6.1.1.2 or SR 3.6.1.1.3.

Technical Specifications SR 3.6.1.1.4 establishes a leakage test frequency of 24 months to determine the suppression chamber-to-drywell vacuum breaker total bypass leakage, except when the bypass leakage test of SR 3.6.1.1.2 has been performed (Note to SR 3.6.1.1.4). Thus, the determination of suppression chamber-to-drywell vacuum breaker total leakage will have a leak test frequency of 24 months by either SR 3.6.1.1.2 or SR 3.6.1.1.4.

These valves are also verified-closed by position indicators, exercised, and tested in the open direction using a torque wrench per Technical Specification SR 3.6.1.7.1, SR 3.6.1.7.2, and SR 3.6.1.7.3. In accordance with a separate commitment, the valves are visually inspected each refueling outage.

Quality/Safety Impact The leakage criteria and corrective actions specified in the Columbia Generating Station Technical Specifications SR 3.6.1.1.2, SR 3.6.1.1.3, and SR 3.6.1.1.4 combined with visual examination of valve seats every refuel outage provides 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. RVO1.

References Letter G12-07-016, dated February 9, 2007, Carl F. Lyon (NRC) to J. V. Parish (Energy Northwest),

"Columbia Generating Station - Issuance of Amendment RE: Suppression Chamber-to-Drywell Vacuum Breakers and Drywell-to-Suppression Chamber Bypass Leakage Test (TAC No. MDl 225)".

NRC Acceptance/SER Dated May 15, 2007 Relief granted as requested (G12-07-087).

IST Program Plan Columbia Generating Station Page 175 of 185 3rd 10-Year Interval Revision 1 Relief Request - RV02 Relief Request in Accordance with 10 CFR 50.55a(f)(5)(iii)

- Inservice Testing Impracticality -

ASME Code Components Affected

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-11 A & 11 B are controlled by thermostats which regulate main control room air temperature.

IST Program Plan Columbia Generatn Station Page 176 of 185 3rd 10-Year Interval Revision 1 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 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. The proposed tests are performed in accordance with Code Case OMN-8, using the applicable paragraphs of 2001 ASME OM Code with 2002 and 2003 addenda.

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.

NRC Acceptance/SER Dated May 15, 2007 Relief granted as requested (G12-07-087).

IST Program Plan Columbia Station Page 177 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RV03 Proposed Alternative in Accordance with 10 CFR 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-X80-1 2 A PSR-V-X83-1 2 A PSR-V-X77A1 1 A PSR-V-X82-1 2 A Containment Isolation Post Accident Sampling PSR-V-X84-1 2 A PSR-V-X77A3 1 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 ADplicable Code Reauirement OM Subsection ISTC-5150, Solenoid-Operated Valves, Stroke Testing

Reason for Request

Subsection ISTC-5151 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.

IST Program Plan Columbia Station Page 178 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RV03 (Contd.)

Quality/Safety 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.

NRC Acceptance/SER Dated March 23, 2007 Relief granted as requested (G12-07-053).

IST Program Plan Columbia Station Page 179 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RV04 Proposed Alternative in Accordance with 10 CFR 50.55a(a)(3)(i)

- Alternative Provides Acceptable Level of Quality and Safety -

ASME Code Components Affected Affected Valves Class Cat. Function System(s)

MS-RV-1A, B, C, D 1 C MS-RV-2A, B, C, D 1 C Overpressure Protection Main Steam MS-RV-3A, B, C 1 C MS-RV-3D 1 C Overpressure Protection and Auto MS-RV-4A, B, C, D 1 C Depressurization System to lower reactor pressure sufficient to allow initiation of Low MS-RV-5B, C 1 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 I, 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.

ST Program Plan olumbia Station Page 180 of 185 3rd 10-Year Interval Generating Revision 1 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 1-3310(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.

IST Program Plan Columbia Station Page 181 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RV04 (Contd.)

Proposed Alternative and Basis for Use

1. "Valves" and "accessories" (actuators, solenoids, etc.) shall be tested separately and meet Paragraph 1-1320 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 1-3310(d) and (e) tests to be performed during outage prior to Paragraphs 1-3310 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 1-3310(h).

Quality/Safety 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.

IST Program Plan Columbia Station Page 182 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RV04 (Contd.)

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. RV05.

NRC Acceptance/SER Dated March 23, 2007 Relief granted as requested (G12-07-053).

IST Program Plan Columbia Station Page 183 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RV05 Proposed Alternative in Accordance with 10 CFR 50.55a(a)(3)(i)

- Alternative Provides Acceptable Level of Quality and Safety -

ASME Code Components Affected Affected Valves Class Cat. System(s) / Function PI-EFC-X37E, F 1 C System(s): Process Instrumentation for various PI-EFC-X38A, B, C, D, E, F 1 C systems connected to RPV PI-EFC-X39A, B, D, E 1 C Function: Excess flow check valves are provided in PI-EFC-X40C, D 1 C each instrument process line that is Part of the reactor coolant pressure PI-EFC-X40E, F 2 C boundary. Design and installation of the PI-EFC-X41C, D 1 C excess flow check valves at Columbia PI-EFC-X41 E, F 2 C Generating Station conform to Regulatory Guide 1.11.

PI-EFC-X42A, B 1 C PI-EFC-X44A Series (Typ 12) 1 C Close: The reactor instrument line excess flow PI-EFC-X44B Series (Typ 12) 1 C check valves close to limit the flow in the respective instrument lines in the event of PI-EFC-X61A, B 1 C an instrument line break downstream of PI-EFC-X62C, D 1 C the EFCVs outside containment.

PI-EFC-X69A, B, E 1 C PI-EFC-X70A, B, C, D, E, F 1 C PI-EFC-X71A, B, C, D, E, F 1 C PI-EFC-X72A 1 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 1 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-X110 1 C PI-EFC-X1 11 1 C PI-EFC-X112 1 C PI-EFC-X113 1 C PI-EFC-X114 1 C PI-EFC-X1 15 1 C

IST Program Plan Generating Page 184 of 185 3rd 10-Year Interval Columbia Station Revision 1 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 1.01 E-7 per hour.

There have been no failures 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 Station Page 185 of 185 3rd 10-Year Interval Generating Revision 1 Relief Request - RV05 (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 G12-01-017, 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)"

NRC Acceotance/SER Dated March 23, 2007 Relief granted as requested (G[2-07-053).